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215-203
F ConocoPhillips NOV10 201b Alaska _ P.O. BOX 100360 kt ,.I ' ANCHORAGE,ALASKA 99510-0360 _fi .:/ November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SEWEDMAE al?, Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date _ ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 ( 2S-01 50103207270000 2152030 1.5' NA 98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 ItiCk#EIV M.; STATE OF ALASKA APR 1 z 2016 Ili 2 7 1 6 (� A SKA OIL AND GAS CONSERVATION COMMI )N tml REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon I-. Plug Perforations ( Fracture Stimulate l" Pull Tubing I....... Operations Shutdown f--- Performed: Performed: Suspend I Perforate I...... Other Stimulate Alter Casing I..... Change Approved Program Plug for Redrill I— Perforate New Pool i— Repair Well I Re-enter Susp Well „— P 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fv. Exploratory "i....... 215-203 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic C Service 50-103-20727-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25604,25603,25589 KRU 2S-01 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 21720 feet Plugs(measured) None true vertical 6440 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 12304, 12388 true vertical 0 feet (true vertical) 6245, 6166 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 119 119 SURFACE 2911 10 3/4 2952 2603 INTERMEDIATE 12536 7 5/8 12575 6206 LINER 8058 41/2 20446 6403 Perforation depth: Measured depth: n/a SCANNED MAY 1 8 201E True Vertical Depth: n/a Tubing(size,grade, MD,and TVD) 3.5, L-80, 12449 MD, 6180 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PRODUCTION PACKER @ 12304 MD and 6145 TVD PACKER-BAKER HRD-EZXP Flex Lock Liner Top Packer @ 12388 MD and 6166 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13,400'-16,492', 17,775'-20,357' Treatment descriptions including volumes used and final pressure: Total well - 10 stages 853,703#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 0 130 660 Subsequent to operation 0 0 0 125 1930 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Development Service l— Stratigraphic 1— Daily Report of Well Operations F.-- .\ Exploratory P �J 16.Well Status after work: t Copies of Logs and Surveys Run l Oil I— Gas , WDSPL Printed and Electronic Fracture Stimulation Data F GSTOR ...... WINJ fl" WAG WAG . GINJ r...... 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: 316-026 Contact Adam Klem (J 263-4529 Email Adam.Klemconocophillips.com Printed Name Adam Klem Title Completions Engineer Signature Phone:263-4529 Date v'rt— Jr'/p/1� ro k.acc:wt.t Form 10-404 Revised 5/2015 if :(ERBDMS LU T v 201Submit Original Only caw s77zo/G • 2S-01 • DTTM JOBTYP SUMMARYOPS START 2/6/16 FRACTURING Pump DataFrac and first 5 stages of frac. Place 446,961# proppant behind pipe. Screenout during stage 5 displacement with 97bbls left for ball seat. Placed 119,938# of 124,425# behind pipe during stage 5. 2/16/16 DRILLING PERFORMED WEEKLY BOP TEST, RIH FOR A DRY TAG, TAGGED AT 16042' SUPPORT CTMD, CLEAN OUT DOING 15BBL GEL PILLS FOLLOWED WITH SLICK -CAPITAL SEAWATER, CLEANED OUT DOWN TO 17888' CHASING EACH BITE UP THE HOLE. INJECTION SRIT 1 BPM WHP 550, IA 1158, OA201 1.5 BPM WHP 714, IA 1138, OA 194 2 BPM WHP 830, IA 1115, OA 188 2.5 BPM WHP 903 IA 1105, OA 185 3 BPM, WHP 1023, IA 1090, OA 182 3.5 BPM, WHP 1857, IA 1068, OA 179 4 BPM, WHP 2345, IA 1010, OA 197 4.5 BPM, WHP 2678, IA 944, OA 219 5 BPM, WHP 2752, IA 939, OA 228 STACK BACK FOR THE NIGHT, COME GET UNIT IN THE MORNING. 2/17/16 FRACTURING RIGGED DOWN THE COIL UNIT, MOVED OVER TO 2S-13 GOT RIGGED UP 2/19/16 FRACTURING Attempt to pump 2.313 ball to seat, unable to obtain enough injection rate after dropping ball to shift seat and continue frac. Ready for coil. 2/20/16 FRACTURING RIH WITH 2.313" SHIFTING NOZZLE. TAG SLEEVE AT 17134'. PRESSURED UP ON BACK SIDE, WOULD NOT HOLD A CONSTANT PRESSURE. WE COULD PUMP INTO THE WELL @ 3.8 BPM 3700 PSI, PUMPED 210 BBLS AWAY. WE TRIED MULTIPLE THINGS TO GET THE SLEEVE TO SHIFT. POOH TO LOOK AT TOOLS AND COME UP WITH GAME PLAN FOR TOMORROW. ****JOB IN PROGRESS**** 2/21/16 FRACTURING CTU standing by waiting for TCP operations. 2/22/16 FRACTURING Perforate from 17,100' to 17,120' using Halliburton's 2" 6 SPF 60 Phasing Millennium HMX Perf Gun. Inspection of perf gun at surface showed ASF. Perform Injectivity test with SLB CTU and got unsatisfactory results 2.5 bpm = 2,700 psi 3.0 bpm = 2,800 psi 3.5 bpm = 3,400 psi and climbing After POOH, rigged up SLB Cement Van to perform an injectivity utilizing higher rates and pressures 3.5 bpm = 6,300 psi and climbing 2.5 bpm = 5,600 2/23/16 FRACTURING Perform Fill Clean Out above frac sleeve at 17,135' and estimate 47' of fill. Maintain 1:1 returns for the majority of the cleanout. Jet wash perf zone with multiple passes at 4 fpm. Perform njectivity test down the backside of coil, leveling off at 3.8 bpm, 3150 psi. Chase final gel pill to surface. Job in Progress. 2/24/16 FRACTURING SLB CTU #5: PERFORM WEEKLY BOP TEST. SHIFT FRAC SLEEVE#6 OPEN AT 16,493'WITH 2.375" SHIFTING NOZZLE. WITH COIL OUT OF THE WELL, CONFIRM INJECTIVITY PUMPING 7 BPM AT 2770 PSI WHP. RIG UNIT BACK FOR THE NIGHT. 2/25/16 FRACTURING SLB CTU #5: RIG DOWN COIL UNIT AND MOB TO DEADHORSE FOR UNIT#11 SWAP. 3/12/16 FRACTURING Pump remaining 5 stages of frac. Place —420,000# proppant behind pipe. Job complete 3/13/16 FRACTURING ATTEMPT TO LOAD WELL W/CRW SW (PUMPED 57 BBL & BEGAN TO LOCK UP). FP W/ DIESEL; BRUSH n' FLUSHED W/2.79 GAUGE RING DOWN TO D- NIPPLE @ 12,3330' RKB; SET 2.75" CA-2 PLUG W/GAUGES © SAME. ATTEMPT TO MITT& DDT (BOTH FAILED). IN PROGRESS. • 2S-01 3/14/16 FRACTURING PULLED 2,75" CA-2 PLUG W/GAUGES @ 12,330' RKB; SET COLLAR STOP @ 2875' RKB; SET 3 1/2 SIM PLUG @ 2863' RKB; MITT & 30 MIN DDT/NFT (PASSED); APPLIED PRESSURE BACK ON TBG & SIM PLUG MOVED DOWN HOLE TO COLLAR STOP; PULLED SIM PLUG & COLLER STOP (FLAGGED WIRE FOR RBP). IN PROGRESS. 3/15/16 FRACTURING SET 3 1/2" STATEWIDE RBP @ 2856'. MITT 3000 PSI (PASSED). DDT/NFT (PASSED). SET 2.75"AVA CATCHER @ 2835' SLM. PULLED DV FROM 2770' RKB. READY FOR DHD 3/16/16 FRACTURING Swap out 1.75"coil tubing for 2" coil tubing. Swap out BOP's, gooseneck rollers, etc. 3/16/16 FRACTURING (SEC) TEST BPV FOR TREE SWAP (PASS). UPPER T POT (PASS), UPPER T PPPOT(PASS), LOWER T POT (PASS), LOWER T PPPOT (PASS). IC POT (PASS), IC PPPOT (PASS). 3/17/16 FRACTURING Swap out 1.75"to 2.00" Coil Tubing. 3/17/16 FRACTURING (SEC): TREE SHELL TEST (PASSED). 3/17/16 FRACTURING PULL CATCHER @ 2834' SLM, PULL RBP @ 2866' RKB, ***DEPLOY CATCHER (OAL= 48", MAX OD= 2.79")***, JOB IN PROGRESS. 3/18/16 FRACTURING PULLED DV'S @ 12,194 & 5987' RKB, SET OV @ 12,194, SET GLV @ 5987' RKB. PULLED & REPLACED DV© 10,715' RKB. SET DV @ 2770' RKB. PULL CATCHER @ 12,330' RKB, DRAW DOWN ON IA TO CONFIRM INTEGRITY, READY FOR COIL. NOTE: BK LATCH © 10,715 & 12,194' RKB WERE FLOW CUT BY FRAC SAND. 3/18/16 FRACTURING Swap Pipe 3/19/16 FRACTURING MIRU CTU; Function & PT BOP; Pump 1-3/8' ball to drift CT & load CT w/slick diesel; Pull Test CT connector(30K) 3/20/16 FRACTURING Mill out#1-4 Frac Sleeves and Balls (13,339', 14,007' 14967', 15565'); POOH, lay down motor and mill, pickup Venturi tool; Venturi 12,000' - 14, 450' and continue TIH w/Venturi tool. 3/21/16 FRACTURING Venturi tool cleanout to 15701'; Mill out Frac Sleeves and Balls#5-8 (16493', 17135', 17776, 18407'); POOH due to multiple overpulls to lay down motor and mill and pick up wash nozzle for FCO to remove junk in hole; RIH w/Jet-Swirl nozzle to 350'; stop due to high snub weights (up to-21 K); Inspecting injector to determine cause of abnormal RIH weights; IN PROGRESS 3/22/16 FRACTURING POOH from 350' due to damaged injector gooseneck; remove damaged gooseneck and replace with new unit; PU 2.20" FCO Jet-Swirl nozzle BHA; Rig Injector to wellhead and pressure test 300/4000 3/23/16 FRACTURING PERFORM FCO TO TOP OF FRAC SLEEVE#2 AT 19046' WITH JSN, SSW, AND FLOVIS GEL. MAINTAIN 1:1 RETURNS WITH MINIMAL SOLIDS. RD FCO BHA, MU FRAC SLEEVE MILLING ASSY AND RIH TO MILL REMAINING TWO FRAC SLEEVES. IN PROGRESS, 24 HOUR OPERATIONS. 3/24/16 FRACTURING SLB CTU #11: MILL REMAINING TWO FRAC SLEEVES AT 19046' & 19717' WITH 2.70" CONCAVE FRAC PORT MILL. WELL LEFT SHUT IN AND FREEZE PROTECTED. READY FOR FLOWBACK. • KUP OD 2S-01 Con©coPhilttps Well Attrib Max Angle&III TD 411 Au$w3_1i1U Wellbore API/UWI Field Name Wellbore Status ncl 0 MD(ftKB) Act Btm(ftKB) (.0,- hilpa 501032072700 KUPARUK RIVER UNIT PROD 92.13 16,461.60 21,720.0 n...e Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-01,4/11/20161139.40 AM SSSV: NONE Last WO: 39.61 1/29/2016 Vertical sohernabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;36.9 Last Tag Rev Reason:GLV CIO,MILLED FRAC pproven 3/28/2016 SLEEVES SEE NOTES gin Casing Strings "" Casing Description OD(in) ID(in) Top(KKR) Set Depth(ftKB) Set Depth(TVD'... Wt/Len(I...Grade Top Thread I CONDUCTOR 16 15.250 38.5 118.5 118.5 62.58 B Welded Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 40.4 2,951.7 2,603.0 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread X0 REDUCING;810W INTERMEDIATE 75/8 6.875 39.0 12,574.6 6,206.3 29.70 L-80 Hyd 563 Iil'r11Casing Description OD(in) 'ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread �ti CONDUCTOR,385-118.5• i PRODUCTION LINER 41/2 3.958 12,388.0 20446.1 6,402.6 12.60 L-80 IBT-m 4 Liner Details GAS LIFT,2,770.0 W Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(.) Item Des Corn (in) 4 I 12,388.0 6,166.2 76.52 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.970 packer L-80 Hyd 521 pin SURFACE;40.42,951.7 12,412.7 6,171.9 76.87 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#L-80 4.240 " Hyd 563 box x box 12,415.1 6,172.5 76.91 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger L-80 4.800 GAS LIFT,5,9870 Hyd 563 pin x pin 12,424.9 6,174.7 77.05 XO Reducing 5.5"Hyd 563 15.5#box x 5"15#H521 pin Crossover 4.420 4 Jr Coupling 12,436.2 6,177.2 77.21 SBE Seal Bore Extension 80-40 5"H521 x 4%"H521 box 4.000 GAS LIFT,10,715.1 13,087.3 6,320.8 82.04 Swell Packer Baker-"Swell Packer"-"A",Water activated 3.958 (922/834)SN:050011-001-9 GAS LIFT;12,194.6 13,400.3 6,350.7 84.63 FRAC PORT Baker 4-1/2"Frac Sleeve#10-(2.625"Ball,Drift ID 2.700 2.563")PN:10437088 MB 14,001.3 6,357.3 89.91 FRAC PORT Baker 4-1/2"Frac Sleeve#9-2.563"Ball,Drift w/ 2.700 SLEEVE;12,253.8 2.50"PN:10437087 GAUGE;12,278.3 1 14,965.7 6,376.7 87.02 FRAC PORT Baker 4-1/2"Frac Sleeve#8-(2.5"Ball,Drift w/ 2.700 Ing 2.438")PN:10437086 xO Threads;12,294.1 IN PACKER;12,303.5 15,563.0 6,379.8 89.63 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(2.438"Ball,Drift w/ 2.700 xo Threads;12,310.2 2.375")PN:10437085 16,492.8 6,374.5 91.97 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(2.375"Ball,Drift w/ 2.700 2.313")PN:10437084 Ill le 17,134.8 6,372.6 89.00 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(2.313"Ball,Drift w/ 2.700 LOCATOR;12,383.4 =If 2.25")PN:10437083 LOCATOR;12,384.4 )I! 17,775.6 6,385.2 87.62 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(2.25"Ball,Drift w/ 2.700 2.188") PN:10437082 E ! 18,407.5 6,393.7 89.10 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.188"Ball,Drift w/ 2.700 :'-1 2.125")PN:10437081 Il /I 19,046.5 6,393.3 89.30 FRAC PORT Baker 4-1/2"Frac Sleeve#2-(2.125"Ball,Drift w/ 2.700 2.063")PN:10437070 'ii., ..1a 19,717 9 6,397.2 89.50 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.063"Ball,Drift w/ 2.700 2.00")PN:H810-090416 SHOE;12,448.0 Ai I20,357.0 6,401.5 89.31 Frac Sleeve Baker 4-1/2"Alpha Sleeve PN 10487898 3.020 20,370.5 6,401.6 89.31 SLEEVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN 3.958 t 10488946 20,411.7 6,402.1 89.30 COLLAR 4-1/2"Weatherford Model 402E Float collar 3.958 INTERMEDIATE,39.0-12,574.6 Tubing Strings .- - Tubing Description 'String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft..]Set Depth(TVD)(...I Wt( Ib/ft) 'Grade I Top Connection TUBING 31/2 2.992 369 1244901 6,180.0 9.301L-80 1EUE 8rd-M Completion Details 1-:: Nominal ID ,-g Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 1 36.9 36.9 0.15 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 - 81.0 81.0 0.33 XO XO,4-1/2"12.6#L-80(BTM box x 3-1/2"9.3#L-80 EUE- 3.000 REDUCING Mod pin Sand Frac;13400.0 ° -• 12,253.9 6,131.1 73.09 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.810 11 8 2.812"profile ENNO I, 12,278.3 6,138.1 73.72 GAUGE Schlumberger Gauge Carrier 3-1/2"EUE P X P 2.913 (measured w/collar on top) I " ,MO 12,303.5 6,145.0 74.36 PACKER Baker Premier Production Packer 2.890 I 12,330.0 6,152.0 75.05 NIPPLE Camco 2.75 D nipple 4.5"OD 2.750 -. 12,383.4 6,165.2 76.43 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub-- 3.020 E- I Large OD - - 12,384.5 6,165.4 7646 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 2.990 small OD t I 12,448.0 6,179.8 77.38 SHOE Mule shoe WLEG 2.992 Stimulations&Treatments aire Min Top Max Btm I I Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 13,400.0 16,492.0 6,350.7 6,374.5 Sand Frac 3/12/2016 PUMPED STAGES 7-11 PLACING 402,255#16/20 CARBOLITE PROPPANT. I ® ) 17,775.0 20,357.0 6,385.2 6,401.5 Sand Frac 2/6/2016 PUMPED DATAFRAC AND STAGES 1-5 PLACING MS 446,961#16/20 CARBOLITE PROPPANT. SCREENED OUT DURING DISPLACEMENT. S Send Frac;17,77E0 Mandrel Inserts t.:... ._.. St ati ■ N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date Corn 1 2,770.0 2,504.2 Camco KBMG 1 GAS LIFT DMY BK 3/18/2016 n r] 2 5,987.0 3,692.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 2,057.0 3/18/2016 3 10,715.1 5,489.4 Camco KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 1/28/2016 II 4 12,194.6 6,113.1 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 3/18/2016 PRODUCTION LINER,12,3 .0 -20,44686.1 , • KUP OOD • 2S-01 IIor�occPhrillips A 1sk 1.Inc ConoCt PhUlips ••• 2S-01.4/11/201611:39:40 AM Vertical schematic(actual) HANGER;36.9 ;a°it Notes:General&Safety End Date Annotation El a 3/24/2016 NOTE:MILLED FRAC SEATS TO 2.70"ID XO REDUCING;81.0 iv .._A.CONDUCTOR;38.5-118.5• II GAS LIFT;2,770.0 iii: SURFACE;40.4-2,951.7— GAS LIFT;5,987.0 i * GAS LIFT;10,715.1 II GAS LIFT;12,794.6 in NI SLEEVE;10253.8 7 GAUGE;12,278.3 X0 Threads;12,294.1 ill PACKER;12,303.5 I XO Threads;12,310.2 MI Mr Si Mg LOCATOR;12,383.4 LOCATOR;12,384.4 `l� F.. i! i1' lit SHOE;12,448.0 Ai 1 it INTERMEDIATE;39.0-12,574.8 f I re a tII Sand Frac,13,400.0 o; pI It i 17- p1 X0 t I IF Sand Frac,17,775.0 ENEI Wia 0 III } 0 II PRODUCTION LINER;12,388.0 -20446.1' - 0 0 ! I Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 2/5/2016 Job End Date: 3/12/2016 State: Alaska County:erHarrison72 - B-00 Frac API Number: 50-103-20727-00-00 Focus Operator Name: ConocoPhillips Company/Burlington Cheri c-:(Disclosure Registry Resources Well Name and Number: 2S-01 Longitude: -150.15388500 Y NI: Latitude: 70.21970500 "wr a Datum: NAD83 10(0ii&Gas Federal/Tribal Well: NO True Vertical Depth: 6,440 Total Base Water Volume(gal): 550,130 Total Base Non Water Volume; 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number Concentration in Concentration in Comments (CAS#) o Additive o HF Fluid ,,,� (/o by mass)"' (/o by mass)" on;,'°erta a;,„,..2 .aaw �:,.� g ,._ ;.�..:�. - � ,,s. ,- YF127FIexD.WF127, Schlumberger Surfactant,Breaker, W F127, Stabilizing Agent, YF130FIexD:WF130 2rosslinker,Guar Slurry,Scale Inhibitor, Additive,Bactericide, uroppinq Agent Water(Including Mix Water NA 83.86485 Supplied by Client)* Ceramic materials and wares, 66402-68-4 94.13931 15.18952 _ chemicals Distillates,petroleum, 64742-47-8 1.62327 0.26192 Hydrotreated light Guar gum 9000-30-0 1.50243 0.24242 Ethylene Glycol 107-21-1 0.62110 0.10022 Boronatrocalcite 1319-33-1 0.60510 0.09765 Diammonium peroxodisulphate 7727-54-0 0.39543 0.06380 2-Propenoic acid,polymer with 129898-01-7 0.25323 0.04086 sodium phosphinate 2-butoxyethanol 111-76-2 0.10854 0.01751 Propan-2-ol 67-63-0 0.10854 0.01751 Alcohol,C11 linear,ethoxylated 34398-01-1 0.09969 0.01609 0 • Vinylidene 25038-72-6 0.08573 0.01383 chloride/methyl acrylate copolymer Sodium hydroxide(impurity) 1310-73-2 0.07360 0.01187 Sorbitol 50-70-4 0.07257 0.01171 C12-15 alcohol ethyoxylated 68131-39-5 0.06245 0.01008 Sodium chloride 7647-14-5 0.05114 0.00825 Sodium tetraborate 1330-43-4 0.05096 0.00822 Amine treated smectite clay 68153-30-0 0.04173 0.00673 Calcium Chloride 10043-52-4 0.02584 0.00417 Monosodium fumarate 7704-73-6 0.01591 0.00257 Fumaric acid 110-17-8 0.01591 0.00257 Boric acid 10043-35-3 0.01592 0.00257 1-undecanol 112-42-5 0.00868 0.00140 Diatomaceous earth,calcined 91053-39-3 0.00702 0.00113 Silicon Dioxide 7631-86-9 0.00417 0.00067 2,2"-oxydiethanol(impurity) 111-46-6 0.00273 0.00044 Magnesium silicate hydrate(talc;14807-96-6 0.00262 0.00042 Magnesium nitrate 10377-60-3 0.00140 0.00023 poly(tetratuoroethylene) 9002-84-0 0.00112 0.00018 Potassium chloride(impurity) 7447-40-7 0.00082 0.00013 Diutan gum 125005-87-0 0.00080 0.00013 5-chloro-2-methyl-2h- 26172-55-4 0.00075 0.00012 sothiazolol-3-one Magnesium chloride 7786-30-3 0.00070 0.00011 Acetic acid,potassium salt 127-08-2 0.00033 0.00005 2-methyl-2h-isothiazol-3-one 2682-20-4 0.00023 0.00004 Quartz,Crystalline silica 14808-60-7 0.00014 0.00002 Cristobalite 14464-46-1 0.00014 0.00002 Acetic acid(impurity) 64-19-7 0.00005 0.00001 Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. 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BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-01 Date Dispatched: 27-Apr-16 Job#: 16AKA0096 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy [-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 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: MAL,..../.7.4k-' 215203 • RECEIVED. 27063 APR 2 7 2016 AOGCC FINAL � J NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-01 2S-01 Definitive Survey Report 19 January, 2016 NAD 27 • Schlumberger Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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-01 Well Position +N/-S 0.00 usft Northing: 5,930,036.15 usfi Latitude: 70° 13'12.058 N +E/-W 0.00 usft Easting: 481,309.01 usfi Longitude: 150°9'2.839 W', Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-01 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 12/30/2015 18.42 80.86 57,486 Design 2S-01 Audit Notes: II Version: 1.0 Phase: ACTUAL Tie On Depth: 39.61 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.61 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 84.00 839.00 2S-01 Srvy#1 -GYD-GC-SS(2S-01) GYD-GC-SS Gyrodata gyro single shots 12/17/2015 9:i 863.34 2,889.66 2S-01 Srvy#2-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/17/2015 9: 2,969.65 5,955.96 2S-01 Srvy#3-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/22/2015 11 6,046.37 12,512.12 2S-01 Srvy#4-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2015 10. 12,571.05 12,571.05 2S-01 Srvy#5-INC+TREND(2S-01) INC+TREND Inclinometer+known azi trend 1/7/2016 8:22. 12,666.66 21,659.83 2S-01 Srvy#6-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/8/2016 9:26. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.61 0.00 0.00 39.61 -120.00 0.00 0.00 5,930,036.15 481,309.01 0.00 0.00 UNDEFINED 84.00 0.61 294.79 84.00 -75.61 0.10 -0.21 5,930,036.25 481,308.80 1.37 -0.04 GYD-GC-SS(1) 118.50 0.66 294.99 118.50 -41.11 0.26 -0.56 5,930,036.41 481,308.45 0.15 -0.11 NOT an Actual Survey 16"x 20" 184.00 0.76 295.30 183.99 24.38 0.61 -1.30 5,930,036.76 481,307.72 0.15 -0.25 GYD-GC-SS(1) 276.00 1.08 300.08 275.98 116.37 1.30 -2.60 5,930,037.46 481,306.42 0.36 -0.58 GYD-GC-SS(1) 370.00 0.82 356.34 369.97 210.36 2.42 -3.41 5,930,038.57 481,305.61 0.98 -1.45 GYD-GC-SS(1) 462.00 2.52 54.48 461.93 302.32 4.25 -1.80 5,930,040.40 481,307.22 2.39 -3.64 GYD-GC-SS(1) 557.00 3.50 62.90 556.80 397.19 6.78 2.48 5,930,042.92 481,311.51 1.13 -7.19 GYD-GC-SS(1) 650.00 4.12 74.68 649.59 489.98 8.96 8.23 5,930,045.09 481,317.26 1.07 -10.78 GYD-GC-SS(1) 1/19/2016 8:42:43AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 745.00 4.70 77.85 744.31 584.70 10.68 15.32 5,930,046.79 481,324.36 0.66 -14.28 GYD-GC-SS(1) 839.00 5.41 71.52 837.95 678.34 12.89 23.29 5,930,048.98 481,332.33 0.96 -18.48 GYD-GC-SS(1) 863.34 5.44 67.69 862.18 702.57 13.70 25.45 5,930,049.78 481,334.49 1.49 -19.82 MWD+IFR-AK-CAZ-SC(2) 958.04 6.22 63.52 956.39 796.78 17.69 34.19 5,930,053.75 481,343.25 0.94 -25.93 MWD+IFR-AK-CAZ-SC(2) 1,052.28 7.57 66.62 1,049.95 890.34 22.43 44.46 5,930,058.46 481,353.52 1.49 -33.17 MWD+IFR-AK-CAZ-SC(2) 1,146.12 8.95 65.38 1,142.81 983.20 27.92 56.77 5,930,063.93 481,365.85 1.48 -41.66 MWD+IFR-AK-CAZ-SC(2) 1,240.91 11.25 62.85 1,236.12 1,076.51 35.21 71.70 5,930,071.18 481,380.80 2.47 -52.57 MWD+IFR-AK-CAZ-SC(2) 1,335.43 15.64 62.42 1,328.03 1,168.42 45.33 91.21 5,930,081.24 481,400.33 4.65 -67.39 MWD+IFR-AK-CAZ-SC(2) 1,430.70 16.64 62.38 1,419.55 1,259.94 57.60 114.68 5,930,093.45 481,423.82 1.05 -85.31 MWD+IFR-AK-CAZ-SC(2) 1,524.30 18.13 64.66 1,508.87 1,349.26 70.04 139.72 5,930,105.84 481,448.89 1.75 -103.82 MWD+IFR-AK-CAZ-SC(2) 1,618.41 19.93 64.46 1,597.83 1,438.22 83.23 167.42 5,930,118.95 481,476.63 1.91 -123.72 MWD+IFR-AK-CAZ-SC(2) 1,713.85 21.53 65.92 1,687.09 1,527.48 97.38 198.09 5,930,133.03 481,507.33 1.76 -145.34 MWD+IFR-AK-CAZ-SC(2) 1,808.53 25.67 67.86 1,773.83 1,614.22 112.21 232.96 5,930,147.77 481,542.23 4.45 -168.68 MWD+IFR-AK-CAZ-SC(2) 1,903.85 29.11 68.07 1,858.46 1,698.85 128.65 273.61 5,930,164.11 481,582.91 3.61 -195.08 MWD+IFR-AK-CAZ-SC(2) 1,998.34 31.36 67.22 1,940.09 1,780.48 146.76 317.60 5,930,182.11 481,626.95 2.42 -223.96 MWD+IFR-AK-CAZ-SC(2) 2,093.33 34.19 66.72 2,019.95 1,860.34 166.88 364.92 5,930,202.11 481,674.31 2.99 -255.64 MWD+IFR-AK-CAZ-SC(2) 2,187.89 37.04 63.71 2,096.82 1,937.21 190.00 414.87 5,930,225.11 481,724.32 3.54 -290.91 MWD+IFR-AK-CAZ-SC(2) 2,282.23 40.05 62.07 2,170.60 2,010.99 216.81 467.18 5,930,251.78 481,776.68 3.37 -330.34 MWD+IFR-AK-CAZ-SC(2) 2,376.85 43.57 61.39 2,241.11 2,081.50 246.69 522.72 5,930,281.52 481,832.29 3.75 -373.58 MWD+IFR-AK-CAZ-SC(2) 2,470.82 44.76 60.58 2,308.52 2,148.91 278.45 579.97 5,930,313.14 481,889.61 1.40 -419.07 MWD+IFR-AK-CAZ-SC(2) 2,565.64 47.68 61.98 2,374.12 2,214.51 311.33 640.01 5,930,345.86 481,949.73 3.26 -466.37 MWD+IFR-AK-CAZ-SC(2) 2,660.48 49.36 62.69 2,436.93 2,277.32 344.31 702.94 5,930,378.68 482,012.73 1.86 -514.51 MWD+IFR-AK-CAZ-SC(2) 2,753.26 54.04 61.90 2,494.42 2,334.81 378.17 767.37 5,930,412.38 482,077.25 5.09 -563.89 MWD+IFR-AK-CAZ-SC(2) 2,849.33 56.31 62.11 2,549.28 2,389.67 415.18 837.01 5,930,449.21 482,146.96 2.37 -617.67 MWD+IFR-AK-CAZ-SC(2) 2,889.66 58.69 61.80 2,570.95 2,411.34 431.17 867.02 5,930,465.13 482,177.02 5.94 -640.88 MWD+IFR-AK-CAZ-SC(2) 2,951.00 59.06 60.33 2,602.66 2,443.05 456.58 912.97 5,930,490.42 482,223.03 2.13 -677.31 NOT an Actual Survey (3) 10 3/4"x 13-1/2" 2,969.65 59.17 59.89 2,612.23 2,452.62 464.55 926.85 5,930,498.36 482,236.92 2.13 -688.61 MWD+IFR-AK-CAZ-SC(3) 3,022.65 60.47 61.03 2,638.88 2,479.27 487.14 966.71 5,930,520.84 482,276.83 3.08 -720.74 MWD+IFR-AK-CAZ-SC(3) 3,121.62 64.04 61.37 2,684.94 2,525.33 529.32 1,043.46 5,930,562.83 482,353.68 3.62 -781.35 MWD+IFR-AK-CAZ-SC(3) 3,211.94 66.32 61.52 2,722.86 2,563.25 568.51 1,115.46 5,930,601.83 482,425.77 2.53 -837.84 MWD+IFR-AK-CAZ-SC(3) 3,307.43 68.81 61.14 2,759.30 2,599.69 610.85 1,192.89 5,930,643.98 482,503.30 2.63 -898.78 MWD+IFR-AK-CAZ-SC(3) 3,403.45 69.15 61.47 2,793.74 2,634.13 653.88 1,271.51 5,930,686.82 482,582.02 0.48 -960.70 MWD+IFR-AK-CAZ-SC(3) 3,496.67 69.62 61.83 2,826.56 2,666.95 695.32 1,348.30 5,930,728.05 482,658.90 0.62 -1,020.59 MWD+IFR-AK-CAZ-SC(3) 3,590.88 69.61 61.69 2,859.37 2,699.76 737.10 1,426.10 5,930,769.64 482,736.79 0.14 -1,081.09 MWD+IFR-AK-CAZ-SC(3) 3,685.79 69.68 61.60 2,892.39 2,732.78 779.36 1,504.41 5,930,811.71 482,815.20 0.12 -1,142.18 MWD+IFR-AK-CAZ-SC(3) 3,780.39 69.67 62.07 2,925.25 2,765.64 821.23 1,582.61 5,930,853.38 482,893.50 0.47 -1,202.86 MWD+IFR-AK-CAZ-SC(3) 3,874.54 69.63 61.75 2,957.99 2,798.38 862.80 1,660.49 5,930,894.75 482,971.47 0.32 -1,263.17 MWD+IFR-AK-CAZ-SC(3) 3,968.93 70.14 60.83 2,990.45 2,830.84 905.38 1,738.22 5,930,937.13 483,049.30 1.06 -1,324.41 MWD+IFR-AK-CAZ-SC(3) 4,063.87 70.18 60.72 3,022.67 2,863.06 948.98 1,816.16 5,930,980.53 483,127.34 0.12 -1,386.70 MWD+IFR-AK-CAZ-SC(3) 1/19/2016 8:42.:43AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,157.78 69.66 61.97 3,054.91 2,895.30 991.27 1,893.56 5,931,022.63 483,204.83 1.37 -1,447.59 MWD+IFR-AK-CAZ-SC(3) 4,252.12 69.61 62.14 3,087.75 2,928.14 1,032.72 1,971.69 5,931,063.88 483,283.06 0.18 -1,507.84 MWD+IFR-AK-CAZ-SC(3) 4,346.55 69.58 62.70 3,120.67 2,961.06 1,073.70 2,050.13 5,931,104.66 483,361.60 0.56 -1,567.73 MWD+IFR-AK-CAZ-SC(3) 4,442.96 69.62 62.47 3,154.27 2,994.66 1,115.30 2,130.35 5,931,146.06 483,441.91 0.23 -1,628.68 MWD+IFR-AK-CAZ-SC(3) 4,536.26 69.58 63.31 3,186.80 3,027.19 1,155.15 2,208.19 5,931,185.71 483,519.84 0.84 -1,687.31 MWD+IFR-AK-CAZ-SC(3) 4,631.02 69.55 63.92 3,219.88 3,060.27 1,194.61 2,287.73 5,931,224.98 483,599.47 0.60 -1,746.02 MWD+IFR-AK-CAZ-SC(3) 4,729.75 69.58 64.11 3,254.35 3,094.74 1,235.15 2,370.90 5,931,265.30 483,682.73 0.18 -1,806.70 MWD+IFR-AK-CAZ-SC(3) 4,820.19 69.62 63.77 3,285.88 3,126.27 1,272.39 2,447.05 5,931,302.35 483,758.96 0.36 -1,862.38 MWD+IFR-AK-CAZ-SC(3) 4,913.24 69.65 63.16 3,318.26 3,158.65 1,311.36 2,525.09 5,931,341.12 483,837.10 0.62 -1,920.22 MWD+IFR-AK-CAZ-SC(3) 5,008.61 69.61 63.22 3,351.46 3,191.85 1,351.68 2,604.89 5,931,381.24 483,916.98 0.07 -1,979.82 MWD+IFR-AK-CAZ-SC(3) 5,102.60 69.55 63.10 3,384.25 3,224.64 1,391.45 2,683.48 5,931,420.82 483,995.67 0.14 -2,038.58 MWD+IFR-AK-CAZ-SC(3) 5,198.70 69.61 63.17 3,417.78 3,258.17 1,432.15 2,763.82 5,931,461.31 484,076.10 0.09 -2,098.68 MWD+IFR-AK-CAZ-SC(3) 5,293.66 69.75 62.73 3,450.75 3,291.14 1,472.65 2,843.13 5,931,501.61 484,155.50 0.46 -2,158.33 MWD+IFR-AK-CAZ-SC(3) 5,388.04 69.52 62.27 3,483.60 3,323.99 1,513.51 2,921.62 5,931,542.26 484,234.08 0.52 -2,218.10 MWD+IFR-AK-CAZ-SC(3) 5,481.73 69.58 61.69 3,516.33 3,356.72 1,554.74 2,999.11 5,931,583.31 484,311.67 0.58 -2,278.00 MWD+IFR-AK-CAZ-SC(3) 5,578.13 69.55 60.91 3,549.99 3,390.38 1,598.12 3,078.35 5,931,626.49 484,391.00 0.76 -2,340.40 MWD+IFR-AK-CAZ-SC(3) 5,670.05 69.65 60.86 3,582.03 3,422.42 1,640.04 3,153.61 5,931,668.22 484,466.37 0.12 -2,400.38 MWD+IFR-AK-CAZ-SC(3) 5,765.67 69.55 61.28 3,615.36 3,455.75 1,683.40 3,232.05 5,931,711.37 484,544.90 0.42 -2,462.56 MWD+IFR-AK-CAZ-SC(3) 5,859.37 69.62 61.52 3,648.05 3,488.44 1,725.43 3,309.15 5,931,753.21 484,622.10 0.25 -2,523.11 MWD+IFR-AK-CAZ-SC(3) 5,955.96 69.45 61.97 3,681.82 3,522.21 1,768.27 3,388.86 5,931,795.85 484,701.91 0.47 -2,585.12 MWD+IFR-AK-CAZ-SC(3) 6,046.37 69.74 62.21 3,713.34 3,553.73 1,807.94 3,463.74 5,931,835.32 484,776.88 0.41 -2,642.82 MWD+IFR-AK-CAZ-SC(4) 6,140.84 69.69 63.01 3,746.09 3,586.48 1,848.70 3,542.42 5,931,875.89 484,855.65 0.80 -2,702.56 MWD+IFR-AK-CAZ-SC(4) 6,235.41 69.79 62.91 3,778.84 3,619.23 1,889.04 3,621.44 5,931,916.02 484,934.76 0.14 -2,761.97 MWD+IFR-AK-CAZ-SC(4) 6,330.43 69.69 64.00 3,811.74 3,652.13 1,928.87 3,701.18 5,931,955.66 485,014.60 1.08 -2,821.08 MWD+IFR-AK-CAZ-SC(4) 6,424.80 69.80 62.81 3,844.42 3,684.81 1,968.51 3,780.35 5,931,995.09 485,093.85 1.19 -2,879.86 MWD+IFR-AK-CAZ-SC(4) 6,519.68 69.77 61.96 3,877.20 3,717.59 2,009.78 3,859.24 5,932,036.16 485,172.84 0.84 -2,940.14 MWD+IFR-AK-CAZ-SC(4) 6,615.12 69.63 61.40 3,910.31 3,750.70 2,052.24 3,938.04 5,932,078.43 485,251.73 0.57 -3,001.55 MWD+I FR-AK-CAZ-SC(4) 6,708.74 69.73 60.36 3,942.83 3,783.22 2,094.96 4,014.74 5,932,120.96 485,328.53 1.05 -3,062.67 MWD+IFR-AK-CAZ-SC(4) 6,803.27 69.73 61.76 3,975.58 3,815.97 2,137.87 4,092.34 5,932,163.67 485,406.22 1.39 -3,124.20 MWD+IFR-AK-CAZ-SC(4) 6,897.89 69.79 61.15 4,008.31 3,848.70 2,180.29 4,170.32 5,932,205.89 485,484.31 0.61 -3,185.36 MWD+IFR-AK-CAZ-SC(4) 6,992.20 69.86 60.16 4,040.84 3,881.23 2,223.68 4,247.48 5,932,249.08 485,561.57 0.99 -3,247.24 MWD+IFR-AK-CAZ-SC(4) 7,087.00 69.80 60.54 4,073.53 3,913.92 2,267.70 4,324.82 5,932,292.90 485,639.00 0.38 -3,309.77 MWD+IFR-AK-CAZ-SC(4) 7,181.53 69.82 60.61 4,106.15 3,946.54 2,311.29 4,402.09 5,932,336.30 485,716.38 0.07 -3,371.88 MWD+IFR-AK-CAZ-SC(4) 7,275.82 69.73 61.08 4,138.75 3,979.14 2,354.39 4,479.36 5,932,379.20 485,793.75 0.48 -3,433.51 MWD+IFR-AK-CAZ-SC(4) 7,370.63 69.63 61.55 4,171.67 4,012.06 2,397.06 4,557.36 5,932,421.68 485,871.84 0.48 -3,494.92 MWD+IFR-AK-CAZ-SC(4) 7,465.99 69.77 61.74 4,204.76 4,045.15 2,439.54 4,636.07 5,932,463.96 485,950.65 0.24 -3,556.32 MWD+IFR-AK-CAZ-SC(4) 7,564.31 69.74 63.46 4,238.78 4,079.17 2,481.99 4,717.96 5,932,506.20 486,032.64 1.64 -3,618.52 MWD+IFR-AK-CAZ-SC(4) 7,653.49 69.70 62.91 4,269.69 4,110.08 2,519.73 4,792.62 5,932,543.75 486,107.38 0.58 -3,674.29 MWD+IFR-AK-CAZ-SC(4) 7,749.38 69.71 63.31 4,302.95 4,143.34 2,560.40 4,872.83 5,932,584.22 486,187.68 0.39 -3,734.34 MWD+IFR-AK-CAZ-SC(4) 7,843.29 69.57 64.17 4,335.62 4,176.01 2,599.36 4,951.78 5,932,622.98 486,266.73 0.87 -3,792.40 MWD+IFR-AK-CAZ-SC(4) 1/19/2016 8:42:43AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,938.35 69.74 63.70 4,368.67 4,209.06 2,638.52 5,031.85 5,932,661.94 486,346.88 0.50 -3,850.95 MWD+IFR-AK-CAZ-SC(4) 8,031.58 69.73 62.76 4,400.97 4,241.36 2,677.91 5,109.93 5,932,701.13 486,425.05 0.95 -3,909.21 MWD+IFR-AK-CAZ-SC(4) 8,126.13 69.71 61.86 4,433.74 4,274.13 2,719.12 5,188.46 5,932,742.15 486,503.68 0.89 -3,969.35 MWD+IFR-AK-CAZ-SC(4) 8,221.47 69.60 61.17 4,466.89 4,307.28 2,761.76 5,267.03 5,932,784.58 486,582.35 0.69 -4,030.86 MWD+IFR-AK-CAZ-SC(4) 8,315.96 69.77 61.34 4,499.69 4,340.08 2,804.37 5,344.73 5,932,827.00 486,660.14 0.25 -4,092.13 MWD+IFR-AK-CAZ-SC(4) 8,410.46 69.79 60.94 4,532.35 4,372.74 2,847.17 5,422.39 5,932,869.60 486,737.90 0.40 -4,153.58 MWD+IFR-AK-CAZ-SC(4) 8,505.43 69.73 62.06 4,565.21 4,405.60 2,889.69 5,500.69 5,932,911.92 486,816.30 1.11 -4,214.91 MWD+IFR-AK-CAZ-SC(4) 8,599.82 69.76 61.79 4,597.89 4,438.28 2,931.37 5,578.83 5,932,953.40 486,894.53 0.27 -4,275.39 MWD+IFR-AK-CAZ-SC(4) 8,694.74 69.81 61.56 4,630.69 4,471.08 2,973.63 5,657.24 5,932,995.46 486,973.03 0.23 -4,336.50 MWD+IFR-AK-CAZ-SC(4) 8,789.09 69.67 61.71 4,663.36 4,503.75 3,015.68 5,735.12 5,933,037.32 487,051.02 0.21 -4,397.28 MWD+IFR-AK-CAZ-SC(4) 8,884.04 69.81 61.38 4,696.24 4,536.63 3,058.12 5,813.44 5,933,079.56 487,129.43 0.36 -4,458.55 MWD+IFR-AK-CAZ-SC(4) 8,978.74 69.28 63.15 4,729.33 4,569.72 3,099.41 5,891.97 5,933,120.65 487,208.05 1.84 -4,518.76 MWD+IFR-AK-CAZ-SC(4) 9,072.59 68.76 66.54 4,762.95 4,603.34 3,136.66 5,971.27 5,933,157.70 487,287.44 3.42 -4,575.26 MWD+IFR-AK-CAZ-SC(4) 9,167.47 68.45 68.23 4,797.56 4,637.95 3,170.63 6,052.81 5,933,191.46 487,369.06 1.69 -4,629.18 MWD+IFR-AK-CAZ-SC(4) 9,261.56 68.30 70.43 4,832.24 4,672.63 3,201.50 6,134.64 5,933,222.13 487,450.95 2.18 -4,680.18 MWD+IFR-AK-CAZ-SC(4) 9,355.54 68.10 71.60 4,867.14 4,707.53 3,229.89 6,217.15 5,933,250.31 487,533.53 1.18 -4,728.95 MWD+IFR-AK-CAZ-SC(4) 9,453.28 67.46 73.65 4,904.11 4,744.50 3,256.91 6,303.50 5,933,277.12 487,619.93 2.05 -4,777.40 MWD+IFR-AK-CAZ-SC(4) 9,545.54 66.12 76.14 4,940.47 4,780.86 3,279.01 6,385.35 5,933,299.01 487,701.83 2.87 -4,819.93 MWD+IFR-AK-CAZ-SC(4) 9,639.05 65.50 79.25 4,978.79 4,819.18 3,297.19 6,468.67 5,933,316.99 487,785.19 3.11 -4,859.06 MWD+IFR-AK-CAZ-SC(4) 9,734.16 63.96 82.05 5,019.40 4,859.79 3,311.18 6,553.52 5,933,330.76 487,870.06 3.12 -4,894.53 MWD+IFR-AK-CAZ-SC(4) 9,828.99 62.55 85.01 5,062.08 4,902.47 3,320.73 6,637.65 5,933,340.10 487,954.21 3.16 -4,925.53 MWD+IFR-AK-CAZ-SC(4) 9,923.33 62.73 87.39 5,105.44 4,945.83 3,326.28 6,721.24 5,933,345.45 488,037.81 2.25 -4,952.53 MWD+IFR-AK-CAZ-SC(4) 10,018.61 61.48 90.51 5,150.03 4,990.42 3,327.84 6,805.42 5,933,346.79 488,121.98 3.18 -4,975.82 MWD+IFR-AK-CAZ-SC(4) 10,113.47 60.59 95.60 5,195.99 5,036.38 3,323.44 6,888.26 5,933,342.19 488,204.80 4.79 -4,993.00 MWD+IFR-AK-CAZ-SC(4) 10,207.39 61.27 100.56 5,241.64 5,082.03 3,311.89 6,969.49 5,933,330.44 488,285.99 4.67 -5,002.88 MWD+IFR-AK-CAZ-SC(4) 10,302.79 61.83 104.08 5,287.10 5,127.49 3,293.99 7,051.42 5,933,312.34 488,367.87 3.30 -5,006.79 MWD+IFR-AK-CAZ-SC(4) 10,396.93 61.67 107.78 5,331.67 5,172.06 3,271.24 7,131.14 5,933,289.39 488,447.53 3.47 -5,005.45 MWD+IFR-AK-CAZ-SC(4) 10,491.27 60.92 110.92 5,376.99 5,217.38 3,243.83 7,209.20 5,933,261.80 488,525.51 3.03 -4,999.18 MWD+IFR-AK-CAZ-SC(4) 10,586.26 59.69 113.68 5,424.06 5,264.45 3,212.54 7,285.54 5,933,230.32 488,601.76 2.84 -4,988.71 MWD+IFR-AK-CAZ-SC(4) 10,681.17 59.36 116.26 5,472.20 5,312.59 3,178.02 7,359.68 5,933,195.61 488,675.81 2.37 -4,974.55 MWD+IFR-AK-CAZ-SC(4) 10,775.96 59.93 118.30 5,520.10 5,360.49 3,140.53 7,432.37 5,933,157.95 488,748.40 1.95 -4,957.15 MWD+IFR-AK-CAZ-SC(4) 10,871.21 61.11 120.90 5,566.98 5,407.37 3,099.57 7,504.45 5,933,116.81 488,820.37 2.68 -4,936.25 MWD+IFR-AK-CAZ-SC(4) 10,965.55 61.35 123.80 5,612.40 5,452.79 3,055.32 7,574.30 5,933,072.40 488,890.10 2.71 -4,911.59 MWD+IFR-AK-CAZ-SC(4) 11,061.46 61.93 126.60 5,657.96 5,498.35 3,006.67 7,643.25 5,933,023.59 488,958.93 2.64 -4,882.44 MWD+IFR-AK-CAZ-SC(4) 11,155.13 62.85 129.95 5,701.38 5,541.77 2,955.26 7,708.40 5,932,972.02 489,023.94 3.32 -4,849.64 MWD+IFR-AK-CAZ-SC(4) 11,249.55 63.36 134.05 5,744.11 5,584.50 2,898.93 7,770.95 5,932,915.54 489,086.35 3.91 -4,811.42 MWD+IFR-AK-CAZ-SC(4) 11,344.07 63.66 138.26 5,786.28 5,626.67 2,837.93 7,829.53 5,932,854.40 489,144.77 4.00 -4,767.66 MWD+IFR-AK-CAZ-SC(4) 11,438.26 64.24 142.75 5,827.66 5,668.05 2,772.65 7,883.32 5,932,788.99 489,198.40 4.33 -4,718.53 MWD+IFR-AK-CAZ-SC(4) 11,533.86 65.06 145.99 5,868.60 5,708.99 2,702.44 7,933.64 5,932,718.66 489,248.53 3.18 -4,663.73 MWD+IFR-AK-CAZ-SC(4) 11,627.70 66.20 148.62 5,907.33 5,747.72 2,630.51 7,979.80 5,932,646.62 489,294.51 2.83 -4,606.20 MWD+IFR-AK-CAZ-SC(4) 1/19/2016 8:42:43AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,722.74 67.38 152.17 5,944.79 5,785.18 2,554.57 8,022.93 5,932,570.59 489,337.44 3.65 -4,544.01 MWD+IFR-AK-CAZ-SC(4) 11,817.37 68.46 155.10 5,980.37 5,820.76 2,476.01 8,061.86 5,932,491.94 489,376.17 3.09 -4,478.21 MWD+IFR-AK-CAZ-SC(4) 11,912.31 69.09 156.58 6,014.74 5,855.13 2,395.27 8,098.07 5,932,411.12 489,412.19 1.60 -4,409.59 MWD+IFR-AK-CAZ-SC(4) 12,006.26 68.86 157.71 6,048.45 5,888.84 2,314.46 8,132.13 5,932,330.23 489,446.05 1.15 -4,340.35 MWD+IFR-AK-CAZ-SC(4) 12,101.29 69.65 160.48 6,082.12 5,922.51 2,231.45 8,163.83 5,932,247.15 489,477.54 2.85 -4,268.37 MWD+IFR-AK-CAZ-SC(4) 12,195.51 71.59 162.74 6,113.38 5,953.77 2,147.11 8,191.86 5,932,162.76 489,505.35 3.06 -4,194.16 MWD+IFR-AK-CAZ-SC(4) 12,290.59 74.03 165.57 6,141.49 5,981.88 2,059.75 8,216.64 5,932,075.34 489,529.92 3.83 -4,116.19 MWD+IFR-AK-CAZ-SC(4) 12,385.39 76.48 168.31 6,165.62 6,006.01 1,970.45 8,237.34 5,931,986.00 489,550.39 3.81 -4,035.29 MWD+IFR-AK-CAZ-SC(4) 12,480.60 77.85 172.31 6,186.78 6,027.17 1,878.97 8,252.96 5,931,894.49 489,565.78 4.34 -3,950.96 MWD+IFR-AK-CAZ-SC(4) 12,512.12 77.98 173.39 6,193.38 6,033.77 1,848.39 8,256.79 5,931,863.90 489,569.54 3.38 -3,922.42 MWD+IFR-AK-CAZ-SC(4) 12,571.05 78.19 173.00 6,205.54 6,045.93 1,791.13 8,263.63 5,931,806.63 489,576.23 0.74 -3,868.88 INC+TREND(5) 12,574.00 78.18 172.97 6,206.15 6,046.54 1,788.27 8,263.98 5,931,803.77 489,576.57 1.19 -3,866.21 'NOT an Actual Survey (6) 7-5/8"-9-7/8 x 11" 12,666.66 77.71 171.94 6,225.50 6,065.89 1,698.44 8,275.88 5,931,713.92 489,588.25 1.19 -3,782.52 MWD+IFR-AK-CAZ-SC(6) 12,761.77 75.71 175.07 6,247.37 6,087.76 1,606.49 8,286.36 5,931,621.95 489,598.50 3.83 -3,696.41 MWD+IFR-AK-CAZ-SC(6) 12,856.21 75.05 178.87 6,271.22 6,111.61 1,515.25 8,291.19 5,931,530.71 489,603.11 3.96 -3,609.54 MWD+IFR-AK-CAZ-SC(6) 12,951.13 75.97 180.43 6,294.97 6,135.36 1,423.36 8,291.75 5,931,438.83 489,603.44 1.86 -3,520.92 MWD+IFR-AK-CAZ-SC(6) 13,046.58 80.30 180.40 6,314.59 6,154.98 1,329.97 8,291.07 5,931,345.45 489,602.53 4.54 -3,430.54 MWD+IFR-AK-CAZ-SC(6) 13,141.51 84.37 180.82 6,327.25 6,167.64 1,235.91 8,290.07 5,931,251.41 489,601.29 4.31 -3,339.43 MWD+IFR-AK-CAZ-SC(6) 13,235.84 85.87 184.41 6,335.27 6,175.66 1,142.04 8,285.78 5,931,157.56 489,596.77 4.11 -3,247.65 MWD+IFR-AK-CAZ-SC(6) 13,330.83 83.89 188.73 6,343.75 6,184.14 1,048.08 8,274.96 5,931,063.63 489,585.72 4.99 -3,154.08 MWD+IFR-AK-CAZ-SC(6) 13,425.88 84.91 191.53 6,353.03 6,193.42 954.97 8,258.32 5,930,970.57 489,568.86 3.12 -3,059.84 MWD+IFR-AK-CAZ-SC(6) 13,520.68 87.03 193.91 6,359.69 6,200.08 862.74 8,237.50 5,930,878.40 489,547.81 3.36 -2,965.36 MWD+IFR-AK-CAZ-SC(6) 13,615.59 90.66 197.00 6,361.61 6,202.00 771.30 8,212.22 5,930,787.04 489,522.30 5.02 -2,870.50 MWD+IFR-AK-CAZ-SC(6) 13,710.65 91.86 198.35 6,359.52 6,199.91 680.76 8,183.37 5,930,696.57 489,493.23 1.90 -2,775.57 MWD+IFR-AK-CAZ-SC(6) 13,805.18 90.78 197.62 6,357.34 6,197.73 590.87 8,154.19 5,930,606.77 489,463.83 1.38 -2,681.20 MWD+IFR-AK-CAZ-SC(6) 13,899.61 89.68 196.15 6,356.96 6,197.35 500.52 8,126.76 5,930,516.49 489,436.18 1.94 -2,586.82 MWD+IFR-AK-CAZ-SC(6) 13,994.80 89.92 193.68 6,357.29 6,197.68 408.54 8,102.26 5,930,424.58 489,411.46 2.61 -2,491.64 MWD+IFR-AK-CAZ-SC(6) 14,090.52 89.82 191.53 6,357.51 6,197.90 315.13 8,081.38 5,930,331.24 489,390.34 2.25 -2,396.01 MWD+IFR-AK-CAZ-SC(6) 14,184.83 89.96 192.47 6,357.69 6,198.08 222.89 8,061.77 5,930,239.05 489,370.51 1.01 -2,301.83 MWD+IFR-AK-CAZ-SC(6) 14,279.75 89.29 195.30 6,358.31 6,198.70 130.75 8,038.99 5,930,146.98 489,347.51 3.06 -2,206.94 MWD+IFR-AK-CAZ-SC(6) 14,375.49 90.63 196.00 6,358.38 6,198.77 38.56 8,013.17 5,930,054.87 489,321.46 1.58 -2,111.21 MWD+IFR-AK-CAZ-SC(6) 14,470.24 89.29 196.87 6,358.45 6,198.84 -52.31 7,986.36 5,929,964.07 489,294.43 1.69 -2,016.49 MWD+IFR-AK-CAZ-SC(6) 14,564.84 89.37 199.26 6,359.55 6,199.94 -142.24 7,957.03 5,929,874.22 489,264.88 2.53 -1,922.04 MWD+IFR-AK-CAZ-SC(6) 14,660.05 88.76 199.87 6,361.11 6,201.50 -231.94 7,925.15 5,929,784.61 489,232.78 0.91 -1,827.15 MWD+IFR-AK-CAZ-SC(6) 14,754.87 87.07 198.84 6,364.56 6,204.95 -321.33 7,893.75 5,929,695.30 489,201.16 2.09 -1,732.67 MWD+IFR-AK-CAZ-SC(6) 14,849.61 86.52 197.37 6,369.85 6,210.24 -411.24 7,864.35 5,929,605.48 489,171.54 1.65 -1,638.22 MWD+IFR-AK-CAZ-SC(6) 14,944.83 86.65 195.24 6,375.53 6,215.92 -502.46 7,837.67 5,929,514.33 489,144.64 2.24 -1,543.20 MWD+IFR-AK-CAZ-SC(6) 15,039.60 88.31 194.48 6,379.69 6,220.08 -593.97 7,813.39 5,929,422.89 489,120.13 1.93 -1,448.52 MWD+IFR-AK-CAZ-SC(6) 15,134.33 89.82 193.47 6,381.24 6,221.63 -685.88 7,790.52 5,929,331.05 489,097.03 1.92 -1,353.83 MWD+IFR-AK-CAZ-SC(6) 1/19/2016 8:42:43AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,229.11 90.23 191.01 6,381.20 6,221.59 -778.50 7,770.42 5,929,238.49 489,076.71 2.63 -1,259.16 MWD+IFR-AK-CAZ-SC(6) 15,323.97 90.75 190.27 6,380.39 6,220.78 -871.72 7,752.91 5,929,145.32 489,058.97 0.95 -1,164.58 MWD+IFR-AK-CAZ-SC(6) 15,419.11 90.33 190.01 6,379.49 6,219.88 -965.37 7,736.16 5,929,051.72 489,041.99 0.52 -1,069.79 MWD+IFR-AK-CAZ-SC(6) 15,514.10 89.65 188.75 6,379.51 6,219.90 -1,059.09 7,720.68 5,928,958.05 489,026.28 1.51 -975.26 MWD+IFR-AK-CAZ-SC(6) 15,608.75 89.61 187.36 6,380.12 6,220.51 -1,152.80 7,707.42 5,928,864.38 489,012.79 1.47 -881.31 MWD+IFR-AK-CAZ-SC(6) 15,703.73 89.82 186.95 6,380.59 6,220.98 -1,247.04 7,695.59 5,928,770.18 489,000.72 0.48 -787.22 MWD+IFR-AK-CAZ-SC(6) 15,798.16 89.65 187.82 6,381.03 6,221.42 -1,340.68 7,683.45 5,928,676.57 488,988.36 0.94 -693.62 MWD+IFR-AK-CAZ-SC(6) 15,893.10 90.37 188.58 6,381.01 6,221.40 -1,434.65 7,669.91 5,928,582.65 488,974.58 1.10 -599.35 MWD+IFR-AK-CAZ-SC(6) 15,988.09 91.70 188.25 6,379.29 6,219.68 -1,528.60 7,656.01 5,928,488.74 488,960.45 1.44 -505.00 MWD+IFR-AK-CAZ-SC(6) 16,082.54 87.81 188.71 6,379.70 6,220.09 -1,622.00 7,642.09 5,928,395.39 488,946.30 4.15 -411.18 MWD+IFR-AK-CAZ-SC(6) 16,177.90 89.99 189.18 6,381.53 6,221.92 -1,716.18 7,627.26 5,928,301.26 488,931.24 2.34 -316.38 MWD+IFR-AK-CAZ-SC(6) 16,272.59 91.02 188.56 6,380.69 6,221.08 -1,809.73 7,612.66 5,928,207.75 488,916.41 1.27 -222.24 MWD+IFR-AK-CAZ-SC(6) 16,366.15 91.50 188.29 6,378.64 6,219.03 -1,902.26 7,598.96 5,928,115.27 488,902.48 0.59 -129.32 MWD+IFR-AK-CAZ-SC(6) 16,461.60 92.12 187.62 6,375.62 6,216.01 -1,996.74 7,585.76 5,928,020.83 488,889.05 0.96 -34.63 MWD+IFR-AK-CAZ-SC(6) 16,557.27 91.67 185.41 6,372.46 6,212.85 -2,091.74 7,574.91 5,927,925.87 488,877.96 2.36 59.93 MWD+IFR-AK-CAZ-SC(6) 16,651.13 91.41 184.24 6,369.93 6,210.32 -2,185.23 7,567.02 5,927,832.41 488,869.84 1.28 152.28 MWD+IFR-AK-CAZ-SC(6) 16,747.05 89.89 185.29 6,368.85 6,209.24 -2,280.81 7,559.05 5,927,736.86 488,861.64 1.93 246.66 MWD+IFR-AK-CAZ-SC(6) 16,841.74 89.72 186.97 6,369.17 6,209.56 -2,374.95 7,548.94 5,927,642.75 488,851.30 1.78 340.22 MWD+IFR-AK-CAZ-SC(6) 16,936.78 89.27 185.91 6,370.01 6,210.40 -2,469.39 7,538.28 5,927,548.35 488,840.40 1.21 434.19 MWD+IFR-AK-CAZ-SC(6) 17,031.64 89.37 185.92 6,371.13 6,211.52 -2,563.73 7,528.50 5,927,454.04 488,830.40 0.11 527.86 MWD+IFR-AK-CAZ-SC(6) 17,126.71 89.03 186.72 6,372.46 6,212.85 -2,658.22 7,518.04 5,927,359.59 488,819.70 0.91 621.83 MWD+IFR-AK-CAZ-SC(6) 17,222.19 88.62 188.48 6,374.42 6,214.81 -2,752.83 7,505.41 5,927,265.01 488,806.84 1.89 716.49 MWD+IFR-AK-CAZ-SC(6) 17,314.68 88.93 189.62 6,376.39 6,216.78 -2,844.15 7,490.87 5,927,173.74 488,792.07 1.28 808.46 MWD+IFR-AK-CAZ-SC(6) 17,410.75 89.61 189.82 6,377.62 6,218.01 -2,938.83 7,474.65 5,927,079.11 488,775.62 0.74 904.11 MWD+IFR-AK-CAZ-SC(6) 17,503.96 90.39 190.21 6,377.62 6,218.01 -3,030.62 7,458.44 5,926,987.37 488,759.19 0.94 996.97 MWD+IFR-AK-CAZ-SC(6) 17,598.29 89.32 192.77 6,377.86 6,218.25 -3,123.05 7,439.65 5,926,895.00 488,740.17 2.94 1,091.11 MWD+IFR-AK-CAZ-SC(6) 17,693.31 86.70 195.99 6,381.16 6,221.55 -3,215.02 7,416.08 5,926,803.10 488,716.37 4.37 1,186.05 MWD+IFR-AK-CAZ-SC(6) 17,788.13 87.76 198.61 6,385.74 6,226.13 -3,305.43 7,387.91 5,926,712.76 488,687.98 2.98 1,280.67 MWD+IFR-AK-CAZ-SC(6) 17,882.58 89.41 200.14 6,388.07 6,228.46 -3,394.50 7,356.59 5,926,623.78 488,656.44 2.38 1,374.81 MWD+IFR-AK-CAZ-SC(6) 17,976.99 89.92 202.20 6,388.63 6,229.02 -3,482.53 7,322.50 5,926,535.84 488,622.14 2.25 1,468.67 MWD+IFR-AK-CAZ-SC(6) 18,071.59 89.24 205.31 6,389.32 6,229.71 -3,569.11 7,284.40 5,926,449.37 488,583.83 3.37 1,562.15 MWD+IFR-AK-CAZ-SC(6) 18,165.44 89.75 204.29 6,390.15 6,230.54 -3,654.30 7,245.03 5,926,364.29 488,544.26 1.22 1,654.63 MWD+IFR-AK-CAZ-SC(6) 18,259.21 88.93 203.53 6,391.23 6,231.62 -3,740.01 7,207.03 5,926,278.67 488,506.05 1.19 1,747.26 MWD+IFR-AK-CAZ-SC(6) 18,354.25 89.06 201.82 6,392.89 6,233.28 -3,827.69 7,170.40 5,926,191.10 488,469.20 1.80 1,841.43 MWD+IFR-AK-CAZ-SC(6) 18,447.45 89.13 202.89 6,394.37 6,234.76 -3,913.87 7,134.96 5,926,105.01 488,433.55 1.15 1,933.85 MWD+IFR-AK-CAZ-SC(6) 18,542.74 90.13 202.74 6,394.98 6,235.37 -4,001.70 7,098.01 5,926,017.28 488,396.39 1.06 2,028.25 MWD+IFR-AK-CAZ-SC(6) 18,636.44 91.64 202.24 6,393.53 6,233.92 -4,088.26 7,062.17 5,925,930.82 488,360.34 1.70 2,121.14 MWD+IFR-AK-CAZ-SC(6) 18,728.40 90.75 204.61 6,391.62 6,232.01 -4,172.62 7,025.62 5,925,846.56 488,323.59 2.75 2,212.08 MWD+IFR-AK-CAZ-SC(6) 18,825.93 89.92 206.36 6,391.05 6,231.44 -4,260.65 6,983.66 5,925,758.64 488,281.41 1.99 2,307.97 MWD+IFR-AK-CAZ-SC(6) 18,918.30 89.55 204.93 6,391.47 6,231.86 -4,343.92 6,943.69 5,925,675.48 488,241.23 1.60 2,398.75 MWD+IFR-AK-CAZ-SC(6) 1/19/2016 8:42:43AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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 19,015.14 88.88 204.37 6,392.80 6,233.19 -4,431.93 6,903.30 5,925,587.58 488,200.63 0.90 2,494.21 MWD+IFR-AK-CAZ-SC(6) 19,109.60 90.15 203.49 6,393.60 6,233.99 -4,518.26 6,864.99 5,925,501.35 488,162.11 1.64 2,587.52 MWD+IFR-AK-CAZ-SC(6) 19,204.42 88.98 202.30 6,394.32 6,234.71 -4,605.61 6,828.10 5,925,414.11 488,125.01 1.76 2,681.43 MWD+IFR-AK-CAZ-SC(6) 19,299.09 89.79 198.96 6,395.34 6,235.73 -4,694.19 6,794.75 5,925,325.62 488,091.45 3.63 2,775.63 MWD+IFR-AK-CAZ-SC(6) 19,393.18 90.13 197.78 6,395.40 6,235.79 -4,783.48 6,765.10 5,925,236.41 488,061.58 1.31 2,869.55 MWD+IFR-AK-CAZ-SC(6) 19,487.30 89.55 198.05 6,395.66 6,236.05 -4,873.04 6,736.15 5,925,146.93 488,032.41 0.68 2,963.55 MWD+IFR-AK-CAZ-SC(6) 19,581.42 89.41 199.44 6,396.52 6,236.91 -4,962.16 6,705.91 5,925,057.89 488,001.95 1.48 3,057.46 MWD+IFR-AK-CAZ-SC(6) 19,676.95 89.97 199.52 6,397.03 6,237.42 -5,052.22 6,674.05 5,924,967.92 487,969.87 0.59 3,152.70 MWD+IFR-AK-CAZ-SC(6) 19,771.08 88.89 198.98 6,397.97 6,238.36 -5,141.08 6,643.02 5,924,879.15 487,938.62 1.28 3,246.56 MWD+IFR-AK-CAZ-SC(6) 19,864.90 89.03 198.99 6,399.67 6,240.06 -5,229.78 6,612.50 5,924,790.53 487,907.89 0.15 3,340.14 MWD+IFR-AK-CAZ-SC(6) 19,957.69 89.82 197.45 6,400.61 6,241.00 -5,317.91 6,583.49 5,924,702.48 487,878.66 1.87 3,432.78 MWD+IFR-AK-CAZ-SC(6) 20,050.98 90.16 196.98 6,400.62 6,241.01 -5,407.02 6,555.88 5,924,613.45 487,850.83 0.62 3,526.00 MWD+IFR-AK-CAZ-SC(6) 20,146.66 90.55 193.48 6,400.03 6,240.42 -5,499.33 6,530.75 5,924,521.22 487,825.48 3.68 3,621.66 MWD+IFR-AK-CAZ-SC(6) 20,241.72 89.34 190.14 6,400.12 6,240.51 -5,592.36 6,511.30 5,924,428.24 487,805.80 3.74 3,716.56 MWD+IFR-AK-CAZ-SC(6) 20,337.65 89.31 188.89 6,401.25 6,241.64 -5,686.96 6,495.44 5,924,333.69 487,789.71 1.30 3,812.04 MWD+IFR-AK-CAZ-SC(6) 20,432.45 89.30 190.80 6,402.40 6,242.79 -5,780.35 6,479.24 5,924,240.34 487,773.27 2.01 3,906.44 MWD+IFR-AK-CAZ-SC(6) 20,524.96 88.33 192.82 6,404.31 6,244.70 -5,870.88 6,460.31 5,924,149.87 487,754.12 2.42 3,998.78 MWD+IFR-AK-CAZ-SC(6) 20,618.45 88.65 194.20 6,406.78 6,247.17 -5,961.75 6,438.47 5,924,059.07 487,732.07 1.51 4,092.21 MWD+IFR-AK-CAZ-SC(6) 20,714.89 89.92 196.28 6,407.98 6,248.37 -6,054.78 6,413.13 5,923,966.11 487,706.49 2.53 4,188.63 MWD+IFR-AK-CAZ-SC(6) 20,808.44 90.70 196.42 6,407.47 6,247.86 -6,144.55 6,386.79 5,923,876.42 487,679.94 0.85 4,282.15 MWD+IFR-AK-CAZ-SC(6) 20,903.54 89.60 196.83 6,407.23 6,247.62 -6,235.67 6,359.59 5,923,785.37 487,652.51 1.23 4,377.21 MWD+IFR-AK-CAZ-SC(6) 20,998.04 86.24 198.56 6,410.66 6,251.05 -6,325.62 6,330.89 5,923,695.50 487,623.59 4.00 4,471.53 MWD+IFR-AK-CAZ-SC(6) 21,091.86 84.95 195.39 6,417.86 6,258.25 -6,415.08 6,303.58 5,923,606.12 487,596.06 3.64 4,565.00 MWD+IFR-AK-CAZ-SC(6) 21,186.78 86.96 193.06 6,424.56 6,264.95 -6,506.85 6,280.32 5,923,514.42 487,572.58 3.24 4,659.67 MWD+IFR-AK-CAZ-SC(6) 21,281.54 86.61 191.68 6,429.87 6,270.26 -6,599.26 6,260.05 5,923,422.06 487,552.08 1.50 4,754.18 MWD+IFR-AK-CAZ-SC(6) 21,375.71 88.45 189.16 6,433.93 6,274.32 -6,691.78 6,243.04 5,923,329.60 487,534.84 3.31 4,847.95 MWD+IFR-AK-CAZ-SC(6) 21,469.44 89.41 188.39 6,435.68 6,276.07 -6,784.39 6,228.74 5,923,237.03 487,520.32 1.31 4,941.10 MWD+IFR-AK-CAZ-SC(6) 21,564.27 89.34 187.86 6,436.72 6,277.11 -6,878.27 6,215.34 5,923,143.20 487,506.68 0.56 5,035.25 MWD+IFR-AK-CAZ-SC(6) 21,659.83 88.48 186.63 6,438.54 6,278.93 -6,973.04 6,203.29 5,923,048.46 487,494.40 1.57 5,129.91 MWD+IFR-AK-CAZ-SC(6) 21,720.00 88.48 186.63 6,440.13 6,280.52 -7,032.79 6,196.35 5,922,988.74 487,487.31 0.00 5,189.42 PROJECTED to TD 1/19/2016 8:42:43AM Page 8 COMPASS 5000.1 Build 74 i • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Eyes ❑ ND 1 have checked to the best of my ability that the following data is correct: H Surface Coordinates • Declination 8 Convergence U GRS Survey Corrections n Survey Tool Codes Vincent Nita,*sired b>'Y,cx >r, Dk:cn-Yr scrr.05ara, o-SchLarberyr, a.-Schlumberger, Asara emiil-wosa•atsln.cern.c_ SLB DE: Cats,N16.97,814:5147 fF the Jake Voss C']c Y:3'KAAk 41 cct m-.wa way e.cac7w ao.pw,cmaNats•mse+ccmm E-US Client Representative: °�°�°I�a,r",1ten Date: 19-Ian-__O16 11 5203 • • 27063 RECEIVED APR 2 7 2015 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-01 2S-01 Definitive Survey Report 18 January, 2016 NAD 83 • Schlumberger Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-01 Well Position +N/-S 0.00 usft Northing: 5,929,785.74 usft Latitude: 70° 13'10.937 N +E/-W 0.00 usft Easting: 1,621,342.33 usft Longitude: 150°9'13.988 W' Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 12/30/2015 18.42 80.86 57,486 Design 2S-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.61 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.61 0.00 0.00 195.00 Survey Program Date 1/18/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 84.00 839.00 2S-01 Srvy#1 -GYD-GC-SS(2S-01) GYD-GC-SS Gyrodata gyro single shots 12/17/2015 9:1 863.34 2,889.66 2S-01 Srvy#2-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/17/2015 9: 2,969.65 5,955.96 2S-01 Srvy#3-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/22/2015 11 6,046.37 12,512.12 2S-01 Srvy#4-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2015 10 12,571.05 12,571.05 2S-01 Srvy#5-INC+TREND(2S-01) INC+TREND Inclinometer+known azi trend 1/7/2016 8:22. 12,666.66 21,659.83 2S-01 Srvy#6-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/8/2016 9:26 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.61 0.00 0.00 39.61 -120.00 0.00 0.00 5,929,785.74 1,621,342.33 0.00 0.00 UNDEFINED 84.00 0.61 294.79 84.00 -75.61 0.10 -0.21 5,929,785.84 1,621,342.12 1.37 -0.04 GYD-GC-SS(1) 118.50 0.66 294.99 118.50 -41.11 0.26 -0.56 5,929,786.00 1,621,341.77 0.15 -0.11 NOT an Actual Survey 16"x 20" 184.00 0.76 295.30 183.99 24.38 0.61 -1.30 5,929,786.35 1,621,341.03 0.15 -0.25 GYD-GC-SS(1) 276.00 1.08 300.08 275.98 116.37 1.30 -2.60 5,929,787.05 1,621,339.73 0.36 -0.58 GYD-GC-SS(1) 370.00 0.82 356.34 369.97 210.36 2.42 -3.41 5,929,788.16 1,621,338.93 0.98 -1.45 GYD-GC-SS(1) 462.00 2.52 54.48 461.93 302.32 4.25 -1.80 5,929,789.99 1,621,340.54 2.39 -3.64 GYD-GC-SS(1) 557.00 3.50 62.90 556.80 397.19 6.78 2.48 5,929,792.52 1,621,344.82 1.13 -7.19 GYD-GC-SS(1) 650.00 4.12 74.68 649.59 489.98 8.96 8.23 5,929,794.68 1,621,350.58 1.07 -10.78 GYD-GC-SS(1) 1 1/18/2016 4:42:19PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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 745.00 4.70 77.85 744.31 584.70 10.68 15.32 5,929,796.38 1,621,357.68 0.66 -14.28 GYD-GC-SS(1) 839.00 5.41 71.52 837.95 678.34 12.89 23.29 5,929,798.57 1,621,365.65 0.96 -18.48 GYD-GC-SS(1) 863.34 5.44 67.69 862.18 702.57 13.70 25.45 5,929,799.37 1,621,367.81 1.49 -19.82 MWD+IFR-AK-CAZ-SC(2) 958.04 6.22 63.52 956.39 796.78 17.69 34.19 5,929,803.34 1,621,376.56 0.94 -25.93 MWD+IFR-AK-CAZ-SC(2) 1,052.28 7.57 66.62 1,049.95 890.34 22.43 44.46 5,929,808.05 1,621,386.84 1.49 -33.17 MWD+IFR-AK-CAZ-SC(2) 1,146.12 8.95 65.38 1,142.81 983.20 27.92 56.77 5,929,813.52 1,621,399.16 1.48 -41.66 MWD+IFR-AK-CAZ-SC(2) 1,240.91 11.25 62.85 1,236.12 1,076.51 35.21 71.70 5,929,820.77 1,621,414.11 2.47 -52.57 MWD+IFR-AK-CAZ-SC(2) 1,335.43 15.64 62.42 1,328.03 1,168.42 45.33 91.21 5,929,830.83 1,621,433.64 4.65 -67.39 MWD+IFR-AK-CAZ-SC(2) 1,430.70 16.64 62.38 1,419.55 1,259.94 57.60 114.68 5,929,843.04 1,621,457.14 1.05 -85.31 MWD+IFR-AK-CAZ-SC(2) 1,524.30 18.13 64.66 1,508.87 1,349.26 70.04 139.72 5,929,855.42 1,621,482.21 1.75 -103.82 MWD+IFR-AK-CAZ-SC(2) 1,618.41 19.93 64.46 1,597.83 1,438.22 83.23 167.42 5,929,868.53 1,621,509.95 1.91 -123.72 MWD+IFR-AK-CAZ-SC(2) 1,713.85 21.53 65.92 1,687.09 1,527.48 97.38 198.09 5,929,882.61 1,621,540.65 1.76 -145.34 MWD+IFR-AK-CAZ-SC(2) 1,808.53 25.67 67.86 1,773.83 1,614.22 112.21 232.96 5,929,897.35 1,621,575.55 4.45 -168.68 MWD+IFR-AK-CAZ-SC(2) 1,903.85 29.11 68.07 1,858.46 1,698.85 128.65 273.61 5,929,913.69 1,621,616.23 3.61 -195.08 MWD+IFR-AK-CAZ-SC(2) 1,998.34 31.36 67.22 1,940.09 1,780.48 146.76 317.60 5,929,931.68 1,621,660.27 2.42 -223.96 MWD+IFR-AK-CAZ-SC(2) 2,093.33 34.19 66.72 2,019.95 1,860.34 166.88 364.92 5,929,951.68 1,621,707.63 2.99 -255.64 MWD+IFR-AK-CAZ-SC(2) 2,187.89 37.04 63.71 2,096.82 1,937.21 190.00 414.87 5,929,974.68 1,621,757.64 3.54 -290.91 MWD+IFR-AK-CAZ-SC(2) 2,282.23 40.05 62.07 2,170.60 2,010.99 216.81 467.18 5,930,001.35 1,621,810.01 3.37 -330.34 MWD+IFR-AK-CAZ-SC(2) 2,376.85 43.57 61.39 2,241.11 2,081.50 246.69 522.72 5,930,031.09 1,621,865.62 3.75 -373.58 MWD+IFR-AK-CAZ-SC(2) 2,470.82 44.76 60.58 2,308.52 2,148.91 278.45 579.97 5,930,062.70 1,621,922.94 1.40 -419.07 MWD+IFR-AK-CAZ-SC(2) 2,565.64 47.68 61.98 2,374.12 2,214.51 311.33 640.01 5,930,095.42 1,621,983.06 3.26 -466.37 MWD+IFR-AK-CAZ-SC(2) 2,660.48 49.36 62.69 2,436.93 2,277.32 344.31 702.94 5,930,128.24 1,622,046.06 1.86 -514.51 MWD+IFR-AK-CAZ-SC(2) 2,753.26 54.04 61.90 2,494.42 2,334.81 378.17 767.37 5,930,161.93 1,622,110.58 5.09 -563.89 MWD+IFR-AK-CAZ-SC(2) 2,849.33 56.31 62.11 2,549.28 2,389.67 415.18 837.01 5,930,198.76 1,622,180.30 2.37 -617.67 MWD+IFR-AK-CAZ-SC(2) 2,889.66 58.69 61.80 2,570.95 2,411.34 431.17 867.02 5,930,214.68 1,622,210.35 5.94 -640.88 MWD+IFR-AK-CAZ-SC(2) 2,951.00 59.06 60.33 2,602.66 2,443.05 456.58 912.97 5,930,239.96 1,622,256.36 2.13 -677.31 NOT an Actual Survey(3) 10 3/4"x 13-1/2" 2,969.65 59.17 59.89 2,612.23 2,452.62 464.55 926.85 5,930,247.90 1,622,270.26 2.13 -688.61 MWD+IFR-AK-CAZ-SC(3) 3,022.65 60.47 61.03 2,638.88 2,479.27 487.14 966.71 5,930,270.38 1,622,310.17 3.08 -720.74 MWD+IFR-AK-CAZ-SC(3) 3,121.62 64.04 61.37 2,684.94 2,525.33 529.32 1,043.46 5,930,312.37 1,622,387.02 3.62 -781.35 MWD+IFR-AK-CAZ-SC(3) 3,211.94 66.32 61.52 2,722.86 2,563.25 568.51 1,115.46 5,930,351.37 1,622,459.11 2.53 -837.84 MWD+IFR-AK-CAZ-SC(3) 3,307.43 68.81 61.14 2,759.30 2,599.69 610.85 1,192.89 5,930,393.51 1,622,536.64 2.63 -898.78 MWD+IFR-AK-CAZ-SC(3) 3,403.45 69.15 61.47 2,793.74 2,634.13 653.88 1,271.51 5,930,436.34 1,622,615.37 0.48 -960.70 MWD+IFR-AK-CAZ-SC(3) 3,496.67 69.62 61.83 2,826.56 2,666.95 695.32 1,348.30 5,930,477.58 1,622,692.25 0.62 -1,020.59 MWD+IFR-AK-CAZ-SC(3) 3,590.88 69.61 61.69 2,859.37 2,699.76 737.10 1,426.10 5,930,519.16 1,622,770.15 0.14 -1,081.09 MWD+IFR-AK-CAZ-SC(3) 3,685.79 69.68 61.60 2,892.39 2,732.78 779.36 1,504.41 5,930,561.22 1,622,848.55 0.12 -1,142.18 MWD+IFR-AK-CAZ-SC(3) 3,780.39 69.67 62.07 2,925.25 2,765.64 821.23 1,582.61 5,930,602.89 1,622,926.86 0.47 -1,202.86 MWD+IFR-AK-CAZ-SC(3) 3,874.54 69.63 61.75 2,957.99 2,798.38 862.80 1,660.49 5,930,644.25 1,623,004.83 0.32 -1,263.17 MWD+IFR-AK-CAZ-SC(3) 3,968.93 70.14 60.83 2,990.45 2,830.84 905.38 1,738.22 5,930,686.63 1,623,082.66 1.06 -1,324.41 MWD+IFR-AK-CAZ-SC(3) 4,063.87 70.18 60.72 3,022.67 2,863.06 948.98 1,816.16 5,930,730.03 1,623,160.70 0.12 -1,386.70 MWD+IFR-AK-CAZ-SC(3) 1/18/2016 4:42:19PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,157.78 69.66 61.97 3,054.91 2,895.30 991.27 1,893.56 5,930,772.13 1,623,238.20 1.37 -1,447.59 MWD+IFR-AK-CAZ-SC(3) 4,252.12 69.61 62.14 3,087.75 2,928.14 1,032.72 1,971.69 5,930,813.37 1,623,316.42 0.18 -1,507.84 MWD+IFR-AK-CAZ-SC(3) 4,346.55 69.58 62.70 3,120.67 2,961.06 1,073.70 2,050.13 5,930,854.15 1,623,394.97 0.56 -1,567.73 MWD+IFR-AK-CAZ-SC(3) 4,442.96 69.62 62.47 3,154.27 2,994.66 1,115.30 2,130.35 5,930,895.55 1,623,475.28 0.23 -1,628.68 MWD+IFR-AK-CAZ-SC(3) 4,536.26 69.58 63.31 3,186.80 3,027.19 1,155.15 2,208.19 5,930,935.19 1,623,553.21 0.84 -1,687.31 MWD+IFR-AK-CAZ-SC(3) 4,631.02 69.55 63.92 3,219.88 3,060.27 1,194.61 2,287.73 5,930,974.45 1,623,632.85 0.60 -1,746.02 MWD+IFR-AK-CAZ-SC(3) 4,729.75 69.58 64.11 3,254.35 3,094.74 1,235.15 2,370.90 5,931,014.77 1,623,716.11 0.18 -1,806.70 MWD+IFR-AK-CAZ-SC(3) 4,820.19 69.62 63.77 3,285.88 3,126.27 1,272.39 2,447.05 5,931,051.81 1,623,792.34 0.36 -1,862.38 MWD+IFR-AK-CAZ-SC(3) 4,913.24 69.65 63.16 3,318.26 3,158.65 1,311.36 2,525.09 5,931,090.58 1,623,870.48 0.62 -1,920.22 MWD+IFR-AK-CAZ-SC(3) 5,008.61 69.61 63.22 3,351.46 3,191.85 1,351.68 2,604.89 5,931,130.70 1,623,950.37 0.07 -1,979.82 MWD+IFR-AK-CAZ-SC(3) 5,102.60 69.55 63.10 3,384.25 3,224.64 1,391.45 2,683.48 5,931,170.27 1,624,029.05 0.14 -2,038.58 MWD+IFR-AK-CAZ-SC(3) 5,198.70 69.61 63.17 3,417.78 3,258.17 1,432.15 2,763.82 5,931,210.76 1,624,109.49 0.09 -2,098.68 MWD+IFR-AK-CAZ-SC(3) 5,293.66 69.75 62.73 3,450.75 3,291.14 1,472.65 2,843.13 5,931,251.05 1,624,188.89 0.46 -2,158.33 MWD+IFR-AK-CAZ-SC(3) 5,388.04 69.52 62.27 3,483.60 3,323.99 1,513.51 2,921.62 5,931,291.71 1,624,267.47 0.52 -2,218.10 MWD+IFR-AK-CAZ-SC(3) 5,481.73 69.58 61.69 3,516.33 3,356.72 1,554.74 2,999.11 5,931,332.75 1,624,345.06 0.58 -2,278.00 MWD+IFR-AK-CAZ-SC(3) 5,578.13 69.55 60.91 3,549.99 3,390.38 1,598.12 3,078.35 5,931,375.92 1,624,424.40 0.76 -2,340.40 MWD+IFR-AK-CAZ-SC(3) 5,670.05 69.65 60.86 3,582.03 3,422.42 1,640.04 3,153.61 5,931,417.65 1,624,499.76 0.12 -2,400.38 MWD+IFR-AK-CAZ-SC(3) 5,765.67 69.55 61.28 3,615.36 3,455.75 1,683.40 3,232.05 5,931,460.80 1,624,578.31 0.42 -2,462.56 MWD+IFR-AK-CAZ-SC(3) 5,859.37 69.62 61.52 3,648.05 3,488.44 1,725.43 3,309.15 5,931,502.63 1,624,655.50 0.25 -2,523.11 MWD+IFR-AK-CAZ-SC(3) 5,955.96 69.45 61.97 3,681.82 3,522.21 1,768.27 3,388.86 5,931,545.27 1,624,735.31 0.47 -2,585.12 MWD+IFR-AK-CAZ-SC(3) 6,046.37 69.74 62.21 3,713.34 3,553.73 1,807.94 3,463.74 5,931,584.74 1,624,810.29 0.41 -2,642.82 MWD+IFR-AK-CAZ-SC(4) 6,140.84 69.69 63.01 3,746.09 3,586.48 1,848.70 3,542.42 5,931,625.30 1,624,889.06 0.80 -2,702.56 MWD+IFR-AK-CAZ-SC(4) 6,235.41 69.79 62.91 3,778.84 3,619.23 1,889.04 3,621.44 5,931,665.43 1,624,968.17 0.14 -2,761.97 MWD+IFR-AK-CAZ-SC(4) 6,330.43 69.69 64.00 3,811.74 3,652.13 1,928.87 3,701.18 5,931,705.06 1,625,048.01 1.08 -2,821.08 MWD+IFR-AK-CAZ-SC(4) 6,424.80 69.80 62.81 3,844.42 3,684.81 1,968.51 3,780.35 5,931,744.49 1,625,127.27 1.19 -2,879.86 MWD+IFR-AK-CAZ-SC(4) 6,519.68 69.77 61.96 3,877.20 3,717.59 2,009.78 3,859.24 5,931,785.56 1,625,206.25 0.84 -2,940.14 MWD+IFR-AK-CAZ-SC(4) 6,615.12 69.63 61.40 3,910.31 3,750.70 2,052.24 3,938.04 5,931,827.82 1,625,285.15 0.57 -3,001.55 MWD+IFR-AK-CAZ-SC(4) 6,708.74 69.73 60.36 3,942.83 3,783.22 2,094.96 4,014.74 5,931,870.34 1,625,361.95 1.05 -3,062.67 MWD+IFR-AK-CAZ-SC(4) 6,803.27 69.73 61.76 3,975.58 3,815.97 2,137.87 4,092.34 5,931,913.05 1,625,439.65 1.39 -3,124.20 MWD+IFR-AK-CAZ-SC(4) 6,897.89 69.79 61.15 4,008.31 3,848.70 2,180.29 4,170.32 5,931,955.27 1,625,517.73 0.61 -3,185.36 MWD+IFR-AK-CAZ-SC(4) 6,992.20 69.86 60.16 4,040.84 3,881.23 2,223.68 4,247.48 5,931,998.45 1,625,595.00 0.99 -3,247.24 MWD+IFR-AK-CAZ-SC(4) 7,087.00 69.80 60.54 4,073.53 3,913.92 2,267.70 4,324.82 5,932,042.28 1,625,672.43 0.38 -3,309.77 MWD+IFR-AK-CAZ-SC(4) 7,181.53 69.82 60.61 4,106.15 3,946.54 2,311.29 4,402.09 5,932,085.66 1,625,749.81 0.07 -3,371.88 MWD+IFR-AK-CAZ-SC(4) 7,275.82 69.73 61.08 4,138.75 3,979.14 2,354.39 4,479.36 5,932,128.57 1,625,827.18 0.48 -3,433.51 MWD+IFR-AK-CAZ-SC(4) 7,370.63 69.63 61.55 4,171.67 4,012.06 2,397.06 4,557.36 5,932,171.04 1,625,905.28 0.48 -3,494.92 MWD+IFR-AK-CAZ-SC(4) 7,465.99 69.77 61.74 4,204.76 4,045.15 2,439.54 4,636.07 5,932,213.31 1,625,984.08 0.24 -3,556.32 MWD+IFR-AK-CAZ-SC(4) 7,564.31 69.74 63.46 4,238.78 4,079.17 2,481.99 4,717.96 5,932,255.55 1,626,066.08 1.64 -3,618.52 MWD+IFR-AK-CAZ-SC(4) 7,653.49 69.70 62.91 4,269.69 4,110.08 2,519.73 4,792.62 5,932,293.10 1,626,140.82 0.58 -3,674.29 MWD+IFR-AK-CAZ-SC(4) 7,749.38 69.71 63.31 4,302.95 4,143.34 2,560.40 4,872.83 5,932,333.57 1,626,221.13 0.39 -3,734.34 MWD+IFR-AK-CAZ-SC(4) 7,843.29 69.57 64.17 4,335.62 4,176.01 2,599.36 4,951.78 5,932,372.32 1,626,300.17 0.87 -3,792.40 MWD+IFR-AK-CAZ-SC(4) 1/18/2016 4:42:19PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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) (°1100') (ft) Survey Tool Name 7,938.35 69.74 63.70 4,368.67 4,209.06 2,638.52 5,031.85 5,932,411.27 1,626,380.33 0.50 -3,850.95 MWD+IFR-AK-CAZ-SC(4) 8,031.58 69.73 62.76 4,400.97 4,241.36 2,677.91 5,109.93 5,932,450.46 1,626,458.50 0.95 -3,909.21 MWD+IFR-AK-CAZ-SC(4) 8,126.13 69.71 61.86 4,433.74 4,274.13 2,719.12 5,188.46 5,932,491.47 1,626,537.13 0.89 -3,969.35 MWD+IFR-AK-CAZ-SC(4) 8,221.47 69.60 61.17 4,466.89 4,307.28 2,761.76 5,267.03 5,932,533.90 1,626,615.80 0.69 -4,030.86 MWD+IFR-AK-CAZ-SC(4) 8,315.96 69.77 61.34 4,499.69 4,340.08 2,804.37 5,344.73 5,932,576.32 1,626,693.59 0.25 -4,092.13 MWD+IFR-AK-CAZ-SC(4) 8,410.46 69.79 60.94 4,532.35 4,372.74 2,847.17 5,422.39 5,932,618.92 1,626,771.36 0.40 -4,153.58 MWD+IFR-AK-CAZ-SC(4) 8,505.43 69.73 62.06 4,565.21 4,405.60 2,889.69 5,500.69 5,932,661.23 1,626,849.76 1.11 -4,214.91 MWD+IFR-AK-CAZ-SC(4) 8,599.82 69.76 61.79 4,597.89 4,438.28 2,931.37 5,578.83 5,932,702.71 1,626,927.99 0.27 -4,275.39 MWD+IFR-AK-CAZ-SC(4) 8,694.74 69.81 61.56 4,630.69 4,471.08 2,973.63 5,657.24 5,932,744.77 1,627,006.50 0.23 -4,336.50 MWD+IFR-AK-CAZ-SC(4) 8,789.09 69.67 61.71 4,663.36 4,503.75 3,015.68 5,735.12 5,932,786.62 1,627,084.48 0.21 -4,397.28 MWD+IFR-AK-CAZ-SC(4) 8,884.04 69.81 61.38 4,696.24 4,536.63 3,058.12 5,813.44 5,932,828.86 1,627,162.90 0.36 -4,458.55 MWD+IFR-AK-CAZ-SC(4) 8,978.74 69.28 63.15 4,729.33 4,569.72 3,099.41 5,891.97 5,932,869.95 1,627,241.52 1.84 -4,518.76 MWD+IFR-AK-CAZ-SC(4) 9,072.59 68.76 66.54 4,762.95 4,603.34 3,136.66 5,971.27 5,932,906.99 1,627,320.91 3.42 -4,575.26 MWD+IFR-AK-CAZ-SC(4) 9,167.47 68.45 68.23 4,797.56 4,637.95 3,170.63 6,052.81 5,932,940.75 1,627,402.53 1.69 -4,629.18 MWD+IFR-AK-CAZ-SC(4) 9,261.56 68.30 70.43 4,832.24 4,672.63 3,201.50 6,134.64 5,932,971.41 1,627,484.43 2.18 -4,680.18 MWD+IFR-AK-CAZ-SC(4) 9,355.54 68.10 71.60 4,867.14 4,707.53 3,229.89 6,217.15 5,932,999.59 1,627,567.01 1.18 -4,728.95 MWD+IFR-AK-CAZ-SC(4) 9,453.28 67.46 73.65 4,904.11 4,744.50 3,256.91 6,303.50 5,933,026.39 1,627,653.41 2.05 -4,777.40 MWD+IFR-AK-CAZ-SC(4) 9,545.54 66.12 76.14 4,940.47 4,780.86 3,279.01 6,385.35 5,933,048.28 1,627,735.31 2.87 -4,819.93 MWD+IFR-AK-CAZ-SC(4) 9,639.05 65.50 79.25 4,978.79 4,819.18 3,297.19 6,468.67 5,933,066.25 1,627,818.67 3.11 -4,859.06 MWD+IFR-AK-CAZ-SC(4) 9,734.16 63.96 82.05 5,019.40 4,859.79 3,311.18 6,553.52 5,933,080.02 1,627,903.55 3.12 -4,894.53 MWD+IFR-AK-CAZ-SC(4) 9,828.99 62.55 85.01 5,062.08 4,902.47 3,320.73 6,637.65 5,933,089.36 1,627,987.69 3.16 -4,925.53 MWD+IFR-AK-CAZ-SC(4) 9,923.33 62.73 87.39 5,105.44 4,945.83 3,326.28 6,721.24 5,933,094.70 1,628,071.29 2.25 -4,952.53 MWD+IFR-AK-CAZ-SC(4) 10,018.61 61.48 90.51 5,150.03 4,990.42 3,327.84 6,805.42 5,933,096.04 1,628,155.46 3.18 -4,975.82 MWD+IFR-AK-CAZ-SC(4) 10,113.47 60.59 95.60 5,195.99 5,036.38 3,323.44 6,888.26 5,933,091.43 1,628,238.28 4.79 -4,993.00 MWD+IFR-AK-CAZ-SC(4) 10,207.39 61.27 100.56 5,241.64 5,082.03 3,311.89 6,969.49 5,933,079.68 1,628,319.48 4.67 -5,002.88 MWD+IFR-AK-CAZ-SC(4) 10,302.79 61.83 104.08 5,287.10 5,127.49 3,293.99 7,051.42 5,933,061.57 1,628,401.35 3.30 -5,006.79 MWD+IFR-AK-CAZ-SC(4) 10,396.93 61.67 107.78 5,331.67 5,172.06 3,271.24 7,131.14 5,933,038.62 1,628,481.01 3.47 -5,005.45 MWD+IFR-AK-CAZ-SC(4) 10,491.27 60.92 110.92 5,376.99 5,217.38 3,243.83 7,209.20 5,933,011.02 1,628,558.99 3.03 -4,999.18 MWD+IFR-AK-CAZ-SC(4) 10,586.26 59.69 113.68 5,424.06 5,264.45 3,212.54 7,285.54 5,932,979.54 1,628,635.24 2.84 -4,988.71 MWD+IFR-AK-CAZ-SC(4) 10,681.17 59.36 116.26 5,472.20 5,312.59 3,178.02 7,359.68 5,932,944.83 1,628,709.29 2.37 -4,974.55 MWD+IFR-AK-CAZ-SC(4) 10,775.96 59.93 118.30 5,520.10 5,360.49 3,140.53 7,432.37 5,932,907.16 1,628,781.88 1.95 -4,957.15 MWD+IFR-AK-CAZ-SC(4) 10,871.21 61.11 120.90 5,566.98 5,407.37 3,099.57 7,504.45 5,932,866.02 1,628,853.85 2.68 -4,936.25 MWD+IFR-AK-CAZ-SC(4) 10,965.55 61.35 123.80 5,612.40 5,452.79 3,055.32 7,574.30 5,932,821.61 1,628,923.57 2.71 -4,911.59 MWD+IFR-AK-CAZ-SC(4) 11,061.46 61.93 126.60 5,657.96 5,498.35 3,006.67 7,643.25 5,932,772.79 1,628,992.40 2.64 -4,882.44 MWD+IFR-AK-CAZ-SC(4) 11,155.13 62.85 129.95 5,701.38 5,541.77 2,955.26 7,708.40 5,932,721.22 1,629,057.40 3.32 -4,849.64 MWD+IFR-AK-CAZ-SC(4) 11,249.55 63.36 134.05 5,744.11 5,584.50 2,898.93 7,770.95 5,932,664.73 1,629,119.81 3.91 -4,811.42 MWD+IFR-AK-CAZ-SC(4) 11,344.07 63.66 138.26 5,786.28 5,626.67 2,837.93 7,829.53 5,932,603.59 1,629,178.23 4.00 -4,767.66 MWD+IFR-AK-CAZ-SC(4) 11,438.26 64.24 142.75 5,827.66 5,668.05 2,772.65 7,883.32 5,932,538.18 1,629,231.85 4.33 -4,718.53 MWD+IFR-AK-CAZ-SC(4) 11,533.86 65.06 145.99 5,868.60 5,708.99 2,702.44 7,933.64 5,932,467.85 1,629,281.98 3.18 -4,663.73 MWD+IFR-AK-CAZ-SC(4) 11,627.70 66.20 148.62 5,907.33 5,747.72 2,630.51 7,979.80 5,932,395.81 1,629,327.95 2.83 -4,606.20 MWD+IFR-AK-CAZ-SC(4) 1/18/2016 4:42:19PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,722.74 67.38 152.17 5,944.79 5,785.18 2,554.57 8,022.93 5,932,319.78 1,629,370.89 3.65 -4,544.01 MWD+IFR-AK-CAZ-SC(4) 11,817.37 68.46 155.10 5,980.37 5,820.76 2,476.01 8,061.86 5,932,241.12 1,629,409.61 3.09 -4,478.21 MWD+IFR-AK-CAZ-SC(4) 11,912.31 69.09 156.58 6,014.74 5,855.13 2,395.27 8,098.07 5,932,160.30 1,629,445.62 1.60 -4,409.59 MWD+IFR-AK-CAZ-SC(4) 12,006.26 68.86 157.71 6,048.45 5,888.84 2,314.46 8,132.13 5,932,079.41 1,629,479.48 1.15 -4,340.35 MWD+IFR-AK-CAZ-SC(4) 12,101.29 69.65 160.48 6,082.12 5,922.51 2,231.45 8,163.83 5,931,996.33 1,629,510.96 2.85 -4,268.37 MWD+IFR-AK-CAZ-SC(4) 12,195.51 71.59 162.74 6,113.38 5,953.77 2,147.11 8,191.86 5,931,911.93 1,629,538.78 3.06 -4,194.16 MWD+IFR-AK-CAZ-SC(4) 12,290.59 74.03 165.57 6,141.49 5,981.88 2,059.75 8,216.64 5,931,824.51 1,629,563.33 3.83 -4,116.19 MWD+IFR-AK-CAZ-SC(4) 12,385.39 76.48 168.31 6,165.62 6,006.01 1,970.45 8,237.34 5,931,735.17 1,629,583.81 3.81 -4,035.29 MWD+IFR-AK-CAZ-SC(4) 12,480.60 77.85 172.31 6,186.78 6,027.17 1,878.97 8,252.96 5,931,643.66 1,629,599.19 4.34 -3,950.96 MWD+IFR-AK-CAZ-SC(4) 12,512.12 77.98 173.39 6,193.38 6,033.77 1,848.39 8,256.79 5,931,613.07 1,629,602.95 3.38 -3,922.42 MWD+IFR-AK-CAZ-SC(4) 12,571.05 78.19 173.00 6,205.54 6,045.93 1,791.13 8,263.63 5,931,555.80 1,629,609.63 0.74 -3,868.88 INC+TREND(5) 12,574.00 78.18 172.97 6,206.15 6,046.54 1,788.27 8,263.98 5,931,552.94 1,629,609.98 1.19 -3,866.21 NOT an Actual Survey (6) 7-5/8"-9-7/8 x 11" 12,666.66 77.71 171.94 6,225.50 6,065.89 1,698.44 8,275.88 5,931,463.09 1,629,621.65 1.19 -3,782.52 MWD+IFR-AK-CAZ-SC(6) 12,761.77 75.71 175.07 6,247.37 6,087.76 1,606.49 8,286.36 5,931,371.12 1,629,631.89 3.83 -3,696.41 MWD+IFR-AK-CAZ-SC(6) 12,856.21 75.05 178.87 6,271.22 6,111.61 1,515.25 8,291.19 5,931,279.88 1,629,636.50 3.96 -3,609.54 MWD+IFR-AK-CAZ-SC(6) 12,951.13 75.97 180.43 6,294.97 6,135.36 1,423.36 8,291.75 5,931,188.00 1,629,636.82 1.86 -3,520.92 MWD+IFR-AK-CAZ-SC(6) 13,046.58 80.30 180.40 6,314.59 6,154.98 1,329.97 8,291.07 5,931,094.62 1,629,635.91 4.54 -3,430.54 MWD+IFR-AK-CAZ-SC(6) 13,141.51 84.37 180.82 6,327.25 6,167.64 1,235.91 8,290.07 5,931,000.58 1,629,634.67 4.31 -3,339.43 MWD+IFR-AK-CAZ-SC(6) 13,235.84 85.87 184.41 6,335.27 6,175.66 1,142.04 8,285.78 5,930,906.73 1,629,630.14 4.11 -3,247.65 MWD+IFR-AK-CAZ-SC(6) 13,330.83 83.89 188.73 6,343.75 6,184.14 1,048.08 8,274.96 5,930,812.80 1,629,619.09 4.99 -3,154.08 MWD+IFR-AK-CAZ-SC(6) 13,425.88 84.91 191.53 6,353.03 6,193.42 954.97 8,258.32 5,930,719.74 1,629,602.22 3.12 -3,059.84 MWD+IFR-AK-CAZ-SC(6) 13,520.68 87.03 193.91 6,359.69 6,200.08 862.74 8,237.50 5,930,627.57 1,629,581.17 3.36 -2,965.36 MWD+IFR-AK-CAZ-SC(6) 13,615.59 90.66 197.00 6,361.61 6,202.00 771.30 8,212.22 5,930,536.21 1,629,555.66 5.02 -2,870.50 MWD+IFR-AK-CAZ-SC(6) 13,710.65 91.86 198.35 6,359.52 6,199.91 680.76 8,183.37 5,930,445.75 1,629,526.58 1.90 -2,775.57 MWD+IFR-AK-CAZ-SC(6) 13,805.18 90.78 197.62 6,357.34 6,197.73 590.87 8,154.19 5,930,355.94 1,629,497.17 1.38 -2,681.20 MWD+IFR-AK-CAZ-SC(6) 13,899.61 89.68 196.15 6,356.96 6,197.35 500.52 8,126.76 5,930,265.67 1,629,469.52 1.94 -2,586.82 MWD+IFR-AK-CAZ-SC(6) 13,994.80 89.92 193.68 6,357.29 6,197.68 408.54 8,102.26 5,930,173.76 1,629,444.79 2.61 -2,491.64 MWD+IFR-AK-CAZ-SC(6) 14,090.52 89.82 191.53 6,357.51 6,197.90 315.13 8,081.38 5,930,080.42 1,629,423.67 2.25 -2,396.01 MWD+IFR-AK-CAZ-SC(6) 14,184.83 89.96 192.47 6,357.69 6,198.08 222.89 8,061.77 5,929,988.23 1,629,403.83 1.01 -2,301.83 MWD+IFR-AK-CAZ-SC(6) 14,279.75 89.29 195.30 6,358.31 6,198.70 130.75 8,038.99 5,929,896.16 1,629,380.83 3.06 -2,206.94 MWD+IFR-AK-CAZ-SC(6) 14,375.49 90.63 196.00 6,358.38 6,198.77 38.56 8,013.17 5,929,804.05 1,629,354.77 1.58 -2,111.21 MWD+IFR-AK-CAZ-SC(6) 14,470.24 89.29 196.87 6,358.45 6,198.84 -52.31 7,986.36 5,929,713.25 1,629,327.74 1.69 -2,016.49 MWD+IFR-AK-CAZ-SC(6) 14,564.84 89.37 199.26 6,359.55 6,199.94 -142.24 7,957.03 5,929,623.41 1,629,298.18 2.53 -1,922.04 MWD+IFR-AK-CAZ-SC(6) 14,660.05 88.76 199.87 6,361.11 6,201.50 -231.94 7,925.15 5,929,533.80 1,629,266.08 0.91 -1,827.15 MWD+IFR-AK-CAZ-SC(6) 14,754.87 87.07 198.84 6,364.56 6,204.95 -321.33 7,893.75 5,929,444.49 1,629,234.45 2.09 -1,732.67 MWD+IFR-AK-CAZ-SC(6) 14,849.61 86.52 197.37 6,369.85 6,210.24 -411.24 7,864.35 5,929,354.67 1,629,204.84 1.65 -1,638.22 MWD+IFR-AK-CAZ-SC(6) 14,944.83 86.65 195.24 6,375.53 6,215.92 -502.46 7,837.67 5,929,263.52 1,629,177.92 2.24 -1,543.20 MWD+IFR-AK-CAZ-SC(6) 15,039.60 88.31 194.48 6,379.69 6,220.08 -593.97 7,813.39 5,929,172.09 1,629,153.42 1.93 -1,448.52 MWD+IFR-AK-CAZ-SC(6) 15,134.33 89.82 193.47 6,381.24 6,221.63 -685.88 7,790.52 5,929,080.24 1,629,130.31 1.92 -1,353.83 MWD+IFR-AK-CAZ-SC(6) 1/18/2016 4:42:19PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,229.11 90.23 191.01 6,381.20 6,221.59 -778.50 7,770.42 5,928,987.69 1,629,109.99 2.63 -1,259.16 MWD+IFR-AK-CAZ-SC(6) 15,323.97 90.75 190.27 6,380.39 6,220.78 -871.72 7,752.91 5,928,894.51 1,629,092.24 0.95 -1,164.58 MWD+IFR-AK-CAZ-SC(6) , 15,419.11 90.33 190.01 6,379.49 6,219.88 -965.37 7,736.16 5,928,800.92 1,629,075.26 0.52 -1,069.79 MWD+IFR-AK-CAZ-SC(6) 15,514.10 89.65 188.75 6,379.51 6,219.90 -1,059.09 7,720.68 5,928,707.25 1,629,059.54 1.51 -975.26 MWD+IFR-AK-CAZ-SC(6) 15,608.75 89.61 187.36 6,380.12 6,220.51 -1,152.80 7,707.42 5,928,613.58 1,629,046.04 1.47 -881.31 MWD+IFR-AK-CAZ-SC(6) 15,703.73 89.82 186.95 6,380.59 6,220.98 -1,247.04 7,695.59 5,928,519.38 1,629,033.98 0.48 -787.22 MWD+IFR-AK-CAZ-SC(6) 15,798.16 89.65 187.82 6,381.03 6,221.42 -1,340.68 7,683.45 5,928,425.78 1,629,021.60 0.94 -693.62 MWD+IFR-AK-CAZ-SC(6) 15,893.10 90.37 188.58 6,381.01 6,221.40 -1,434.65 7,669.91 5,928,331.85 1,629,007.83 1.10 -599.35 MWD+IFR-AK-CAZ-SC(6) 15,988.09 91.70 188.25 6,379.29 6,219.68 -1,528.60 7,656.01 5,928,237.95 1,628,993.69 1.44 -505.00 MWD+IFR-AK-CAZ-SC(6) 16,082.54 87.81 188.71 6,379.70 6,220.09 -1,622.00 7,642.09 5,928,144.59 1,628,979.53 4.15 -411.18 MWD+IFR-AK-CAZ-SC(6) 16,177.90 89.99 189.18 6,381.53 6,221.92 -1,716.18 7,627.26 5,928,050.46 1,628,964.47 2.34 -316.38 MWD+IFR-AK-CAZ-SC(6) 16,272.59 91.02 188.56 6,380.69 6,221.08 -1,809.73 7,612.66 5,927,956.96 1,628,949.64 1.27 -222.24 MWD+IFR-AK-CAZ-SC(6) 16,366.15 91.50 188.29 6,378.64 6,219.03 -1,902.26 7,598.96 5,927,864.47 1,628,935.70 0.59 -129.32 MWD+IFR-AK-CAZ-SC(6) 16,461.60 92.12 187.62 6,375.62 6,216.01 -1,996.74 7,585.76 5,927,770.03 1,628,922.26 0.96 -34.63 MWD+IFR-AK-CAZ-SC(6) 16,557.27 91.67 185.41 6,372.46 6,212.85 -2,091.74 7,574.91 5,927,675.08 1,628,911.17 2.36 59.93 MWD+IFR-AK-CAZ-SC(6) 16,651.13 91.41 184.24 6,369.93 6,210.32 -2,185.23 7,567.02 5,927,581.61 1,628,903.05 1.28 152.28 MWD+IFR-AK-CAZ-SC(6) 16,747.05 89.89 185.29 6,368.85 6,209.24 -2,280.81 7,559.05 5,927,486.07 1,628,894.84 1.93 246.66 MWD+I FR-AK-CAZ-SC(6) 16,841.74 89.72 186.97 6,369.17 6,209.56 -2,374.95 7,548.94 5,927,391.96 1,628,884.49 1.78 340.22 MWD+IFR-AK-CAZ-SC(6) 16,936.78 89.27 185.91 6,370.01 6,210.40 -2,469.39 7,538.28 5,927,297.56 1,628,873.59 1.21 434.19 MWD+IFR-AK-CAZ-SC(6) 17,031.64 89.37 185.92 6,371.13 6,211.52 -2,563.73 7,528.50 5,927,203.24 1,628,863.58 0.11 527.86 MWD+IFR-AK-CAZ-SC(6) 17,126.71 89.03 186.72 6,372.46 6,212.85 -2,658.22 7,518.04 5,927,108.80 1,628,852.88 0.91 621.83 MWD+IFR-AK-CAZ-SC(6) 17,222.19 88.62 188.48 6,374.42 6,214.81 -2,752.83 7,505.41 5,927,014.22 1,628,840.02 1.89 716.49 MWD+IFR-AK-CAZ-SC(6) 17,314.68 88.93 189.62 6,376.39 6,216.78 -2,844.15 7,490.87 5,926,922.95 1,628,825.24 1.28 808.46 MWD+IFR-AK-CAZ-SC(6) 17,410.75 89.61 189.82 6,377.62 6,218.01 -2,938.83 7,474.65 5,926,828.32 1,628,808.79 0.74 904.11 MWD+IFR-AK-CAZ-SC(6) 17,503.96 90.39 190.21 6,377.62 6,218.01 -3,030.62 7,458.44 5,926,736.58 1,628,792.35 0.94 996.97 MWD+IFR-AK-CAZ-SC(6) 17,598.29 89.32 192.77 6,377.86 6,218.25 -3,123.05 7,439.65 5,926,644.21 1,628,773.33 2.94 1,091.11 MWD+IFR-AK-CAZ-SC(6) 17,693.31 86.70 195.99 6,381.16 6,221.55 -3,215.02 7,416.08 5,926,552.31 1,628,749.52 4.37 1,186.05 MWD+IFR-AK-CAZ-SC(6) 17,788.13 87.76 198.61 6,385.74 6,226.13 -3,305.43 7,387.91 5,926,461.98 1,628,721.13 2.98 1,280.67 MWD+IFR-AK-CAZ-SC(6) 17,882.58 89.41 200.14 6,388.07 6,228.46 -3,394.50 7,356.59 5,926,373.00 1,628,689.59 2.38 1,374.81 MWD+IFR-AK-CAZ-SC(6) 17,976.99 89.92 202.20 6,388.63 6,229.02 -3,482.53 7,322.50 5,926,285.06 1,628,655.28 2.25 1,468.67 MWD+IFR-AK-CAZ-SC(6) 18,071.59 89.24 205.31 6,389.32 6,229.71 -3,569.11 7,284.40 5,926,198.59 1,628,616.96 3.37 1,562.15 MWD+IFR-AK-CAZ-SC(6) 18,165.44 89.75 204.29 6,390.15 6,230.54 -3,654.30 7,245.03 5,926,113.51 1,628,577.38 1.22 1,654.63 MWD+I FR-AK-CAZ-SC(6) 18,259.21 88.93 203.53 6,391.23 6,231.62 -3,740.01 7,207.03 5,926,027.90 1,628,539.17 1.19 1,747.26 MWD+IFR-AK-CAZ-SC(6) 18,354.25 89.06 201.82 6,392.89 6,233.28 -3,827.69 7,170.40 5,925,940.32 1,628,502.32 1.80 1,841.43 MWD+IFR-AK-CAZ-SC(6) 18,447.45 89.13 202.89 6,394.37 6,234.76 -3,913.87 7,134.96 5,925,854.24 1,628,466.66 1.15 1,933.85 MWD+IFR-AK-CAZ-SC(6) 18,542.74 90.13 202.74 6,394.98 6,235.37 -4,001.70 7,098.01 5,925,766.51 1,628,429.50 1.06 2,028.25 MWD+IFR-AK-CAZ-SC(6) 18,636.44 91.64 202.24 6,393.53 6,233.92 -4,088.26 7,062.17 5,925,680.05 1,628,393.44 1.70 2,121.14 MWD+IFR-AK-CAZ-SC(6) 18,728.40 90.75 204.61 6,391.62 6,232.01 -4,172.62 7,025.62 5,925,595.79 1,628,356.69 2.75 2,212.08 MWD+IFR-AK-CAZ-SC(6) 18,825.93 89.92 206.36 6,391.05 6,231.44 -4,260.65 6,983.66 5,925,507.87 1,628,314.51 1.99 2,307.97 MWD+IFR-AK-CAZ-SC(6) 18,918.30 89.55 204.93 6,391.47 6,231.86 -4,343.92 6,943.69 5,925,424.72 1,628,274.33 1.60 2,398.75 MWD+IFR-AK-CAZ-SC(6) 1/18/2016 4:42:19PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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 19,015.14 88.88 204.37 6,392.80 6,233.19 -4,431.93 6,903.30 5,925,336.82 1,628,233.72 0.90 2,494.21 MWD+IFR-AK-CAZ-SC(6) 19,109.60 90.15 203.49 6,393.60 6,233.99 -4,518.26 6,864.99 5,925,250.59 1,628,195.20 1.64 2,587.52 MWD+IFR-AK-CAZ-SC(6) 19,204.42 88.98 202.30 6,394.32 6,234.71 -4,605.61 6,828.10 5,925,163.35 1,628,158.09 1.76 2,681.43 MWD+IFR-AK-CAZ-SC(6) 19,299.09 89.79 198.96 6,395.34 6,235.73 -4,694.19 6,794.75 5,925,074.86 1,628,124.52 3.63 2,775.63 MWD+IFR-AK-CAZ-SC(6) 19,393.18 90.13 197.78 6,395.40 6,235.79 -4,783.48 6,765.10 5,924,985.65 1,628,094.65 1.31 2,869.55 MWD+IFR-AK-CAZ-SC(6) 19,487.30 89.55 198.05 6,395.66 6,236.05 -4,873.04 6,736.15 5,924,896.18 1,628,065.47 0.68 2,963.55 MWD+IFR-AK-CAZ-SC(6) 19,581.42 89.41 199.44 6,396.52 6,236.91 -4,962.16 6,705.91 5,924,807.14 1,628,035.01 1.48 3,057.46 MWD+IFR-AK-CAZ-SC(6) 19,676.95 89.97 199.52 6,397.03 6,237.42 -5,052.22 6,674.05 5,924,717.17 1,628,002.93 0.59 3,152.70 MWD+IFR-AK-CAZ-SC(6) 19,771.08 88.89 198.98 6,397.97 6,238.36 -5,141.08 6,643.02 5,924,628.40 1,627,971.67 1.28 3,246.56 MWD+IFR-AK-CAZ-SC(6) 19,864.90 89.03 198.99 6,399.67 6,240.06 -5,229.78 6,612.50 5,924,539.78 1,627,940.94 0.15 3,340.14 MWD+IFR-AK-CAZ-SC(6) 19,957.69 89.82 197.45 6,400.61 6,241.00 -5,317.91 6,583.49 5,924,451.74 1,627,911.71 1.87 3,432.78 MWD+IFR-AK-CAZ-SC(6) 20,050.98 90.16 196.98 6,400.62 6,241.01 -5,407.02 6,555.88 5,924,362.71 1,627,883.87 0.62 3,526.00 MWD+IFR-AK-CAZ-SC(6) 20,146.66 90.55 193.48 6,400.03 6,240.42 -5,499.33 6,530.75 5,924,270.48 1,627,858.51 3.68 3,621.66 MWD+IFR-AK-CAZ-SC(6) 20,241.72 89.34 190.14 6,400.12 6,240.51 -5,592.36 6,511.30 5,924,177.50 1,627,838.83 3.74 3,716.56 MWD+IFR-AK-CAZ-SC(6) 20,337.65 89.31 188.89 6,401.25 6,241.64 -5,686.96 6,495.44 5,924,082.95 1,627,822.73 1.30 3,812.04 MWD+IFR-AK-CAZ-SC(6) 20,432.45 89.30 190.80 6,402.40 6,242.79 -5,780.35 6,479.24 5,923,989.61 1,627,806.29 2.01 3,906.44 MWD+IFR-AK-CAZ-SC(6) 20,524.96 88.33 192.82 6,404.31 6,244.70 -5,870.88 6,460.31 5,923,899.14 1,627,787.14 2.42 3,998.78 MWD+IFR-AK-CAZ-SC(6) 20,618.45 88.65 194.20 6,406.78 6,247.17 -5,961.75 6,438.47 5,923,808.33 1,627,765.08 1.51 4,092.21 MWD+IFR-AK-CAZ-SC(6) 20,714.89 89.92 196.28 6,407.98 6,248.37 -6,054.78 6,413.13 5,923,715.37 1,627,739.50 2.53 4,188.63 MWD+IFR-AK-CAZ-SC(6) 20,808.44 90.70 196.42 6,407.47 6,247.86 -6,144.55 6,386.79 5,923,625.68 1,627,712.94 0.85 4,282.15 MWD+IFR-AK-CAZ-SC(6) 20,903.54 89.60 196.83 6,407.23 6,247.62 -6,235.67 6,359.59 5,923,534.64 1,627,685.50 1.23 4,377.21 MWD+IFR-AK-CAZ-SC(6) 20,998.04 86.24 198.56 6,410.66 6,251.05 -6,325.62 6,330.89 5,923,444.77 1,627,656.58 4.00 4,471.53 MWD+IFR-AK-CAZ-SC(6) 21,091.86 84.95 195.39 6,417.86 6,258.25 -6,415.08 6,303.58 5,923,355.39 1,627,629.05 3.64 4,565.00 MWD+IFR-AK-CAZ-SC(6) 21,186.78 86.96 193.06 6,424.56 6,264.95 -6,506.85 6,280.32 5,923,263.69 1,627,605.56 3.24 4,659.67 MWD+IFR-AK-CAZ-SC(6) 21,281.54 86.61 191.68 6,429.87 6,270.26 -6,599.26 6,260.05 5,923,171.34 1,627,585.06 1.50 4,754.18 MWD+IFR-AK-CAZ-SC(6) 21,375.71 88.45 189.16 6,433.93 6,274.32 -6,691.78 6,243.04 5,923,078.87 1,627,567.82 3.31 4,847.95 MWD+IFR-AK-CAZ-SC(6) 21,469.44 89.41 188.39 6,435.68 6,276.07 -6,784.39 6,228.74 5,922,986.30 1,627,553.29 1.31 4,941.10 MWD+IFR-AK-CAZ-SC(6) 21,564.27 89.34 187.86 6,436.72 6,277.11 -6,878.27 6,215.34 5,922,892.47 1,627,539.65 0.56 5,035.25 MWD+IFR-AK-CAZ-SC(6) 21,659.83 88.48 186.63 6,438.54 6,278.93 -6,973.04 6,203.29 5,922,797.74 1,627,527.36 1.57 5,129.91 MWD+IFR-AK-CAZ-SC(6) 21,720.00 88.48 186.63 6,440.13 6,280.52 -7,032.79 6,196.35 5,922,738.01 1,627,520.27 0.00 5,189.42 PROJECTED to TD 1/18/2016 4:42:19PM Page 8 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. E Yes ❑ ND !have checked to the best of my ability that the following data is correct: H Surface Coordinates 7 Declination & Convergence GRS Survey Corrections ❑ SurveyTool Codes Vincent Dtccn-ncern Osara � on:��-vnc<ntthara Srr,, rse,, a:-501urroergcr Asara ema• ail-vosalnbco�n,c-US SLB DE: carr "E16:>342 0900 Client Representative: Jake Voss ��:� ,..�a. rt... Date: 19-Jan-2016 • 21 5203 26973 RECEIVED ConocoPhillips MAR 2 4 2016 AOGCC TRANSMITTAL DATA LOGGED 3 /24/201G M K BENDER FROM: Sandra D. Lemke,AT014-1412 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC R.O. Box 100360 Anchorage Pouch Mail Anchorage AK 99510-0360 RE: 2S-01 DATE: 02/11/2016 Transmitted: kuparuk River Unit, Alaska 12S-01 11 CD of final report w/log images and 1 color hardcopv print each Ioq Halliburton Surface Data Logging-End of well report for 2S-01; 01/17/2016; ;general information,daily summary, 11 l days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one 11 I;set each for wellbore. ( *no lithology-mud loggers did not catch samples. Formation Evaluation log-CVE gas extraction-MD 1Gas ratio-CVE gas extraction-MD Qriiling Engineering Log-CVE gas extraction-MD 1CD contains Final log files, End of welt report,final LAS exports, log viewers i 11 1Please promptly sign, scan and return electronically to Sandra.D.Lemke(c)COP.com It 1 CC: 2S-01 transmittal folder, production well files,eSearch Receipt. _, ,.�_ „oh, te: GIS-Technical Data Management I ConocoPhlllips(Anchorage, Alaska LPh;907.265.6947 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil R' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.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.,Sus or LL 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 1//2016 215-203/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 12/16/2016 4 50-103-20727-00-00 0,4.1 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3012' FNL, 1261'FEL, Sec 17,T1ON, R8E, UM 1/14/2016KRU 2S-01 Top of Productive Interval: 9. Ref Elevations: KB: 159.(.I '-'' 17. Field/Pool(s): 1905.4 FNL,3535.45 FEL, Sec 15,T1ON, R8E, UM GL: 120 BF: Kuparuk River Field/Kuparuk River Oil Pool , Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4767'FNL, 366 FEL,Sec 21,T1ON, R8E, UM n/a ADL 25604,25603,25589 4b. Location of Well(State Base Plane Coordinates, NAD 27): LL 11.Total Depth MD/TVD: 19. Land Use Permit: • Surface: x- 540441 g8t309 y y- §984$z^e 593003(P Zone- 4 21,720'/6440' 2677, 2678 TPI: x- 489593.82 y- 5931126.62 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 487487 y- 5922989 Zone- 4 none 1470/1457 5. Directional or Inclination Survey: Yes RI (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) I n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessaryr, tAxam ,q erou 4r_., FEB 2 2 2016 GR/Res/Neu./ '1 ,/htd4y6AAL 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 38 118 38 118 24 Preinstalled cement to surface 10.75 45.5 L-80 40 2952 40 2603 13.5 417.2 bbls Lead DeepCrete' 64.9 bbl of 12 ppg Tail Deep Crete 7.625 29.7 L-80 39 12575 39 6206 9.875 Stage 1: 142.5 bbl 15.8 ppg GasBlok,Stage 2: 58.6 bbls 15.5 ppg GasBlok 4.5 12.6 L-80 12388 20446 6166 6403 6.75 n/a 24.Open to production or injection? Yes 0 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 12,449' 12388/6166, 12303/6145 FRAC PORTS @ 13400 MD,6351 TVD-19718 MD,6397 TVD FRAC SLEEVE @ 20357 MD,6402 TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETiuw Was hydraulic fracturing used during completion? Yes❑ No 2 DATE Per 20 AAC 25.283(i)(2)attach electronic and printed information k12a « DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED LL 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 yr L 4/z?//‘, , 9j "` %%%"'TINUED ON PAGE 2 RBDMS FEB1-L- 2 3 1016ubmit ORIGINIAL or})'Igv , ?IQ 111)-711C /V • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 7 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1470 1457 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 13267 6178 information, including reports, per 20 AAC 25.071. West Sak Sand 1914 1867 West Sak Base 2855 2552 C-80 3924 2975 C-37 9485 4916 Top HRZ 11727 5946 Top Kalubik 12164 6103 Kuparuk C 12925 6288 Kuparuk B 12945 6293 Kuparuk A5 12989 6303 Kuparuk A4 13267 6338 Kuparuk A5 20788 6406 Kuparuk A4 21091 6417 TD(Kuparuk A4) 21720 6439 Formation at total depth: Kuparuk A4 31. List of Attachments: Summary of Daily Operations, Definitive Survey,Cement Report,Schematic Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, Paleontological report production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true nd correct to the best of my knowledge. Contact: Jake Voss @ 265-6935 /tEmail: jake.voss(o,cop.com Printed Name: G.L.Alvord// Title: Alaska Drilling Engineer Signature: /C,• � Phone: 265-6120 Date: 4(2-2—(2016 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only KUP PROD 2S-01 conocoPhiHH1ps 4 Well Attribu Max Angll TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status ncl CI MD(ft Act Btm(ftKB) CoMMAtllkps' 501032072700 KUPARUK RIVER UNIT PROD 92.13 16,461.60 21,720.0 AY.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 25-01,2/17/201622301 PM SSSV: NONE Last WO: 39.61 1/29/2016 Varlmal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,369 ,i Last Tag: Rev Reason: NEW WELL lehallf 2/15/2016 Easing Strings OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len g...Grade Top Thread [ 1 I] CONDUCTOR 16 15.250 38.5 118.5 118.5 62.58 B Welded Can Description OD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 40.4 2,951.7 2,603.0 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND[..Wt/Len(I...Grade Top Thread XO REDUCING;81.0 • ir INTERMEDIATE 7 5/8 6.875 39.0 12,574.6 6,206.3 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len 0...-Grade Top Thread -tib CONDUCTOR;38.&118.5- PRODUCTION LINER 4 1/2 3.958 12,388.0 20,446.1 6,402.6 12.60 L-80 IBT-m Liner Details GAS LIFT;2,7700 Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top lentil Item Des Com (in) i 12,388.0 6,166.2 76.52 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.970 packer L-80 Hyd 521 pin SURFACE,40 4-0951 7-41 12,412.7. 6,171.9 76.87 NIPPLE Baker5.5""RS"Packoff Seal Nipple 17#L-80 4240 Hyd 563 box x box 12,415.1 6,172.5 76.91 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger L-80 4.800 lar Hyd 563 pin x pin GAS LIFT,5,987.0 12,424.9 6,174.7 77.05 XO Reducing 5.5"Hyd 563 15.5#box x 5"15#H521 pin Crossover 4.420 • Coupling 12,436.2 6,177.2 77.21 SBE Seal Bore Extension 80-40 5"H521 x 4%"H521 box 4.000 ari GAS LIFT;10,715.1MI 13,087.3 6,320.8 82.04 Swell Packer Baker-"Swell Packer"-"A",Water activated 3.958' Mt (922/834)SN:050011-001-9 AK 13,400.3 6,350.7 84.63'FRAC PORT Baker 4-1/2"Frac Sleeve#10-(2.625"Ball,Drift ID 2.573 GAS LIFT;12,194.6 2.563")PN:10437088 14,001.3 6,357.3 89.91 FRAC PORT Baker 4-1/2"Frac Sleeve#9-2.563"Ball,Drift w/ 2.510 • 2.50"PN:10437087 SLEEVE;12,253.8 14,965.7 6,376.7 87.02 FRAC PORT Baker 4-1/2"Frac Sleeve#8-(2.5"Ball,Drift w/ 2.448 GAUGE;12,278.3 w-I 2.438")PN:10437086 00 Threads,12,303.1 IR 15,563.0 6,379.8 89.63 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(2.438"Ball,Drift wl 2.385 PACKER;12,303.5 [ I 2.375")PN:10437085 00 Threads;12,3102 16,492.8 6,374.5 91.97 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(2.375"Ball,Drift wl 2.323 2.313")PN:10437084 jii 17,134.8 6,372.6 89.00 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(2.313"Ball,Drift wl 2260 2.25")PN:10437083 IIIII LOCATOR;10383.4 a! 17,775.6 6,385.2 87.62 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(2.25"Ball,Drift w/ 2.198 LOCATOR;12,384.4 ! 2.188")PN:10437082 I._ I18,407.5 6,393.7 89.10 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.188"Ball,Drift w/ 2.135 2.125")PN:10437081 ii 19,046.5 6,393.3 89.30 FRAC PORT Baker 4-1/2"Frac Sleeve#2-(2.125"Ball,Drift wl 2.073 I 2.063")PN:10437070 19,717.9 6,397.2 89.50 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.063"Ball,Drift w/ 2.010 Ill 2.00")PN:H810-090416 a1; 1m Ilk II 20,357.0 6,401.5 89.31 Frac Sleeve Baker 4-1/2"Alpha Sleeve PN 10487898 3.020 SHOE:12,448.0 20,370.5 6,401.6 89.31 SLEEVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN 3.958 o1 10488946 1 ' I 20,411.7 6,402.1 89.30 COLLAR 4-1/2"Weatherford Model 402E Float collar 3.958 Tubing Strings INTERMEDIATE,39.0-12,574.6 Tubing Description Stung Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(Ibtft) Grade Top Connection TUBING 31/2 2.992 36.9 12,449.0 6,180.0 9.30 L-80 EUE 8rd-M Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I 1 36.9 36.9 0.15 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 81.0 81.0 0.33 XO XO,4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 EUE- 3.000 I REDUCING Mod pin 1 12,253.9 6,131.1 73.09 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.810 2.812"profile 12,278.3 6,138.1 73.72 GAUGE Schlumberger Gauge Carrier 3-1/2"EUE P X P 2.913 (measured w/collar on top) 12,303.5 6,145.0 74.36 PACKER Baker Premier Production Packer 2.890 I 12,330.0 6,152.0 75.05 NIPPLE Camco 2.75 D nipple 4.5"OD 2.750 ol 12,383.4 6,165.2 76.43 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.020 ® Large OD MCI 12,384.5 6,165.4 76.46 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 2.990 small OD lb 711 12,448.0 6,179.8 77.38 SHOE Mule shoe WLEG 2.992 l;x�a Mandrel Inserts MIMI St ati EMU on N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) - (psi) Run Date Com 1 2,770.0 2,504.2 Camco KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 1/28/2016 2 5,987.0 3,692.7 Camco KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 1/28/2016 3 10,715.1 5,489.4 Camco KBMG - 1 GAS LIFT .DMY _BK-2 0.000 0.0 1/28/2016 4 12,194.6 6,113.1 Camco KBMG 1 GAS LIFT DMY BEK-2 0.000 0.0 2/1/2016 tIx 1 7 PRODUCTION LINER;12,388.0 -20,446.1' - !perations Summary (with Timelog Depths) 0 0 2S-01 Ccano x hillhps Rig: DOYON 25 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) 12/12/2015 12/12/2015 4.00 MIRU MOVE MOB P Lower derrick&separate modules for 0.0 0.0 00:00 04:00 moving rig from 1C-pad to 2S-pad. 12/12/2015 12/12/2015 6.00 MIRU MOVE RGRP T Hydraulic pump on pit module moving 0.0 0.0 04:00 10:00 system failed-troubleshoot and repair.Continue separating modules and preparing for rig move where possible. 12/12/2015 12/12/2015 5.50 MIRU MOVE MOB P Separate pit module&prepare sub 0.0 0.0 10:00 15:30 structure for moving to 2S-pad 12/12/2015 12/12/2015 2.50 MIRU MOVE MOB P Move casing shed module and sub- 0.0 0.0 15:30 18:00 structure from 1C-pad to 1A-pad 12/12/2015 12/12/2015 1.00 MIRU MOVE WAIT P Wait for field change outs. 0.0 0.0 18:00 19:00 12/12/2015 12/12/2015 3.50 MIRU MOVE MOB P Move casing shed module and sub- 0.0 0.0 19:00 22:30 structure from 1A-pad to 2M-pad. 12/12/2015 12/13/2015 1.50 MIRU MOVE MOB P Move casing module from 2M-pad to 0.0 0.0 22:30 00:00 2S-pad,staging sub-strucutre at 2M- pad. 12/13/2015 12/13/2015 0.50 MIRU MOVE MOB P Spot casing module on 2S-pad 0.0 0.0 00:00 00:30 12/13/2015 12/13/2015 2.50 MIRU MOVE MOB P Move sub-structure from 2M-pad to 2S 0.0 0.0 00:30 03:00 -pad. 12/13/2015 12/13/2015 4.25 MIRU MOVE MOB P Re-locate to 1C-pad and prep pipe 0.0 0.0 03:00 07:15 shed and pit module for moving to 2S- pad. Simops-Stomp sub-structure into place @ 06:00.Lower cellar doors, install walkway grating,and begin heating cellar 12/13/2015 12/13/2015 4.75 MIRU MOVE MOB P Move pipe shed and pit module to 2M- 0.0 0.0 07:15 12:00 pad 12/13/2015 12/13/2015 3.00 MIRU MOVE MOB P Move pipe shed from 2M-pad to 2S- 0.0 0.0 12:00 15:00 pad.Stage pit module at 2M-pad and allow tires to cool. 12/13/2015 12/13/2015 2.00 MIRU MOVE MOB P Re-locate to 1C-pad and prep pump 0.0 0.0 15:00 17:00 module and power complex from moving to 2S-pad. Simops-Stomp pipe shed into place. 12/13/2015 12/13/2015 3.50 MIRU MOVE MOB P Move pump module and power 0.0 0.0 17:00 20:30 complex from 1C-pad to CPF-2. Simops-Stomp pipe shed into place, pin to sub structure,&start shimming @ 19:15 12/13/2015 12/13/2015 0.75 MIRU MOVE WAIT P Allow tires to cool and perform truck 0.0 0.0 20:30 21:15 maintenance. Simops-Continue shimming pipe shed. Page 1/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) x- - 2S-01 ConocoPhiliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(RKB) 12/13/2015 12/14/2015 2.75 MIRU MOVE MOB P Move pump module and power 0.0 0.0 21:15 00:00 complex from CPF-2 to 2M-pad.Stage power complex at 2M-pad and move pit module&pump module from 2M- pad to 2S-pad. Simops-Raise derrick @ 21:30,skid rig floor in,and stomp casing shed into place. 12/14/2015 12/14/2015 2.00 MIRU MOVE MOB P Unhook from pit complex on 2S-pad 0.0 0.0 00:00 02:00 and stomp into position. 12/14/2015 12/14/2015 1.50 MIRU MOVE MOB P Unhook from pump complex on 2S- 0.0 0.0 02:00 03:30 pad and stomp into position. Simops-begin plugging in electrical interconnects. 12/14/2015 12/14/2015 2.50 MIRU MOVE MOB P Move power complex from 2M-pad to 0.0 0.0 03:30 06:00 2S-pad,unhook,and stomp into position Simops-Continue plugging in electrical interconnects. 12/14/2015 12/14/2015 1.50 MIRU MOVE RURD P Continue plugging in electrical 0.0 0.0 06:00 07:30 interconnects.Swap over to Cat 3516 Generator power @ 07:30 hrs. 12/14/2015 12/14/2015 0.50 MIRU MOVE RURD P Finish hooking up all steam,water, 0.0 0.0 07:30 08:00 vac,&hi pressure line interconnects. 12/14/2015 12/14/2015 0.50 MIRU MOVE RURD P Spool drill line back onto drum 0.0 0.0 08:00 08:30 12/14/2015 12/14/2015 1.00 MIRU MOVE RURD P Unpin blocks and top drive.Bridle up 0.0 0.0 08:30 09:30 scoping lines. 12/14/2015 12/14/2015 0.50 MIRU MOVE RURD P Scope derrick up. 0.0 0.0 09:30 10:00 12/14/2015 12/14/2015 1.00 MIRU MOVE RURD P Bridle down scoping lines,secure in 0.0 0.0 10:00 11:00 derrick,&remove yokes. 12/14/2015 12/14/2015 1.00 MIRU MOVE RURD P Secure derrick&complete rig 0.0 0.0 11:00 12:00 acceptance checklist. RIG ACCEPTED @ 12:00 hrs 12/14/2015 12/14/2015 1.00 MIRU MOVE SEQP P Cameron service hand cut off ground 0.0 0.0 12:00 13:00 tab on conductor&energize wellhead. 12/14/2015 12/14/2015 1.00 MIRU MOVE RURD P Raise 17'surface riser to rig floor and 0.0 0.0 13:00 14:00 steam/clean flanges and ring grooves. Perform pre-spud derrick inspection. Simops-Begin installing hydraulic manifold on topdrive 12/14/2015 12/14/2015 4.50 MIRU MOVE NUND P N/U diverter system,flow line,and 0.0 0.0 14:00 18:30 kelly hose. 12/14/2015 12/14/2015 2.00 MIRU MOVE RURD P Install master bushings&5"elevators, 0.0 0.0 18:30 20:30 unload 5"DP doubles from pipe tubs, and obtain RKB and diverter line measurements. 40.41 ft RKB to top of load ring 39.57 ft RKB to ground level Page 2/51 Report Printed: 2/10/2016 Operations Summary (with Timelog 6epths) 2S-01 conocdphitl ips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Ttnte End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (EKB) End Depth(ftKB) 12/14/2015 12/15/2015 3.50 MIRU MOVE PULD P M/U and rack back 24 x stands 5"DP 0.0 0.0 20:30 00:00 with doubles from pipe shed.Tag up @ 106'MD. Note:Phase 2 conditions as of 21:30 hrs Simops-Load and strap 5"DP singles in casing shed 12/15/2015 12/15/2015 3.00 MIRU MOVE PULD P Pick up/Make up 21 stds of 5"DP 1x1. 0.0 0.0 00:00 03:00 Concurrently,load 5"DP into casing shed. 12/15/2015 12/15/2015 1.00 MIRU MOVE RURD P Remove master bushings and install 0.0 0.0 03:00 04:00 bell niple and PS-21 slip inserts. 12/15/2015 12/15/2015 4.00 MIRU MOVE PULD P Pick up/Make up 27 stds of 5"1x1. 0.0 0.0 04:00 08:00 Concurrently,load Schlumberger tools into casing shed. 12/15/2015 12/15/2015 1.50 MIRU - MOVE RURD P Change out 4-1/2"IF save sub. 0.0 0.0 08:00 09:30 Concurrently,load 18jts 5"HWDP into pipe shed. 12/15/2015 12/15/2015 1.50 MIRU MOVE PULD P Pick up/Make up 6 stds 5"HWDP 1x1 0.0 0.0 09:30 11:00 12/15/2015 12/15/2015 0.50 MIRU MOVE SFTY P Hold table top rig evacuation drill with 0.0 0.0 11:00 11:30 rig crew,CPAI Rep,and 2S SIMOPS Coordinator. Discuss roles and responsibilities with crew. Discuss congested pad and identified primary and secondary muster locations. 12/15/2015 12/15/2015 0.50 MIRU MOVE RURD P Expedite surface BHA to rig floor. 0.0 0.0 11:30 12:00 Change out PS-21 with master bushings. 12/15/2015 12/15/2015 0.50 MIRU MOVE SFTY P Hold pre-spud and table top rig 0.0 0.0 12:00 12:30 evacuation drill with new rig crew and CPAI Rep. 12/15/2015 12/15/2015 0.50 MIRU MOVE RURD P Secure 4"Dump valves on conductor 0.0 0.0 12:30 13:00 Concurrently,troubleshoot TOTCO system 12/15/2015 12/15/2015 2.00 MIRU MOVE NUND P Energize Koomey and function test 0.0 0.0 13:00 15:00 annular and knife valve,take on mud to pits,continue to offload drillpipe and rig equipment from trucks. Concurrently,troubleshoot TOTCO system. 12/15/2015 12/15/2015 1.00 MIRU MOVE SVRG P Raise,shim and level casing shed. 0.0 0.0 15:00 16:00 Concurrently,troubleshoot TOTCO system. 12/15/2015 12/15/2015 2.25 MIRU MOVE OTHR P Load,strap and tally 5"drill pipe to 0.0 0.0 16:00 18:15 shed.Pick up and install PS-21 slips. Concurrently,troubleshoot TOTCO system. Page 3/51 Report Printed: 2/10/2016 Operations Summary (with Timelogepths) ort 2S-01 Conoco Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time L©g Start Depth Start Time ?' End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 12/15/2015 12/15/2015 4.50 MIRU MOVE PULD P Pick up/Make up 28 stds 5"drill pipe 0.0 0.0 18:15 22:45 lx with singles from shed. Concurrently,troubleshoot TOTCO system. 12/15/2015 12/16/2015 1.25 MIRU MOVE SLPC P Cut off 80'drilling line,slip on same, 0.0 0.0 22:45 00:00 serice and inspect top drive,calibrate amphion block height. Concurrently,troubleshoot TOTCO system and begin loading 10-3/4" casing into shed. 12/16/2015 12/16/2015 1.00 MIRU MOVE SLPC P Clean and clear tools from slip and 0.0 0.0 00:00 01:00 cut. 12/16/2015 12/16/2015 0.50 MIRU MOVE SVRG P Service crown and inspect top drive. 0.0 0.0 01:00 01:30 12/16/2015 12/16/2015 1.50 MIRU MOVE OTHR P Load 10-3/4"45.5#L-80,Hydril 563 0.0 0.0 01:30 03:00 surface casing into casing shed. Concurrently,trouble shoot TOTCO system. 12/16/2015 12/16/2015 1.00 MIRU MOVE BOPE P Conduct diverter drill and Koomy 0.0 0.0 03:00 04:00 drawdown.AOGCC Witness waived by Bob Noble. Initial=3000psi, function diverter,After=2200psi. 200psi recovery with 2 electric pumps=l2sec,full recovery at 51sec with 2 electric and 2 air pumps,6 bottle average=1908psi. Annular closing time=28sec. Knife valve opening time=1lsec. " 12/16/2015 12/16/2015 1.00 MIRU MOVE SEQP P Prime mud pumps and test surface 0.0 0.0 04:00 05:00 lines with water to 3500psi(Good test). Blow down top drive. 12/16/2015 12/16/2015 7.00 MIRU MOVE RGRP T Trouble shoot TOTCO system. 0.0 0.0 05:00 12:00 Concurrently,continue to process 10- 3/4"45.5#L-80, Hydril 563 surface casing.Work on housekeeping and preventative maintenance." 12/16/2015 12/16/2015 4.00 MIRU MOVE RGRP T Trouble shoot TOTCO system 0.0 0.0 12:00 16:00 Concurrently,continue to process 10- 3/4"45.5#L-80,Hydril 563 surface casing.Work on housekeeping and expedite mud products to pits. 12/16/2015 12/16/2015 1.50 MIRU MOVE RGRP T Trouble shoot TOTCO system 0.0 90.0 16:00 17:30 Concurrently,make up 13-1/2"surface BHA to 90'MD.Orient UBHO and scribe. 12/16/2015 12/16/2015 2.00 MIRU MOVE RGRP T Change out QUADCO drawworks 90.0 90.0 17:30 19:30 encoder and calibrate TOTCO block height,function test TOTCO mud pump stroke counters and pressure guages. TOTCO fully operational. 12/16/2015 12/16/2015 0.50 MIRU MOVE RURD P Pick up/Rig up Gyro sheaves and 90.0 90.0 19:30 20:00 equipment Page 4/51 Report Printed: 2/10/2016 Aerations Summary (with Timelog 6epths) 0 2S-01 ConocoYhiEr� Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 12/16/2015 12/16/2015 0.75 MIRU MOVE SEQP P Make up 5"HWDP and RIH tagging 90.0 106.0 20:00 20:45 @ 106'MD.Flush and fill surface equipment nd conductor with H2O. Check surface equipment for leaks, shallow pulse test MWD @ 400 GPM, 285psi,42%flow out. 12/16/2015 12/16/2015 0.25 MIRU MOVE REAM P Wash and ream from 106'MD to 118' 106.0 118.0 20:45 21:00 MD @ 400 GPM,285psi,42%flow out,40 RPM, 1k TQ,and 1k WOB. 12/16/2015 12/16/2015 0.75 MIRU MOVE SFTY P Pre-spud meeting with CPAI,Mud 118.0 118.0 21:00 21:45 Engineer,Truck Pusher, Schlumberger MWD/LWD/DD and Gyro hands. 12/16/2015 12/16/2015 1.25 SURFAC DRILL DDRL P Drill 13-1/2"surface hole and gyro 118.0 222.0 21:45 23:00 from 118'MD to 222'MD/TVD with 450 GPM,580psi,41%flow out,40 RPM,3k TQ, 18k WOB,2opsi for Off bottom pressure. P/U=59k,S/O=64k,Rot=63k, 1k TQ ART/ADT/Total Bit hours=0.77 Total Jar Hours=41.37 12/16/2015 12/17/2015 1.00 SURFAC DRILL BHAH P POOH from 222'MD to 86'MD,blow 222.0 190.0 23:00 00:00 down Top Drive,lay down X-O,Make up BHA from 86'MD to 190'MD with NMDC's,stabilizers,and 7-3/4"jars. 12/17/2015 12/17/2015 6.75 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 222' 222.0 745.0 00:00 06:45 MD to 745'MD/744'TVD with 600 GPM, 1216 psi,46%flow out,70 RPM,3k TQ,25k WOB,Off Bottom pressure 860psi. PU wt=76k,SO wt=82k,ROT wt=81 k, with 2k off bottom TQ. AST=0.83,ART=1.79,ADT=2.62 12/17/2015 12/17/2015 0.75 SURFAC DRILL WAIT T Blow down top drive.Work string from 745.0 745.0 06:45 07:30 745'MD to 719'MD while waiting on supersuckers. Upwt=91k, Dnwt=91k 12/17/2015 12/17/2015 4.50 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 745' 745.0 1,148.0 07:30 12:00 MD to 1148'MD/1132'TVD with 600 GPM, 1342 psi,46%flow out,70 RPM,4k TQ,24k WOB,Off Bottom pressure=1200psi. PU wt=99k,SO wt=99k,ROT wt=99k, with 2k off bottom TQ. AST=0.82,ART=1.79,ADT=2.61, Total bit Hrs=6.0,Total Jar Hrs=45.83 Swapped from Rig Generator Power to High Line power @ 11:15am Page 5/51 Report Printed: 2/10/2016 !perations Summary (with Timelog epths) 2S-01 CConocoPtaitlmps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time i End Time Dur(hr),, Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS) 12/17/2015 12/17/2015 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1148' 1,148.0 1,785.0 12:00 18:00 MD to 1785'MD/1752'TVD with 700 GPM, 1600 psi,48%flow out,70 RPM,5k TQ,24k WOB,Off Bottom pressure=1450psi. PU wt=112k,SO wt=102k, ROT wt=107k,with 4k off bottom TQ. AST=2.27,ART= 1.48,ADT=3.75. 12/17/2015 12/18/2015 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1785' 1,785.0 2,284.0 18:00 00:00 MD to 2284'MD/2165'TVD with 700 GPM, 1930 psi,53%flow out,80 RPM,7k TQ,27k WOB,Off Bottom pressure= 1720psi. PU wt=117k,SO wt=114k, ROT wt=115k,with 4k off bottom TQ. AST=2.26,ART= 1.47,ADT=3.73, Total bit Hrs=13.48,Total Jar Hrs=53.31 12/18/2015 12/18/2015 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2284' 2,284.0 2,731.0 00:00 06:00 MD to 2731'MD,2482'TVD with 700 GPM, 1965 PSI,50%flow out,80 RPM,5k TQ,25k WOB,Off bottom pressure=1805psi. PU wt=118k,SO wt=110k,Rot wt=110k,off bottom TQ=3k AST=2.46,ART=1.62,ADT=4.08 12/18/2015 12/18/2015 3.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2731' 2,731.0 2,960.0 06:00 09:00 MD to 2960'MD,2607'TVD with 700 GPM, 1935 PSI,53%flow out, 100 RPM,7k TQ,25k WOB,Off bottom pressure=1780psi. PU wt=115k,SO wt=110k,Rot wt=110k,off bottom TQ=5k AST=1.27,ART=0.84,ADT=2.11 12/18/2015 12/18/2015 1.25 SURFAC CASING CIRC P Rotate and reciprocate from 2690'MD 2,960.0 2,826.0 09:00 10:15 to 2826'MD with 700 GPM, 1750psi, 53%flow out, 100 RPM,5k Off bottom TQ. PU wt=115k,SO wt= 110k,Rot wt=110k,off bottom TQ=5k.Total stks pumped=9831. 12/18/2015 12/18/2015 0.25 SURFAC CASING OWFF P Observe well for flow for 10 min.(Well 2,826.0 2,826.0 10:15 10:30 Static) 12/18/2015 12/18/2015 1.50 SURFAC CASING BKRM P Backream out of hole from 2826'MD 2,826.0 2,447.0 10:30 12:00 to 2447'MD with 700 GPM, 1750psi, 53%flow out, 100 RPM,5-6k TQ Up wt=109k, Dn wt=108k 12/18/2015 12/18/2015 5.25 SURFAC CASING BKRM P Backream out of hole from 2447'MD 2,447.0 1,248.0 12:00 17:15 to 1248'MD with 600 GPM, 1100psi, 57%flow out, 100 RPM,2k TQ Up wt=99k,Dn wt=95k 12/18/2015 12/18/2015 0.25 SURFAC CASING OWFF P Blow down top drive and monitor well 1,248.0 1,248.0 17:15 17:30 for 15min(fluid dropped—2in) Page 6/51 Report Printed: 2/10/2016 =` �erations Summary (with TimelogDepths) ex .R _ 2S-01 Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/18/2015 12/18/2015 0.50 SURFAC CASING TRIP P POOH on elevators from 1248'MD to 1,248.0 812.0 17:30 18:00 812'MD, Pull 40k over @ 812'MD. Wipe and attempt to pull again with no success.Monitor hole via trip tank. Up wt=93k,Dn wt=91k 12/18/2015 12/18/2015 0.75 SURFAC CASING PMPO P Pump out of hole from 841'MD to 650' 841.0 650.0 18:00 18:45 MD with 600 GPM, 1000si,and 52% flow out. 12/18/2015 12/18/2015 0.75 SURFAC CASING TRIP P Continue to pull out hole racking back 650.0 190.0 18:45 19:30 HWDP from 650'MD to 190'MD. Monitor displacement via trip tank. 12/18/2015 12/18/2015 2.25 SURFAC CASING BHAH P Lay down BHA#1 as per Directional 190.0 0.0 19:30 21:45 Driller from 190'MD to surface. Monitor displacement via trip tank.(Bit Grade 1-2-FC-A-E-2-WT-TD) 12/18/2015 12/18/2015 0.50 SURFAC CASING BHAH P Clean and clear rig floor 0.0 0.0 21:45 22:15 12/18/2015 12/18/2015 1.50 SURFAC CASING RURD P Rig up to run 10-3/4"casing,45.5#,L- 0.0 0.0 22:15 23:45 80,Hydril 563 dopeless surface casing.Change out to 180"bails. Make up Volant casing running tool. Rig up power tongs and install elevators. 12/18/2015 12/19/2015 0.25 SURFAC CASING RURD P Drain stack,Make up 10-3/4"casing 0.0 0.0 23:45 00:00 hanger to landing joint and perform dummy run.4.25'stick-up.(40.83'to land out on load shoulder). 12/19/2015 12/19/2015 1.50 SURFAC CASING RURD P Install PS-21 power slips.Continue to 0.0 0.0 00:00 01:30 rig up for surface casing job.Hold pre- job safety meeting on running of 10- 3/4",45.5#, L-80,Hydril 563 casing. 12/19/2015 12/19/2015 1.25 SURFAC CASING PUTB P Pick up and make up 10-3/4"45.5#,L- 0.0 122.0 01:30 02:45 90,Hydril 563 shoe track and BakerLoc t 122'MD. Check floats (Good) 12/19/2015 12/19/2015 4.25 SURFAC CASING PUTB P Run 10-3/4"45.5#,L-90, Hydril 563 122.0 1,433.0 02:45 07:00 casing from 122'MD to 1433'MD. Taking 30k Down wt at 1003'MD. Wash down from 990'MD to 1190'MD at 2 BPM, 10psi. Up wt=82k, Dn wt=73k 12/19/2015 12/19/2015 0.75 SURFAC CASING PUTB T Lay down joints#35 and#36 due to 1,433.0 1,392.0 07:00 07:45 back make up.Replace with spare joints#81 and#82. 12/19/2015 12/19/2015 1.00 SURFAC CASING PUTB P Continue to run 10-3/4"45.5#,L-80, 1,392.0 1,600.0 07:45 08:45 Hydrl 563 casing from 1392'MD to 1600'MD. Up wt=110k Dn wt=102k Page 7/51 Report Printed: 2/10/2016 • a Operations Summary (with Timelog Depths) 2S-01 ConocoPhIIII4 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/19/2015 12/19/2015 0.75 SURFAC CASING CIRC P Circulate bottoms up,stage pumps up: 1,600.0 1,600.0 08:45 09:30 2 BPM=229psi,72%flow out, 3 BPM=240psi,72%flow out. 4 BPM=228psi,81%flow out. 5 BPM=210psi,84%flow out. 6 BPM=220psi,86%flow out. 7 BPM=245psi,83%flow out. 8 BPM=280psi,84%flow out. Final Circulating Pressure=260psi, 70%flow out.Total strokes pumped 2104 stks(211.9 bbls). 12/19/2015 12/19/2015 2.50 SURFAC CASING PUTB P Continue to run 10-3/4"45.5#,L-80, 1,600.0 2,785.0 09:30 12:00 Hydrl 563 casing from 1600'MD to 2785'MD. PU wt= 143k,SO wt=107k 12/19/2015 12/19/2015 0.50 SURFAC CASING PUTB P Continue to run 10-3/4"45.5#,L-80, 2,785.0 2,908.0 12:00 12:30 Hydrl 563 casing from 2785'MD to 2908'MD. PU wt=143k,SO wt=107k 12/19/2015 12/19/2015 0.50 SURFAC CASING HOSO P Make up hanger and landing joint and 2,908.0 2,951.0 12:30 13:00 wash down @ 225 GPM,310psi,46% flow out.Land on depth at 2951'MD. Pick up wt without pumps=165k, Slack off wt without pumps=124k. 12/19/2015 12/19/2015 0.25 SURFAC CEMENT RURD P Rig up cement hose and blowdown 2,951.0 2,951.0 13:00 13:15 top drive 12/19/2015 12/19/2015 4.75 SURFAC CEMENT CIRC T Circulate through cement hose while 2,950.0 2,920.0 13:15 18:00 reciprocating from 2950'MD to 2920' MD staging up to 9 BPM,460psi,6 BPM=385,7 BPM=400psi,8 BPM= 460psi. Mud wt in and out=9.7ppg, Total strokes pumped 24190(2436 bbls). PU wt= 147k,SO wt= 131k. Hold PJSM prior to beginning cement job. Page 8/51 Report Printed: 2/10/2016 •erations Summary (with Timelog epths) 2S-01 Conoco P imps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/19/2015 12/19/2015 3.50 SURFAC CEMENT CMNT P Cement surface casing while 2,920.0 2,951.0 18:00 21:30 reciprocating 30ft strokes.Pump 5bbls of CW100,Test trips and lines to 3500psi for 5 min(Good Test).Pump additional 70.6 bbls of CW100©6.6 BPM,240 psi, Batch and pump 75 bbls of 10.6ppg MPII @ 5.7 BPM,410 psi. Drop bottom plug,batch and pump 417.2 bbls of 11.0ppg Lead cement at rate of 6.7 BPM,220 psi, chase with 64.9 bbls of 12 ppg tail. Cement @ 6.6BPM,300 psi. Drop top plug and kick out with 1 Obbls of H2O. Swap to rig and displace with 9.7ppg spud mud @ 6 BPM,550psi.At 600 stks into displacement,land hanger and take returns to cellar. Reduce pump rate from 2-4.5 bpm.Reduce pump rate to 3 BPM for final 10 bbls, 380 psi @ 2664 stks bump plug with 890psi.Bleed off 2.96bb1 and check floats(holding).Cement in Place(CIP) =21:16hrs.Total cement returned from surface=152.5 bbls. Bump Plug @ 2664 stks 12/19/2015 12/20/2015 2.50 SURFAC CEMENT RURD P Blow down and rig down cement hose, 0.0 0.0 21:30 00:00 rig down volant casing running tool. Break out landing joint and lay down same.Flush surface stack with black water pill and function annular. Flush flow line with black water pill.Blow down top drive,rig down elevators and bail extensions.Remove diverter line. Rig up supersucker and clean out Joe's box. 12/20/2015 12/20/2015 0.50 SURFAC CEMENT RURD P Clear and clean floor of surface casing 0.0 0.0 00:00 00:30 equipment 12/20/2015 12/20/2015 6.00 SURFAC CEMENT NUND P Remove flow line,pull pitcher nipple, 0.0 0.0 00:30 06:30 slide joes box,Nipple down 21-1/4" surface bag,Nipple down surface riser,diverter T and diverter adaptor 12/20/2015 12/20/2015 0.50 SURFAC CEMENT CMNT P Flush 16"x 10-3/4"OA with water and 0.0 0.0 06:30 07:00 suck out same.Top off with 15 gal of cement. 12/20/2015 12/20/2015 2.00 SURFAC WHDBOP NUND P Nipple up Cameron 11"5m MBS 0.0 0.0 07:00 09:00 Wellhead. Concurrently,change out Blind rams operator,remove dutch riser flange, spot MPD Mud Flo cross on BOP annular. 12/20/2015 12/20/2015 2.50 SURFAC WHDBOP MPDA P Install and torque MPD mud flow cross 0.0 0.0 09:00 11:30 on BOP annular. 12/20/2015 12/20/2015 0.50 SURFAC WHDBOP NUND P Nipple Up Adaptor spool to Cameron 0.0 0.0 11:30 12:00 Wellhead. 11"5m x 13-5/8"5m Page 9/51 Report Printed: 2/10/2016 4.1 Operations Summary (with Timelog Ipths) 0 2S-01 aPhitlhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/20/2015 12/20/2015 5.50 SURFAC WHDBOP NUND P Nipple up BOPe,inspect all BOPE 0.0 0.0 12:00 17:30 rams and elements.Install spools and riser,install Joes Box,Make up choke and kill lines. Install flow line.Pick up MPD tools and equipment.Install trip nipple, Concurrently, inspect mud pumps and cuttings tank line valves." 12/20/2015 12/20/2015 6.00 SURFAC WHDBOP MPDA P Install e-Balance MPD system. Install 0.0 0.0 17:30 23:30 air valve,install 4""and 2""High pressure hoses. Connect electrical and hydraulic lines. Instal Katch-Kan and drain lines. Concurrently,change bails,install elevators,Make up Test Plug and set same.Rig up to test BOPE,inspect saver sub and gripper assembly." 12/20/2015 12/21/2015 0.50 SURFAC WHDBOP BOPE P Test BOPE;Witness of test waived by 0.0 0.0 23:30 00:00 AOGCC inspector Jeff Jones. Pressure test BOPE to 250/3,500 psi for 5 minutes to chart recorder using 5"test joint.Test annular,2-7/8x5-1/2" Upper and Lower pipe rams and Blind Rams. Manual operated and super choke tested to 250/2,000 psi for 5 minutes to chart recorder. Test choke valves 1-15,manual&auto choke, choke&kill manuals,HCR valves,4" valve on kill line,5"TIW,5"dart valve, and Upper&lower IBOP. 12/21/2015 12/21/2015 4.00 SURFAC WHDBOP BODE P Continue to Test BOPE;Witness of 0.0 0.0 00:00 04:00 test waived by AOGCC inspector Jeff Jones. Pressure test BOPE to 250/3,500 psi for 5 minutes to chart recorder using 5"test joint.Test annular,2-7/8x5-1/2"Upper and Lower pipe rams and Blind Rams. Manual operated and super choke tested to 250/2,000 psi for 5 minutes to chart recorder. Test choke valves 1 -15,manual&auto choke,choke&kill manuals,HCR valves,4"valve on kill line,5"TIW,5"dart valve,and Upper &lower IBOP. Perform Koomey drawdown test. Accumulator PSI=3000 psi, Manifold=1500 psi,System pressure1550 psi after all functions on bottles.200 psi attained=21 sec with 2 electric pumps,full system pressure attained=116 sec with 2 electric and 2 air pumps.6 bottle N2 average=1916 psi.Closing times for annular=25 sec,UPR=16 sec,BSR =16 sec,LPR=16 sec,Choke HCR= 2 sec,Kill HCR=2 sec. Page 10/51 Report Printed: 2/10/2016 Operations Summary (with Timelog IPpths) if iF 2S-01 Conocaehil'liips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time - Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6).. End Depth MKS) 12/21/2015 12/21/2015 0.50 SURFAC WHDBOP MPDA P Pull MPD trip nipple and install MPD 0.0 0.0 04:00 04:30 test cap. Concurrently,top off conductor with 1.21 bbls of cement 12/21/2015 12/21/2015 0.50 SURFAC WHDBOP MPDA P Fill and body test MPD equipment to 0.0 0.0 04:30 05:00 250 low and 1500 High for 5min/5min charted.(Good Test) 12/21/2015 12/21/2015 2.00 SURFAC WHDBOP MPDA P Attempt to test MI-Swaco chokes to 0.0 0.0 05:00 07:00 250psi Low(Failed).Continue to test upstream choke valves and gut line to 250psi Low and 1500psi High for 5min/5min(Good Test). Test air actuated valve to 250psi Low and 1500psi High for 5min/5min charted (Good) 12/21/2015 12/21/2015 1.00 SURFAC WHDBOP MPDA T Disassemble MI-Swaco choke valve 0.0 0.0 07:00 08:00 #1.No abnormalties found.Greased and reassembled 12/21/2015 12/21/2015 0.50 SURFAC WHDBOP MPDA T Test MI-Swaco choke valves#1 and 0.0 0.0 08:00 08:30 #2 to 250psi Low 1500psi High for 5min/5min charted(Good Test) 12/21/2015 12/21/2015 0.50 SURFAC WHDBOP MPDA P Pull MPD test cap,install trip nipple. 0.0 0.0 08:30 09:00 12/21/2015 12/21/2015 1.75 SURFAC WHDBOP RURD P Install PS-21.Pull test plug. Install 30- 0.0 0.0 09:00 10:45 7/8"L, 10-3/4"ID wear bushing.Run in lock down screws(lower x2).Rig down 5"test joint.Blow down choke and kill lines 12/21/2015 12/21/2015 1.75 SURFAC CEMENT PULD P PJSM,Run in hole to 758'picking up 0.0 758.0 10:45 12:30 doubles from shed. Monitoring displacement via trip tank. 12/21/2015 12/21/2015 0.50 SURFAC CEMENT TRIP P POOH racking back from 758'MD. 758.0 0.0 12:30 13:00 12/21/2015 12/21/2015 0.25 SURFAC CEMENT RURD P Change out PS-21 slip inserts, 0.0 0.0 13:00 13:15 mobilize BHA from shed 12/21/2015 12/21/2015 2.00 SURFAC CEMENT BHAH P PJSM.Pick up BHA#2 as per DD to 0.0 171.0 13:15 15:15 171'MD.Install source.Monitor displacement via trip tank. 12/21/2015 12/21/2015 0.50 SURFAC CEMENT TRIP P Run in hole with HWDP and Jars from 171.0 732.0 15:15 15:45 171'MD to 732'MD while monitoring displacment via trip tank. 12/21/2015 12/21/2015 3.00 SURFAC CEMENT PULD P Run in hole with doubles from 732'MD 732.0 2,812.0 15:45 18:45 to 2812'MD while monitoring displacment via trip tank. 12/21/2015 12/21/2015 1.50 SURFAC CEMENT CIRC P Circulate while rotating and 2,812.0 2,812.0 18:45 20:15 reciprocating from 2812'MD to 2723' MD with 550 GPM, 1420psi,36%flow out,40 RPM,5k TQ. Total stks pumped 8726.MWin and out 9.6ppg. 12/21/2015 12/21/2015 1.25 SURFAC CEMENT PRTS P Rig up and test casing to 3500psi for 2,812.0 2,812.0 20:15 21:30 30 min charted(Good Test).37stks to pressure up,3.2 bbl bleed back.Rig down and blow down test equipment. Page 11/51 Report Printed: 2/10/2016 Operations Summary (with Timelog�pths) 0ex 2S-01 ConocoPhil liips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 12/21/2015 12/21/2015 0.50 SURFAC CEMENT MPDA P Pick up stand and stab bearing and 2,812.0 2,812.0 21:30 22:00 rack back stand. Concurrently,troubleshoot WITS detection from TOTCO and MPD software. 12/21/2015 12/21/2015 0.50 SURFAC CEMENT MPDA T Troubleshoot WITS detection from 2,812.0 2,812.0 22:00 22:30 TOTCO and MPD software. Concurrently,service Top Drive. 12/21/2015 12/22/2015 1.50 SURFAC CEMENT MPDA P Install MPD bearing in RCD head. 2,812.0 2,812.0 22:30 00:00 Line up MPD manifold,test,and train on the MPD manifold with @Balance representatives. 12/22/2015 12/22/2015 1.50 SURFAC CEMENT MPDA P Continue training on the MPD 2,812.0 2,812.0 00:00 01:30 manifold with @Balance representatives. 12/22/2015 12/22/2015 1.00 SURFAC CEMENT MPDA P PJSM. Remove MPD Bearing. Blow 2,812.0 2,812.0 01:30 02:30 down top-drive. Install trip nipple. 12/22/2015 12/22/2015 2.50 SURFAC CEMENT DRLG P Wash&ream f/2812' to 2857'MD. 2,812.0 2,905.0 02:30 05:00 Drill float collar and shoe track f/ 2857'to 2905'MD @ 580 GPM, 1605 PSI,33%Flow,50 RPM,7K TQ,7K WOB,Off bottom=1581 PSI. PU= 118K,SO=107K,ROT=113K. Tag Cmt @ 2857'MD,FC @ 2866'MD. 12/22/2015 12/22/2015 0.75 SURFAC CEMENT DRLG P Reduced rate due to bad swab on 2,905.0 2,949.0 05:00 05:45 Mud Pump#2. Cont.drilling shoe track f/2905'to 2949'MD @ 440 GPM,931 PSI,27%Flow,50 RPM, 5K TQ,4K WOB,Off bottom=930 PSI. PU=118K,SO=107K,ROT= 113K. SIMOPS C/O swab&liner on Pump#2. SPR's @ 2904'MD,2570' TVD,MW=9.5 PPG. MP#1 -20/30 SPM=80/120 PSI. MP#2-20/30= 120/160 PSI 12/22/2015 12/22/2015 1.00 SURFAC CEMENT DRLG P Drill float shoe f/2949'to 2951'MD @ 2,949.0 2,951.0 05:45 06:45 580 GPM, 1589 PSI,35%Flow,50 RPM,8K TQ,5K WOB,Off bottom= 1570 PSI. PU= 118K,SO=107K, ROT=113K. 12/22/2015 12/22/2015 0.25 SURFAC CEMENT DRLG P Drill rat hole from 2951'—2960'MD. 2,951.0 2,960.0 06:45 07:00 12/22/2015 12/22/2015 0.50 SURFAC CEMENT DDRL P Drill 20'of new hole to 2980'MD @ 2,960.0 2,980.0 07:00 07:30 582 GPM, 1559 PSI,33%Flow,50 RPM,8K TQ, 10K WOB, PU=114K, SO= 107K,ROT=111K. 12/22/2015 12/22/2015 2.25 SURFAC CEMENT CIRC P CBU at 582 GPM, 1573 PSI,33% 2,980.0 2,980.0 07:30 09:45 Flow. Pumped 16,793 Stks. 12/22/2015 12/22/2015 0.25 SURFAC CEMENT OWFF P Observe well for flow. Blow down top 2,980.0 2,980.0 09:45 10:00 drive 12/22/2015 12/22/2015 1.50 SURFAC CEMENT LOT P POOH to 2907'MD and conduct LOT. 2,980.0 2,907.0 10:00 11:30 Pressure to 670 PSI with 9.5 PPG mud for an EMW of 14.4 PPG. RD and blow down kill line. 12/22/2015 12/22/2015 0.50 INTRM1 DRILL SVRG P Service top drive. 2,907.0 2,907.0 11:30 12:00 Page 12/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01 Conor r Phitilps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/22/2015 12/22/2015 1.00 INTRM1 DRILL DISP P PJSM. TIH from 2907'to 2942'MD 2,907.0 2,942.0 12:00 13:00 and displace well to 9.6 PPG LSND @ 635 GPM, 1430 PSI,35%Flow,50 RPM,5.5K TQ 12/22/2015 12/22/2015 3.00 INTRM1 DRILL DDRL P TIH from 2942'-2980'MD. Drill 9- 2,942.0 3,094.0 13:00 16:00 7/8"hole f/2980—3094'MD,2672' TVD,@ 650 GPM, 1550 PSI,35% Flow,80 RPM,6.5K TQ,4.5K WOB, ECD=10.26,Off bottom=1520 PSI, PU=112K,SO=111K,ROT=112K, 6K TQ. SPR's @ 2999'MD,2626' TVD,MW=9.6 PPG. MP#1 -20/30 SPM= 120/150 PSI. MP#2-20/30= 120/140 PSI 12/22/2015 12/22/2015 0.50 INTRM1 DRILL CIRC P POOH to 3080'MD. Break connection 3,094.0 3,080.0 16:00 16:30 and drop RFID tag to open reamer Circulate down as per WFT rep.Lost 200 psi indicating blades open.Ream from 3080'to 3085'MD. PU to 3080' w/no rotary and observed 10K overpull. 12/22/2015 12/22/2015 1.50 INTRMI DRILL DDRL P Drill f/3094'to 3207'MD,2722'TVD, 3,080.0 3,207.0 16:30 18:00 @ 750 GPM, 1710 PSI,38%Flow,80 RPM,4-9K TQ,7K WOB, ECD= 10.41,Off bottom=1700 PSI,PU= 112K,SO=116K,ROT=114K,5K TQ. ADT=3.22 HRS,Total Bit HRS =3.22,Total Jar HRS=3.45 12/22/2015 12/23/2015 6.00 INTRMI DRILL DDRL P Drill f/3207'to 3756'MD,2917'TVD, 3,207.0 3,756.0 18:00 00:00 ©750 GPM, 1880 PSI,38%Flow, 150 RPM,6-8K TQ, 12K WOB, ECD =10.49,Off bottom=1850 PSI,PU= 112K,SO= 114K,ROT=113K,5K TQ. ADT=4.33 HRS,Total Bit HRS =7.55,Total Jar HRS=7.78. SPR's @ 3568'MD,2850'TVD, MW=9.6 PPG. MP#1 -20/30 SPM=140/160 PSI. MP#2-20/30=120/160 PSI. 12/23/2015 12/23/2015 6.00 INTRMI DRILL DDRL P Drill 9-7/8"X 11"Intermediate hole 3,756.0 4,227.0 00:00 06:00 with Riptide Underreamer f/3756'to 4227'MD,3077'TVD,@ 750 GPM, 2035 PSI,38%Flow, 100-150 RPM,6 -11K TQ, 10-20K WOB, ECD=10.59, Off bottom=1850 PSI,PU=115K, SO=117K, ROT=116K,5K TQ. ADT=4.62 HRS,Total Bit HRS= 12.17,Total Jar HRS= 12.40. 12/23/2015 12/23/2015 6.00 INTRM1 DRILL DDRL P Drill f/4227'to 4430'MD,3149'TVD, 4,227.0 4,430.0 06:00 12:00 @ 750 GPM,2020 PSI,38%Flow, 100-150 RPM,8K TQ, 10-20K WOB, ECD= 10.33,Off bottom=2015 PSI, PU=121K,SO=119K,ROT=117K, 6K TQ. Pumped 20#Nut Plug Sweep @ 4261'&4290'MD. ADT=4.34 HRS,Total Bit HRS=16.51,Total Jar HRS=16.71. SPR's @ 4412'MD, 3143'TVD,MW=9.6 PPG. MP#1 - 20/30 SPM=100/140 PSI. MP#2- 20/30=120/140 PSI. Loss for tour=0 BBLS Page 13/51 Report Printed: 2/10/2016 !perations Summary (with Timelog Depths) mayfoe ;, 2S-01 Commiftlitlips , Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth r: Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/23/2015 12/23/2015 6.00 INTRM1 DRILL DDRL P Drill f/4430'to 4975'MD,3339'TVD, 4,430.0 4,975.0 12:00 18:00 @ 750 GPM,2385 PSI,39%Flow, 150 RPM,9K TQ,22K WOB, ECD= 10.70,Off bottom=2350 PSI, PU= 120K,SO=115K,ROT=118K,6K TQ. Pumped 20#Nut Plug Sweep @ 4546'&4781'MD. ADT=4.85 HRS, Total Bit HRS=21.37,Total Jar HRS =21.6. 12/23/2015 12/24/2015 6.00 INTRM1 DRILL DDRL P Drill f/4975'to 5593'MD,3555'TVD, 4,975.0 5,593.0 18:00 00:00 @ 750 GPM,2600 PSI,39%Flow, 160 RPM, 10.5K TQ,24K WOB, ECD =11.01,Off bottom=2570 PSI,PU= 132K,SO= 122K,ROT=126K,8K TQ. Pumped 20#Nut Plug Sweep© 5173'MD. ADT=4.46 HRS,Total Bit HRS=25.82,Total Jar HRS=26.05. SPR's @ 4985'MD,3342'TVD, MW= 9.6 PPG. MP#1 -20/30 SPM= 160/200 PSI. MP#2-20/30= 140/200 PSI. Loss for tour=0 BBLS 12/24/2015 12/24/2015 4.00 INTRM1 DRILL DDRL P Drill f/5593'to 5975'MD,3688'TVD, 5,593.0 5,975.0 00:00 04:00 ©750 GPM,2667 PSI,39%Flow, 160 RPM, 11K TQ,25K WOB, ECD= 11.03,Off bottom=2660 PSI,PU= 147K,SO=124K, ROT= 133K,9K TQ. ADT=2.96 HRS,Total Bit HRS =28.78,Total Jar HRS=29.01. 12/24/2015 12/24/2015 8.00 INTRM1 DRILL PMPO T Observed 254 PSI pack-off while 5,975.0 4,100.0 04:00 12:00 drilling at 5975'MD. Attempt to regain returns by rotating and working pipe from 5975'to 4100'MD with 20—40K overpull. Attempt to establish circulation with 100—300 PSI trapped pressure on DP,24K TQ and 7—8 RPM. PU=147K,SO=124K, Rot= 133K. Loss for tour=0 BBLS 12/24/2015 12/24/2015 8.50 INTRM1 DRILL REAM T Continue to work tight hole. RIH from 4,100.0 4,225.0 12:00 20:30 4100'to 4291'MD with torque max'd at 25K and 3-10 RPM. Work pipe up to 4142'MD w/70K overpull,torque max'd at 25K and 1 RPM. Work back down to 4316'MD and between 4316 to 4225'MD slacking off to block wt. and PU to 110K overpull with torque max'd at 25K and 8-80 RPM. Pressure up to 350 PSI attempting to establish circulation. 12/24/2015 12/24/2015 2.00 INTRM1 DRILL PMPO T Work pipe from 4225'to 3282'MD 4,225.0 3,282.0 20:30 22:30 holding 350 PSI on drillpipe with rotary stalled at 25K TQ and 110K overpull. At 3820 MD the overpull and torque dropped off. Obtained full returns at 3570'MD w/2 BPM,240 PSI and 12%FO. Page 14/51 Report Printed: 2/10/2016 !perations Summary (with Timelog!pths) ti. 2S-01 ConocdPhillips `<' Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/24/2015 12/24/2015 0.50 INTRM1 DRILL CIRC T Drop RFID tags at 3282'MD to close 3,282.0 3,191.0 22:30 23:00 Weatherford Riptide Reamer and pump down while POOH to 3191'MD. SD pumps for 10 min to allow reamer to activate. 12/24/2015 12/24/2015 0.50 INTRM1 DRILL PMPO T Pump OOH from 3191'to 2905'into 3,191.0 2,905.0 23:00 23:30 casing @ 4 BPM,310 PSI and 23% FO. 12/24/2015 12/25/2015 0.50 INTRM1 DRILL CIRC T Circulate BU while rotating and recip f/ 2,905.0 2,805.0 23:30 00:00 2905'to 2805'MD staging up to 585 GPM, 1650 PSI,35%FO, 100 RPM and 7K TQ. 12/25/2015 12/25/2015 2.50 INTRM1 DRILL CIRC T Continue to circulate bottoms up while 2,805.0 2,805.0 00:00 02:30 rotating and reciprocating from 2905' to 2805'MD(inside of 10-3/4"casing). Pumping 585 GPM, 1580-1543 PSI, 35%FO, 100 RPM and 7K TQ.PU wt 102k,SO wt 116k,Rot wt 114k. Pumped(2)35 bbl sweeps:20ppb nut plug with 3%drillzone. Total volume pumped=2520 bbls. Initial circ pressure 1580,final 1543. Initial ECD's 10.44 ppg,final 10.13 PPO. 12/25/2015 12/25/2015 0.25 INTRM1 DRILL CIRC T Obtain slow pump rates @ 2905'MD 2,805.0 2,805.0 02:30 02:45 (2576'TVD).Mud weight 9.6 ppg.#1 mud pump:20 spm=100 psi,30 spm = 160 psi.Mud pump#2:20 spm= 100 psi,30 spm=140 psi. 12/25/2015 12/25/2015 0.25 INTRMI DRILL OWFF T Monitor well for flow-static. 2,805.0 2,805.0 02:45 03:00 12/25/2015 12/25/2015 1.50 INTRM1 DRILL BKRM T Back ream from 2805'to 1959'. 2,805.0 1,959.0 03:00 04:30 Pumping 584 gpm w/1545 psi,34% flow out.Rotating 100 rpm w/4k ft lbs of torque. 12/25/2015 12/25/2015 0.50 INTRM1 DRILL CIRC T Circulate bottoms up while rotating 1,959.0 1,860.0 04:30 05:00 and reciprocating from 1959'to 1860' MD(inside of 10-3/4"casing). Pumping 585 GPM, 1450 PSI,33% FO, 100 RPM and 3K TQ.PU wt 95k, SO wt 107k,Rot wt 106k. Total volume pumped=423.6 bbls. Blow down the top drive. 12/25/2015 12/25/2015 1.00 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 1,860.0 728.0 05:00 06:00 1860'to 728'.Monitor well on the trip tank. 12/25/2015 12/25/2015 0.25 INTRM1 DRILL OWFF T Monitor well-static. 728.0 728.0 06:00 06:15 12/25/2015 12/25/2015 1.00 INTRMI DRILL TRIP T Rack back 5"HWDP f/728'to 171'. 728.0 171.0 06:15 07:15 Clean clay off the pipe. 12/25/2015 12/25/2015 0.50 INTRM1 DRILL SFTY T Held Pre job safety meeting on 171.0 171.0 07:15 07:45 removing sources,then removed. 12/25/2015 12/25/2015 2.00 INTRM1 DRILL BHAH T Lay down BHA per Schlumberger 171.0 0.0 07:45 09:45 MWD/DD and Weatherford Ripe Tide reamer hand.Monitor well on the trip tank. 12/25/2015 12/25/2015 0.50 INTRM1 DRILL BHAH T Crew change,clean and clear floor. 0.0 0.0 09:45 10:15 12/25/2015 12/25/2015 1.75 INTRM1 DRILL BHAH T Pick up and make up Bottom hole 0.0 168.0 10:15 12:00 assembly#3 per Schlumberger DD. Monitor displacement via pit#2. Page 15/51 Report Printed: 2/10/2016 • Operations Summary (with Timelog Depths) 2S-01 Conocddhifliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 12/25/2015 12/25/2015 1.75 INTRM1 DRILL TRIP T Change out slip inserts and RIH w/ 168.0 2,715.0 12:00 13:45 HWDP to 729'MD. Continue RIH with 5"DP to 2715'MD. Filled pipe at 2000'MD. PU= 110K,SO=112K. 12/25/2015 12/25/2015 1.50 INTRM1 DRILL REAM T Ream down from 2715' to 3090'MD 2,715.0 3,090.0 13:45 15:15 @ 575 GPM, 1560 PSI,32%FO,40 RPM,4K TQ. 12/25/2015 12/25/2015 0.25 INTRM1 DRILL CIRC T Open Weatherford Riptide 3,090.0 3,090.0 15:15 15:30 Underreamer by dropping 5 RFID tags. Pump down @ 575 GPM, 1560 PSI,32%FO,40 RPM,4K TQ. At 360 strokes,reduce rate to 300 GPM. After 600 strokes,increase rate to 575 GPM and verify Riptide blades were open. PU to orig top of 11"hole and verify cutters open w/10K overpull. 12/25/2015 12/26/2015 8.50 INTRM1 DRILL REAM T Ream down from 3090'to 4840' MD 3,090.0 4,840.0 15:30 00:00 @ 750 GPM,2350 PSI,39%FO, 110 increasing to120 RPM,6-8K TQ,at 300 FPH running speed. 12/26/2015 12/26/2015 6.00 INTRM1 DRILL REAM T Ream down from 4840'to 5976' MD 4,840.0 5,976.0 00:00 06:00 @ 750 GPM,2350-2650 PSI,39% FO, 120 RPM, 13K TQ,at 300 FPH running speed.Tag bottom @ 5976'. 12/26/2015 12/26/2015 1.00 INTRM1 DRILL REAM T Re tag bottom @ 5976',pumping 750 5,976.0 5,930.0 06:00 07:00 gpm w/2650 psi,39%flow out.Rotate 120 rpm w/13k ft lbs of torque.Rack back stand#56 watching hole closely for packoff. 12/26/2015 12/26/2015 0.25 INTRMI DRILL SFTY T Pre job safety meeting on displacing 5,930.0 5,930.0 07:00 07:15 old 9.6ppg LSND mud from the hole. 12/26/2015 12/26/2015 1.50 INTRMI DRILL DISP T Displace to new 9.6 ppg LSND mud. 5,930.0 5,930.0 07:15 08:45 Reciprocate f/5930'to 5881'.Working string @ 120 fUhr.rotate 50 rpm, pumping 250 gpm w/408 psi w/21% flow out. 12/26/2015 12/26/2015 1.50 INTRM1 DRILL CIRC T Continue to circulate and reciprocate 5,930.0 5,930.0 08:45 10:15 from 5930'to 5881'.Working string @ 120 fUhr.Stage pumps up to 750 gpm w/1915 psi.Haul off old mud/bring in new mud to increase volume in the pits. 12/26/2015 12/26/2015 0.25 INTRMI DRILL CIRC T Obtain slow pump rates @ 5924'MD 5,930.0 5,976.0 10:15 10:30 (3670'TVD). Mud pump#1:20 spm w/ 150 psi,30 spm w/180 psi.Mud pump #2:20 spm w/150 psi,30 spm w/190 psi. 12/26/2015 12/26/2015 1.50 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11"hole f/ 5,976.0 6,073.0 10:30 12:00 5976' to 6073'MD(3722'TVD). Pumping 750 GPM w/1955 PSI,39% Flow out. Rotating 130 RPM w/9-10K TQ. 10K WOB, ECD= 10.49,Off bottom=1949 PSI,PU= 146K,SO= 122K,ROT=123K,8K TQ. ADT= 1.07 HRS,Total Bit HRS= 1.07,Total Jar HRS=30.08. Loss for tour=0 BBLS Page 16/51 Report Printed: 2/10/2016 eP '0 !perations Summary (with Timelogepths) h.!, 2S-01 ccPhilliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code'. Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 12/26/2015 12/26/2015 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11"hole f/ 6,073.0 6,590.0 12:00 18:00 6073' to 6590'MD(3901'TVD). Pumping 750 GPM w/2160 PSI,38% Flow out.Rotating 130 RPM w/10- 11K TQ. 12K WOB, ECD=10.61,Off bottom=2150 PSI,PU=150K,SO= 122K,ROT= 126K,8K TQ. Pump 20#Nut Plug Sweeps @ 6210'& 6495'MD. ADT=4.8 HRS,Total Bit HRS=5.97,Total Jar HRS=34.98. 12/26/2015 12/27/2015 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11"hole f/ 6,590.0 7,095.0 18:00 00:00 6590' to 7095'MD(4076'TVD). Pumping 750 GPM w/2400 PSI,39% Flow out.Rotating 150 RPM w/12K TQ. 12K WOB, ECD=10.76,Off bottom=2380 PSI,PU=165K,SO= 124K,ROT=138K, 10K TQ. Pump 20#Nut Plug Sweeps @ 6779&7065' MD. ADT=5.6 HRS,Total Bit HRS= 10.4,Total Jar HRS=40.48. Obtain slow pump rates @ 6874'MD(3999' TVD). Mud pump#1:20 spm w/200 psi,30 spm w/230 psi. Mud pump#2: 20 spm w/180 psi,30 spm w/220 psi. Loss for tour=0 BBLS 12/27/2015 12/27/2015 0.25 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11"hole f/ 7,095.0 7,138.0 00:00 00:15 7095'—7138'MD(4091'TVD). Pumping 750 GPM w/2312 PSI,39% Flow out. 150 RPM,w/12K TQ. 12K WOB, ECD=10.96,Observe 200 PSI increase in pump pressure and ECD spike. 12/27/2015 12/27/2015 3.25 INTRM1 DRILL CIRC T Reduced pump rate to 350 GPM and 7,138.0 7,138.0 00:15 03:30 pump pressure dropped from 2312 PSI to 1021 PSI with 120 RPM,8- 12K TQ,and 22%FO. Recip& Rotate and hole started to unload cuttings nearly plugging flowline. Football size chunks in bell nipple and base ball size across shakers. Circ 4 BU and finally cleaned up enough to go back to drilling @ 50 FPH,70 GPM,2512 PSI, 12K TQ and 50%FO with flowline jets running. 12/27/2015 12/27/2015 2.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 7,138.0 7,313.0 03:30 06:00 7138' to 7313'MD(4151'TVD). Pumping 750 GPM w/2487 PSI,50% Flow out. 150 RPM w/12K TQ.7K WOB, ECD= 10.79,Off bottom= 2395 PSI,PU=172K,SO=124K, ROT= 134K, 10K TQ off Bot,ADT= 2.55 HRS,Total Bit HRS=12.94, Total Jar HRS=41.95. Obtain slow pump rates @ 7152'MD(4096'TVD). Mud pump#1:20 spm w/210 psi,30 spm w/230 psi.Mud pump#2:20 spm w/210 psi,30 spm w/240 psi. Page 17/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01 Conn coPhititps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/27/2015 12/27/2015 2.50-INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 7,313.0 7,486.0 06:00 08:30 7313' to 7486'MD(4212'TVD). Pumping 750 GPM w/2500 PSI,39% Flow out. 150 RPM w/12-16K TQ. 12K WOB, ECD=10.69, 12K TQ, PU =177K,SO=118K,ROT=139K, Pump 20#Nut Plug Sweep @ 7440' MD 12/27/2015 12/27/2015 0.75 INTRM1 DRILL CIRC T Circulate BU at reduced pressures 7,486.0 7,486.0 08:30 09:15 due to gradual pump pres increase while Recip&Rotate from 7486'to 7439'MD @ 350 GPM,812 PSI,39% FO, 120 RPM, 10—12K TQ. Slowly increase rate back to 750-GPM,2536 PSI,49% FO, 120 RPM, 10—16K TQ. 12/27/2015 12/27/2015 2.75 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 7,486.0 7,660.0 09:15 12:00 7486' to 7660'MD(4274 TVD). Pumping 800 GPM w/2839 PSI,51% Flow out. 150 RPM w/14-16K TQ. 12K WOB, ECD=10.79,Off bottom= 2920 PSI,PU=201K,SO=115K, ROT=134K, 13K TQ off Bot, Pump 20#Nut Plug Sweep @ 7657'MD. ADT=3.52 HRS,Total Bit HRS= 16.46,Total Jar HRS=45.46. 12/27/2015 12/27/2015 1.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 7,660.0 7,725.0 12:00 13:00 7660' to 7725'MD(4295'TVD). Pumping 800 GPM w/2830 PSI,53% Flow out. 150 RPM w/13-18K TQ. 24K WOB, ECD=10.79,Off bottom= 2800 PSI,PU=201K,SO=115K, ROT=134K, 13K TQ off Bot, 12/27/2015 12/27/2015 1.00 INTRM1 DRILL CIRC T Circulate BU while Recip&Rotate 7,725.0 7,725.0 13:00 14:00 from 7725'to 7630'MD @ 800 GPM, 2880 PSI, 52% FO, 120 RPM, 11 — 14K TQ. Total Stks pumped= 11,643. 12/27/2015 12/27/2015 4.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 7,725.0 8,009.0 14:00 18:00 7725' to 8009'MD(4392 TVD). Pumping 800 GPM w/2995 PSI,51% Flow out. 150 RPM w/13-16K TQ. 12K WOB, ECD=10.63,Off bottom= 2950 PSI,PU=202K,SO=121K, ROT=151K, 11.5K TQ off Bot, Pump 20#Nut Plug Sweep @ 7730'MD. ADT=4.1 HRS,Total Bit HRS= 20.56,Total Jar HRS=49.56. Obtain slow pump rates @ 7910'MD(4357' TVD),9.6 PPG. Mud pump#1:20 spm w/220 psi,30 spm w/260 psi. Mud pump#2:20 spm w/220 psi,30 spm w/260 psi. Page 18/51 Report Printed: 2/10/2016 • • :,;. 0 0 I,i. Operations Summary (with Timelog Depths) k 2S-01 ConacaPhithps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) , End Depth(ftKB) 12/27/2015 12/28/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 8,009.0 8,423.0 18:00 00:00 8009'to 8423'MD(4573'TVD). Pumping 800 GPM w/3150 PSI,51% Flow out. 150 RPM w/13-15K TQ. 12K WOB, ECD=10.77,Off bottom= 3100 PSI,PU=206K,SO=121K, ROT=155K, 11K TQ off Bot, Pump 20#Nut Plug Sweep @ 8009'&8292' MD. ADT=4.42 HRS,Total Bit HRS =24.98,Total Jar HRS=53.98. 12/28/2015 12/28/2015 3.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 8,423.0 8,670.0 00:00 03:30 8423' to 8670'MD(4623'TVD). Pumping 800 GPM w/3325 PSI,41% Flow out. 150 RPM w/13-16K TQ.6- 10K WOB, ECD=10.83,Off bottom= 3241 PSI,PU=205K,SO=123K, ROT=157K, 12K TQ off Bot,ADT= 2.77 HRS,Total Bit HRS=27.88, Total Jar HRS=56.89. Obtain slow pump rates @ 8477'MD(4556'TVD). Mud pump#1:20 spm w/260 psi,30 spm w/300 psi.Mud pump#2:20 spm w/260 psi,30 spm w/300 psi. 12/28/2015 12/28/2015 1.00 INTRM1 DRILL CIRC P Pump 50 gal,20#Nut Plug Sweep 8,670.0 8,670.0 03:30 04:30 followed by 520 BBLS of new 9.6 PPG mud while recip&rotation f/8670'to 8575'MD @ 600 GPM, 1930 PSI, 100 RPM, 13-15K TQ,35%FO. 12/28/2015 12/28/2015 1.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 8,670.0 8,748.0 04:30 06:00 8670'to 8748'MD(4653'TVD). Pumping 800 GPM w/2789 PSI,39% Flow out. 150 RPM w/12-14K TQ.8K WOB, ECD=10.68,Off bottom= 3080 PSI,PU=204K,SO=124K, ROT=148K, 12K TQ off Bot,ADT =.5 HRS,Total Bit HRS=28.38,Total Jar HRS=57.39. 12/28/2015 12/28/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 8,748.0 9,202.0 06:00 12:00 8748'to 9202'MD(4810'TVD). Pumping 800 GPM w/3125 PSI,39% Flow out. 150 RPM w/13-16K TQ. 10K WOB, ECD=10.74,Off bottom= 3138 PSI,PU=207K,SO=123K, ROT=156K, 15K TQ off Bot,ADT= 4.55 HRS,Total Bit HRS=32.93, Total Jar HRS=61.94. Pump 20#Nut Plug Sweep @ 8860'&9136'MD. Obtain slow pump rates @ 8761'MD (4654'TVD).Mud pump#1:20 spm w/ 250 psi,30 spm w/290 psi.Mud pump #2:20 spm w/250 psi,30 spm w/290 psi. 12/28/2015 12/28/2015 1.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 9,202.0 9,333.0 12:00 13:30 9202'-9333'MD(4859'TVD). Pumping 800 GPM w/3260 PSI,39%Flow out. 130 RPM w/13-17K TQ. 10K WOB, ECD=10.77,Off bottom=3230 PSI, PU= 198K,SO=125K,ROT=145K, 15K TQ off Bot,ADT=1.50 HRS, Total Bit HRS=34.43,Total Jar HRS =63.44. Page 19/51 Report Printed: 2/10/2016 p Summaryerations (with Timelog Depths) • • 2S-01 ConoceoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/28/2015 12/28/2015 1.50 INTRM1 DRILL CIRC P Circ BU prior to installing MPD bearing 9,333.0 9,333.0 13:30 15:00 while recip&rotation(/9333'—9420' MD @ 800 GPM,3230 PSI,39%FO, 120 RPM, 10-17K TQ, 10.62 ECD 12/28/2015 12/28/2015 0.75 INTRM1 DRILL MPDA P Pull trip nipple and install MPD 9,333.0 9,333.0 15:00 15:45 Bearing. Obtain slow pump rates thru MPD skid @ 9331'MD(4858'TVD). Mud pump#1:20 spm w/250 psi,30 spm w/310 psi.Mud pump#2:20 spm w/250 psi,30 spm w/300 psi. 12/28/2015 12/28/2015 2.25 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 9,333.0 9,530.0 15:45 18:00 9333'—9530'MD(4933'TVD). Pumping 800 GPM w/3375 PSI,34% Flow out. 130 RPM w/13-17K TQ. 18K WOB, ECD=10.96,Off bottom= 3350 PSI, PU=199K,SO=133K, ROT=154K, 13K TQ off Bot,ADT= 1.62 HRS,Total Bit HRS=36.05, Total Jar HRS=65.06. Pump 20#Nut Plug Sweep @ 9427'MD. 12/28/2015 12/28/2015 4.25 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 9,530.0 9,870.0 18:00 22:15 9530'-9870 MD(5080'TVD). Pumping 800 GPM w/3295 PSI,51% Flow out. 130 RPM w/13-17K TQ. 12K WOB, ECD=10.89,Off bottom= 3250 PSI. Pump 20#Nut Plug Sweep @ 9710'MD. 12/28/2015 12/28/2015 0.75 INTRM1 DRILL RGRP T Circ BU while C/O swab and liner on 9,870.0 9,870.0 22:15 23:00 #2 Mud Pum @ 400 GPM, 1060 PSI, 41%F0,50 RPM, 14K TQ, 12/28/2015 12/29/2015 1.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole 9,870.0 9,899.0 23:00 00:00 (/9870'—9899' MD(5093'TVD). Pumping 800 GPM w/3315 PSI,51% Flow out. 130 RPM w/15K TQ.7K WOB, ECD= 10.73,Off bottom= 3300 PSI,PU=193K,SO= 132K, ROT= 153K, 12K TQ off Bot,ADT= 3.37 HRS,Total Bit HRS=39.42, Total Jar HRS=68.43. 12/29/2015 12/29/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole 9,899.0 10,372.0 00:00 06:00 f/9899'—10372' MD(5321'TVD). Pumping 800 GPM w/3378 PSI,41% Flow out. 130 RPM w/16-19K TQ. 12K WOB, ECD=10.79,Off bottom= 3351 PSI,PU=200K,SO=145K, ROT= 174K, 13K TQ off Bot,ADT= 4.05 HRS,Total Bit HRS=43.47, Total Jar HRS=72.48. Obtain slow pump rates @ 9991'MD(5137'TVD). Mud pump#1:20 spm w/220 psi,30 spm w/270 psi.Mud pump#2:20 spm w/220 psi,30 spm w/270 psi. Page 20/51 Report Printed: 2/10/2016 • 0 !perations Summary (with Timelog Depths) 2S-01 moo. o hinips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time' End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE) 12/29/2015 12/29/2015 5.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole 10,372.0 10,690.0 06:00 11:30 f110372'—10690' MD(5479'TVD). Pumping 800 GPM w/3394 PSI,41% Flow out. 130 RPM w/13-17K TQ.8K WOB, ECD=10.90,Off bottom= 3312 PSI, PU=217K,SO=143K, ROT=172K, 13K TQ off Bot,ADT= 3.30 HRS,Total Bit HRS=46.77, Total Jar HRS=75.78.Obtain slow pump rates @ 10654'MD(51375456' TVD). Mud pump#1:20 spm w/230 psi,30 spm w/280 psi. Mud pump#2: 20 spm w/220 psi,30 spm w/270 psi. Observe 400 psi pressure drop gradually from 10500'-10690'MD with corresponding reduction in MWD turbine speed. 12/29/2015 12/29/2015 0.50 INTRM1 DRILL SEQP T Inspect all surface equipment with no 10,690.0 10,690.0 11:30 12:00 findings.Trap 200 psi on annulus below MPD bearing and bleed down DP. Observe instantaneous communication between annulus and DP. Decision made to pump out of hole looking for washout. 12/29/2015 12/29/2015 1.25 INTRM1 DRILL TRIP T POOH looking for washout from 10,690.0 9,612.0 12:00 13:15 10690'-9612'MD w/2 BPM andd 100 PSI. 12/29/2015 12/29/2015 0.75 INTRM1 DRILL CIRC T Close Weatherford Riptide 9,612.0 9,612.0 13:15 14:00 Underreamer at 9612'MD by dropping 5 RFID tags and pump down at 600 GPM, 1720 PSI,30%FO. Reduce rate at 1300 stks to 300 GPM,. After 1800 Stks,shut down pump f/10 min. Stage rate up to 600 GPM and observe no change in parameters indicating Riptide activation. RFID tags may have circulated out of leak in DP. 12/29/2015 12/29/2015 2.50 INTRM1 DRILL TRIP T Continue to Pump OOH looking for 9,612.0 6,840.0 14:00 16:30 washout f/9612'-6840'MD @ 3 BPM and 120 PSI. Observe washout on middle single of stand#65 on slip area. 12/29/2015 12/29/2015 0.75 INTRM1 DRILL PULD T Lay down bad joint and pump at 750 6,840.0 6,840.0 16:30 17:15 GPM,2840 PSI to verify no additional leaks. PU replacement joint and blow down top drive prior to RIH. 12/29/2015 12/29/2015 2.25 INTRM1 DRILL TRIP T RIH on elevators from 6840'-10475' 6,840.0 10,475.0 17:15 19:30 MD. PU=210K,SO=123K 12/29/2015 12/29/2015 1.75 INTRM1 DRILL CIRC T Wash and ream to 10655'MD. 10,475.0 10,655.0 19:30 21:15 Circulate out dehydrated mud and cuttings from until evened out at 9.7 PPG. 12/29/2015 12/29/2015 0.50 INTRM1 DRILL CIRC T Open Weatherford Riptide 10,655.0 10,655.0 21:15 21:45 Underreamer at 10655'MD by dropping 5 RFID tags and pump down at 600 GPM,2530 PSI,43%FO. Reduce rate at 1300 stks to 300 GPM. After 1800 Stks,increase rate to 600 GPM to confirm activation. Page 21/51 Report Printed: 2/10/2016 0 •' POperations Summary (with Timelog Depths) 2S-01 Conocohillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/29/2015 12/29/2015 0.50 INTRM1 DRILL CIRC T Circulate while recip&rotate f/10690 10,655.0 10,690.0 21:45 22:15 -10653'MD at 450 GPM, 1450 PSI to even mud out. MW in=9.7 PPG,Out =9.8 PPG. Wash to 10690'MD. 12/29/2015 12/30/2015 1.75 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 10,690.0 10,935.0 22:15 00:00 10690'to 10835'MD(5552'TVD). Pumping 800 GPM w/3690 PSI,46% Flow out. 130 RPM w/17-19K TQ. 14K WOB, ECD=10.94,Off bottom= 3650 PSI,PU=221K,SO= 144K, ROT= 180K, 13K TQ off Bot,ADT= 1.37 HRS,Total Bit HRS=48.14, Total Jar HRS=77.15. Pump 50 BBL,20#Nut Plug Sweep w/ 3%DrillZone @ 9995', 10278'& 10562'MD 12/30/2015 12/30/2015 4.25 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 10,935.0 11,131.0 00:00 04:15 10835'to 11131'MD(5698'TVD). Pumping 800 GPM w/3789 PSI,38% Flow out. 130 RPM w/18-20K TQ. 10K WOB, ECD=10.86,Off bottom= 3785 PSI,PU=222K,SO= 144K, ROT=184K, 14K TQ off Bot.SPR's at 10842'MD(5555'TVD),9.7 PPG. Mud pump#1:20 spm w/230 psi,30 spm w/280 psi.Mud pump#2:20 spm w/240 psi,30 spm w/290 psi. 12/30/2015 12/30/2015 0.50 INTRM1 DRILL RGRP T Circulate and recip from 11125'— 11,131.0 11,131.0 04:15 04:45 11035'MD while changing out PSV that popped off at 4300 PSI. Circ @ 400 GPM, 1214 PSI and 20 RPM on #2 MP only. 12/30/2015 12/30/2015 1.25 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 11,131.0 11,226.0 04:45 06:00 11131'to 11226'MD(5734'TVD). Pumping 800 GPM w/3790 PSI,37% Flow out. 130 RPM w/18-20K TQ. 15K WOB, ECD=10.68,Off bottom= 3775 PSI,PU=235K,SO=146K, ROT=183K, 15K TQ off Bot,ADT= 4.37 HRS,Total Bit HRS=52.51, Total Jar HRS=81.52. 12/30/2015 12/30/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 11,226.0 11,650.0 06:00 12:00 11226'to 11650'MD(5918'TVD). Pumping 800 GPM w/4031 PSI,36% Flow out. 130 RPM w/18-20K TQ. 10K WOB, ECD=11.13,Off bottom= 3905 PSI, PU=237K,SO=138K, ROT=178K, 15K TQ off Bot,ADT= 3.8 HRS,Total Bit HRS=56.31,Total Jar HRS=85.32. Started weighting up to 10 PPG at 10,300' -11,450' MD. SPR's at 11603'MD(5900' TVD), 10 PPG.Mud pump#1:20 spm w/280 psi,30 spm w/2320 psi.Mud pump#2:20 spm w/260 psi,30 spm w/320 psi. Page 22/51 Report Printed: 2/10/2016 p Operations Summary (with Timelog ths) p9 p 2S-01 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 12/30/2015 12/30/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 11,650.0 12,100.0 12:00 18:00 11650'to 12100'MD(6084'TVD). Pumping 800 GPM w/3930 PSI,36% Flow out. 130 RPM w/22K TQ. 15K WOB, ECD=10.97,Off bottom= 3900 PSI,ROT= 171K, 14-21K TQ off Bot,ADT=4.16 HRS,Total Bit HRS= 60.47,Total Jar HRS=89.48. 12/30/2015 12/31/2015 6.00 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11"hole f/ 12,100.0 12,456.0 18:00 00:00 12100'to 12456'MD(6187'TVD). Pumping 800 GPM w/3580 PSI,37% Flow out. 130 RPM w/21K TQ.6K WOB, ECD= 10.82,Off bottom= 3575 PSI,ROT= 174K,20K TQ off Bot,ADT=4.82 HRS,Total Bit HRS= 65.29,Total Jar HRS=94.30. Fluid loss for last 24 hrs=0 Pump 50 BBL,20#Nut Plug Sweep w/ 3%DrillZone @ 10846', 11132', 11320'MD. 12/31/2015 12/31/2015 4.50 INTRM1 DRILL DDRL P TD 9-7/8"x 11"hole Intermediate 12,456.0 12,585.0 00:00 04:30 section at 12,585'MD after drilling f/ 12456'to 12585'MD(6209'TVD). Pumping 800 GPM w/3789 PSI,36% Flow out. 130 RPM w/19-20K TQ.6K WOB, ECD=10.76,Off bottom= 3571 PSI,PU=239K,SO=135K, ROT=167K, 15K TQ off Bot. ADT= 3.32 HRS,Total Bit HRS=68.61, Total Jar HRS=97.62. SPR's at 12580'MD(6209'TVD), 10.0 PPG. Mud pump#1:20 spm w/200 psi,30 spm w/270 psi.Mud pump#2:20 spm w/220 psi,30 spm w/280 psi. 12/31/2015 12/31/2015 0.50 INTRM1 CASING CIRC P Circulate for final SLB survey and drop 12,585.0 12,585.0 04:30 05:00 5 RFID closing tags for Weatherford Riptide Underreamer at 700 GPM and 3057 PSI. Reduce rate to 300 GPM at 1640 stks then increased to 700 GPM to verify closed. No good indication of Reamer closing. Plan to drop more chips after circulation. 12/31/2015 12/31/2015 1.25 INTRM1 CASING CIRC P Circ and recip 8600 stks to move 12,585.0 12,585.0 05:00 06:15 cuttings up hold to build section and place fresh mud over HRZ. Rotate and recip from 12583'—12553'MD @ 800 GPM,3571 PSI,38%FO, 130 RPM and 17K TQ. 12/31/2015 12/31/2015 0.50 INTRM1 CASING OWFF P Conduct MPD drawdown test and no 12,585.0 12,585.0 06:15 06:45 pressure build-up was observed. 12/31/2015 12/31/2015 3.50 INTRM1 CASING PMPO P Pump OOH f/12583'—11500'MD 12,585.0 11,500.0 06:45 10:15 (above HRZ)©300 GPM&915 PSI @ 3000 FPH holding 250 PSI with MPD. Drop 5 more RFID reamer closing Tags. Page 23/51 Report Printed: 2/10/2016 %`vOperations Summary (with Timelog Depths) 2S-01 r. iilips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/31/2015 12/31/2015 2.75 INTRM1 CASING CIRC P Circ 3 BU while rotate and recip f/ 11,500.0 11,500.0 10:15 13:00 11500'-11410'MD©750 GPM, 3280 PSI,35%FO, 100 RPM, 14K TQ,MW in&out=10 PPG,PU= 230K,SO=144K,Rot=180K. Pumped total of 32075 stks. 12/31/2015 12/31/2015 0.50 INTRM1 CASING OWFF P Monitor well f/30 min(static) 11,500.0 11,500.0 13:00 13:30 12/31/2015 12/31/2015 0.25 INTRM1 CASING OTHR P Swap power to rig generators for 3rd 11,500.0 11,500.0 13:30 13:45 party hi-line transformer maintenance. 12/31/2015 12/31/2015 0.50 INTRM1 CASING CIRC P Pump 35 BBL 12PPG dry job,B/D top 11,500.0 11,500.0 13:45 14:15 drive,line up MPD for stripping OOH. 12/31/2015 12/31/2015 6.00 INTRM1 CASING SMPD P Strip OOH f/ 11550-2907'MD 11,500.0 2,907.0 14:15 20:15 following pressure schedule monitoring with pit 2&3. PU=112K, SO=110K. 12/31/2015 12/31/2015 0.75 INTRM1 CASING MPDA P Pull MPD bearing and install trip 2,907.0 2,907.0 20:15 21:00 nipple. 12/31/2015 12/31/2015 1.50 INTRM1 CASING CIRC P Circ BU while Recip&Rot f/2900'- 2,907.0 2,907.0 21:00 22:30 2803'MD @ 700 GPM,2110 PSI, 35%FO, 100 RPM,2.5K TQ. Pump 35 BBL nutplug sweep. MW in&Out =10 PPG. Total pumped=10,106 stks. 12/31/2015 12/31/2015 1.00 INTRM1 CASING SLPC P Cut and slip drill line. Monitor well 2,907.0 2,907.0 22:30 23:30 (static) 12/31/2015 1/1/2016 0.50 INTRM1 CASING SVRG P Service top drive,blocks and crown. 2,907.0 2,907.0 23:30 00:00 Calibrate Amphion,Totco and SLB Block HT. 1/1/2016 1/1/2016 1.25 INTRM1 CASING TRIP P TOH on elevators f/2900' -728'MD 2,907.0 728.0 00:00 01:15 Monitor via trip tank. 1/1/2016 1/1/2016 0.25 INTRM1 CASING OWFF P Monitor well(static). C/O PS-21 slips. 728.0 728.0 01:15 01:30 1/1/2016 1/1/2016 3.25 INTRM1 CASING BHAH P LD Slumberger BHA f/728'MD to 728.0 0.0 01:30 04:45 surface. 1/1/2016 1/1/2016 0.75 INTRM1 CASING BHAH P Clean&clear floor. 0.0 04:45 05:30 1/1/2016 1/1/2016 1.50 INTRM1 WHDBOP RURD P Pull wear ring,flush and drain stack, 0.0 0.0 05:30 07:00 install test plug 1/1/2016 1/1/2016 1.00 INTRM1 WHDBOP RURD P Change out 2-7/8"X 5-1/2"VBR pipe 0.0 0.0 07:00 08:00 rams to 7-5/8"casing rams. 1/1/2016 1/1/2016 0.75 INTRM1 WHDBOP RURD P Install 5"test joint and complete shell 0.0 0.0 08:00 08:45 test to 3500 PSI. Page 24/51 Report Printed: 2/10/2016 • i Operations Summary (with Timelog Depths) 2S-01 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/1/2016 1/1/2016 4.00 INTRM1 WHDBOP BOPE P Pressure test BOPE to 250/3,500 psi 0.0 0.0 08:45 12:45 for 5 minutes on chart recorder using 5"test joint.Test annular,2-7/8x5-1/2" Lower pipe rams and Blind Rams. Manual operated and super choke tested to 250/2,000 psi for 5 minutes on chart recorder. Test choke valves 1-15,manual&auto choke,choke& kill manuals,HCR valves,4"valve on kill line,4"TIW,4"dart valve,5"TIW, 5"dart valve,and Upper&lower IBOP. Perform Koomey drawdown test.Accumulator PSI=3000 psi, Manifold=1500 psi,System pressure 1700 psi after all functions on bottles. 200 psi attained=20 sec with 2 electric pumps.Full system pressure attained=109 sec with 2 electric and 2 air pumps.6 bottle N2 average=1921 psi.Closing times for annular=23 sec, UPR=18 sec, BSR = 16 sec,LPR=16 sec,Choke HCR= 2 sec, Kill HCR=2 sec. Remove 5" test joint and install 7-5/8"TJ. Test annular,upper pipe rams,manual, HCR Choke to 250/3500 PSI,all charted and held for 5 minutes. Witness of test waived by AOGCC inspector Bob Noble. 1/1/2016 1/1/2016 0.75 INTRM1 WHDBOP RURD P Rig down and blow down test 0.0 0.0 12:45 13:30 equipment 1/1/2016 1/1/2016 2.25 INTRM1 CASING RURD P RU to run 7-5/8", L-80,HYD 563 0.0 0.0 13:30 15:45 casing,dopeless connection,RU 6' bail extensions,power tongs,Volant CRT,7-5/8"slip inserts. 1/1/2016 1/1/2016 0.50 INTRM1 CASING PUTB P MU 7-5/8"shoe track to 129'MD. Fill 0.0 129.0 15:45 16:15 and check floats. 1/1/2016 1/1/2016 5.00 INTRM1 CASING PUTB P RIH with 7-5/8"casing f/129'—2885' 129.0 2,885.0 16:15 21:15 MD torqueing to the mark @ 12.4K ft/lbs,filling every joint on the fly and topping off each 10 jts w/Casing Running Tool(CTR). Displace and monitor via pits#2&3. 1/1/2016 1/1/2016 0.75 INTRM1 CASING CIRC P CBU w/recip f/2844'—2885'MD 2,885.0 2,885.0 21:15 22:00 while 7-5/8"casing still in surface casing. Stage pumps up to 6 BPM over 15 minutes. ICP @ 6 BPM= 175 PSI,FCP=160 PSI. 20%FO, 1250 total strokes. Very little cuttings in returns and mud in good shape. 1/1/2016 1/2/2016 2.00 INTRM1 CASING PUTB P Cont'RIH w/7-5/8"casing f/2885'- 2,885.0 3,863.0 22:00 00:00 3048'MD. Make up Weatherford Model 754 Stage tool and BakerLock the top and bottom connections and one connection in the joint above. Cont'RIH to 3863'MD. PU=120K,SO =104K. Loss for past 24 Hrs=0 0915 Swap f/rig generator to hi-line Page 25/51 Report Printed: 2/10/2016 5 °> Operations Summary (with Timelog Depths) C4 2S-01 conoccOhimps - Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr). Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/2/2016 1/2/2016 2.75 INTRM1 CASING PUTB P Cont.to run 7-5/8",L-80, HYD 563 3,863.0 5,726.0 00:00 02:45 casing,dopeless connection f/3862'- 5726'MD,torqueing to 12.4K FT-LBS, filling on the fly and topping off each 10 jts w/Casing Running Tool(CRT). 1/2/2016 1/2/2016 1.50 INTRM1 CASING CIRC P CBU while recip f/5760'to 5726'MD 5,726.0 5,726.0 02:45 04:15 staging pumps up to 6 BPM over 15 minutes w/24%FO. ICP=346 PSI, FCP=211 PSI @ 5.5 BPM. Total pumped=4950 STKS. PU©3 BPM =146K,SO=105K. 1/2/2016 1/2/2016 3.25 INTRM1 CASING PUTB P Cont RIH w/7-5/8"casing f/5726'— 5,726.0 8,140.0 04:15 07:30 8140'MD,torqueing to 12.4K FT-LBS, filling on the fly and topping off each 10 jts w/CRT. 1/2/2016 1/2/2016 1.00 INTRMI CASING CIRC P Circ while recip f/8140'-8111'MD 8,140.0 8,140.0 07:30 08:30 staging pumps up to 6 BPM over 15 minutes w/22%FO. ICP=385 PSI, FCP=358 PSI. Total pumped=2521 STKS. PU @ 3 BPM=178K,SO= 115K. 1/2/2016 1/2/2016 0.50 INTRM1 CASING PUTB P Cont RIH w/7-5/8"casing f/8140'— 8,140.0 8,639.0 08:30 09:00 8639'MD,torqueing to 12.4K FT-LBS, filling on the fly and topping off each 10 jts w/CRT. 1/2/2016 1/2/2016 0.75 INTRM1 CASING CIRC P Circ while recip f/8639'-8603'MD 8,639.0 8,639.0 09:00 09:45 staging pumps up to 6 BPM over 15 minutes w/22%FO. ICP=350 PSI, FCP=289 PSI. Total pumped=3193 STKS. PU @ 3 BPM=185K,SO= 117K. 1/2/2016 1/2/2016 4.25 INTRM1 CASING PUTB P Cont RIH w/7-5/8"casing f/8639'— 8,639.0 11,504.0 09:45 14:00 11504'MD,torqueing to 12.4K FT- LBS,filling on the fly and topping off each 10 jts w/CRT. 1/2/2016 1/2/2016 3.50 INTRM1 CASING CIRC P Circ while recip f/11463'-11504'MD 11,504.0 11,504.0 14:00 17:30 staging pumps up to 6 BPM over 15 minutes w/19%FO. ICP=440 PSI, FCP=378 PSI. Total pumped= 10978 STKS. PU @ 3 BPM=242K, SO= 132K. MW in=10.0,Out= 10.1+. 1/2/2016 1/2/2016 1.50 INTRM1 CASING PUTB P Cont RIH w/7-5/8"casing f/11504'— 11,504.0 12,532.0 17:30 19:00 12532'MD,torqueing to 12.4K FT- LBS,filling on the fly and topping off each 10 jts w/CRT. 1/2/2016 1/2/2016 1.50 INTRM1 CASING CIRC P Circ while recip f/12497'-12532'MD 12,532.0 12,532.0 19:00 20:30 staging pumps up to 6 BPM over 15 minutes w/20%FO,425 PSI. Total pumped=3000 STKS. PU @ 3 BPM =270K,SO=137K. 1/2/2016 1/2/2016 0.50 INTRM1 CASING HOSO P Make up CIW hanger and landing jt. 12,532.0 12,574.0 20:30 21:00 Wash down @ 2 BPM,255 PSI, 14% FO. Landed at 12574'MD. 1/2/2016 1/2/2016 2.50 INTRM1 CEMENT CIRC P Circ while recip f/12557'-12574'MD 12,574.0 12,574.0 21:00 23:30 staging pumps up to 6 BPM over 15 minutes w/15%FO. ICP=255 PSI, FCP=335 PSI. Total pumped=6000 STKS. PU @ 3 BPM=265K,SO= 140K. Page 26/51 Report Printed: 2/10/2016 • 1110 Operations Summary (with Timelog Depths) ) 2S-01 Fhilii�ss Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time - End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/2/2016 1/3/2016 0.50 INTRM1 CEMENT OTHR T Lost COPA hi-line power,all rig 12,574.0 12,574.0 23:30 00:00 power off. Attempting to start 3516 generators without success. Fluid loss for past 24 hrs=0 BBP's 1/3/2016 1/3/2016 0.50 INTRM1 CEMENT RGRP T Lost hi-line power,all rig power off. 12,574.0 12,574.0 00:00 00:30 Started Gens after 1 hour. 1/3/2016 1/3/2016 1.00 INTRM1 CEMENT CIRC P Resume circ while recip f/12557'- 12,574.0 12,574.0 00:30 01:30 12574'MD staging pumps up to 6 BPM,440 PSI w/22%FO. Total pumped=7013 STKS. 1/3/2016 1/3/2016 1.50 INTRM1 CEMENT CIRC P RU Cement hose to Casing Running 12,574.0 12,574.0 01:30 03:00 Tool(CRT). Blow down top drive. Resume circ while recip f/12557'- 12574'MD staging pumps up to 6 BPM,440 PSI w/22%FO. Total pumped=5678 STKS. PU=274K, SO=144K. 1/3/2016 1/3/2016 4.25 INTRM1 CEMENT CMNT P Stage 1 Cement job-SLB pumped 12,574.0 12,574.0 03:00 07:15 5.0 BBL H2O,PT lines to 4000 psi. Continue pumping 41 bbl MudPush2 ©4.5 bpm,300 psi, 19%flow out. Drop bottom Weatherford By-Pass plug,pump 142.5 bbl 15.8 ppg GasBlok cement @ 4-7 bpm, 180— 360 PSI,22%flow out.Drop top Weatherford Shut-Off plug,kick out with 10 bbl water.Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM to catch cement at 1450 stks. Reduce rate to 5 BPM, ICP=220 PSI,FCP=533 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16% flow at 5462 Stks pumped. Recip pipe w/15'strokes throughout the job until 5270 stks pumped. Bump plug @ 5500 stks,pressure up 500 psi over to 1100 psi and hold for 5 minutes.Bleed pressure to 0 psi,bled back 2.3 bbl. Check floats-good.Final P/U=252k, S/0=124k.CIP:06:33 hrs 1-03-16. 1/3/2016 1/3/2016 1.75 INTRM1 CEMENT CMNT P Stage 2 Cement job—Pres to 2718 12,574.0 12,574.0 07:15 09:00 PSI and observed Weatherford Stage tool opening. Pres reduced to 105 PSI,circ @ 6 BPM,345 PSI, 19%FO. Swap back to SLB. Pump 39.7 BBL of MudPush2 followed by 58.6 BBL of 15.5 PPG GasBlok cement @ 6 BPM, 300 PSI,22%FO. Drop Weatherford Closing plug,kick out with 10 bbl water.Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM,75 PSI,6%FO. Reduce rate to at 3675 stks pumped to 6 BPM,ICP =484 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16%flow at 4138 Stks pumped.Bumped plug at 4240 stks. Pres up to 1300 PSI and observed stage tool closing. Monitor flow back to confirm closure. Good test. CIP: 08:54 hrs 1-03-16. Page 27/51 Report Printed: 2/10/2016 •O Operations Summary • (with TimelogDepths) p ,44.,„,,,,,,,„,.., 2S-01 ConocoPhithps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 1/3/2016 1/3/2016 2.00 INTRM1 CEMENT RURD P R/D Circ equipment. R/D Volant CRT. 0.0 0.0 09:00 11:00 Drain&Flush stack. Pull Landing Joint SIMOPS,loading 4"DP into pipeshed. 1/3/2016 1/3/2016 4.50 INTRM1 CEMENT WWSP T RIH w/Pack-off and attempt to seat. 0.0 0.0 11:00 15:30 Would not seat. RU stack cleaner and flush stack and top of hanger. RIH w/ Pack-off and attempt to seat. Still would not seat. 1/3/2016 1/3/2016 2.00 INTRM1 CEMENT WWSP P RU pressure washer and ran in to 0.0 0.0 15:30 17:30 wash top of hanger. Re-attempt and pack-off seated. RI LDS and test to 5000 PSI for 10 min. Pull landing jt. 1/3/2016 1/3/2016 0.75 INTRM1 CEMENT RURD P Change out long casing bails for 0.0 0.0 17:30 18:15 drilling bails. Install slip inserts. PU and set mousehole. 1/3/2016 1/3/2016 4.25 INTRM1 CEMENT PULD P Layed down 150 joints of 5"DP. . 0.0 0.0 18:15 22:30 SIMOPS-Pump Isotherm job. PT'd lines to 2000 PSI. Perform injection LOT on OA. Pump 120 stks @ 7 SPM. SI with 570 PSI f/5 min,bled to 480 PSI. Flush OA with 129 bbl fresh H2O total @ 5 BPM, 1045 PSI. Freeze protect 7-5/8"X 10-3/4"OA w/ Isotherm using Little Red Services. Pump 89 bbl total @ 3 BPM, Initial Pres=1050 PSI, Final Pres=800 PSI. Freeze Protect in place @ 2210 hrs. Final SI=760 PSI. Estimated depth of Freeze Protect-2242 MD/2139 TVD. 1/3/2016 1/4/2016 1.50 INTRM1 CEMENT PULD P Continue laying down 15 joints of 5" 0.0 0.0 22:30 00:00 DP via mousehole. 1/4/2016 1/4/2016 9.00 INTRM1 CEMENT PULD P Continue to lay down 216 joints of 5" 0.0 0.0 00:00 09:00 Drill Pipe via mousehole. SIMOPS- C/O 7-5/8"casing rams to 2-7/8"X 5- 1/2"VBR's. 1/4/2016 1/4/2016 1.50 INTRM1 CEMENT RURD P Laydown mousehole,change 0.0 0.0 09:00 10:30 elevators,change saver sub to 4". SIMOPS-C/O valves&seats on#2 mud pump. C/O swab&liner on#2 Pod. 1/4/2016 1/4/2016 1.50 INTRM1 CEMENT BOPE P Install test plug and test 2-7/8"X 5- 0.0 0.0 10:30 12:00 1/2"upper and lower VBR's with 4" test joint@ 250/3500 psi,for 5 minutes each,charted. 1/4/2016 1/4/2016 0.75 INTRM1 CEMENT BOPE P Rig down and blow down test 0.0 0.0 12:00 12:45 equipment,pull test plug,set wear bushing and run in LDS. Laydown test joint. 1/4/2016 1/4/2016 0.50 INTRM1 CEMENT RURD P Torque and install safety wire on saver 0.0 0.0 12:45 13:15 sub clamp,C/O slip inserts. 1/4/2016 1/4/2016 7.25 INTRM1 CEMENT PULD P PU 150 joints of 4"drillpipe and stand 0.0 0.0 13:15 20:30 back in derrick. SIMOPS-Change out suction and discharge valves and seats in#1 mud pump. 1/4/2016 1/4/2016 3.00 INTRM1 CEMENT PULD P PU and RIH w/4"drillpipe singles to 0.0 0.0 20:30 23:30 2689'MD. Monitor displacement via trip tank. 1/4/2016 1/5/2016 0.50 INTRM1 CEMENT SVRG P Service topdrive-SIMOPS Remove 0.0 0.0 23:30 00:00 broken buggy guide on skate. Page 28/51 Report Printed: 2/10/2016 F hT. Operations Summary (with Timelog Depths) . 2S-01 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time : End Time Our Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT RGRP T Continue to service skate,pipe shed, 2,689.0 2,689.0 00:00 00:30 blocks and top drive. 1/5/2016 1/5/2016 3.00 INTRM1 CEMENT PULD P Continue to run in hole with 4"DP 2,689.0 4,839.0 00:30 03:30 singles from 2689'MD to 4839'MD, monitor displacement via trip tank#1. 1/5/2016 1/5/2016 2.00 INTRM1 CEMENT TRIP P Pull out of hole from 4839'MD while 4,839.0 0.0 03:30 05:30 racking back stands in the derrick, monitor displacment via trip tank#1. 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT SFTY P Clean and clear rig floor.Change out 0.0 0.0 05:30 06:00 slip inserts. 1/5/2016 1/5/2016 2.50 INTRM1 CEMENT BHAH P PJSM for picking up BHA.Pick up 0.0 0.0 06:00 08:30 BHA as per Schlumberger DD. 1/5/2016 1/5/2016 2.75 INTRM1 CEMENT PULD P Change out slip inserts. Run in hole 0.0 2,285.0 08:30 11:15 with 60 singles to 2285'MD.Monitor displacement via pit#3 1/5/2016 1/5/2016 0.25 INTRM1 CEMENT DHEQ P Fill pipe and break circulation by 2,285.0 2,285.0 11:15 11:30 staging pumps up to 5 BPM.Shallow pulse test @ 210 GPM, 1155 psi,21% flow out and blow down top drive. 1/5/2016 1/5/2016 1.75 INTRM1 CEMENT PULD P Continue running in hole with singles 2,285.0 4,190.0 11:30 13:15 from 2285'MD to 4190'MD,monitor displacement via pit#3. 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT DHEQ P Fill pipe and check MWD staging 4,190.0 4,190.0 13:15 13:45 pump to 210 GPM, 1265psi, 18%flow out,and blow down top drive. 1/5/2016 1/5/2016 0.25 INTRM1 CEMENT PULD P Continue to run in hole with singles 4,190.0 4,318.0 13:45 14:00 from 4190'MD to 4318'MD,monitor displacement via pit#3. 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT RGRP T Repair/Replace broken skate buggy 4,318.0 4,318.0 14:00 14:30 chain guides. 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT SVRG P Service and inspect top drive and 4,318.0 4,318.0 14:30 15:00 blocks. 1/5/2016 1/5/2016 2.50 INTRM1 CEMENT SLPC P PJSM for cut and slip of drill line. Cut 4,318.0 4,318.0 15:00 17:30 55'of drill line,slip on same,replace topdrive link tilt yoke bushings, calibrate TOTCO and Amphion block height. 1/5/2016 1/5/2016 1.75 INTRM1 CEMENT PULD P Continue to run in hole with singles 4,318.0 6,214.0 17:30 19:15 from 4318'MD to 5772'MD.Run in hole with 4"doubles to 6214'MD, monitor displacement via pit#3. 1/5/2016 1/5/2016 0.50 INTRM1 CEMENT DHEQ P Fill pipe and check MWD to 210 GPM, 6,214.0 6,214.0 19:15 19:45 1350 psi, 19%flow out,and blow down top drive. 1/5/2016 1/5/2016 1.00 INTRM1 CEMENT MPSP P PJSM for Baker Storm Packer.Make 6,214.0 6,265.0 19:45 20:45 up/Run in hole/set Storm Packer as per Baker rep(Bit depth at 6265'MD, 87'MD below rotary table).Rack stand and lay down running tool. 1/5/2016 1/5/2016 0.75 INTRM1 WHDBOP RURD P Pick up 3-1/2"test jt,pull wear 6,265.0 6,265.0 20:45 21:30 bushing,drain BOP stack,and set upper test plug. Page 29/51 Report Printed: 2/10/2016 .„ . . • x J Operations Summary (with Timelog Depths) Cts $ _ ti 2S-01 PhiHgps • Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/5/2016 1/6/2016 2.50 INTRM1 WHDBOP BOPE P Test BOPE using 3-1/2"test joint to 6,265.0 6,265.0 21:30 00:00 250psi/3500psi for 5 charted minutes for all tests with exception of Manual Operated and Super Choke(250psi/ 2000psi for 5 charted minutes). Tested annular(Closing time:23sec), 4"kill,choke valves#1,#13,#14,#15, Upper IBOP.Tested Upper 2-7/8"x 5- 1/2"VBR(Closing Time:18sec),HCR Kill(Closing Time:2sec),choke valves #2,#3,#6,#7,#8,#9,#10,#11,#12,and Lower IBOP. Test witnessed by AOGCC Rep Brian Bixby. 1/6/2016 1/6/2016 2.50 INTRM1 WHDBOP BOPE P Test BOPE using 3-1/2"test joint to 6,265.0 6,265.0 00:00 02:30 250psi/3500psi for 5 charted minutes for all tests with exception of Manual Operated and Super Choke(250psi/ 2000psi for 5 charted minutes). Tested 2-7/8"x5-1/2"Upper VBR, Koomey draw down test before=3000psi,after= 1600psi, 200psi electric pump recovery=20sec, Overall recovery= 130sec,6bottle avg=1900psi. Blind rams test choke valves#4,#5,#7.Using 4-1/2"test joint,test annular, HCR choke,2-7/8" x 5-1/2"VBR's and manual choke. Annular closing time=26sec,HCR Choke closing time=2sec.Test witnessed by AOGCC Rep Brian Bixby. 1/6/2016 1/6/2016 1.00 INTRMI WHDBOP RURD P Rig down and blow down test 6,265.0 6,265.0 02:30 03:30 equipment. Pull upper test plug,set cameron 10"ID wear bushing. 1/6/2016 1/6/2016 1.25 INTRM1 CEMENT MPSP P PJSM for retrieving Storm Packer. 6,265.0 6,241.0 03:30 04:45 Make up 7-5/8"Baker Storm Packer retrieval tool. Run in hole to 87'MD. Make up 4"TIW valve,engage retrieval tool,check pressure below storm packer,releas storm packer and pull out of hole. Lay out storm packer. Blow down kill line. 1/6/2016 1/6/2016 2.75 INTRM1 CEMENT PULD P Change out slip inserts,PJSM for 6,241.0 8,490.0 04:45 07:30 running in hole with 4"drill pipe. Run in hole withe 4"doubles from 6241' MD to 8490'MD while monitoring displacement via pit 3. Fill pipe every 2000'. 1/6/2016 1/6/2016 1.50 INTRM1 CEMENT CIRC P Make up head pin 2"high pressure 8,490.0 8,490.0 07:30 09:00 hose,circulate bottoms up,establish circualtion @ 4 BPM,950psi,20% flow out. 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT PRTS P PJSM for testing casing.Pressure test 8,490.0 8,490.0 09:00 10:00 casing to 3500psi @ 7 SPM(50stks) and hold for 10min.Bleed off pressure and measure bleed back(5bbl). Rig down and blow down test equipment. Page 30/51 Report Printed: 2/10/2016 Operations Summary (with Timelo Depths) I 2S-01 Cc ocothitli 3s Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/6/2016 1/6/2016 0.50 INTRM1 CEMENT TRIP P Continue running in hole from 8490' 8,490.0 8,600.0 10:00 10:30 MD to 8530'MD. Started taking weight(15k).Make up top drive and circulate down @ 205 GPM, 1550psi, 20%flow out,40 RPM,6-7k TQ. Wash through obstruction without incident to 8600'MD. 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT TRIP P Run in hole from 8600'MD to 9300' 8,600.0 9,300.0 10:30 11:30 MD while monitoring displacement via pit#3. 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT COCF P Make up top drive and wash down 9,300.0 9,505.0 11:30 12:30 from 9300'MD to 9505'MD @ 205 GPM, 1580psi,20%flow out,40 RPM, 6-7k TQ. PU wt=140k,SO wt=80k,ROT wt= 108k 1/6/2016 1/6/2016 0.25 INTRM1 CEMENT COCF P Drill cement from 9505'MD to 9519' 9,505.0 9,519.0 12:30 12:45 MD @ 207 GPM, 1570psi,21%flow out,40 RPM,9-10k TQ,5k WOB. 1/6/2016 1/6/2016 2.50 INTRM1 CEMENT DRLG P Tag 2nd stage plug @ 9520'MD,drill 9,519.0 9,563.0 12:45 15:15 plug and stage collar from 9520'MD to 9524'MD @ 200 GPM, 1450 psi, 18% flow out,30-60 RPM, 10-14k TQ,2- 15k WOB. Continue drilling to end of stand @ 9563'MD. Work through stage collar 3 times from 9505'MD to 9563'MD @ above parameters. PU wt=153k,SO wt=78k, Rot wt= 110k. 1/6/2016 1/6/2016 1.25 INTRM1 CEMENT PULD P Continue running in hole with 4" 9,563.0 11,146.0 15:15 16:30 doubles from 9563'MD to 11,146'MD while monitring displacement via pit #3. 15k drag @ 11,146'MD. 1/6/2016 1/6/2016 0.50 INTRM1 CEMENT COCF P Wash and ream through strings from 11,146.0 11,270.0 16:30 17:00 11,146'MD to 11,270'MD while staging pump up to 204 GPM, 1700psi, 18%flow out,40 RPM, 10k TQ, Blow down top drive. PU wt=158k,SO wt=80k. 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT PULD P Run in hole with 4"doubles from 11,270.0 12,160.0 17:00 18:00 11,270'MD to 12,160'MD while monitoring displacement via pit#3. PU wt= 172k,SO wt=80k. 1/6/2016 1/6/2016 1.25 INTRM1 CEMENT COCF P Wash and ream thru stringers from 12,160.0 12,419.0 18:00 19:15 12,160'MD to 12,419'MD@204 GPM, 1785psi,23%flow out,40 RPM, 13k TQ. 1/6/2016 1/6/2016 1.75 INTRM1 CEMENT DRLG P Drill cement on top of landing collar 12,419.0 12,440.0 19:15 21:00 from 12,419'MD to 12,440'MD @ 248 GPM,2380 psi,20%flow out,60 RPM, 14-15k TQ. Page 31/51 Report Printed: 2/10/2016 !perations Summary (with Timelog epths) 2S-01 Cc nocoPhillmps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time PT-X Operation (ftKB) End Depth(ftKB) 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT DRLG T Attempt to drill plugs from 12,440'MD 12,440.0 12,441.0 21:00 22:00 to 12,441'MD @ 248 GPM,2380 psi, 20%flow out,60 RPM, 14-15k TQ. Experiences high torque and string stalling out. Modify RPM 20-95 RPM and flow rates(200-260 GPM)and continue to drill out plug(unsuccesful) 1/6/2016 1/6/2016 1.00 INTRM1 CEMENT BKRM T Back ream out of hole from 12,440' 12,440.0 12,440.0 22:00 23:00 MD to 12,253'MD @ 248 GPM,2380 psi,20%flow out,60 RPM, 14-15k TQ. 1/6/2016 1/7/2016 1.00 INTRM1 CEMENT DRLG P Drill plug and landing collar from 12,440.0 12,451.0 23:00 00:00 12,441'MD to 12,448'MD @ 210 GPM, 1730psi, 17%flow out,50-60 RPM,2-6k WOB, 14.5k TQ. Continue drilling cment from 12,448'MD to 12,451'MD with 248 GPM,2380 psi, 20%flow out,60 RPM, 14-15k TQ. 1/7/2016 1/7/2016 0.50 INTRM1 CEMENT DRLG P Drill cement from 12,451'MD to 12,451.0 12,473.0 00:00 00:30 12473'MD @ 230 GPM,2087psi, 18%flow out,70 RPM, 13-14k TQ, 14k WOB 1/7/2016 1/7/2016 1.50 INTRM1 CEMENT CIRC P Circulate while reciprocating and 12,473.0 12,473.0 00:30 02:00 rotating from 12371'MD to 12466'MD @ 230 GPM,2048psi, 17%flow out, 70 RPM, 14-15k TQ 1/7/2016 1/7/2016 1.50 INTRM1 CEMENT PRTS P Blow down top drive and rig up to test 12,473.0 12,473.0 02:00 03:30 casing to 3500psi for 30 charted minutes. Flood lines and pressure up to 3500psi with 7spm. Total volume req'd=60stks or 6bbls to get to 3550psi. Hold for 30min,bleed off pressure and measure bleed back (6bbls). Rig down and blow down pressure test equipment. 1/7/2016 1/7/2016 2.50 INTRM1 CEMENT DRLG P Lay down single on top of stand#127, 12,473.0 12,568.0 03:30 06:00 Pick up std 128 and ream down to 12480'MD @ 230 GPM,2147psi,60 RPM, 14-15k TQ,and 10k WOB. Tag up on float collar at 12480'MD and drill out with 240 GPM,2227psi,40 RPM, 14-17k TQ,2-10k WOB. Ream through float collar to clean up and continue reaming down to shoe @ 12568'MD.Drill out shoe with 230 GPM,2062psi,50 RPM, 15-17k TQ. PU wt=230k,SO wt=81 k,Rot wt= 136k. Off bottom TQ=15k. 1/7/2016 1/7/2016 0.75 INTRM1 CEMENT DDRL P Drill 6-3/4"production hole from 12,568.0 12,605.0 06:00 06:45 12585'MD to 12605'MD/6212'TVD with 240 GPM,2387psi, 17%flow out, 70 RPM, 14-15k TQ,and 10k WOB. ECD=11.01,Off bottom pressure 2143psi, PU wt=230k,SO wt=81 k,Rot wt= 136k. Off bottom TQ=15k. ART/ADT=0.22 Page 32/51 Report Printed: 2/10/2016 tperations Summary (with Timelog!epths) 2S-01 C'.c no dPhimps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttKB) 1/7/2016 1/7/2016 1.25 INTRM1 CEMENT CIRC P Circulate bottoms up while 12,605.0 12,605.0 06:45 08:00 reciprocating and rotating from 12604' MD to 12537'MD with 230 GPM, 2198psi, 17%flow out,70 RPM,and 14-15k TQ. 1/7/2016 1/7/2016 1.00 INTRM1 CEMENT FIT P Rack back stand#129 and blow down 12,605.0 12,605.0 08:00 09:00 top drive. Rig up to perform Formation Integrity Test(FIT)to a maximum of 15ppg EMW. Pressure up with 7 SPM,30 strokes or 3bbls,to 1403psi, 14.3ppg MW. Hold for 15 charted minutes.Bleed off pressure while monitoring bleed back(2.9bbls). Wait on town approval(Good Test) and blow down test lines. 1/7/2016 1/7/2016 2.00 PROD1 DRILL DISP P PJSM for displacing well to Klashield 12,605.0 12,605.0 09:00 11:00 mud. Displace well to 10.3ppg Klashield,pump 70bbI 10.3ppg High vis spacer followed by 516bbls of 10.3ppg Klashield while reciprocating and rotating from 12604'MD to 12537' MD. Pump rate was 230GPM, 147psi, 18%flow out,40 RPM, 14k TQ. 1/7/2016 1/7/2016 0.25 PROD1 DRILL OWFF P Observe well for flow(static) 12,605.0 12,605.0 11:00 11:15 1/7/2016 1/7/2016 0.25 PROD1 DRILL CIRC P Take slow pump rates 12,605.0 12,605.0 11:15 11:30 PU wt=193k,SO wt=90k,Rot wt= 136k,and Off Bottom TQ=9k. 1/7/2016 1/7/2016 1.00 PROD1 DRILL DHEQ T Troubleshoot MWD(unsuccessful) 12,605.0 12,534.0 11:30 12:30 while cleaning pits,rack stand#128 to 12,534'MD then blow down top drive. 1/7/2016 1/7/2016 0.50 PROD1 DRILL OWFF T Monitor well for 30min while cleaning 12,534.0 12,534.0 12:30 13:00 pits,shakers,flowline,jet and hole fill lines. 1/7/2016 1/7/2016 1.50 PROD1 DRILL MPDA T PJSM,partially drain stack,remove 12,534.0 12,534.0 13:00 14:30 RCD trip nipple,install MPD bearing on joint of drill pipe and install in RCD. Line up MPD and injection lines prior to securing bearing in clamp. 1/7/2016 1/7/2016 0.75 PROD1 DRILL MPDA T Break in MPD bearing and calibrate 12,534.0 12,534.0 14:30 15:15 choke skid by pumping down string and staging up to 240 GPM,2080psi, 18%flow out,20/50 RPM, 10k TQ. 1/7/2016 1/7/2016 0.50 PROD1 DRILL CIRC T Pump 30 bbls of 12ppg slug. Blow 12,534.0 12,534.0 15:15 15:45 down top drive. 1/7/2016 1/7/2016 1.25 PROD1 DRILL MPDA T Establish circulation across top of well 12,534.0 12,534.0 15:45 17:00 calibrating and troubleshooting MPD pressure sensors. 1/7/2016 1/7/2016 6.75 PROD1 DRILL SMPD T Strip out of hole from 12534'MD to 12,534.0 964.0 17:00 23:45 964'MD @ 90ft/min while maintaining 60psi while in slips and 320psi while POOH via MPD chokes.Monitor displacement via Pit#4. Off bottom PU wt=182k,SO wt=104k Page 33/51 Report Printed: 2/10/2016 !perations Summary (with Timelog!epths) *14 2S-01 Conoco:hiltips i Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/7/2016 1/8/2016 0.25 PROD1 DRILL OWFF T Fully open MPD chokes,isolate 964.0 964.0 23:45 00:00 injection line,line up and monitor well for 10min via trip tank(well static). 1/8/2016 1/8/2016 0.25 PROD1 DRILL OWFF T Monitoring well via Trip tank(Well 964.0 964.0 00:00 00:15 Static) 1/8/2016 1/8/2016 1.00 PROD1 DRILL MPDA T Remove MPD bearing and pull off 964.0 964.0 00:15 01:15 pipe,install trip nipple. 1/8/2016 1/8/2016 1.75 PROD1 DRILL TRIP T Continue pulling out of the hole from 964.0 206.0 01:15 03:00 964'MD to 206'MD racking stands back in derrick. 1/8/2016 1/8/2016 1.75 PROD1 DRILL BHAH T PJSM-lay down BHA as per 206.0 0.0 03:00 04:45 Schlumberger DD:Lay out ADN, Impulse,Periscope,Power Drive,and Bit. Inspect MPD Sensor and clean and clear rig floor. 1/8/2016 1/8/2016 1.75 PROD1 DRILL BHAH T PJSM-Pick up BHA as per 0.0 397.0 04:45 06:30 Schlumberger DD. Pick up BHA and run in hole to 397'MD and cross over to 4"DP out of the derrick. 1/8/2016 1/8/2016 1.25 PROD1 DRILL TRIP T Run in hole with 4"DP from 397'MD 397.0 1,906.0 06:30 07:45 to 1906'MD while monitoring displacment via trip tank. 1/8/2016 1/8/2016 0.25 PROD1 DRILL DHEQ T Fill pipe and break circulation.Stage 1,906.0 1,906.0 07:45 08:00 pumps up to 210 GPM,shallow hole test MWD/LWD with 210 GPM, 969psi, 19%flow out. (Good Test) 1/8/2016 1/8/2016 7.75 PROD1 DRILL TRIP T Continue running in the hole from 1,906.0 12,255.0 08:00 15:45 1906'MD to 9000'MD @ 90ft/min. Continue running in the hole from 9000'MD to 12,255'MD©50ft/min. Monitor displacement via pit#2 and fill pipe every 20stds. 1/8/2016 1/8/2016 0.75 PROD1 DRILL MPDA T PJSM,remove RCD trip nipple,install 12,255.0 12,255.0 15:45 16:30 RCD bearing onto drill pipe. Seat and secure in RCD head. 1/8/2016 1/8/2016 0.25 PROD1 DRILL MPDA T Establish circulation taking returns 12,255.0 12,255.0 16:30 16:45 through the MPD choke skid. Stage pumps from 1BPM to 3BPM. 1 BPM=340psi,3%flow out, 2BPM=550psi,8%flow out,and 3BPM=780psi, 12%flow out. 1/8/2016 1/8/2016 1.00 PROD1 DRILL SLPC T While circulating at 84 GPM,550psi, 12,255.0 12,255.0 16:45 17:45 9%flow out,cut and slip drill line 47'. Calibrate TOTCO and Amphion block height. 1/8/2016 1/8/2016 0.50 PROD1 DRILL SVRG T Service and inspect top drive and 12,255.0 12,255.0 17:45 18:15 blocks. 1/8/2016 1/8/2016 1.25 PROD1 DRILL REAM T Wash and ream from 12,255'MD to 12,255.0 12,610.0 18:15 19:30 12,610'MD @ 210 GPM, 1680psi, 16%flow out,40 RPM,7K TQ. Obtain SPR's on#1 and#2 MP's Page 34/51 Report Printed: 2/10/2016 gperations Summary (with Timelog!epths) 2S-01 ConocoPhitiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)` Phase Op Code Activity Code Time P-T-X Operation MO) End Depth(ftKB) 1/8/2016 1/9/2016 4.50 PROD1 DRILL DDRL P Directional drill 6-3/4"production hole 12,610.0 12,916.0 19:30 00:00 from 12610'MD to 12916'MD,6286' TVD with 248 GPM,2350psi,20% flow out, 120 RPM, 12k TQ,and 12k WOB. ECD=11.88ppg. Off Bottom pressure=2300psi,PU wt=174k,SO wt=90k,ROT wt=124k, off bottom TQ=9.5k,ART/ADT=3.27 1/9/2016 1/9/2016 7.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 12,916.0 13,390.0 00:00 07:00 12,916'MD to 13,390'MD/6,356' TVD with 260 GPM,2550psi, 130 RPM,22%flow out, 12k WOB,and 12k TQ. PU wt=186k,SO wt=90k,ROT wt= 132k,Off bottom TQ=12k. 1/9/2016 1/9/2016 1.25 PROD1 DRILL CIRC P Rotate and reciprocate from 13,390' 13,390.0 13,316.0 07:00 08:15 MD to 13,316'MD with 261 GPM, 2507psi,22%flow out, 130 RPM,and 11k TQ. PU wt= 187k,SO wt=90k,ROT wt= 132k, Max Gas=1503 units(1% =10ounits) 1/9/2016 1/9/2016 0.75 PROD1 DRILL OWFF P Perform drawdown test of wellbore @ 13,316.0 13,389.0 08:15 09:00 13,389'MD via MPD choke manifold. Well found to be static with 10.3ppg mud weight. 1/9/2016 1/9/2016 1.25 PROD1 DRILL CIRC P Rotate and reciprocate from 13,389' 13,390.0 13,390.0 09:00 10:15 MD to 13,316'MD with 261 GPM, 2550psi,20%flow out, 130 RPM,and 11k TQ. PU wt=187k,SO wt=90k,ROT wt= 132k 1/9/2016 1/9/2016 7.75 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,390.0 14,058.0 10:15 18:00 13,390'MD to14,058'MD/6,356'TVD with 265 GPM,2635psi, 130 RPM, 23%flow out, 10k WOB,and 14k TQ. PU wt=178k,SO wt=85k, ROT wt= 119k,Off bottom TQ=12k. 1/9/2016 1/9/2016 0.50 PROD1 DRILL MPDA T Remove,clean and inspect MPD 14,058.0 14,058.0 18:00 18:30 choke valve#1. Concurrently,replace top drive IBOP valve actuator mount and grease swivel packing. 1/9/2016 1/10/2016 5.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 14,058.0 14,600.0 18:30 00:00 14,058'MD to14,538'MD/6,356'TVD with 260 GPM,2730psi, 130 RPM, 22%flow out,8k WOB,and 14.5k TQ. PU wt=185k,SO wt=78k,ROT wt= 128k,Off bottom TQ= 13k. Page 35/51 Report Printed: 2/10/2016 SYS � �` �� !perations Summary (with Timelog epths) 44,7 2S-01 03nocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/10/2016 1/10/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 14,538.0 15,003.0 00:00 06:00 14,538'MD to 15,003'MD,6378'TVD with 260 GPM,2825psi,22%Flow out, 130 RPM, 12k WOB,and 15k TQ. Fault crossed at 14,676'MD and 14684'MD resulting in a down throw of-23'. Out of zone from 14689'MD to 14,888'MD(199') PU wt=196k,SO wt=73k,RT wt= 130k,Off Bottom TQ= 14k 1/10/2016 1/10/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 15,003.0 15,505.0 06:00 12:00 15,003'MD to 15,505'MD,6378'TVD with 261 GPM,2830psi,22%Flow out, 130 RPM, 12k WOB,and 15k TQ. PU wt= 196k,SO wt=73k,RT wt= 119k,Off Bottom TQ=13k 1/10/2016 1/10/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 15,505.0 16,048.0 12:00 18:00 15,505'MD to 16,048'MD,6378'TVD with 265 GPM,2870psi,22%Flow out, 130 RPM, 11k WOB,and 15k TQ. Fault crossed at 15,974'MD resulting in a down throw of-16'. Out of zone from 15,974'MD to 16,080'MD(106') PU wt= 192k,SO wt=74k,RT wt= 119k,Off Bottom TQ= 14k 1/10/2016 1/11/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 16,048.0 16,466.0 18:00 00:00 16,048'MD to 16,466'MD,6375'TVD with 261 GPM,2880psi,22%Flow out, 130 RPM, 10k WOB,and 16k TQ. PU wt=194k,SO wt=74k,RT wt= 117k,Off Bottom TQ=13.5k 1/11/2016 1/11/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 16,466.0 17,053.0 00:00 06:00 16,466'MD to 17,053'MD/6371'TVD with 261 GPM,2919psi,22%flow out, 130 RPM,8k WOB and 16k TQ. PU wt=197k,SO wt=103k @ 20 RPM,Rot wt=115k 1/11/2016 1/11/2016 4.75 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 17,053.0 17,470.0 06:00 10:45 17,053'MD to 17,470'MD/6377'TVD with 230 GPM,2912psi,21%flow out, 130 RPM,7k WOB and 16k TQ. PU wt=210k,SO wt=106k @ 30 RPM,Rot wt=129k 1/11/2016 1/11/2016 1.25 PROD1 DRILL CIRC T Not able to get weight transfer to bit. 17,470.0 17,470.0 10:45 12:00 Rotate and reciprocate from 17,470' MD to 17,375'MD with 261 GPM, 2905psi,21%flow out. Pu wt=210k,SO wt= 106k with 30 RPM,Rot wt=129k.Off bottom torque =16k Page 36/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01 C —`� d% nocoPhiliips •'�. A7.�:ks Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttt6). 1/11/2016 1/11/2016 2.75 PROD1 DRILL CIRC T Continue to have issues getting weight 17,470.0 17,470.0 12:00 14:45 transfer to bit. Rotate and reciprocate from 17,470'MD to 17,375'MD with 261 GPM,2905psi,21%flow out. Establish TQ and drag parameters @ 260 GPM,2800psi. While circulating,Pu wt=212k,SO wt= 106k with 30 RPM,Rot wt=125k. Off bottom torque=14k With 400 psi on annulus via MPD and 0 spp,PU wt=205k,SO wt=75k,ROT wt=135k. 1/11/2016 1/11/2016 5.50 PROD1 DRILL DDRL P Continue drilling 6-3/4"production 17,470.0 17,942.0 14:45 20:15 hole from 17,470'MD to 17,942'MD/ 6387'MD with 261 GPM,2960psi, 22%flow out, 130 RPM,6k WOB and 16k TQ. PU wt=212k,SO wt=70k @ 30 RPM, Rot wt=131k Concurrently,remove#1 Shaker bed and remove from pits. 1/11/2016 1/11/2016 1.50 PROD1 DRILL MPDA T Programmable Logic Controller(PLC) 17,942.0 17,942.0 20:15 21:45 of MPD equipment inadvertantly turned off during cleaning of BOP area. Back-up battery exhausted prior to noticing power issue resulting in the PLC powering down,MPD chokes automatically closing,and loss of calibration data. Circulate while rotating from 17942' MD to 17,846'MD at 255 GPM, 2820psi,23%flow out, 110 RPM,and 14.5k off bottom torque. 1/11/2016 1/12/2016 2.25 PROD1 DRILL DDRL P Continue drilling 6-3/4"production 17,942.0 18,131.0 21:45 00:00 hole from 17,942'MD to 18,131'MD/ 6388'MD with 261 GPM,2975psi, 20%flow out, 130 RPM, 10k WOB and 17k TQ. PU wt=220k,SO wt=65k @ 30 RPM, Rot wt=135k Total on-bottom bit Hours:42.47,Total RCD Bearing hours:78 1/12/2016 1/12/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 18,131.0 18,601.0 00:00 06:00 18,131'MD to 18,601'MD/6,395' TVD with 261 GPM,3070psi,20% flow out, 130 RPM,8k WOB,and 17k TQ. PU wt=208,SO wt=70k,Rot wt= 123k,Off Bottom TQ= 15k. Page 37/51 Report Printed: 2/10/2016 R ng !perations Summary (with Timelog epths) 4V-V4 orlt 2S-01 Conocaehillips Rig: DOYON 25 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 MKS) 1/12/2016 1/12/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 18,601.0 19,005.0 06:00 12:00 18,601'MD to 19,005'MD/6,390' TVD with 261 GPM,3151 psi, 19% flow out, 140 RPM,10k WOB,and 18k TQ. PU wt=215,SO wt=67,Rot wt= 131k, Off Bottom TQ=15k. 1/12/2016 1/12/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 19,005.0 19,478.0 12:00 18:00 19,005'MD to 19,478'MD/6,395' TVD with 261 GPM,3150psi,21% flow out, 140 RPM,7k WOB,and 18k TQ. PU wt=227,SO wt=64k,Rot wt= 132k,Off Bottom TQ=15.5k. 1/12/2016 1/13/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 19,478.0 19,958.0 18:00 00:00 19,478'MD to 19,958'MD/6,400' TVD with 261 GPM,3315psi,21% flow out, 140 RPM,9k WOB,and 18.5k TQ. PU wt=226,SO wt=64k,Rot wt= 132k,Off Bottom TQ=15.5k. Total on-bottom bit Hours:59.78,Total RCD Bearing hours: 102, Losses for Day=146bb1 1/13/2016 1/13/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 19,958.0 20,397.0 00:00 06:00 19,958'MD to 20,397'MD/6,400' TVD with 261 GPM,3340psi,22% flow out, 140 RPM,7k WOB,and 17k TQ. PU wt=220k,SO wt=60k,Rot wt= 136k,Off Bottom TQ=15k. 1/13/2016 1/13/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 20,397.0 20,869.0 06:00 12:00 20,397'MD to 20,869'MD/6,406' TVD with 261 GPM,3367psi,21% flow out, 140 RPM,8k WOB,and 18k TQ. PU wt=217,SO wt=60k,Rot wt= 132k,Off Bottom TQ=15k. 1/13/2016 1/13/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 20,869.0 21,247.0 12:00 18:00 20,869'MD to 21,247'MD/6,421' TVD with 261 GPM,3430psi,21% flow out, 140 RPM,8k WOB,and 17.5k TQ. PU wt=230,SO wt=28k, Rot wt= 123k,Off Bottom TQ=14.5k. 1/13/2016 1/14/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 21,247.0 21,575.0 18:00 00:00 21,247'MD to 21,575'MD/6,435' TVD with 261 GPM,3430psi,20% flow out, 140 RPM,8k WOB,and 18k TQ. PU wt=218,SO wt=64k,Rot wt= 129k,Off Bottom TQ= 14k. Total on-bottom bit Hours:74.93,Total RCD Bearing hours: 126,Losses for Day=97bb1 Page 38/51 Report Printed: 2/10/2016 Operations Summary (with Timelogepths) _, .. _: 2S-01 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'.'. 1/14/2016 1/14/2016 2.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 21,575.0 21,720.0 00:00 02:00 21,575'MD to a TD of 21,720'MD/ 6,437'TVD with 261 GPM,3518psi, 22%Flow out,8k WOB, 140 RPM, and 17 TQ. PU wt=218k,SO wt=64k,Rot wt=129k,Off Bottom TQ= 14k. 1/14/2016 1/14/2016 2.00 PROD1 CASING CIRC P Rotate and reciprocate from 21,720' 21,720.0 21,624.0 02:00 04:00 MD to 21,624'MD with 261 GPM, 3446psi,21%Flow out, 140 RPM,Off Bottom TQ=16k. After circulation, rack stand back and blow down top drive in preparation for MPD Drawdown. PUwt=210k,SO wt=60k, Rot wt=134k. 1/14/2016 1/14/2016 1.00 PROD1 CASING OWFF P Pull back in hole from 21,624'MD to 21,624.0 21,624.0 04:00 05:00 21,594'MD and conduct drawdown of wellbore @ 21,594'MD via MPD chokes. Rotation speed=10 RPM. Well found to be static with a mud weight of 10.4ppg. 1/14/2016 1/14/2016 2.00 PROD1 CASING CIRC P Rotate and reciprocate from 21,624' 21,624.0 21,531.0 05:00 07:00 MD to 21,531'MD with 261 GPM, 3465psi,21%Flow out, 140 RPM,Off Bottom TQ= 16k. PUwt=210k,SO wt=60k,Rot wt=134k.Max Gas to surface= 477units.(1%=100 units) 1/14/2016 1/14/2016 4.00 PROD1 CASING CIRC P Continue rotating and reciprocation 21,531.0 21,531.0 07:00 11:00 while waiting up from 10.4ppg to 10.5ppg. Pumping with 261 GPM, 3424psi,Flow Out=22%, RPM= 140psi. 1/14/2016 1/14/2016 1.00 PROD1 CASING MPDA P Change out RCD Bearing on MPD 21,531.0 21,531.0 11:00 12:00 equipment prior to stripping out of hole. 1/14/2016 1/14/2016 0.75 PROD1 CASING MPDA P Obtain torque and drag parameters. 21,531.0 21,439.0 12:00 12:45 Blow down top drive,re-align injection line to RCD head,and input MPD calibrations. PU wt=200k,SO wt=73k,ROT wt=135k. 1/14/2016 1/14/2016 1.75 PROD1 CASING SMPD P Strip out of hole from 21,439'MD to 21,439.0 20,306.0 12:45 14:30 20,306'MD. Pulling at 2000'/hr, encountered a consistant 40k overpull to 240k. PU wt from 20,515'to 20,420'MD,monitor dispalcement via Pit#2. Consult with town regarding overpull and decision was made to begin backreaming out of hole. Page 39/51 Report Printed: 2/10/2016 � _- Operations Summary (with Timelog epths) }'ry .r, 2S-01 Cxxxxornillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/14/2016 1/14/2016 3.50 PROD1 CASING BKRM P Re-align injection line to choke skid 20,306.0 18,889.0 14:30 18:00 while maintaining constant annulus pressure via injection line to MPD choke skid. Follow ramp schedule and pump out of hole from 20,306'MD to 18,889'MD. Flow rate=261 GPM, 3200psi,26%flow out, 140 RPM, 15k TQ. Concurrently,wellbore is being monitored via pits#2,#3,and#4. 1/14/2016 1/15/2016 6.00 PROD1 CASING BKRM P Continue to backream out of hole from 18,889.0 15,843.0 18:00 00:00 18,889'MD to 15,843'MD. Stage up to 1800 fph pulling speed. 1/15/2016 1/15/2016 7.00 PROD1 CASING BKRM P Backream out of hole from 15,843'to 15,843.0 13,679.0 00:00 07:00 13,679'MD @ 2,000 fUhr pulling speed with 261 GPM,2,800psi,22% Flow out, 140 RPM, 12k TQ. Monitor displacement on pits 2,3,&4. Maintain constant annulus pressure via pumping through injection line to MPD skid. Observe torque stall out @ 13k while pulling at 15,600'&14,800'MD. 1/15/2016 1/15/2016 3.00 PROD1 CASING BKRM P Prior to entering shales,reduce pulling 13,679.0 13,500.0 07:00 10:00 speed to 125 ft/hr to allow for 1 x BU per stand and continue backreaming out of hole from 13,679'to 13,500'MD using 261 GPM,2,760 PSI,23%F/O, 140 RPM, 11k TQ. Monitor displacement via pits 2,3,&4. Maintain constant annulus pressure via pumping through injection line to MPD skid. 1/15/2016 1/15/2016 1.75 PROD1 CASING BKRM P Decrease pulling speed,flow rate,and 13,500.0 12,868.0 10:00 11:45 rpm to 150-300 ft/hr,85-127 GPM, 1,287psi, 19%Flow out,20 RPM,&9k TQ and continue backreaming out of hole from 13,500'to 12,868'MD. Monitoring displacement on pits 2,3, &4. Maintain constant annulus pressure via pumping through injection line to MPD skid. Observe torque stall out @ 13k while pulling at 15,600'&14,800'MD. 1/15/2016 1/15/2016 4.25 PROD1 CASING BKRM T Work tight spot @ 12,868'MD. Pull 12,868.0 12,868.0 11:45 16:00 195k,PU wt=172,SOW=80k,ROT wt=120k,9k TQ. Stage pump rate up:1.5 BPM,982psi,Flow out=7%; 2.0 BPM,990psi,Flow out=7.5%;2.5 BPM, 1120 psi,Flow out= 12%;3.0 BPM, 1298psi,Flow out= 12%; Increase choke pressure 100psi and 2.5 BPM, 1220psi,Flow out=10%. Wash down to 12940'MD,holding 500psi on MPD choke,570psi on DP. Page 40/51 Report Printed: 2/10/2016 fperations with Timelo De theSummary � 9 p ) 2S-01 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 1/15/2016 1/15/2016 4.00 PROD1 CASING SMPD T Work tight hole as per ConcoPhillips 12,868.0 12,720.0 16:00 20:00 Rep. Run in hole to 13,000'MD and stage pumps to 260 GPM,2715psi, Flow out 22%,30 RPM,9k TQ. Attempt to straight pull with pumps @ 2 BPM,990psi: Unable to work above 12,820'MD and no returns. Continue to troubleshoot tight hole with and without rotary,able to pull with 400psi annulus back pressure and no rotary to12,720'MD. 1/15/2016 1/15/2016 2.00 PROD1 CASING BKRM P Begin rotation and backream from 12,720.0 12,535.0 20:00 22:00 12,720'MD to 12,535'MD using 2 BPM,970psi,20 RPM,and 11.5-15k TQ. PU wt=173k,SO wt=80k,Rot wt= 120k. 1/15/2016 1/16/2016 2.00 PROD1 CASING CIRC P Circulate and reciprocate from 12,527' 12,535.0 12,438.0 22:00 00:00 MD to 12,438'MD with 260 GPM, 2660psi,Flow out 21%,80 RPM,7.5k TQ. Pu wt= 160k,SO wt=89k,Rot wt= 127k. 1/16/2016 1/16/2016 0.50 PROD1 CASING CIRC P Circulate while rotating and 12,438.0 12,574.0 00:00 00:30 reciprocating from 12,527'MD to 12,438'MD with 260 GPM,2660psi, 21%Flow out,80 RPM,7.5k TQ, 12.09ppg ECD. MWin and out= 10.5ppg PU wt=160k,SO wt=89k,Rot wt= 127k." 1/16/2016 1/16/2016 1.50 PROD1 CASING DISP P Pump 50 bbl of Hi-Vis spacer and 12,574.0 12,065.0 00:30 02:00 chase with 12ppg NaBr/NaCI. Spot viscous pill from 12,574'to 12,065'MD while pumping at 2.5 BPM,450psi,50 ft/min pulling speed. 1/16/2016 1/16/2016 1.75 PROD1 CASING DISP P Displace to 12ppg NaBr/NaCI while 12,065.0 12,065.0 02:00 03:45 rotating and reciprocating from 11,970' MD to 12,065'MD with 190 GPM, 1197psi, 16%Flow out,60 RPM,9k TQ, 12.06ppg ECD. PU wt= 177k,SO wt=93k,and Rot wt=119k" 1/16/2016 1/16/2016 0.50 PROD1 CASING OWFF P Blow down top drive and monitor well 12,065.0 12,065.0 03:45 04:15 for 30min via trip tank. 1/16/2016 1/16/2016 1.00 PROD1 CASING MPDA P PJSM for pulling RCD bearing and 12,065.0 12,065.0 04:15 05:15 installing trip nipple. Pull RCD bearing and install trip nipple. 1/16/2016 1/16/2016 0.75 PROD1 CASING OWFF P Monitor well for 30min via trip tank. 12,065.0 12,065.0 05:15 06:00 Concurrently,Clean and clear rig floor. Blow down MPD choke skid and mud lines. 1/16/2016 1/16/2016 5.25 PROD1 CASING TRIP P PJSM for pulling out of hole. Pull out 12,065.0 397.0 06:00 11:15 of hole from 12,065'MD to 397'MD. Drop 2.39""OD steel drift with 114'of slickline tail. Monitor displacement via trip tank. Page 41/51 Report Printed: 2/10/2016 Operations Summary (with TimelogDepths) 4 ' 0124k ' 2S-01 ConocoPhriiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/16/2016 1/16/2016 0.75 PROD1 CASING BHAH P Monitor well at 397'MD,recover 2.39" 397.0 214.0 11:15 12:00 OD Drift on top of jars.Change out PS -21 slip inserts to hand slips.PJSM lay out BHA,pick up single 4"HWDP drift with 2.39"OD steel drift. Lay down jars,drift last stand of HWDP with 2.39"OD steel drift.Monitor displacement via trip tank. Pull out of hole to 214'MD. 1/16/2016 1/16/2016 2.25 PROD1 CASING BHAH P Continue to lay down BHA#5 as per 214.0 0.0 12:00 14:15 DD from 214' MD to 106'MD. Remove radioactive source from ADN. Continue tripping out of hole with BHA to surface while monitoring displacement via trip tank. 1/16/2016 1/16/2016 0.50 PROD1 CASING SVRG P Clean and clear rig floor. 0.0 0.0 14:15 14:45 Concurrently,maneuver BHA in pipeshed and install 4"slip inserts. 1/16/2016 1/16/2016 1.25 COMPZN CASING PULD P Make up mule shoe and run in hole 0.0 1,658.0 14:45 16:00 with 4"HWDP to 1658'MD while monitoring displacement via TripTank. 1/16/2016 1/16/2016 1.00 COMPZN CASING SLPC P Hang off blocks to cut and slip 86' 1,658.0 1,658.0 16:00 17:00 6x19 ext imp plow steel drill line. Monitor well via trip tank. 1/16/2016 1/16/2016 0.75 COMPZN CASING SVRG P Service top drive,blocks and crown. 1,658.0 1,658.0 17:00 17:45 Calibrate Amphion,TOTCO,and SLB block height. 1/16/2016 1/16/2016 0.50 COMPZN CASING CIRC P Circulate 4"HWDP while reciprocating 1,658.0 1,658.0 17:45 18:15 from 1658'MD to 1565'MD. 1/16/2016 1/16/2016 1.75 COMPZN CASING TRIP P Pull out of hole racking back 4"HWDP 1,658.0 0.0 18:15 20:00 from 1658'MD to surface while monitoring displacement via Trip Tank. 1/16/2016 1/16/2016 1.75 COMPZN CASING RURD P Rig up to run liner while staging frac 0.0 0.0 20:00 21:45 sleeves and swell packers in pepeshed. Verify pipe count.Hold PJSM on picking up liner. 1/16/2016 1/17/2016 2.25 COMPZN CASING PUTB P Run in hole with 4-1/2"12.6#, L-80 0.0 1,114.0 21:45 00:00 IBT with torque rings to 1114'MD. Baker lock connections below float collar.Check floats(Good). Monitor displacment via trip tank. 1/17/2016 1/17/2016 6.00 COMPZN CASING PUTB P Run 4.5"12.6ppf L-80 IBT-M with 1,114.0 4,590.0 00:00 06:00 torque rings from 1,114'MD to 4,590' MD. Make up to 4,500 ft/lbs. Fill each joint on the fly and top off every 10 jts. Change out Joint#80 with Joint#316 due to an egged collar.Monitor displacement via trip tank. 1/17/2016 1/17/2016 6.00 COMPZN CASING PUTB P Run 4.5"12.6ppf L-80 IBT-M with 4,590.0 8,711.0 06:00 12:00 torque rings from 4,590'MD to 8,711' MD. Make up to 4,500 fUlbs. Fill each joint on the fly and top off every 10 jts. Monitor displacement via trip tank. PU wt=103k,SO wt=74k. Page 42/51 Report Printed: 2/10/2016 p ; h ,F • • Operations Summary (with Timelog Depths) ,ate 2S-01 Conoco Phil ips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS).,. 1/17/2016 1/17/2016 1.00 COMPZN CASING PUTB P Run 4.5"12.6ppf L-80 IBT-M with 8,711.0 9,247.0 12:00 13:00 torque rings from 8,711'MD to 9,247' MD. Make up to 4,500 ft/lbs. Fill each joint on the fly and top off every 10 its. Monitor displacement via trip tank. 1/17/2016 1/17/2016 1.00 COMPZN CASING OTHR P Change out elevators,tongs,and slip 9,247.0 9,425.0 13:00 14:00 inserts. Pick up and make up Seal Bore Extension and Liner hanger.Rig down liner equipment 1/17/2016 1/17/2016 1.25 COMPZN CASING CIRC P Kelly up to stand#1 and circulate liner 9,425.0 9,425.0 14:00 15:15 volume staging up to 5 BPM.2BPM= 130psi, 10%flow out;3 BPM=255psi, 11%flow out.,4 BPM=430psi, 14% flow out.5 BPM=630psi, 17%flow out. Blow down top drive. Mud wt in and out=12 ppg. PU wt=109k and SO wt=80k 1/17/2016 1/17/2016 1.50 COMPZN CASING RUNL P Run in hole on drill pipe from 9,425' 9,425.0 12,574.0 15:15 16:45 MD to 12,574'MD.Fill on fly and top off every 10 joints.Monitor displacement via Pit#2. 1/17/2016 1/17/2016 3.75 COMPZN CASING DISP P Displace well to 10.5ppg Kla-Shield. 12,574.0 12,574.0 16:45 20:30 Pump 90 bbl high viscosity pill and chase with Kla-Shield while maintaining pressure under 900 psi. Final Circulating Pressure @ 4BPM= 865psi. 1/17/2016 1/17/2016 1.00 COMPZN CASING OWFF P Obtain torque and drag parameters. 12,574.0 12,754.0 20:30 21:30 PU wt= 142k,SO wt=96k,Rot wt=119k with 10 RPM,6.7k TQ. Rack back stand,blow down top drive and monitor well for 30 min(static) 1/17/2016 1/18/2016 2.50 COMPZN CASING RUNL P Continue to run in hole on drill pipe 12,574.0 15,484.0 21:30 00:00 from 12,574'MD to 15,484'MD. Fill on fly and top off every 10 joints. Monitor displacement via trip tank. 1/18/2016 1/18/2016 0.50 COMPZN CASING RUNL P Run 4-1/2"liner in hole on 4"DP from 15,484.0 15,505.0 00:00 00:30 15,484'MD to 15,505'MD.PU wt=170k,SO wt=77k. Liner began to take weight on stand#66(PU=230k, SO wt=40k). Unable to go down or break over picking up. 1/18/2016 1/18/2016 5.50 COMPZN CASING RUNL T Rack back stand#66 and pick up a 15,505.0 15,505.0 00:30 06:00 wild single. Continue to work pipe from 40k to 230k with no success. After working pipe for 2 hours,attempt to establish circulation with 1 BPM, 850-990psi.,0%flow out while working pipe(no success-pipe not free). Rotating and reciprocating with maximum torque limit set to 10k ft/lbs (as per Baker Rep)continue to work pipe(no success-pipe not free). PU wt=250k to 260k,SO wt=40k, Rotation= 10 RPM,TQ=9.5k Page 43/51 Report Printed: 2/10/2016 !perations Summary (with Timelog Depths) 2S-01 C_'c nocoPhinips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time i End Time Dur(hr) Phase Op Code;, Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/18/2016 1/18/2016 4.00 COMPZN CASING OTHR T Continue to work tight hole from 15,505.0 15,505.0 06:00 10:00 15,505'MD to 15,484'MD increase weight pulled to 300k,310k,320k, 330k,340k up to 346k and down weights of 40k.Pipe broke over at 346k and PU weight fell off to 230k and eventually falls to 192k. Rack back stand#65. 1/18/2016 1/18/2016 2.00 COMPZN CASING PMPO T Pump out of hole from 15,505'MD to 15,505.0 14,892.0 10:00 12:00 14,892'MD with 0.5 BPM,550psi- 345psi,0%flow out. PU wt=178k,SO wt=77k. 1/18/2016 1/18/2016 3.50 COMPZN CASING PMPO T Continue to pump out of hole from 14,892.0 12,573.0 12:00 15:30 14,892'MD to 12,573'MD. Pump @ 1 BPM, 100-220psi. Observed additional PU wt(-increase of 20k) each time a packer entered the Kalubik. Monitor displaceement via pit #3. PU wt=146k,SO wt=105k. 1/18/2016 1/18/2016 0.50 COMPZN CASING OWFF T Observe well for flow for 30min 12,573.0 12,573.0 15:30 16:00 (static). Concurrently,blow down top drive and clean floor. 1/18/2016 1/19/2016 8.00 COMPZN CASING CIRC T Circulate and condition while 12,573.0 12,488.0 16:00 00:00 reciprocating from 12,573'MD to 12,488'MD @ 5 BPM,895psi, 16% flow out while waiting on brine for displacement. 1/19/2016 1/19/2016 3.00 COMPZN CASING CIRC T Spot 45 BBL hi-vis spacer pill while 12,488.0 12,011.0 00:00 03:00 POOH from 12,488'to 12011'MD @ 5 BPM,658 psi, 16%flow out. Chase with 520 BBL 11.8 PPG NaCI brine at 5 BPM,520 PSI. 1/19/2016 1/19/2016 2.00 COMPZN CASING PULL T POOH w/DP on elevators from 12011 12,011.0 9,330.0 03:00 05:00 to 9330'MD. LD Baker Liner Hanger. PU= 116K,SO=76K. 1/19/2016 1/19/2016 4.00 COMPZN CASING PULL T POOH w/4-1/2"Lower Completion f/ 9,330.0 8,545.0 05:00 09:00 9330'-8545'MD. Torque rings damaged f/joint 301-286. 1/19/2016 1/19/2016 0.50 COMPZN CASING SVRG T Service and inspect top drive. 8,545.0 8,545.0 09:00 09:30 1/19/2016 1/19/2016 1.25 COMPZN CASING RGRP T Had leak on hydraulic hose on pipe 8,545.0 8,545.0 09:30 10:45 skate. C/O hose and complete top drive inspection. 1/19/2016 1/20/2016 13.25 COMPZN CASING PULL T Cont.POOH w/4-1/2"Lower 8,545.0 380.0 10:45 00:00 Completion f/8545'-380'MD. Multiple torque rings damaged f/joint 277-148. Swell packers are worn on the packer body and on the rubber sub ends. The top three swell packers have sever wear and missing sections on the rubber end pieces down to the base pipe. Last packer layed down had a groove gouged down the side of the element. 1/20/2016 1/20/2016 1.25 COMPZN CASING PULL T Cont.POOH w/4-1/2"Lower 380.0 0.0 00:00 01:15 Completion f/380'MD to surface. Page 44/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01, C ono oPhiliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/20/2016 1/20/2016 0.50 COMPZN CASING OWFF T Monitor well 30 minutes. 0.0 0.0 01:15 01:45 1/20/2016 1/20/2016 0.50 COMPZN CASING PULL T PJSM. Heat Bakerloc'd shoe track 0.0 0.0 01:45 02:15 and break float collar connection. Lay down shoe track. 1/20/2016 1/20/2016 2.25 COMPZN WHDBOP RURD T RU for BOP test. Wash stack with 0.0 0.0 02:15 04:30 stack washer tool. Pull wear bushing and set upper test plug. Fill BOP's with H2O and hold BOP PJSM. 1/20/2016 1/20/2016 5.50 COMPZN WHDBOP RGRP T Attempting to isolate leak in BOPE 0.0 0.0 04:30 10:00 system. Change out bleeder and isolation valves on test pump. Locate 4"Demco kill line valve leaking. 1/20/2016 1/20/2016 5.75 COMPZN WHDBOP BOPE T Witness of test waived by AOGCC 0.0 0.0 10:00 15:45 inspector Johnnie Hill. Pressure test BOPE to 250/3,500 psi for 5 minutes on chart recorder using 3-1/2"and 4- 1/2"test joints.Test annular,2-7/8x5- 1/2"Upper and Lower pipe rams and Blind Rams. Manual operated and super choke tested to 250/2,000 psi for 5 minutes on chart recorder. Test choke valves 1-15,manual&auto choke,choke&kill manuals, HCR valves,4"valve on kill line,4"TIW,4" dart valve,and Upper&lower IBOP. 1/20/2016 1/20/2016 2.00 COMPZN WHDBOP OTHR T Change out saver sub. SIMOPS, 0.0 0.0 15:45 17:45 replace 4"Demco valve on kill line. 1/20/2016 1/20/2016 0.50 COMPZN WHDBOP BOPE T Retest 4"Demco valve on kill line to 0.0 0.0 17:45 18:15 250/3500 PSI for 5 minutes on chart recorder. 1/20/2016 1/20/2016 0.75 COMPZN WHDBOP RURD T Rig down test equipment. Drain stack, 0.0 0.0 18:15 19:00 pull test plug and install wear bushing. 1/20/2016 1/20/2016 1.50 COMPZN CASING BHAH T MU BHA#6 for clean out run. RIH to 0.0 233.0 19:00 20:30 233'MD. 1/20/2016 1/21/2016 3.50 COMPZN CASING TRIP T RIH from 233'to 7822'MD for clean- 233.0 7,822.0 20:30 00:00 out run. Losses for day=12.4 BBL 1/21/2016 1/21/2016 3.25 COMPZN CASING TRIP T Continue RIH from 7822'to 12515' 7,822.0 12,515.0 00:00 03:15 MD for clean-out run. Monitor well for 15 minutes. 1/21/2016 1/21/2016 1.75 COMPZN CASING SLPC T PJSM. Slip and cut drilling line. 12,515.0 12,515.0 03:15 05:00 1/21/2016 1/21/2016 1.00 COMPZN CASING MPDA T Remove trip nipple and install MPD 12,515.0 12,515.0 05:00 06:00 bearing prior to mud swap and clean- out run. 1/21/2016 1/21/2016 3.25 COMPZN CASING DISP T Displace well by pumping 63 BBL 11.5 12,515.0 12,515.0 06:00 09:15 PPG KlayShield hi vis spacer followed by 579 BBL of 10.5 PPG Klayshield mud at 200 GPM w/270 PSI back pressure on MPD choke. Work pipe from 12515'to 12574'MD. Obtain SPR's at 12574'MD,6206'TVD w/ 10.7 PPG mud. #1 MP-20/30 SPM =540/700 PSI. #2 MP-20/30 SPM= 500/680 PSI. Page 45/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1/21/2016 1/21/2016 2.75 COMPZN CASING WASH T Wash down from 12515 to 12685'MD. 12,515.0 12,574.0 09:15 12:00 Worked tight spots at 12616, 12644 and 12685'MD. Packed off at 12644' and 12685'. POOH from 12685'to 12574. Reduce back pressure on MPD choke to 0 PSI. 1/21/2016 1/21/2016 0.50 COMPZN CASING CIRC T Circulate at shoe the obtain 12,574.0 12,574.0 12:00 12:30 parameters. .5 BPM=340 PSI, 1 BPM=415 PSI, 1.5 BPM=490 PSI,2 BPM=580 PSI,2.5 BPM=675 PSI, 3.0 BPM=775 PSI,3.5 BPM=900 PSI,4 BPM=1045 PSI,5 BPM= 1475 PSI,6 BPM=1900 PSI. 1/21/2016 1/21/2016 5.00 COMPZN CASING REAM T Wash and ream from 12574'to 13079' 12,574.0 13,463.0 12:30 17:30 MD. Encountered packoff at 12721' MD. Worked down to 13079'MD. Wash and ream from 13079 to 13463' MD at 5 BPM, 1475 PSI,50 RPM, 10 —13K TQ. 1/21/2016 1/21/2016 2.75 COMPZN CASING CIRC T Circulate bottoms up while Rotating 13,463.0 13,550.0 17:30 20:15 and Recip from 13550—13460'MD at 250 GPM, 1865 PSI. PU—196K,SO= 101K. 1/21/2016 1/22/2016 3.75 COMPZN CASING SMPD T Strip in hole while holding 250 PSI 13,550.0 16,311.0 20:15 00:00 annular back pressure from 13550'to 16311'MD. Sat down at 14383 and worked thru with 3 BPM,50 RPM. Wiped w/o rotary and pump after. Stacked out w/block weight at 15054', 15333', 15679', 15722' 15845', 15864', 15910',and 15920' Wiped each spot and continued thru OK. PU =240K,SO=65K. 1/22/2016 1/22/2016 1.00 COMPZN CASING SMPD T Continue stripping in hole from 16311' 16,311.0 16,590.0 00:00 01:00 to 16590'MD holding 250 PSI backpressure. Drag was becoming excessive and couldn't RIH without pumping and rotating. PU=204K,SO =70K,ROT= 140K. 1/22/2016 1/22/2016 9.50 COMPZN CASING REAM T Wash and ream holding 250 PSI 16,590.0 20,568.0 01:00 10:30 backpressure from 16590'to 20568' MD pumping 4 BPM @ 1550 PSI, 23%FO,15 RPM, 14K TQ,PU=223, SO=62K, Rot=124K. 1/22/2016 1/22/2016 7.75 COMPZN CASING CIRC T Circulate while rotate and recip from 20,568.0 20,070.0 10:30 18:15 20568 to 20070'MD @ 6.5 BPM, 2970 PSI,23%FO, 140 RPM, 16.5K TQ. Total pumped=25450 strokes. MW IN/OUT=10.5 PPG. PU=229K, SO=75K,ROT=127 K @ 15K TQ. 1/22/2016 1/22/2016 0.25 COMPZN CASING CIRC T Obtain Slow Pump Rates @ 20070', 20,070.0 20,070.0 18:15 18:30 6400'TVD,MW= 10.5 PPG. #1 MP- 20/30 SPM=875/1135 PSI. #2 MP— 20/30 SPM=850/1130 PSI. Blow down topdrive. 1/22/2016 1/23/2016 5.50 COMPZN CASING SMPD T Strip Out of Hole w/350 PSI 20,070.0 13,843.0 18:30 00:00 backpressure from 20700 to 13843" MD. PU=210K,SO=103K. Loss for past 24 hrs=47.5 BBLS Page 46/51 Report Printed: 2/10/2016 !perations Summary (with Timelog Depths) 2S-01 ConocoPhitiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK8) 1/23/2016 1/23/2016 1.75 COMPZN CASING SMPD T Continue to strip out of hole at 50 FPM 13,843.0 12,505.0 00:00 01:45 w/350 PSI backpressure from 13843' to 12505' MD. Observe 15-20K overpull at 12930'&12723'MD. Wipe both spots clean. PU=210K,SO= 106K. 1/23/2016 1/23/2016 2.25 COMPZN CASING CIRC T Circulate 2 BU while recip&rotate f/ 12,505.0 12,505.0 01:45 04:00 12510'to 12415'MD @ 6 BPM,2002 PSI, 19%FO, 140 RPM, 10K TQ, Total 9222 stks. 1/23/2016 1/23/2016 1.75 COMPZN CASING SMPD T RIH f/12505'to 13460'MD holding 12,505.0 13,460.0 04:00 05:45 250 PSI on backside. Took weight at 12593', 12620'and 12742. Picked up and dropped thru ok. 1/23/2016 1/23/2016 1.25 COMPZN CASING SMPD T Stripped OOH holding 350 on 13,460.0 12,505.0 05:45 07:00 backside f/13460'to 12505'MD to inside of shoe. Hole in good shape. PU=205K,SO=103K. 1/23/2016 1/23/2016 5.50 COMPZN CASING CIRC T Circ 2 BU while recip and rotate from 12,505.0 11,397.0 07:00 12:30 12510'to 11937'MD @ 6 BPM, 1989 PSI, 140 RPM for a total of 7958 strokes. Pump 50 BBLs of 11.8 PPG hi vis brine spacer followed by 535 BBLs of 12 PPG brine @ 6 BPM, 1490 PSI,22%FO,60 RPM,8K TQ. 1/23/2016 1/23/2016 0.75 COMPZN CASING MPDA T Blow down topdrive,pull MPD bearing 11,937.0 11,937.0 12:30 13:15 and install trip nipple. Monitor well for 30 min. 1/23/2016 1/23/2016 4.50 COMPZN CASING TRIP T POOH f/11937'to 233'MD. 11,937.0 233.0 13:15 17:45 1/23/2016 1/23/2016 1.00 COMPZN CASING BHAH T LD BHA and rack back HWDP from 233.0 0.0 17:45 18:45 233'to surface. 1/23/2016 1/23/2016 0.50 COMPZN CASING BHAH T Clean&clear rig floor 0.0 0.0 18:45 19:15 1/23/2016 1/23/2016 1.00 COMPZN CASING RURD T RU to run 4-1/2"Lower Completion 0.0 0.0 19:15 20:15 and hold PJSM. 1/23/2016 1/24/2016 3.75 COMPZN CASING PUTB T RIH with shoe track. Check floats/OK. 0.0 1,353.0 20:15 00:00 Continue to 1353'MD making up 4- 1/2"IBT-m connections with Tesco torque rings to 7K TQ. Deformed ring in joint 26 and pinched pin on joint 27. LD jts 26&27 and replaced with joints 197&198. Deformed ring in joint 28 and pinched pin on joint 29. Replaced with joints 199&200. When changing out joint 28,noted that box in 198 drifted to 3.75'and pin was still 3.833. Called town and decision made to reduce MU torque to 4.5K. 1/24/2016 1/24/2016 9.00 COMPZN CASING PUTB T Continue RIH with 4-1/2", 12.6#, L-80, 1,353.0 7,994.0 00:00 09:00 IBT-M Lower Completion w/Tesco Torque rings from 1353'-7994'MD. Torque all connections to 4.5K Ft-Lbs. 1/24/2016 1/24/2016 1.00 COMPZN CASING OTHR T Make up Baker Liner Hanger w/ 7,994.0 8,073.0 09:00 10:00 packer. Install PAL mix and X/O to drillpipe. RIH f/7994'to 8073'MD. Page 47/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) . "' 2S-01 shimps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time " End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/24/2016 1/24/2016 1.00 COMPZN CASING CIRC T Get running parameters. Pumped 3 8,073.0 8,073.0 10:00 11:00 BPM @ 193 PSI,6 BPM @ 630 PSI. Torque at 3 BPM and 10 RPM=3.6K, @ 15 RPM=3.9K,20 RPM=4.3 K. Pumps off Torque @ 10 RPM=3.1K, 15 RPM=3.5K,20 RPM=3.9K. PU =99K,SO=86K,ROT=91K. 1/24/2016 1/24/2016 3.00 COMPZN CASING RUNL T RIH with Lower Completion on 8,073.0 12,527.0 11:00 14:00 drillpipe from 8073'to 12527'MD'. Fill on the fly and top off every 10 stands. 1/24/2016 1/24/2016 0.50 COMPZN CASING MPDA T Remove trip nipple and install MPD 12,527.0 12,527.0 14:00 14:30 bearing. Line up to MPD skid. 1/24/2016 1/24/2016 0.75 COMPZN CASING CIRC T Get running parameters in brine 12,527.0 12,527.0 14:30 15:15 before swap to mud. 1 BPM/80 PSI,2 BPM/170 PSI,3 BPM/489 PSI,5 BPM/680 PSI. Torque at 3 BPM and 10 RPM=6.7K,@ 15 RPM=7K,20 RPM=7.5K. Pumps off Torque @ 10 RPM=6.5K, 15 RPM=7K,20 RPM= 7.5K. PU=145K,SO=96K,ROT= 120K. 1/24/2016 1/24/2016 3.00 COMPZN CASING DISP T Displace well to 10.5 PPG Klayshield 12,527.0 12,527.0 15:15 18:15 Mud w/3%Lubes while recip f/12569' to 12520'MD. Pumped 49 BBL hi vis spacer ahead and 550 BBLs mud. 1/24/2016 1/24/2016 0.75 COMPZN CASING CIRC T Get running parameters in 10.5 PPG 12,527.0 12,527.0 18:15 19:00 Klayshield Mud. Pumps off Torque @ 10 RPM=7K, 15 RPM=7K,20 RPM =7.5K. PU=140K,SO WT=98K, ROT WT= 117K. 1/24/2016 1/24/2016 2.25 COMPZN CASING RUNL T Strip in hole with Lower Completion on 12,527.0 15,505.0 19:00 21:15 drillpipe into open hole from 12527'- 15505'MD. Off Trouble time at this depth. Fill on the fly and top off every 10 stands. 1/24/2016 1/25/2016 2.75 COMPZN CASING RUNL P Strip in hole with Lower Completion on 15,505.0 17,455.0 21:15 00:00 drillpipe from 15505'—17455 MD. Fill on the fly and top off every 10 stands. Wash down from 16,510'to 16695' MD. 1/25/2016 1/25/2016 10.50 COMPZN CASING RUNL P Continue stripping while holding 250 17,455.0 20,440.0 00:00 10:30 PSI backpressure and washing in hole with Lower Completion on drillpipe from 17455'—20440'MD. PU single and wash down to 20470'MD. Page 48/51 Report Printed: 2/10/2016 Operations Summary (with Timelog Depths) 2S-01 OS Conoco`Phillips p Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/25/2016 1/25/2016 2.50 COMPZN CASING PACK P PU to to 20449'MD to place DP in 20,440.0 20,440.0 10:30 13:00 tension. Drop 1.25"ball to close WIV and set Baker Liner Hanger. Pump ball down @ 4 BPM, 1433 PSI. Ball on seat @ 2323 stks,pres to 1100 PSI to close WIV. Continue to 3700 PSI and set hanger. Bleed pres to 2000 PSI and slack off to block wt.to verify hanger set. PU to release dogs from hanger. Set down string wt.on hanger and set liner top packer. PU and rotate @ 15 RPM,6.5K TQ and set down again to insure packer set. PU drillpipe to neutral wt.,close annular preventer and pres up on annulus to 3500 PSI. Good test. Charted for 10 minutes. 1/25/2016 1/25/2016 0.50 COMPZN WELLPR PULD P Blow down top drive. Lay down two 12,408.0 12,408.0 13:00 13:30 singles,End of liner running tool @ 12408'MD,inside of liner hanger. RU to reverse circulate well to seawater. 1/25/2016 1/25/2016 1.75 COMPZN WELLPR CIRC P Pump 50 BBL hi-vis sweep followed 12,408.0 12,408.0 13:30 15:15 by 560 BBLs.seawater @ 8 BPM, 1710 PSI final. 1/25/2016 1/25/2016 0.25 COMPZN WELLPR TRIP P 'POOH f/12408'to 12313'MD. RU to 12,408.0 12,313.0 15:15 15:30 circulate bottoms up. 1/25/2016 1/25/2016 2.00 COMPZN WELLPR CIRC P Circ 3 BU while rotate and recip f/ 12,313.0 12,313.0 15:30 17:30 12313'to 12219'MD @ 485 GPM, 3010 PSI. Total pumped=12015 strokes. MW in/out=8.7 PPG. PU= 173K,SO=133K. 1/25/2016 1/25/2016 1.50 COMPZN WELLPR SLPC P Cut&slip drill line. 12,313.0 12,313.0 17:30 19:00 1/25/2016 1/25/2016 0.50 COMPZN WELLPR SVRG P Service topdrive,blocks and crown. 12,313.0 12,313.0 19:00 19:30 1/25/2016 1/25/2016 0.75 COMPZN WELLPR MPDA P Remove MPD bearing and install trip 12,313.0 12,313.0 19:30 20:15 nipple. 1/25/2016 1/25/2016 2.25 COMPZN WELLPR PULD P POOH and LD HWDP from 12313'to 12,313.0 10,530.0 20:15 22:30 10530'MD. LD 60 joints of HWDP. 1/25/2016 1/26/2016 1.50 COMPZN WELLPR PULD P POOH and LD drillpipe from 10530'to 10,530.0 9,080.0 22:30 00:00 9080'MD. LD 45 joints of drillpipe. 1/26/2016 1/26/2016 9.75 COMPZN WELLPR PULD P Cont.to POOH and LD DP from 9080 9,080.0 0.0 00:00 09:45 to 60'MD,290 joints. LD Baker liner running tool. Tool was sheared indicating good set. 1/26/2016 1/26/2016 4.25 COMPZN WELLPR TRIP P Clear rig floor. PJSM. RIH w/4"DP 0.0 10,988.0 09:45 14:00 out of derrick from surface to 10988' MD,350 jts of DP. PU=140K,SO= 107K. 1/26/2016 1/27/2016 10.00 COMPZN WELLPR PULD P POOH and lay down drillpipe from 10,988.0 571.0 14:00 00:00 10988'to 571',332 joints of DP. 1/27/2016 1/27/2016 0.50 COMPZN WELLPR PULD P Continue to LD drillpipe from 571'MD 571.0 0.0 00:00 00:30 to Surface, 18 joints. 1/27/2016 1/27/2016 1.50 COMPZN RPCOMP RURD P Drain stack,pull wear ring and flush 0.0 0.0 00:30 02:00 stack with stack washer. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP SFTY P PJSM to run 3.5",9.3#Upper 0.0 0.0 02:00 02:30 Completion. Page 49/51 Report Printed: 2/10/2016 Iterations Summary (with Timelog 6epths) kr�3r F�S+4y3'% Y uko 2S-01 c onc.tcoPh iiip Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr)r. Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 1/27/2016 1/27/2016 1.00 COMPZN RPCOMP RURD P RU tongs,C/O slip inserts,hang 0.0 0.0 02:30 03:30 sheave for gauge wire. 1/27/2016 1/27/2016 0.75 COMPZN RPCOMP PUTB P Run 3.5",9.3#Upper Completion per 0.0 150.0 03:30 04:15 tally to 150'MD. Splice in Schlumberger gauge assembly and test. Torque all connections to 2240' MD. 1/27/2016 1/27/2016 14.50 COMPZN RPCOMP PUTB P Run 3.5",9.3#Upper Completion per 150.0 8,022.0 04:15 18:45 tally installing Cannon clamps every connection and testing gauge every 1000'MD to from 150'to 8022'MD. 1/27/2016 1/27/2016 2.75 COMPZN RPCOMP PUTB T Splice gauge wire to start on 2nd 8,022.0 8,022.0 18:45 21:30 spool. Test continuity and gauge. 1/27/2016 1/28/2016 2.50 COMPZN RPCOMP PUTB P Continue running 3.5",9.3#Upper 8,022.0 9,790.0 21:30 00:00 Completion per tally installing Cannon clamps every connection and testing gauge every 1000'MD from 8022'to 9790'MD. 1/28/2016 1/28/2016 6.00 COMPZN RPCOMP PUTB P Continue running 3.5",9.3#Upper 9,790.0 12,453.0 00:00 06:00 Completion per tally installing Cannon clamps every connection and testing gauge every 1000'MD from 9790'to 12453'MD. Tag up on liner top and observe shear of pins on locator sub. No-Go out on depth w/locator sub @ 12388'MD. Determine space out and LD jt#386 for corrosion inhibitor circ. PU=111K,S0=77K 1/28/2016 1/28/2016 0.75 COMPZN RPCOMP CIRC P Pump 10 BBLS of inhibited brine 12,453.0 12,453.0 06:00 06:45 followed by 106 BBLS of 8.6 brine at 3 BPM,340 PSI. Total pumped=1151 Strokes. 1/28/2016 1/28/2016 1.00 COMPZN RPCOMP HOSO P Lay down tubing joints#385,384& 12,453.0 12,449.0 06:45 07:45 383. PU 3.5"space out pups 10.24', 10.15'&6.15',one joint of 4.5'tubing and tubing hanger w/pup joint. 1/28/2016 1/28/2016 2.25 COMPZN RPCOMP THGR P Terminate TEC wire and feed through 12,449.0 12,449.0 07:45 10:00 hanger. Test control line in hanger to 5000 psi for 15 minutes. Good test. Drain stack,make up landing joint and land hanger. Drop ball and rod. Run in Lock Down ScrewsTest upper and lower hanger seals to 5000 PSI for 15 minutes. Good test. 1/28/2016 1/28/2016 2.50 COMPZN RPCOMP PRTS P Pressure up tubing to 1450 PSI and 12,449.0 12,449.0 10:00 12:30 set packer. Pressure tubing to 4500 PSI for 30 minutes,charted. Good test. Bleed tubing down to 2500 PSI. PT IA to 4000 PSI for 30 minutes, charted. Good test. Bleed IA and TBG to 0 PSI. Pres up on IA to 2600 PSI and shear SOV. Confirm sheared with 2 BPM,500 PSI circulated. 1/28/2016 1/28/2016 0.25 COMPZN RPCOMP RURD P RD landing jt and blow down lines 12,449.0 12,449.0 12:30 12:45 1/28/2016 1/28/2016 0.75 COMPZN WHDBOP MPSP P Dry rod in BPV and test f/below to 12,449.0 12,449.0 12:45 13:30 2500 PSI for 10 minutes,charted. Good. Page 50/51 Report Printed: 2/10/2016 !perations Summary (with Timelog epths) frit 2S-01 conocophmos Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time ' End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation ((KB) End Depth MB) 1/28/2016 1/28/2016 0.50 COMPZN WHDBOP OWFF P Monitor well for 30 min. Hold PJSM 12,449.0 12,449.0 13:30 14:00 for ND BOP's. 1/28/2016 1/28/2016 2.50 COMPZN WHDBOP NUND P Pull power slips,clean out Joes box, 12,449.0 12,449.0 14:00 16:30 rig down flow line,choke&kill lines. ND BOP's. Remove spacer spool& adapter spool. 1/28/2016 1/28/2016 2.75 COMPZN WHDBOP NUND P Clean well head and cellar box. Run 12,449.0 12,449.0 16:30 19:15 TEC wire thru adapter flange and NU adapter flange to tubing head. Install test sub on adapter flange. 1/28/2016 1/28/2016 1.50 COMPZN WHDBOP PRTS P CIW performed pre-test adapter flange 12,449.0 12,449.0 19:15 20:45 connection to 10000 PSI. Test upper tubing hanger seals and TEC wire seals to 250/5000 PSI for 15 minutes,witnessed. 1/28/2016 1/28/2016 2.25 COMPZN WHDBOP NUND P Install test plug into BPV. Nipple up 12,449.0 12,449.0 20:45 23:00 10K CIW tree. 1/28/2016 1/29/2016 1.00 COMPZN WHDBOP PRTS P Load tree with diesel. Prep to 12,449.0 12,449.0 23:00 00:00 pressure test 1/29/2016 1/29/2016 2.50 COMPZN WHDBOP PRTS P Pres test tree at 250/5000 PSI for 15 12,449.0 12,449.0 00:00 02:30 min each,charted. Bring pres up to 10000 PSI w/CIW pump and test for 15 min. Witnessed by Pat Archey. 1/29/2016 1/29/2016 3.50 COMPZN WHDBOP MPSP T Attempt to dry rod out CIW Type HG 12,449.0 12,449.0 02:30 06:00 TWC. It became stuck in the lift thread area below the lower master valve. Closed lower master valve and removed upper tree and remove TWC. Re-nipple up tree. 1/29/2016 1/29/2016 1.50 COMPZN WHDBOP PRTS T Re-test tree to 5000 PSI charted and 12,449.0 12,449.0 06:00 07:30 10000 PSI witnessed. 1/29/2016 1/29/2016 3.25 COMPZN WHDBOP FRZP P Freeze protect tubing and annulus by 12,449.0 12,449.0 07:30 10:45 pumping 72 BBLs of diesel down annulus and u-tubing into tubing, charted. Allowed to equalize for 1 hour. Verify 0 PSI on tubing and annulus. 1/29/2016 1/29/2016 1.00 COMPZN WHDBOP MPSP P Dry rod BPV per Cameron. RR @ 12,449.0 12,449.0 10:45 11:45 1200 1/29/2016 1/29/2016 0.25 DEMOB MOVE DMOB P Prepare to move off location from 2S- 12,449.0 11:45 12:00 01 to 2S-03 Page 51/51 Report Printed: 2/10/2016 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-01 2S-01 Definitive Survey Report 19 January, 2016 • Schlumberger 1 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig:120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 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-01 Well Position +N/-S 0.00 usft Northing: 5,930,036.15 usfl Latitude: 70°13'12.058 N +El-W 0.00 usft Easting: 481,309.01 usfl Longitude: 150°9'2.839 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-01 Magnetics mel Name Sample Date Declination Dip Angle"-' :' • Field Strength _..... .::., (°) (°) (nT) BGGM2015 12/30/2015 18.42 80.86 57,486 Design 2S-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.61 Vertical Section: Depth From(TVD) +NI-S +E./.-W DiftitetiOrt, (usft) ( ) (0) 39.61 0.00 0.00 195.00 Survey Program Date From To (usft) ,,Staft) Su c(Wellbore) Tool Name Description Survey Date 84.00 839.00 2S-01 Srvy#1 -GYD-GC-SS(2S-01) GYD-GC-SS Gyrodata gyro single shots 12/17/2015 9:1 863.34 2,889.66 2S-01 Srvy#2-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/17/2015 9: 2,969.65 5,955.96 2S-01 Srvy#3-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/22/2015 11 6,046.37 12,512.12 2S-01 Srvy#4-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2015 10. 12,571.05 12,571.05 2S-01 Srvy#5-INC+TREND(2S-01) INC+TREND Inclinometer+known azi trend 1/7/2016 8:22. 12,666.66 21,659.83 2S-01 Srvy#6-GMAG(2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/8/2016 9:26 Map Map Verticaal MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DCS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.61 0.00 0.00 39.61 -120.00 0.00 0.00 5,930,036.15 481,309.01 0.00 0.00 UNDEFINED 84.00 0.61 294.79 84.00 -75.61 0.10 -0.21 5,930,036.25 481,308.80 1.37 -0.04 GYD-GC-SS(1) 118.50 0.66 294.99 118.50 -41.11 0.26 -0.56 5,930,036.41 481,308.45 0.15 -0.11 GYD-GC-SS(1) 16"x 20" 184.00 0.76 295.30 183.99 24.38 0.61 -1.30 5,930,036.76 481,307.72 0.15 -0.25 GYD-GC-SS(1) 276.00 1.08 300.08 275.98 116.37 1.30 -2.60 5,930,037.46 481,306.42 0.36 -0.58 GYD-GC-SS(1) 370.00 0.82 356.34 369.97 210.36 2.42 -3.41 5,930,038.57 481,305.61 0.98 -1.45 GYD-GC-SS(1) 462.00 2.52 54.48 461.93 302.32 4.25 -1.80 5,930,040.40 481,307.22 2.39 -3.64 GYD-GC-SS(1) 557.00 3.50 62.90 556.80 397.19 6.78 2.48 5,930,042.92 481,311.51 1.13 -7.19 GYD-GC-SS(1) 650.00 4.12 74.68 649.59 489.98 8.96 8.23 5,930,045.09 481,317.26 1.07 -10.78 GYD-GC-SS(1) 1/19/2016 8:42:43AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) , Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) .. 2S-01 North Reference: True Weill . ' 2S-01 Survey Calculation Method: Minimum Curvature l gn 2S-01 Database: OAKEDMP2 Si-MO Map, Map Vertical MD Inc AZi. TVD TVDSS *Ni-S +E/-W Northing Easting CLS Section (mitt) (0); (a) .., (usft) (usft) > (usft) (usft) (ft) (ft) (°/100)' (ft) Survey Tool Name 745.00 4.70 77.85 744.31 584.70 10.68 15.32 5,930,046.79 481,324.36 0.66 -14.28 GYD-GC-SS(1) 839.00 5.41 71.52 837.95 678.34 12.89 23.29 5,930,048.98 481,332.33 0.96 -18.48 GYD-GC-SS(1) 863.34 5.44 67.69 862.18 702.57 13.70 25.45 5,930,049.78 481,334.49 1.49 -19.82 MWD+IFR-AK-CAZ-SC(2) 958.04 6.22 63.52 956.39 796.78 17.69 34.19 5,930,053.75 481,343.25 0.94 -25.93 MWD+IFR-AK-CAZ-SC(2) 1,052.28 7.57 66.62 1,049.95 890.34 22.43 44.46 5,930,058.46 481,353.52 1.49 -33.17 MWD+IFR-AK-CAZ-SC(2) 1,146.12 8.95 65.38 1,142.81 983.20 27.92 56.77 5,930,063.93 481,365.85 1.48 -41.66 MWD+IFR-AK-CAZ-SC(2) 1,240.91 11.25 62.85 1,236.12 1,076.51 35.21 71.70 5,930,071.18 481,380.80 2.47 -52.57 MWD+IFR-AK-CAZ-SC(2) 1,335.43 15.64 62.42 1,328.03 1,168.42 45.33 91.21 5,930,081.24 481,400.33 4.65 -67.39 MWD+IFR-AK-CAZ-SC(2) 1,430.70 16.64 62.38 1,419.55 1,259.94 57.60 114.68 5,930,093.45 481,423.82 1.05 -85.31 MWD+IFR-AK-CAZ-SC(2) 1,524.30 18.13 64.66 1,508.87 1,349.26 70.04 139.72 5,930,105.84 481,448.89 1.75 -103.82 MWD+IFR-AK-CAZ-SC(2) 1,618.41 19.93 64.46 1,597.83 1,438.22 83.23 167.42 5,930,118.95 481,476.63 1.91 -123.72 MWD+IFR-AK-CAZ-SC(2) 1,713.85 21.53 65.92 1,687.09 1,527.48 97.38 198.09 5,930,133.03 481,507.33 1.76 -145.34 MWD+IFR-AK-CAZ-SC(2) 1,808.53 25.67 67.86 1,773.83 1,614.22 112.21 232.96 5,930,147.77 481,542.23 4.45 -168.68 MWD+IFR-AK-CAZ-SC(2) 1,903.85 29.11 68.07 1,858.46 1,698.85 128.65 273.61 5,930,164.11 481,582.91 3.61 -195.08 MWD+IFR-AK-CAZ-SC(2) 1,998.34 31.36 67.22 1,940.09 1,780.48 146.76 317.60 5,930,182.11 481,626.95 2.42 -223.96 MWD+IFR-AK-CAZ-SC(2) 2,093.33 34.19 66.72 2,019.95 1,860.34 166.88 364.92 5,930,202.11 481,674.31 2.99 -255.64 MWD+IFR-AK-CAZ-SC(2) 2,187.89 37.04 63.71 2,096.82 1,937.21 190.00 414.87 5,930,225.11 481,724.32 3.54 -290.91 MWD+IFR-AK-CAZ-SC(2) 2,282.23 40.05 62.07 2,170.60 2,010.99 216.81 467.18 5,930,251.78 481,776.68 3.37 -330.34 MWD+IFR-AK-CAZ-SC(2) 2,376.85 43.57 61.39 2,241.11 2,081.50 246.69 522.72 5,930,281.52 481,832.29 3.75 -373.58 MWD+IFR-AK-CAZ-SC(2) 2,470.82 44.76 60.58 2,308.52 2,148.91 278.45 579.97 5,930,313.14 481,889.61 1.40 -419.07 MWD+IFR-AK-CAZ-SC(2) 2,565.64 47.68 61.98 2,374.12 2,214.51 311.33 640.01 5,930,345.86 481,949.73 3.26 -466.37 MWD+IFR-AK-CAZ-SC(2) 2,660.48 49.36 62.69 2,436.93 2,277.32 344.31 702.94 5,930,378.68 482,012.73 1.86 -514.51 MWD+IFR-AK-CAZ-SC(2) 2,753.26 54.04 61.90 2,494.42 2,334.81 378.17 767.37 5,930,412.38 482,077.25 5.09 -563.89 MWD+IFR-AK-CAZ-SC(2) 2,849.33 56.31 62.11 2,549.28 2,389.67 415.18 837.01 5,930,449.21 482,146.96 2.37 -617.67 MWD+IFR-AK-CAZ-SC(2) 2,889.66 58.69 61.80 2,570.95 2,411.34 431.17 867.02 5,930,465.13 482,177.02 5.94 -640.88 MWD+IFR-AK-CAZ-SC(2) 2,951.00 59.06 60.33 2,602.66 2,443.05 456.58 912.97 5,930,490.42 482,223.03 2.13 -677.31 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2" 2,969.65 59.17 59.89 2,612.23 2,452.62 464.55 926.85 5,930,498.36 482,236.92 2.13 -688.61 MWD+IFR-AK-CAZ-SC(3) 3,022.65 60.47 61.03 2,638.88 2,479.27 487.14 966.71 5,930,520.84 482,276.83 3.08 -720.74 MWD+IFR-AK-CAZ-SC(3) 3,121.62 64.04 61.37 2,684.94 2,525.33 529.32 1,043.46 5,930,562.83 482,353.68 3.62 -781.35 MWD+IFR-AK-CAZ-SC(3) 3,211.94 66.32 61.52 2,722.86 2,563.25 568.51 1,115.46 5,930,601.83 482,425.77 2.53 -837.84 MWD+IFR-AK-CAZ-SC(3) 3,307.43 68.81 61.14 2,759.30 2,599.69 610.85 1,192.89 5,930,643.98 482,503.30 2.63 -898.78 MWD+IFR-AK-CAZ-SC(3) 3,403.45 69.15 61.47 2,793.74 2,634.13 653.88 1,271.51 5,930,686.82 482,582.02 0.48 -960.70 MWD+IFR-AK-CAZ-SC(3) 3,496.67 69.62 61.83 2,826.56 2,666.95 695.32 1,348.30 5,930,728.05 482,658.90 0.62 -1,020.59 MWD+IFR-AK-CAZ-SC(3) 3,590.88 69.61 61.69 2,859.37 2,699.76 737.10 1,426.10 5,930,769.64 482,736.79 0.14 -1,081.09 MWD+IFR-AK-CAZ-SC(3) 3,685.79 69.68 61.60 2,892.39 2,732.78 779.36 1,504.41 5,930,811.71 482,815.20 0.12 -1,142.18 MWD+IFR-AK-CAZ-SC(3) 3,780.39 69.67 62.07 2,925.25 2,765.64 821.23 1,582.61 5,930,853.38 482,893.50 0.47 -1,202.86 MWD+IFR-AK-CAZ-SC(3) 3,874.54 69.63 61.75 2,957.99 2,798.38 862.80 1,660.49 5,930,894.75 482,971.47 0.32 -1,263.17 MWD+IFR-AK-CAZ-SC(3) 3,968.93 70.14 60.83 2,990.45 2,830.84 905.38 1,738.22 5,930,937.13 483,049.30 1.06 -1,324.41 MWD+IFR-AK-CAZ-SC(3) 4,063.87 70.18 60.72 3,022.67 2,863.06 948.98 1,816.16 5,930,980.53 483,127.34 0.12 -1,386.70 MWD+IFR-AK-CAZ-SC(3) 1/19/2016 8:42:43AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) ' (usft) (usft) (ft) (ft) ('/100')', (ft) Survey Tool Name 4,157.78 69.66 61.97 3,054.91 2,895.30 991.27 1,893.56 5,931,022.63 483,204.83 1.37 -1,447.59 MWD+IFR-AK-CAZ-SC(3) 4,252.12 69.61 62.14 3,087.75 2,928.14 1,032.72 1,971.69 5,931,063.88 483,283.06 0.18 -1,507.84 MWD+IFR-AK-CAZ-SC(3) 4,346.55 69.58 62.70 3,120.67 2,961.06 1,073.70 2,050.13 5,931,104.66 483,361.60 0.56 -1,567.73 MWD+IFR-AK-CAZ-SC(3) 4,442.96 69.62 62.47 3,154.27 2,994.66 1,115.30 2,130.35 5,931,146.06 483,441.91 0.23 -1,628.68 MWD+IFR-AK-CAZ-SC(3) 4,536.26 69.58 63.31 3,186.80 3,027.19 1,155.15 2,208.19 5,931,185.71 483,519.84 0.84 -1,687.31 MWD+IFR-AK-CAZ-SC(3) 4,631.02 69.55 63.92 3,219.88 3,060.27 1,194.61 2,287.73 5,931,224.98 483,599.47 0.60 -1,746.02 MWD+IFR-AK-CAZ-SC(3) 4,729.75 69.58 64.11 3,254.35 3,094.74 1,235.15 2,370.90 5,931,265.30 483,682.73 0.18 -1,806.70 MWD+IFR-AK-CAZ-SC(3) 4,820.19 69.62 63.77 3,285.88 3,126.27 1,272.39 2,447.05 5,931,302.35 483,758.96 0.36 -1,862.38 MWD+IFR-AK-CAZ-SC(3) 4,913.24 69.65 63.16 3,318.26 3,158.65 1,311.36 2,525.09 5,931,341.12 483,837.10 0.62 -1,920.22 MWD+IFR-AK-CAZ-SC(3) 5,008.61 69.61 63.22 3,351.46 3,191.85 1,351.68 2,604.89 5,931,381.24 483,916.98 0.07 -1,979.82 MWD+IFR-AK-CAZ-SC(3) 5,102.60 69.55 63.10 3,384.25 3,224.64 1,391.45 2,683 48 5,931,420.82 483,995.67 0.14 -2,038.58 MWD+IFR-AK-CAZ-SC(3) 5,198.70 69.61 63.17 3,417.78 3,258.17 1,432.15 2,763.82 5,931,461.31 484,076.10 0.09 -2,098.68 MWD+IFR-AK-CAZ-SC(3) 5,293.66 69.75 62.73 3,450.75 3,291.14 1,472.65 2,843.13 5,931,501.61 484,155.50 0.46 -2,158.33 MWD+IFR-AK-CAZ-SC(3) 5,388.04 69.52 62.27 3,483.60 3,323.99 1,513.51 2,921.62 5,931,542.26 484,234.08 0.52 -2,218.10 MWD+IFR-AK-CAZ-SC(3) 5,481.73 69.58 61.69 3,516.33 3,356.72 1,554.74 2,999.11 5,931,583.31 484,311.67 0.58 -2,278.00 MWD+IFR-AK-CAZ-SC(3) 5,578.13 69.55 60.91 3,549.99 3,390.38 1,598.12 3,078.35 5,931,626.49 484,391.00 0.76 -2,340.40 MWD+IFR-AK-CAZ-SC(3) 5,670.05 69.65 60.86 3,582.03 3,422.42 1,640.04 3,153.61 5,931,668.22 484,466.37 0.12 -2,400.38 MWD+IFR-AK-CAZ-SC(3) 5,765.67 69.55 61.28 3,615.36 3,455.75 1,683.40 3,232.05 5,931,711.37 484,544.90 0.42 -2,462.56 MWD+IFR-AK-CAZ-SC(3) 5,859.37 69.62 61.52 3,648.05 3,488.44 1,725.43 3,309.15 5,931,753.21 484,622.10 0.25 -2,523.11 MWD+IFR-AK-CAZ-SC(3) 5,955.96 69.45 61.97 3,681.82 3,522.21 1,768.27 3,388.86 5,931,795.85 484,701.91 0.47 -2,585.12 MWD+IFR-AK-CAZ-SC(3) 6,046.37 69.74 62.21 3,713.34 3,553.73 1,807.94 3,463.74 5,931,835.32 484,776.88 0.41 -2,642.82 MWD+IFR-AK-CAZ-SC(4) 6,140.84 69.69 63.01 3,746.09 3,586.48 1,848.70 3,542.42 5,931,875.89 484,855.65 0.80 -2,702.56 MWD+IFR-AK-CAZ-SC(4) 6,235.41 69.79 62.91 3,778.84 3,619.23 1,889.04 3,621.44 5,931,916.02 484,934.76 0.14 -2,761.97 MWD+IFR-AK-CAZ-SC(4) 6,330.43 69.69 64.00 3,811.74 3,652.13 1,928.87 3,701.18 5,931,955.66 485,014.60 1.08 -2,821.08 MWD+IFR-AK-CAZ-SC(4) 6,424.80 69.80 62.81 3,844.42 3,684.81 1,968.51 3,780.35 5,931,995.09 485,093.85 1.19 -2,879.86 MWD+IFR-AK-CAZ-SC(4) 6,519.68 69.77 61.96 3,877.20 3,717.59 2,009.78 3,859.24 5,932,036.16 485,172.84 0.84 -2,940.14 MWD+IFR-AK-CAZ-SC(4) 6,615.12 69.63 61.40 3,910.31 3,750.70 2,052.24 3,938.04 5,932,078.43 485,251.73 0.57 -3,001.55 MWD+IFR-AK-CAZ-SC(4) 6,708.74 69.73 60.36 3,942.83 3,783.22 2,094.96 4,014.74 5,932,120.96 485,328.53 1.05 -3,062.67 MWD+IFR-AK-CAZ-SC(4) 6,803.27 69.73 61.76 3,975.58 3,815.97 2,137.87 4,092.34 5,932,163.67 485,406.22 1.39 -3,124.20 MWD+IFR-AK-CAZ-SC(4) 6,897.89 69.79 61.15 4,008.31 3,848.70 2,180.29 4,170.32 5,932,205.89 485,484.31 0.61 -3,185.36 MWD+IFR-AK-CAZ-SC(4) 6,992.20 69.86 60.16 4,040.84 3,881.23 2,223.68 4,247.48 5,932,249.08 485,561 57 0.99 -3,247.24 MWD+IFR-AK-CAZ-SC(4) 7,087.00 69.80 60.54 4,073.53 3,913.92 2,267.70 4,324.82 5,932,292.90 485,639.00 0.38 -3,309.77 MWD+IFR-AK-CAZ-SC(4) 7,181.53 69.82 60.61 4,106.15 3,946.54 2,311.29 4,402.09 5,932,336.30 485,716.38 0.07 -3,371.88 MWD+IFR-AK-CAZ-SC(4) 7,275.82 69.73 61.08 4,138.75 3,979.14 2,354.39 4,479.36 5,932,379.20 485,793.75 0.48 -3,433.51 MWD+IFR-AK-CAZ-SC(4) 7,370.63 69.63 61.55 4,171.67 4,012.06 2,397.06 4,557.36 5,932,421.68 485,871.84 0.48 -3,494.92 MWD+IFR-AK-CAZ-SC(4) 7,465.99 69.77 61.74 4,204.76 4,045.15 2,439.54 4,636.07 5,932,463.96 485,950.65 0.24 -3,556.32 MWD+IFR-AK-CAZ-SC(4) 7,564.31 69.74 63.46 4,238.78 4,079.17 2,481.99 4,717.96 5,932,506.20 486,032.64 1.64 -3,618.52 MWD+IFR-AK-CAZ-SC(4) 7,653.49 69.70 62.91 4,269.69 4,110.08 2,519.73 4,792.62 5,932,543.75 486,107.38 0.58 -3,674.29 MWD+IFR-AK-CAZ-SC(4) 7,749.38 69.71 63.31 4,302.95 4,143.34 2,560.40 4,872.83 5,932,584.22 486,187.68 0.39 -3,734.34 MWD+IFR-AK-CAZ-SC(4) 7,843.29 69.57 64.17 4,335.62 4,176.01 2,599.36 4,951.78 5,932,622.98 486,266.73 0.87 -3,792.40 MWD+IFR-AK-CAZ-SC(4) 1/19/2016 8:42:43AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig:120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey MapMap Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft), (usft) (usft) (usft) (ft) (ft) (01100') (ft) Survey Tool Name 7,938.35 69.74 63.70 4,368.67 4,209.06 2,638.52 5,031.85 5,932,661.94 486,346.88 0.50 -3,850.95 MWD+IFR-AK-CAZ-SC(4) 8,031.58 69.73 62.76 4,400.97 4,241.36 2,677.91 5,109.93 5,932,701.13 486,425.05 0.95 -3,909.21 MWD+IFR-AK-CAZ-SC(4) 8,126.13 69.71 61.86 4,433.74 4,274.13 2,719.12 5,188.46 5,932,742.15 486,503.68 0.89 -3,969.35 MWD+IFR-AK-CAZ-SC(4) 8,221.47 69.60 61.17 4,466.89 4,307.28 2,761.76 5,267.03 5,932,784.58 486,582.35 0.69 -4,030.86 MWD+IFR-AK-CAZ-SC(4) 8,315.96 69.77 61.34 4,499.69 4,340.08 2,804.37 5,344.73 5,932,827.00 486,660.14 0.25 -4,092.13 MWD+IFR-AK-CAZ-SC(4) 8,410.46 69.79 60.94 4,532.35 4,372.74 2,847.17 5,422.39 5,932,869.60 486,737.90 0.40 -4,153.58 MWD+IFR-AK-CAZ-SC(4) 8,505.43 69.73 62.06 4,565.21 4,405.60 2,889.69 5,500.69 5,932,911.92 486,816.30 1.11 -4,214.91 MWD+IFR-AK-CAZ-SC(4) 8,599.82 69.76 61.79 4,597.89 4,438.28 2,931.37 5,578.83 5,932,953.40 486,894.53 0.27 -4,275.39 MWD+IFR-AK-CAZ-SC(4) 8,694.74 69.81 61.56 4,630.69 4,471.08 2,973.63 5,657.24 5,932,995.46 486,973.03 0.23 -4,336.50 MWD+IFR-AK-CAZ-SC(4) 8,789.09 69.67 61.71 4,663.36 4,503.75 3,015.68 5,735.12 5,933,037.32 487,051.02 0.21 -4,397.28 MWD+IFR-AK-CAZ-SC(4) 8,884.04 69.81 61.38 4,696.24 4,536.63 3,058 12 5,813.44 5,933,079.56 487,129.43 0.36 -4,458.55 MWD+IFR-AK-CAZ-SC(4) 8,978.74 69.28 63.15 4,729.33 4,569.72 3,099.41 5,891.97 5,933,120.65 487,208.05 1.84 -4,518.76 MWD+IFR-AK-CAZ-SC(4) 9,072.59 68.76 66.54 4,762.95 4,603.34 3,136.66 5,971.27 5,933,157.70 487,287.44 3.42 -4,575.26 MWD+IFR-AK-CAZ-SC(4) 9,167.47 68.45 68.23 4,797.56 4,637.95 3,170.63 6,052.81 5,933,191 46 487,369.06 1.69 -4,629.18 MWD+IFR-AK-CAZ-SC(4) 9,261.56 68.30 70.43 4,832.24 4,672.63 3,201.50 6,134.64 5,933,222.13 487,450.95 2.18 -4,680.18 MWD+IFR-AK-CAZ-SC(4) 9,355.54 68.10 71.60 4,867.14 4,707.53 3,229.89 6,217.15 5,933,250.31 487,533.53 1.18 -4,728.95 MWD+IFR-AK-CAZ-SC(4) 9,453.28 67.46 73.65 4,904.11 4,744.50 3,256.91 6,303.50 5,933,277.12 487,619.93 2.05 -4,777.40 MWD+IFR-AK-CAZ-SC(4) 9,545.54 66.12 76.14 4,940.47 4,780.86 3,279.01 6,385.35 5,933,299.01 487,701.83 2.87 -4,819.93 MWD+IFR-AK-CAZ-SC(4) 9,639.05 65.50 79.25 4,978.79 4,819.18 3,297.19 6,468.67 5,933,316.99 487,785.19 3.11 -4,859.06 MWD+IFR-AK-CAZ-SC(4) 9,734.16 63.96 82.05 5,019.40 4,859.79 3,311.18 6,553.52 5,933,330.76 487,870.06 3.12 -4,894.53 MWD+IFR-AK-CAZ-SC(4) 9,828.99 62.55 85.01 5,062.08 4,902.47 3,320.73 6,637.65 5,933,340.10 487,954.21 3.16 -4,925.53 MWD+IFR-AK-CAZ-SC(4) 9,923.33 62.73 87.39 5,105.44 4,945.83 3,326.28 6,721.24 5,933,345.45 488,037.81 2.25 -4,952.53 MWD+IFR-AK-CAZ-SC(4) 10,018.61 61.48 90.51 5,150.03 4,990.42 3,327.84 6,805.42 5,933,346.79 488,121.98 3.18 -4,975.82 MWD+IFR-AK-CAZ-SC(4) 10,113.47 60.59 95.60 5,195.99 5,036.38 3,323.44 6,888.26 5,933,342.19 488,204.80 4.79 -4,993.00 MWD+IFR-AK-CAZ-SC(4) 10,207.39 61.27 100.56 5,241.64 5,082.03 3,311.89 6,969 49 5,933,330.44 488,285.99 4.67 -5,002.88 MWD+IFR-AK-CAZ-SC(4) 10,302.79 61.83 104.08 5,287.10 5,127.49 3,293.99 7,051.42 5,933,312.34 488,367.87 3.30 -5,006.79 MWD+IFR-AK-CAZ-SC(4) 10,396.93 61.67 107.78 5,331.67 5,172.06 3,271.24 7,131.14 5,933,289.39 488,447.53 3.47 -5,005.45 MWD+IFR-AK-CAZ-SC(4) 10,491.27 60.92 110.92 5,376.99 5,217.38 3,243.83 7,209.20 5,933,261.80 488,525.51 3.03 -4,999.18 MWD+IFR-AK-CAZ-SC(4) 10,586.26 59.69 113.68 5,424.06 5,264.45 3,212.54 7,285.54 5,933,230.32 488,601.76 2.84 -4,988.71 MWD+IFR-AK-CAZ-SC(4) 10,681.17 59.36 116.26 5,472.20 5,312.59 3,178.02 7,359.68 5,933,195.61 488,675.81 2.37 -4,974.55 MWD+IFR-AK-CAZ-SC(4) 10,775.96 59.93 118.30 5,520.10 5,360.49 3,140.53 7,432.37 5,933,157.95 488,748.40 1.95 -4,957.15 MWD+IFR-AK-CAZ-SC(4) 10,871.21 61.11 120.90 5,566.98 5,407.37 3,099.57 7,504.45 5,933,116.81 488,820.37 2.68 -4,936.25 MWD+IFR-AK-CAZ-SC(4) 10,965.55 61.35 123.80 5,612.40 5,452.79 3,055.32 7,574.30 5,933,072.40 488,890.10 2.71 -4,911.59 MWD+IFR-A!K-CAZ-SC(4) 11,061.46 61.93 126.60 5,657.96 5,498.35 3,006.67 7,643.25 5,933,023.59 488,958.93 2.64 -4,882.44 MWD+IFR-AK-CAZ-SC(4) 11,155.13 62.85 129.95 5,701.38 5,541.77 2,955.26 7,708.40 5,932,972.02 489,023.94 3.32 -4,849.64 MWD+IFR-AK-CAZ-SC(4) 11,249.55 63.36 134.05 5,744.11 5,584.50 2,898.93 7,770.95 5,932,915.54 489,086.35 3.91 -4,811.42 MWD+IFR-AK-CAZ-SC(4) 11,344.07 63.66 138.26 5,786.28 5,626.67 2,837.93 7,829.53 5,932,854.40 489,144.77 4.00 -4,767.66 MWD+IFR-AK-CAZ-SC(4) 11,438.26 64.24 142.75 5,827.66 5,668.05 2,772.65 7,883.32 5,932,788.99 489,198.40 4.33 -4,718.53 MWD+IFR-AK-CAZ-SC(4) 11,533.86 65.06 145.99 5,868.60 5,708.99 2,702.44 7,933.64 5,932,718.66 489,248.53 3.18 -4,663.73 MWD+IFR-AK-CAZ-SC(4) 11,627.70 66.20 148.62 5,907.33 5,747.72 2,630.51 7,979.80 5,932,646.62 489,294.51 2.83 -4,606.20 MWD+IFR-AK-CAZ-SC(4) 1/19/2016 8:42:43AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig:120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft)° (usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 11,722.74 67.38 152.17 5,944.79 5,785.18 2,554.57 8,022.93 5,932,570.59 489,337.44 3.65 -4,544.01 MWD+IFR-AK-CAZ-SC(4) 11,817.37 68.46 155.10 5,980.37 5,820.76 2,476.01 8,061.86 5,932,491.94 489,376.17 3.09 -4,478.21 MWD+IFR-AK-CAZ-SC(4) 11,912.31 69.09 156.58 6,014.74 5,855.13 2,395.27 8,098.07 5,932,411.12 489,412.19 1.60 -4,409.59 MWD+IFR-AK-CAZ-SC(4) 12,006.26 68.86 157.71 6,048.45 5,888.84 2,314.46 8,132.13 5,932,330.23 489,446.05 1.15 -4,340.35 MWD+IFR-AK-CAZ-SC(4) 12,101.29 69.65 160.48 6,082.12 5,922.51 2,231.45 8,163.83 5,932,247.15 489,477.54 2.85 -4,268.37 MWD+IFR-AK-CAZ-SC(4) 12,195.51 71.59 162.74 6,113.38 5,953.77 2,147.11 8,191.86 5,932,162.76 489,505.35 3.06 -4,194.16 MWD+IFR-AK-CAZ-SC(4) 12,290.59 74.03 165.57 6,141.49 5,981.88 2,059.75 8,216.64 5,932,075.34 489,529.92 3.83 -4,116.19 MWD+IFR-AK-CAZ-SC(4) 12,385.39 76.48 168.31 6,165.62 6,006.01 1,970.45 8,237.34 5,931,986.00 489,550.39 3.81 -4,035.29 MWD+IFR-AK-CAZ-SC(4) 12,480.60 77.85 172.31 6,186.78 6,027.17 1,878.97 8,252.96 5,931,894.49 489,565.78 4.34 -3,950.96 MWD+IFR-AK-CAZ-SC(4) 12,512.12 77.98 173.39 6,193.38 6,033.77 1,848.39 8,256.79 5,931,863.90 489,569.54 3.38 -3,922.42 MWD+IFR-AK-CAZ-SC(4) 12,571.05 78.19 173.00 6,205.54 6,045.93 1,791.13 8,263.63 5,931,806.63 489,576.23 0.74 -3,868.88 INC+TREND(5) 12,574.00 78.18 172.97 6,206.15 6,046.54 1,788.27 8,263.98 5,931,803.77 489,576.57 1.19 -3,866.21 MWD+IFR-AK-CAZ-SC(6) 7-5/8"-9718x11" 12,666.66 77.71 171.94 6,225.50 6,065.89 1,698.44 8,275.88 5,931,713.92 489,588.25 1.19 -3,782.52 MWD+IFR-AK-CAZ-SC(6) 12,761.77 75.71 175.07 6,247.37 6,087.76 1,606.49 8,286.36 5,931,621.95 489,598.50 3.83 -3,696.41 MWD+IFR-AK-CAZ-SC(6) 12,856.21 75.05 178.87 6,271.22 6,111.61 1,515.25 8,291.19 5,931,530.71 489,603.11 3.96 -3,609.54 MWD+IFR-AK-CAZ-SC(6) 12,951.13 75.97 180.43 6,294.97 6,135.36 1,423.36 8,291.75 5,931,438.83 489,603.44 1.86 -3,520.92 MWD+IFR-AK-CAZ-SC(6) 13,046.58 80.30 180.40 6,314.59 6,154.98 1,329.97 8,291.07 5,931,345.45 489,602.53 4.54 -3,430.54 MWD+IFR-AK-CAZ-SC(6) 13,141.51 84.37 180.82 6,327.25 6,167.64 1,235.91 8,290.07 5,931,251 41 489,601.29 4.31 -3,339.43 MWD+IFR-AK-CAZ-SC(6) 13,235.84 85.87 184.41 6,335.27 6,175.66 1,142.04 8,285.78 5,931,157.56 489,596.77 4.11 -3,247.65 MWD+IFR-AK-CAZ-SC(6) 13,330.83 83.89 188.73 6,343.75 6,184.14 1,048.08 8,274.96 5,931,063.63 489,585.72 4.99 -3,154.08 MWD+IFR-AK-CAZ-SC(6) 13,425.88 84.91 191.53 6,353.03 6,193.42 954.97 8,258.32 5,930,970.57 489,568.86 3.12 -3,059.84 MWD+IFR-AK-CAZ-SC(6) 13,520.68 87.03 193.91 6,359.69 6,200.08 862.74 8,237.50 5,930,878.40 489,547.81 3.36 -2,965.36 MWD+IFR-AK-CAZ-SC(6) 13,615.59 90.66 197.00 6,361.61 6,202.00 771.30 8,212.22 5,930,787.04 489,522.30 5.02 -2,870.50 MWD+IFR-AK-CAZ-SC(6) 13,710.65 91.86 198.35 6,359.52 6,199.91 680.76 8,183.37 5,930,696.57 489,493.23 1.90 -2,775.57 MWD+IFR-AK-CAZ-SC(6) 13,805.18 90.78 197.62 6,357.34 6,197.73 590.87 8,154.19 5,930,606.77 489,463.83 1.38 -2,681.20 MWD+IFR-AK-CAZ-SC(6) 13,899.61 89.68 196.15 6,356.96 6,197.35 500.52 8,126.76 5,930,516.49 489,436.18 1.94 -2,586.82 MWD+IFR-AK-CAZ-SC(6) 13,994.80 89.92 193.68 6,357.29 6,197.68 408.54 8,102.26 5,930,424.58 489,411.46 2.61 -2,491.64 MWD+IFR-AK-CAZ-SC(6) 14,090.52 89.82 191.53 6,357.51 6,197.90 315.13 8,081.38 5,930,331 24 489,390.34 2.25 -2,396.01 MWD+IFR-AK-CAZ-SC(6) 14,184.83 89.96 192.47 6,357.69 6,198.08 222.89 8,061.77 5,930,239.05 489,370.51 1.01 -2,301.83 MWD+IFR-AK-CAZ-SC(6) 14,279.75 89.29 195.30 6,358.31 6,198.70 130.75 8,038.99 5,930,146.98 489,347.51 3.06 -2,206.94 MWD+IFR-AK-CAZ-SC(6) 14,375.49 90.63 196.00 6,358.38 6,198.77 38.56 8,013.17 5,930,054.87 489,321.46 1.58 -2,111.21 MWD+IFR-AK-CAZ-SC(6) 14,470.24 89.29 196.87 6,358.45 6,198.84 -52.31 7,986.36 5,929,964.07 489,294.43 1.69 -2,016.49 MWD+IFR-AK-CAZ-SC(6) 14,564.84 89.37 199.26 6,359.55 6,199.94 -142.24 7,957.03 5,929,874.22 489,264.88 2.53 -1,922.04 MWD+IFR-AK-CAZ-SC(6) 14,660.05 88.76 199.87 6,361.11 6,201.50 -231.94 7,925.15 5,929,784.61 489,232.78 0.91 -1,827.15 MWD+IFR-AK-CAZ-SC(6) 14,754.87 87.07 198.84 6,364.56 6,204.95 -321.33 7,893.75 5,929,695.30 489,201.16 2.09 -1,732.67 MWD+IFR-AK-CAZ-SC(6) 14,849.61 86.52 197.37 6,369.85 6,210.24 -411.24 7,864.35 5,929,605.48 489,171.54 1.65 -1,638.22 MWD+IFR-AK-CAZ-SC(6) 14,944.83 86.65 195.24 6,375.53 6,215.92 -502.46 7,837.67 5,929,514.33 489,144.64 2.24 -1,543.20 MWD+IFR-AK-CAZ-SC(6) 15,039.60 88.31 194.48 6,379.69 6,220.08 -593.97 7,813.39 5,929,422.89 489,120.13 1.93 -1,448.52 MWD+IFR-AK-CAZ-SC(6) 15,134.33 89.82 193.47 6,381.24 6,221.63 -685.88 7,790.52 5,929,331.05 489,097.03 1.92 -1,353.83 MWD+IFR-AK-CAZ-SC(6) 1/19/2016 8:42:43AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig:120+39.61 @ 159.61 usft(Doyon25) Site:', Kuparuk 2S Pad MD Reference: Rig:120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,229.11 90.23 191.01 6,381.20 6,221.59 -778.50 7,770.42 5,929,238.49 489,076.71 2.63 -1,259.16 MWD+IFR-AK-CAZ-SC(6) 15,323.97 90.75 190.27 6,380.39 6,220.78 -871.72 7,752.91 5,929,145.32 489,058.97 0.95 -1,164.58 MWD+IFR-AK-CAZ-SC(6) 15,419.11 90.33 190.01 6,379.49 6,219.88 -965.37 7,736.16 5,929,051.72 489,041.99 0.52 -1,069.79 MWD+IFR-AK-CAZ-SC(6) 15,514.10 89.65 188.75 6,379.51 6,219.90 -1,059.09 7,720.68 5,928,958.05 489,026.28 1.51 -975.26 MWD+IFR-AK-CAZ-SC(6) 15,608.75 89.61 187.36 6,380.12 6,220.51 -1,152.80 7,707.42 5,928,864.38 489,012.79 1.47 -881.31 MWD+IFR-AK-CAZ-SC(6) 15,703.73 89.82 186.95 6,380.59 6,220.98 -1,247.04 7,695.59 5,928,770.18 489,000.72 0.48 -787.22 MWD+IFR-AK-CAZ-SC(6) 15,798.16 89.65 187.82 6,381.03 6,221.42 -1,340.68 7,683.45 5,928,676.57 488,988.36 0.94 -693.62 MWD+IFR-AK-CAZ-SC(6) 15,893.10 90.37 188.58 6,381.01 6,221.40 -1,434.65 7,669.91 5,928,582.65 488,974.58 1.10 -599.35 MWD+IFR-AK-CAZ-SC(6) 15,988.09 91.70 188.25 6,379.29 6,219.68 -1,528.60 7,656.01 5,928,488.74 488,960.45 1.44 -505.00 MWD+IFR-AK-CAZ-SC(6) 16,082.54 87.81 188.71 6,379.70 6,220.09 -1,622.00 7,642.09 5,928,395.39 488,946.30 4.15 -411.18 MWD+IFR-AK-CAZ-SC(6) 16,177.90 89.99 189.18 6,381.53 6,221.92 -1,716.18 7,627.26 5,928,301.26 488,931.24 2.34 -316.38 MWD+IFR-AK-CAZ-SC(6) 16,272.59 91.02 188.56 6,380.69 6,221.08 -1,809.73 7,612.66 5,928,207.75 488,916.41 1.27 -222.24 MWD+IFR-AK-CAZ-SC(6) 16,366.15 91.50 188.29 6,378.64 6,219.03 -1,902.26 7,598.96 5,928,115.27 488,902.48 0.59 -129.32 MWD+IFR-AK-CAZ-SC(6) 16,461.60 92.12 187.62 6,375.62 6,216.01 -1,996.74 7,585.76 5,928,020.83 488,889.05 0.96 -34.63 MWD+IFR-AK-CAZ-SC(6) 16,557.27 91.67 185.41 6,372.46 6,212.85 -2,091.74 7,574.91 5,927,925.87 488,877.96 2.36 59.93 MWD+IFR-AK-CAZ-SC(6) 16,651.13 91.41 184.24 6,369.93 6,210.32 -2,185.23 7,567.02 5,927,832.41 488,869.84 1.28 152.28 MWD+IFR-AK-CAZ-SC(6) 16,747.05 89.89 185.29 6,368.85 6,209.24 -2,280.81 7,559.05 5,927,736.86 488,861.64 1.93 246.66 MWD+IFR-AK-CAZ-SC(6) 16,841.74 89.72 186.97 6,369.17 6,209.56 -2,374.95 7,548.94 5,927,642.75 488,851.30 1.78 340.22 MWD+IFR-AK-CAZ-SC(6) 16,936.78 89.27 185.91 6,370.01 6,210.40 -2,469.39 7,538.28 5,927,548.35 488,840.40 1.21 434.19 MWD+IFR-AK-CAZ-SC(6) 17,031.64 89.37 185.92 6,371.13 6,211.52 -2,563.73 7,528.50 5,927,454.04 488,830.40 0.11 527.86 MWD+IFR-AK-CAZ-SC(6) 17,126.71 89.03 186.72 6,372.46 6,212.85 -2,658.22 7,518.04 5,927,359.59 488,819.70 0.91 621.83 MWD+IFR-AK-CAZ-SC(6) 17,222.19 88.62 188.48 6,374.42 6,214.81 -2,752.83 7,505.41 5,927,265.01 488,806.84 1.89 716.49 MWD+IFR-AK-CAZ-SC(6) 17,314.68 88.93 189.62 6,376.39 6,216.78 -2,844.15 7,490.87 5,927,173.74 488,792.07 1.28 808.46 MWD+IFR-AK-CAZ-SC(6) 17,410.75 89.61 189.82 6,377.62 6,218.01 -2,938.83 7,474.65 5,927,079.11 488,775.62 0.74 904.11 MWD+IFR-AK-CAZ-SC(6) 17,503.96 90.39 190.21 6,377.62 6,218.01 -3,030.62 7,458.44 5,926,987.37 488,759.19 0.94 996.97 MWD+IFR-AK-CAZ-SC(6) 17,598.29 89.32 192.77 6,377.86 6,218.25 -3,123.05 7,439.65 5,926,895.00 488,740.17 2.94 1,091.11 MWD+IFR-AK-CAZ-SC(6) 17,693.31 86.70 195.99 6,381.16 6,221.55 -3,215.02 7,416.08 5,926,803.10 488,716.37 4.37 1,186.05 MWD+IFR-AK-CAZ-SC(6) 17,788.13 87.76 198.61 6,385.74 6,226.13 -3,305.43 7,387.91 5,926,712.76 488,687.98 2.98 1,280.67 MWD+IFR-AK-CAZ-SC(6) 17,882.58 89.41 200.14 6,388.07 6,228.46 -3,394.50 7,356.59 5,926,623.78 488,656.44 2.38 1,374.81 MWD+IFR-AK-CAZ-SC(6) 17,976.99 89.92 202.20 6,388.63 6,229.02 -3,482.53 7,322.50 5,926,535.84 488,622.14 2.25 1,468.67 MWD+IFR-AK-CAZ-SC(6) 18,071.59 89.24 205.31 6,389.32 6,229.71 -3,569.11 7,284.40 5,926,449.37 488,583.83 3.37 1,562.15 MWD+IFR-AK-CAZ-SC(6) 18,165.44 89.75 204.29 6,390.15 6,230.54 -3,654.30 7,245.03 5,926,364.29 488,544.26 1.22 1,654.63 MWD+IFR-AK-CAZ-SC(6) 18,259.21 88.93 203.53 6,391.23 6,231.62 -3,740.01 7,207.03 5,926,278.67 488,506.05 1.19 1,747.26 MWD+IFR-AK-CAZ-SC(6) 18,354.25 89.06 201.82 6,392.89 6,233.28 -3,827.69 7,170.40 5,926,191.10 488,469.20 1.80 1,841.43 MWD+IFR-AK-CAZ-SC(6) 18,447.45 89.13 202.89 6,394.37 6,234.76 -3,913.87 7,134.96 5,926,105.01 488,433.55 1.15 1,933.85 MWD+IFR-AK-CAZ-SC(6) 18,542.74 90.13 202.74 6,394.98 6,235.37 -4,001.70 7,098.01 5,926,017.28 488,396.39 1.06 2,028.25 MWD+IFR-AK-CAZ-SC(6) 18,636.44 91.64 202.24 6,393.53 6,233.92 -4,088.26 7,062.17 5,925,930.82 488,360.34 1.70 2,121.14 MWD+IFR-AK-CAZ-SC(6) 18,728.40 90.75 204.61 6,391.62 6,232.01 -4,172.62 7,025.62 5,925,846.56 488,323.59 2.75 2,212.08 MWD+IFR-AK-CAZ-SC(6) 18,825.93 89.92 206.36 6,391.05 6,231.44 -4,260.65 6,983.66 5,925,758.64 488,281.41 1.99 2,307.97 MWD+IFR-AK-CAZ-SC(6) 18,918.30 89.55 204.93 6,391.47 6,231.86 -4,343.92 6,943.69 5,925,675.48 488,241.23 1.60 2,398.75 MWD+IFR-AK-CAZ-SC(6) 1/19/2016 8:42:43AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-01 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.61 @ 159.61 usft(Doyon25) Well: 2S-01 North Reference: True Wellbore: 2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/1©Q')' (ft) Survey Tool Name 19,015.14 88.88 204.37 6,392.80 6,233.19 -4,431.93 6,903.30 5,925,587.58 488,200.63 0.90 2,494.21 MWD+IFR-AK-CAZ-SC(6) 19,109.60 90.15 203.49 6,393.60 6,233.99 -4,518.26 6,864.99 5,925,501.35 488,162.11 1.64 2,587.52 MWD+IFR-AK-CAZ-SC(6) 19,204.42 88.98 202.30 6,394.32 6,234.71 -4,605.61 6,828.10 5,925,414.11 488,125.01 1.76 2,681.43 MWD+IFR-AK-CAZ-SC(6) 19,299.09 89.79 198.96 6,395.34 6,235.73 -4,694.19 6,794.75 5,925,325.62 488,091.45 3.63 2,775.63 MWD+IFR-AK-CAZ-SC(6) 19,393.18 90.13 197.78 6,395.40 6,235.79 -4,783.48 6,765.10 5,925,236.41 488,061.58 1.31 2,869.55 MWD+IFR-AK-CAZ-SC(6) 19,487.30 89.55 198.05 6,395.66 6,236.05 -4,873.04 6,736.15 5,925,146.93 488,032.41 0.68 2,963.55 MWD+IFR-AK-CAZ-SC(6) 19,581.42 89.41 199.44 6,396.52 6,236.91 -4,962.16 6,705.91 5,925,057.89 488,001.95 1.48 3,057.46 MWD+IFR-AK-CAZ-SC(6) 19,676.95 89.97 199.52 6,397.03 6,237.42 -5,052.22 6,674.05 5,924,967.92 487,969.87 0.59 3,152.70 MWD+IFR-AK-CAZ-SC(6) 19,771.08 88.89 198.98 6,397.97 6,238.36 -5,141.08 6,643.02 5,924,879.15 487,938.62 1.28 3,246.56 MWD+IFR-AK-CAZ-SC(6) 19,864.90 89.03 198.99 6,399.67 6,240.06 -5,229.78 6,612.50 5,924,790.53 487,907.89 0.15 3,340.14 MWD+IFR-AK-CAZ-SC(6) 19,957.69 89.82 197.45 6,400.61 6,241.00 -5,317.91 6,583.49 5,924,702.48 487,878.66 1.87 3,432.78 MWD+IFR-AK-CAZ-SC(6) 20,050.98 90.16 196.98 6,400.62 6,241.01 -5,407.02 6,555.88 5,924,613.45 487,850.83 0.62 3,526.00 MWD+IFR-AK-CAZ-SC(6) 20,146.66 90.55 193.48 6,400.03 6,240.42 -5,499.33 6,530.75 5,924,521.22 487,825.48 3.68 3,621.66 MWD+IFR-AK-CAZ-SC(6) 20,241.72 89.34 190.14 6,400.12 6,240.51 -5,592.36 6,511.30 5,924,428.24 487,805.80 3.74 3,716.56 MWD+IFR-AK-CAZ-SC(6) 20,337.65 89.31 188.89 6,401.25 6,241.64 -5,686.96 6,495.44 5,924,333.69 487,789.71 1.30 3,812.04 MWD+IFR-AK-CAZ-SC(6) 20,432.45 89.30 190.80 6,402.40 6,242.79 -5,780.35 6,479.24 5,924,240.34 487,773.27 2.01 3,906.44 MWD+IFR-AK-CAZ-SC(6) 20,524.96 88.33 192.82 6,404.31 6,244.70 -5,870.88 6,460.31 5,924,149.87 487,754.12 2.42 3,998.78 MWD+IFR-AK-CAZ-SC(6) 20,618.45 88.65 194.20 6,406.78 6,247.17 -5,961.75 6,438.47 5,924,059.07 487,732.07 1.51 4,092.21 MWD+IFR-AK-CAZ-SC(6) 20,714.89 89.92 196.28 6,407.98 6,248.37 -6,054.78 6,413.13 5,923,966.11 487,706.49 2.53 4,188.63 MWD+IFR-AK-CAZ-SC(6) 20,808.44 90.70 196.42 6,407.47 6,247.86 -6,144.55 6,386.79 5,923,876.42 487,679.94 0.85 4,282.15 MWD+IFR-AK-CAZ-SC(6) 20,903.54 89.60 196.83 6,407.23 6,247.62 -6,235.67 6,359.59 5,923,785.37 487,652.51 1.23 4,377.21 MWD+IFR-AK-CAZ-SC(6) 20,998.04 86.24 198.56 6,410.66 6,251.05 -6,325.62 6,330.89 5,923,695.50 487,623.59 4.00 4,471.53 MWD+IFR-AK-CAZ-SC(6) 21,091.86 84.95 195.39 6,417.86 6,258.25 -6,415.08 6,303.58 5,923,606.12 487,596.06 3.64 4,565.00 MWD+IFR-AK-CAZ-SC(6) 21,186.78 86.96 193.06 6,424.56 6,264.95 -6,506.85 6,280.32 5,923,514.42 487,572.58 3.24 4,659.67 MWD+IFR-AK-CAZ-SC(6) 21,281.54 86.61 191.68 6,429.87 6,270.26 -6,599.26 6,260.05 5,923,422.06 487,552.08 1.50 4,754.18 MWD+IFR-AK-CAZ-SC(6) 21,375.71 88.45 189.16 6,433.93 6,274.32 -6,691.78 6,243.04 5,923,329.60 487,534.84 3.31 4,847.95 MWD+IFR-AK-CAZ-SC(6) 21,469.44 89.41 188.39 6,435.68 6,276.07 -6,784.39 6,228.74 5,923,237.03 487,520.32 1.31 4,941 10 MWD+IFR-AK-CAZ-SC(6) 21,564.27 89.34 187.86 6,436.72 6,277.11 -6,878.27 6,215.34 5,923,143.20 487,506.68 0.56 5,035.25 MWD+IFR-AK-CAZ-SC(6) 21,659.83 88.48 186.63 6,438.54 6,278.93 -6,973.04 6,203.29 5,923,048.46 487,494.40 1.57 5,129.91 MWD+IFR-AK-CAZ-SC(6) 21,720.00 88.48 186.63 6,440.13 6,280.52 -7,032.79 6,196.35 5,922,988.74 487,487.31 0.00 5,189.42 PROJECTED to TD 1/19/2016 8:42:43AM Page 8 COMPASS 5000.1 Build 74 • Drumm Cement Detail Report &Wells 2S-01 ConocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL, 12/12/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 12/21/2014 08:55 12/21/2014 09:00 2S-01 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement conductor in 39.6 118.5 No No No place Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Peak drilled 42"hole to 82'below ground level,set 16"62.58#APISL Grade B Insulated Conductor.SLB cemented in two stages with 15.7ppg Arctic Set 1 cement.Topped with 5'deep,6'wide sealed pan cellar. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/10/2016 S i ng Cement Detail Report &Wells 2S-01 ConocoPhitlips ._ String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/12/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/19/2015 16:42 12/19/2015 21:27 2S-01 Comment Circulate through cement hose while reciprocating from 2950'MD to 2920'MD staging up to 9 BPM,460psi,6 BPM=385, 7 BPM=400psi,8 BPM=460psi. Mud wt in and out=9.7ppg,Total strokes pumped 24190(2436 bbls). PU wt= 147k,SO wt= 131k. Hold PJSM prior to beginning cement job. Pump 5bbl CW 100 and test cement lines to 3500psi(Good Test). Dowell continue to pump 70bbl of CW100 at 5.9BPM,220psi, FO=22%. Pump 75bb1 of 10.5ppg Mud Push II with 2 gal of Red Dye at 5.5BPM,220psi,and FO=23%. Drop bottom plug,pump 417.2bb1 of Lead Deep Crete 11.Oppg at 6.6BPM,235psi, FO=22%. Pump 64.9bbl 12ppg Tail cement at 6.6BPM,290psi, FO=20%. Drop top plug and chase with 10bb1 of water prior to swapping to rig pumps. Continue pumping 266.4bbls of 9.5ppg Spud mud at 2.5-6 BPM, FO=24%using rig pumps. Divert to cellar box at 600stks,slow pumps to 2BPM at 700stks, 135psi.Slowly increase back to 6BPM by1900stk,465psi. Bump plug with 2664stks, 385psi. Increase to 895psi and shut in. Pressure had a small drop to 845psi then held for 5min. Bled back to Opsi. Bleed off pressure rapidly and check floats.(Floats held).Total bleed back 2.7bbls. Full Returns. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 46.0 2,960.0 Yes 152.5 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) 6 3 7 380.0 850.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,857.0 Drill Bit 2,960.0 9 7/8 Comment Circulate through cement hose while reciprocating from 2950'MD to 2920'MD staging up to 9 BPM,460psi,6 BPM=385, 7 BPM=400psi,8 BPM=460psi. Mud wt in and out=9.7ppg,Total strokes pumped 24190(2436 bbls). PU wt= 147k,SO wt= 131k. Hold PJSM prior to beginning cement job. Pump 5bbl CW 100 and test cement lines to 3500psi(Good Test). Dowell continue to pump 70bbl of CW100 at 5.9BPM,220psi,FO=22%. Pump 75bb1 of 10.5ppg Mud Push II with 2 gal of Red Dye at 5.5BPM,220psi,and FO=23%. Drop bottom plug, pump 417.2bb1 of Lead Deep Crete 11.0ppg at 6.6BPM,235psi, FO=22%. Pump 64.9bbl 12ppg Tail cement at 6.6BPM,290psi, FO=20%. Drop top plug and chase with 10bbl of water prior to swapping to rig pumps. Continue pumping 266.4bbls of 9.5ppg Spud mud at 2.5-6 BPM, FO=24%using rig pumps. Divert to cellar box at 600stks,slow pumps to 2BPM at 700stks, 135psi.Slowly increase back to 6BPM by1900stk,465psi. Bump plug with 2664stks, 385psi. Increase to 895psi and shut in. Pressure had a small drop to 845psi then held for 5min. Bled back to Opsi. Bleed off pressure rapidly and check floats.(Floats held).Total bleed back 2.7bbls. Full returns. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 75.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.35 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 75.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.53 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead-DeepCRETE 42.4 2,314.4 1,227 417.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.88 11.00 5.33 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.05 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant LT 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail-DeepCRETE 2,314.4 2,960.0 220 64.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.66 5.83 12.00 4.70 Page 1/2 Report Printed: 2/10/2016 • • MiffingCement Detail Report :1'4 &Wells 2S-01 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/12/2015 00:00 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.02 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant LT 0.06 gal/sx Page 2/2 Report Printed: 2/10/2016 • • I Cement Detail Report &Wefts 2S-01 Conoco Phillips String: Intermediate Job: DRILLING ORIGINAL, 12/12/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 1/3/2016 03:30 1/3/2016 09:00 2S-01 Comment Stage 1 Cement job-SLB pumped 5.0 BBL H2O,PT lines to 4000 psi.Continue pumping 41 bbl MudPush2 @ 4.5 bpm,300 psi, 19%flow out. Drop bottom Weatherford By-Pass plug, pump 142.5 bbl 15.8 ppg GasBlok cement @ 4-7 bpm, 180-360 PSI,22%flow out. Drop top Weatherford Shut-Off plug, kick out with 10 bbl water.Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM to catch cement at 1450 stks. Reduce rate to 5 BPM, ICP=220 PSI, FCP=533 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16%flow at 5462 Stks pumped. Recip pipe w/15'strokes throughout the job until 5270 stks pumped. Bump plug @ 5500 stks, pressure up 500 psi over to 1100 psi and hold for 5 minutes. Bleed pressure to 0 psi, bled back 2.3 bbl.Check floats-good. Final P/U=252k,S/0=124k.CIP:06:33 hrs 1-03-16. Stage 2 Cement job-Pres to 2718 PSI and observed Weatherford Stage tool opening. Pres reduced to 105 PSI,circ @ 6 BPM, 345 PSI, 19%FO. Swap back to SLB. Pump 39.7 BBL of MudPush2 followed by 58.6 BBL of 15.5 PPG GasBlok cement @ 6 BPM,300 PSI,22%FO. Drop Weatherford Closing plug, kick out with 10 bbl water.Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM,75 PSI,6%FO. Reduce rate to at 3675 stks pumped to 6 BPM, ICP =484 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16%flow at 4138 Stks pumped. Bumped plug at 4240 stks. Pres up to 1300 PSI and observed stage tool closing. Monitor flow back to confirm closure. Good test. CIP:08:54 hrs 1-03-16. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Cement to top of Cairn 10,878.0 12,585.0 Yes Yes Yes formation Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 602.0 1,100.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Stage 1 Cement job-SLB pumped 5.0 BBL H2O,PT lines to 4000 psi.Continue pumping 41 bbl MudPush2 @ 4.5 bpm, 300 psi, 19%flow out. Drop bottom Weatherford By-Pass plug, pump 142.5 bbl 15.8 ppg GasBlok cement @ 4-7 bpm, 180-360 PSI,22%flow out.Drop top Weatherford Shut-Off plug,kick out with 10 bbl water.Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM to catch cement at 1450 stks. Reduce rate to 5 BPM, ICP=220 PSI, FCP=533 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16%flow at 5462 Stks pumped. Recip pipe w/15'strokes throughout the job until 5270 stks pumped. Bump plug @ 5500 stks, pressure up 500 psi over to 1100 psi and hold for 5 minutes. Bleed pressure to 0 psi, bled back 2.3 bbl.Check floats-good. Final P/U=252k,S/0=124k.CIP:06:33 hrs 1-03-16. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,878.0 12,585.0 682 G 142.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.22 15.80 126.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant 0065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.15 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Cement to 500'above C- 8,784.0 9,522.0 Yes Yes No 37 Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 500.0 1,300.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Stage 2 Cement job-Pres to 2718 PSI and observed Weatherford Stage tool opening. Pres reduced to 105 PSI,circ @ 6 BPM, 345 PSI, 19%FO. Swap back to SLB. Pump 39.7 BBL of MudPush2 followed by 58.6 BBL of 15.5 PPG GasBlok cement @ 6 BPM,300 PSI,22%FO. Drop Weatherford Closing plug, kick out with 10 bbl water. Swap to rig pumps and displace with 10.0 PPG LSND mud at 8 BPM,75 PSI,6%FO. Reduce rate to at 3675 stks pumped to 6 BPM, ICP =484 PSI.Slow pump rate to 3 BPM @ 607 PSI, 16%flow at 4138 Stks pumped. Bumped plug at 4240 stks. Pres up to 1300 PSI and observed stage tool closing. Monitor flow back to confirm closure. Good test. CIP:08:54 hrs 1-03-16. Page 1/2 Report Printed: 2/10/2016 • lik • Cement Detail Report .i-` t ' 2S-01 Conoco hillips String: Intermediate Job: DRILLING ORIGINAL, 12/12/2015 00:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 8,784.0 9,522.0 280 G 58.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.22 15.80 123.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.2 gal/sx Additive Type Concentration Conc Unit label Gas Block D6000 1.0 gal/sx Page 2/2 Report Printed: 2/10/2016 p 17 z15 - Z °3 • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Sunday, January 31, 2016 9:43 AM To: Klem, Adam Cc: Wallace, Chris D (DOA) Subject: Re: [EXTERNAL]RE: KRU 2S-01(PTD 215-203, Sundry 316-026) Frac Sundry Modifications Adam, You may proceed with your plan as outlined below. Thanx, Victoria Sent from my iPhone >On Jan 30, 2016, at 4:55 PM, Klem,Adam<Adam.Klem@conocophillips.com>wrote: >The IA will still be tested to 4000psi,we just cannot hold 4000psi with our pop off valve during the frac. > From: Wallace, Chris D (DOA)<chris.wallace@alaska.gov> >Sent:Saturday,January 30, 2016 2:13:34 PM >To: Klem, Adam; Loepp,Victoria T(DOA) >Cc: Davasher, Mick J >Subject: RE: (EXTERNAL]RE: KRU 2S-01(PTD 215-203, Sundry 316-026) Frac Sundry Modifications >Adam, >What is/was the IA tested to? >Chris > Original message > From: "Klem,Adam" <Adam.Klem@conocophillips.com> > Date: 01/30/2016 9:47 AM (GMT-09:00) >To: "Loepp, Victoria T(DOA)" <victoria.loepp@alaska.gov> >Cc: "Wallace, Chris D (DOA)"<chris.wallace@alaska.gov>, "Davasher, Mick J" < asher@conocophillips.com> >Subject: RE: [EXTERNAL]RE: KRU 2S-01(PTD 215-203,Sundry 316-026) Frac Sundry Modifications >Victoria and Chris, > I was just informed our IA pop off can only be set to a maximum pressure of 4000psi. So,we are only comfortable holding 3800psi on the IA.Therefore we are now going to pressure test the tubing to 5000psi. Can we get permission to proceed with this plan? >So with a maximum anticipated frac pressure of 8040psi minus the 3800Psi on the IA results in 4,240psi differential. Pressure testing the tubing to 5000psi exceeds the 110%required pressure test. > Please let me know if this is ok. We are planning to frac on Monday 2/1. 1 • • >Thanks, >Adam Klem > From: Loepp, Victoria T(DOA)<victoria.loepp@alaska.gov> >Sent:Wednesday,January 20, 2016 6:04:32 PM >To: Klem, Adam >Cc: Wallace, Chris D (DOA) >Subject: [EXTERNAL]RE: KRU 2S-01(PTD 215-203,Sundry 316-026) Frac Sundry Modifications >Adam, >The modifications to the sundry outlined below are approved. Please include this approval with your copy of the approved frac sundry. >Thanx, >Victoria > From: Klem,Adam [mailto:Adam.Klem@conocophillips.corn] >Sent: Wednesday,January 20, 2016 2:55 PM >To: Loepp,Victoria T(DOA) >Subject: KRU 2S-01(PTD 215-203, Sundry 316-026) Frac Sundry Modifications > Re: KRU 2S-01 > PTD: 215-203 >Sundry#: 316-026 >Victoria, >As we just discussed,we recently experienced some issues running the production liner on 2S-01.The liner got (somewhat) stuck roughly 3,000' into the lateral. After a little bit of work,we pulled the liner out of the hole. We are now performing a cleanout run before attempting to run the liner again. Due to the problems experienced running the liner, we are now planning to run the liner short of TD, with the shoe now planned to be at roughly 20,390' (vs planned 21,739'), short of the fault at 20,760'. This will decrease our total number of frac stages from the 15 we stated on the approved sundry to 11 total stages.Additionally, due to the difficulties experienced running swell packers through the shale, we plan on dropping all but the heel swell packer from the liner.We will set the packer at the heel in the Kuparuk A sand to isolate the Kalubik shale and the intermediate shoe.The reduction of total length to the first frac stage should decrease our maximum expected treating pressure slightly, but not significantly. We will still be running the same amount of 3 (1/2)" tubing as stated on the approved sundry.All the pressures we stated we would test the tubing (4500psi)and IA(4000psi)to on the sundry are still valid. We will still hold 4000psi on the IA during the fracture stimulation. > Let me know if this is acceptable to proceed with our fracture stimulation operation. >Thank you, >Adam Klem >Senior Completions Engineer >Greater Kuparuk Area >ConocoPhillips Alaska 2 PTD Zi 5'-zo3 Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Wednesday,January 20, 2016 3:05 PM To: 'Klem, Adam' Cc: Wallace, Chris D (DOA) Subject: RE: KRU 2S-01(PTD 215-203, Sundry 316-026) Frac Sundry Modifications Adam, The modifications to the sundry outlined below are approved. Please include this approval with your copy of the approved frac sundry. Thanx, Victoria From: Klem, Adam [mailto:Adam.Klem(aconocophillips.com] Sent: Wednesday, January 20, 2016 2:55 PM To: Loepp, Victoria T(DOA) Subject: KRU 2S-01(PTD 215-203, Sundry 316-026) Frac Sundry Modifications Re: KRU 2S-01 PTD: 215-203 Sundry#: 316-026 Victoria, As we just discussed,we recently experienced some issues running the production liner on 2S-01.The liner got (somewhat) stuck roughly 3,000' into the lateral.After a little bit of work,we pulled the liner out of the hole. We are now performing a cleanout run before attempting to run the liner again. Due to the problems experienced running the liner, we are now planning to run the liner short of TD,with the shoe now planned to be at roughly 20,390' (vs planned 21,739'), short of the fault at 20,760'.This will decrease our total number of frac stages from the 15 we stated on the approved sundry to 11 total stages. Additionally,due to the difficulties experienced running swell packers through the shale,we plan on dropping all but the heel swell packer from the liner. We will set the packer at the heel in the Kuparuk A sand to isolate the Kalubik shale and the intermediate shoe. The reduction of total length to the first frac stage should decrease our maximum expected treating pressure slightly, but not significantly. We will still be running the same amount of 3%2"tubing as stated on the approved sundry.All the pressures we stated we would test the tubing (4500psi)and IA(4000psi)to on the sundry are still valid. We will still hold 4000psi on the IA during the fracture stimulation. Let me know if this is acceptable to proceed with our fracture stimulation operation. Thank you, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1410 1 r ti OF Tk • wP�� I 77' s THE STAT• Alaska Oil and Gas of/\ T /\ sKA Conservation Commission -#x _ 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER ".� Main: 907.279.1433 ®'S'ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-01 Permit to Drill Number: 215-203 Sundry Number: 316-026 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, "14-6c2 Cathy P Foerster Chair DATED this(,1 day of January, 2016. RBDMS LL JAN 1 9 2016 RECEIVED • STATE OF ALASKA • JAN 1 426 ALASKA OIL AND GAS CONSERVATION COMMISSION pc,S/ d4 APPLICATION FOR SUNDRY APPROVALS AO la 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 . Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory ❑ Development E 215-203 • 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20727-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-01 ' Will planned perforations require a spacing exception? Yes ❑ No i J 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25604, 25603, 25589 . 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): 21,740' • 6,409' • 8,040 Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 118' 118' Surface 2,912' 10-3/4" 2,951' 2,602' Intermediate 12,716' 7-5/8" 12,572' 6,207' Production Liner 9,189'est. 4-1/2'est. 21,739'est. 6,409'est. Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Sizer Tubing Grade: Tubing MD(ft): See attached schematic • See attached schematic 3.5" L-80 12,475'est. Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV 12,375'est. 12.Attachments: Proposal Summary E Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development E • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 18th,2016 OIL ❑✓ % 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 deflated from without prior written approval. Contact Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam em Title: Completions Engineer / 1/%'///4 Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31(.t. - 021.,E Plug Integrity ❑ BOP Test ❑ Mechanical Integrity�Test ❑ Location Clearance ❑ Other: Tubih `Vit. 4 4'j OO cl , lA i�'i, } t 4-000^, . BQ�foiYSSUx 4 .2. 00 i. i-worn) held IA "vrin, frGG.c. , . Post Initial Injection MIT Req'd? Yes ❑ No N/ Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: /0 — 4, 4_ RBDMS L L JAN 1 9 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /_ / ! /5, Dy/ S�20 (,/ 9‘_z_t_g___ORtGtNAt � //-403R viserJ 11/2015 for 12 months fhJL�te fapproval. ��j/achmentsin Duplicate /i • • 2 S-01 ConocoPhillips Grassroots Horizontal A-Sand Producer Current:Proposed Wel'bore Schematic(vp09.1) r".. i ,,i,,, ) came mom to- v Last Edited: Voss 12-31-15 W v Conducbar In 1=1 IN . .,..1 , 13.5" Surface Hole Base'Nest sak 2,855MD r 22544°TM 3- 'x1 ,.-Cameo MMG GLM = — 'Surface Casing 10-314"45.5#L-80 11ydril 563 2,951'MD!2,602'TVD(59 INC) 9-7/8"x 11" Intermediate Hole Iubinsa 3-1,12- 9.3#L-80 EUE 8RDMOD = t,ir j OLN al 50%' . ..,,0--. 2'4 Stage TOC-SNP WI abode 0-37 rodwdoeuti at 8,985'1434,73:11'TM} 11111111 —— Washed-Toni Stags Cedar 5 522 MO 0-37:5 48S litD141,517°1VD dd; a tx.„'.). 1"Stagp IOC Top or BensuclaC,aind formal Cfl:, Grodeler bbeltdreig 5,82r MCI 5,005 TVD , — *., \ r&SW Ito "..34.SHIIStg KKK... 2-.--.,K 7-W,Pranks'Reaper Calm 10.5br MO;5,d2z I2 TO Barrnecla'11,057 MD!555 WC — ..Jet., , s...•:. :N pDie \ \ 47.,,, KU:11 777 MD!S .\ ' / ) .. MUM:12,224°Mn d b„124'TVS / eta Z143 4. '...,, te a 41144"tatellE haw , KUIL f KLIpartlitUPSIAA C1226 .100.441.PAD'VfeI 24 242%2;TVD VD-li.3 ppg ,„ „.... 1 I .°-.. `JIM 1111 M . ll 111 1 n.1111.10z...1.1 I 1, 7144Lfx:t:L -I:'aMIWL.Z . ' ', li Hance? .......1144. ...... .... TD:21,740'MD/SAW TVD Intermediate Casing Production Liner: 6-314" Production Hole 7-5 "29.7#L-80 Hyd563 Casing 4-1/2"11.6#L-80 IBTM with Torque Rings 12,575'bAD I 6,210'TVD(780 INC) 21,739'MD 16409'TVD • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). • • ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-01 Kuparuk River Unit, Alaska ADL 25604, KRU Tract 89; and ADL 25607, KRU Tract 96 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-01 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 5, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 25569, KRU Tract 44 as depicted on Exhibit 1 as follows: Surface Location: 3012' FNL, 1261' FEL, Section 17, T1ON, RO8E, UM Target Location: 1323' FNL, 3530' FEL, Section 15, T1ON, RO8E, UM Bottomhole Location: 4780' FNL, 356' FEL, Section 21, T1ON, RO8E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Hanna Sylte Rebecca Swensen 2S-01 Hydraulic Fracturing Notice Lets 410 January 5, 2016 Page 2 Exhibit 1 ConocoPhillips 2S-01 Well Alaska 17Dec15 ADL025590 ADL0255.8e I i %2 mile radius S from Well D52- 14 ACL025e04 ADL025505 DL025533 T 1 O N 8 I � aci --------------- I � ADL45507 ADL392952 ADL025608 • Frac Point Open Section References: —Well Trajectory Well Data ConocoPhillipsAlaska Technical Database(ATM) ❑ 1/2 ML Radius I._KRU Boundary [1 Kuparuk PA Boundary 0 0.2 0.4 0.6 0.8 1:25,000 Miles ❑CPAI Lease 2S-01 Hydraulic Fracturing Notice Le. . January 5, 2016 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO TF ASKA OIL AND GAS CONSERVATION COOSSION 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-01 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. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations(Notice"). 4. On or about January 5, 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 5th day of January, 2016. © - k. Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 5th day of January, 2016, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA ,' : I NOTARY PUBLIC _ �": WCIL REBECCA SWENSEN "t--, `My Commission Expires Aug.27,2016 • 0 Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-01 Landowners ConocoPhil l i ps 2S-01 Weil ''1'7.8{:3 17Dec15 B /000000.000.00.0.000000.0000.0.000000 „ AFu025$82 �A�Z30 ,'1 15 D nota rE ADux?s675 , 2TION 8. .0 a s ADA 5607 PDL392352 ileums . • Frac Point Open Section Refeiences Wei Data:CarocoPhilips A.aska Technics Database jATD61 Weil Trajectory CI 1/2 Mi.Radius N E KRU Boundary ❑Kuparuk PA Boundary 0 0.2 O4 0.8 0.8 125.000 I Wiles )1\ ❑CPA'Lease • • Table 1: Wells within .5 miles Well Name API Drill Site Status Well Type 2K-19A 501032011801 2K ACTIVE PROD 2S-08 501032072200 2S PROP INJ 2S-07 501032071300 2S ACTIVE INJ 2S-02 501032071000 2S ACTIVE INJ 2K-19AL1 501032011860 2K ACTIVE PROD 2K-21A 501032012301 2K ACTIVE PROD 2S-10 501032071700 2S ACTIVE INJ 25-04 501032072100 2S ACTIVE INJ 2S-04PB1 501032072170 2S PA N/A KRU 21-10-8 501032010300 PA N/A • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exception Order No. 2 — Milne Point Unit. Which states "Those portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 10 AAC 25.440" • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 12/19/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 12 ppg tail cement, displaced with 9.5 ppg mud. Full returns were seen throughout the job. The plug bumped at 850 psi and the floats were checked and they held. The 7-5/8" casing cement report on 1/3/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,100 psi and the floats were checked and they held. The second stage was pumped with 15.8 ppg class G cement and displaced with 10 PPG LSND mud. Full returns were seen throughout the job. The plug bumped at 1,300 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 12/21/2015 the 10 & 3/4" casing was pressure tested to 3500 psi for 30 mins. On 1/6/2016 the 7 & 5/8" casing was pressure tested to 3500 psi. 400 o p,'� ./ The 7 & 5/8" casing will be pressure tested to 3 psi prior to frac'ing. The 3.5" tubing will be pressure tested to 4 psi prior to frac'ing. q SOOest �� II1S/2.o1to • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings • 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 120' TVT thick at the heel, with the top of the Kuparuk A at 6,142' TVDSS (12986' MD) and 110' TVT at the toe of the well, with the top Kuparuk A at 6,198' (21,740' MD). The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 418' TVT (1,260' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,787' TVDSS (11,727' 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 6,255' TVDSS at the heel (no MD as the Miluveach interval was not penetrated in the 2S-01 wellbore). .,j,:riLc,,, L..).irrc,,-.1.7„.or...,-,I. ,,,,----27----7.,,Iti7r:it '7•':'-',',.711.7,,,, lip-- it[II! 1 1 i 65 or s 1 -- I , . cmy- lel a1,i,1r1,7,„ -1- - : - , '7 ' 4" 1002 4' 1002 1 < ,a. ,... , ..: •,'"t;,,4°.'''''''• '''•', 4-1/16' '11.2.,3).1.7 ,•• 4-1il _ ... cl— L'''' _,, , ,i'W. :4)'' . ' ' ,—',,..,-:,•-. '1' :' ,,,,„L ' ' : *. , ----..1 . : A ," , „.,/ : '... '' 24..08' 2' 1502 S.,.........„....,..33 I 3 1 I lydr:),„Ac , .• , , =1'7" I 184.45" .111r3' 1U12--,- '. _7-•'•----'-•..' : ,.• , .. i ----,:x at . ., _ • IA" t \-,. .5_111 .-'am, , .,, me , 1 • ‘,,-4-,,_._.,1 ,. • .4 L :;,-,9„,,,,,t• „,'. gyi,p3 1 1 i ma II' '..:, 0;.:14 Li,. , g1 ,,.,, • ° i Slag ., ...ii. 1 ,„ , ,. 11I '' " .' ' :4 ' • r '2!,•47,f.',?" Iirm•-'''.• - - . f , - • -. —, ., .., . .., ,., . . : . r.: =ills • - , 2 ' i t 19' r( 11 1 1111 r 1-,,,-.)p of Conduc'-,- 7_11 C(}ndudff f to Btm. r.-0.• [10-q"'" •,, 1 I r il . = ,:, is.,, t1 14 ) ,.:, :,11.,....!)18_3.,--„ : "Vt11-1" ConocoPhillips s .. .: P D' 7, le,='-'5- i'rof_tAe ., d eCAME RON 10K Tree '".1S7EPH EN 1.„„ 12-30-15 1162040-0,,,-- S 0 10K Frac Tree Note. Dimensional information(effected on this&awing are estimated aleasuromenis only. 6-5°TIS I111111' . _ , I i I I• I ) . I .--- .. 4.1002 ------, '."mom.1 4"1002 4-1/16" 10,000# 401% 4-1/16 I 0,000# Ci... ..ta 4 15 ,_ _ 4 - I ...: , ii, i .:. .)'- - - j"-- ,41, I A )'''' jilt )411 i A ' ; i ' ' i il 2.2 C8' 4" 1502- 4-1116," 10,000# Itydradlic MI NA ------ WI p.m 0 4-1116" 10,000# /MA ilkir* I "i-l/1 h' 1C,000# ,a....:6 ConocoPhillips eCAMERON Dna s,tt 2S-11K I-lac l'e;:- ... S-EPHEN 22-3C-25 # I :.-_,.,::.t,, -2 • 0 Stimulation Surface Rig-Up sr Plood Tatty x DEir 66 's TaleTank ° ' ' ti t E ir a+ cs ro ,.1'i1 1�. • o 8 • Minimum pressure rating on all surface / treating lines 10,000 psi ,/ )84 OPOI 41 Da • Main treating line PRV is set to 95%of max treating pressure 4.0 �� ' ),r/, • IA parallel PRV set to 35 psi f� • Frac pump trip press e setting are staggered 7.1 and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 r, a psi. E. 2 �C. 0a IP :I_%. cI :C q R ;fzrul&Ind Pop Off Tank y N of MA o Pump Truck Pap-Q Tank Wiz=y`! h J BS m.l y V> C:41 AC] Frac Pump r'Ai 04 Email ` Frac Pump ti Frac Furrrp r`, . N a is,.,i Frac Pump. 2 Frac Pump rAi €.04 4' Pr-d- Frac Pump s • SECTION 10 - LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2K-19: The 7" casing cement pump report on 11/14/1989 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement, displaced with 10.2 ppg brine. The plug bumped at 2500 psi and the floats were checked and they held. 2K-21: The 7" casing cement pump report on 1/18/1990 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with batch mixed class G cement, displaced with 10 ppg brine. The plug bumped at 2100 psi and the floats were checked and they held. 2S-08: The 7 & 5/8 casing cement pump report on 11/15/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.1 ppg mud. The plug bumped at 1,400 psi and the floats were checked and they held. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-02: The 7 & 5/8 casing cement pump report on 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. 2S-04: 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, followed by 16 ppg tail cement. The plug bumped at 1,450 psi and the floats were checked and they held. • • KRU 21-10-8: KRU 21-10-8 was plugged and abandoned as per state regulations on 4/28/1989. • I 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 8 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-01. Three faults intersect the 2S-01 wellbore and terminate within the confining layer. No losses were observed at any of the fault crossings during drilling of the 2S-01 lateral section. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 25-01 Faults MD SSTVD Throw Fault#1 (A4/A4) 14676 6202 24(DTS) Fault#2 (A4/A4) 15976 6219 18 (DTS) Fault#3 (A4/A5) 20789 6247 28 (DTS) Two mapped faults intersect the offset 2S-02 wellbore in the Kuparuk A sands. Fault#1 terminates in the C35 and Fault #2 terminates within the HRZ. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of-16ppg. No losses were observed at any faults during drilling of the 2S-02 lateral section. The 2S-01 lateral is greater than 1500' east of the 2S-02 wellbore. 2S-02 Faults MD SSTVD Throw i Fault#1 (A4/A5) 16225 6227 27 (DTS) Fault#2 (A4/A4) 17488 6214 25 (DTS) The effective fracture length is estimated to be 327'. All of the fractures will be longitudinal, running parallel to the 2S-01 wellbore. Distance of the projected fracture wings to the nearest fault that does not intersect the 2S-01 wellbore is approximately 300'. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Plat 2: Fault Analysis ConocoPhillips 2S-01 FaulhAnalyrsis4laSk . Inc. 13Jan16 AD1.06b0 ADL026452 7 / IN ADLD?F004 7/ N. DS2S •t ADLD255D5 f KRLI 21 '',. i ta 4 1 . • Frac Point Active Well Within Confining Zone Abandoned Well Within Confining Zone References: Well Data.ConocoPhilhps Alaska Technical Database(ATDB) —Well Trajectory —Fault Within Confining Zone 112 Mi.Frac Point Radius N Q 1/2 Mi.Trajectory Radius L:KRU Boundary 0 0.2 0A 0.6 0.8 49 0 CPAI Lease 125,001 Miles + • • ti . 0ti m UI 0▪ m � o ., y ., s . a y ¢_ ¢� � < � 'T u.--2. m H n �� � m p< 0°1 0 �0 g « O W v ¢Z O m C O O O O m OO c_ N N < c -• - 'i n p ,- as,_ Ss.n Z a Tri a ti a a ,v, m o d n 0 U a 0 S N 0 0 C N 0 N to N Fg' O O N 2 a m rn m In ci 0 y o to C an U m O m m m .n U U' , u .. V u N l7 (7 a ma m a a OD OD a a - a n O O m a •+ a O E m co N_ mm m j m : HLti 7 ti(7 lui.-. m W N E d N a u e u o UI mmnm oe m CO N an a . cv m I-- -,4 o ✓ v N o @ @ o an .Ni n o o w` `w in usi @1 `w `w y w` :11 I C1 aa� @1 0.00 _^IT 3 aa• 2 a ,. a2 a2 i2 CO ~oA a 04 04 04 04 c4 N Z N N O o O V U 4.N m ° m Q m O OE v u O VO O coOO 0 m n aa v a a N o o 0 0 0 0 0 0 Qu c o• a w c m w v < E a < v 3 9a' v m .`o w v ,:c ..i CC LI- 0 O r CO 0 • F., m a to ccv m w 'o m m1- Eo v J n Q c u - u 'o • - 'o 'o EaoE U po U V V O � c C E Co \ oN W ▪ 0 W W rO v' .i d--+ o �n Q N o m Ti. ar e van' (/7 a" N 12 U E n N c - 01v F.,G o 'ri m N o o u�' m m 1O MI n a+ o m o @ c- m0 @ N ao. c e ro M. 43. U- o O1 .�. a m F 0 a \ a a h Q - o h o So v oo < an co � mi `° O N N N N Z O t0 tO t0 M 'O 'O. tp tO Cl/a 1116.m m o t; 0 v o o m INnt6 c.i - o e o N Is a 0 0 m a . .- m m M m an ins an \ _ 0.4 00 06 z ab a.4 a4 U n n n n n N • O 0 F O <2a. 2 2 o a 2 2 <a F aa COan161 ao ru m n .<i o v i Z O O O N O V ,-1 N D N N N N N N N �' 3cc N ,f) N • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-01 was completed in 2016 as horizontal producer in the Kuparuk A4 formation. The well was 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: Schlumberger Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 20,000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU SLB 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 250 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM Cs` as quick as possibler.pressure permitting. Slowly increase annulus pressure from it_� � 2,500 psi to ;500 psi as the tubing pressures up. Ensure sufficient volume is Gph1 IIs/2°— pumped t�d Fe well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 8040 psi. • 400 bbls YF127FLEXD Pad • 107 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 20bpm, pulsed • 103 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite@ 20bpm, pulsed • 111 bbls YF127FLEXD w/4 ppa 16/20 Carbolite@ 20bpm, pulsed • 125 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite@ 20bpm, pulsed • 132 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite@ 20bpm, pulsed • 118 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite@ 20bpm, pulsed • Drop ball 1, displace with 15 bbls YF127FLEXD • 400 bbls YF127FLEXD Pad © 20 bpm • 100 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 20 bpm i • • 100 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 20 bpm • 140 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20 bpm • 40 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20 bpm • Drop ball 2, displace with 15 bbls YF127FLEXD • 400 bbls YF127FLEXD Pad • 107 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 20bpm, pulsed • 103 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 20bpm, pulsed • 111 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 20bpm, pulsed • 125 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 20bpm, pulsed • 132 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20bpm, pulsed • 118 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20bpm, pulsed • Drop ball 3, displace with 15 bbls YF127FLEXD • 400 bbls YF127FLEXD Pad • 100 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 20 bpm • 100 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 20 bpm • 140 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 20 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20 bpm • 40 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 20 bpm • Drop ball 4, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 129 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 25bpm, pulsed • 121 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 25bpm, pulsed • 151 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 25bpm, pulsed • 159 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 25bpm, pulsed • 179 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 25bpm, pulsed • 150 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25bpm, pulsed • 50 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25bpm, pulsed • Drop ball 5, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 25 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 25 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 25 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 25 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite • • Drop ball 6, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 129 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 25bpm, pulsed • 121 bbls YF127FLEXD w/2 ppa 16/20 Carbolite @ 25bpm, pulsed • 151 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 25bpm, pulsed • 159 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 25bpm, pulsed • 179 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 25bpm, pulsed • 150 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25bpm, pulsed • 50 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25bpm, pulsed • Drop ball 7, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 25 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/ 4 ppa 16/20 Carbolite @ 25 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 25 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 25 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 25 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 25 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 25 bpm • Drop ball 8, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 30 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 30 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • Drop ball 9, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 30 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 30 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • Drop ball 10, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • • • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 30 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 30 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • Drop ball 11, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 30 bpm • 110 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 30 bpm • 120 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 30 bpm • 130 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 30 bpm • 100 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 30 bpm • Drop ball 12, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 35 bpm • 130 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 35 bpm • 130 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 35 bpm • 140 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 35 bpm • 150 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 35 bpm • 160 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • Drop ball 13, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/ 2 ppa 16/20 Carbolite @ 35 bpm • 130 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite @ 35 bpm • 130 bbls YF127FLEXD w/4 ppa 16/20 Carbolite @ 35 bpm • 140 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 35 bpm • 150 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite @ 35 bpm • 160 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • Drop ball 14, displace with 15 bbls YF127FLEXD • 450 bbls YF127FLEXD Pad • i • 120 bbls YF127FLEXD w/ 1 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/2 ppa 16/20 Carbolite @ 35 bpm • 130 bbls YF127FLEXD w/ 3 ppa 16/20 Carbolite © 35 bpm • 130 bbls YF127FLEXD w/4 ppa 16/20 Carbolite © 35 bpm • 140 bbls YF127FLEXD w/ 5 ppa 16/20 Carbolite @ 35 bpm • 150 bbls YF127FLEXD w/ 6 ppa 16/20 Carbolite © 35 bpm • 160 bbls YF127FLEXD w/ 7 ppa 16/20 Carbolite @ 35 bpm • 120 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • 40 bbls YF127FLEXD w/ 8 ppa 16/20 Carbolite @ 35 bpm • Flush with 100 bbls of YF127FLEXD • Flush with 100 bbls of linear fluid (WF127) and freeze protect • Total Sand: Approx: 400,000 lbs 16/20 Carbolite 12. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). ConocoPhillips discloses that it will be using the listed volumes of ZeroWash®Tracer, Chemical Frac Tracer, and Oil Frac Tracer for tracing purposes in the concentrations detailed in the attached Core lab Hydraulic Fracturing Fluid Product Component Information Disclosure. In support of this application, ConocoPhillips provides the front page of the Core Lab/Protechnics' MSDSs for each of the chemical additive, as well as the Hydraulic Fracturing Fluid Product Component Information Disclosure provided by Core Lab/Protechnics. Core Lab/Protechnics will supply the AOGCC with additional chemical disclosure information for the proprietary additives listed in the Hydraulic Fracturing Fluid Product Component Information Disclosure ATTACHMENT 1:PUMP SCHEDULE • MAWP 9800 Mo Slurry Rale 36 Highest Pump 8800 Proppam Density 2.71 Well Name 2S-01 AFE Nitrogen PRV 9000 Anulus Pressure 3600 Fluid Type YF127FlexD Prappant Used 16120 emboli. STEP STAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Clean Encaps. PUMP TIME 6 6 TYPE RATE PATE STAGE CUM STAGE CUM STAGE CUM SCE GROES CUM Pulse Breaker STAGE CMM (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LW (LEIS) IBM) (OOL) (sec) (MMpaG) Ihh:mm:ssl Ihh:mm:ss) 1 Injection test WF127 20 20.0 250 250 10496 10496 250 250 8.0 00:12:29 00:12:29 Hare shutdown;manor pressure. 0.0 05.00:00 00:12:29 2 Pad YF127FIe9D 20 20.0 200 450 8,400 18,896 200 450 8.0 00:10:00 00:2229 5 Displacement WF127 20 20.0 250 700 10,496 29,391 250 700 8.0 00:12:29 00:34:58 Hard shutdown;monitor pressure, FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Clean Encaps. PUMP TIME STEP STAGE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SUE GROSS CUM Pulse Breaker STAGE CUM 6 0 PPA (13PM) (SPM) (BBL) (BBL) (GAL) (GAL) (LEG) (LES) (BBL) (BBL) (sec) IBM9al) )MSL) (BBL) 6 PAD YF727FIe0D 20 20.0 400 1,100 16,800 46,191 0 0 0 400 1,100 8.0 00:20:00 00:54:58 7 1 PULSED YF127FlexD 20 19.2 107 1,207 4,507 50,698 2,159 2,159 -..s...3,5:. 103 1,203 15 8.0 00.05:21 01:00:19 8 5 PULSED YF727FIe80 20 184 103 1,310 4,318 55,015 3,988 8,127 94 1,297 19 8.0 00:05:08 01:05:27 8 PULSED YF127FlexD 20 17.- 111 1,421 4,670 59,686 6,192 12,319 98 1,395 19 10.0 00:05:33 01:11:00 10 r PULSED YF127FlexD 20 17.0 125 1,546 5,254 64,940 8,945 21,264 106 1,501 17 10.0 00:06:15 01:17:15 11 S P1.5.5E0 YF727FIe8D 20 164 132 1,678 5,540 70,480 11,360 32,624 108 1,609 14 10.0 00:06:35 01:23:50 12 PULSED YF127FIe8D 20 15.8 118 1,796 4,948 75,427 11,756 44,380 93 1,703 11 10.0 00:05:53 01:29:43 13 _ TAIL.IN YF127FlexD 20 15.8 40 1,836 1,680 77,107 7,984 52,364 1.. 32 1734 10.0 00:02:00 01:31:43 14 0, i DISPLACE YF127FlexD 20 20.0 15 1,851 630 77,737 0 52364 15 1.749 8.0 00:00:45 01:32:28 15 PAD YF127FlexD 20 20.0 400 2,251 16,800 94,537 0 52,364 400 2.149 8.0 00:20:00 01:52:28 16 1 FLAT YF127FlexD 20 19.2 100 2,351 4,200 98,737 4,022 56,386 16m0.,, 96 2,245 8.0 00:05:00 01:57:28 17 2 FLAT YF127FlexD 20 184 100 2,451 4,200 102,937 7,717 64,103 torso ca,9.. 92 2,337 8.0 00:0500 02:02:28 18 3 FLAT YF127FlexD 20 17.7 120 2,571 5,040 107,977 13,348 77,451 um CarEV.C, 106 2,443 10.0 0506:00 02:08:28 19 4 FLAT YF127FlexD 20 17.0 120 2,691 5,040 113,017 17,129 94,580 1600 parkas. 102 2,545 10.0 00:06:00 02:14:28 20 5 FLAT YF127FlexD 20 16.4 140 2,831 5,880 118,897 24,074 118,654 16125 camotaa 115 2,659 10.0 00:07:00 02:21:28 21 6 FLAT YF127FlexD 20 15.8 120 2,951 5,040 123,937 23,896 142,550 ism Carbone 95 2,754 10.0 00:06:00 02:27:28 22 8 FLAT YF127FlexD 20 15.8 40 2,991 , 1,680 125,617 7,965 150,516 lama Cada... 32 2,786 10.0 00:02:00 02:29:28 23 Ball 1.875" DISPLACE YF727FIe00 20 20.0 15 3,006 630 126,247 0 150,516 15 2,801 8.0 00:00:45 02:3513 24 PAD YF127FlexD 20 20.0 400 3,406 16,800 143,047 0 150,516 400 3,201 8.0 00:20:00 02:50:13 25 1 PULSED YF127FlexD 20 192 M5 3,513 4,507 147,554 2,159 152,675 103 3,304 15 8.0 00:05:21 02:55:34 26 Y PULSED YF127FIex0 20 184 3,616 4,318 151,872 3,968 156,643 94 3,398 19 8.0 050508 050542 27 3 PULSED YF127FlexD 20 177 111 3,727 4,670 156,542 6,192 162,835 98 3,496 19 10.0 00:05:33 03:06:15 26 4 PULSED YF127FlexD 20 17.0 125 3,852 5,254 161,796 8,945 171,780 106 3,602 17 10.0 00:06:15 03:12:30 29 :.:5 PULSED YF727FIe0D 20 164 132 3,984 5,540 167,336 11,360 183,140 1600 O., 108 3,710 14 10.0 00:06:35 03:19:05 30 :8 PULSED YF127FIex0 20 15.8 116 4,102 4,948 172284 11,758 194,896 591.04a, 93 3,804 11 10.0 0505:53 0524:58 31 6 545,44 YF727FIex0 20 158 40 4,142 1580 173,964 7984 202,880 'seriaart 32 _ 3,835 10.0 0502:00 03:28:58 32 Ball 1.938" DISPLACE YF127FlexD 20 200 15 4,157 630 174,594 0 202,880 15 3,850 8.0 00:00:45 03:27:43 33 PAD YF127FIe80 20 20.0 400 4,557 16,800 191,394 0 202,880 400 4,250 8.0 00:20:00 03:47:43 34 1 FLAT YF127FlexD 20 192 100 4,657 4,200 195,594 4,022 206,902 SS00 ceGOLne 96 4,346 8.0 00:05:00 055243 86 2 FLAT YF727F1ex0 20 18.4 100 4,757 4,200 199,794 7,717 214,619 10000arb301te 92 4,438 8.0 00:05:00 03:57:43 36 3 FLAT YF127FIex13 20 17.7 120 4,877 5,040 204,834 13,348 227,967 167208arb30S. 106 4,544 10.0 00:06.00 04:03:43 37 4 FLAT YF127FlexD 20 17.0 120 4,997 5,040 209,874 17,129 245,096 Imo 085.0. 102 4,646 10.0 00:06:00 04:09:43 38 5 FLAT YF127FlexD 20 16.4 140 5,137 5,880 215,754 24,074 269,170 Imo caraane 115 4,760 10.0 00:07:00 04:16:43 39 6 FLAT YF127FIex0 20 15.8 120 5,257 5,040 220,794 23,896 293,066 1600 6.15003. 95 4,855 10.0 00:06:00 04:22:43 40 6 FLAT YF127FIe80 20 15.8 40 5,297 1,680 222,474 7,965 301,032 Lama 6a3bon. 32 4,887 10.0 00:02:00 04:2443 56 Ball 2.0" DISPLACE VF127FIe00 25 25 15 5,312 630 223,104 0 301,032 15 4,902 8.0 00:00:36 04 2519 57 PAD YF127FlexD 25 25.0 450 5,782 18,900 242,004 0 301,032 450 5,352 8.0 00:18:00 04:43:19 58 9y YF127FIexD 25 239 - 139 5,891 5,431 247,434 2,602 303634 40386506x6. 127 5479 17 8.0 00:05:10 0448:29 TA ,��, YF127F1ex0 25 230 121 6,013 5099 252,533 4,689 308323 1V254aare14.q 117 5596 18 8.0 00:04:51 0453:20 m YF127FIeXD 25 221 151 8,163 6,321 258,854 8,384 316707 leattp6,4k.y. 142 5738 16 10.0 0008:01 04.59:21 61 ) ti at{. YF127FIex0 25 212 159 6,322 5657 265511 , 11,328 328035 lacataar1A440,, 147 5885 15 10.0 000620 05:05:41 99 YF727FIexD 25 20.5 179 6,501 7,535 273,046 15457 343,492 15M04C59360a 163 6,048 12 10.0 00:07:10 05:12:51 93 YF/27FIexD 25 198 150 8,851 6,300 279,346 14,969 358461 a 134 6,182 10 11.0 00:08:00 05:18:51 _ 64 Sri 1'„* YF127FIex0 25 198 „ 50 6,701 2,100 281,446 9,980 368441 3/440944 oiMkE 40 5222 10.0 0502:00 05:20:51 85 Ball 2.063" DISPLACE YF127FlexD 25 25.0 15 6,716 630 282,076 0 368,441 15 6,237 8.0 00:00:36 05:21:27 66 PAD YF727FIe8D 26 25.0 450 7,186 18,900 300,976 0 388,441 450 6,687 8.0 00:18:00 05:39:27 67 1 FLAT YF127FIe0D 25 23.9 125 7,291 5,250 306,226 5,028 373,468 1095 8.0035 120 6,806 8.0 00:05:00 05:44:27 68 2 FLAT YF127FIexD 25 23.0 125 7,416 5,250 311,476 9,646 383,115 16125 areas 115 6,921 , 8.0 00:05:00 05:49:27 69 3 FLAT YF127FIe80 25 22.1 150 7,566 6,300 317,776 16,685 399,800 maa.,5ob. 132 7,054 10.0 00:08:00 05:55:27 70 4 FLAT YF727FIe80 26 21.2 1 3 7,726 6,720 324,496 22,838 422,638 10,35 05,54.., 136 7,190 , 10.0 00:06:24 06:01:51 TI 5 FLAT YF127FlexD 25 20.5 7,906 7,560 332,056 30,953 453,590 um careoure 147 7,337 10.0 00.07:12 06:09:03 12 6 FLAT YF127FlexD 25 19.8 8,066 6,720 338,776 31,862 485,452 tarso Cal0LM 126 7,463 11.0 00:06:24 06:15:27 73 FLAT YF727FIexD 26 19.8 8,106 1,880 340,458 7,965 493,418 16x0 Cs.. 32 7,495 10.0 00:01:36 06:17:03 74 t;...! DISPLACE YF127FlexD 26 25.1. 8,121 630 341,086 0 493,418 15 7,510 8,0 00:00:36 06:17:39 75 PAD YF727FIex13 26 25.5 8,571 18,900 359,986 0 493,418 450 7,960 8.0 00:1500 06:35:39 le PULSED YF127FlexD 25 23.9 129 8,700 5,431 365416 2602 496,020 4enbrU= 127 6,087 17 8.0 00:05:10 06:40:49 77 ‘,11.4";" PULSED YF127FlexD 25 23.0 121 8522 5099 370515 4,689 505709 A9915145e, 117 8,204 , 18 8.0 0504:51 06:45:40 78 3 PUL5E0 Y5727FIO 0 25 22 151 8572 5321 375836 5384 509,093 .101135.,11 142 5346 16 10.0 00:06:01 06:51:41 79 I PULSED YF727FIe00 26 21.2 159 9,191 6,657 383,493 11,328 520,421 152 147 5493 , 15 10.0 005620 06:58:01 68 S PULSED YF127FlexD 25 20 1 179 9,310 7,535 391,028 15,457 535,878 IV 163 8,656 12 10.0 00:07:10 07:05:11 81 6 PULSED YF127FlexD 26 15.8 9,460 8,300 397,328 14,969 550,847 i3 134 8,790 10 11.0 00:06:00 07:11:11 82 :6 TAIL-IN YF127FlexD 25 19.5 9,510 2,100 399,428 9,980 580,827 La 40 8,830 10.0 00:02:00 07:13:11 83 Ball 2.188 DISPLACE YF127FIe00 26 20.0 9,525 630 400,058 0 560,827 15 8,845 8.0 0500:38 07:13:47 84 PAD YF727FIe00 25 250 450 9,975 18,900 418,958 0 560,827 450 9,295 8.0 0518:00 07:31:47 as 1 FLAT YF127FIe0D 26 23.9 120 10,095 5,040 423,998 4,826 585,653 IRrs00amoLE. 115 9,410 8.0 00:04.48 07:36:35 86 2 FLAT YF127FlexD 25 23.0 120 10,215 5,040 429,038 9,281 574,914 16740 art.... 110 9,520 8.0 00:04:48 07:41.23 87 3 FLAT YF127FlexD 26 22.1 110 10,325 4,820 433,658 12,236 587,149 1620 0am.... 97 9,617 10.0 00:04:24 07:45:47 88 4 FLAT VF127FIe00 25 21.2 110 10,435 4,620 438,278 15,701 602,851 93 9,711 10.0 00.04:24 07:50:11 89 5 FLAT YF127FIe00 25 20.5 110 10,545 4,620 442,898 18,915 621,766 1620 60rbALE. 90 9,801 10.0 00:0424 07:54:35 90 6 FLAT YF127FIe80 26 19.8 120 10,685 5,040 447,938 23,896 645,662 IOGOOrbiIts 95 9,896 10.0 00:04:48 07:59:23 9, 7 FLAT YF127FIe00 25 19.1 130 10,795 5,460 453,398 , 29,182 674,844 Lam CarbOLIN 99 9,995 10.0 00:05:12 08:04:35 92 8 FLAT YF127F1e80 25 18.5 100 10,895 4,200 457,598 24,816 699,660 15,35 0.,5305. 74 10,069 10.0 00:04:00 08:0825 93 8 FLAT VF127FIe80 25 185 40 10,936 1,680 459,278 9,926 709,587 tarso 0,50.0. 30 10,098 10.0 00:01:36 08:10:11 94 Ball2.25" DISPLACE YF127F1e00 25 25 15 10,950 630 459,908 0 709,587 15 10,113 8.0 00:00:36 08:10:47 95 PAD YF127Fle00 30 30.0 450 11,400 18,900 478,808 0 709,587 450 10,563 8.0 00:15:00 08:25:47 96 1 FLAT YF727FIe0D 30 28.7 120 11,520 5,040 483,848 4,826 714,413 lSl00...u. 115 10,678 8.0 00:04:00 08:29:47 97 2 FLAT YF127FIexD 30 27.6 120 11,640 5,040 488,888 9,261 723,674 two arrouts 110 10,789 8.0 00:04:00 08:33:47 98 3 FLAT YF127FIe80 30 26.5 110 11,750 4,820 493,508 12,238 735,910 Lam.rbow. 97 10,886 10.0 00:03:40 08:37:27 99 4 FLAT YF127FlexD 30 25.5 110 11,860 4,620 498,128 15,701 751,611 1620 carcase 93 10,979 10.0 00'03'40 08:41:07 100 5 FLAT YF127FIe00 30 24.6 110 11,970 4,620 502,748 18,915 770,526 1805.115308. 90 11,089 10.0 00:03:40 08:44:47 101 6 FLAT VF127F6000 30 237 120 12,090 5,040 507,788 23,896 794,422 1e05camerae 95 11,164 10.0 00:04:00 08:48:47 102 7 FLAT YF127FlexD 30 22.9 130 12,220 5,460 513,248 29,182 823,604 10,30 0.mol.. 99 11,263 10.0 00:04:20 08:53:07 103 8 FLAT VF127FIeOD 30 22.2 100 12,320 4,200 517,448 24,818 848,420 16G0 Gamuts 74 11,337 10.0 00:03:20 08:56:27 104 8 FLAT YF127F1e80 30 22.2 40 12,360 1,680 519,128 9,926 858,347 1500.3551.8. 30 11,367 10.0 00:01:20 08:57:47 10s I Ball 2.313" DISPLACE YF127FlexD 30 30 15 12,375 630 519,758 0 858,347 15 11,382 8.0 00:00:30 08:58:17 106 1 PAD YF127FIe05 30 30.0 450 12,825 18,900 538,658 0 858,347 450 11,832 8.0 00:15:00 09:13:17 107 1 1 FLAT YF127FIe60 30 28 7 120 12,945 5,040 543,698 4,826 863,173 mirto caftans 115 11,947 8.0 00:04:00 09:17:17 108 1 2 FLAT YF727FIe00 30 27.6 120 13,065 5,040 548,738 9,261 872,434 1680.wout. 110 12,057 8.0 00:04:00 09:21:17 109 1 3 FLAT YF127FlexD 30 26.5 110 13,175 4,620 553,358 12,236 884,670 16,30.,5308. 97 12,154 10.0 00:03:40 09:24:57 51O 1 4 FLAT YF127FlexD 30 25.5 110 13,285 4,620 557,978 15,701 800.371two 93 12,247 10.0 00:03:40 09:28:37 111 5 5 FLAT YF127FlexD 30 24.6 110 13,395 4,620 562,598 18,915 919,286 w,3o.woLna 90 12,337 10.0 00:03:40 09:32:17 112 1 6 FLAT YF127FlexD 30 23.7 120 13,515 5,040 567,638 23,896 943,183 trIsio Carbollte 95 12,432 10.0 0004:00 09:36:17 113 1 7 FLAT YF127FlexD 30 22.9 130 13,645 5,460 573,098 29,182 972,365 ie90 cereoute 99 12,532 10.0 00:04:20 09:40:37 114 1 8 FLAT YF727FIe00 30 22.2 100 13,745 4,200 577,298 24,816 997,181 1620.rban. 74 12,605 10.0 00:0520 09:43:57 115 1 8 FLAT YF127F1e013 30 22.2 40 13,785 1,680 578,978 9,926 1,007,107 Lem carer.. 30 12, ____ 10.0 0501.20 09:45:17 116 1 Ball 2.375" DISPLACE YF127F1e00 30 30 15 13,800 630 579,608 0 1,007,107 15 12,650 8.0 00:00:30 09:45:47 117 1 PAD YF727FIe0D 30 300 450 14,250 18,900 598,508 0 1,007,107 450 13,100 8.0 00:15:00 10:00:47 118 1 1 FLAT YF127FlexD 30 287 120 14,370 5,040 603,548 4,826 1,011,934 IWrsa arm... 115 13,215 8.0 00:04.00 10:04:47 119 1 2 FLAT YF127FlexD 30 27.6 120 14,490 5,040 608,588 9,261 1,021,194 1812e0,55.6. 110 13,325 8.0 00:04:00 10:08:47 120 1 3 FLAT YF727FIe9D 30 26.5 110 14,600 4,620 613,208 12,236 1,033,430 I972O Garbo. 97 13,422 10.0 00:03:40 10:12:27 121 1 4 FLAT YF727FIe0D 30 25.5 110 14,710 4,620 617,828 15,701 1,049,131 tamp 03rb0LB. 93 13,516 10.0 0053:40 10:16:07 122 1 5 FLAT YF127FIe0D 30 24.6 110 14,820 4,620 822,448 18,915 1,068,047 'sea care°. 90 13,606 10.0 00:03:40 10:19:47 123 1 6 FLAT YF127FlexD 30 23.7 120 14,940 5,040 627,488 23,896 1,091,943 tarso arboL6. 95 13,701 10.0 00:04:00 10:23:47 124 1 7 FLAT YF127FlexD 30 22.9 130 15,070 5,460 632,948 29,182 1,121,125 Imo 6are.LB. 99 13,800 10.0 00:04:20 10:28:07 125 1 8 FLAT YF127FlexD 30 22.2 100 15,170 4,200 637,148 24,816 1,145,941 1600 03r5on. 74 13,874 10.0 00:03:20 1531:27 126 I 8 FLAT YF127FIe85 30 22.2 40 15,210 1,680 638,828 9,926 1,155,867 Lem 8arb30b 30 13,903 10.0 00:01:20 10:32:47 11-12-15 ill 127 12 Ball 2.438" DISPLACE VF127FIROD 30 ?0 15 15.225 630 639,458 0 1.155,867 15 13.916 8.0 00:00:30 113117 128 12 PAD YF127FIex0 30 30.0 450 15,875 18,900 658,358 0 1,155,867 450 14,368 8.0 00:15:00 10:48:17 129 12 1 FLAT YF727FIe00 30 28.7 120 15,796 5,040 663,398 4,826 1,160,694 1600 Ca5oLlte 115 14,483 8.0 00:04:00 10.52.17 130 12 2 FLAT YF727FIexD 30 276 120 15,916 5,040 668,438 9,261 1,169,954 1680 991100L.. 110 14,593 8.0 00:04:00 10:56:17 131 12 3 FLAT VF127FIexD 30 26.5 110 16,025 4,620 673,058 12,236 1,182,190 1620arbolne 97 14,690 10.0 00:03:40 10:59:57 132 12 4 FLAT YF727FIexD 30 25.5 110 16,135 4,620 677,878 15,701 1,197,891 16/20 arboLile 93 14,784 10.0 00:0140 11:03:37 133 12 5 FLAT YF127FIe00 30 24.6 110 16,245 4,620 682,298 18,915 1,216,807 1680 cob,. 90 14,874 10.0 00:03:40 11:07:17 134 12 6 FLAT YF127FIexD 30 23.7 120 16,365 5,040 687,338 23,896 1,240,703 1620 0.11501. 95 14,969 10.0 00:04:00 11:11:17 135 12 7 FLAT YF727FIe00 30 229 130 16,495 5,460 892,798 29,182 1,269,885 16/20 010boL0e 99 15,068 10.0 00:04:20 11:15:37 138 12 8 FLAT YF727FIe00 30 22.2 100 16,595 4,200 696,998 , 24,816 1,294,701 1680 arbollle 74 15,142 10.0 00:0120 11:18:57 137 12 8 FLAT YF127FIe00 30 222 40 16,635 1,680 698,678 9,926 1,304,627 16000a004L9 30 15,171 10.0 010120 11:20'.17 138 13 Ball 2.448" DISPLACE YF727F1e90 30 30 15 18,650 630 699,308 0 1,304,627 15 15,186 8.0 00:00:30 112147 139 13 PAD YF727FIe00 35 35.0 450 17,100 18,900 718,208 0 1,304,627 450 15,636 8.0 00:12:51 11:3138 140 13 1 FLAT YF727FIe00 35 335 120 17,220 5,040 723,248 4,826 1,309,454 16/20 amoLIN 115 15,751 8.0 00:03:25 11:37:03 141 13 2 FLAT YF727FIexD 35 322 120 17,340 5,040 728,288 9,261 1,318,714 160001054.9e 110 15,862 8.0 00:03:25 11:40:28 142 13 3 FLAT YF727F1e413 36 30.9 130 17,470 5,460 733,748 14,461 1,333,175 1620010boL99 115 15,976 10.0 00:03:42 11:44:10 143 13 4 FLAT YF727FIe0D 35 29.7 130 17,600 5,460 739,208 18,556 1,351,731 10000.560099 110 16,087 10.0 00:03:42 11:47:52 144 13 5 FLAT YF727FIexD 35 28.7 140 17,740 5,880 745,088 24,074 1,375,805 1600 010b0L4. 115 16,202 10.0 00:04:00 11:51:52 145 13 6 FLAT YF727F5080 36 27.7 150 17,890 6,300 751,388 29,870 1,405,675 low ar otne 119 16,320 10.0 00:04:17 11:56:09 148 13 7 FLAT YF727FIe00 35 26.7 160 18,050 6,720 758,108 35,916 1,441,592 1600 0.555. 122 16,442 10.0 00:04:34 12:00:43 147 13 8 FLAT YF727FIe00 36 259 120 18,170 5,040 763,148 29,779 1,471,371 MaoarsoLm 89 16,531 10.0 010325 12:04:08 148 13 8 FLAT YF727FIe00 35 25.9 40 18,210 1,680 764,828 9,926 1,481,297 low aroaOn. 30 16,560 10.0 0001:08 12:05:18 149 14 Balt 2.563" DISPLACE YF727FIexD 36 35 15 18,225 630 765,458 0 1,481,297 15 16,575 , 8.0 00:00:25 12:05:41 150 14 PAD YF727FIe0D 35 35.0 450 18,675 18,900 784,358 0 1,481,297 450 17,025 8.0 0112:51 12:18:32 151 14 1 FLAT YF727FIe00 35 33.5 120 18,796 5,040 789,398 4,826 1,486,124 16009am50lm 115 17,140 8.0 00:03:25 12:21:57 152 14 2 FLAT YF727FIexD 35 32.2 120 18,915 5,040 794,438 9,261 1,495,384 16Go carsoLlte 110 17,251 8.0 00:03:25 12:25:22 153 14 3 FLAT YF727FIexD 35 30.9 130 19,045 5,460 799,898 14,461 1,509,845 16095ars51. 115 17,365 10.0 0103:42 12:29:04 154 14 4 FLAT YF727FIexD 35 29.7 130 19,175 5,460 805,358 18,556 1,528,401 16200.2/2.60 110 17,476 10.0 00:03:42 12:32:46 155 td 5 FLAT YF727FIexD 35 28.7 140 19,315 5,880 811,238 24,074 1,552,475 16R00aM.A.. 115 17,590 10.0 00:04:00 12:36:46 156 14 6 FLAT YF727FIe0D 35 27.7 750 19,465 6,300 817,538 29,870 1,582,345 1026 010901.99 119 17,709 10.0 00:04:17 12:41:03 157 14 7 FLAT YF127FlexD 35 26.7 160 19,625 6,720 824,258 35,916 1,618,262 16126 0.155.99 122 17,831 10.0 00:04:34 12:45:37 558 td 8 FLAT YF727FIe0D 35 25.9 120 19,745 5,040 829,298 29,779 1,648,041 1608 arb:Leo 89 17,920 10.0 00:03:25 12:49:02 159 14 8 FLAT YF727FIexD 35 25.9 40 79,785 1,680 830,978 9,926 1,657,967 1600/22x6. 30 17,949 10.0 00:01:08 12:50:10 160 15 Ball 2.625" DISPLACE YF727FIexD 35 35 15 19,800 630 831,608 0 1,657,967 15 17,964 8.0 00:00:25 12:50:35 161 15 PAD YF727FIe00 35 35.0 450 20,250 18,900 850,508 0 1,657,967 450 18,414 8.0 00:12:51 13:03:26 162 15 1 FLAT YF727FIexD 35 33.5 120 20,370 5,040 855,548 4,826 1,662,794 11/20 arboLrce 115 18,529 8.0 00:03:25 13:06:51 163 16 2 FLAT YFI27FlexD 35 32.2 120 20,490 5,040 860,588 9,261 1,672,054 16ao cartroute 110 18,839 8.0 00:03:25 13:10:16 164 16 3 FLAT YF727FIexD 35 30.9 130 20,620 5,460 886,048 14,461 1,686,515 1600 010001.6. 115 18,754 10.0 00:0142 13:13:58 165 16 4 FLAT YF727FIe0D 35 297 130 20,750 5,460 871,508 18,556 1,705,071 1620 arboEmr 110 18,865 10.0 00:03:42 13:17:40 166 16 5 FLAT YF727FIe0D 35 28.7 140 20,890 5,880 877,388 24,074 1,729,145 11/20 arbuw 115 18,979 10.0 00:04:00 13:21:40 167 15 6 FLAT YF727FIexD 35 27.7 160 21,040 6,300 883,688 29,870 1,759,015 ism car60L99 119 19,098 10.0 00:04:17 13:25:57 168 16 7 FLAT YF727FIexD 35 26.7 160 21,200 6,720 890,408 35,916 1,794,932 1680 Carla.. 122 19,220 10.0 00:04:34 13:30:31 169 16 8 FLAT YF727FIexD 35 25.9 120 21,320 5,040 895,448 , 29,779 1,824,711 1620 arboL.. 89 19,309 10.0 00:03:25 13:33:58 170_ 16 8 FLAT YF727FIexD 35 25,9 40 21,360 1,680 897,128 9,926 1,834,837 1128 Garbxt. , 30 19,338 10.0 00:01:08 13:35:04 171 16 FLUSH YF127F1exD 35 35.0 100 21,461 4,218 901,346 1,834,637 100 19,439 8.0 0102:52 13:37:56 172 15 FLUSH WF127 35 35.0 100 21,561 4,218 905,584 1,834,637 100 19,539 8.0 00:02:52 13:4148 173 16 FLUSH Freezeprofect 16 15.0 , 19 21,580 804 906,368 1,834,637 19 19,558 00:01:18 13:42:04 TOTALS 21,580 1,834,637 19,658 13:42104 SD and obtain ISIP 816 min SIP. WATER VOL FLUSH INFORMATION WELL AND TREATING PRESSURE INFORMATION MODEL AND FRAC.ORIENTATION INFORMATION Dat6FRAC= 700 bbls VOL TO TOP PORT=1223.3 ISIP GRADIENT= 0.76 BHP=4152 psi WO Pe,H,1= MAIN JOB= 18839 bbls Extra 460 bbl. -50420671 USI-Is 3_0 FLUID SG= 1.030 +TBG FRIG=3058 pal TOTAL JOB= 19639 bbls FLUSH VOL=220 FRICTION LOSS= 0.2768 +PEEP FRIG=0300 psi 10989 bbls -with contingency MD TO Tb9 Tail= 12515 -HYD HEAD=2440 psi Angle Through Perls= GENERAL JOB INFO ND BTM SLEEVE= 6063 EST.MAX MP.5870 psi Well Azimuth(t/North). TANKS REQUIRED PIPE TIME(mmp PREF! MD FIRST SLEEVE= 13790 molml1 44,42 <=450 NA per tank pumpable PADISLURRY RATIO Stage 1 35% Stage 9 32% Stage 2 35% Stege 10 32% TOTALS FOR 11 STAGES Stage 3 35% Stage 11 32% UPPER TUBING SIZE= 3.6000 0.0067 Ws Porosity= Stage 4 35% Stage 12 32% NICOLE TUBING SIZE= WAN Water 19,909 bbls Stage 532% Stage 13 29% LOWER TUBING SIZE= IMAM Reserver Pressure.3400 Mink fluid 19,039 bbS Stage 6 32% Slags 14 29% LENGTH 64I0OIE TBG= Permeability= Linear fluid 600 bbls Stage?32% Stage 15 29% LENGTH LOWER TBG= Temperature= 160 Proppant 1.836631 IS Stage 832% CASING SIZE= 4.6000 0.0152 b56.M 910601 57 bbls Stage Ports MD Displ. Pump tune 13:4]:04 hh:mm:ss fl volume Seat Size Stege 1 21569 246.9 Gds Alpha Jd75 1.303 lbs Stage 2 21,072 2390 OE1s 1.76 Stage Ports MD DN. 5097 L066 1.643 gal S9ge3 20,558 231.2 Ws 1.823 name 1 volume Q. F103 821 gal Stage 4 20.040 223.3 6Ws 1.885 Stage 10 18.781 1738 bbls 2.280 J604 1,591 gal Stage 5 19,523 215.5 bias 1948 Stage 11 16,185 164.7 1.10 2.323 M002 1,193 lbs Stage 6 19,007 207.6 fids 2.010 Stage 12 15,589 155.6 bbls 2.385 J891 0175 gal Stage 7 18,490 199.8 Lias 2.073 Stage 13 14,992 146.6 des 2.448 J622 2,588 lbs Stage 8 17,974 191.9 Ws 2.135 Stage 14 14,386 137.3 W= 2.510 Stage 9 17,378 182.8 bias 2.198 Stage 15 13,790 128.3 bbl= 2.573 11-1M5 • • Client: ConocoPhillips Alaska Schlumberger Well: Basin/Field: Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 1/20/2016 Date Prepared: 12/11/2015 4:40 PM Report ID: RPT-40582 Fluid Descriptic n(s) Yf127FIexD:WF127 861,000 Gal Contains:Water,Surfactant,Breaker,Crosslinker,Low Temperature Fiber,Guar Slurry,Scale Inhibitor,Additive, Bactericide,Propping Agent The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. k Proprietary Technology CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* -79 % -----...-......- 52-51-7 2-bromo-2-nitropropane-1,3-diol <0.00001 % 64-19-7 Aceticacid(impurity) <0.0001 % 67-63-0 Propan-2-ol <0.1 % 107-21-1 Ethylene Glycol <0.1 % 110-17-8 Fumaric acid <0.01 % 111-46-6 2,2"-oxydiethanol(impurity) <0.001 % 111-76-2 2-butoxyethanol <0.1 % 112-42-5 1-undecanol <0.01 % 112-53-8 C12 fatty alcohol <0.00001 % 127-08-2 Acetic acid,potassium salt <0.0001 % 1310-73-2 Sodium hydroxide(impurity) <0.1 % 1319-33-1 Boronatrocalcite <0.1 % 1330-43-4 Sodium tetra borate <0.01 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 7631-86-9 Silicon Dioxide <0.001 % 7647-14-5 Sodium chloride <0.01 % 7704-73-6 Monosodium fumarate <0.01 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 Guar gum <1 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 9012-54-8 Hemicellulase enzyme <0.001 % 9016-88-0 1,4-Benzenedicarboxylic acid,polymer with 1,2-ethanediol and a-hydro-w-hydroxypoly <0.0001 % (oxy-1,2-ethanediyl) 9043-30-5 C13 alcohol ethoxylate <0.00001 % 9051-89-2 1,4-Dioxane-2,5-dione,3,6-dimethyl-,(3Rcis)-,polymer with(3S-cis)-3,6-dimethyl- <0.1 % 10043-35-3 Boric acid <0.01 % 10043-52-4 Calcium Chloride <0.01 % 10377-60-3 Magnesium nitrate <0.001 % 14464-46-1 Cristo balite <0.0001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 34398-01-1 Alcohol,C11 linear,ethoxylated <0.1 % 39322-78-6 •Phosphoric acid,dodecyl ester,potassium salt <0.0001 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 66402-68-4 Ceramic materials and wares,chemicals ' 20 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 68153-30-0 Amine treated smectite clay <0.01 % 72283-36-4 Oxirane,2-methyl-,polymer with oxirane,mono-(92)-9-octadecenoate,methyl ether <0.0001 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 125005-87-0 Diutan gum <0.001 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1 % Total 100 •Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. Schlumberger 2015.Used by ConocoPhillips Alaska by permission. Page:1/1 0 • Ati ProTechnics Division 6510 West Sam Houston Parkway North Houston,Texas 77041 Phone 713-328-2320 Fax 713-328-2163 Core Lati www.corelab.corn &6SAYGUA 5'fl4I1A710F Tracing Records for: Operator: ConocoPhillips Alaska Well Name: 2S-01 Stage 1 January 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT2900 Tracer "Trade Secret Status" 0.00005%by weight OFT15450 Tracer "Trade Secret Status" 0.00005%by weight Stage 2 January 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status f CFT3000 Tracer "Trade Secret Status" 0.00005%by weight OFT15400 Tracer "Trade Secret Status" 0.00005%by weight Stage 3 January 16,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT2500 Tracer "Trade Secret Status" 0.00005%by weight OFT15210 Tracer "Trade Secret Status" 0.00005%by weight Stage 4 January 16,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT2400 Tracer "Trade Secret Status" 0.00005%by weight OFT15160 Tracer "Trade Secret Status" 0.00005%by weight ////✓ Stage 5 Janua 17,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status / CFT1300 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) ✓ OFT15850 Tracer "Trade Secret Status" 0.00005%by weight / Stage 6 January 17,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate • Status CFT2000 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) .. tOFT15200 Tracer "Trade Secret Status" 0.00005%by weight Stage 7 January 18,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT1700 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) OFT15750 Tracer "Trade Secret Status" 0.00005%by weight / Attachment II • i • Stage 8 January 18,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT2200 Tracer "Trade Secret Status" 0.00005%by weight,On File(March 2015) )OFT15600 Tracer "Trade Secret Status" 0.00005%by weight Stage 9 January 19,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT2100 Tracer "Trade Secret Status' 0.00005%by weight OFT15190 Tracer "Trade Secret Status" 0.00005%by weight Stage 10 January 19,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status 7; CFT1600 Tracer "Trade Secret Status" 0.00005%by weight OFT15170 Tracer "Trade Secret Status" 0.00005%by weight Stage 11 January 20,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT1500 Tracer "Trade Secret Status" 0.00005%by weight, / OFT15050 Tracer "Trade Secret Status" 0.00005%by weight V/ Stage 12 Janua 20,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT1900 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) V, OFT15010 Tracer "Trade Secret Status" 0.00005%by weight I Stage 13 January 21,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status ' CFT1200 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015)i 17 OFT15110 Tracer "Trade Secret Status" 0.00005%by weight . Stage 14 January 21,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT1100 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) OFT15070 Tracer ( "Trade Secret Status" 0.00005%by weight Stage 15 January 22,2017 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate Status CFT1000 Tracer "Trade Secret Status" 0.00005%by weight On File(March 2015) 1,, OFT15000 Tracer "Trade Secret Status" 0.00005%by weight !✓ Attachment II • • '0 TD C -0 ((f)'C3 o 2 Q 0 1 (0 L L, _ ca a)a 0) —ti/ Cs .-1= 6 -5 (N 2 • (1) CU 0.) Q.) Qi 0.1 W 4-4 4-4 4-0 4-4 4-4 4.4 4-4 4-4 CL :1'3 17,1 =1 ID :Zi 0 0 0 0 0 0 0 0 11-4.1 L. S . L. L. C ft) (t) ft3 ROULJULJOUUL) CL000000000 CL• NNNNNNNN 0 LO LC) LO Qv-Iv-I -1 T-1 r-I 0 1^.^. Lt) N CO 0 0 N cr) r-i •:1" 'zZt* 100-1 r-i 411 = . 0 0 0 0 0 0 0 0 N N N N N N N N a) 00 Go et. .._ = a) CD 0 0 0 0 0 0 0 0 Co co >< xxxx xxx cu a) a) a) a) a) a) a) 1— LL LL LL LL Li. 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N 4.0NNNNNNNNNNN U. .5 ,1 ,---1 r-.1 r-1 r-1 r-i c-1 s-.1 r-1 c-1 t-1 IL 1.1. IL- LL U.. LL LI- LL IL IL LL VI 4-0 C a) a) u E a= E 0-0 4-0 4-J 4-1 4-1 co 4-1 0 (f) (-0 03 CO (10 (Ts co ro co (13 ris L.) Ei 0... u. u.. u.. u.. u... u. L.L... L.L.. U- r-1 r..1 teni.0 r-- oo oo < Cl. CL CU tO co h_ a) — > ra .4 co (1) (1) CU CU (1) CU CU 4-.1 .1.-; 4- 000000000 In -0 In -0 -0 -0 -0 -0 -0 4.# S.- S-. S-. S-. S.. S.. S.- S.. r0 (0 CU 03 (0 (0 ft (0 co UOVUOVUUU C2. 0 0 0 0 0 0 0 0 0 NNNNNNNNN 2 t.c) kr) tr.) (ID t.0 CL r-i r-i c—I r-1 r-i r-I In 0 0, 0 0 0 C) CD gg (-4 rr-I N .0 (i) . Lno000000000 (*NJ m (r) rn (r) rn rn CY) C\1 (1,0) ro c21 01) a) cCo a 0 0 0 0 0 0 0 0 0 0 0 (7) xx xxx x xxx xx cu ,a) (1) a) a) as as (1) a) (1) LL LL U. U. LL LL U. U. LL LL U. 10 N. N N N N N N N N N N NNNNNNNNNNN ILL r-1 r-i r-i r-i U- U. U. U. LL LL U. LL U- ›- cn +.0 C cu U E (13 E - 4.4 4-, +- l 4,..1 4.4 O (4 (t) (1:3 a3 (0 CO r0 (0 U O . Q. U. U U. U. U u_ U. U. 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CU — > (1:3 14t CO • • 4._ — 0 '4: 0 .1...J o -oa) 0E cn O co o a, E °na) a 0 ••= --_ 0 CO O)4-- — .IW = -0 Cfl to' Co) r •U.4•010 0 s- = -� Qs- ...,= L- (n 0 22 D cn Eo •— cow 0 LI- N'' Ca 1 1 1 1 1 0 0 0- 0 n = 0 47 0) — " C 0 t 0 .f O = CO 1 — }' ca 0 00 I-_ J _ N c_n c c cn co •mi0 > E 4.1 cl) -a •0 �' .4... i 5, 0 ooa) ms -0 t„ oCD0 'h _C 2 � m � — ' i • z� � 0 •- o m = i .� 0 O Q's= — �O cii T ^^L Z 0 0 Ag. 0 LL = i C sw - To to C' _ cz 0 E •c 'o N ,_ ,_ o 7 CV •- CU i a—� c O N +r o 'J > co w -0 0 = •— -0 0 _ — '— O c c o O O 0 I . • i SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) • • Wallace, Chris D (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Friday, January 15, 2016 10:22 AM To: Wallace, Chris D (DOA) Subject: RE: Sundry 316-026 Well KRU 2S-01 PTD 2152030 Frac treatment Chris, Thank you for your quick review of the sundry. See below for your answers: Let me know if I can assist with anything else. Also, our frac date has been pushed back slightly as of this morning to January 21, so not as soon as we originally planned. Adam Klem From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, January 15, 2016 9:39 AM To: Klem, Adam Subject: [EXTERNAL]Sundry 316-026 Well KRU 2S-01 PTD 2152030 Frac treatment Adam, We are in the process of reviewing the Sundry Application received by AOGCC on January 14, 2016, with a stated estimated date for commencing operations of January 18th. As per 20 AAC 25.283 (c)" When hydraulic fracturing is done through a fracturing string, the fracturing string must be (1) stung into a liner or run on a packer set at a measured depth of not less than 100 feet below the cement top of the production casing or intermediate casing; and (2) tested to not less than 110 percent of the maximum anticipated pressure differential to which the fracturing string may be subjected. For(1)- Please provide the MD of the premier packer/top of 4%" liner that satisfies the 100 ft. Please confirm the TOC as I read it as 11032 ft. We have not run the tubing yet, however the planned depth is right around 12,235' for the production packer. It may move a little but still way below the required 100' from TOC. We did not log the TOC, but the job was pumped as designed (full returns and reciprocated pipe during job, bumped plug on schedule, floats held)giving an estimated of TOC 10,878'. For(2)—I read the IA backpressure to be held is 3500 psi. I read the maximum expected pressure is 8040 psi. That makes the max differential of 4540 psi requiring a tubing test of 110%or 4994 psi. Please let me know if I am mistaken or if you wish to change any of these numbers? Sorry,the pressure on the IA should have been updated to show that we will hold 4000psi. Our standard is 3500, but due to the length of the tubing and liner, the treating pressure is expected to be higher than our usual completion. So the pressure tests will be as follows: IA:4000psi,tubing: 4500psi. / 49-49--r si TT/�. !'//n Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 333 West 7th Avenue • • Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.ciov. 2 OF 77.1, S • STHE STATE Alaska Oil and Gas �.;, Of /,` TAsK,6„i Conservation Commission 333 West Seventh Avenue 1/41"10, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '11,74, 1, Main: 907.279.1433 AL AS 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-01 ConocoPhillips Alaska, Inc. Permit No: 215-203 Surface Location: 3012' FNL, 1261' FEL, SEC. 17, T1ON, RO8E, UM Bottomhole Location: 4780' FNL, 356' FEL, SEC. 21, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oer ter Chair DATED this /' 'da day of November, 2015. STATE OF ALASKA RECEIVED 11110KA OIL AND GAS CONSERVATION COISION NOV 12 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: 1 b.Proposed Well Class. Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑Q - Service- Winj ❑ Single Zone ❑2 , Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q ' Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. , Bond No. 59-52-180 , KRU 2S-01 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: ' 21,740 TVD: , 6,409 Kuparuk River Field- 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Wit Surface: 3012'FNL, 1261'FEL, Sec 17, T1ON,R008E,UM ADL 256041 AS6-03 USTI Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2069'FNL,3631'FEL,Sec 15,T1ON,R008E,UM 2677,2678 12/1/2015 Total Depth: 9.Acres in Property: ?It 14.Distance to Nearest Property: 4780'FNL, 356'FEL, Sec 21,T1ON,R008E, UM , 20 �`p'�a`, 5659 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- 481309 y- 5930036 Zone- 4 . GL Elevation above MSL(ft): 120 . to Same Pool: KRU 21-10-8:978' 16.Deviated wells: Kickoff depth: , 600 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 90 degrees Downhole: 3826`• Surface: 3185 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 79' 39.5' 39.5' 118' 118' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 3192' 39.5' 39.5' 3231' 2730' 1324 sx DeepCRETE,195sx DeepCRETE 1(N X 9.875" 7.625" 29.7# L-80 Hydril 563 12666' 39.5' 39.5' 12705' 6248'z..$-(4,' 791 sx GasBLOK,205 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 9190' 12550' 6211' 21740' 6409' N/A 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 1(/' C7/f 22. I hereby certify that the foregoing is true and the procedure approved herein will not Jacob Voss 265-6935 be deviated from without prior written approval. Contact 1i---- jake.voss@cop.co Email Printed Name G.L.Alvord /� Title Alaska Drilling Manager Signature A_ 6_ 4. . Phone 265-6120 Date /f(10 (Z.45- Commission .r5- Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: c,216--- a,,, 50-ro3- QQ�a?_� -ob Date: i t 11`6 l(s requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Vi Other: 3 Sao p (�os(" Samples req'd: Yes❑ No[ ' Mud log req'd:Yes❑ No yr Z Sbb fay. i4h,,c,_.C6-, T 5�_- H2S measures: Yes .Z No❑ Directional svy req'd:Yes[2'No❑ Spacing exception req'd: Yes ❑ Nog Inclination-only svy req'd:Yes❑ No[r Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: 1(A4$11 . COMMISSIONER THE COMMISSION Date://-4,/../S (s' M i('I/ `� � � ?nr- j l Submit Form and Form 401(Revis(.� d 11/2015) GReirt6 lallo onths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-01 Saved: 10-Nov-15 Post Office Box 100360 RECEIVED Anchorage,Alaska 99510-0360 Phone(907)265-6935 NOV 1 2 2015 ConocoPhillips Email: iake.vossaconocophillips.com AOGCC November 10,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-01,A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is December 1,2015. It is planned to use rig Doyon 25./ 2S-01 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+1-3,231' MD/2,730' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 12,705'MD/6,248'TVD.The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/-21,740'MD/6,409'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. A proposed completion diagram. 7. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jacob Voss at 265-6935 (jake.voss(aiconocophillips.com)or Chip Alvord at 265-6120. Sincerely, c_ et, Chip Alvord Drilling Manager • i Application for Permit to Drill Document 01111) Kuparuk Well 2S-01 conoc ,inips Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-01 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3012' FNL, 1261' FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 159.5' AMSL Northings: 5,930,036.15' Eastings: 481,309.01' Pad Elevation 120'AMSL Location at Top of 2069' FNL,3631' FEL, Sec 15,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 13,469' Northings: 5,930,963.25' Eastings: 489,498.10' Total Vertical Depth, RKB: 6,351' Total Vertical Depth, SS: 6,192' Location at Total Depth 4780' FNL, 356' FEL, Sec 21,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 21,740' Northings: 5,922,975.48' Eastings: 487,496.75' Total Vertical Depth, RKB: 6,409' _ _ Total Vertical Depth, SS: 6,250' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 25. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-01 is calculated using an estimated maximum reservoir pressure of 3,826 psi (11.6 ppg, based on 2S-02 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,383' TVD (WP10): A Sand Estimated. BHP = 3,826 psi A Sand estimated depth (WP08) = 6,409' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 641 psi (6,383' TVD * 0.10 psi/ft) MPSP = BHP—gas column =3,185 psi (3,826 psi—641psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole weight Length Top MD/TVD Btm MD/TVD (in) ��) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program L 16 24 62.5 H-40 Welded 78 Surf 118/118 Existing �,�` Hydril Cement to Surface with § 10-3/4 13-1/2 45.5 L-80 563 3,192 Surf 3,231/2,730 1,324 sx DeepCRETE Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 791 sx Class G+GASBLOK at 9-7/8- 15.8 ppg w/TOC at 10,820 MD N< 7-5/8 X 29.7 L-80 H563'I 12,666 Surf 12,705/6,248 Stage 2: 205 sx Class G+GASBLOK at 11 . 15.8 ppg w/TOC at 8,872'MD ti 4 1/2 6-3/4 11.6 L-80 IBTM 9,190 12,550/6,213 21,740/6,409 Uncemented Liner with Frac Sleeves • • 2S-01_wp09 Cementing Schematic 16" Conductor to 118' 10-3/4"45.5# L-80 HYD563 3,231' MD/2,730'TVD @ 62.5° inc. it 6th 9-7/8" x 11" Hole Top of 2nd Stage Cement 8,872' MD/4,686'TVD C-37 9,372' MD/4,866'TVD Top of 1st Stage Cement 10,820' MD/5,532'TVD Kalubik 7-5/8" 29.7# L-80 HYD563 Casing 12,194' MD/6,110'TVD 12,705 MD/6,248'TVD @ 77° Kuparuk A 116,. 13,469' MD/6,352'TVD 6-3/4" Hole 4-1/2" Liner 11.6# L80 IBT 21,740' MD/6,409' TVD @ 90° • • 10.75" Surface Casing run to 3,233' MD/2,730' TVD Cement from 3231' MD to 2731'(500' of tail)with DeepCrete. @ 12 ppg, and from 2731'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1417' MD),zero excess in 16"conductor. Lead slurry from 2,701' MD to surface with Arctic Lite Crete @ 11.2 ppg Conductor (115'—0') X 1.339 ft3/ft X 1.0(0%excess) = 154 ft3 Permafrost to Conductor (1,416'—115') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,656 ft3 Top of Tail to Permafrost (2,731 —1,416')X 0.3637 ft3/ft X 1.5 (50%excess) =718 ft3 Total Volume= 154+ 1,656+718=2,528 ft3=> 1,324 sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 3,231' MD to 2,731' MD with 12 ppg DeepCrete Shoe to Top of Tail (3,233—2,733')X 0.3637 ft3/ft X 1.50 (50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=> 194 sx of 12 ppg DeepCrete @ 1.63 ft3/sk 7.625"Intermediate Casing run to 12,705' MD/6,248 TVD 1st stage slurry designed to be at the top of Bermuda/Cairn Formation at 10,820' MD.Top of 2nd stage slurry is designed to be at 8,872' MD,which is 500' above the C-37.Assume 40%excess annular volume. 1st Stage slurry from 12,705' MD to 10,820' MD with 15.8ppg Class G+additives Shoe to Top of Cement (12,705'—10,820)X 0.3428 ft3/ft X 1.40(40%excess) =905 ft3 Shoe Joint (it( 0,0" (80')X 0.2578 ft3/ft X 1.0(0%excess) =21 ft3 Total Volume=905+21 =9E4ft3=>791 sx of 15.8 ppg Class G+GasBLOK @ 1.17 ft3/sk ✓ 5aG 2'"d Stage slurry from 9,372' MD to 8,87,E MD with 15.8ppg Class G+additives Stage Collar to Top of Cement (9,372'—8,872')X 0.3428 ft3/ft X 1.40(40%excess) =240 ft3 Total Volume=240 ft3=>205sx of 15.8 ppg Class G +GasBLOK @ 1.17 ft3/sk • • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 25. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Spud LSND KlaySheild Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6- 11.5 10.5—11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 25 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. • • Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic • • 1. Move in/rig up Doyon Rig 25. Install Annular with 16"diverter line and function test. V 2. Spud and directionally drill 13.5"hole to casing point at+/-3,231 MD/2,730' TVD as per directional plan (wp09). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi 13OP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes./c4Ais " cp< 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Open 9-5/8"x 11"Under Reamer and directionally drill to the top of the HRZ at-11,902' MD/6,008 TVD. Install RCD bearing at this time for use of MPD if necessary. WI-) 9. Directionally drill to intermediate TD of 12,705'MD/6,248' TVD,landing below the K-1 Marker. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 11. Laydown intermediate BHA and rack back 5"DP 4F- 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 12,705' MD. C/o /?4-i^ 4. Z y� fe G�f 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 10,820' MD(top of Cairn IN formation),top of second stage to be 8,871'MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. V 15. Lay down 5"DP. G/o 7 9e "gam -p/'- 16. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,and neutron density)/ 17. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. { 18. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of /// 14.5 ppg EMW leak off,recording results. 19. Directionally drill 6-3/4"hole geosteering though the Kuparuk A4 sand to TD 21,740' MD as per directional plan(wp09). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 11.6#liner. The top of liner will be placed at 12,550'MD,allowing for 150' of overlap in the 7-5/8"casing. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes • • 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes and POOH 27. Run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DSIB). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances, and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • • 2S-01 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp09) 'CAMERON Last Edited: 4-'/"tree,top joint is4-/"12.6#IBTM Voss 11-10-15 16"Conductor to-118' LA t ( 17 13.5" Surface Hole Base West Sak:3,106'MD/2,680'TVD L 3-Y2"x 1-1A"Camco MMG GLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 3,231'MD/2,730'TVD (62.6" INC) 9-7/8" Intermediate Hole ' Tubing: X /i" 3-1/2" 9.3#L-80 EUE 8RD-MOD GL J GLM w/SOV 2nd Stage TOC= 500'MD above C-37 Formation at 8,872'MD/4,686'MD) 1 1 1 1(111 Weatherford Stage Collar:9,372'MD C-37:9,371 MD/4,866'TVD 1s`Stage TOC: Top of Bermuda/Cairn formation) Growler(Iceberg):9,866'MD/5,076'ND Baker 2.812"CMU Sliding Sleeve Cairn:10,820'MD/5,532'TVD 3-%"x 7-5/8",Premier Packer Bermuda:10,945'MD/5,646'TVD 3-%"2.813"XN Nipple HRZ:11,902'MD/6,008'TVD Kalubik:12,194'MD/6,110'TVD '1;"* ' SLB DHG ,.,..n 6.375"x 4-%"Swell Packer Kuparuk C:13,052'MD/6,312'TVD I Kuparuk A4:13,469'MD/6,352'ND-11.5 ppg WA. 111 111 d =Bullet 7-5/8"x 4-%"Baker ZXP Packer/Flex Lock Liner 'M^� IY Hanger ■ ■ ■ ■ ■ soeae°AP" TD:21,740'MD/6,409'ND Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"11.6#L-80 IBTM with Torque Rings 12,705'MD/6,248'TVD(78° INC) 21,739' MD/6,409'TVD • • /". z s z 2 Zm —` T7 _( F13 • P a N � co m u � m II o n -0 —( o O o z m --< MI g g 5 III o 1 m aG� N N iz - v I O _ —< (1) El \ 00 IIIIIIIMINI o ❑ Vf ipp © ❑ N A 1 _ ® ❑ o — = _._._ ® o e >o o ® a 9 q — \V9D — K a di m o m _3 ® >- c 1 (Na —< f D O C) D ia 0 Z A N 0 O 1— T T T T T T/ m 5 • • 2S-OlwpO9 [Mako] 7236 Plan Summary '.5 Top VB�cl(V'S$ k D) C{37o ) -5 ---"-., c 1 > - //IA II /4,,7 - ;... co 0 ik4pTVAI rmB9t(?) C-56-40 - . _.._. , , • i , 0 I I I I I I I � � II I I I I 1 I I I I I 0 ��� 0 5000 10000 7-5/8"X 9-7/8'15000 20000 110-3/4"x 13-1/21' / Measured Depth °1113-2/4" Geodetic Datum: North American Datum 1983 I'® x 13-121' -\_ , Depth Reference: Plan:120+39.5�q 159.50usft(Doyon25) L1L 00 o Rig: Doyon25 . ron $ 000 00 0 N _ y O� O , m7 5/8"X 9-7/8' m oy•- 0 1 4-112"x 6-3/4'1 o - ^o 000 0 0 . . 0 0 t o - 0 0 0 0 0 o I A "1 2 oar., envoi A on ® 0 1 . u1 m rn I __. , S i .__ I I I I I I I I i...i I I i I I o'I t�' I 1 0 2000 4000 6000 8000 10000 12000 14000 16t00.18 W 20000 0 600 - 790 Horizontal Departure 1 790 - 970 123-0).0-46.....4 root 330 _ 30 .01'7•4i ...... 970 - 1160 .. ati; 1160 - 1340 O 1 - s-' , • ' 1340 - 1530 m 60 ;� • • • 300 i+�'� ' 60 1530 - 1710 o_ • 1�\. ......... •..-.... �iiti :i 1710 - 1900 fj ��-�c ...-_ :........ •i _.. .. • :w 7 . 1900 2730 \ ..._. i t 2730 3550 �j 30 \�2S 02 - �� 3550 - 4380 4380 - 5200 o _ ` _ 270 7',. 10M 90 5200 - 6030 2 -03wAQ7(Qaf[Ibp7) _ . '•.,.. 6030 - 6850 U . _.. , --_ 6850 - 7680 y • 7680 - 8500 O I 1 1 1 I I I I I I I I I I I I I I 1 I / • 3 • /I "� _ 8500 - 1016. 0 3000 6000 9000 12000 15000 18000 21000 240 v; ;`} 120 10160 - 1181 2s-04P 1 ".`' SURVEY PROGRAM I ?� 11810 - 1347. Surface Location I �,rho 13470 - 15120 Depth From Depth To Survey/Plan Tool 1'S-0s,�oatw..� �d:�-si; p Pad Elevation: 120.00 �,.�.��- 15120 - 1678. 39.50 800.00 2S-01wp09[Mako (Plan.2S-01) GYD-GC-SS 210 s-�'!i, 150 800.00 1800.00 2S-01wp09 Mako (Plan 2S-01 MWD r'S:; 16780 1843. 800.00 3230.66 2S-01wp09 Mako Plan 2S-01 WD+IFR-AK-CAZ-SC 180 18430 2009. 3230.66 4730.66 2S-01wp09 Mako Plan 2S-01 MWD CASING DETAILS 20090 - 2174. 3230.66 12705.06 2S-01wp09 Mako Plan 2S-01)v1WD+IFR-AK-CAZ-SC 12705.06 14205.06 2S-01wp09 Mako Plan 2S-01) MWD TVD MD Name M 12705.06 21739.58 2S-01wp09[Mako Plan 2S-01Jv1WD+IFR-AK-CAZ-SC 2730.00 3230.66 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 6247.50 12705.06 7-5/8"X 9-7/8" Magnetic Model Date: 30-Dec-15 - 6409.50 21739.58 4-1/2"x 6-3/4" Magnetic Declination: 18.42° To convert a Magnetic Direction to a True Direction,Add 18.421 East SECTION DETAILS .-gm T-3 Sand Sec MD Inc Azi TVD +N/-S OE/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,631 TF,for 400' K-15 Marker 3 1000.00 6.00 63.00 999.27 9.50 18.64 1.50 83.00 -14.00 Start 2.5°/100'DLS,0°TF,for 364.79' 4 1364.79 15.12 63.00 1357.50 39.82 78.15 2.50 0.00 -58.69 Hold for 103.59' 5 1468.37 15.12 63.00 1457.50 52.08 102.22 0.00 0.00 -76.77 Start 3°/100'DLS,-0.73°TF,for 1820.15' -1407.5 8 3288.53 69.72 62.36 2750.87 597.80 1150.58 3.00 -0.73 -875.22 Hold for 5805.01' Base permafrost(7 7 9093.53 69.72 62.36 4762.63 3123.72 5974.54 0.00 0.00-4563.61 Start 3°/100'DLS,111.33°TF,for 3611.53' 8 12705.06 77.60 177.50 6247.50 1693.55 8285.62 3.00 111.33 -3780.32 Hold for 20' -1841.5 9 12725.06 77.60 177.50 6251.79 1674.04 8286.47 0.00 0.00-3761.69 Start 3.01°/100'DLS,68.24°TF,for 349.07' 10 13074.13 81.65 187.34 6314.79 1331.51 8271.80 3.01 68.24 -3427.04 Hold for 0.53' Top W Sak(W Sak.) 11 13074.86 81.85 187.34 6314.87 1330.99 8271.74 0.00 0.00-3428.52 Hold for 0.53' 12 13424.26 87.00 196.45 6349.50 991.08 8200.01 3.01 59.98-3079.83 25-Mako 1.Heel 102115 PB Start 21/100'DLS,-3.43°TF,for 139.98' 13 13584.22 89.79 196.28 6353.41 856.86 8160.59 2.00 -3.43-2939.78 Hold for 691.82' `2679.5 14 14256.04 89.79 196.28 6355.90 192.79 7966.64 0.00 0.00-2248.14 Start 2°/100'DLS,138.82°TF,for 152.45' Base W Sak 15 14408.49 87.50 198.29 6359.50 47.28 7921.36 2.00 138.82 -2095.87 2S-Mako 2.Point 1 102115 PB Start 3.5°/100'DLS,106.92°TF,for 14.8' -2965.5 16 14423.29 87.35 198.79 6360.16 33.27 7916.66 3.50 106.92-2081.12 Hold for 344.69' 17 14767.98 87.35 198.79 6376.11 -292.72 7805.78 0.00 0.00 -1737.54 Start 3.5°/100'DLS,-80.04°TF,for 124.89' 18 14892.88 89.54 195.00 6379.50 -412.15 7769.51 3.50 -60.04-1612.79 2S-Mako 3.Point 2 102115 PB Start 3°/100'DLS,-89.78°TF,for 288.59' 19 15181.47 89.58 186.34 6381.74 -695.47 7716.12 3.00 -89.78-1325.31 Hold for 1724.71' C-80 20 18906.18 89.58 186.34 6394.51 -2409.58 7525.61 0.00 0.00 379.70 Start 3°/100'DLS,91.61 TF,for 465.37' 21 17371.55 89.20 200.30 6399.50 -2861.29 7418.66 3.00 91.60 843.70 25-Mako 4.Point 3 102115 PB Adjust TF to-179.94°,for 0.39' 22 17371.95 89.19 200.30 8399.51 -2861.65 7418.53 3.00 -179.94 844.09 Adjust TF to-179.94°,for 0.39' 23 18772.64 89.19 200.30 8419.32 -4175.22 6932.65 0.00 0.00 2238.66 Hold for 1400.69' -4437.5 24 18806.18 90.20 200.30 6419.50 -4206.68 6921.01 3.00 0.06 2272.05 28-Mako 5.Point 4 102115 PB Start 3°/100'DLS,0.08°TF,for 33.54' C-50 25 21739.58 90.19 187.97 6409.50 -7045.78 6206.11 0.42 -89.99 5199.44 25-Mako 6.Toe 102115 PB Start 0.421/100'DLS,-89.99°TF,for 2933.4' =5703 0 �� 6jG � `r# Growler-AA Permit P k =MeRga41fiaa C-35 8YerRKZ(K�-22k(m(�krr)¢)��HRZ) ,Ai A @fd(. g76jJ`f:Vzikr) E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck Ifeanyi Ifesie • ill 13:44,November 06 2015 Easting(4000 usft/in) 9 �� -28 M- 7i/_', 2M-26 - 2M-24 zH 13 H-11 2H-0, 2H-07 2H-14A — •-38wp07.1 /2H- •AL ' 11�L11 0 — M-31 30 2M 17 2M-22 2H-14 2H-10 2H-01 2H-08 �— 2 9 2M-02 M 0 2 09A 2K-04 2K-03 2]C< 1 2K-05 2K-01 — 2M-1 _ 2 -0 L1-01 ` r 2 -Timb newp10 WIP... 1tJ�AK 15 1- 7 _Ti rlinePB1WP10 — 2M-33 2M-32L1PB1 04 2M-08 2M-09 K 0' Kuparuk 2K Pam 2K-o7 2G-14 rBAP: cR-15L1 2S-14wp07[M.a 2M-32L1PB 4L1 — 2 -34 ��''"'';`\ ` 2G-14A 2G-13AL2 - 2 is2L32Q1 1111.11 �!fi, 2S-13 �Mptel4tliil9]ite]N 35 - L- 1_ K 13AL2 , -2K- 2 -23 S_ - 2S-09wp06[Tiger] 8 Pl4AL1 i - 2S-04 2S-07 K o c— 2S-05wp:..-i1'-:F- 2K-19 $ $'` 2K-1: 14149r ''2K-23 —0= o - v- 2K-2� 2K-22A c - c- Kuparuk 2S Pa K-21A 2K-286 1 -c 2K-25 w O po i 2S-0 2K-21 2K-22 2K-24 - 308PB1 25613':/ Pik „�.1,i4”" 44 — _ 2L-306P61 ' � f� 2K-22AL1-01 r6 2L-31: �,4 (, 2K-22AL1 - - 2L-308 , �/ � K 21-10-8 L-310 2L- 2L- -S a 1 Z. • - .4.1. `'•2L-3 6wp0�-`2 12L-302( .01) 2S-01wp09[Maim] 2L-31 • 2L-320 ';•!Q1Rayi01 — 2 2L-32S-10 ou ..n ..... c_r ..• a rc..I - - r1309 — 2N 01 (wp Prelim: Kuparuk Cairn Pacii27[Bamboo] . . :C17 .:r: : .t,[Squali[.9.ex) i 1 1 i i i 1 i 1 i i i i , i i i i I i i i i I I I I I , i i I I , I I i I I i i i i i i I i I 1 1 i i i i i , I , i Easting(4000 usft/in) • • 2S-01 wp09 [Mako] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4000- 2000— -9; 000- 2000 9; 7-5/8"X 9-7/8"- L 10-3/4"x 13-1/ a 0 2S Mako 1. Heel 102115 PB c � 0— 600 2S-Mako 2. Point 1 102115 PB o N 2S-Mako 3. Point 2 102115 PB 2000— r 0 2S-Mako 4. Point 3 102115 'B 15 04000- 2S-Mako 5. Point 4 102115 'B -6000 28-O1wp09 fMako] 4-1/2"x6-3/4"- , 2S-Mako 6. Toe 102115 PB -8000— -4000 -2000 0 2000 4000 6000 8000 10000 12000 West(-)/East(+) (2000 usft/in) • s 2S-01 wp09 [Mako] Section View -1500 W 0- 0° 1000 c 1500- Z- co0 0 'n 10-3/4"x 13-1/20 _v•'•, _c 3000 do a o o0 N ' O N > 4500 r. o0 0 a) o g i 0 o -0 'o 0 aD /oWO a0 0 0 0 0 0 ai t` 0 0 0 0 0 o x. 6000- —a 01,- o e- In ve0 rn o 'v I 7-5/8"X 9-7/8" o 0' 8' ti 0 0 C /" o 7500- 4-1/2"x 6-3/4" 1 -7 I I I 1 I -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 Vertical Section at 195.00° (1500 usft/in) • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-01 Plan: 2S-01 Plan: 2S-01wp09 [Mako] Report Permit Pack 10 November, 2015 • • Schlumberger Comments apply to Report the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 Well Plan:2S-01 Well Position +N/-S usft Northing: usft Latitude: +El-W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 12/30/2015 18.42 80.86 57,486 Design 2S-01wp09[Mako] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 195.00 Survey Tool Program Date 11/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 800.00 25-01wp09[Mako](Plan:2S-01) GYD-GC-SS Gyrodata gyro single shots 800.00 1,800.00 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 800.00 3,230.66 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,230.66 4,730.66 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 3,230.66 12,705.06 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12,705.06 14,205.06 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 12,705.06 21,739.58 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 39.50 0.00 0.00 39.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.50 0.00 0.00 0.04 200.00 0.00 0.00 200.00 40.50 0.00 0.00 0.19 295.50 0.00 0.00 295.50 136.00 0.00 0.00 0.33 top T-3 Sand 300.00 0.00 0.00 300.00 140.50 0.00 0.00 0.33 11/10/2015 1:05:11PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 384.50 0.00 0.00 384.50 225.00 0.00 0.00 0.48 K-15 Marker 400.00 0.00 0.00 400.00 240.50 0.00 0.00 0.48 500.00 0.00 0.00 500.00 340.50 0.00 0.00 0.62 600.00 0.00 0.00 600.00 440.50 0.00 0.00 0.77 KOP:Start 1.5°/100'DLS,63°TF,for 400' 700.00 1.50 63.00 699.99 540.49 1.50 63.00 0.90 800.00 3.00 63.00 799.91 640.41 1.50 0.00 1.01 900.00 4.50 63.00 899.69 740.19 1.50 0.00 1.08 1,000.00 6.00 63.00 999.27 839.77 1.50 0.00 1.10 Start 2.5°/100'DLS,0°TF,for 364.79' 1,100.00 8.50 63.00 1,098.46 938.96 2.50 0.00 1.17 1,200.00 11.00 63.00 1,197.01 1,037.51 2.50 0.00 1.30 1,300.00 13.50 63.00 1,294.73 1,135.23 2.50 0.00 1.50 1,364.79 15.12 63.00 1,357.50 1,198.00 2.50 0.00 1.68 Hold for 103.59' 1,400.00 15.12 63.00 1,391.49 1,231.99 0.00 0.00 1.79 1,416.58 15.12 63.00 1,407.50 1,248.00 0.00 0.00 2.01 Base permafrost(?) 1,468.37 15.12 63.00 1,457.50 1,298.00 0.00 0.00 2.01 Start 3°/100'DLS,-0.73°TF,for 1820.15' 1,500.00 16.07 62.96 1,487.96 1,328.46 3.00 -0.73 2.12 1,600.00 19.07 62.85 1,583.29 1,423.79 3.00 -0.69 2.53 1,700.00 22.07 62.76 1,676.90 1,517.40 3.00 -0.59 3.01 1,800.00 25.07 62.70 1,768.55 1,609.05 3.00 -0.51 3.59 1,881.37 27.51 62.66 1,841.50 1,682.00 3.00 -0.45 2.14 Top W Sak(W Sak D) 1,900.00 28.07 62.65 1,857.98 1,698.48 3.00 -0.41 2.14 2,000.00 31.07 62.61 1,944.95 1,785.45 3.00 -0.41 2.40 2,100.00 34.07 62.57 2,029.21 1,869.71 3.00 -0.37 2.69 2,200.00 37.07 62.55 2,110.55 1,951.05 3.00 -0.34 3.02 2,300.00 40.07 62.52 2,188.73 2,029.23 3.00 -0.32 3.38 2,400.00 43.07 62.50 2,263.53 2,104.03 3.00 -0.30 3.77 2,500.00 46.07 62.48 2,334.77 2,175.27 3.00 -0.28 4.19 2,600.00 49.07 62.46 2,402.23 2,242.73 3.00 -0.27 4.63 2,700.00 52.07 62.44 2,465.74 2,306.24 3.00 -0.25 5.09 • 2,800.00 55.07 62.43 2,525.12 2,365.62 3.00 -0.24 5.58 2,900.00 58.07 62.41 2,580.21 2,420.71 3.00 -0.23 6.08 3,000.00 61.07 62.40 2,630.86 2,471.36 3.00 -0.23 6.60 3,100.00 64.07 62.38 2,676.92 2,517.42 3.00 -0.22 7.13 3,105.91 64.24 62.38 2,679.50 2,520.00 3.00 -0.21 7.66 Base W Sak 3,200.00 67.07 62.37 2,718.28 2,558.78 3.00 -0.21 7.66 3,230.66 67.99 62.37 2,730.00 2,570.50 3.00 -0.21 8.18 10-3/4"x 13-1/2" 11/10/2015 1:05:11PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit ND Reference: Plan: 120+39.5 @ 159.5ousft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) 3,288.53 69.72 62.36 2,750.87 2,591.37 3.00 -0.21 8.18 Hold for 5805.01' 3,300.00 69.72 62.36 2,754.85 2,595.35 0.00 0.00 8.26 3,400.00 69.72 62.36 2,789.51 2,630.01 0.00 0.00 9.06 3,500.00 69.72 62.36 2,824.16 2,664.66 0.00 0.00 10.03 3,600.00 69.72 62.36 2,858.82 2,699.32 0.00 0.00 11.12 3,700.00 69.72 62.36 2,893.47 2,733.97 0.00 0.00 12.31 3,800.00 69.72 62.36 2,928.13 2,768.63 0.00 0.00 13.56 3,900.00 69.72 62.36 2,962.78 2,803.28 0.00 0.00 14.86 3,907.84 69.72 62.36 2,965.50 2,806.00 0.00 0.00 16.20 C-80 4,000.00 69.72 62.36 2,997.44 2,837.94 0.00 0.00 16.20 4,100.00 69.72 62.36 3,032.09 2,872.59 0.00 0.00 17.57 4,200.00 69.72 62.36 3,066.75 2,907.25 0.00 0.00 18.97 4,300.00 69.72 62.36 3,101.41 2,941.91 0.00 0.00 20.38 4,400.00 69.72 62.36 3,136.06 2,976.56 0.00 0.00 21.81 4,500.00 69.72 62.36 3,170.72 3,011.22 0.00 0.00 23.24 4,600.00 69.72 62.36 3,205.37 3,045.87 0.00 0.00 24.69 4,700.00 69.72 62.36 3,240.03 3,080.53 0.00 0.00 26.15 4,800.00 69.72 62.36 3,274.68 3,115.18 0.00 0.00 13.56 4,900.00 69.72 62.36 3,309.34 3,149.84 0.00 0.00 14.04 5,000.00 69.72 62.36 3,343.99 3,184.49 0.00 0.00 14.53 5,100.00 69.72 62.36 3,378.65 3,219.15 0.00 0.00 15.03 5,200.00 69.72 62.36 3,413.31 3,253.81 0.00 0.00 15.53 5,300.00 69.72 62.36 3,447.96 3,288.46 0.00 0.00 16.03 5,400.00 69.72 62.36 3,482.62 3,323.12 0.00 0.00 16.54 5,500.00 69.72 62.36 3,517.27 3,357.77 0.00 0.00 17.05 5,600.00 69.72 62.36 3,551.93 3,392.43 0.00 0.00 17.57 5,700.00 69.72 62.36 3,586.58 3,427.08 0.00 0.00 18.09 5,800.00 69.72 62.36 3,621.24 3,461.74 0.00 0.00 18.62 5,900.00 69.72 62.36 3,655.89 3,496.39 0.00 0.00 19.14 6,000.00 69.72 62.36 3,690.55 3,531.05 0.00 0.00 19.67 6,100.00 69.72 62.36 3,725.21 3,565.71 0.00 0.00 20.21 6,200.00 69.72 62.36 3,759.86 3,600.36 0.00 0.00 20.74 6,300.00 69.72 62.36 3,794.52 3,635.02 0.00 0.00 21.28 6,400.00 69.72 62.36 3,829.17 3,669.67 0.00 0.00 21.82 6,500.00 69.72 62.36 3,863.83 3,704.33 0.00 0.00 22.36 6,600.00 69.72 62.36 3,898.48 3,738.98 0.00 0.00 22.90 6,700.00 69.72 62.36 3,933.14 3,773.64 0.00 0.00 23.44 6,800.00 69.72 62.36 3,967.79 3,808.29 0.00 0.00 23.99 6,900.00 69.72 62.36 4,002.45 3,842.95 0.00 0.00 24.54 7,000.00 69.72 62.36 4,037.11 3,877.61 0.00 0.00 25.08 7,100.00 69.72 62.36 4,071.76 3,912.26 0.00 0.00 25.63 7,200.00 69.72 62.36 4,106.42 3,946.92 0.00 0.00 26.18 7,300.00 69.72 62.36 4,141.07 3,981.57 0.00 0.00 26.73 11/10/2015 1:05:11PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Makol Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 7,400.00 69.72 62.36 4,175.73 4,016.23 0.00 0.00 27.29 7,500.00 69.72 62.36 4,210.38 4,050.88 0.00 0.00 27.84 7,600.00 69.72 62.36 4,245.04 4,085.54 0.00 0.00 28.39 7,700.00 69.72 62.36 4,279.69 4,120.19 0.00 0.00 28.95 7,800.00 69.72 62.36 4,314.35 4,154.85 0.00 0.00 29.50 7,900.00 69.72 62.36 4,349.01 4,189.51 0.00 0.00 30.06 8,000.00 69.72 62.36 4,383.66 4,224.16 0.00 0.00 30.62 8,100.00 69.72 62.36 4,418.32 4,258.82 0.00 0.00 31.17 8,155.35 69.72 62.36 4,437.50 4,278.00 0.00 0.00 31.73 C-50 8,200.00 69.72 62.36 4,452.97 4,293.47 0.00 0.00 31.73 8,300.00 69.72 62.36 4,487.63 4,328.13 0.00 0.00 32.29 8,400.00 69.72 62.36 4,522.28 4,362.78 0.00 0.00 32.85 8,500.00 69.72 62.36 4,556.94 4,397.44 0.00 0.00 33.41 8,600.00 69.72 62.36 4,591.59 4,432.09 0.00 0.00 33.97 8,700.00 69.72 62.36 4,626.25 4,466.75 0.00 0.00 34.53 8,800.00 69.72 62.36 4,660.91 4,501.41 0.00 0.00 35.10 8,900.00 69.72 62.36 4,695.56 4,536.06 0.00 0.00 35.66 9,000.00 69.72 62.36 4,730.22 4,570.72 0.00 0.00 36.22 9,009.47 69.72 62.36 4,733.50 4,574.00 0.00 0.00 36.75 C-40 9,093.53 69.72 62.36 4,762.63 4,603.13 0.00 0.00 36.75 Start 3°/100'DLS,111.33°TF,for 3611.53' 9,100.00 69.65 62.56 4,764.88 4,605.38 3.00 111.33 36.78 9,200.00 68.59 65.56 4,800.52 4,641.02 3.00 111.26 37.06 9,300.00 67.58 68.60 4,837.85 4,678.35 3.00 110.19 37.25 9,371.47 66.90 70.81 4,865.50 4,706.00 3.00 109.05 37.35 C-37 9,400.00 66.63 71.69 4,876.75 4,717.25 3.00 108.20 37.35 9,500.00 65.75 74.83 4,917.13 4,757.63 3.00 107.85 37.34 9,600.00 64.92 78.00 4,958.88 4,799.38 3.00 106.59 37.23 9,700.00 64.17 81.22 5,001.87 4,842.37 3.00 105.26 37.01 9,800.00 63.48 84.47 5,045.99 4,886.49 3.00 103.88 36.67 9,865.63 63.08 86.63 5,075.50 4,916.00 3.00 102.44 36.21 Growler-AA 9,900.00 62.88 87.76 5,091.12 4,931.62 3.00 101.47 36.21 10,000.00 62.34 91.09 5,137.13 4,977.63 3.00 100.96 35.63 10,100.00 61.89 94.44 5,183.91 5,024.41 3.00 99.43 34.94 10,200.00 61.52 97.83 5,231.31 5,071.81 3.00 97.86 34.12 10,300.00 61.24 101.23 5,279.22 5,119.72 3.00 96.25 33.19 10,400.00 61.04 104.65 5,327.49 5,167.99 3.00 94.62 32.14 10,500.00 60.93 108.07 5,376.01 5,216.51 3.00 92.97 30.99 10,600.00 60.90 111.51 5,424.63 5,265.13 3.00 91.31 29.73 10,700.00 60.97 114.94 5,473.22 5,313.72 3.00 89.64 28.39 10,800.00 61.12 118.36 5,521.65 5,362.15 3.00 87.97 26.97 11/10/2015 1:05:11 PM Page 5 COMPASS 5000.1 Build 74 1 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit ND Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 10,820.41 61.16 119.06 5,531.50 5,372.00 3.00 86.32 25.48 Top Cairn 10,900.00 61.35 121.77 5,569.78 5,410.28 3.00 85.98 25.48 10,945.40 61.49 123.32 5,591.50 5,432.00 3.00 84.67 23.94 Top Bermuda 11,000.00 61.67 125.17 5,617.49 5,457.99 3.00 83.94 23.94 11,059.25 61.90 127.17 5,645.50 5,486.00 3.00 83.05 22.37 Base Bermuda 11,100.00 62.08 128.54 5,664.64 5,505.14 3.00 82.11 22.37 11,153.31 62.33 130.32 5,689.50 5,530.00 3.00 81.46 20.78 C-35 11,200.00 62.56 131.88 5,711.10 5,551.60 3.00 80.63 20.78 11,300.00 63.13 135.19 5,756.75 5,597.25 3.00 79.91 19.20 11,400.00 63.77 138.47 5,801.46 5,641.96 3.00 78.40 17.65 11,500.00 64.48 141.71 5,845.11 5,685.61 3.00 76.93 16.16 11,600.00 65.27 144.91 5,887.58 5,728.08 3.00 75.52 14.78 11,700.00 66.12 148.06 5,928.75 5,769.25 3.00 74.16 13.54 11,800.00 67.03 151.18 5,968.51 5,809.01 3.00 72.86 12.51 11,900.00 68.01 154.25 6,006.75 5,847.25 3.00 71.63 11.75 11,901.99 68.03 154.31 6,007.50 5,848.00 3.00 70.45 11.30 Top HRZ(K-2 mkr) 12,000.00 69.04 157.28 6,043.37 5,883.87 3.00 70.43 11.30 12,100.00 70.12 160.26 6,078.26 5,918.76 3.00 69.34 11.20 12,194.30 71.19 163.04 6,109.50 5,950.00 3.00 68.30 11.47 Upper Kalubik(base HRZ) 12,200.00 71.26 163.20 6,111.34 5,951.84 3.00 67.38 11.47 12,300.00 72.44 166.11 6,142.50 5,983.00 3.00 67.33 12.05 12,400.00 73.66 168.97 6,171.66 6,012.16 3.00 66.42 12.90 12,500.00 74.91 171.80 6,198.75 6,039.25 3.00 65.59 13.96 12,600.00 76.21 174.60 6,223.69 6,064.19 3.00 64.82 15.18 12,700.00 77.53 177.36 6,246.41 6,086.91 3.00 64.12 16.21 12,705.06 77.60 177.50 6,247.50 6,088.00 3.00 63.50 16.26 Hold for 20'-Lower Kalubik(K-1 mkr)-7-5/8"X 9-7/8" 12,725.06 77.60 177.50 6,251.79 6,092.29 0.00 0.00 16.21 Start 3.01°/100'DLS,68.24°TF,for 349.07' 12,800.00 78.44 179.64 6,267.35 6,107.85 3.01 68.24 16.87 12,900.00 79.59 182.47 6,286.40 6,126.90 3.01 67.79 17.86 13,000.00 80.77 185.27 6,303.46 6,143.96 3.01 67.25 18.94 13,051.82 81.38 186.72 6,311.50 6,152.00 3.00 66.78 19.78 Kuparuk C(Top C4) 13,074.13 81.65 187.34 6,314.79 6,155.29 3.00 66.55 19.78 Hold for 0.53' 13,074.66 81.65 187.34 6,314.87 6,155.37 0.00 0.00 19.78 Start 3.01°/100'DLS,59.96°TF,for 349.61' 13,100.00 82.03 188.01 6,318.47 6,158.97 3.01 59.96 20.04 11/10/2015 1:05:11 PM Page 6 COMPASS 5000.1 Build 74 1 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 13,122.35 82.37 188.59 6,321.50 6,162.00 3.01 59.87 21.18 B 13,161.53 82.96 189.62 6,326.50 6,167.00 3.01 59.79 21.18 A6 13,200.00 83.55 190.63 6,331.02 6,171.52 3.01 59.66 21.18 13,204.33 83.62 190.74 6,331.50 6,172.00 3.01 59.54 22.34 A5 13,300.00 85.08 193.23 6,340.92 6,181.42 3.01 59.53 22.34 13,387.90 86.44 195.51 6,347.42 6,187.92 3.01 59.28 23.53 2S-Mako 2.Toe 012815 PB 13,400.00 86.62 195.82 6,348.15 6,188.65 3.01 59.11 23.53 13,424.26 87.00 196.45 6,349.50 6,190.00 3.02 59.09 23.82 Start 2°/100'DLS,-3.43°TF,for 139.96'-2S-Mako 1.Heel 102115 PB-2S-Mako 1.Heel 102115 PB Circle 13,469.19 87.90 196.39 6,351.50 6,192.00 2.00 -3.43 23.82 A4 13,500.00 88.51 196.36 6,352.47 6,192.97 2.00 -3.43 23.82 13,519.52 88.90 196.33 6,352.91 6,193.41 2.00 -3.43 23.79 2S-Mako 2.Toe 13,564.22 89.79 196.28 6,353.41 6,193.91 2.00 -3.43 23.79 Hold for 691.82' 13,600.00 89.79 196.28 6,353.54 6,194.04 0.00 0.00 23.82 13,700.00 89.79 196.28 6,353.90 6,194.40 0.00 0.00 23.95 13,800.00 89.79 196.28 6,354.26 6,194.76 0.00 0.00 24.18 13,900.00 89.79 196.28 6,354.62 6,195.12 0.00 0.00 24.49 14,000.00 89.79 196.28 6,354.98 6,195.48 0.00 0.00 24.88 14,100.00 89.79 196.28 6,355.34 6,195.84 0.00 0.00 25.36 14,200.00 89.79 196.28 6,355.70 6,196.20 0.00 0.00 25.91 14,256.04 89.79 196.28 6,355.90 6,196.40 0.00 0.00 24.29 Start 2°/100'DLS,138.82°TF,for 152.45' 14,300.00 89.13 196.86 6,356.31 6,196.81 2.00 138.82 24.51 14,400.00 87.63 198.18 6,359.14 6,199.64 2.00 138.81 24.94 14,408.49 87.50 198.29 6,359.50 6,200.00 2.00 138.77 24.98 Start 3.5°/100'DLS,106.92°TF,for 14.8'-2S-Mako 2.Point 1 102115 PB 14,423.29 87.35 198.79 6,360.16 6,200.66 3.50 106.92 25.18 Hold for 344.69' 14,500.00 87.35 198.79 6,363.71 6,204.21 0.00 0.00 25.14 14,600.00 87.35 198.79 6,368.34 6,208.84 0.00 0.00 25.14 14,700.00 87.35 198.79 6,372.96 6,213.46 0.00 0.00 25.15 14,767.98 87.35 198.79 6,376.11 6,216.61 0.00 0.00 25.17 Start 3.5°/100'DLS,-60.04°TF,for 124.89' 14,800.00 87.91 197.81 6,377.43 6,217.93 3.50 -60.04 24.74 14,892.88 89.54 195.00 6,379.50 6,220.00 3.50 -60.00 23.45 Start 3°/100'DLS,-89.78°TF,for 288.59'-2S-Mako 3.Point 2 102115 PB 14,900.00 89.54 194.79 6,379.56 6,220.06 3.00 -89.78 23.36 15,000.00 89.55 191.79 6,380.35 6,220.85 3.00 -89.77 22.03 15,100.00 89.56 188.79 6,381.13 6,221.63 3.00 -89.75 20.82 11/10/2015 1:05:11PM Page 7 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5©159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 15,181.47 89.58 186.34 6,381.74 6,222.24 3.00 -89.73 19.95 Hold for 1724.71' 15,200.00 89.58 186.34 6,381.88 6,222.38 0.00 0.00 19.96 15,300.00 89.58 186.34 6,382.62 6,223.12 0.00 0.00 20.13 15,400.00 89.58 186.34 6,383.36 6,223.86 0.00 0.00 20.32 15,500.00 89.58 186.34 6,384.10 6,224.60 0.00 0.00 20.52 15,600.00 89.58 186.34 6,384.84 6,225.34 0.00 0.00 20.74 15,700.00 89.58 186.34 6,385.58 6,226.08 0.00 0.00 20.97 15,800.00 89.58 186.34 6,386.32 6,226.82 0.00 0.00 21.21 15,900.00 89.58 186.34 6,387.06 6,227.56 0.00 0.00 21.47 16,000.00 89.58 186.34 6,387.80 6,228.30 0.00 0.00 21.73 16,100.00 89.58 186.34 6,388.54 6,229.04 0.00 0.00 22.01 16,200.00 89.58 186.34 6,389.28 6,229.78 0.00 0.00 22.31 16,300.00 89.58 186.34 6,390.02 6,230.52 0.00 0.00 22.61 16,400.00 89.58 186.34 6,390.76 6,231.26 0.00 0.00 22.92 16,500.00 89.58 186.34 6,391.50 6,232.00 0.00 0.00 23.24 16,600.00 89.58 186.34 6,392.24 6,232.74 0.00 0.00 23.58 16,700.00 89.58 186.34 6,392.98 6,233.48 0.00 0.00 23.92 16,800.00 89.58 186.34 6,393.72 6,234.22 0.00 0.00 24.27 16,900.00 89.58 186.34 6,394.46 6,234.96 0.00 0.00 24.63 16,906.18 89.58 186.34 6,394.51 6,235.01 0.00 0.00 24.66 Start 3°/100'DLS,91.6°TF,for 465.37' 17,000.00 89.50 189.16 6,395.27 6,235.77 3.00 91.60 25.37 17,100.00 89.42 192.15 6,396.22 6,236.72 3.00 91.58 26.06 17,200.00 89.33 195.15 6,397.31 6,237.81 3.00 91.55 26.81 17,300.00 89.26 198.15 6,398.54 6,239.04 3.00 91.52 27.59 17,371.55 89.20 200.30 6,399.50 6,240.00 3.00 91.48 28.17 2S-Mako 4.Point 3 102115 PB 17,371.95 89.19 200.30 6,399.51 6,240.01 3.00 -179.94 28.17 Adjust TF to-179.94°,for 0.39' 17,400.00 89.19 200.30 6,399.90 6,240.40 0.00 0.00 28.18 17,500.00 89.19 200.30 6,401.32 6,241.82 0.00 0.00 28.44 17,600.00 89.19 200.30 6,402.73 6,243.23 0.00 0.00 28.71 17,700.00 89.19 200.30 6,404.15 6,244.65 0.00 0.00 28.99 17,800.00 89.19 200.30 6,405.56 6,246.06 0.00 0.00 29.28 17,900.00 89.19 200.30 6,406.98 6,247.48 0.00 0.00 29.58 18,000.00 89.19 200.30 6,408.39 6,248.89 0.00 0.00 29.89 18,100.00 89.19 200.30 6,409.80 6,250.30 0.00 0.00 30.20 18,200.00 89.19 200.30 6,411.22 6,251.72 0.00 0.00 30.52 18,300.00 89.19 200.30 6,412.63 6,253.13 0.00 0.00 30.85 18,400.00 89.19 200.30 6,414.05 6,254.55 0.00 0.00 31.19 18,500.00 89.19 200.30 6,415.46 6,255.96 0.00 0.00 31.53 18,600.00 89.19 200.30 6,416.88 6,257.38 0.00 0.00 31.89 18,700.00 89.19 200.30 6,418.29 6,258.79 0.00 0.00 32.24 11/10/2015 1:05:11 PM Page 8 COMPASS 5000.1 Build 74 1 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 18,772.64 89.19 200.30 6,419.32 6,259.82 0.00 0.00 32.51 Hold for 1400.69' 18,800.00 90.01 200.30 6,419.51 6,260.01 3.00 0.06 32.61 18,806.18 90.20 200.30 6,419.50 6,260.00 3.00 0.06 32.63 Start 3°/100'DLS,0.06°TF,for 33.54'-2S-Mako 5.Point 4102115 PB 18,900.00 90.20 199.91 6,419.18 6,259.68 0.42 -89.99 32.76 19,000.00 90.20 199.49 6,418.84 6,259.34 0.42 -89.99 32.75 19,100.00 90.20 199.06 6,418.50 6,259.00 0.42 -89.99 32.75 19,200.00 90.20 198.64 6,418.15 6,258.65 0.42 -89.99 32.76 19,300.00 90.20 198.22 6,417.81 6,258.31 0.42 -90.00 32.79 19,400.00 90.20 197.80 6,417.47 6,257.97 0.42 -90.00 32.84 19,500.00 90.20 197.38 6,417.13 6,257.63 0.42 -90.00 32.90 19,544.95 90.20 197.19 6,416.97 6,257.47 0.42 -90.00 32.98 2S-Mako 1.Heel 19,600.00 90.20 196.96 6,416.79 6,257.29 0.42 -90.00 32.98 19,700.00 90.20 196.54 6,416.44 6,256.94 0.42 -90.00 33.07 19,782.25 90.20 196.20 6,416.16 6,256.66 0.42 -90.00 33.17 2S-Mako 1.Heel 012815 PB 19,800.00 90.20 196.12 6,416.10 6,256.60 0.42 -90.00 33.17 19,900.00 90.20 195.70 6,415.76 6,256.26 0.42 -90.00 33.29 20,000.00 90.20 195.28 6,415.42 6,255.92 0.42 -90.01 33.42 20,100.00 90.20 194.86 6,415.08 6,255.58 0.42 -90.01 33.57 20,200.00 90.20 194.44 6,414.73 6,255.23 0.42 -90.01 33.73 20,300.00 90.20 194.02 6,414.39 6,254.89 0.42 -90.01 33.91 20,400.00 90.20 193.60 6,414.05 6,254.55 0.42 -90.01 34.10 20,500.00 90.20 193.18 6,413.71 6,254.21 0.42 -90.01 34.30 20,600.00 90.20 192.76 6,413.37 6,253.87 0.42 -90.01 34.51 20,700.00 90.20 192.34 6,413.03 6,253.53 0.42 -90.02 34.74 20,800.00 90.20 191.92 6,412.69 6,253.19 0.42 -90.02 34.98 20,900.00 90.20 191.50 6,412.35 6,252.85 0.42 -90.02 35.23 21,000.00 90.19 191.08 6,412.01 6,252.51 0.42 -90.02 35.50 21,100.00 90.19 190.66 6,411.67 6,252.17 0.42 -90.02 35.77 21,200.00 90.19 190.24 6,411.33 6,251.83 0.42 -90.02 36.06 21,300.00 90.19 189.82 6,410.99 6,251.49 0.42 -90.02 36.35 21,400.00 90.19 189.39 6,410.65 6,251.15 0.42 -90.03 36.66 21,500.00 90.19 188.97 6,410.31 6,250.81 0.42 -90.03 36.98 21,600.00 90.19 188.55 6,409.97 6,250.47 0.42 -90.03 37.30 21,700.00 90.19 188.13 6,409.63 6,250.13 0.42 -90.03 37.64 21,739.58 90.19 187.97 6,409.50 6,250.00 0.42 -90.03 37.77 Start 0.42°/100'DLS,-89.99°TF,for 2933.4'-2S-Mako 6.Toe 102115 PB_Circle-2S-Mako 6.Toe 102115 PB 11/10/2015 1.05.11PM Page 9 COMPASS 5000.1 Build 74 1 Schlumberger • Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.5ousft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 11/10/2015 1:05:11PM Page 10 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.5°/100'DLS,63°TF,for 400' 1,000.00 999.27 9.50 18.64 Start 2.5°/100'DLS,0°TF,for 364.79' 1,364.79 1,357.50 39.82 78.15 Hold for 103.59' 1,468.37 1,457.50 52.08 102.22 Start 37100'DLS,-0.73°TF,for 1820.15' 3,288.53 2,750.87 597.80 1,150.58 Hold for 5805.01' 9,093.53 4,762.63 3,123.72 5,974.54 Start 3°/100'DLS, 111.33°TF,for 3611.53' 12,705.06 6,247.50 1,693.55 8,285.62 Hold for 20' 12,725.06 6,251.79 1,674.04 8,286.47 Start 3.01°/100'DLS,68.24°TF,for 349.07' 13,074.13 6,314.79 1,331.51 8,271.80 Hold for 0.53' 13,074.66 6,314.87 1,330.99 8,271.74 Start 3.01°/100'DLS,59.96°TF,for 349.61' 13,424.26 6,349.50 991.08 8,200.02 Start 2°/100'DLS,-3.43°TF,for 139.96' 13,564.22 6,353.41 856.86 8,160.59 Hold for 691.82' 14,256.04 6,355.90 192.79 7,966.64 Start 2°/100'DLS, 138.82°TF,for 152.45' 14,408.49 6,359.50 47.28 7,921.36 Start 3.5°/100'DLS, 106.92°TF,for 14.8' 14,423.29 6,360.16 33.27 7,916.66 Hold for 344.69' 11/10/2015 1:05:11PM Page 11 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 14,767.98 6,376.11 -292.72 7,805.78 Start 3.5°/100'DLS,-60.04°TF,for 124.89' 14,892.88 6,379.50 -412.15 7,769.51 Start 3°/100'DLS,-89.78°TF,for 288.59' 15,181.47 6,381.74 -695.47 7,716.12 Hold for 1724.71' 16,906.18 6,394.51 -2,409.58 7,525.61 Start 3°/100'DLS,91.6°TF,for 465.37' 17,371.95 6,399.51 -2,861.65 7,418.53 Adjust TF to-179.94°,for 0.39' 18,772.64 6,419.32 -4,175.22 6,932.65 Hold for 1400.69' 18,806.18 6,419.50 -4,206.68 6,921.01 Start 3°/100'DLS,0.06°TF,for 33.54' 21,739.58 6,409.50 -7,045.78 6,206.11 Start 0.42°/100'DLS,-89.99°TF,for 2933.4' Checked By: Approved By: Date: 11/10/2015 1:05:11PM Page 12 COMPASS 5000.1 Build 74 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-01 Plan: 2S-01 2S-01wp09 [Mako] Clearance Summary Anticollision Report 09 November,2015 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-01-Plan:2S-01-2S-01wp09[Mako] Well Coordinates: Datum Height: Plan:120+39.5 i 159.50usft(Doyon25) Scan Range: 0.00 to 21,739.58 usft.Measured Depth. Scan Radius is 2,370.01 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-01-2S-O1wpO9 [Mako] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-01-Plan:2S-01-2S-01wp09[Mako] Scan Range: 0.00 to 21,73948 usft.Measured Depth. Scan Radius is 2,370.01 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 2S-02-2S-02-2S-02 486.56 28.97 486.56 18.91 475.00 2.880 Centre Distance Pass-Major Risk 2S-02-2S-02-2S-02 511.41 29.18 511.41 18.76 500.00 2.799 Clearance Factor Pass-Major Risk 2S-04-2S-04-2S-04 39.50 89.96 39.50 88.95 27.50 88.985 Centre Distance Pass-Major Risk 2S-04-2S-04-2S-04 611.70 93.94 611.70 83.62 600.00 9.100 Clearance Factor Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 39.50 89.96 39.50 88.95 27.50 88.985 Centre Distance Pass-Major Risk 2S-04-2S-04PB1-2S-04PB1 611.70 93.94 611.70 83.62 600.00 9.100 Clearance Factor Pass-Major Risk 2S-07-2S-07-2S-07 39.50 179.59 39.50 178.36 27.50 146.048 Centre Distance Pass-Major Risk 2S-07-2S-07-2S-07 611.36 182.32 611.36 166.17 600.00 11.295 Clearance Factor Pass-Major Risk 2S-10-2S-10-2S-10 704.94 264.66 704.94 253.20 700.00 23.084 Centre Distance Pass-Major Risk 2S-10-2S-10-2S-10 800.00 265.28 800.00 252.42 800.00 20.636 Clearance Factor Pass-Major Risk Plan:2S-03-Plan:2S-03-2S-03wp07[Bamboo] 734.18 54.29 734.18 41.72 725.00 4.320 Centre Distance Pass-Major Risk Plan:2S-03-Plan:2S-03-2S-03wp07[Bamboo] 783.33 54.60 783.33 41.37 775.00 4.127 Clearance Factor Pass-Major Risk Plan:2S-05-Plan:2S-05-2S-05wp06[Nurse] 659.49 118.83 659.49 107.74 650.00 10.718 Centre Distance Pass-Major Risk Plan:2S-05-Plan:2S-05-2S-05wp06[Nurse] 707.81 119.25 707.81 107.42 700.00 10.082 Clearance Factor Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 611.08 149.66 611.08 138.91 600.06 13.926 Centre Distance Pass-Major Risk Plan:2S-06-Plan:2S-06-25-06wp06[Salmon] 683.19 150.14 683.19 138.15 675.00 12.525 Clearance Factor Pass-Major Risk Plan:2S-09-Plan:2S-09-25-09wp06[Tiger] 436.50 240.10 436.50 232.40 425.00 31.186 Centre Distance Pass-Major Risk Plan:2S-09-Plan:2S-09-2S-09wp06[Tiger] 634.30 240.99 634.30 230.29 625.00 22.530 Clearance Factor Pass-Major Risk Rig:2S-08-Rig:2S-08-2S-08wp12.1[Hammerhead] 462.00 210.13 462.00 201.99 450.00 25.803 Centre Distance Pass-Major Risk Rig:2S-08-Rig:2S-08-2S-08wp12.1[Hammerhead] 611.39 211.07 611.39 200.34 600.04 19.673 Clearance Factor Pass-Major Risk Non-Pad KRU 21-10-8-KRU 21-10-8-KRU 21-10-8 17,714.89 978.01 17,714.89 818.96 7,150.00 6.149 Clearance Factor Pass-Major Risk KRU 21-10-8-KRU 21-10-8-KRU 21-10-8 17,714.40 977.99 17,714.40 818.99 7,156.00 6.151 Centre Distance Pass-Major Risk 09 November,2015- 11:14 Page 2 of 5 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-01- 2S-O1wpO9 [Mako] Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.50 800.00 2S-01wp09[Mako] GYD-GC-SS 800.00 1,800.00 2S-01wp09[Mako] MWD 800.00 3,230.66 2S-01wp09[Mako] MWD+IFR-AK-CAZ-SC 3,230.66 4,730.66 2S-01wp09[Mako] MWD 3,230.66 12,705.06 2S-01wp09[Mako] MWD+IFR-AK-CAZ-SC 12,705.06 14,205.06 2S-01wp09[Mako] MWD 12,705.06 21,739.58 2S-01wp09[Mako] MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 November,2015- 11:14 Page 3 of 5 COMPASS • 11:20, November 09 2015 09 Mako Ladder View 2S-01 w p [Mako] The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors E ^°o iS-E1 m ..i.. Az 0 3 ac4o N N 300 '' '- -- III 1 a a) 150 i. GIl ,'I o '�I' mid ami IPld�' 0-Equivelant Magnetic Distance I I I I I I I I I I 1 I I I I I I I I I I I I I 0 3000 6000 9000 12000 15000 18000 21000 Displayed interval could be less than entire well:Measured Depth 39.50 To 21739.58 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 800.00 25-01wp09[Mako] (Plan: 2S-01) GYD-GC-SS 2730.01230.66 10-3/4"x 13-1/2" 800.00 1800.00 2S-01wp09[Mako] (Plan: 2S-01) MWD 6247. Y05.06 7-5/8"X 9-7/8" 800.00 3230.66 2S-01wp09[Mako] (Plan: 2S-01) MWD+IFR-AK-CAZ-SC 6409217739.58 4-1/2"x 6-3/4" 3230.66 4730.66 2S-01wp09[Mako] (Plan: 2S-01) MWD 3230.6612705.06 2S-01wp09[Mako] (Plan: 2S-01) MWD+IFR-AK-CAZ-SC 12705.0614205.06 25-01wp09[Mako] (Plan: 2S-01) MWD 12705.0621739.58 25-01wp09[Mako] (Plan: 2S-01) MWD+IFR-AK-CAZ-SC 0 E m . 3 N N gi 60 / / i I i 0 1111111 1 (D N 30 -- II Iil` �'i 2 - w 0 0 ; I I 1 1 1111 11111111111111 I 1 1 1 Mil 0 ; 500 1000 1500 2000 2500 3000 3500 ; Partial Measured Depth Equivelant Magnetic Distance 40 bUU 2S-01wp09 [Mako] 9 Inc Azi TVD Dleg TFace arget 600 790 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 21739.58 600.00 0.00 0.00 600.00 0.00 0.00 790 970 1000.00 6.00 63.00 999.27 1.50 63.00 364.79 15.12 63.00 1357.50 2.50 0.00 970 1160 11:22,November 09 2015 468.37 15.12 63.00 1457.50 0.00 0.00 1160 1340 288.53 69.72 62.36 2750.87 3.00 -0.73 CASING DETAILS 0093.53 69.72 62.36 4762.63 0.00 0.00 1340 1530 12705.06 77.60 177.50 6247.50 3.00 111.33 TVD MD Nan162725.06 77.60 177.50 6251.79 0.00 0.00 1530 1710 2730.00 3230.66 10-3/4" x 13-1/r074.13 81.65 187.34 6314.79 3.01 68.24 6297.50 12705.06 7-5/6" x 9-7/ 074.66 81.65 187.34 6314.87 0.00 0.00 1710 1900 6409.50 21739.58 4-1/2" x 6-3/ 12424.26 87.00 196.45 6349.50 3.01 59.96 2S-Mako 1. Heel 102115 PB 1900 2730 13564.22 89.79 196.28 6353.41 2.00 -3.43 s0,,,,152P 1 -256.04 89.79 196.28 6355.90 0.00 0.00 2730 3550 uepm From neFD To Mar.,.F/Plm 408.49 87.50 198.29 6359.50 2.00 138.82 2S-Mako 2. Point 1 102115 PB35 50 800 00 3550 4380 800 00 -°01,005 moi au zs-o° "_ss 423.29 87.35 198.79 6360.16 3.50 106.92 :300'00 23 01,05[Mako] (Plan 25-0,20.788-8X-CIM-SC 767.98 8 7.3 5 198.79 6376.11 0.0 0 0.0 0 9290 lo.ss 2s-01,05 moo] (Fla:25 038M4380 -___ 5200 61120506 xs-01,005 mei (Plan zs-o i3F1"`�" 892.88 89.59 195.00 6379.50 3.50 -60.04 2S-Mako 3. Point 2 102115 PB 12705 06 1:'05°6zl9se FF-03.,09 ( ¼3c''''SS-O1*SS.1F.-AF-CAS-s` 181.47 89.58 186.34 6381.74 3.00 -89.78 5200 6030 906.18 89.58 186.34 6394.51 0.00 0.00 371.55 89.20 200.30 6399.50 3.00 91.60 2S-Mako 4. Point 3 102115 PB 6030 ----- 6850 371.95 89.19 200.30 6399.51 3.00 -179.94 18772.64 89.19 200.30 6419.32 0.00 0.00 6850 --- - 7680 18806.18 90.20 200.30 6419.50 3.00 0.06 2S-Mako 5. Point 4 102115 PB 7680 8500 21739.58 90.19 187.97 6409.50 0.42 -89.99 25-Mako 6. Toe 102115 PB 8500 10160 0/360 10160 11810 2S-03wp07[Bamboo] 11810 13470 225 - -30/330 y'�*�li, 210 30 13470 15120 ;e.00%� ,� 15120 16780 (0,-..so..,r.'S®i►§�11 89 o5 16780 18430 Irerit,ORI"', �.1 18430 20090 40 �� %f"`+�` 20090 21740 2S-06wp06 [SalmIo$1.rri 15��`e�, 135 -6d/300 % As ~�4, 60 it ft nv 12'1 1sii�' »\, llIii agiglIl 90 il75 p/di/i'f��,. Avi1 �e/• •1 `,.ri/i Jr tip. '4'.40"01.•' lboAt tit, ;o ..: 25-08wp12.1 [Ham '"�'���I1.4 t 7:: ' 11 k1 Illirfet:VA %VW' 1 frri-;:1•411: Vartri 4 ,,.....„..„. ,,,,,,,,,,,,„ 90/270 •.s 44 ;,•-1-.'",,7't- 90 • f otv T, . it - 40, y ss ‘-1,244.414-iwv4.0 ailw:;,1/4'. c; 1,(0;',741; 'ice s'm�.���/lw,�l • iy; .=c4�, ,Qi,1.off ` `, •1. *�:.1� Art--11, ;;oma` �'. �w`44, ar *.If 4, ,I;N: .,1, i1A�. a `Yr%� ,044a , 4141110-04d ilei OW,�,♦!:71b.,Amp' t... a�C �� 1 -120/240 At^"XVII" ,/•**11."*4 ►�r':1'7" 120 / i6.4 ,...4:.',.11,1 2S-04PB1 p.4. I e�� ►1 U:i ► ►.Frio' f:1111W4 44111"2".4 `4:4 IS MA .� ��� _IP' 150 r®- s� 2S-05wp06 [Nurse] "litp, -180/180 --'2S-02 • • 11:31,November 09 2015 Easting(2500 usfUin) IIull11I , , , , 111 , 1I1 , 1 III I 111 1 I � � � � I � � � � i 2S-09wp06[Tiger] 2S-04 2S-07 2S-05wp06[Nurse] 2S-02 4 • r i/� - Kuparuk 2S Pad I' _S 0 N N C - KRU '1-10-8 = Z- —5 - ✓ 2S-01wp09[Mato] 2S-10 — 2S-06wp06[Salmon] 2S-03wp07[Bamboo] Prelim: Kuparuk Cairn Pad2 Easting(2500 usft/in) AC Flipbook • Casing Details Survey Program 25--oiwpo9 [Mako] 30.00 j2;0.66 of/q"x19.04/2e Depth 9.50rom Depth To Survey25-mw/Plan ool 40 600 6407.50 21735.56 75/8"x9-7/8" FrSu 80hTo 25-31w/Plan ko](Plan:250t) GVDGC-SS V 6409.50 3739.58 q-1/2"zb-3/q" 800.00 1800.00 i5-otwp59[Mako](Plan:2501) MWD 800.00 3230.66 25-01wpo9[Mako](Plan:25.01) MWDA FR-AK-CV-SC _ 3230.66 4730.66 25-01wp09[Mako](Plan:25.01) MWD 6lJ00 790 1000.00 To 2000.00 3230.66 12705.06 25o1wp [Mako](Plan:25-o1) MWD.IFR-AK-CAZ-SC 12735.06 14405.06 25otwp09[Mako](Plan:25.01) MWD 12705.06 21739.58 25otwpo9 o9[Mako](Plan:25-01) MWDAFR-AK-CAZ-SC 790 970 MD Azi 2S-o3wpo7[Bamboo] 0 / 360 970 1160 39.50 0.00 90 1160 1340 600.00 o.00 -30 /331 0 1000.00 63.00 ,,....4 1340 1530 1364.79 63.00 ��►�1��, ,,-_ 1530 1710 1468.37 63.00 ��a►����s �� ��� 60 �' ` 1710 1900 3288.53 62.36 60 / 300 I6o 1900 2730 9093.53 62.36 12705.06 177.50 \ 2730 3550 12725.06 177.50 13074.13 187 34 30 3550 4380 13074.66 187.34 / 4380 5200 13424.26 196.45 5200 6030 13564.22 196.20 i 270 90 6030 6850 14256.04 196.28 f 685o 768o 14408.49 198.29 14423.29 198.79 -- ---, 3o i ,..., 768o 8500 14767.98 198.79 85oo 10160 14892.88 195.00 _ � � .� ,=�� ...'120 10160 11810 / 15181.47 186.34 -120 / 240 16906.18 186.34 60 \ • 11810 13470 17371.55 200.30 13470 15120 ........... 17371.95 200.30 iii `, \------ \ 15120 16780 18772.64 200.30 -150 / 210150 daft 18806.18 200.3016780 18430 21739.58 187.97 --- - -180 / 180 25-02 18430 20090 20090 21740 12207,November 09 2015 • • Casing Detaik Survey Program To ND MD Name Depth From Depth To Survey/Plan ol 2S-olwp09 [Mako] 35.05 3Z3o.66 3q"xt3-t/a 395o 800.00 z5-otwpog[Meko](Plan:2Sot) O-GC-55 40 600 6207.50 tt75506 7-5/e"X9-7/e" g00.o0 t800.55 aSotwpog[Mako](Plan:2S on) MWD 6009.50 2039 58 4-U2"K6-310 800.00 323o.66 2S otwpog[Mako](Plan:2S on) MWD+IFR AK-CAZ-SC 3230.66 0735.66 2Sotwpog[Mako](Plan:isor) MWD LOO 790 39.50 To 1000.00 3J30.66 tx70506 aSotwpo9[Mako(Plan:eS-ot) MWD+IFR AK AZ SC l7 tt7o55fi 745.58 zSotwpog[Mako](Plan:z85t) MWD n7o5�o6 +73958 zSotwp09[Mako](Plan:i5-ot) MWD+IFR-AK-CAZ-SC 790 970 MD Azi 0 / 360 970 1160 39.50 0.00 90 116o 1340 600.00 o.00 -30 / 33• 0 1000.00 63.00 1340 1530 1364.79 63.00 2S-03wp07[Bamboo] 1530 1710 1468.37 63.00 6o 1710 1900 3288.53 62.36 9093 53 62.36 -60 / 300 60 1900 2730 12705.06 177.50 ' �`,'' 2730 3550 12725.06 177.50 to ��+4t te....." �( 30 3550 4380 13074.13 187.34 ',amnia.,, �,I 4380 5200 13074.66 187.34 ► 13424.26 196.45 5200 6030 13564.22 196.2-00 / 270 -�' - 90 14256.04 196.28 fp ��. 6030 6850 � �� ' 14408.49 198.29 - 6850 7680 14423.29 198.79 25-0 'B1 y� 0 768o 8500 14767.98 198.79 v1/ i 85oo 10160 14892.88 195.00 r�' , 10160 11810 15181.47 186.34 -120 / 240 120 16 06.18 186. 71 11810 13470 9 34 la,`.�► -I, 17371.55 200.30 .. W �w���� ,;, ` 13470 15120 17371.95 200.30 i��rl� , 18772.64 200.30 ',kla i \`"--- \ 15120 16780 -150 / 210 , 0 18806.18 200.30 I D • Al -- 25-02 1678o 18430 21739.58 187.97 -180 / 18o 18430 20090 20090 21740 12:07,November o9 2015 • s Casing Details Survey Program x730.00 3x30.66 Name Depth From Depth To Survey/Plan/Plan Tool G ND MD o.3 q"x13_t/xx Y 40 600 25-o�wpo9 [Mako] bxq]•5o 2,735.56 )5/8"X9)/8" 39.5o 800.00 xSotwpo9[Mako](Plan:x5at) LYDGC-55 67o.00 x93958 q-t/x"x6-3/q" Boo.00 1800.00 xSorwpoq[Mako](Plam 2S.m) MWD 9 800.00 3230.66 2Sotwpo9[Mako](Plan:25 at) MWDAFR-AK-CAZ-X 2000 00 To 2■ 3230.66 4730.66 xiotwpo9[M Atli](Plan:OS.on) MWD 600790 • 739•/ 3235.66 [x705.06 xiotwpoq[Mako](Plan:x501) [x705.06 t4205.06 xiotwpo9[Mako](Plan:25.01) MWD tx]o5 o6 2[]39.58 xSmwpoq[Mako](Plan:2S-m) ) MWDAFR-AK-CAZ-X 790 970 MD Azi 0 / 360 970 1160 39.50 0.00 90 1160 1340 600.00 o.00 -30 / 33. ' 0 1000.00 63.00 1340 1530 1364.79 63.00 \ ,\ / 1530 - 1710 1468.37 63.00 6 0 1710 1900 3288.53 62.36 •%'. -60 / 00 9093 53 62.36 3 ;-, 60 1900 2730 12705.06 177.50 2730 3550 12725.06 177.50 30 3550 4380 13074.13 187.34 4380 5200 13074.66 187.34 13424.26 196.45 5200 6030 13564.22 196.2190 / 270 90 6030 6850 14256.04 196.28 14408.49 198.29 6850 7680 14423.29 198.79 3 0 7680 8500 14767.98 198.79 \ 8500 10160 14892.88 195.00 15181.47 186.34 -120 / 240 120 10160 11810 16906.18 186.34 6o 11810 13470 17371.55 200.30 13470 15120 17371.95 200.30 1512o_ 16780 18772.64 200.30 -150 / 210 150 18806.18 200.30 90 1678o 18430 21739.58 187.97 -180 / 180 18430 . 20090 20090 - 21740 12:08,November o9 2015 i • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-01 Plan: 2S-01 Plan: 2S-01wp09 [Mako] Report - Errors 09 November, 2015 IP III Schlumberger Report- Errors Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5©159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5© 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-01 Well Position +N/-S usft Northing: usfi Latitude: +E/-W usft Easting: usfi Longitude: Position Uncertainty usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 12/30/2015 18.42 80.86 57,486 Design 2S-01wp09[Mako] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 195.00 Survey Tool Program Date 11/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 800.00 2S-01wp09[Mako](Plan:2S-01) GYD-GC-SS Gyrodata gyro single shots 800.00 1,800.00 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 800.00 3,230.66 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,230.66 4,730.66 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 3,230.66 12,705.06 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12,705.06 14,205.06 2S-01wp09[Mako](Plan:2S-01) MWD MWD-Standard 12,705.06 21,739.58 2S-01wp09[Mako](Plan:2S-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 39.50 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.50 1.15 0.04 0.04 200.00 1.15 0.00 0.00 40.50 1.15 0.19 0.19 295.50 1.15 0.00 0.00 136.00 1.15 0.33 0.33 top T-3 Sand 300.00 1.15 0.00 0.00 140.50 1.15 0.33 0.33 11/9/2015 11:19:57AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 384.50 1.15 0.00 0.00 225.00 1.15 0.48 0.48 K-15 Marker 400.00 1.15 0.00 0.00 240.50 1.15 0.48 0.48 500.00 1.15 0.00 0.00 340.50 1.15 0.62 0.62 600.00 1.15 0.00 0.00 440.50 1.15 0.77 0.77 KOP:Start 1.5°/100'DLS,63°TF,for 400' 700.00 1.16 1.50 135.00 540.49 1.16 0.90 0.90 800.00 1.16 3.00 154.39 640.41 1.16 1.01 1.01 900.00 1.16 4.50 151.90 740.19 1.16 1.08 1.07 1,000.00 1.17 6.00 66.87 839.77 1.16 1.10 1.08 Start 2.5°/100'DLS,0°TF,for 364.79' 1,100.00 1.18 8.50 65.62 938.96 1.16 1.17 1.10 1,200.00 1.19 11.00 65.06 1,037.51 1.16 1.30 1.14 1,300.00 1.20 13.50 64.70 1,135.23 1.16 1.50 1.19 1,364.79 1.22 15.12 64.54 1,198.00 1.15 1.68 1.22 Hold for 103.59' 1,400.00 1.22 15.12 64.46 1,231.99 1.15 1.79 1.25 1,416.58 1.22 15.12 64.34 1,248.00 1.16 2.01 1.31 Base permafrost(?) 1,468.37 1.22 15.12 64.34 1,298.00 1.16 2.01 1.31 Start 3°/100'DLS,-0.73°TF,for 1820.15' 1,500.00 1.23 16.07 64.30 1,328.46 1.16 2.12 1.33 1,600.00 1.25 19.07 64.17 1,423.79 1.16 2.53 1.42 1,700.00 1.28 22.07 64.03 1,517.40 1.16 3.01 1.51 1,800.00 1.31 25.07 63.89 1,609.05 1.17 3.59 1.63 1,881.37 1.34 27.51 70.34 1,682.00 1.15 2.14 1.54 Top W Sak(W Sak D) 1,900.00 1.34 28.07 70.34 1,698.48 1.15 2.14 1.54 2,000.00 1.38 31.07 69.45 1,785.45 1.15 2.40 1.62 2,100.00 1.42 34.07 68.72 1,869.71 1.16 2.69 1.70 2,200.00 1.47 37.07 68.10 1,951.05 1.18 3.02 1.78 2,300.00 1.52 40.07 67.58 2,029.23 1.20 3.38 1.86 2,400.00 1.58 43.07 67.13 2,104.03 1.23 3.77 1.94 2,500.00 1.65 46.07 66.74 2,175.27 1.28 4.19 2.03 2,600.00 1.71 49.07 66.40 2,242.73 1.33 4.63 2.11 2,700.00 1.79 52.07 66.09 2,306.24 1.40 5.09 2.20 2,800.00 1.87 55.07 65.82 2,365.62 1.48 5.58 2.28 2,900.00 1.95 58.07 65.57 2,420.71 1.57 6.08 2.36 3,000.00 2.04 61.07 65.34 2,471.36 1.67 6.60 2.44 3,100.00 2.13 64.07 65.13 2,517.42 1.79 7.13 2.51 3,105.91 2.22 64.24 64.94 2,520.00 1.91 7.66 2.59 Base W Sak 3,200.00 2.22 67.07 64.94 2,558.78 1.91 7.66 2.59 3,230.66 2.39 67.99 64.71 2,570.50 1.92 8.18 2.59 10-3/4"x 13-1/2" 11/9/2015 11:19:57AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 3,288.53 2.39 69.72 64.71 2,591.37 1.92 8.18 2.59 Hold for 5805.01' 3,300.00 2.39 69.72 64.66 2,595.35 1.92 8.26 2.59 3,400.00 2.40 69.72 64.24 2,630.01 1.97 9.06 2.64 3,500.00 2.40 69.72 63.88 2,664.66 2.08 10.03 2.73 3,600.00 2.41 69.72 63.60 2,699.32 2.23 11.12 2.86 3,700.00 2.42 69.72 63.37 2,733.97 2.42 12.31 3.03 3,800.00 2.43 69.72 63.20 2,768.63 2.63 13.56 3.22 3,900.00 2.44 69.72 63.07 2,803.28 2.87 14.86 3.44 3,907.84 2.45 69.72 62.97 2,806.00 3.12 16.20 3.68 C-80 4,000.00 2.45 69.72 62.97 2,837.94 3.12 16.20 3.68 4,100.00 2.46 69.72 62.89 2,872.59 3.38 17.57 3.93 4,200.00 2.46 69.72 62.82 2,907.25 3.66 18.97 4.20 4,300.00 2.47 69.72 62.77 2,941.91 3.94 20.38 4.48 4,400.00 2.48 69.72 62.73 2,976.56 4.22 21.81 4.77 4,500.00 2.49 69.72 62.69 3,011.22 4.52 23.24 5.06 4,600.00 2.50 69.72 62.66 3,045.87 4.81 24.69 5.37 4,700.00 2.51 69.72 62.64 3,080.53 5.11 26.15 5.67 4,800.00 2.52 69.72 63.41 3,115.18 3.19 13.56 3.74 4,900.00 2.54 69.72 63.37 3,149.84 3.32 14.04 3.87 5,000.00 2.55 69.72 63.33 3,184.49 3.46 14.53 4.00 5,100.00 2.56 69.72 63.30 3,219.15 3.60 15.03 4.14 5,200.00 2.57 69.72 63.27 3,253.81 3.74 15.53 4.27 5,300.00 2.58 69.72 63.24 3,288.46 3.88 16.03 4.41 5,400.00 2.59 69.72 63.21 3,323.12 4.02 16.54 4.56 5,500.00 2.60 69.72 63.19 3,357.77 4.16 17.05 4.70 5,600.00 2.61 69.72 63.17 3,392.43 4.31 17.57 4.85 5,700.00 2.63 69.72 63.15 3,427.08 4.46 18.09 4.99 5,800.00 2.64 69.72 63.13 3,461.74 4.61 18.62 5.14 5,900.00 2.65 69.72 63.12 3,496.39 4.76 19.14 5.30 6,000.00 2.66 69.72 63.10 3,531.05 4.91 19.67 5.45 6,100.00 2.68 69.72 63.09 3,565.71 5.06 20.21 5.60 6,200.00 2.69 69.72 63.08 3,600.36 5.21 20.74 5.76 6,300.00 2.70 69.72 63.06 3,635.02 5.36 21.28 5.91 6,400.00 2.72 69.72 63.05 3,669.67 5.51 21.82 6.07 6,500.00 2.73 69.72 63.04 3,704.33 5.67 22.36 6.23 6,600.00 2.74 69.72 63.03 3,738.98 5.82 22.90 6.39 6,700.00 2.76 69.72 63.03 3,773.64 5.98 23.44 6.55 6,800.00 2.77 69.72 63.02 3,808.29 6.13 23.99 6.71 6,900.00 2.78 69.72 63.01 3,842.95 6.29 24.54 6.87 7,000.00 2.80 69.72 63.00 3,877.61 6.44 25.08 7.03 7,100.00 2.81 69.72 63.00 3,912.26 6.60 25.63 7.19 7,200.00 2.83 69.72 62.99 3,946.92 6.76 26.18 7.36 7,300.00 2.84 69.72 62.99 3,981.57 6.91 26.73 7.52 11/92015 11:19:57AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 7,400.00 2.86 69.72 62.98 4,016.23 7.07 27.29 7.68 7,500.00 2.87 69.72 62.98 4,050.88 7.23 27.84 7.85 7,600.00 2.88 69.72 62.97 4,085.54 7.39 28.39 8.01 7,700.00 2.90 69.72 62.97 4,120.19 7.55 28.95 8.18 7,800.00 2.91 69.72 62.96 4,154.85 7.70 29.50 8.34 7,900.00 2.93 69.72 62.96 4,189.51 7.86 30.06 8.51 8,000.00 2.95 69.72 62.96 4,224.16 8.02 30.62 8.67 8,100.00 2.96 69.72 62.95 4,258.82 8.18 31.17 8.84 8,155.35 2.98 69.72 62.95 4,278.00 8.34 31.73 9.01 C-50 8,200.00 2.98 69.72 62.95 4,293.47 8.34 31.73 9.01 8,300.00 2.99 69.72 62.95 4,328.13 8.50 32.29 9.17 8,400.00 3.01 69.72 62.95 4,362.78 8.66 32.85 9.34 8,500.00 3.02 69.72 62.94 4,397.44 8.82 33.41 9.51 8,600.00 3.04 69.72 62.94 4,432.09 8.98 33.97 9.68 8,700.00 3.06 69.72 62.94 4,466.75 9.14 34.53 9.84 8,800.00 3.07 69.72 62.94 4,501.41 9.30 35.10 10.01 8,900.00 3.09 69.72 62.93 4,536.06 9.46 35.66 10.18 9,000.00 3.10 69.72 62.93 4,570.72 9.62 36.22 10.35 9,009.47 3.12 69.72 62.93 4,574.00 9.77 36.75 10.51 C-40 9,093.53 3.12 69.72 62.93 4,603.13 9.77 36.75 10.51 Start 3°/100'DLS,111.33°TF,for 3611.53' 9,100.00 3.12 69.65 62.93 4,605.38 9.78 36.78 10.51 9,200.00 3.64 68.59 62.95 4,641.02 9.93 37.06 10.65 9,300.00 4.84 67.58 62.99 4,678.35 10.09 37.25 10.83 9,371.47 6.36 66.90 63.06 4,706.00 10.25 37.35 11.06 C-37 9,400.00 6.36 66.63 63.06 4,717.25 10.25 37.35 11.06 9,500.00 8.02 65.75 63.16 4,757.63 10.40 37.34 11.36 9,600.00 9.74 64.92 63.30 4,799.38 10.55 37.23 11.72 9,700.00 11.50 64.17 63.46 4,842.37 10.70 37.01 12.17 9,800.00 13.26 63.48 63.66 4,886.49 10.85 36.67 12.69 9,865.63 15.02 63.08 63.89 4,916.00 10.99 36.21 13.28 Growler-AA 9,900.00 15.02 62.88 63.89 4,931.62 10.99 36.21 13.28 10,000.00 16.77 62.34 64.14 4,977.63 11.14 35.63 13.92 10,100.00 18.51 61.89 64.43 5,024.41 11.28 34.94 14.62 10,200.00 20.22 61.52 64.74 5,071.81 11.43 34.12 15.34 10,300.00 21.89 61.24 65.08 5,119.72 11.57 33.19 16.08 10,400.00 23.54 61.04 65.45 5,167.99 11.71 32.14 16.81 10,500.00 25.14 60.93 65.83 5,216.51 11.85 30.99 17.53 10,600.00 26.69 60.90 66.23 5,265.13 11.99 29.73 18.21 10,700.00 28.20 60.97 66.65 5,313.72 12.13 28.39 18.85 10,800.00 29.65 61.12 67.09 5,362.15 12.27 26.97 19.42 11/9/2015 11:19:57AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 10,820.41 31.04 61.16 67.53 5,372.00 12.41 25.48 19.92 Top Cairn 10,900.00 31.04 61.35 67.53 5,410.28 12.41 25.48 19.92 10,945.40 32.36 61.49 67.99 5,432.00 12.55 23.94 20.34 Top Bermuda 11,000.00 32.36 61.67 67.99 5,457.99 12.55 23.94 20.34 11,059.25 33.62 61.90 68.45 5,486.00 12.70 22.37 20.68 Base Bermuda 11,100.00 33.62 62.08 68.45 5,505.14 12.70 22.37 20.68 11,153.31 34.81 62.33 68.92 5,530.00 12.84 20.78 20.92 C-35 11,200.00 34.81 62.56 68.92 5,551.60 12.84 20.78 20.92 11,300.00 35.92 63.13 69.39 5,597.25 12.98 19.20 21.07 11,400.00 36.95 63.77 69.86 5,641.96 13.12 17.65 21.12 11,500.00 37.91 64.48 70.32 5,685.61 13.27 16.16 21.08 11,600.00 38.77 65.27 70.78 5,728.08 13.42 14.78 20.96 11,700.00 39.55 66.12 71.23 5,769.25 13.56 13.54 20.75 11,800.00 40.25 67.03 71.67 5,809.01 13.71 12.51 20.47 11,900.00 40.85 68.01 72.10 5,847.25 13.87 11.75 20.13 11,901.99 41.35 68.03 72.51 5,848.00 14.02 11.30 19.73 Top HRZ(K-2 mkr) 12,000.00 41.35 69.04 72.51 5,883.87 14.02 11.30 19.73 12,100.00 41.76 70.12 72.91 5,918.76 14.17 11.20 19.29 12,194.30 42.08 71.19 73.29 5,950.00 14.33 11.47 18.83 Upper Kalubik(base HRZ) 12,200.00 42.08 71.26 73.29 5,951.84 14.33 11.47 18.83 12,300.00 42.29 72.44 73.64 5,983.00 14.49 12.05 18.36 12,400.00 42.41 73.66 73.97 6,012.16 14.65 12.90 17.89 12,500.00 42.43 74.91 74.27 6,039.25 14.81 13.96 17.43 12,600.00 42.35 76.21 74.54 6,064.19 14.97 15.18 17.01 12,700.00 42.40 77.53 75.49 6,086.91 15.04 16.21 16.57 12,705.06 42.40 77.60 75.54 6,088.00 15.04 16.26 16.55 Hold for 20'-Lower Kalubik(K-1 mkr)-7-5/8"X 9-7/8" 12,725.06 42.40 77.60 75.74 6,092.29 15.04 16.21 16.55 Start 3.010/100'DLS,68.24°TF,for 349.07' 12,800.00 42.20 78.44 76.48 6,107.85 15.05 16.87 16.25 12,900.00 41.87 79.59 77.46 6,126.90 15.07 17.86 15.89 13,000.00 41.48 80.77 78.40 6,143.96 15.09 18.94 15.60 13,051.82 41.14 81.38 79.08 6,152.00 15.11 19.78 15.42 Kuparuk C(Top C4) 13,074.13 41.14 81.65 79.08 6,155.29 15.11 19.78 15.42 Hold for 0.53' 13,074.66 41.14 81.65 79.08 6,155.37 15.11 19.78 15.42 Start 3.01°/100'DLS,59.96°TF,for 349.61' 13,100.00 41.03 82.03 79.32 6,158.97 15.12 20.04 15.36 11/92015 11:19:57AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Makoj Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Veil.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 13,122.35 40.55 82.37 80.18 6,162.00 15.17 21.18 15.17 B 13,161.53 40.55 82.96 80.18 6,167.00 15.17 21.18 15.17 A6 13,200.00 40.55 83.55 80.18 6,171.52 15.17 21.18 15.17 13,204.33 40.01 83.62 81.01 6,172.00 15.22 22.34 15.09 A5 13,300.00 40.01 85.08 81.01 6,181.42 15.22 22.34 15.09 13,387.90 39.40 86.44 81.77 6,187.92 15.28 23.53 15.10 2S-Mako 2.Toe 012815 PB 13,400.00 39.40 86.62 81.77 6,188.65 15.28 23.53 15.10 13,424.26 39.25 87.00 81.95 6,190.00 15.29 23.82 15.12 Start 2°/100'DLS,-3.43°TF,for 139.96'-2S-Mako 1.Heel 102115 PB-2S-Mako 1. Heel 102115 PB Circle 13,469.19 39.25 87.90 82.54 6,192.00 15.34 23.82 15.23 A4 13,500.00 39.25 88.51 82.54 6,192.97 15.34 23.82 15.23 13,519.52 39.23 88.90 83.09 6,193.41 15.39 23.79 15.37 2S-Mako 2.Toe 13,564.22 39.23 89.79 83.09 6,193.91 15.39 23.79 15.37 Hold for 691.82' 13,600.00 39.23 89.79 83.39 6,194.04 15.42 23.82 15.40 13,700.00 39.23 89.79 84.21 6,194.40 15.51 23.95 15.49 13,800.00 39.24 89.79 85.03 6,194.76 15.60 24.18 15.58 13,900.00 39.24 89.79 85.85 6,195.12 15.70 24.49 15.68 14,000.00 39.24 89.79 86.68 6,195.48 15.81 24.88 15.79 14,100.00 39.24 89.79 87.52 6,195.84 15.93 25.36 15.91 14,200.00 39.24 89.79 88.38 6,196.20 16.05 25.91 16.03 14,256.04 38.52 89.79 78.77 6,196.40 15.31 24.29 15.29 Start 2°/100'DLS,138.82°TF,for 152.45' 14,300.00 38.37 89.13 78.88 6,196.81 15.32 24.51 15.25 14,400.00 38.02 87.63 79.19 6,199.64 15.36 24.94 15.19 14,408.49 37.99 87.50 79.22 6,200.00 15.36 24.98 15.19 Start 3.5°/100'DLS,106.92°TF,for 14.8'-2S-Mako 2.Point 1 102115 PB 14,423.29 37.84 87.35 79.26 6,200.66 15.36 25.18 15.19 Hold for 344.69' 14,500.00 37.84 87.35 79.42 6,204.21 15.39 25.14 15.22 14,600.00 37.84 87.35 79.59 6,208.84 15.43 25.14 15.26 14,700.00 37.85 87.35 79.76 6,213.46 15.47 25.15 15.30 14,767.98 37.85 87.35 79.86 6,216.61 15.50 25.17 15.33 Start 3.5°/100'DLS,-60.04°TF,for 124.89' 14,800.00 38.12 87.91 79.93 6,217.93 15.52 24.74 15.37 14,892.88 38.83 89.54 80.17 6,220.00 15.56 23.45 15.52 Start 3°/100'DLS,-89.78°TF,for 288.59'-2S-Mako 3.Point 2 102115 PB 14,900.00 38.88 89.54 80.19 6,220.06 15.56 23.36 15.52 15,000.00 39.59 89.55 80.49 6,220.85 15.61 22.03 15.57 15,100.00 40.20 89.56 80.79 6,221.63 15.66 20.82 15.62 11/9/2015 11:19:57AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 15,181.47 40.62 89.58 81.04 6,222.24 15.70 19.95 15.67 Hold for 1724.71' 15,200.00 40.62 89.58 81.08 6,222.38 15.71 19.96 15.68 15,300.00 40.62 89.58 81.30 6,223.12 15.76 20.13 15.73 15,400.00 40.62 89.58 81.51 6,223.86 15.82 20.32 15.78 15,500.00 40.63 89.58 81.73 6,224.60 15.87 20.52 15.84 15,600.00 40.63 89.58 81.93 6,225.34 15.93 20.74 15.90 15,700.00 40.63 89.58 82.14 6,226.08 15.99 20.97 15.96 15,800.00 40.63 89.58 82.35 6,226.82 16.05 21.21 16.02 15,900.00 40.63 89.58 82.55 6,227.56 16.12 21.47 16.08 16,000.00 40.64 89.58 82.75 6,228.30 16.18 21.73 16.15 16,100.00 40.64 89.58 82.96 6,229.04 16.25 22.01 16.22 16,200.00 40.64 89.58 83.16 6,229.78 16.32 22.31 16.28 16,300.00 40.64 89.58 83.36 6,230.52 16.39 22.61 16.36 16,400.00 40.64 89.58 83.56 6,231.26 16.46 22.92 16.43 16,500.00 40.65 89.58 83.75 6,232.00 16.53 23.24 16.50 16,600.00 40.65 89.58 83.95 6,232.74 16.61 23.58 16.58 16,700.00 40.65 89.58 84.15 6,233.48 16.68 23.92 16.65 16,800.00 40.65 89.58 84.35 6,234.22 16.76 24.27 16.73 16,900.00 40.66 89.58 84.55 6,234.96 16.84 24.63 16.81 16,906.18 40.66 89.58 84.57 6,235.01 16.85 24.66 16.82 Start 3°/100'DLS,91.6°TF,for 465.37' 17,000.00 40.36 89.50 84.82 6,235.77 16.92 25.37 16.89 17,100.00 39.99 89.42 85.14 6,236.72 17.01 26.06 16.96 17,200.00 39.56 89.33 85.44 6,237.81 17.09 26.81 17.04 17,300.00 39.08 89.26 85.73 6,239.04 17.18 27.59 17.12 17,371.55 38.71 89.20 85.91 6,240.00 17.24 28.17 17.18 2S-Mako 4.Point 3 102115 PB 17,371.95 38.71 89.19 85.91 6,240.01 17.24 28.17 17.18 Adjust TF to-179.94°,for 0.39' 17,400.00 38.71 89.19 86.00 6,240.40 17.26 28.18 17.20 17,500.00 38.71 89.19 86.07 6,241.82 17.35 28.44 17.29 17,600.00 38.72 89.19 86.13 6,243.23 17.44 28.71 17.38 17,700.00 38.72 89.19 86.17 6,244.65 17.53 28.99 17.47 17,800.00 38.72 89.19 86.21 6,246.06 17.63 29.28 17.56 17,900.00 38.72 89.19 86.23 6,247.48 17.72 29.58 17.66 18,000.00 38.72 89.19 86.23 6,248.89 17.82 29.89 17.75 18,100.00 38.73 89.19 86.22 6,250.30 17.91 30.20 17.85 18,200.00 38.73 89.19 86.20 6,251.72 18.01 30.52 17.95 18,300.00 38.73 89.19 86.15 6,253.13 18.11 30.85 18.05 18,400.00 38.73 89.19 86.08 6,254.55 18.21 31.19 18.15 18,500.00 38.74 89.19 85.99 6,255.96 18.31 31.53 18.25 18,600.00 38.74 89.19 85.87 6,257.38 18.42 31.89 18.36 18,700.00 38.74 89.19 85.72 6,258.79 18.52 32.24 18.46 11/92015 11:19:57AM Page 8 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 18,772.64 38.74 89.19 85.59 6,259.82 18.60 32.51 18.54 Hold for 1400.69' 18,800.00 38.72 90.01 85.54 6,260.01 18.62 32.61 18.63 18,806.18 38.71 90.20 85.52 6,260.00 18.63 32.63 18.65 Start 3°/100'DLS,0.06°TF,for 33.54'-2S-Mako 5.Point 4 102115 PB 18,900.00 38.76 90.20 85.63 6,259.68 18.73 32.76 18.75 19,000.00 38.80 90.20 86.08 6,259.34 18.84 32.75 18.85 19,100.00 38.85 90.20 86.53 6,259.00 18.95 32.75 18.96 19,200.00 38.89 90.20 86.98 6,258.65 19.06 32.76 19.07 19,300.00 38.93 90.20 87.45 6,258.31 19.17 32.79 19.18 19,400.00 38.97 90.20 87.91 6,257.97 19.28 32.84 19.29 19,500.00 39.01 90.20 88.39 6,257.63 19.39 32.90 19.41 19,544.95 39.04 90.20 88.88 6,257.47 19.50 32.98 19.52 2S-Mako 1.Heel 19,600.00 39.04 90.20 88.88 6,257.29 19.50 32.98 19.52 19,700.00 39.07 90.20 89.39 6,256.94 19.62 33.07 19.63 19,782.25 39.10 90.20 89.91 6,256.66 19.73 33.17 19.75 2S-Mako 1.Heel 012815 PB 19,800.00 39.10 90.20 89.91 6,256.60 19.73 33.17 19.75 19,900.00 39.13 90.20 90.46 6,256.26 19.85 33.29 19.87 20,000.00 39.15 90.20 91.03 6,255.92 19.97 33.42 19.98 20,100.00 39.18 90.20 91.63 6,255.58 20.09 33.57 20.10 20,200.00 39.20 90.20 92.28 6,255.23 20.21 33.73 20.22 20,300.00 39.22 90.20 92.96 6,254.89 20.33 33.91 20.34 20,400.00 39.23 90.20 93.71 6,254.55 20.45 34.10 20.46 20,500.00 39.25 90.20 94.52 6,254.21 20.57 34.30 20.58 20,600.00 39.26 90.20 95.41 6,253.87 20.69 34.51 20.70 20,700.00 39.27 90.20 96.40 6,253.53 20.82 34.74 20.83 20,800.00 39.28 90.20 97.51 6,253.19 20.94 34.98 20.95 20,900.00 39.28 90.20 98.76 6,252.85 21.06 35.23 21.08 21,000.00 39.29 90.19 100.20 6,252.51 21.19 35.50 21.20 21,100.00 39.29 90.19 101.86 6,252.17 21.32 35.77 21.33 21,200.00 39.29 90.19 103.79 6,251.83 21.44 36.06 21.46 21,300.00 39.29 90.19 106.07 6,251.49 21.57 36.35 21.58 21,400.00 39.29 90.19 108.76 6,251.15 21.70 36.66 21.71 21,500.00 39.29 90.19 111.94 6,250.81 21.83 36.98 21.84 21,600.00 39.28 90.19 115.66 6,250.47 21.96 37.30 21.97 21,700.00 39.27 90.19 119.94 6,250.13 22.09 37.64 22.10 21,739.58 39.27 90.19 121.77 6,250.00 22.14 37.77 22.16 Start 0.42°/100'DLS,-89.99°TF,for 2933.4'-2S-Mako 6.Toe 102115 PB_Circle-2S-Mako 6.Toe 102115 PB 11/92015 11:19:57AM Page 9 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 11/92015 11:19:57AM Page 10 COMPASS 5000.1 Build 74 IP• Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.5°/100'DLS,63°TF,for 400' 1,000.00 999.27 9.50 18.64 Start 2.5°/100'DLS,0°TF,for 364.79' 1,364.79 1,357.50 39.82 78.15 Hold for 103.59' 1,468.37 1,457.50 52.08 102.22 Start 3°/100'DLS,-0.73°TF,for 1820.15' 3,288.53 2,750.87 597.80 1,150.58 Hold for 5805.01' 9,093.53 4,762.63 3,123.72 5,974.54 Start 3°/100'DLS, 111.33°TF,for 3611.53' 12,705.06 6,247.50 1,693.55 8,285.62 Hold for 20' 12,725.06 6,251.79 1,674.04 8,286.47 Start 3.01°/100'DLS,68.24°TF,for 349.07' 13,074.13 6,314.79 1,331.51 8,271.80 Hold for 0.53' 13,074.66 6,314.87 1,330.99 8,271.74 Start 3.01°/100'DLS,59.96°TF,for 349.61' 13,424.26 6,349.50 991.08 8,200.01 Start 2°/100'DLS,-3.43°TF,for 139.96' 13,564.22 6,353.41 856.86 8,160.59 Hold for 691.82' 14,256.04 6,355.90 192.79 7,966.64 Start 2°/100'DLS, 138.82°TF,for 152.45' 14,408.49 6,359.50 47.28 7,921.36 Start 3.5°/100'DLS, 106.92°TF,for 14.8' 14,423.29 6,360.16 33.27 7,916.66 Hold for 344.69' 11/9/2015 11:19:57AM Page 11 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-01 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-01 North Reference: True Wellbore: Plan:2S-01 Survey Calculation Method: Minimum Curvature Design: 2S-01wp09[Mako] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 21,739.58 6,409.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 12,705.06 6,247.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 3,230.66 2,730.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 10,945.40 5,591.50 Top Bermuda 1,881.37 1,841.50 Top W Sak(W Sak D) 0.00 1,416.58 1,407.50 Base permafrost(?) 0.00 12,194.30 6,109.50 Upper Kalubik(base HRZ) 11,901.99 6,007.50 Top HRZ(K-2 mkr) 9,009.47 4,733.50 C-40 11,059.25 5,645.50 Base Bermuda 11,153.31 5,689.50 C-35 9,371.47 4,865.50 C-37 13,122.35 6,321.50 B 3,907.84 2,965.50 C-80 13,469.19 6,351.50 A4 13,204.33 6,331.50 A5 10,820.41 5,531.50 Top Cairn 384.50 384.50 K-15 Marker 0.00 3,105.91 2,679.50 Base W Sak 0.00 13,051.82 6,311.50 Kuparuk C(Top C4) 8,155.35 4,437.50 C-50 295.50 295.50 top T-3 Sand 0.00 12,705.06 6,247.50 Lower Kalubik(K-1 mkr) 9,865.63 5,075.50 Growler-AA 13,161.53 6,326.50 A6 14,767.98 6,376.11 -292.72 7,805.78 Start 3.5°/100'DLS,-60.04°TF,for 124.89' 14,892.88 6,379.50 -412.15 7,769.51 Start 3°/100'DLS,-89.78°TF,for 288.59' 15,181.47 6,381.74 -695.47 7,716.12 Hold for 1724.71' 16,906.18 6,394.51 -2,409.58 7,525.61 Start 3°/100'DLS,91.6°TF,for 465.37' 17,371.95 6,399.51 -2,861.65 7,418.53 Adjust TF to-179.94°,for 0.39' 18,772.64 6,419.32 -4,175.22 6,932.65 Hold for 1400.69' 18,806.18 6,419.50 -4,206.68 6,921.01 Start 3°/100'DLS,0.06°TF,for 33.54' 21,739.58 6,409.50 -7,045.78 6,206.11 Start 0.42°/100'DLS,-89.99°TF,for 2933.4' Checked By: Approved By: Date: 11/52015 11:19:57AM Page 12 COMPASS 5000.1 Build 74 Pool Report ! • WELLBORE TARGET DETAILS(MAP CO-ORDINATED 13:,4,November 102015 2S-01wp09 [Mako] Name TVD Shape 25-P.mko 1.Heel 102115 PB 6348.50 Cktle(Radius:100.00) 25-Mako 2.Point 1 102115 PB 6359.50 Clyde(Radius:100.00) Quarter M i I e View 2-Mako 3.Point 3102115 PB 6399.50 Circle(Radius 10000) 29- k°4.Point 3102115 PB 6419.50 Circle(Radius:100.00) 2S-MaMako 5.Point4102115 PB 6419.50 Circle(Radius:100.00) 25-Mako 6.Toe 102115 102115 PB 6409.50 Circle(Radius:100.00) 25-Mako 1.Heel 102115 PB—Circe 6349.50 Circle(Radius:1320.00) 25a.Lko 6.Toe 102115 PB Circe 6409.50 Circle(R us:1320.00) 5000 4-4a 28,07 2500 ... -- - i c I • CD 0 0 /J2s o4aev •• • N ! ap •• `i p I , ... ,, . ......... 0 500 -.- - ' x __. z •c��5000 I ------.....1V1 - 4 -7500 _._._ k N ,, • 2S'10 2S-O,wP09[Ma;CIO) • I 1 - T I I I -7500 -5000 -2500 0 2500 5000 7500 10000 12500 West(-)/East(+) (2500 usftlinl • 0 2S-01 wp09 [Mako] Section View 6030-- -_ 6120- Z) 7-5/8"X 9-7/8" b ..4- ,E6210- 6210- 9 T cn w Iv 'N d o O o O .0 x6300— o m o a .co Till 0 0 2S-02--__ a0 a) oo- o o > CO) X6390-- 1 co o IV o) to o 0 4-1g"x 6 /4 a 0 o o 0 6480— 2S-01wp09 [Mako] KRU 21-10-8 6570— I I I I - 1 — 1 1 i -- 1 -6000 -4000 -2000 0 2000 4000 6000 8000 10000 Vertical Section at 195.00° (2000 usft/in) ! i 2S-01 wp09 [Mako] 3-D View \I , -. 2S-0. 2S-04PB ....n;.. •._ .. . 2S 01wp09 Mak. • • 2S-01 wp09 [Mako] 3-D View • •• .,:. KRU 2 10-. • • • •..' ~.•`. 250 i i 2S-01wp09 [Mako] 3-D View LUIZ ,/ -... __.-. 2S0. • • • • • • ;: 2S-01wp09[Mako • • 0 2S-01wp08 Surface Location r - E!!). CPAI Coordinate Converter From: To: Datum: 1NAD83 2:1 Region- lalaska "I Datum: IINAD27 ,1 Region: Jalaska .. i 1 C• Latitude/Longitude [ ' al Degrees --E,, c- Latitude/Longitude 1Decimal Degrees -----A c.- UTM Zone: 1---- E South r UTM Zone. l'irCe— E South (; State Plane Zone: 14 ,1 Units: rus:T.L..1 i"',‘'' State Plane Zone. 14-----7,1 Units: 1----.3tis.ft , ....A —...i Legal Description(NAD27 only) r Legal Description(NAD27 only) L *.] Starting Coordinates: -Ening Coordinates: X: 1162134233 X: 1 481309.014763658 V: 15929785.74 Y: 1 5930036.1484412 I ,.......................... Transform Quit Help 2S-01wp08 Intermediate Casing I CPAI Coordinate Converter. 1 From: To: Datum: 1NAD 83 ."I Region: lalaska .s..1 Datum: ..... INAD27 . Region: lalaska 2:i C' Latitude/Longitude ID ecimal Degrees 2, C Latitude/Longitude ID ecimal Degrees , _ 1---True C UTM Zone: i- 1- South r UTM Zone: E South ,rz State Plane Zone: Fi---E, Units: 1,171 .E ( State Plane Zone: ....:1-7,,I Units: rtTs-FE, C Legal Description(NAD27 only) C Legal Description(NAD27 only) . , Starting Coordinates: '—'-'i Ending Coordinates: X: 11622446.43 X: [482413.146791745 Y: 15930355.66 Y: 1 5930606.04025482 Transform Quit I Help i 2S-01wp08 Top of Production Horizon r 'y. CPA'Coordinate Converter 44:, a From: To:_ __1 Datum: NA083 Region: Ialaska � Datum: INAD27 Region: Jalaska �-i I �� c'• Latitude/Longitude !Decimal Degrees C Latitude/Longitude !Decimal Degrees ....._1 r' UTM Zone: South >? UTM Zone: True E South 1 1 State Plane Zone: q Units: us ft . C. State Plane Zone: q Units: us-ft 1 C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: - — X: 11629531.20 X: 1489498.102481522 Y: 15930712.99 Y: 15930963.2539604 Transform II Quit Help 2S-01 wp08 TD rCPAI Coordinate Converter ' From: ..__.. ._. ._._ -._ ------ To: Datum: 1NAD83 _.:.! Region: lalaska ni Datum: INAD27 zi Regie alaska _. C Latitude/Longitude [Decimal Degrees C Latitude/Longitude !Decimal Degrees*____ C' UTM Zone: I ' South C UTM Zone: True E South t.- State Plane Zone: q Units: us-ft _1 r State Plane Zone: q . Units: us-ft C- Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: --- '' X: 11627530 X: 487496.750616524 Y: 15922725 Y: 15922975.47751947 1 Transform Quit I Help • 0 2S-01wp08 Surface Location r tz CPA!Coordinate Converter 1,c::/f1-3411- 10 From: To: Datum: INAD83 w 1 Region: lalaska A Datum: 1NAD 27 w Region: lalaska w I C Latitude/Longitude [ ecimal Degrees ---- C Latitude/Longitude [Decimal Degrees .....J. ; i True UTM Zone: 1 r- South C UTM 1- South Zone: i-::' State Plane Zone: 14---E, Units: Fir."-A. i"- State Plane Zone: 1-4----cl Units: ' t .,, C Legal De-r;criprion ITIAD27 onlyt X: 11621342.33 .74 Meridian: iiF _............ i'.4. Legal Description(NAD27 only) Starting Coordinates: Legal Description Township: u010 ii-I-- „." —I Range: 1008 [ 'J Y: 15929785 Section:1-17 Fl VIEl- 13-0.1174978 jFELJ 11261.2317 Transform - 1 Quit J Heti 4... ..rimi 25-01wp08 Intermediate Casing i 1, e3. CPA!Coordinate Converter C.= 1 al From: .i. To. I Datum: 1NAD83 .-1 Region: lalaska ..m.1 Datum: 1NAD27 -.. Region: lalaska -.. 1 , C Latitude/Longitude Decimal Degrees ir' Latitude/Longitude !Decimal Degrees J ! (- UTM Zone: 1 1— South C UTM Zone: [True E South rii State Plane Zone: [ j Units: 1---:j us-ft .. [ C State Plane Zone: [-71.---....j. Units: ijiT1iE,. C. Legal DesgriptIon(NAD27 onlyl (4;• Legal Description(NAD 27 only) _.... -Starting Coordinates:--- - Legal Description X. r,622446A3 Township: I 1010 frii Range: 10r-08-- Ii-----.1 Y: 15930355.66 Meridian: lu w Section:11 7 ... .........___ __________ FFR----...1 12438.9073 FECT:;71 1156.71206 ...1 Transform Quit l' Help I am • 0 2S-01wp08 Top of Production Horizon i I M ,:-..., LeJ I, ,CPAI Coordinate Converter E..S j From: To: Datum FIA633----7.-1 Region: lalaska ....7:1 Datum: NAD 27 -ii, Region. lalaska _ ,-- Latitude/Longitude 1Decimal Degrees 7j C Latitude/Longitude 13ecirWal Degrees UTM Zone: i--- le- South C UTM Zone: ITtue E South 6; State Plane Zone: F-,----,,. Units: Fil-E C State Plane Zone: ri :.1 Units: ' C Le,cal Description(NAD27 Clr110 r; Legal Description(NAD27 only) _ Starting Coordinates: Legal Description -1 X: 11629531.20 Township: 1-----oi o 1Range: 1008 IT Y: 15930712.99 ' Meridian: [13 ESection:11 5 1 ---- - _ K-. -1 12068.4733 FF117:1 13630.8583 I i Transform Quit Help N 2S-01wp08 TD M, CPAI Coordinate Converter ! c:-..." I Cg 1prAriaram From. To: 1 1 Datum: 1NAD83 j Region: lalaska ... Datum: 1NAD27 zi Region: lalaska .....7.1 1 I I"- Latitude/Longitude Decimal Degrees z.1 C Latitude/Longitude 'Decimal Degrees ....d (..- UTM Zone: 1 r South C UTM Zone: ITrue r South C. State Plane Zone: F4------,,3 Units: ru5:,,.] C State Plane Zone: 4 Units: 1---113us. ... C Legal Desciiption 114AD27 only] r.-. Legal Description(NAD27 only) , 0 1„.„,„.., — — i i Starting Coordinates: Legal Description X: 11627530 Township: ram— IN j Range: RioT IFD. Y: 15922725 Meridian: lu wl Section:121 411771 14780.0952FEl17 ----F 1356.32150 i ------------- -------------------------------------- _i ...... Transform ---.1 Q uit I Help I -.3 As - built REV-. DATE BY CK APP 0 DESCRIPTION REV DATE BY OK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS , u , 17 16 '115 't -)14 yi3 J: 6I I. 17 f .....460, .� -- C'C'NOTES: I, 1 DS2A 1�.._._. �' 'DOC 1 ws 14 4u 1. BASIS OF LOCATION AND ELEVATION IS DS2S �1i-_ 1 , '] +, 10 MONUMENTATION PER LOUNSBURY & ASSOC. � `\1 DS2B' • ,OPF2 s , (ii ]7 52�' 25 31 ..'_l+ , 5 r 27 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, „ ` na2M �' '' ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES , �P �? `'DS2H /S „1 OS2F 4 ARE NAD 27. ', c5�,r' - 1-' ''. DS2G , .. . / P v w w ip T10N 3. ELEVATIONS ARE B.P.M.S.L. l'\ °_,..-.t--9 ,4` 1 ,x , 4�s Z 1 cccc 5 ] 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED ` IDS2K I �\�� f SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, j ,,z + f. + / n rr 7 z 5 10 UMIAT MERIDIAN. p P ..)"•,-., `' �j 3.... /3 . 9S6S '''c>;is 2 13 S 68 \61}� • 66 # 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS c 1f1 % i' L15-28, L15-29, L15-32, L15-35 11 ,— � I'+ 2i.1.: S Y. �l 1] '24 I, 1+� ;�P w='2,� 22 6. ALL DISTANCES SHOWN ARE TRUE. __ I LOCAPROJTION I `4 •s 'ja5 -�2�.-i ill ,, n 25 (3° 29 28 21 T .,\:!„. /)\- ...._,,i_ tl„ ].0, . N a,v L J --- .1 2 { 1n 31(..;.; 3�[..`} )1f ,b{ t`� 35 1]1 32 __ 3' VICINITY MAP _„, NTS 30 "P. DS2S --\ r 6 4 . ® 14 12 .10000ID 00 ° 3 21 0019 7 0 5 13 1 -- 7---- LEGEND - JLEGEND ® AS—BUILT CONDUCTOR LOCATION \ 17 16 20i 21 GRAPHIC SCALE 0 immL100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 It. SURVEYORS ENGINEERS PLANNERS 1 11.VAREA:2S MODULE: XXXX UNIT: D2 • Conoco hillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 1 of 2 1 REV DATE BY CK APP • DESCRIPTION REV DATE BY < APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.0. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150° 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150. 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150° 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' „c��,• ''' ' SURVEYOR'S CERTIFICATE °• 49th \ •.' ♦� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY = DONE BY ME OR UNDER MY DIRECT SUPERVISION AND 0 t" ;JEREMIAH F. CORNELL; o/ 0‘62.;:. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT � J•j°: LS-12663 • , it AS OF MAY 27, 2015. ,,11111a��M* LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS 44* AREA:2S MODULE: XXXX UNIT: D2 ConocoPhil lips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 1 . 2S-01 Drilling Hazards Summary 13-1/2" Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill(use of trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tam formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K RLL 02S—O PTD: caIS — 02c7 3 /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: 4ApckirtAK2POOL: / y3cjJ< RiVe_tr 47004,1AAgiVEAF / Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: / Well Logging ✓✓✓ Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, �/ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • 0 ❑❑ y , , a) a , N N , 4) 0a , O N , C, 0 CO a - m L ? , , , U >, a)' CO c O 0' , Z oS a) F', ,-, m E, a , Q* 2 Co , o. 0) a ' W m O .• C c , a 3 3, ° J ;! ll �pic as E N, 1111 m °�' a)' ' � o I- p. O. N a O -r O O. 2 0 a > w vj �; a Z; 0- 0' C' , �, oS' R' c CO' 2 92 ct N, rn a , �, E O, N no N Y C, 'm 0 C. , , ,-, as a �, 3, M m , �, �, a Q 0' , _ ° O 0 O). ) O, CO TD, ., a) C €' N. 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F2 N N N N N N N N N N M M M M M M co M co coO U U C L. u) H o 0 0 0) G" C a0+ N .0, N aO.i N 0 CO ce M O CO _ Co (0 CO co 0)'m W' N f�'6 m _ O N E J N H m a) C� o J #k •C a mc a (1) ° Q. m 0 W O a d c a U a) a s a Q Q w Q C7 Q • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: January 17, 2016 Surface Data Logging End of Well Report 2S-01 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 25 Well: 2S-01 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20727-00-00 Sperry Job Number: AK-XX-0903000543 Job Start Date: 26 December 2015 Spud Date: 16 December 2015 Total Depth: 21720’ MD, 6438’ TVD North Reference: True Declination: 18.42° Dip Angle: 80.86° Total Field Strength: 57,486 nT Date Of Magnetic Data: 30 Dec 2015 Wellhead Coordinates N: North 70° 13’ 10.937” Wellhead Coordinates W: West 150° 9’ 13.988“ Drill Floor Elevation 159.61’ Ground Elevation: 120.00’ Permanent Datum: Mean Sea Level SDL Engineers: Michael LaDouceur, Lesley Hunter, Ryan Lenberg Company Geologist: Jeff MacBeth, Ryan Massey Company Representatives: Granville Rizek, Rob Reinhardt, Pat Archie, SSDS Unit Number: 105 12/22/2015 SDL arrives on location mid run of intermediate section. Begin rigging up unit network and up CVE system. Drill through cement plug, circulate, and drill ahead to 3756’ MD. 12/23/2015 SDL crew continues to rig up equipment. Drill ahead from 3756’ MD to 5593’ MD. 12/24/2015 SDL crew continues to rig up equipment. Drill ahead from 5593’ MD to 5975’ MD. Pull out of hole to 2905’ MD due to pack offs. 12/25/2015 SDL crew continues to rig up equipment. Circulate and back ream out of hole. Run back in the hole and ream to 4840’ MD. 12/26/2015 SDL crew online monitor data. Trip in hole, washing down to bottom at 5976’ MD. Establish circulation and drill ahead to 7095’MD. Gas: Max gas was 41 units while drilling, average gas was 29 units. Fluids: No significant fluids were lost or gained from the hole. 12/27/2015 Drill ahead from 7081’ MD. Experience a minor pack-off event at 7139’ MD, pull off bottom to circulate. Drill ahead to 8437’ MD. Gas: Max gas was 210 units while circulating, average gas was 21 units. Fluids: No significant fluids were lost or gained from the hole. 12/28/2015 Drill from 8437' MD to 9333’ MD. Dilute 580bbls while drilling and circulate hole at 9333'. Pull trip nipple, install MPD bearing. Drill ahead from 9333' MD to 9899’ MD. Gas: Max gas was 269 units while drilling through the lower C37 at 9703’ MD, average gas was 56 units. Fluids: No significant fluids were lost or gained from the hole. 12/29/2015 Drill from 9899' MD to 10690' MD. Observe 400 psi gradual drop in pressure from 10500' MD to 10690' MD and reduction in MWD turbine speed. Pull out of hole to find washout at 6850' MD. Trip in hole from 6840' MD to 10475' MD. Wash and ream to 10655' MD. Circulate and condition. Drill ahead from 10690' MD to 10819' MD. Gas: Max gas was 249 units while tripping, average gas was 49 units. Fluids: No significant fluids were lost or gained from the hole. 12/30/2015 Drill from 10835' MD to 11131' MD. Circulate while changing mud pump swab. Drill ahead to 12,455' MD. Gas: Max gas was 890 units while drilling through the Upper Kalubik at 12272’ MD, average gas was 120 units. Fluids: No significant fluids were lost or gained from the hole. 12/31/2015 Drill from 12,455’ MD to intermediate TD at 12,585’MD/6,208’ TVD at 03:55hrs. Circulate three bottoms up at TD. Strip out of hole to shoe, circulate three bottoms up at shoe. Continue to pull out of hole to 2901' MD. Gas: Max gas of 268 units formation gas was the K-1 Marker in the Lower Kalubik Formation, average gas was 97 units (while drilling). Fluids: No significant fluids were lost or gained from the hole. 01/01/2016 Finish pulling out of the hole. Lay down BHA, test BOPs, and rig up casing equipment. Run in hole with 7-5/8” casing at 3830’ MD. Gas: Max gas was 25 units, average gas was 2 units. Fluids: No significant fluids were lost or gained from the hole. 01/02/2016 Continue run in hole with 7-5/8" casing and circulate up at 5726' MD, 8140' MD, 8639' MD, 11504' MD, 12532' MD, and on bottom at 12574' MD. Gas: Max gas was 441 units from circulating on bottom. Fluids: 6 bbls LSND were lost downhole. 01/03/2016 Land casing, complete the circulation and condition mud. Rig up cementers and run 2 stage cement job. Begin to lay down 5” drill pipe. Gas: Max gas was 106 units, average gas was 13 units. Fluids: No significant fluids were lost or gained from the hole. 01/04/2016 Finish laying down 5" drill pipe. Test upper variable bore rams and lower pipe rams with 4" test joint. Run in hole with 4" drill pipe singles. Gas: No significant gas data. Fluids: No significant fluids were lost or gained from the hole. 01/05/2016 Continue to run in hole with 4" drill pipe singles to 4839' MD. Pull out of hole with triple stands to surface. Pick up BHA and continue to run in hole with 4" drill pipe singles to 6214' MD and test BOPE. Gas: Max gas was 22 units, average was 1 units. Fluids: No significant fluids were lost or gained from the hole. 01/06/2016 Complete testing BOPE, rig down test equipment. Continue to run in hole while occasionally washing down and back reaming. Drill out stage collar, cement stringers, landing collar, and drill plugs. Continue to drill out plug and cement. Gas: Max gas was 22 units, average was 5 units. Fluids: No significant fluids were lost or gained from the hole. 01/07/2016 Continue drilling out cement, test casing, drill ahead 6 ¾” production section from 12585’ MD to 12605’ MD. Perform formation integrity test to 13.5 ppg EMW. Troubleshoot MWD tools and drill ahead from 12605’ MD to 12611’ MD. At 17:00hrs begin to strip out of hole due to MWD tool failure to 962’ MD and monitoring well. Gas: Max gas was 44 units, average was 0 units. Fluids: No significant fluids were lost or gained from the hole. 01/08/2016 Continue to pull out of hole, lay down BHA. Change out MWD and pick BHA, run in hole, and wash and ream from 12255' MD to 12610' MD. Begin drilling ahead in 6-3/4” production hole at 19:30. Gas: Max gas was 135 units, average was 68 units. Fluids: No significant fluids were lost or gained from the hole. 01/09/2016 Continue to drill ahead in 6-3/4” production section from 12869’ MD to 13389’ MD. Perform drawdown and the well is static at 10.3 ppg MW. Continue drilling ahead at 14535’ MD. Gas: Max gas was 2211 units of formation gas at 14125’ MD, average was 478 units. Fluids: No significant fluids were lost or gained from the hole. 01/10/2016 Continue drilling ahead in 6-3/4” production section from 14535’ MD to 16466’ MD. Gas: Max gas of 1927 units and is related to the MPD drawdown and an average of 523 units. Fluids: 62.7 bbls of Kla Shield mud was lost downhole. 01/11/2016 Continue drilling ahead in 6-3/4” production section from 16466’ MD to 17470’ MD unable to get slack off reading, CBU for 4 hours. Continue drilling ahead in production hole from 17942' MD to 17942' MD while MPD recalibrates chokes. Drilling ahead at 18135' MD. Gas: Max gas of 5220 units formation gas from a lagged depth of 17840' MD and average gas of 916 units. Fluids: 84.4 bbls of Kla Shield mud was lost downhole. 01/12/2016 Continue drilling ahead in 6-3/4" production section f/ 18130' MD t/19961' MD. Gas: Max gas of 2459 units formation gas and an average of 1326 units. Fluids: 94 bbls of Kla Shield mud was lost downhole. 01/13/2016 Continue drilling ahead in 6-3/4" production section from 19961' MD to 21567' MD. Gas: Max gas of 2153 units and an average of 857 units. Fluids: 83 bbls of Kla Shield mud was lost downhole. 01/14/2016 Reached production TD at 01:48 hrs AKST and 21720’ MD, 6438.89’ TVD. SDL released to rig down. 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-01 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0903000543 Days vs. Depth 22 Dec 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Burough STATE: Alaska SPUD: 16-Dec-2015 TD: 14-Jan-2016 Commenced Logging 9.875" Intermediate Hole Section On Bot: 10:30 26 Dec 2015 TD Intermediate Hole Section 12585' MD, 6210' TVD Off Bot: 03:55 31 Dec 2015 POOH for MWD Tool Failure 07 Jan 2016 Commenced 6.75" Production Hole Section On Bot: 06:25 07 Jan 2016 Landed 7.625" Casing 12574' MD, 6206' TVD 02 Jan 2015 TD Production Hole Section 21720' MD, 6438' TVD Off Bot: 01:48 14 Jan 2016 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: While drilling, there were problems with the connection to Totco WITS. Anytime this connection is lost, we lose our ability to track and record depth and our ability to track pit volumes. Without this connection, we are unable to display real time gas data on the Totco screens around the rig. We also had issues connecting to the Halliburton network with the Aruba, which inhibits our ability to send data to INSITE Anywhere. Recommendations: Make sure that the Aruba is configured correctly before it is sent to location, this will minimize troubleshooting on location. If we could run our own pit sensors, depth wheel, and hookload sensor we would not have to rely on WITS with Totco to track volumes and depth. Innovations and/or cost savings: N/A The rig up of the CVE system went well. Some components of the system were rigged up at the SDL shop to ensure the rig up went smoothly. This reduced troubleshooting on location. The placement of the SPX 25 pump was quick and efficient. The calibration of the equipment was good as the correlation between our GC and THA carried well through the run. 2S-01 Kuparuk River Unit ConocoPhillips Alaska, Inc North Slope Borough AK-XX-0903000543 Alaska Doyon 25 Intermediate Mike Ladouceur, Lesley Hunter 31-Dec-2015 What went as, or better than, planned: Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Excessive moisture returning back to the unit. Added a 3" length 3/4" tube to the inside of the dropout jars, which increases circulation through dropout jar and increased the amount of water being collected. Ice plugs formed very quickly in our gas gear exhaust line. Recommendations: Continue to blowback lines at every connection and empty dropout jars once a tour to reduce moisture. Innovations and/or cost savings: N/A Our entire insite system ran much smoother than the previous run; we had no major computer or gas gear issues. 2S-01 Kuparuk River Unit ConocoPhillips Alaska, Inc North Slope Borough AK-XX-0903000543 Alaska Doyon 25 Production Ryan Lenberg 14-Jan-2016 What went as, or better than, planned: Surface Data Logging After Action Review 2S-01 ConocoPhillips Alaska, Inc MI Swaco Doyon 25 AK-XX-0903000543 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 26-Dec 6846 9.60 46 12 28 12/18/21 4.6 52/40/34/27/13/11 1/-8.25 2/90 0.10 0.50 10.0 7.5 .25/1.10 550 160 Drill 9-7/8"x11" Int 27-Dec 8211 9.60 50 15 29 12/19/25 4.0 59/44/37/25/15/12 1/-9.00 4/88 0.10 0.40 9.5 25.0 .10/0.90 500 80 Drill 9-7/8"x11" Int 28-Dec 9762 9.70 42 13 26 11/14/18 3.5 52/39/34/27/12/10 1/-9.00 3/88 0.10 0.25 9.1 22.5 .10/0.75 500 80 Drill 9-7/8"x11" Int 29-Dec 10690 9.70 46 14 23 8/15/18 3.8 51/37/30/23/9/8 1/-9.50 3/88 0.15 0.28 9.6 26.0 .15/1.00 600 80 Drill 9-7/8"x11" Int 30-Dec 12376 10.00 41 14 17 7/11/18 3.0 45/31/26/19/8/7 1/-10.50 3/87 0.15 0.50 9.4 22.5 .40/1.10 600 80 Drill 9-7/8"x11" Int 31-Dec 12585 10.00 43 10 21 8/10/11 2.6 41/31/26/21/9/8 1/-10.00 2/88 tr 0.40 9.4 20.0 .30/1.50 700 80 Cut/Slip Drill Line 1-Jan 12585 10.00 49 13 18 7/9/12 2.6 44/31/26/20/8/7 1/-10.00 2/88 tr 0.35 9.5 20.0 .29/1.22 700 80 RIH casing 2-Jan 12585 10.10 45 12 19 7/11/13 2.8 43/31/26/21/9/7 1/-10.00 2/88 tr 0.35 9.5 20.0 .25/1.05 650 60 Circ. cond. hole 3-Jan 12585 10.00 40 10 15 5/6/8 2.8 35/25/19/14/6/5 1/-10.00 2/88 tr 0.30 9.5 20.0 .25/.95 600 60 L/D 5" DP 4-Jan 12585 10.00 42 10 17 5/6/8 2.8 37/27/20/14/6/5 1/-10.00 2/88 tr 0.30 9.5 20.0 .25/.95 600 60 PU 4" DP 5-Jan 12585 10.00 42 10 18 5/6/8 2.8 38/28/19/14/6/5 1/-10.00 2/88 tr 0.30 9.5 20.0 .25/.95 600 60 Test BOPE 6-Jan 12585 10.00 60 10 23 7/9/11 3.0 43/33/24/19/8/7 1/-10.00 2/88 tr 0.35 10.7 20.0 .25/.95 650 120 Drill Cement 7-Jan 12611 10.30 51 13 21 7/9/10 2.8 47/34/29/21/7/6 1/1 13.00 2/85 0.00 2.60 9.9 1.3 2.10/6.40 135000 60 Monitor Well 8-Jan 12661 10.30 53 11 20 7/8/9 3.2 42/31/26/19/8/6 1/1 11.70 2/86 tr 6.60 10.0 1.9 5.6/11.4 129000 60 Drill 6-3/4" Production 9-Jan 14253 10.30 53 16 25 8/9/10 3.2 57/41/36/26/9/8 1/1 14.00 2/84 0.25 5.30 9.9 5.0 3.60/6.90 125000 120 Drill 6-3/4" Production 10-Jan 16144 10.30 54 16 28 9/11/13 2.5 60/44/36/27/9/7 1/1 13.50 3/84 0.50 4.30 9.7 3.8 4.00/9.80 131000 120 Drill 6-3/4" Production 11-Jan 17491 10.30 53 15 25 8/10/11 3.5 55/40/34/26/10/8 1/1 13.50 3/84 0.25 5.10 9.7 3.0 3.00/8.50 130500 80 Drill 6-3/4" Production 12-Jan 19670 10.30 52 15 30 10/14/15 3.4 60/45/38/28/11/9 1/1 15.00 2/83 0.25 3.90 9.6 5.0 3.60/8.80 136000 80 Drill 6-3/4" Production 13-Jan 21170 10.40 58 18 35 12/18/20 3.1 71/53/44/34/13/11 1/1 15.50 4/81 0.25 3.20 9.5 4.5 2.80/7.50 137000 80 Drill 6-3/4" Production Casing Record RIG:SPUD:16-Dec-2015 SPERRY JOB:TD:14-Jan-2016 Remarks 10.75" Casing @ 2952' MD, 2603' TVD 7.625" Casing @ 12574' MD, 6206' TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 3 200 2 MSI516BPX PDC 9.875 5975 12585 6610 68.61 0.982 115.0 20 150 3920 800 1-1-WT-A-X-I-WT-TD Intermediate TD 4 300 3 MM55 PDC 6.75 12585 12611 26 0.46 0.383 56.5 17 70 2050 230 1-1-WT-A-X-I-WT-DTF Production 5 400 4 MM55 PDC 6.75 12611 21720 9109 -0.383 ------Production TD - personnel released at TD Alaska RIG:Doyon 25 SPUD:16-Dec-15 WELL NAME:2S-01 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0903000543 TD:21,720.00 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap:Trip in hole washing down from 4840' to bottom of hole at 5976'. Establish circulation and drill ahead to 7095' at rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 26-Dec-2015 12:00 AM Current Pump & Flow Data: 2335 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 8.3 9.875 9.70 PDC 9.60 Size 2952' 100% Gas In Air=10,000 Units31Connection 4 Tools API FL Chromatograph (ppm) 2960' 5975' WOB Surface Casing Avg Min Comments RPM ECD (ppg) ml/30min 19Background (max)Trip Average Mud Type Lst Type PDC LSND 4.6 5975' 7095'28 Depth in / out YP (lb/100ft2) 10.00 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0903000543 - - Drilling Ahead PV 3015' 9.875 0.982 Footage Granville Rizek/Pat Archie ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 142.0 Flow In (gpm) Flow In (spm) 5976' 7081' 1105' Max @ ft Current 6658'82.0 Date: Time: report time. 29 in 0Minimum Depth C-5n 6147' 125.0 C-2 41 SPP (psi) Gallons/stroke TFABit Type Depth 7.546 MBT pH 0.982 0 Siltst 748 177 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone: 0 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg/Michael LaDouceur Set AtSize 44.3 Grade 10.75'' (max)(current) 44 Cly 5552 Bottoms Up Time 606 6022725119 33 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 735.79 7306928143.2 38 (max)(current) 154 Cly 19750 Set AtSize 44.3 Grade 10.75'' 907-659-7599Unit Phone: 0 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg/Michael LaDouceur 798 189 Units* Casing Summary Lithology (%) MBT pH 0.982 16 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 25.050 C-5n 7132' 100.0 C-2 210 in 0Minimum Depth Time: bottom and circulated. Max gas of 210 units was recorded 01:30 as a result of this pack-off. Continued drilling ahead at 03:30 after 21 7081' 8437' 1356' Max @ ft Current 7115'94.7 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 149.0 Flow In (gpm) Flow In (spm) Gas Summary 5 0 (current) Granville Rizek/Pat Archie ShClyst TuffGvlCoal cP 15 3015' 9.875 0.982 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0903000543 - - Drilling Ahead PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 PDC LSND 4.0 5975' 8423'29 Depth in / out Mud Type Lst Type Average N/A20Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 2960' 5975' WOB Surface Casing 100% Gas In Air=10,000 Units24Connection 16 circulating and conditioning the hole. Drilling ahead at 8437' MD with no issue at report time. 2952' ConditionBit # 9.0 9.875 9.65 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Dec-2015 12:00 AM Current Pump & Flow Data: 3209 Max Chlorides mg/l 500.00 Continue drilling ahead from 7081' MD. Experienced a minor pack-off event at 00:30hrs at 7139' MD, pulled off rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 875.32 86911100.59 169.19 46 (max)(current) 1594 Cly 19446 Set AtSize 44.3 Grade 10.75'' 907-659-7599Unit Phone: 108 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 795 188 Units* Casing Summary Lithology (%) MBT pH 0.982 174 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.542 C-5n 9703' 119.0 C-2 269 in 0Minimum Depth Time: Pull trip nipple, install MPD bearing & get SPR's via MPU skid. Drill f/9333' to 9870'. Circulate while change mud pump swab. 56 8437' 9899' 1462' Max @ ft Current 9827'105.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 148.0 Flow In (gpm) Flow In (spm) Gas Summary 376 112 (current) Granville Rizek/Pat Archie ShClyst TuffGvlCoal cP 13 3015' 9.875 0.982 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0903000543 - - Drilling Ahead PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.10 PDC LSND 3.5 5975' 9762'26 Depth in / out Mud Type Lst Type Average N/A48Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 2960' 5975' WOB Surface Casing 100% Gas In Air=10,000 Units95Connection 1031 Drill to 9899' MD/ 5093' TVD. Max gas of 269 units was seen at 9703' MD and is due to formation gas in the lower C-37. 2952' ConditionBit # 9.0 9.875 9.70 PDC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 28-Dec-2015 12:00 AM Current Pump & Flow Data: 3248 Max Chlorides mg/l 500.00 Drill f/8423' MD t/ 9899’ MD. 580 bbl whole mud dilution at 8670' MD 03:35-05:10hrs. Circulate hole at 9333'. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill f/9899' to 10690' Observe 400 psi gradual dropoff f/10500' to 10690' & reduction in MWD turbine speed. rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 600.00 90 29-Dec-2015 11:59 PM Current Pump & Flow Data: 3584 Max 4.23 @ Mud Data Depth Chlorides Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) 9.59.809.70 Size Activate underreamer, circ & cond hole and drill f/100690' to 10819' MD at report time. Peak gas of 249 units was trip gas after 2952' Condition circulating on bottom of short trip. 100% Gas In Air=10,000 Units-Connection 309 Tools Gamma, Res, ECD, Density API FL Chromatograph (ppm) WOB Surface Casing Trip -- Avg Min Comments RPM ECD (ppg) Average N/A74Background (max) Mud Type Lst Type LSND 3.810690'23 Depth in / out YP (lb/100ft2) 9.60 124912 Cht Silt C-4i C-4n 182 Hours C-3 00 CementSs (ppb Eq) C-1 C-5i AK-AM-0903000543 - - Drilling Ahead PV Footage 5975' TuffGvlCoal cP 14 Weight ml/30min 0 150 42 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: 147.0 Flow In (gpm) Flow In (spm) Granville Rizek/Pat Archey 24 hr Max Job No.: Daily Charges: Date: Avg to5975' Gas Summary POOH to find washout at 2 bpm to 6850'. Washout in 5" DP & replace. TIH f/6840' to 10475'. Wash & ream to 10655'. 39 9899' 10819' 920' Max @ ft Current Depth Time: 147'147.0 ShClyst 0 -Minimum C-5n 10696' 90.0 C-2 249 SPP (psi) Gallons/stroke TFA Depth 26.046 in MBT 10819' pH 0 62 0 Siltst 798 188 Units* Casing Summary Lithology (%) 193868 0 907-659-7599Unit Phone: 12 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg Set AtSize 44.3 Grade 10.75'' (max)(current) 575 0 Cly 9762 Annular Volume Lag Correction Bottoms Up Bottoms Up 971.93 9655 51 2 PDC 9.875 0.982 Volumes Hole Capacity Drillstring 1219.66 187.18 1 PDC 5975' 3015' Bit #Bit Type 9.875 0.982 2960' . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC 5975' 3015'12 160 2 PDC 9.875 0.982 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 1401 215 Bottoms Up Strokes Bottoms Up Time 1119 -11111 58 (max)(current) 4015 0 Cly 907-659-7599Unit Phone: 240 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 15870 0 795 189 Units* Casing Summary Lithology (%) Set AtSize 44.310.75'' 0 276 0 Siltst Grade TFA Depth 22.541 in MBT 12455' (ppb Eq) Minimum C-5n 12272' 39.0 C-2 111.0 ShClyst 0 - 890 Time: 11719' SPP (psi) Gallons/stroke pH to 12,455' MD at 40 ft/hr at report time. 120 10819' 12455' 1636' Max @ ft Current Date: Avg to5975' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 131.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: 217 (current) Depth 36654 cP 14 Weight 894 C-1 C-5i AK-AM-0903000543 - - Drilling Intermediate PV CementSsTuffGvlCoal C-3 Footage Annular Volume (bbls) Lag Correction (bbls) 9733690 000 5975' YP (lb/100ft2) 9.40 C-4i C-4n 1460 Hours Lst Type LSND 3.017 Mud Type 12376' Depth in / out 209Background Min Comments RPM ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP Surface Casing Trip Cht Silt 2131 Average N/A rig Tools Gamma, Res, Neut, ECD, Density API FL Chromatograph (ppm) 10,000 Units512Connection (max) 100% Gas In Air= 10.1010.00 Size 2952' Condition Total Charges: MWD Summary 96% Rig Activity: 11.75 Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides 7.7510.97 Avg 30-Dec-2015 11:59 PM Current Pump & Flow Data: 3494 Max mg/l WOB 10.5600.00 Drill f/10835' MD to 11131' MD. Circ while change mud pump swab. Drilling ahead f/ 10835’ MD 773 111 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Drill f/ 12,455’ MD t/ intermediate TD at 12,485’MD/6,2409’ TVD at 03:55hrs. Circ 3 BU and POOH to shoe. CIRC 2 BH 341 75 31-Dec-2015 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides -- Avg Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Lower Kalubik Formation. 2952' Condition -Connection (max) 100% Gas In Air= rig Tools Gamma, Res, Neut, ECD, Density API FL Chromatograph (ppm) Trip Cht Silt 589 Average 25 10,000 Units ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP Surface Casing 10.0700.00 0Background Min Comments RPM Mud Type 12585' Depth in / out 10.00LSND 2.62110.00 Size 608 Hours Lst Type YP (lb/100ft2) 9.40 C-4i C-4n 8822873 000 C-3 Footage 12585' Annular Volume (bbls) Lag Correction (bbls) 68.61 CementSsTuffGvlCoal 575 C-1 C-5i AK-AM-0903000543 - - Drilling Intermediate PV cP 10 Weight 6610' 127 (current) Depth 22389 Yesterday's Depth: Current Depth: 24 Hour Progress: 42.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: Date: Avg to5975' Gas Summary BU at shoe. Cont POOH at report time w/ bit depth of 2901' MD. Max gas of 268 units formation gas was the K-1 Marker in the 97 12455' 12585' 130' Max @ ft Current Time: 12572' SPP (psi) Gallons/stroke pH 39.0 ShClyst 0 - 268 Minimum C-5n 12509' 0.0 C-2 TFA Depth 20.043 in MBT 12585' (ppb Eq) 0 587 0 Siltst Grade 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.310.75'' 6277 0 907-659-7599Unit Phone: 148 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg (max)(current) 2168 0 Cly Bottoms Up Strokes Bottoms Up Time 209 --- Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 1416 - 5975' 3015'12 160 2 PDC 9.875 0.982 5975' Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC 3015'12 160 2 PDC 9.875 0.982 5975' Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- Bottoms Up Strokes Bottoms Up Time ---- (max)(current) 0 0 Cly 907-659-7599Unit Phone: 0 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 0 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.310.75'' 0 0 0 Siltst Grade TFA Depth 20.049 in MBT 12585' (ppb Eq) Minimum C-5n - 0.0 C-2 ShClyst 0 - 25 Time: SPP (psi) Gallons/stroke pH ~3 12585' 12585' 0' Max @ ft Current Date: Avg to5975' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: 0 (current) Depth 0 cP 13 Weight 6610' 5975' 0 C-1 C-5i AK-AM-0903000543 - - Running 7-5/8" CSG PV Ss TuffGvlCoal 12585' Annular Volume (bbls) Lag Correction (bbls) 68.61 000 9.50 C-4i C-4n Footage Cement Hours Lst Type C-3 LSND 2.61810.00 Size Mud Type 12585' Depth in / out 10.00 0Background Min Comments RPM ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP Surface Casing 10.0700.00 YP (lb/100ft2) Trip Cht Silt 0 Average 25 10,000 Units rig Tools Gamma, Res, Neut, ECD, Density API FL Chromatograph (ppm) -Connection (max) 100% Gas In Air= 2952' Condition Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 1-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB Complete POOH. L/D BHA, test BOPE, R/U casing equipment. RIH 7 5/8” CSG at 3830’ MD at report time. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC 160 2 PDC 9.875 0.982 5975' Ss 3015'12 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- (max)(current) Intermediate Casing 1888 0 Cly 907-659-7599Unit Phone: 62 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 10.75'' 0 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 0 82 0 Siltst -- TFA Depth 20.045 in MBT 12585' (ppb Eq) Minimum C-5n 21:50 0.0 C-2 ShClyst 0 - 441 Time: SPP (psi) Gallons/stroke L-80 pH and on bottom at 12574' MD. The max gas of 441 units was from CBU on bottom at 12,574' MD. - 12585' 12585' 0' Max @ ft Current Date: Avg to5975' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: Time Bottoms Up Strokes Bottoms Up Time - 6610'20 150 5975' 61 (current) 44890 Grade C-5i AK-AM-0903000543 - - CBU w/ CSG on Bottom PV cP 12 Coal 7.625" 252 C-1 29.0 Weight 12585' Annular Volume (bbls) Lag Correction (bbls) 68.61 TuffGvl 000 9.50 C-4i C-4n Footage Cement Hours Lst Type C-3 LSND 2.81910.10 Size Mud Type 12585' Depth in / out 10.05 100Background Min Comments RPM ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD Surface Casing 10.0650.00 YP (lb/100ft2) Trip Cht Silt 755 Average 441 10,000 Units rig Tools Gamma, Res, ECD, Density API FL Chromatograph (ppm) -Connection (max) 100% Gas In Air= 2952' Condition Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 2-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB Cont' RIH w/ 7-5/8" CSG and CBU at the following depths 5726' MD, 8140' MD, 8639' MD, 11504' MD, 12532' MD, Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Complete circ and condition mud. R/U cementers and run 2 stage cement job. L/D 5” drill pipe at report time. 98 15 3-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides -- Avg Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) 12574' 2952' Condition 100% Gas In Air=106 10,000 Units Minimum API FL Chromatograph (ppm) 10.0600.00 YP (lb/100ft2) rig -Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD 2.815 0Background Surface Casing 278 Size Mud Type 12585' Average 10.00 Cement 158 Hours Lst 154914 Type 0 0 TuffGvl 0 9.50 C-4i C-4n Footage 125 C-1 29.0 Weight Annular Volume (bbls) Lag Correction (bbls) C-3 AK-AM-0903000543 - - L/D 5" Drill Pipe PV cP 10 Coal 36 (current) 8709 Grade C-5i 7.625" Time Bottoms Up Strokes Bottoms Up Time - Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: Date: Avg to5975' Gas Summary 13 12585' 12585' 0' Max @ ft Current Time: SPP (psi) Gallons/stroke L-80 pH ShClyst 0 - 106 C-5n 03:15 0.0 C-2 Depth 20.040 in MBT 12585' (ppb Eq) LSND 10.00 Gamma, Res, ECD, Density 42 0 Siltst -- 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 2388 0 0 907-659-7599Unit Phone: 38 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg (max)(current) Intermediate Casing 482 0 Cly - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- Ss 3015'12 10.75'' 6610'20 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- (max)(current) Intermediate Casing Cly 907-659-7599Unit Phone:Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 Siltst -- Depth 20.042 in MBT (ppb Eq) LSND 10.00 - C-5n 0.0 C-2 ShClyst - - Time: SPP (psi) Gallons/stroke L-80 pH - 12585' 12585' 0' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Pat Archey 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time - (current) Grade C-5i 7.625" AK-AM-0903000543 - - RIH w/ 4" DP SNGL's PV cP 10 Coal 29.0 Weight Annular Volume (bbls) Lag Correction (bbls) C-3 9.50 C-4i C-4n Footage Type TuffGvl Hours Lst C-1 Size Mud Type 12585' Average 10.00 -Background Surface Casing ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD -17 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 10.0600.00 YP (lb/100ft2) Cement 100% Gas In Air=-10,000 Units Minimum 12574' 2952' Condition Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 4-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB Finish L/D 5" DP. Test upper VBR's and LPR's w/ 4" TJ. RIH w/ 4" DP singles at report time. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- (max)(current) Intermediate Casing 194 Cly 907-659-7599Unit Phone: 26 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 76 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 29 Siltst -- Depth 20.042 in MBT (ppb Eq) LSND 10.00 GR, Res, Dens, Neu C-5n 19:34 0.0 C-2 ShClyst 0 22 Time: SPP (psi) Gallons/stroke L-80 pH and test BOPE at report time. 1 12585' 12585' 0' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Time Bottoms Up Strokes Bottoms Up Time - 27 (current) 1891 Grade C-5i 7.625" AK-AM-0903000543 - - Test BOPE PV cP 10 Coal 29.0 Weight Annular Volume (bbls) Lag Correction (bbls) C-3 9.50 C-4i C-4n Footage Type TuffGvl 6 Hours Lst 141 83 C-1 Size Mud Type 12485' Average 10.00 0Background Surface Casing 148 ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD 2.818 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 10.0600.00 YP (lb/100ft2) Cement 100% Gas In Air=-10,000 Units Minimum 12574' 2952' Condition Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 5-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB Cont RIH w/ 4" DP singles t/ 4839' MD, POOH STDS and P/U BHA. Cont RIH w/ 4" DP singles t/ 6214' MD 5 1 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Complete testing BOPE, R/D test equipment. Cont RIH while occasionally washing down and back reaming. 24 5 6-Jan-2016 11:59 PM Current Pump & Flow Data: 1743 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides -- Avg Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) 12574' 2952' Condition 100% Gas In Air=-10,000 Units Minimum API FL Chromatograph (ppm) 10.0650.00 YP (lb/100ft2) Cement rig -Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD 3.023 0Background Surface Casing 164 Size Mud Type 12585' Average 10.00 21 Hours Lst 7206 96 C-1 Type 0 0 TuffGvl 0 10.70 C-4i C-4n Footage 29.0 Weight Annular Volume (bbls) Lag Correction (bbls) C-3 AK-AM-0903000543 - - Drill Cement PV cP 10 Coal 27 (current) 1760 Grade C-5i 7.625" Time Bottoms Up Strokes Bottoms Up Time - Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Date: Avg to12585' Gas Summary . Drill out stage collar, cement stringers, landing collar, drill plugs. Drilling out drill plug/cement at report time at 12,451’ MD. 5 12585' 12585' 0' Max @ ft Current Time: SPP (psi) Gallons/stroke L-80 pH ShClyst 0 22 C-5n 08:44 0.0 C-2 Depth 20.060 in MBT (ppb Eq) LSND 10.00 GR, Res, Dens, Neu 30 0 Siltst -- 209 50 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 388 0 0 907-659-7599Unit Phone: 28 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg (max)(current) Intermediate Casing 203 0 Cly - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- Ss 3015'12 10.75'' 6610'20 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) -- (max)(current) Intermediate Casing 289 0 Cly 907-659-7599Unit Phone: 16 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 275 0 0 0 0 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 13 0 Siltst -- Depth 1.351 in MBT 12611' (ppb Eq) Kla-Shield 10.30 GR, Res, Dens, Neu C-5n 12606' 0.0 C-2 109.0 ShClyst 0 - 44 Time: 12,611' SPP (psi) Gallons/stroke L-80 pH Perform FIT t/ max 15ppg EMW. Displaced well to 10.3 ppg Kla-Shield mud. Troubleshoot MWD tools and drill ahead f/ 12605’ MD 0 12585' 12611' 26' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 251.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time - 13 (current) 4782 0.383 Grade C-5i 7.625" 12585' AK-AM-0903000543 - - TOOH for MWD PV cP 13 26' Coal 29.0 Weight Annular Volume (bbls) Lag Correction (bbls) C-3 9.90 C-4i C-4n Footage Type 6.75 0 0 TuffGvl 0 17 Hours Lst 482 44 C-1 Size Mud Type 12611' Average 10.30 PDC 0Background Surface Casing 107 ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 1-1-WT-A-X-I-WT-TD 2.821 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 12611' 13.0135000.00 YP (lb/100ft2) Cement 100% Gas In Air=5 10,000 Units Minimum t/ 12611’ MD. At 1700 hrs begin strip OOH due to MWD tool failure, bit depth of 962’ MD and monitoring well at report time. 12574' 2952' Condition 3 Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 7-Jan-2016 11:59 PM Current Pump & Flow Data: 0 Max mg/l WOB Cont’ drill cement, test casing, drill ahead 6 ¾” production section f/ 12585’ MD t/ 12605’ MD. 9 1 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 62 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 497 126 (max)(current) Intermediate Casing 1104 0 Cly 907-659-7599Unit Phone: 35 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 7992 0 0 248 59 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 44 0 Siltst 370 - Depth 1.953 in MBT 12869' (ppb Eq) Kla-Shield 10.30 GR, Res, Dens, Neu C-5n 12812' 123.0 C-2 94.0 ShClyst 0 - 135 Time: 12587' SPP (psi) Gallons/stroke L-80 pH 19:30. 68 12611' 12869' 258' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 125.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time 3679 26 (current) 13602 0.383 Grade C-5i 7.625" 0.46 12585' AK-AM-0903000543 - - Drilling Production Sec. PV cP 11 26' Coal 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- 10.00 C-4i C-4n Footage Type 6.75 0 0 TuffGvl 0 513 Hours Lst 13404 121 C-1 Size Mud Type 12661' Average 10.35 PDC 62Background Surface Casing 457 ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 3.220 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 12611' 11.7129000.00 YP (lb/100ft2) Cement 100% Gas In Air=5 10,000 Units Minimum 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 8-Jan-2016 11:59 PM Current Pump & Flow Data: 2328 Max mg/l WOB Cont' POOH, L/D BHA, P/U BHA, RIH, and wash & ream f/ 12255' MD t/12610' MD. Drill ahead production hole at 19:30. 177 13 Density (ppg) out (sec/qt) Viscosity Cor Solids % --4 PDC 6.75 0.383 -12611' . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 72 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 664 155 (max)(current) Intermediate Casing 1561 0 Cly 907-659-7599Unit Phone: 794 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg 28820 0 0 259 62 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 1127 0 Siltst 451 - Depth 5.053 in MBT 14535' (ppb Eq) Kla-Shield 10.30 GR/RES/Neut/Dens/Periscope C-5n 14125' 150.0 C-2 139.0 ShClyst 0 - 2211 Time: 14106' SPP (psi) Gallons/stroke L-80 pH Cont’ drilling ahead at 14535’ MD at report time. Max gas of 2211 units formation gas seen at a lagged depth of 14125’ MD and an 478 12869' 14535' 1666' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 209.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time (mins) 4482 753 (current) 132689 0.383 Grade C-5i 7.625" 0.46 12585' AK-AM-0903000543 - - Drill 6-3/4" Production PV cP 16 26' Coal 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- 9.90 C-4i C-4n Footage Type 6.75 0 0 TuffGvl 0 3306 Hours Lst 250794225 3013 C-1 Size Mud Type 1425' Average 10.30 PDC 512Background Surface Casing 8777 ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 3.225 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 12611' 14.0125000.00 YP (lb/100ft2) Cement 100% Gas In Air=-10,000 Units Minimum average of 478 units. 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides -- Avg 9-Jan-2016 11:59 PM Current Pump & Flow Data: 2700 Max mg/l WOB Cont’ drilling ahead in 6-3/4” production section f/ 12869’ MD. Perform drawdown well is static at 10.3 ppg MW. 2086 273 Density (ppg) out (sec/qt) Viscosity Cor Solids % --4 PDC 6.75 0.383 -12611' . . * 24 hr Recap: --4 PDC 6.75 0.383 -12611' Density (ppg) out (sec/qt) Viscosity Cor Solids % 2338 343 10-Jan-2016 11:59 PM Current Pump & Flow Data: 2853 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides 11.8812.16 Avg Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: 12.26 Doyon 25 Report For: ROP ROP (ft/hr) 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 100% Gas In Air=-10,000 Units Minimum API FL Chromatograph (ppm) 12611' 13.5131000.00 YP (lb/100ft2) Cement rig 1411Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 2.528 PDC 386Background Surface Casing 7494 Size Mud Type 16144' Average 10.30 3236 Hours Lst 3711053321 2345 C-1 Type 6.75 0 0 TuffGvl 0 9.70 C-4i C-4n Footage 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- AK-AM-0903000543 - - Drill 6-3/4" Production PV cP 16 26' Coal 583 (current) 124074 0.383 Grade C-5i 7.625" 0.46 12585' Depth Bottoms Up Strokes Bottoms Up Time (mins) 5052 Yesterday's Depth: Current Depth: 24 Hour Progress: 189.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Date: Avg to12585' Gas Summary Cont’ drilling ahead in 6-3/4” production section f/ 14535’ MD t/ 16466’ MD. Max gas from MPD drawdown. 523 14535' 16466' 1931' Max @ ft Current Time: 16416' SPP (psi) Gallons/stroke L-80 pH 82.0 ShClyst 0 - 1927 C-5n 16183' 133.0 C-2 Depth 3.854 in MBT 16466' (ppb Eq) Kla-Shield 10.30 GR/RES/Neut/Dens/Periscope 919 0 Siltst 508 - 261 62 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 23702 0 0 907-659-7599Unit Phone: 618 Ryan Lenberg Maximum Report By:Logging Engineers:Lesley Hunter/Ryan Lenberg (max)(current) Intermediate Casing 13398 0 Cly 81 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 749 176 Ss 3015'12 10.75'' 6610'20 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out . . * 24 hr Recap: --4 PDC 6.75 0.383 -12611' Density (ppg) out (sec/qt) Viscosity Cor Solids % 4050 540 11-Jan-2016 11:59 PM Current Pump & Flow Data: 2904 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides 8.1212.20 Avg Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: 12.44 Doyon 25 Report For: ROP ROP (ft/hr) Cont' drilling ahead production hole f/ 17942' MD t/ 17942' MD recalibrate MPD chokes. Drilling ahead at 18135' MD at report time. 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 Max formation gas of 5220 units from a lagged depth of 17840' MD. 100% Gas In Air=-10,000 Units Minimum API FL Chromatograph (ppm) 12611' 13.5132000.00 YP (lb/100ft2) Cement rig -Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 3.525 PDC 1247Background Surface Casing 12886 Size Mud Type 17941' Average 10.30 6174 Hours Lst 4781550426 3835 C-1 Type 6.75 0 0 TuffGvl 0 9.70 C-4i C-4n Footage 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- AK-AM-0903000543 - - Drill 6-3/4" Production PV cP 15 26' Coal 890 (current) 349105 0.383 Grade C-5i 7.625" 0.46 12585' Depth Bottoms Up Strokes Bottoms Up Time (mins) 5542 Yesterday's Depth: Current Depth: 24 Hour Progress: 196.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Date: Avg to12585' Gas Summary Cont’ drilling ahead in 6-3/4” production section f/ 16466’ MD t/ 17470’ MD unable to get slack off reading, CBU for 4 hours. 916 16466' 18130' 1664' Max @ ft Current Time: 17225' SPP (psi) Gallons/stroke L-80 pH 137.0 ShClyst 0 - 5220 C-5n 17840' 125.0 C-2 Depth 3.053 in MBT 18130' (ppb Eq) Kla-Shield 10.30 GR/RES/Neut/Dens/Periscope 1451 0 Siltst 558.2 - 261 62 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 49939 0 0 907-659-7599Unit Phone: 948 Ryan Lenberg Maximum Report By:Logging Engineers:Michael LaDouceur/Ryan Lenberg (max)(current) Intermediate Casing 28431 0 Cly 89 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 823.25 194.39 Ss 3015'12 10.75'' 6610'20 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out . . * 24 hr Recap: Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Ss 3015'12 10.75'' 6610'20 98 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 823 214 (max)(current) Intermediate Casing 16337 0 Cly 907-659-7599Unit Phone: 1026 Ryan Lenberg Maximum Report By:Logging Engineers:Michael LaDouceur/Ryan Lenberg 69436 0 0 259 62 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 1398 0 Siltst 613 - Depth 5.052 in MBT 19961' (ppb Eq) Kla-Shield 10.30 GR/RES/Neut/Dens/Periscope C-5n 19583' 115.0 C-2 108.0 ShClyst 0 - 2459 Time: 19550' SPP (psi) Gallons/stroke L-80 pH Contine drilling ahead in 6-3/4" production section f/ 18130' MD t/19961' MD. 1326 18130' 19961' 1831' Max @ ft Current Date: Avg to12585' Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 149.0 Flow In (gpm) Flow In (spm) Granville Rizek/Kurt Alexa 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time (mins) 6082 947 (current) 141057 0.383 Grade C-5i 7.625" 0.46 12585' AK-AM-0903000543 - - Drill 6-3/4" Production PV cP 15 26' Coal 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- 9.60 C-4i C-4n Footage Type 6.75 0 0 TuffGvl 0 8719 Hours Lst 6552214587 3801 C-1 Size Mud Type 19670' Average 10.30 PDC 1200Background Surface Casing 10640 ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 3.430 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 12611' 15.0136000.00 YP (lb/100ft2) Cement 100% Gas In Air=-10,000 Units Minimum 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 Total Charges: MWD Summary 96% Rig Activity: 12.75 Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides 12.1312.58 Avg 12-Jan-2016 11:59 PM Current Pump & Flow Data: 3295 Max mg/l WOB 5851 787 Density (ppg) out (sec/qt) Viscosity Cor Solids % --4 PDC 6.75 0.383 -12611' . . * 24 hr Recap: --4 PDC 6.75 0.383 -12611' Density (ppg) out (sec/qt) Viscosity Cor Solids % 3663 537 13-Jan-2016 11:59 PM Current Pump & Flow Data: 3486 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides 12.4212.75 Avg Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2S-01 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: 12.88 Doyon 25 Report For: ROP ROP (ft/hr) 12574' 2952' Condition 1-1-WT-A-X-I-WT-DTF3 100% Gas In Air=-10,000 Units Minimum API FL Chromatograph (ppm) 12611' 15.5137000.00 YP (lb/100ft2) Cement rig -Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 1-1-CT-N-X-I-WT-HP 8 1-1-WT-A-X-I-WT-TD 3.135 PDC 716Background Surface Casing 9520 Size Mud Type 21170' Average 10.35 5090 Hours Lst 5171570453 3466 C-1 Type 6.75 0 0 TuffGvl 0 9.50 C-4i C-4n Footage 29.0 Weight 65 Annular Volume (bbls) Lag Correction (bbls) C-3 --- AK-AM-0903000543 - - Drill 6-3/4" Production PV cP 18 26' Coal 866 (current) 112969 0.383 Grade C-5i 7.625" 0.46 12585' Depth Bottoms Up Strokes Bottoms Up Time (mins) 6556 Yesterday's Depth: Current Depth: 24 Hour Progress: 166.0 Flow In (gpm) Flow In (spm) Granville Rizek/Kurt Alexa 24 hr Max Job No.: Daily Charges: Date: Avg to12585' Gas Summary Continue drilling ahead in 6-3/4" production section f/ 19961' MD t /21567' MD. 857 19961' 21567' 1606' Max @ ft Current Time: 20878' SPP (psi) Gallons/stroke L-80 pH 109.0 ShClyst 27 - 2153 C-5n 20096' 120.0 C-2 Depth 4.558 in MBT 21567' (ppb Eq) Kla-Shield 10.40 GR/RES/Neut/Dens/Periscope 1258 0 Siltst 613 - 261 62 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 41550 0 0 907-659-7599Unit Phone: 948 Ryan Lenberg Maximum Report By:Logging Engineers:Michael LaDouceur/Ryan Lenberg (max)(current) Intermediate Casing 14197 0 Cly 106 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 892 232 Ss 3015'12 10.75'' 6610'20 160 2 PDC 9.875 0.982 5975' 150 5975' 12585' 68.61 Bit #Bit Type 9.875 0.982 27.78 2960' 1 PDC TFA Depth in / out WELL INFORMATION Created On : Jan 28 2016 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-01 Job Number :AK-XX-0903000543 Rig Name :Doyon 25 Field Name :Kuparuk River Unit State / Province :Alaska Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 84.00 0.61 294.79 84.00 0.19 N 0.41 W -0.08 0.73 184.00 0.76 295.30 183.99 0.69 N 1.49 W -0.29 0.15 276.00 1.08 300.08 275.98 1.39 N 2.79 W -0.62 0.36 370.00 0.82 356.34 369.97 2.50 N 3.60 W -1.49 0.98 462.00 2.52 54.48 461.93 4.34 N 2.00 W -3.67 2.39 557.00 3.50 62.90 556.80 6.87 N 2.29 E -7.23 1.13 650.00 4.12 74.68 649.59 9.05 N 8.03 E -10.82 1.07 745.00 4.70 77.85 744.31 10.77 N 15.13 E -14.32 0.66 839.00 5.41 71.52 837.95 12.98 N 23.10 E -18.52 0.96 863.34 5.44 67.69 862.18 13.79 N 25.25 E -19.85 1.49 958.04 6.22 63.52 956.39 17.78 N 34.00 E -25.97 0.94 1052.28 7.57 66.62 1,049.94 22.52 N 44.27 E -33.21 1.49 1146.12 8.95 65.38 1,142.81 28.01 N 56.58 E -41.70 1.48 1240.91 11.25 62.85 1,236.12 35.30 N 71.51 E -52.61 2.47 1335.43 15.64 62.42 1,328.03 45.41 N 91.02 E -67.42 4.65 1430.70 16.64 62.38 1,419.54 57.68 N 114.49 E -85.35 1.05 1524.30 18.13 64.66 1,508.87 70.13 N 139.52 E -103.85 1.75 1618.41 19.93 64.46 1,597.83 83.31 N 167.23 E -123.76 1.91 1713.85 21.53 65.92 1,687.09 97.47 N 197.90 E -145.37 1.76 1808.53 25.67 67.86 1,773.83 112.30 N 232.77 E -168.72 4.45 1903.85 29.11 68.07 1,858.45 128.74 N 273.42 E -195.12 3.61 1998.34 31.36 67.22 1,940.09 146.85 N 317.41 E -224.00 2.42 2093.33 34.19 66.72 2,019.95 166.97 N 364.73 E -255.68 2.99 2187.89 37.04 63.71 2,096.82 190.09 N 414.68 E -290.94 3.54 2282.23 40.05 62.07 2,170.60 216.90 N 466.99 E -330.37 3.37 2376.85 43.57 61.39 2,241.11 246.78 N 522.53 E -373.61 3.75 2470.82 44.76 60.58 2,308.52 278.54 N 579.78 E -419.11 1.40 2565.64 47.68 61.98 2,374.12 311.42 N 639.81 E -466.40 3.26 2660.48 49.36 62.69 2,436.93 344.40 N 702.74 E -514.55 1.86 2753.26 54.04 61.90 2,494.42 378.26 N 767.18 E -563.93 5.09 INSITE V8.3.0 Page 1Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2849.33 56.31 62.11 2,549.28 415.27 N 836.81 E -617.70 2.37 2889.66 58.69 61.80 2,570.95 431.26 N 866.83 E -640.92 5.94 2969.65 59.17 59.89 2,612.23 464.64 N 926.66 E -688.64 2.13 3022.65 60.47 61.03 2,638.88 487.23 N 966.52 E -720.78 3.08 3121.62 64.04 61.37 2,684.94 529.41 N 1,043.27 E -781.39 3.62 3211.94 66.32 61.52 2,722.85 568.59 N 1,115.27 E -837.87 2.53 3307.43 68.81 61.14 2,759.29 610.94 N 1,192.70 E -898.81 2.63 3403.45 69.15 61.47 2,793.74 653.97 N 1,271.32 E -960.73 0.48 3496.67 69.62 61.83 2,826.56 695.40 N 1,348.11 E -1020.63 0.62 3590.88 69.61 61.69 2,859.37 737.19 N 1,425.91 E -1081.12 0.14 3685.79 69.68 61.60 2,892.39 779.45 N 1,504.22 E -1142.21 0.12 3780.39 69.67 62.07 2,925.25 821.32 N 1,582.42 E -1202.90 0.47 3874.54 69.63 61.75 2,957.99 862.89 N 1,660.30 E -1263.20 0.32 3968.93 70.14 60.83 2,990.45 905.46 N 1,738.03 E -1324.45 1.06 4063.87 70.18 60.72 3,022.67 949.07 N 1,815.97 E -1386.73 0.12 4157.78 69.66 61.97 3,054.91 991.36 N 1,893.36 E -1447.62 1.37 4252.12 69.61 62.14 3,087.74 1,032.81 N 1,971.49 E -1507.88 0.18 4346.55 69.58 62.70 3,120.67 1,073.79 N 2,049.94 E -1567.76 0.56 4442.96 69.62 62.47 3,154.27 1,115.39 N 2,130.16 E -1628.71 0.23 4536.26 69.58 63.31 3,186.80 1,155.24 N 2,208.00 E -1687.35 0.84 4631.02 69.55 63.92 3,219.88 1,194.70 N 2,287.54 E -1746.05 0.60 4729.75 69.58 64.11 3,254.35 1,235.24 N 2,370.71 E -1806.73 0.18 4820.19 69.62 63.77 3,285.88 1,272.48 N 2,446.86 E -1862.41 0.36 4913.24 69.65 63.16 3,318.26 1,311.45 N 2,524.90 E -1920.25 0.62 5008.61 69.61 63.22 3,351.46 1,351.77 N 2,604.70 E -1979.86 0.07 5102.60 69.55 63.10 3,384.25 1,391.54 N 2,683.29 E -2038.61 0.14 5198.70 69.61 63.17 3,417.78 1,432.24 N 2,763.63 E -2098.72 0.09 5293.66 69.75 62.73 3,450.75 1,472.74 N 2,842.94 E -2158.36 0.46 5388.04 69.52 62.27 3,483.60 1,513.59 N 2,921.42 E -2218.14 0.52 5481.73 69.58 61.69 3,516.33 1,554.83 N 2,998.92 E -2278.03 0.58 5578.13 69.55 60.91 3,549.99 1,598.21 N 3,078.15 E -2340.44 0.76 5670.05 69.65 60.86 3,582.03 1,640.13 N 3,153.42 E -2400.41 0.12 5765.67 69.55 61.28 3,615.36 1,683.49 N 3,231.86 E -2462.59 0.42 5859.37 69.62 61.52 3,648.05 1,725.52 N 3,308.96 E -2523.15 0.25 5955.96 69.45 61.97 3,681.82 1,768.36 N 3,388.67 E -2585.16 0.47 6046.37 69.74 62.21 3,713.34 1,808.03 N 3,463.55 E -2642.85 0.41 6140.84 69.69 63.01 3,746.09 1,848.79 N 3,542.23 E -2702.59 0.80 6235.41 69.79 62.91 3,778.84 1,889.12 N 3,621.25 E -2762.00 0.14 6330.43 69.69 64.00 3,811.74 1,928.96 N 3,700.99 E -2821.12 1.08 6424.80 69.80 62.81 3,844.42 1,968.60 N 3,780.16 E -2879.89 1.19 6519.68 69.77 61.96 3,877.20 2,009.87 N 3,859.05 E -2940.18 0.84 6615.12 69.63 61.40 3,910.31 2,052.33 N 3,937.85 E -3001.59 0.57 6708.74 69.73 60.36 3,942.83 2,095.05 N 4,014.54 E -3062.70 1.05 6803.27 69.73 61.76 3,975.58 2,137.96 N 4,092.14 E -3124.23 1.39 6897.89 69.79 61.15 4,008.31 2,180.38 N 4,170.13 E -3185.40 0.61 INSITE V8.3.0 Page 2Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6992.20 69.86 60.16 4,040.84 2,223.77 N 4,247.29 E -3247.27 0.99 7087.00 69.80 60.54 4,073.53 2,267.79 N 4,324.63 E -3309.81 0.38 7181.53 69.82 60.61 4,106.15 2,311.37 N 4,401.90 E -3371.91 0.07 7275.82 69.73 61.08 4,138.75 2,354.48 N 4,479.17 E -3433.54 0.48 7370.63 69.63 61.55 4,171.67 2,397.15 N 4,557.17 E -3494.95 0.48 7465.99 69.77 61.74 4,204.76 2,439.63 N 4,635.87 E -3556.35 0.24 7564.31 69.74 63.46 4,238.78 2,482.08 N 4,717.77 E -3618.55 1.64 7653.49 69.70 62.91 4,269.69 2,519.82 N 4,792.42 E -3674.32 0.58 7749.38 69.71 63.31 4,302.95 2,560.49 N 4,872.64 E -3734.37 0.39 7843.29 69.57 64.17 4,335.63 2,599.45 N 4,951.59 E -3792.44 0.87 7938.35 69.74 63.70 4,368.67 2,638.61 N 5,031.66 E -3850.99 0.50 8031.58 69.73 62.76 4,400.97 2,678.00 N 5,109.74 E -3909.25 0.95 8126.13 69.71 61.86 4,433.74 2,719.21 N 5,188.27 E -3969.38 0.89 8221.47 69.60 61.17 4,466.89 2,761.85 N 5,266.84 E -4030.90 0.69 8315.96 69.77 61.34 4,499.69 2,804.46 N 5,344.53 E -4092.17 0.25 8410.46 69.79 60.94 4,532.35 2,847.26 N 5,422.20 E -4153.61 0.40 8505.43 69.73 62.06 4,565.21 2,889.78 N 5,500.50 E -4214.94 1.11 8599.82 69.76 61.79 4,597.89 2,931.45 N 5,578.64 E -4275.42 0.27 8694.74 69.81 61.56 4,630.69 2,973.72 N 5,657.04 E -4336.54 0.23 8789.09 69.67 61.71 4,663.36 3,015.77 N 5,734.93 E -4397.32 0.21 8884.04 69.81 61.38 4,696.24 3,058.21 N 5,813.24 E -4458.58 0.36 8978.74 69.28 63.15 4,729.33 3,099.50 N 5,891.77 E -4518.79 1.84 9072.59 68.76 66.54 4,762.95 3,136.75 N 5,971.07 E -4575.29 3.42 9167.47 68.45 68.23 4,797.56 3,170.72 N 6,052.62 E -4629.21 1.69 9261.56 68.30 70.43 4,832.24 3,201.59 N 6,134.45 E -4680.21 2.18 9355.54 68.10 71.60 4,867.14 3,229.98 N 6,216.96 E -4728.99 1.18 9453.28 67.46 73.65 4,904.11 3,257.00 N 6,303.31 E -4777.43 2.05 9545.54 66.12 76.14 4,940.47 3,279.10 N 6,385.16 E -4819.97 2.87 9639.05 65.50 79.25 4,978.79 3,297.28 N 6,468.48 E -4859.09 3.11 9734.16 63.96 82.05 5,019.40 3,311.27 N 6,553.33 E -4894.56 3.12 9828.99 62.55 85.01 5,062.08 3,320.82 N 6,637.46 E -4925.57 3.16 9923.33 62.73 87.39 5,105.44 3,326.37 N 6,721.05 E -4952.56 2.25 10018.61 61.48 90.51 5,150.03 3,327.93 N 6,805.23 E -4975.85 3.18 10113.47 60.59 95.60 5,195.99 3,323.52 N 6,888.07 E -4993.04 4.79 10207.39 61.27 100.56 5,241.65 3,311.98 N 6,969.30 E -5002.91 4.67 10302.79 61.83 104.08 5,287.10 3,294.08 N 7,051.23 E -5006.83 3.30 10396.93 61.67 107.78 5,331.67 3,271.33 N 7,130.95 E -5005.48 3.47 10491.27 60.92 110.92 5,376.99 3,243.92 N 7,209.01 E -4999.22 3.03 10586.26 59.69 113.68 5,424.06 3,212.63 N 7,285.35 E -4988.74 2.84 10681.17 59.36 116.26 5,472.20 3,178.11 N 7,359.49 E -4974.59 2.37 10775.96 59.93 118.30 5,520.10 3,140.62 N 7,432.18 E -4957.19 1.95 10871.21 61.11 120.90 5,566.98 3,099.65 N 7,504.26 E -4936.28 2.68 10965.55 61.35 123.80 5,612.40 3,055.41 N 7,574.11 E -4911.62 2.71 11061.46 61.93 126.60 5,657.96 3,006.76 N 7,643.06 E -4882.48 2.64 11155.13 62.85 129.95 5,701.38 2,955.35 N 7,708.20 E -4849.68 3.32 INSITE V8.3.0 Page 3Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11249.55 63.36 134.05 5,744.11 2,899.02 N 7,770.76 E -4811.45 3.91 11344.07 63.66 138.26 5,786.28 2,838.02 N 7,829.34 E -4767.70 4.00 11438.26 64.24 142.75 5,827.66 2,772.74 N 7,883.13 E -4718.56 4.33 11533.86 65.06 145.99 5,868.60 2,702.53 N 7,933.44 E -4663.76 3.18 11627.70 66.20 148.62 5,907.33 2,630.60 N 7,979.60 E -4606.23 2.83 11722.74 67.38 152.17 5,944.79 2,554.66 N 8,022.73 E -4544.05 3.65 11817.37 68.46 155.10 5,980.37 2,476.10 N 8,061.66 E -4478.24 3.09 11912.31 69.09 156.58 6,014.74 2,395.36 N 8,097.88 E -4409.62 1.60 12006.26 68.86 157.71 6,048.45 2,314.55 N 8,131.94 E -4340.38 1.15 12101.29 69.65 160.48 6,082.12 2,231.54 N 8,163.64 E -4268.40 2.85 12195.51 71.59 162.74 6,113.39 2,147.20 N 8,191.67 E -4194.20 3.06 12290.59 74.03 165.57 6,141.49 2,059.84 N 8,216.45 E -4116.22 3.83 12385.39 76.48 168.31 6,165.62 1,970.54 N 8,237.15 E -4035.33 3.81 12480.60 77.85 172.31 6,186.78 1,879.06 N 8,252.76 E -3951.00 4.34 12512.12 77.98 173.39 6,193.38 1,848.48 N 8,256.60 E -3922.45 3.38 12571.05 78.19 173.00 6,205.54 1,791.22 N 8,263.43 E -3868.92 0.74 12666.66 77.71 171.93 6,225.50 1,698.53 N 8,275.69 E -3782.55 1.20 12761.77 75.73 175.05 6,247.36 1,606.58 N 8,286.20 E -3696.45 3.81 12856.21 75.08 178.87 6,271.16 1,515.33 N 8,291.05 E -3609.57 3.97 12951.13 76.01 180.41 6,294.86 1,423.42 N 8,291.62 E -3520.95 1.85 13046.58 80.30 180.44 6,314.44 1,330.03 N 8,290.93 E -3430.56 4.49 13141.51 84.36 180.84 6,327.11 1,235.97 N 8,289.88 E -3339.43 4.30 13235.84 85.84 184.45 6,335.17 1,142.11 N 8,285.54 E -3247.64 4.12 13330.83 83.91 188.74 6,343.66 1,048.15 N 8,274.68 E -3154.08 4.94 13425.88 84.91 191.53 6,352.92 955.04 N 8,258.03 E -3059.83 3.10 13520.68 87.05 193.91 6,359.57 862.81 N 8,237.21 E -2965.35 3.37 13615.59 90.65 197.02 6,361.47 771.38 N 8,211.91 E -2870.49 5.01 13710.65 91.85 198.34 6,359.40 680.83 N 8,183.05 E -2775.56 1.88 13805.18 90.79 197.61 6,357.22 590.94 N 8,153.89 E -2681.18 1.36 13899.61 89.69 196.12 6,356.83 500.58 N 8,126.50 E -2586.81 1.96 13994.80 89.93 193.71 6,357.14 408.60 N 8,102.00 E -2491.63 2.54 14090.52 89.83 191.55 6,357.34 315.20 N 8,081.07 E -2395.99 2.26 14184.83 89.97 192.48 6,357.51 222.96 N 8,061.44 E -2301.81 1.00 14279.75 89.31 195.29 6,358.10 130.83 N 8,038.66 E -2206.92 3.04 14375.49 90.62 196.00 6,358.16 38.64 N 8,012.84 E -2111.19 1.56 14470.24 89.31 196.87 6,358.22 52.24 S 7,986.04 E -2016.47 1.66 14564.84 89.38 199.27 6,359.30 142.16 S 7,956.70 E -1922.02 2.54 14660.05 88.76 199.89 6,360.85 231.85 S 7,924.80 E -1827.13 0.92 14754.87 87.08 198.81 6,364.29 321.25 S 7,893.40 E -1732.65 2.11 14849.61 86.53 197.39 6,369.57 411.16 S 7,864.01 E -1638.20 1.61 14944.83 86.67 195.24 6,375.22 502.38 S 7,837.31 E -1543.18 2.26 15039.60 88.32 194.46 6,379.36 593.90 S 7,813.05 E -1448.50 1.93 15134.33 89.83 193.46 6,380.89 685.81 S 7,790.20 E -1353.80 1.91 15229.11 90.24 191.03 6,380.83 778.43 S 7,770.10 E -1259.14 2.60 15323.97 90.75 190.30 6,380.01 871.65 S 7,752.54 E -1164.56 0.94 INSITE V8.3.0 Page 4Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 15419.11 90.34 189.99 6,379.10 965.29 S 7,735.79 E -1069.76 0.54 15514.10 89.66 188.77 6,379.10 1,059.01 S 7,720.31 E -975.23 1.47 15608.75 89.62 187.34 6,379.70 1,152.72 S 7,707.04 E -881.28 1.51 15703.73 89.83 186.98 6,380.16 1,246.96 S 7,695.21 E -787.19 0.44 15798.16 89.66 187.85 6,380.58 1,340.60 S 7,683.02 E -693.59 0.94 15893.10 90.38 188.58 6,380.54 1,434.56 S 7,669.45 E -599.31 1.08 15988.09 91.65 188.26 6,378.86 1,528.51 S 7,655.55 E -504.97 1.38 16082.54 87.87 188.72 6,379.26 1,621.91 S 7,641.61 E -411.14 4.03 16177.90 90.00 189.15 6,381.03 1,716.09 S 7,626.80 E -316.34 2.28 16272.59 91.03 188.54 6,380.18 1,809.65 S 7,612.24 E -222.20 1.26 16366.15 91.51 188.28 6,378.10 1,902.18 S 7,598.56 E -129.28 0.58 16461.60 92.13 187.60 6,375.07 1,996.67 S 7,585.38 E -34.61 0.96 16557.27 91.68 185.42 6,371.89 2,091.66 S 7,574.54 E 59.96 2.33 16651.13 91.41 184.25 6,369.36 2,185.15 S 7,566.63 E 152.31 1.28 16747.05 89.90 185.30 6,368.26 2,280.73 S 7,558.65 E 246.70 1.92 16841.74 89.73 187.01 6,368.57 2,374.87 S 7,548.50 E 340.26 1.81 16936.78 89.28 185.93 6,369.39 2,469.30 S 7,537.79 E 434.24 1.23 17031.64 89.38 185.95 6,370.50 2,563.64 S 7,527.97 E 527.91 0.11 17126.71 89.04 186.76 6,371.81 2,658.12 S 7,517.45 E 621.89 0.92 17222.19 88.63 188.47 6,373.75 2,752.73 S 7,504.80 E 716.55 1.84 17314.68 88.94 189.65 6,375.71 2,844.05 S 7,490.24 E 808.53 1.32 17410.75 89.62 189.82 6,376.92 2,938.73 S 7,474.00 E 904.18 0.73 17503.96 90.38 190.23 6,376.92 3,030.51 S 7,457.77 E 997.04 0.93 17598.29 89.31 192.78 6,377.18 3,122.94 S 7,438.96 E 1091.19 2.93 17693.31 86.74 195.97 6,380.45 3,214.91 S 7,415.39 E 1186.12 4.31 17788.13 87.77 198.61 6,384.99 3,305.33 S 7,387.24 E 1280.75 2.99 17882.58 89.42 200.17 6,387.31 3,394.39 S 7,355.90 E 1374.89 2.40 17976.99 89.93 202.19 6,387.85 3,482.42 S 7,321.79 E 1468.74 2.21 18071.59 89.24 205.30 6,388.53 3,568.99 S 7,283.70 E 1562.23 3.37 18165.44 89.76 204.29 6,389.35 3,654.19 S 7,244.35 E 1654.70 1.21 18259.21 88.94 203.55 6,390.41 3,739.90 S 7,206.33 E 1747.33 1.18 18354.25 89.07 201.84 6,392.06 3,827.56 S 7,169.67 E 1841.50 1.80 18447.45 89.14 202.86 6,393.52 3,913.75 S 7,134.23 E 1933.92 1.10 18542.74 90.14 202.72 6,394.12 4,001.60 S 7,097.32 E 2028.33 1.06 18636.44 91.61 202.25 6,392.69 4,088.16 S 7,061.49 E 2121.22 1.65 18728.40 90.75 204.58 6,390.79 4,172.52 S 7,024.96 E 2212.16 2.70 18825.93 89.93 206.34 6,390.21 4,260.58 S 6,983.04 E 2308.06 1.99 18918.30 89.55 204.92 6,390.63 4,343.86 S 6,943.08 E 2398.84 1.59 19015.14 88.90 204.39 6,391.94 4,431.86 S 6,902.69 E 2494.30 0.87 19109.60 90.14 203.52 6,392.74 4,518.18 S 6,864.34 E 2587.61 1.60 19204.42 89.00 202.30 6,393.45 4,605.51 S 6,827.43 E 2681.52 1.76 19299.09 89.79 198.99 6,394.45 4,694.08 S 6,794.06 E 2775.71 3.59 19393.18 90.14 197.76 6,394.50 4,783.37 S 6,764.40 E 2869.63 1.36 19487.30 89.55 198.04 6,394.76 4,872.94 S 6,735.47 E 2963.63 0.69 19581.42 89.42 199.41 6,395.60 4,962.07 S 6,705.26 E 3057.55 1.46 INSITE V8.3.0 Page 5Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 19676.95 89.97 199.52 6,396.11 5,052.14 S 6,673.42 E 3152.79 0.59 19771.08 88.90 198.96 6,397.04 5,141.01 S 6,642.41 E 3246.65 1.28 19864.90 89.04 199.01 6,398.73 5,229.71 S 6,611.89 E 3340.23 0.16 19957.69 89.83 197.43 6,399.64 5,317.84 S 6,582.88 E 3432.87 1.90 20050.98 90.17 196.96 6,399.64 5,406.96 S 6,555.30 E 3526.09 0.62 20146.66 90.55 193.48 6,399.04 5,499.27 S 6,530.19 E 3621.75 3.66 20241.72 89.35 190.18 6,399.13 5,592.29 S 6,510.70 E 3716.65 3.69 20337.65 89.31 188.90 6,400.25 5,686.89 S 6,494.81 E 3812.14 1.33 20432.45 89.31 190.82 6,401.39 5,780.28 S 6,478.57 E 3906.54 2.03 20524.96 88.35 192.85 6,403.28 5,870.79 S 6,459.61 E 3998.89 2.43 20618.45 88.66 194.20 6,405.72 5,961.66 S 6,437.75 E 4092.31 1.48 20714.89 89.93 196.31 6,406.90 6,054.69 S 6,412.38 E 4188.74 2.55 20808.44 90.69 196.39 6,406.40 6,144.45 S 6,386.05 E 4282.26 0.82 20903.54 89.59 196.84 6,406.17 6,235.58 S 6,358.85 E 4377.32 1.25 20998.04 86.26 198.58 6,409.59 6,325.53 S 6,330.13 E 4471.63 3.98 21091.86 84.99 195.37 6,416.75 6,414.98 S 6,302.82 E 4565.11 3.67 21186.78 86.95 192.66 6,423.42 6,506.84 S 6,279.90 E 4659.77 3.52 21281.54 86.63 190.56 6,428.72 6,599.51 S 6,260.86 E 4754.21 2.24 21375.71 88.46 189.80 6,432.76 6,692.10 S 6,244.23 E 4847.95 2.10 21469.44 89.42 188.13 6,434.49 6,784.67 S 6,229.63 E 4941.14 2.05 21720.00 88.57 188.13 6,438.89 7,032.67 S 6,194.20 E 5189.86 0.34 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 195.00 degrees (True) - A total correction of 18.28 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 21,720.00 feet is 9,371.58 feet along 138.63 degrees (True) INSITE V8.3.0 Page 6Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 7Job No:AK-XX-0903000543 Well Name:2S-01 Survey Report
