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216-167
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En U 0 U U U U U ai .o m N cewc U a E a U amu 1 O I. 0 aoo oom < a) p 0 0 p p p o d 2 a) 0 To E o a. 2w w w w wJ Z 0 a 0 0 0 C c) c.) RECEIVED • STATE OF ALASKA • MAR 0 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AIV' c 1a.Well Status: Oil E ' Gas SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 ' Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or I"" 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/8/2017 Z/71/1 216-167/ • 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 1/25/2017 50-103-20675-60-00 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 5182'FNL,4722'FEL,Sec 1,T11N, R8E, UM 1/31/2017 KRU 2T-41L1 • Top of Productive Interval: 9.Ref Elevations: KB:103.8 17. Field/Pool(s): 1133'FNL, 1962'FEL,Sec 11,T11N,R8E,UM GL:76.3 BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3704'FNL, 1815'FEL,Sec 11,T11N,R8E, UM N/A ADL 25569 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 498947 y- 5970077 Zone- 4 11357/5928 ALK 2560 TPI: x- 496428 y- 5968848 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 496576 y- 5966277 Zone- 4 N/A 1583/1450 5.Directional or Inclination Survey: Yes 2 (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 -WA- 75 ZS'/5q D-1 / 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 65 H-40 27 133 27 133 16 Pre-installed 10 3/4 45.5 L-80 28 3197 28 2580 13 1/2 1596 sx Class G, 194 sx Class G 7 5/8 29.7 L-80 26 7222 26 5685 9 7/8 276 sx Class G,158 sx Class G, 82 sx Class G 82 sx Claaa G 2 3/8 4.6 L-80 9176 11357 5926 5928 3 Liner 24.Open to production or injection? Yes E 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): 4.5"x3.5" 7479 6892'MD/5432'ND, 6992'MD/5509'ND and SLOTTED LINER @ 9188-9663 MD and 5926-5923 ND 7472"MD/5869'ND SLOTTED LINER @ 9664-11357 MD and 5923-5928 ND 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. •.::.i 1`11,1_t.'l lON Was hydraulic fracturing used during completion? Yes❑ No 0 r;A0 f' Per 20 AAC 25.283(i)(2)attach electronic and printed information aL DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED /0!-RiF1' :0L LL- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/16/2017 FLOWING Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/17/2017 18 Test Period -O. 169.5 81 1080 124 479 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 233 1375 24-Hour Rate 226 108 1439 N/A 1 �Form 10-407 Revised 11/2015 IT1, 3/ l QS' ji-7. CONTINUED ON PAGE 2 w MAR 1 20 7 Submit ORIGINIAL on i3/ .c /6'2 - "of RBDMS I • • 28.CORE DATA Conventional Core(s): Yes ❑ No 111 Sidewall Cores: Yes ❑ No 2 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 ND Well tested? Yes ❑ No ❑Q Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1583 1450 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval 7525 5907 information,including reports,per 20 AAC 25.071. Kuparuk A TD 11357 5927 Formation at total depth: Kuparuk A 31. List of Attachments: Daily Operations Summary,Definitive Survey,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical reoort.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan . -.3-4180 Email: Mike.Callahan(ilcop.com Printed Name: K.S arc \-C Title: CTD Director Signature: \ ` ��-� \� Phone: 263-4093 Date: INSTRUCTIONS General: This form -., 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 1a: 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 ND 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 • • 2T-41 Final Schematic � . 3-1/2" Camco DS nipple @ 413' RKB(2.875"min ID) 16"65#H-40 shoe @ 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 134' MD {` 3-1/2"Camco gas lift mandrel @ 3196', 4913', 5802', 6418', 6785' RKB 10-3/4"45.5#L-80 3-1/2" HES X nipple @ 6844' RKB(2.812"min ID) shoe @ 3197' MD Baker 80-40 Seal Assembly @ 6862' MD(3"ID) Baker 80-40 PBR @ 6867' MD(3" ID) Baker Premier Packer @ 6892' MD(2.87" ID) 1111 ZXP Liner Top Packer @ 6993' MD(4.93" ID) j RA Marker in 5-1/2" Liner @ 7244 7-5/8"29.7#L-80 shoe ' 7222MD "� @ ''�"i� '� Blast Rings @ 7354' RKB(on P-110 with 50'of rings) d — -- 3-1/2"CMU Sliding Sleeve @ 7457' RKB(2.813' ID) C-sand perfs 7368' _ j - KBH-22 Anchor Seal Assembly @ 7472' MD -7408' MD Baker FA-1 Packer @ 7472' MD 3-1/2" HES D nipple @ 7477' RKB(2.75"min ID) KOP@7525' MD A-sand perfs 7490' 2T-41L1-01 wp01 -7550' MD t — TD @ 11,353' MD 5-1/2" 17#P-110 shoe @ 7947'MD 2T-41L1 wp05 TD @ 11,357' MD —.000111 Billet at 9173' MD Ilk KUP P OD 2T-41L1 ConocoPhillips ImoWell AttribMax Any D TD Inc,AlaskaWellbore APUUWI Field Name Wellbore Statusncl(°) MD(ftKB) Act Btm(ftKB) coroco'Hnpips if 501032067560 KUPARUK RIVER UNIT PROD 1 95.93 9,001.31 11,357.0 V ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2T-41L1,3/7/201711:20:58 AM SSSV.NIPPLE 65 12/5/2016 Last WO: 27.50 11/28/2013 Variwy,ePharnatc(aatwD Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason:SIDETRACT,H2S&GLV C/O pproven 3/6/2017 HANGER:23,4—. :31i1)',111:1. Iii _ Casing Strings Casing Description OD(in) I ID(in) I Top(ftKB) 'Set Depth(ftKB) I Set Depth(TVD)...IWt/Len(I...I Grade I Top Thread ,«„„„ Liner,AL)Lateral 2 3/8 1.992 9,176.211 11,357 0 4.601L-80 STL Liner Details lr H a Nominal ID Top(568) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) 9,176.2 5,926.3 90.80 Open Hole Open Hole Anchored Aluminum Billet 1.920 Anchored Aluminum Billet CONDUCTOR;27.5-133.5 9,663.1 5,923.4 90.11 Deployment Shorty Deployment Sleeve 1.920 IIIE Sleeve NIPPLE;413.4 .Me Bit Stimulations&Treatments Proppant Designed(lb) Propped In Formation(lb) Date 12/12/2013 Proppant Designed(Ib) Proppant In Formation(lb) Date I'.: I.I 9/3/2014 • Proppant Designed(Ib) Proppant In Formation(Ib) Date 58,700.0 47,500.0 1/10/2016 Notes:General&Safety mil End Date I Annotation GAS LIFT;3,192.0 17 Note SURFACE,28.5-3,198.9--.. ,..i..1:1:' ..:..;::1!„).. GAS LIFT,4,9129 GAS LIFT,5802` GAS LIFT.6.418 2 GAS LIFT;6,785.2 NIPPLE;8,844.2 SEAL ASSY;6,882.2, PBR;6,867.2 �'iar XO Thread;6,800.6 PACKER,6,892,4 XO Thread;6,899.0 iliii I 6 -1I 1 f INTERMEDIATE,25.6-7,222.2—, Radioactive Marker;7,244.3 IPERF;7,368.0-7,388.0 BLAST RING;7,353.9 Hydraulic Fracture'7,368.0 I I I ■ IPERF;7,3880-7,408.0 BE Mb XO Thr ad;7,455.4 IR SLEEVE-0;7,457.4 11=11 int SEAL ASSY;7,471.8 I PACKER;7,4720 —,,. NIPPLE;7,476.8, i° WLEG;7,478.1` 1..EM (PERF;7,490.0-7,510.0 FRAC;7,490.01 � 1 HPBD;7,490.0 i IPERF;7,510.0-7,530.0 WHIPSTOCK-MONOBORE; 7,525.0 , IPERF;7,530.0-7,550.0 1— LINER;6,992.5-7,946.5- Liner,A1l-01 Lateral;7,471.6 11,353.0\ Liner,AL1 Labral;8,178.2- I 11,357.0-• J • 0;!, Operations Summary (with Timeloggpths) )2 2T-41 Con000Phitiips ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/20/2017 1/20/2017 9.00 MIRU MOVE DMOB P Jack up tool house,jack up sub and 09:00 18:00 1/20/2017ce. 8: 00:001/21/2017 6.00 MIRU MOVE DMOB P trucks.Move CDR3 from 3H pad to 2T et sub and service hooked to moving 18:00 00:00 pad 1/21/2017 1/21/2017 2.50 MIRU MOVE MOB P Sub spotted 0.0 0.0 00:00 02:30 0.0 0.0 1/21/2017 1/21/2017 1.50 MIRU MOVE MOB P Pits spotted 02:30 04:00 0.0 0.0 1/21/2017 1/21/2017 5.25 MIRU MOVE RURD P Rigging up COMMS established,erc,& PUT&haZdlines 04:00 09:15 rigged up.Tool house spotted. 1/21/2017 1/21/2017 2.74 MIRU MOVE RURD P cellar. Attempt Attempt replace lltoace SSV a dpop-off stall 0.0 0.0 09:15 11:59 correct 90 degree flange for MP line. Unable to locate 90 degree flange adapter in Nabors conex.Plan to locate proper equipment in Deadhorse while rigging up. 1/21/2017 1/21/2017 4.50 MIRU WHDBOP NUND P NU BOPE.. ser,get heckRKB'tree boltsfor BOPE,Change 0.0 0.0 11:59 16:29 out test **Accept Rig at 16:30 1/21/2017 1/21/2017 2.00 MIRU WHDBOP RURD P Grease and R valves. Change choke anifoutMP line old,MM 0.0 0.0 16:29 18:29 adaptor,can not get XO'd 4 1/16". Start working options. PJSM. 1/21/2017 1/21/2017 0.30 MIRU WHDBOP RURD P Test E-line 0.0 0.0 18:29 18:47 1/21/2017 1/21/2017 0.30 MIRU WHDBOP RURD P Stab on w nozzle and fluid pack coil 0.0 0.0 18:47 19:05 0.0 0.0 1/21/2017 1/21/2017 3.00 MIRU WHDBOP RURD P Fluid pack coil 19:05 22:05 1/21/2017 1/22/2017 1.92 MIRU WHDBOP BOPE P Test B 00 4,200r preventor. high/250 psi 0.0 0.0 22:05 00:00 *Witness waived by AOGCC Inspector,Guy Cook. 1/22/2017 1/22/2017 5.50 MIRU WHDBOP BOPE P low/2,500t ,4,200nular pre high/250 psi psi 0.0 0.0 00:00 05:30 *Witness waived by AOGCC Inspector,Guy Cook. 1/22/2017 1/22/2017 0.50 MIRU WHDBOP BOPE P Pressure test TT line 0.0 0.0 05:30 06:00 0.0 0.0 1/22/2017 1/22/2017 3.00 MIRU WHDBOP MPSP P PJSM,pull BPV. 06:00. 09:00 1/22/2017 1/22/2017 1.50 MIRU WHDBOP PRTS P blow downt ,Blowbleed off dowln bhokes and A d B, 0.0 0.0 09:00 10:30 and well control choke.Prep floor to PU WS.Pre-Spud,PJSM 1/22/2017 1/22/2017 2.25 SLOT RPEQPT PULD P PU and PD 3-1/2"x 5-1/2"TT WS. 0.0 75.0 10:30 12:45 1/22/2017 1/22/2017 3.20 SLOT RPEQPT TRIP P RIH with WS toiont e depth,ht checo,K1 75.0 7,436.0 12:45 15:57 for aPUW=3K. 1/22/2017 1/22/2017 0.20 SLOT RPEQPT TRIP T Nipple.Attempted Dat 2.750"90, 180,and- 7,436.0 7,490.0 270 15:57 16:09 TF with no success drifting WS through D niple. 1/22/2017 1/22/2017 2.10 SLOT RPEQPT DISP T POH,circ well over to milling fluid. 7,490.0 7,450.0 16:09 18:15 Page 1/20 Report Printed: 2/13/2017 • • Operations Summary (with Timelog Depths) r ° 2T-41 ConocoPhi€lips ,' �l:xka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/22/2017 1/22/2017 1.80 SLOT RPEQPT TRIP T POOH with,BHA#1. 7,450.0 75.0 18:15 20:03 1/22/2017 1/22/2017 0.30 SLOT RPEQPT TRIP T PJSM,Flow check,failed. 75.0 75.0 20:03 20:21 1/22/2017 1/22/2017 1.00 SLOT RPEQPT PULD T Tag up,space out,PUD. 75.0 0.0 20:21 21:21 1/22/2017 1/22/2017 0.70 SLOT RPEQPT PULD T LD BHA#1,whipstock and running 0.0 0.0 21:21 22:03 equip. 1/22/2017 1/22/2017 1.00 SLOT RPEQPT PULD T Inspect failed tools,call and confer w 0.0 0.0 22:03 23:03 town support.Found whipstock would not drift a 2.750 No Go ring. No Go would not pass connecting lug on rod that connects to anchors. Anchors had sheared. Additionally a small piece of what appears to be S/L shear stock,steel,from a running tool found wedged in whipstock. 1/22/2017 1/23/2017 0.95 SLOT RPEQPT WAIT T wait on nnew wihpstock from 0.0 0.0 23:03 00:00 deadhorse 1/23/2017 1/23/2017 1.10 SLOT RPEQPT WAIT T wait on new wihpstock from 0.0 0.0 00:00 01:06 deadhorse 1/23/2017 1/23/2017 1.10 SLOT RPEQPT PULD T Examine new wipstock,smallest no go 0.0 0.0 01:06 02:12 ring 2.71"pased WS to 8"up,from bottom of seting tool. 2.72"GR passed entire whipstock and setting tool. 1/23/2017 1/23/2017 1.80 SLOT RPEQPT PULD T PJSM,pu BHA#2 whipstock and 0.0 75.0 02:12 04:00 setting tools, PD same. 1/23/2017 1/23/2017 1.50 SLOT RPEQPT TRIP T RIH 75.0 7,250.0 04:00 05:30 1/23/2017 1/23/2017 1.00 SLOT RPEQPT DLOG T Tie into K1 and RA tag for-10' 7,250.0 7,491.0 05:30 06:30 correction. Wt check,close EDC,zero WOB 1/23/2017 1/23/2017 0.25 SLOT RPEQPT TRIP T Continue to RIH at 80 degrees ROHS 7,491.0 7,491.0 06:30 06:45 to D-Nipple.Set down 5K WOB at 7490'MD,PUH and orient to 270 degrees,set down again at 7491'MD with 4.5K WOB.Confer with town and decision made to POOH to LD BHA #2. 1/23/2017 1/23/2017 2.50 SLOT RPEQPT TRIP T POOH to LD BHA#2,tag up,flow 7,491.0 63.0 06:45 09:15 check well,pass. 1/23/2017 1/23/2017 0.75'SLOT RPEQPT PULD T PJSM,LD BHA#2 over a dead well. 63.0 0.0 09:15 10:00 1/23/2017 1/23/2017 1.00 SLOT RPEQPT PULD T PJSM,PU Cleanout Run Assembly 0.0 63.0 10:00 11:00 BHA#3(2-1/8"straight motor,2.74" window mill,and 2.74"string reamer). 1/23/2017 1/23/2017 2.00 SLOT RPEQPT TRIP T RIH,tie into K1 &RA tag for-11' 63.0 7,452.0 11:00 13:00 correction,tag D-Nipple at 7490'MD with 7K WOB,PUW=36K,PUH to 7453'and begin circulating bottoms up. 1/23/2017 1/23/2017 0.40 SLOT RPEQPT CIRC T Circulate bottoms up at 1.75 bpm.A 7,452.0 7,403.0 13:00 13:24 bit of frac sand over shaker,not excessive. 1/23/2017 1/23/2017 0.85 SLOT RPEQPT MILL T RIH through WS seting interval,see 7,403.0 7,554.0 13:24 14:15 very little motor work,begin taking losses. Page 2/20 Report Printed: 2/13/2017 • 0 Operations Summary (with Timelog epths) 2T-41 01 Onkra cc:PhiilpS ; Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/23/2017 1/23/2017 0.25 SLOT RPEQPT MILL T Ream up,pumped 20 bbl 100K LSRV 7,554.0 7,540.0 14:15 14:30 pill 1/23/2017 1/23/2017 0.50 SLOT RPEQPT MILL T Ream down 7,540.0 7,470.0 14:30 15:00 1/23/2017 1/23/2017 0.75 SLOT RPEQPT MILL T Ream up to stalls&dow down, seeing Dmotor work 7,470.0 7,470.0 15:00 15:45 1/23/2017 1/23/2017 4.25 SLOT RPEQPT CIRC T Drift below 7478'at low rate.Confer 7,510.0 7,535.0 with town.Decision made to circulate 15:45 20:00 3 bottoms up staying below 7510'MD. Pumped another 20 bbl 100K LSRV pill.Pumping additional 10 bbl hi-vis pills for each bottoms up. Losses improved to-.4 bpm 1/23/2017 1/23/2017 0.15 SLOT RPEQPT DLOG T nipple area isb bottoms n p to t 3 see bphat 5.2 7,535.0 7,468.0 20:00 20:09 fpm through nipple. 1/23/2017 1/23/2017 0.15 SLOT RPEQPT TRIP T RBIH depth oadrift 3 bpml down to WS set 7,468.0 7,488.0 20:09 20:18 lean 1/23/2017 1/23/2017 0.15 SLOT RPEQPT TRIP T PUH to 7468'MD,PUW=35K,Clean. 7,488.0 7,468.0 20:18 20:27 1/23/2017 1/23/2017 0.14 SLOT RPEQPT TRIP T RBIH with pumps off.Clean 7,468.0 7,488.0 20:27 20:35 1/23/2017 1/23/2017 0.35 SLOT RPEQPT TRIP T 6K to tie into K1 &RA tag.PUW= 7,488.0 7,250.0 20:35 20:56 1/23/2017 1/23/2017 0.12 SLOT RPEQPT DLOG T RBIH,tie into K1 for a+2'correction. 7,250.0 7,282.0 20:56 21:03 1/23/2017 1/23/2017 0.20 SLOT RPEQPT DLOG T PUH 7,282.0 6,686.0 21:03 21:15 1/23/2017 1/23/2017 0.75 SLOT RPEQPT DLOG T Log CCL,clean through nipple interval 6,686.0 7,540.0 21:15 22:00 1/23/2017 1/24/2017 2.00 SLOT RPEQPT TRIP T POOH,to LD BHA#3,PUW=35K 7,550.0 265.0 22:00 00:00 265.0 75.0 1/24/2017 1/24/2017 0.50 SLOT RPEQPT TRIP T POOH, 00:00 00:30 1/24/2017 1/24/2017 0.50 SLOT RPEQPT OWFF T Observe well for flow,countinued flow, 7,550.0 75.0 00:30 01:00 S/I and wellhead built to 62 psi. 1/24/2017 1/24/2017 2.00 SLOT RPEQPT PULD T PJSM,PUD BHA#3,2.74"milling 75.0 0.0 01:00 03:00 assembly. Observed flow after un stabbing,Stab back on,shut EDC, blow down,flow check,good,un stab, continue PUD,LD BHA. **window mill no go 2.72",string reamer no go less than 2.71"smallest no go on location. 1/24/2017 1/24/2017 1.70 SLOT RPEQPT PULD T PJSM,junk UHA t &Ppwhipstock drift/EDopen 0.0 83.0 03:00 04:42 1/24/2017 1/24/2017 1.40 SLOT RPEQPT TRIP T RIFT Wer BHA#4,stotaking downsize visflutoid over 83.0 6,800.0 04:42 06:06 shathe end.contin to RIH. 1/24/2017 1/24/2017 0.80 SLOT RPEQPT CTOP T Close EDC, Wit Ck o31.53s,3 p mn1.10 6,800 .0 6,900.0 06:06 06:54 bppast X nipple @ 6850',2 passes 1/24/2017 1/24/2017 0.20 SLOT RPEQPT TRIP 'T Continue to RIH, 6,900.0 7,280.0 06:54 07:06 1/24/2017 1/24/2017 0.20 SLOT RPEQPT DLOG T Tie into K1 for 7.5' correction 7,280.0 7,310.0 07:06 07:18 Page 3/20 Report Printed: 2/13/2017 0 • 0 Operations Summary (with Timelog Depths) 21-41 ConocoPhitlips A,t.'vk.a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (7 3)1 O.Q End Depth 7,400.0 1/24/2017 1/24/2017 0.10 SLOT RPEQPT TRIP T Continue to RIH, 07:18 07:24 1/24/2017 1/24/2017 0.80 SLOT RPEQPT CTOP T Wt Ck 36 k lbs, 7,400.0 7,540.0 07:24 08:12venturi passes,7400-7500 X 2 venturi passes,7515-7555 X 2 Dry drift 7480'-7540'-clean • 1/24/2017 1/24/2017 0.80 SLOT RPEQPT TRIP T Open EDC,POOH 7,540.0 72.0 08:12 09:00 1/24/2017 1/24/2017 3.00 SLOT RPEQPT PULD T Flow check-failed,PJSM,PUD BHA 72.0 0.0 09:00 12:00 #4,Observed flow after un stabbing. Stab back on,close EDC,blow down, flow check. Good,un stab.continue to PUD,LD BHA. 1/24/2017 1/24/2017 1.90 PROD1 RPEQPT PULD T PU BHA#5 3.5 x 5.5"whipstock, 0.0 74.0 12:00 13:54 PJSM,PD BHA#5. Open EDC 1/24/2017 1/24/2017 1.80 PROD1 RPEQPT TRIP T RIH w BHA#5. 74.0 7,280.0 13:54 15:42 1/24/2017 1/24/2017 0.10 PROD1 RPEQPT DLOG T Tie into K1 for-10.5'correction,Wt 7,280.0 7,310.0 15:42 15:48 Ck,40k lbs 1/24/2017 1/24/2017 0.10 PROD1 RPEQPT TRIP P Continue to RIH 7,310.0 7,538.0 15:48 15:54 1/24/2017 1/24/2017 0.20 PROD1 RPEQPT WPST P Stop at 7538,pick up to neutral 7,538.0 7,538.0 15:54 16:06 weight,down on pumps,oriented high side,close EDC,Circ pressure broke back at 2900 psi. SD 3.8 k lbs, whipstock set. PU Wt 41 k lbs.EDC open. 1/24/2017 1/24/2017 1.80 PROD1 RPEQPT TRIP P POOH 7,538.0 0.0 16:06 17:54 1/24/2017 1/24/2017 2.00 PROD1 RPEQPT PULD P At surfa e,tbump up,space PJSM,ot, 72.0 0.0 17:54 19:54 haPUD and LD BHA#5 1/24/2017 1/24/2017 1.30 PROD1 WHPST PULD P PU 2.74"diamond mill.2.74"string 0.0 62.7 19:54 21:12 reamer,Baker 2-1/8"motor. MU BHA #6 and pressure deploy. 1/24/2017 1/24/2017 1.40 PROD1 WHPST TRIP P Trip in wl window milling BHA#6, 62.7 7,265.0 21:12 22:36 EDC open,pumping min rate 1/24/2017 1/24/2017 0.30 PROD1 WHPST DLOG P Tie in to K1,-12 ft correction 7,265.0 7,285.0 22:36 22:54 1/24/2017 1/24/2017 0.20 PROD1 WHPST TRIP P Trip in,slow down to 3 FPM w/12K 7,285.0 7,530.0 22:54 23:06 RIW to dry tag TOWS at 7530 ft,set down w/2.5K WOB. Pick-up 10 ft, PUW=39K,bring pumps to 1.78 bpm, 4070 psi CT,578 psi off bottom diff, lateral XY vibration upto 5(red),with no WOB. 1/24/2017 1/25/2017 0.90 PROD1 WHPST WPST P 7530.3',set to auto drill, 1.78 bpm, 7,530.0 7,531.0 23:06 00:00 4400 psi CT,760 psi on bottom diff w/ 1.45K WOB,loss rate at 0.4 bpm(- 30 bph). 1/25/2017 1/25/2017 3.80 PROD1 WHPST -WPST P Continue time milling window,lower 7,531.0 7,534.1 00:00 03:48 pump rate while on-bottom to reduce vibration to acceptable value,1.5 bpm, 3816 psi CT,780 psi on-bottom diff, target 2.0 to 2.5K WOB. Stalled,PUW 36K,off-bottom parameters; 1.5 bpm, 3476 psi CT,35 psi WH,449 psi diff, OK WOB 1/25/2017 1/25/2017 2.40 PROD1 WHPST WPST P Continue milling window 7,534.1 7,535.4 03:48 06:12 Page 4/20 Report Printed: 2/13/2017 • • 0 es' Operations Summary (with Timelog Depths) __________ 2T-41 CortocoP'hillips kL k� Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/25/2017 1/25/2017 1.10 PROD1 WHPST WPST P Exit window,drilling ahead 7,534.1 7,550.0 06:12 07:18 1/25/2017 1/25/2017 2.00 PROD1 WHPST REAM P TD,Ree rng omp g reduasses ced rateings s 1.3 7,550.0 7,526.0 07:18 09:18 bpm,3's and 4's now,then dry drift 25 ft/min set down once,stacked 8k lbs then popped through on first trip down, all passes up were clean,next two passes down wer clean,open EDC, pump a 5x5 sweeps. 1/25/2017 1/25/2017 2.00 PROD1 WHPST TRIP P POOH 7,526.0 50.0 09:18 11:18 1/25/2017 1/25/2017 2.00 PROD1 WHPST PULD P Tag up,PJSM,PUD&LD BHA#6 50.0 0.0 11:18 13:18 1/25/2017 1/25/2017 2.00 PROD1 DRILL PULD P PJSM,PU&PD BHA#7,L1 lat build 0.0 72.0 13:18 15:18 drilling assembly. 1/25/2017 1/25/2017 1.50 PROD1 DRILL TRIP P RIH W BHA#7 72.0 7,220.0 15:18 16:48 1/25/2017 1/25/2017 0.20 PROD1 DRILL DLOG P Tie into ed EDC, 1 for Wt r a 36k lbs tion, 7,220.0 7,290.0 16:48 17:00 1/25/2017 1/25/2017 1.00 PROD1 DRILL TRIP P Continue to RIH,tag TD 7550',PU 7,290.0 7,600.0 17:00 18:00 establish initial rate at 1.5 bpm,***new mud at bit at 7576'@ 18:30 hrs. Increase pump rate to 1.77 bpm,4143 psi CT,500 psi off bottom diff, 12K CTW. 1/25/2017 1/25/2017 2.80 PROD1 DRILL DRLG P Drill build section,1.77 bpm,4383 psi 7,600.0 7,665.0 18:00 20:48 CT,700 psi off bottom diff, 10K CTW, difficulty at 7622'getting a bite,PU and sitdown several times to get a bite,38K to 40K PUW, 1/25/2017 1/25/2017 0.30 PROD1 DRILL SRVY P DD wiper 2',DLS areeddrunn re-surveyg t 32'and 7,665.0 7,665.0 20:48 21:06 49° 1/25/2017 1/26/2017 2.90 PROD1 DRILL DRLG P CT,740 1 KpsCT , 1.8 m diff.,,1.4K3 6 psi 7,665.0 7,828.0 21:06 00:00 OB, 85 ft/hr,slow pump rate to 1.5 bpm to get DLS back closer to 45°,landed build at 7664',inverted and build up to 92°inclination. 1/26/2017 1/26/2017 0.80 PROD1 DRILL DRLG P Continue drilling build section,5.5K 7,828.0 7,900.0 00:00 00:48 CTW, 1.52 bpm,3934 psi CT,603 psi on-btm diff,2.5K WOB,66 ft/hr.Pump 5x5 sweep,sweep at bit 7880 ft, complete build section at 7900 ft. Average DLS was 41.6°with a Max DLS of 49.5°. 1/26/2017 1/26/2017 0.50 PROD1 DRILL WPRT P PUW 34K off btm,chase sweep out, 7,900.0 7,250.0 00:48 01:18 slight(2K)bobble at BOW,stop at 7510 ft,open EDC,continue to PUH, pumping 1.9 bpm,slowed down to 6 FPM thru CMU at 7463',saw a slight bobble,at 7400',the micro motion rate -out dropped off from 1.4 bpm to 0.4 bpm,appear to have opened CMU. Continued up to log K1. 1/26/2017 1/26/2017 0.20 PROD1 DRILL DLOG P Log K1,+1 ft correction 7,250.0 7,280.0 01:18 01:30 Page 5/20 Report Printed: 2/13/2017 S • Li,0 g Operations Summary, (with Timelog Depths) 2T-41 3 conoc 1?tliit9ps R ixka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/26/2017 1/26/2017 0.20 PROD1 DRILL TRIP P Ran bact down to3. CMU, K at ,slowed 746d tmicoo 7,280 .0 7,462.0 01:30 01:42 motion rate-out came back to 1.4 bpm, pulled up to neutral weight,changed TF from highside to 180°,pulled up slow,CMU remained closed. 1/26/2017 1/26/2017 1.70 PROD1 DRILL TRIP P Trip out,follow MP schedule for 11.8 7,462.0 72.1 01:42 03:24 ppg at window,jog near surface,saw fair amount of metal and 15 to 20% frac sand in sample 1/26/2017 1/26/2017 2.00 PROD1 DRILL PULD P At surface,PJSM,PUD&LD BHA#7 72.1 0.0 03:24 05:24 1/26/2017 1/26/2017 0.40 PROD1 DRILL PULD P PJSM MU and PU BHA#8 0.0 0.0 05:24 05:48 1/26/2017 1/26/2017 1.00 PROD1 DRILL SVRG P Crew change,injector maint 0.0 0.0 05:48 06:48 1/26/2017 1/26/2017 1.90 PROD1 DRILL PULD P andMporr completeePD,Check pack offs, 0.0 75.0 06:48 08:42 s. 1/26/2017 1/26/2017 1.50 PROD1 DRILL PULD P RIH W BHA#8 75.0 7,280.0 08:42 10:12 1/26/2017 1/26/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 for-9' correction,close 7,280.0 7,299.0 10:12 10:24 EDC,Wt Ck 33k lbs. 1/26/2017 1/26/2017 0.20 PROD1 DRILL TRIP P Continue to RIH 7,299.0 7,522.0 10:24 10:36 1/26/2017 1/26/2017 0.20 PROD1 DRILL DLOG P Log RA tag,7532.5' 7,522.0 7,575.0 10:36 10:48 1/26/2017 1/26/2017 0.20 PROD1 DRILL TRIP P Continue to RIH 7,575.0 7,900.0 10:48 11:00 1/26/2017 1/26/2017 2.20 PROD1 DRILL DRLG P Set 8 psi d t 1.800 bpm 0 bpm, IH.Wt 11 CTs 7,900.0 8,106.0 11:00 13:12 4607 psi,WOB 3.7 k lbs,ROP 200- 40 ft/hr. Hard stall, 1400 diff to 1700 psi Baker equipment crashed,PU,37 k lbs, 1/26/2017 1/26/2017 0.20'PROD1 DRILL WPRT T reboot,pull short wiper while waiting. 8,106.0 8,007.0 13:12 13:24 1/26/2017 1/26/2017 1.00 PROD1 DRILL WPRT T RBIH,lost HOT again,start slow wiper 8,007.0 7,800.0 13:24 14:24 up while BOT troubleshoots issue 1/26/2017 1/26/2017 1.90 PROD1 DRILL TRIP T POOH,OHydraulic unable Orito nng Tfind a surface 7,800.0 64.0 14:24 16:18 ool is suspect. Tripping to swap out HOT. Pulled above the CMU and opened EDC. 1/26/2017 1/26/2017 2.00 PROD1 DRILL PULD T PJSM,PUD BHA#8,break 64.0 0.0 16:18 18:18 connection at HOT-FVS,pull motor to clean and inspect bit,bit looks new, cleaned ports,RR motor and bit. 1/26/2017 1/26/2017 1.20 PROD1 DRILL PULD T PD BHA#9,bump up,set depth 0.0 75.0 18:18 19:30 1/26/2017 1/26/2017 1.30 PROD1 DRILL TRIP T Trip in, 75.0 7,280.0 19:30 20:48 1/26/2017 1/26/2017 0.30 PROD1 DRILL DLOG T Tie-in to K1,-8'correction 7,280.0 7,293.0 20:48 21:06 1/26/2017 1/26/2017 0.50 PROD1 DRILL TRIP T Trip in to drill,at 7498 ft, close EDC, 7,293.0 8,106.0 21:06 21:36 trip thru window clean, Page 6/20 Report Printed: 2/13/2017 • • 0:i,-, Operations Summary (with Timelog Depths) kit:=,., 2T-41 ConocoyPhillips f"., Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/26/2017 1/26/2017 0.40 PROD1 DRILL DRLG P Set rate to 1.80 bpm,RIH Wt 8K,4540 8,106.0 8,153.0 21:36 22:00 psi CT,710 psi off-btm diff. OBD, 1/26/2017 1/26/2017 0.20 PROD1 DRILL SRVY P DD wiper up,35K CT Wt, re-survey 8,153.0 8,153.0 22:00 22:12 8090'and 8060',good surveys,RIH to drill 1/26/2017 1/27/2017 1.80 PROD1 DRILL DRLG P Drilling to 82 8,153.0 8,288.0 22:12 00:00 1/27/2017 1/27/2017 4.70 PROD1 DRILL DRLG P Drilling per Geo&DD,Ct Wt between 8,288.0 8,610.0 00:00 04:42 -2K to 4.5K, 1.80 bpm,4852 psi CT, 1027 psi on-btm diff, 1K WOB, perform frequent pick-ups(36 to 37.5K)and BHA wipers to get WOB and motor work back,pumped a 5x5 sweep,saw 3K string wt back,better motor work and ROP w/sweep around BHA.Go past planned wiper at 8560',per Geo request. 1/27/2017 1/27/2017 0.40 PROD1 DRILL WPRT P Wiper trip#1,36K Ct Wt, 8,610.0 7,760.0 04:42 05:06 1/27/2017 1/27/2017 0.40 PROD1 DRILL WPRT P RBIH,6 k lbs RIH Wt, 1.80 bpm,CT 7,760.0 8,610.0 05:06 05:30 4700 psi,diff 788 psi, 1/27/2017 1/27/2017 5.10 PROD1 DRILL WPRT P OBD,4800 psi,WOB,0.76 k lbs,CT 8,610.0 9,060.0 05:30 10:36 Wt,0.56 k lbs. Fragile wt transfer, pumped a 5 x 5 sweep,moved coil while the sweep was on the backside in open hole,RBIH CT Wt 3k lbs, WOB 1.5 k lbs,ROP 142 fUhr 1/27/2017 1/27/2017 0.30 PROD1 DRILL WPRT P Wiper trip#2, Pu Wt 36 k lbs, 9,060.0 8,059.0 10:36 10:54 1/27/2017 1/27/2017 0.40 PROD1 DRILL WPRT P RBIH, RIH Wt 7.4 k lbs 8,059.0 9,060.0 10:54 11:18 1/27/2017 1/27/2017 4.10 PROD1 DRILL DRLG P 1.82 bpm,diff 786 psi 9,060.0 9,465.0 11:18 15:24 OBD,CT 5133 psi,CT Wt 4.5 k lbs, WOB 1.5 k lbs,ROP 220 ft/hr Weight transfer fell off,utilized sweeps to get started multiple times. 1/27/2017 1/27/2017 0.50 PROD1 DRILL WPRT P Ppelwiper n EDC. early,PUH,44 k lbs, 9,465.0 7,507.0 15:24 15:54 1/27/2017 1/27/2017 0.70 PROD1 DRILL CIRC P Pump p a botpretoms at thepumps owindff, 7,507.0 7,507.0 7,511.0 15:54 16:36 EDC, ***11.46 ppg and falling 1/27/2017 1/27/2017 0.60 PROD1 DRILL DLOG P log RA tag for+7'correction. 7,511.0 7,585.0 16:36 17:12 1/27/2017 1/27/2017 0.80 PROD1 DRILL TRIP P RBIH to drill 7,585.0 9,565.0 17:12 18:00 1/27/2017 1/27/2017 0.80 PROD1 DRILL DRLG P Struggle drillweight ight transfer to get 9,565.0 9,565.0 18:00 18:48 started 1/27/2017 1/27/2017 0.20 PROD1 DRILL WPRT P Pull r200'wiper trip up to 9360 ft,RBIH 9,565.0 9,565.0 18:48 19:00 ill 1/27/2017 1/27/2017 0.90 PROD1 DRILL DRLG P Drilling,w/5K CT Wt,1.82 bpm,4918 9,565.0 9,607.0 19:00 19:54 psi CT, 1066 psi on-btm diff,1.4K WOB,230 fUhr ROP. Pump two 5x5 sweeps,struggle with Wt transfer. Consult Drilling Engineer, decision to trip for an agitator. Page 7/20 Report Printed: 2/13/2017 • • . 0 Operations Summary (with Timelog Depths) at 2T-41 Canocongilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/27/2017 1/27/2017 1.00 PROD1 DRILL WPRT P PU off bottom 44K,PUH slow till 9,607.0 7,450.0 19:54 20:54 sweep gets to bit,wiper up,pull through window and CMU clean,open EDC, 1/27/2017 1/27/2017 1.40 PROD1 DRILL TRIP P Trip out for agitator,perform near 7,450.0 75.0 20:54 22:18 surface jog to 500 ft.bump up and space out. 1/27/2017 1/27/2017 1.40 PROD1 DRILL PULD P At surface,PJSM,PUD,laydown 75.0 0.0 22:18 23:42 Weatherford 0.5°AKO motor and HCC bit(Grade 2-1,2 chipped pilot cutters) 1/27/2017 1/28/2017 0.30 PROD1 DRILL PULD P Pick-up NOV agitator,Baker 0.5° 0.0 0.0 23:42 00:00 • motor,and RR HYC 3.0"bi-center bit 1/28/2017 1/28/2017 1.00 PROD1 DRILL PULD P Continue w/PD BHA#10,check 0.0 78.3 00:00 01:00 packoffs,packoffs good. 1/28/2017 1/28/2017 1.40 PROD1 DRILL TRIP P Trip in,test agitator at 125',close 78.3 7,275.0 01:00 02:24 EDC,bring rate to 1.4 bpm,869 psi diff,agitator working,continue in w/ EDC closed 1/28/2017 1/28/2017 0.20 PROD1 DRILL DLOG P Tie-in to K1,-9'correction. 7,275.0 7,305.0 02:24 02:36 1/28/2017 1/28/2017 0.90 PROD1 DRILL TRIP P Trip in to drill,RIH Wt 8K lbs, 1.80 7,305.0 9,607.0 02:36 03:30 bpm,off-btm 5360 psi CT, 1492 psi diff,45K CT PU Wt 1/28/2017 1/28/2017 1.00 PROD1 DRILL DRLG P OBD,CT Wt 6.2K lbs,5510 psi CT, 9,607.0 9,712.0 03:30 04:30 1774 psi diff, 1.2K WOB,75 to 200 ft/hr ROP. Pick-up's to get Wgt transfer back,42K and 51K,pump 5x5 sweep, 1/28/2017 1/28/2017 1.00 PROD1 DRILL DRLG P Lower pump rate to 1.63 bpm,4650 9,712.0 9,771.0 04:30 05:30 psi CT, 1220 psi off-btm diff,snubbing -5K CT Wt,w/1.2K WOB,getting 95 to 145 ft/hr ROP,PUW 49K. continue to struggle with weiight transfer. 1/28/2017 1/28/2017 1.00 PROD1 DRILL WPRT P Wiper to the window,pumping 10x10 9,771.0 7,535.0 05:30 06:30 sweep,then 5x5 sweep.PUH weight 40k lbs, 1/28/2017 1/28/2017 0.70 PROD1 DRILL WPRT T Jog the hole to clean 5.5 x 2,RBIH 18 7,535.0 7,508.0 06:30 07:12 fpm,set down 10k at the window,pick up,try again at 14,fan pump,22,& fan pump 28 fpm,SD each time©- 7535',PUH open EDC 1/28/2017 1/28/2017 0.70 PROD1 DRILL CIRC T Pump 5x5 low hi vis sweep,S/D,close 7,508.0 7,511.0 07:12 07:54 EDC,RBIH to TOW,S/D 7030,PU, pumps on at 0.4 bpm while cycling pipe across the 5.5" Stacked 1.6 k WOB @ 7521'then pulled-3.5 k. 1/28/2017 1/28/2017 0.50 PROD1 DRILL DLOG T Park coil,open EDC,PUH for tie in to 7,511.0 7,295.0 07:54 08:24 K1 for+5 correction. 1/28/2017 1/28/2017 0.50 PROD1 DRILL TRIP T Close EDC,RBIH,S/D 7535,PU,36 k 7,295.0 7,535.0 08:24 08:54 lbs, pumps @ 0.4 bpm,motor spins at 0.6 bpm,RBIH,set weight at 7526', PU clean,Set weight again @ 7526. PUH. RIH 18 fpm @ 0.25 bpm.S/D 7530,PU but stay below top of WS, SD 1k WOB,tried to roll bit,saw motor trying to torque up. 1/28/2017 1/28/2017 1.10 PROD1 DRILL TRIP T PUH,Open EDC, 7,535.0 7,535.0 08:54 10:00 Page 8/20 Report Printed: 2/13/2017 • Summary (with Timelog Depths) Operations 0 2T-41 f; u ConocoPhlflips 'i'` Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth B End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) 7th(5.0 1/28/2017 1/28/2017 1.00 PROD1 DRILL TRIP T Call town,discuss path forward 10:00 11:00 1/28/2017 1/28/2017 1.00 PROD1 DRILL TRIP T POOH for window dressing assembly 7,535.0 72.0 11:00 12:00 1/28/2017 1/28/2017 2.00 PROD1 DRILL PULD T B Bump up,Space out,PUD&LD BHA 72.0 0.0 12:00 14:00 0 1/28/2017 1/28/2017 2.20 PROD1 DRILL PULD T Set moor to 0.78°d(checks K ,P holding) and PD 0.0 63.0 14:00 16:12 w/EDCBHA 11 window dressing assembly, w/2.73 NoGo crayola mill 1/28/2017 1/28/2017 1.50 PROD1 DRILL TRIP T RIH w/EDC closed 63.0 7,265.0 16:12 17:42 1/28/2017 1/28/2017 0.20 PROD1 DRILL DLOG T Tie in to K1 7,265.0 7,300.0 17:42 17:54 1/28/2017 1/28/2017 0.60 PROD1 DRILL DLOG T RIH dry,tagged BOW at 7434'w/5K 7,300.0 7,534.0 17:54 18:30 WOB,pick-up was 32K,saw 38K at TOW. PUH 10',Bring pumps to 1.6 BPM,only getting 56 psi diff,Trouble shoot EDC,check status,status showing closed,try different rate 1 bpm,same 65 psi dP,cycle EDC open/closed,same result. Suspect o- ring seals in EDC are blown. 1/28/2017 1/28/2017 0.70 PROD1 DRILL TRIP T Trip for Baker EDC. Stop to inspect 7,534.0 7,029.0 18:30 19:12 gouge mark on pipe back at the reel. Checked depth w/micrometer,0.022" deep. Mark was 10 wraps on reel. Paint gouge w/yellow spray paint. 1/28/2017 1/28/2017 0.30 PROD1 DRILL TRIP T RBIH to get accurate depth. Stop at 7,029.0 7,522.0 19:12 19:30 7522.8',puts paint mark at 1st roller from injector,-15'from top of injector, will get measurement. 1/28/2017 1/28/2017 1.50 PROD1 DRILL TRIP T Trip for EDC. 7,522.0 63.0 19:30 21:00 1/28/2017 1/28/2017 1.50 PROD1 DRILL PULD T PJSM,checks arw/PUD BHA#11e holding, ontinoe 63.0 0.0 21:00 22:30 visual confirmation of failed o-ring, inspect crayola mill,laydown upper CoilTrak BHA,blow air thru motor in mousehole,motor spins. 1/28/2017 1/28/2017 1.20 PROD1 DRILL PULD T PU different upper CoilTrak assembly 0.0 63.0 22:30 23:42 w/back-up ERD,(out-of-spec due to vibration from window milling BHA), Re-run Baker motor and 2.74"Crayola mill,PJSM,PD BHA#12 1/28/2017 1/29/2017 0.30 PROD1 DRILL TRIP T Tripin to testft,good ats EDC 4 C and tost,psi 63.0 1,150.0 23:42 00:00 shallodiff.,continue RIH w/EDC closed. 1/29/2017 1/29/2017 1.10 PROD1 DRILL TRIP T Trip in,pump managed pressure 11.5 1,150.0 7,265.0 00:00 01:06 ppg at window 1/29/2017 1/29/2017 0.20 PROD1 DRILL DLOG T Tie-in to K1,-7'correction 7,265.0 7,282.5 01:06 01:18 1/29/2017 1/29/2017 0.20 PROD1 DRILL TRIP T Dry tag window K RIH Wt Pick-up 35 KK at 3 7,282.5 7,535.0 01:18 01:30 Page 9/20 Report Printed: 2/13/2017 • i O Operations Summary (with Timelog Depths) 2T-41 ConocoPhillips , AIs.A Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/29/2017 1/29/2017 1.20 PROD1 DRILL DRLG T Set rate to 1.42 bpm,3474 psi CT, 7,535.0 7,565.0 01:30 02:42263 psi off-btm diff. RIH with 0°TF, slowdown to 1 FPM at 7534',dress BOW at 7535.3 ft,3557 psi CT,448 psi diff,let differential and WOB mill off to 7536.5 no motor work,run down to 7545'. PUH to 7517',no overpull. RIH two more times at 0°TF to 7540', back ream each time at 30°LOHS and ROHS. Last RIH,drift clean to 7565', pull back thru no issues. 1/29/2017 1/29/2017 1.80 PROD1 DRILL TRIP T Pull thru CMU at 180°TF,open EDC, 7,565.0 63.0 02:42 04:30 POOH,stop at 1000'to check out pit G/L,showing a gain when the micro motion has been showing 0.2 bpm loss,trip sheet shows 5 bbl loss,gain due to mud aerated. POOH to surface. 1/29/2017 1/29/2017 1.80 PROD1 DRILL 'PULD T PUD BHA#12. 63.0 0.0 04:30 06:18 1/29/2017 1/29/2017 0.20 PROD1 WHDBOP RURD T BOPE fucncticlean on test,o r,c prepkor r 0. 0 0.0 06:18 06:30 1/29/2017 1/29/2017 0.30 PROD1 WHDBOP BOPE T Function test BOPE 0.0 0.0 06:30 06:48 1/29/2017 1/29/2017 2.00 PROD1 DRILL PULD T PJSM, Ul &PD BHA with agitator,13,ERD 0.L1 0.0 78.0 06:48 08:48 LAKO Baker motor,inspect P/Os good, tag up. 1/29/2017 1/29/2017 1.60 PROD1 DRILL TRIP T RIH 78.0 7,265.0 08:48 10:24 1/29/2017 1/29/2017 0.20 PROD1 DRILL DLOG T Tieiei to K1,-9.5'correction,close 7,265.0 7,292.0 10:24 10:36 1/29/2017 1/29/2017 0.50 PROD1 DRILL TRIP P Run to gouge in coil, continue to RIH, 7,292.0 8,454.0 10:36 11:06 slide through window clean at 25 ft/min! 1/29/2017 1/29/2017 0.50 PROD1 DRILL TRIP P Set down @ 8454',the center of hot 8,454.0 9,771.0 11:06 11:36 gamma,PU 37 k lbs,reduce rate from 1 bpm to 0.25 bpm,RBIH,stack weight but pop through,continue to RIH,increase rate to 1 bpm. Stacked some weight at 8650'but did not set down. 1/29/2017 1/29/2017 2.50 PROD1 DRILL DRLG P RIH Wt 4 k lbs,1.80 bpm,CT 5048 9,771.0 9,919.0 11:36 14:06 psi,diff 1160 psi, OBD CT 5208 psi,CT 0 lbs,WOB 1.5 k ROP 150 ft/hr. new mud at the bit,12:15,PU for BA wiper,Wt 49.5 k lbs,drill some new hole and Wt Ck,36k lbs. Adjust rate to 1.65 bpm in atempt to get more WOB,having troubles turning down. Turned down,1.80 bpm, poor weight transfer,low WOB 1/29/2017 1/29/2017 0.20 PROD1 DRILL WPRT P 500'wiper trip#1,PU 62 k lbs 9,919.0 9,419.0 14:06 14:18 1/29/2017 1/29/2017 0.20 PROD1 'DRILL WPRT P RBIH,RIH Wt 3 k lbs 9,419.0 9,919.0 14:18 14:30 Page 10/20 Report Printed: 2/13/2017 • S Operations Summary (with Timelog Depths) V",;,, •f� r•{_ 2T-41 +ConocoPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth ftK8 End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation ( ) 1/29/2017 1/29/2017 1.10 PROD1 DRILL DRLG P RIH diff 1276 bs,' 1.80 bpm,CT 5160 9,919.0 9,988.0 14:30 15:36 psi,OBD CT 5384 psi,CT-3 k lbs,WOB 1.3 k ROP 200-150 ft/hr. 1/29/2017 1/29/2017 0.30 PROD1 DRILL WPRT P 500'wiper trip#2,PU 52 k lbs 9,988.0 9,488.0 15:36 15:54 1/29/2017 1/29/2017 0.30 PROD1 DRILL WPRT P RBIH,RIH Wt 3 k lbs 9,488.0 9,988.0 15:54 16:12 1/29/2017 1/29/2017 0.70 PROD1 DRILL DRLG P RIH Wt 3 k l s, 1.77 bpm,CT 5157 9,988.0 10,063.0 16:12 16:54 psi, tpsi, OBD CT 5228 psi,CT-4 k lbs,WOB 1 k ROP 200-66 ft/hr. Multiple pick ups-50 k lbs 1/29/2017 1/29/2017 1.30 PROD1 DRILL WPRT P Longonwiper lino window,er PU Wt,42e clean klu 5.5" 10,063.0 7,560.0 16:54 18:12 1/29/2017 1/29/2017 0.20 PROD1 DRILL DLOG P Tie-in to RA,+5.5'correction, 7,560.0 7,590.0 18:12 18:24 1/29/2017 1/29/2017 1.00 PROD1 DRILL TRIP P RIH back reamed drill, medsaw lx and bobble atd 8475',u47,50.0 10,063.0 18:24 19:24 continue RIH,saw nothing at 8650', At 10000',RIH Wt= -0.8 to 1.8K,1.8 bpm,5264 psi CT,1252 psi off-btm diff 1/29/2017 1/29/2017 1.40 PROD1 DRILL DRLG P Drillanahead w//m rgi6K weight CT Wt,5260, 10,063.0 10,158.0 19:24 20:48 trfrequent short BHA wipers,PU Wts 46 to 55K,at 10125'tried lowering rate to 1.6 bpm,4350 psi off-btm,last PU Wt 58k 1/29/2017 1/29/2017 0.20 PROD1 DRILL WPRT P Short wiper to 10040 10,158.0 10,158.0 20:48 21:00 1/29/2017 1/29/2017 0.70 PROD1 DRILL DRLG P OBD 10,158.0 10,211.0 21:00 21:42 1/29/2017 1/29/2017 0.50 PROD1 DRILL WPRT P 500'wiper trip#1,56K lbs PU Wt, 10,211.0 10,211.0 21:42 22:12 1/29/2017 1/30/2017 1.80 PROD1 DRILL DRLG P OBD,-3.7k CT Wt,1.32 bpm(trying to 10,211.0 10,326.0 22:12 00:00 build to 92°),4027 psi CT, 1026 psi diff,1.7k WOB,bring rate back to 1.5 bpm 4515 psi CT,1103 psi off-btm diff. Pump 5x5 sweep, 1/30/2017 1/30/2017 0.80 PROD1 DRILL DRLG P Drilling,-4K CT Wt,1.5 bpm,4515 psi 10,326.0 10,376.0 00:00 00:48 CT,1103 psi diff.,09K WOB,75 FPH 1/30/2017 1/30/2017 0.70 PROD1 DRILL WPRT P 500'wiper trip#2,41K lbs PU Wt, 10,376.0 10,376.0 00:48 01:30 1/30/2017 1/30/2017 2.60 PROD1 DRILL DRLG P Drilling,pumped 15 bbl Hi vis beaded 10,376.0 10,628.0 01:30 04:06 pill,pill at bit at 01:55 am,pulled BHA wiper,RIH Wt came back to 8.8K, OBD w/+4K CT Wt,1.5 bpm,4687 psi CT, 1269 psi dif,2.1K WOB,175 FPH ROP. Pumped 2nd 10 bbl beaded pill @ 3:05,pill at the bit @ 03:22,+2K CT Wt,1.82 bpm,5307 psi CT, 1248 psi diff, 1.5K WOB,153 Ft/hr ROP. 1/30/2017 1/30/2017 0.20 PROD1 DRILL WPRT P 200'wiper trip,46K CT Wt,pump 10 10,632.0 10,632.0 04:06 04:18 bbls beaded pill#3, 1/30/2017 1/30/2017 1.50 PROD1 ' DRILL DRLG P to herd sego 1.2 to. by ,per Ce per 10,632.0 10,763.0 04:18 05:48 6K CT Wt,3958 psi CT,890 psi diff, 1.1K WOB,90 ft/hr ROP. Page 11/20 Report Printed: 2/13/2017 ri,.:, ,.;:ilk • • Operations Summary (with Timelog Depths) ot 0 ,s 2T-41 ConacoPtt+illips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/30/2017 1/30/2017 1.70 PROD1 DRILL WPRT P Long wiper to window,clean up the 10,763.0 7,490.0 05:48 07:30 5.5"drilling liner above the WS 1/30/2017 1/30/2017 0.20 PROD1 DRILL DLOG P Tie into the WS RA tag+8.5. 7,490.0 7,579.8 07:30 07:42 1/30/2017 1/30/2017 1.20 PROD1 DRILL WPRT P RBIH, oth h'theanhigh 8650' mmaere cleanareas, 7,579.0 10,763.0 07:42 08:54 8445-the way in hole. 1/30/2017 1/30/2017 2.20 PROD1 DRILL DRLG P 1.71 7 bpm, Wt ,CT k lb9 5Dplsi,diff dh reg 4spsi, 10,763.0 10,956.0 08:54 11:06 Rweight,poor weight transfer,0.6 k lbs WOB. Pump 5X10 sweep,high vis w beads. Drill ahead with good weight transfer that slowly dissipates as the beads are circulated out. Experience short drilling break from 10850-19200' ROP-250 ft/hr. Saw positive returns fora short time, 1.7 in 1.8 bpm out. Pinched in choke to manage. Experiencing issues with getting clean surveys,reduce pump rate to 1.5 bpm seems to help. 1/30/2017 1/30/2017 0.40 PROD1 DRILL WPRT P Short wiesper RB8 0',PU Wt 50 k 5X5 low x high 10,956.0 10,154.0 11:06 11:30 trovis(beaded)sweep. 1/30/2017 1/30/2017 0.40 PROD1 DRILL WPRT P RBIH,RIH Wt 7-4 k lbs 10,154.0 10,956.0 11:30 11:54 1/30/2017 1/30/2017 0.40 PROD1 DRILL DRLG P 1.61 bpm,CT CT 45 4 k lbs,WOB 1050,i,diff 150 psi C10,956.0 11,009.0 11:54 12:18 OBD4960 psi,ROP 255,weight transfer issues returned after-50'drilled. 1/30/2017 1/30/2017 0.80 PROD1 DRILL DRLG T Attempted to PU off bottom,pulled 60 11,009.0 11,007.0 12:18 13:06 k,RBIH,dialed up traction,PU,65 k, RBIH,PU 78 k lbs. Pump 5x5 sweep and circulate bottoms up.Orient freely. ECD @ 11.3 ppg,Pull 6 times working up to-5 down and 80 k lbs up. 1/30/2017 1/30/2017 3.10 PROD1 DRILL CIRC T Loadthpill pi i 9 bblsLet of soakVT mi20 coral oil 10,990.0 10,990.0 13:06 16:12 S/D and pulled,up to-10 down and 81 k up lbs. While allowing ECD to bleed down to 11.00 ppg. No luck, pumped additional 9 bbls to advance top of mineral oil on the back side to the window Ct wt.50 k lbs. 1/30/2017 1/30/2017 1.00 PROD1 DRILL CIRC T Soak kk 4 mtiineral oil,sack to-10 k t ECD atnd pull 10,990.0 11,002.0 16:12 17:12 PP9- 1/30/2017 1/30/2017 0.70 PROD1 DRILL CIRC T Circulate out-9 bbls of LVT, 10,990.0 11,002.0 17:12 17:54sequester LVT returns in pill pit. Start draining LVT tote into pill pit. 1/30/2017 1/30/2017 1.70 PROD1 DRILL CIRC T Add1 h tote hold of-1K ,CT pump t while bbls LVT 11,002.0 11,002.0 17:54 19:36 to circulating,pump 17 bbls(OH volume) out bit, 1/30/2017 1/30/2017 0.70 PROD1 DRILL OTHR T oil Shutdown4frn andd soak 2K tk for 30 78at 75.FPM.Cycle 11,002.0 11,002.0 19:36 20:18 cRelax pipe to-1K,pump ECD from 11.18 to 11.33 ppg. Page 12/20 Report Printed: 2/13/2017 ,.,:,,,nik • • 0,1:', Operations Summary (with Timelog Depths) 2T-41 ConocoPhiliips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/30/2017 1/30/2017 0.20 PROD1 DRILL WAIT T Consult Town. 11,002.0 11,002.0 20:18 20:30 1/30/2017 1/30/2017 2.00 PROD1 DRILL OTHR T Bleed WHP pressure down from 11.3 11,002.0 11,002.0 20:30 22:30 ppg to 10.7 ppg ECD,allow BHP to bleed down,after 70 min,BHP is down to 10.3 ppg ECD. Worked pipe 2x from-10K to 78K,no movement. Bled BHP to 10.0 ppg ECD w/-10K down,pipe popped free,45K PU Wt. 1/30/2017 1/31/2017 1.50 PROD1 DRILL WPRT P Long wiper to window at 50 fpm,35K 11,002.0 7,603.0 22:30 00:00 CT Wt, 1.75 bpm,4935 psi CT,1201 psi diff, Both chokes and micro motion-out packed off. Seeing angel hair metal at the shaker. jog at the window and circulate 1 BU. 1/31/2017 1/31/2017 1.00 PROD1 DRILL CIRC P Circulate 1.5 X BU and jog below TT 7,603.0 7,480.0 00:00 01:00 at 7578'to TOW at 7525,1.5 bpm, . troubleshoot packed off chokes and micro motion OUT. 1/31/2017 1/31/2017 0.30 PROD1 DRILL DLOG P Tie-in to RA tag,+9.5'correction 7,480.0 7,570.0 01:00 01:18 1/31/2017 1/31/2017 1.70 PROD1 DRILL TRIP P RIH to drill w/8K CT Wt,at 50 FPM, 7,570.0 11,007.0 01:18 03:00 0.3 bpm min rate through build,no trouble spots seen,snubbing in after 10000'at 20 FPM,backed pump rate to 0.8 bpm to keep moving,pump 5 bbl beaded pill. At 10990',turn around 45K up. 1/31/2017 1/31/2017 1.30 PROD1 DRILL DRLG P Run in to drill,-6K to-8K to get on 11,007.0 11,182.0 03:00 04:18 bottam at 1.58 bpm,4857 psi CT, 1234 psi on-btm diff, 1.2K WOB,118 Ft/hr ROP. Micro Motion plugged, bypass micro motion to troubleshoot, continue drilling beads at bit,CT Wt back to+1K, 1.4K WOB,100 to 200 ft/hr ROP. 1/31/2017 1/31/2017 0.50 PROD1 DRILL WPRT P 200'wiper trip,last PU was 65K,RBIH 11,182.0 11,182.0 04:18 04:48 at 23 FPM,2 to 3K RIH Wt,0.47 bpm, 2198 psi, 143 psi pif 1/31/2017 1/31/2017 0.75 PROD1 DRILL DRLG P BOBD, 1.57 bpm at 4,950 psi,BHP 11,182.0 11,271.0 04:48 05:33 3,760,WHP 233,IA 611,OA 393, DHWOB 1.2 k,ROP 100-150 fph 1/31/2017 1/31/2017 0.45 PROD1 DRILL WPRT P 300'wiper trip,last PU 43 k,RBIH,-2 11,271.0 11,271.0 05:33 06:00 k RIW 1/31/2017 1/31/2017 0.50 PROD1 . DRILL DRLG P BOBD 1.56 bpm at4,690 psi,BHP 11,271.0 11,350.0 06:00 06:30 3,855,WHP 208,IA 622,OA 393 1/31/2017 1/31/2017 2.50 PROD1 DRILL WPRT P TD L1 Lateral,pump 10x10 sweep, 11,350.0 7,493.0 06:30 09:00 chase sweep to the window,perform jog IH between 7,550'-7,650'at 49 fpm pumping 1.00 bpm at 3,820 psi,PUH thru window,make 3 jogging passes in the 5.5" 1/31/2017 1/31/2017 1.25 PROD1 DRILL -TRIP P Wiper to the swab valves,pumping 7,493.0 78.3 09:00 10:15 1.5 bpm,perform jog from 200'-400', tag up at surface,reset counters. 1/31/2017 1/31/2017 1.50 PROD1 DRILL TRIP P RBIH,to confirm TD 78.3 7,255.0 10:15 11:45 1/31/2017 1/31/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of plus 7,255.0 7,284.3 11:45 12:00 12.0',PUW 35 k Page 13/20 Report Printed: 2/13/2017 0 • Operations Summary (with Timelog Depths) "14,f 2T-41 �iflips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/31/2017 1/31/2017 1.90 PROD1 DRILL TRIP P Continue RIH,confirm TD 7,284.3 11,357.0 12:00 13:54 1/31/2017 1/31/2017 4.00 PROD1 DRILL TRIP P Confirm TD @ 13357,Trip out 11,357.0 2,799.0 13:54 17:54 pumping 11.8PPG beaded liner running pill followed by 11.8 PPG _ completion fluid,Paint Log RA for+3.5 EOP flags @ 9500 and 5700' 1/31/2017 1/31/2017 3.50 PROD1 DRILL TRIP T 2800'lost all returns.Out MW=11.1,In 2,799.0 3,000.0 17:54 21:24 MW=11.8.Regained some reyurns @.8 BPM in,.15 BPM out.No returns at lower rates.Confer with town bring completion fluid down to 11.0PPG. Circ in at 3000'.Unable to get returns 1/31/2017 1/31/2017 0.70 PROD1 DRILL TRIP P Continue out of well filling accross top, 3,000.0 72.0 21:24 22:06 loss rate down to 12 BBIs/Hr 1/31/2017 1/31/2017 0.50 PROD1 DRILL OWFF P Flow check well,lost 6 BBIs in 30 min 72.0 72.0 22:06 22:36 1/31/2017 1/31/2017 1.00 PROD1 DRILL PULD P Break off injector and lay down BHA# 72.0 0.0 22:36 23:36 13 1/31/2017 2/1/2017 0.40 COMPZI CASING PUTB P PJSM,M/U BHA#14 with non ported 0.0 0.0 23:36 00:00 bull nose,43 jts slotted liner and shorty deployment sleeve 2/1/2017 2/1/2017 2.10 COMPZI CASING PUTB P Continue M/U BHA#14 L1 lower liner 0.0 1,692.0 00:00 02:06 segment 2/1/2017 2/1/2017 1.20 COMPZ1 CASING PULD P Liner pick up complete,PJSM,M/U 1,692.0 1,738.0 02:06 03:18 coil trak to liner, Change out check valves,check pack offs,M/U injector and surface test tool 2/1/2017 2/1/2017 1.30 COMPZ1 CASING RUNL P RIH with liner,EDC Closed,pumping 1,738.0 7,553.6 03:18 04:36 min rate on 11.0 2/1/2017 2/1/2017 0.10 COMPZ1 CASING DLOG P Stop at 5700'EOP and correct-15.2', 7,553.6 7,437.0 04:36 04:42 PUW=38K 2/1/2017 2/1/2017 2.25 COMPZ1 CASING RUNL P Continue in well,Set down at bottom 7,437.0 11,357.0 04:42 06:57 of window 7537' @ 20 FPM,Sped up to 30 FPM clean pass through window,continue thru open hole speeding up to 50 fph,to TD set down 4 k @ 11,357',bring pump up to 1.7 bpm filling coil,release coil on bottom, PUH,remove Lower Liner Section from BHA, 2/1/2017 2/1/2017 2.50 COMPZ1 CASING TRIP P POOH,painted EOP flags at 6,900'. 44.3 0.0 06:57 09:27 and TD flag at 8,990' 2/1/2017 2/1/2017 1.00 COMPZ1 CASING PULD P LD,Coiltrak and setting tools. 0.0 0.0 09:27 10:27 2/1/2017 2/1/2017 0.50 COMPZ1 CASING PUTB P Prep rig floor for liner operations 0.0 0.0 10:27 10:57 2/1/2017 2/1/2017 1.50 COMPZ1 CASING PUTB P PJSM,MU upper liner section 0.0 473.5 10:57 12:27 2/1/2017 2/1/2017 1.00 COMPZ1 CASING PUTB P PU/MU Coiltrak tools,surface test, 473.5 547.9 12:27 13:27 good test 2/1/2017 2/1/2017 1.50 COMPZ1 CASING RUNL P and O/upper Anchoredbillet,section nEwith C hl12 jts 547.9 895.0 13:27 14:57 differential too high on EDC(1,249 psi),PUH to equalize pressure and open EDC, 2/1/2017 2/1/2017 1.90 COMPZ1 CASING RUNL P Continue RIH 895.0 7,740.0 14:57 16:51 Page 14/20 Report Printed: 2/13/2017 0 II Operations Summary (with Timelog Depths) 2T-41 {Conocof'hillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/1/2017 2/1/2017 1.10 COMPZ1 CASING DLOG P Log the K1 marker correction of minus 7,448.0 7,448.0 16:51 17:57 12.0,attempt to close EDC.,discuss with MWD,switch to SD software and attempt again. 2/1/2017 2/1/2017 1.40 COMPZ1 CASING RUNL P Continue in hole,clean pass through 7,448.0 9,659.0 17:57 19:21 window down to set depth of 9659 2/1/2017 2/1/2017 0.10 COMPZ1 CASING RUNL P PUH and reconfirm bottom,Orient to 9,659.0 9,659.0 19:21 19:27 210°,PUW=39K,Bring pumps online. See tool shift at3100 PSI,PUW=37K 2/1/2017 2/1/2017 2.00 COMPZ1 CASING TRIP P Trip out of hole,At 9642 remove liner 9,659.0 75.0 19:27 21:27 length left in hole 9155 2/1/2017 2/1/2017 0.50 COMPZ1 CASING OWFF; P At surface perform 30 min no flow 75.0 75.0 21:27 21:57 2/1/2017 2/1/2017 0.90 COMPZ1 CASING PULD P Good no flow test,PJSM Lay down 75.0 0.0 21:57 22:51 BHA#15 L1 upper liner segment running tools 2/1/2017 2/2/2017 1.15 PROD2 DRILL CTOP P Coil flat spotted above CTC,Break off 0.0 22:51 00:00 UQC and cut off CTC.Trim 12'pipe, Prep CT and install connector 2/2/2017 2/2/2017 1.20 PROD2 DRILL CTOP P Continue connector install,Pull test to 0.0 0.0 00:00 01:12 35K 2/2/2017 2/2/2017 0.80 PROD2 DRILL CTOP P Test E-line good-rehead upper quick 0.0 0.0 01:12 02:00 connect Pressure test to 4200 PSI 2/2/2017 2/2/2017 1.00 PROD2 STK PULD P PJSM-M/U BHA#16 with.5°WFT 0.0 80.9 02:00 03:00 motor and rebuild hycalog bi center. C/O packoffs,make up co coil and surface test tool 2/2/2017 2/2/2017 1.80 PROD2 STK TRIP P Trip in hole-Shallow test agitator and 80.9 7,280.0 03:00 04:48 motor 1.4 BPM 2/2/2017 2/2/2017 0.20 PROD2 STK DLOG P Log K1 for-7'correction 7,280.0 7,296.0 04:48 05:00 2/2/2017 2/2/2017 1.00 PROD2 STK CIRC P Displace well back to 8.6 PPG floPro 7,296.0 7,475.0 05:00 06:00 2/2/2017 2/2/2017 0.75 PROD2 STK TRIP P Continue IH,dry tag TOB(9173') 7,475.0 9,173.0 06:00 06:45 2/2/2017 2/2/2017 2.75 PROD2 STK KOST P PUW 31 k,bring pump up to 1.5 bpm 9,173.0 9,188.0 06:45 09:30at 4,390',BHP 3,622',WHP 215,IA 0, OA 357,start kickoff as per RP 2/2/2017 2/2/2017 0.25 PROD2 DRILL DRLG P Drill ahead, 1.5 bpm at 4,345 psi,BHP 9,188.0 9,210.0 09:30 09:45 3,669,WHP 200,IA 10,OA 369 2/2/2017 2/2/2017 1.50 PROD2 DRILL WPRT P Notice scribe line issue,tools not 9,210.0 9,188.0 09:45 11:15 drilling the direction needed.trouble shoot issue,drift billet area,drift was clean. 2/2/2017 2/2/2017 1.50 PROD2 DRILL TRIP T Conferred with town both BHI and 9,188.0 80.1 11:15 12:45 CTD team,decision was made to POOH to check drilling tools, 2/2/2017 2/2/2017 0.25 PROD2 DRILL PULD T At surface,PJSM 80.1 80.1 12:45 13:00 2/2/2017 2/2/2017 1.50 PROD2 DRILL PULD T PUD&LD Lateral BHA#16,before 80.1 0.0 13:00 14:30 LD tools remark scribes from previous run,checked out to be correct. • Page 15/20 Report Printed: 2/13/2017 0 S Operations Summary (with Timelog Depths) •,.,,z 'I -k,14 2T -41 Conoco Phillips , Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/2/2017 2/2/2017 2.00 PROD2 . DRILL PULD T Troubleshoot steering issues.surface 0.0 0.0 14:30 16:30 test MWD tool string,checked ok, checked out ako on WFT motor found to be less.conferred with town engineer,decision was made to change out the lower section, DGS,USR,HOT,WFT motor,and bi- center bit. ****Note:Bit grade 1-2-bt-g-x-in-no-hp 2/2/2017 2/2/2017 2.20 PROD2 DRILL PULD T B A#1PU/MU/PD lateral drilling 0.0 80.1 16:30 18:42 7 2/2/2017 2/2/2017 1.30 PROD2 DRILL TRIP T RIH,with drilling BHA#17,agitator 80.1 7,286.0 18:42 20:00 2/2/2017 2/2/2017 0.20 PROD2 DRILL DLOG T Log the K1 marker correction of-11' 7,286.0 7,302.0 20:00 20:12 2/2/2017 2/2/2017 0.90 PROD2 DRILL TRIP T Continue in,Test HOT on RS(Right 7,302.0 9,210.0 20:12 21:06 Stop) 2/2/2017 2/3/2017 2.90 PROD2 DRILL DRLG P 9210',Drill 1.8 BPM @ 5220 PSI FS, 9,210.0 9,448.0 21:06 00:00 BHP=3685,High vibration had to come off bottom for surveys,Drilling with-2 to 4K surface weight 2/3/2017 2/3/2017 1.80 PROD2 DRILL DRLG P 9448 drill ahead, 1.7 BPM @ 5070PSi 9,448.0 9,602.0 00:00 01:48 FS,BHP=3700.RIW=-1.6K to-4K, DHWOB=1.6 to 1.2,High vibration on meters 2/3/2017 2/3/2017 2.45 PROD2 DRILL TRIP T Power failure on tool,trouble shoot 9,602.0 80.1 01:48 04:15 surface connections-No good POOH, Pulled tight at TOW.Jogged free and recip 5 1/2 BEGIN Nabros NPT TIME @ 2:00 2/3/2017 2/3/2017 3.00 PROD2 DRILL CTOP T At surface,brake off INJH,test tools 80.1 0.0 04:15 07:15 IH,test surface line,continue to undeploy drilling BHA#17 2/3/2017 2/3/2017 1.50 PROD2 DRILL CTOP T Trouble shoot after LD of BHA, 0.0 0.0 07:15 08:45 perform lock out tag out,inspect, found that the e-line was shorted inside the 10 k bulkhead,prep and repair shorted cable. 2/3/2017 2/3/2017 1.00 PROD2 DRILL PULD T PD L1-01 lateral drilling BHA#18 80.8 80.8 08:45 09:45 2/3/2017 2/3/2017 1.25 PROD2 DRILL TRIP T RIH,w/drilling BHA and agitator 80.8 7,280.0 09:45 11:00 2/3/2017 2/3/2017 0.25 PROD2 DRILL DLOG T Log the K1 marker correction of minus 7,280.0 7,313.0 11:00 11:15 12.Oft 2/3/2017 2/3/2017 0.40 PROD2 DRILL TRIP T Continue IH,passing through the 7,313.0 9,602.0 11:15 11:39 window clean,setting down ****Note:End of Nabors NPT(7 hrs) 2/3/2017 2/3/2017 3.85 PROD2 DRILL DRLG P OBD, p4,11 psi, BHP 9,602.0 9,775.0 11:39 15:30 WHP0, at 2/3/2017 2/3/2017 0.50 PROD2 DRILL WPRT P Wiper up hole PUW 35 k, 9,775.0 9,100.0 15:30 16:00 2/3/2017 2/3/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 3 k 9,100.0 9,775.0 16:00 16:30 2/3/2017 2/3/2017 2.20 PROD2 DRILL DRLG P BOBD0,WHP 100,IA 393,OA 1.67 bpm at 4,551 psi,BHHP 9,775.0 9,864.0 16:30 18:42 Page 16/20 Report Printed: 2/13/2017 • • .;_,,,, Operations Summary (with Timelog Depths) .,., AF: 2T-41 CoeeocoPhillips : Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/3/2017 2/3/2017 3.10 PROD2 DRILL TRIP T Dwelt ntthialrprepressure OOffe 500 to low,circ c pr0 PSI re ie 9,864.0 65.0 18:42 21:48 Circulation and downhole differential pressure.Unable to drill.Trip for BHA damage of possible pin hole in CT. 2/3/2017 2/3/2017 2.00 PROD2 DRILL PULD T PJSM,PUD BHA#18 65.0 0.0 21:48 23:48 2/3/2017 2/4/2017 0.20 PROD2 DRILL CTOP T instator pection on of s aorge ercBHA compo gets 0.0 23:48 00:00 reveals no damage 2/4/2017 2/4/2017 0.40 PROD2 DRILL CTOP T Continue full visul inspection of BHA. 0.0 0.0 00:00 00:24 Bit @ 1-1.Motor is tight and holds fluid 2/4/2017 2/4/2017 2.00 PROD2 DRILL PULD T re/run Hyc b ce ter bit, FT motor and 0.0 80.8 00:24 02:24 deploy.M/U to coil and surface test 2/4/2017 2/4/2017 1.70 PROD2 DRILL TRIP T Trip in hole,EDC closed,surface test 80.8 7,280.0 02:24 04:06 tool.Could feel agitator working 2/4/2017 2/4/2017 0.20 PROD2 DRILL DLOG T Log K1 for-11'correction.PUW=36K 7,280.0 7,311.0 04:06 04:18 _ 2/4/2017 2/4/2017 1.00 PROD2 DRILL TRIP T Co tinuecotrip in, in eight bobble @ 7,311.0 9,865.0 04:18 05:18 2/4/2017 2/4/2017 0.50 PROD2 DRILL DRLG P OBD 1 WHbpm P 127,,5790 p i, H38P 9,865.0 9,915.0 05:18 05:48 2/4/2017 2/4/2017 0.25 PROD2 DRILL WPRT P Short wiper up hole PUW 39 k 9,915.0 9,860.0 05:48 06:03 2/4/2017 2/4/2017 0.25 PROD2 DRILL WPRT P Wiper back in hole RIW 3 k 9,860.0 9,915.0 06:03 06:18 2/4/2017 2/4/2017 2.00 PROD2 DRILL DRLG P BO$D 1.69 bpmP 9,atA ,516 psi, A,BHP 9,915.0 10,075.0 06:18 08:18 2/4/2017 2/4/2017 0.25 PROD2 DRILL WPRT P Short wiper up hole PUW 54 k 10,075.0 9,975.0 08:18 08:33 2/4/2017 2/4/2017 0.25 PROD2 DRILL WPRT P Wiper back in hole RIW 3 k 9,975.0 10,075.0 08:33 08:48 2/4/2017 2/4/2017 2.10 PROD2 DRILL DRLG P B7O4BD7,WHP 30, IA 5,596 OA psi, BHP 10,075.0 10,290.0 08:48 10:54 381 2/4/2017 2/4/2017 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 42 k 10,290.0 9,250.0 10:54 11:24 2/4/2017 2/4/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole RIW 9,250.0 10,290.0 11:24 11:54 2/4/2017 2/4/2017 3.25 PROD2 DRILL DRLG P B8OBD,35. 1.60 bpm t 5350 psi,BHP 10,290.0 10,599.0 11:54 15:09 2/4/2017 2/4/2017 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 45 k 10,599.0 9,600.0 15:09 15:39 2/4/2017 2/4/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 9,600.0 10,599.0 . 15:39 16:09 2/4/2017 2/4/2017 2.10 PROD2 DRILL DRLG P BOBD 83,WHPbpmP at 5,580 690, psi, A 87P 10,599.0 10,761.0 16:09 18:15 2/4/2017 2/4/2017 0.30 PROD2 DRILL WPRT P BHA Wiper, 100',PUW=38K 10,761.0 10,761.0 18:15 18:33 2/4/2017 2/4/2017 1.60'PROD2 DRILL DRLG P 10761',Drill,1.4 BPM @ 4650 PSI 10,761.0 10,867.0 18:33 20:09 FS,BHP=3790,RIW=-8K, DHWOB=I.6K.Reduced rate and max push for DLS 2/4/2017 2/4/2017 0.20 PROD2 DRILL WPRT P BHA Wiper,PUW=45K 10,867.0 10,867.0 20:09 20:21 Page 17/20 Report Printed: 2/13/2017 • i Operations Summary (with Timelog Depths) 2T-41 ConocoPhilrps t,iska Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/4/2017 2/4/2017 0.30 PROD2 DRILL DRLG P 10867',Drill, 1.6 BPM @ 5625 PSI 10,867.0 10,891.0 20:21 20:39 FS,BHP=3830,RIW=-7K, DHWOB=1.7 2/4/2017 2/4/2017 0.50 PROD2 DRILL WPRT P Stop drilling due to collision concerns. 10,891.0 10,891.0 20:39 21:09 Consult town for plan forward. 2/4/2017 2/5/2017 2.85 PROD2 DRILL WPRT P TD called,pump 10 X 10 sweeps and 10,891.0 3,555.0 21:09 00:00 chase to swab,PUW=41 K,Midnight depth 3555 2/5/2017 2/5/2017 0.90 PROD2 DRILL WPRT P Continue asurface swab,Perform 3,555.0 65.0 00:00 00:54 2/5/2017 2/5/2017 1.40 PROD2 DRILL WPRT P Reset counters and trip in 80.3 7,280.0 00:54 02:18 2/5/2017 2/5/2017 0.20 PROD2 DRILL WPRT P Log K1 for-11,PUW=34K 7,280.0 7,298.0 02:18 02:30 2/5/2017 2/5/2017 1.70 PROD2 DRILL WPRT P t Cntinue wb down ck iwClell,Clean an down pass 7, 298.0 10,900.0 02:30 04:12 10900',Past Ll lateral.Discuss options with town.Plan forward to drill ahead 2/5/2017 2/5/2017 0.30 PROD2 DRILL DRLG P 10900',Drill,1.7 BPM @ 4800PS1 FS, 10,900.0 10,913.0 04:12 04:30 BHP=3820,RIW=8K,DHWOB=1.8. Circ pressure and differential 700PSI low.Able to drill @ 100FPH 2/5/2017 2/5/2017 0.20 PROD2 DRILL WPRT P Pull off bottom for survey,Check 10,913.0 10,913.0 04:30 04:42 pressures 2/5/2017 2/5/2017 3.50 PROD2 DRILL DRLG P B8 BO5,BD 1.6 bpm 20a t 5700 0A 0pOA g398 si,BHP 10,913.0 11,052.0 04:42 08:12 """"Note:10,922'PUH get approval for Baker Inteq to drill past 30'without a clean survey. 2/5/2017 2/5/2017 0.25 PROD2 DRILL WPRT P 100'BHA wiper up hole PUW 45 k 11,052.0 11,052.0 08:12 08:27 2/5/2017 2/5/2017 1.00 PROD2 DRILL DRLG P BOBD,1;59HP b 9, tA 694 OA ggP 11,052.0 11,128.0 08:27 09:27 3872, 2/5/2017 2/5/2017 0.50 PROD2 DRILL WPRT P 1000'wiper up hole PUW 48 k, 11,128.0 10,128.0 09:27 09:57 2/5/2017 2/5/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole RIW 5.3 k, 10,128.0 11,128.0 09:57 10:27 2/5/2017 2/5/2017 3.75 PROD2. DRILL DRLG P B83BDWHpbpm aA 8933,pOsAi, P 11,128.0 11,350.0 10:27 14:12 2/5/2017 2/5/2017 2.25 PROD2 . DRILL WPRT P TD L1-01 lateral,pump 10x10 sweep, 11,350.0 5,812.0 14:12 16:27 chase to window,perform 150'jog at the EOB,continue wiper up hole through the winidow,jet BTP jogging 2 twice.continued wiper up to the swab valves. 2/5/2017 2/5/2017 1.50 PROD2 DRILL WPRT P Notice t A pr pressure o bleed increase pressure,10000t in 5,812.0 5,812.0 16:27 17:57 psi,IA,continue POOH 2/5/2017 2/5/2017 0.20 PROD2 DRILL WPRT P Tag up,reset depth 5,812.0 80.0 17:57 18:09 2/5/2017 2/5/2017 1.70 PROD2 DRILL WPRT P Continue in well 80.0 7,280.0 18:09 19:51 2/5/2017 2/5/2017 0.20 PROD2 DRILL DLOG P Tie iUWt K1 for-12'correction, 7,280.0 7,299.0 19:51 20:03 6K 2/5/2017 2/5/2017 1.50 PROD2 DRILL WPRT P Continue in well.Clean pass through 7,299.0 11,353.0 20:03 21:33 window and to TD @ 11353 Page 18/20 Report Printed: 2/13/2017 • • Operations Summary (with Timelog Depths) l ,"Pry `` 2T-41 44 ConocoPhiilips a.l:xka Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/5/2017 2/6/2017 2.45 PROD2 DRILL TRIP P Trip out pumping g pinillfollowed 11 .0PPG ybea0ded 11,353.0 2,028.0 21:33 00:00 linercompletion fluid,Paint EOP flags @ 9000,5100' 2/6/2017 2/6/2017 0.60 PROD2 DRILL TRIP P Continue out of well 2,028.0 73.0 00:00 00:36 2/6/2017 2/6/2017 0.50 PROD2 DRILL OWFF P Perform 30 no flow rest 73.0 73.0 00:36 01:06 2/6/2017 2/6/2017 1.90 PROD2 DRILL PULD P Lay down BHA#19.Blow down and 73.0 0.0 01:06 03:00 lay down.Pull check valves in UQC, Stab on and reverse circulate 2/6/2017 2/6/2017 10.00 PROD2 DRILL BOPE P Start Full BOPE test,Test witness 0.0 0.0 03:00 13:00 waived by Brian Bixby,AOGCC.Start test with inner reel valve,inner reel iron and shell test,Replace UQS 2/6/2017 2/6/2017 0.50 PROD2 CASING PULD P Prep rig floor and PJSM for MU liner 0.0 0.0 13:00 13:30 2/6/2017 2/6/2017 4.00 COMPZ2 CASING PUTB P MU j}of L1-01 s 01 lower ler iner ner shorty segment with 55 0.0 2,284.5 13:30 17:30 deployment sleeve. 2/6/2017 2/6/2017 0.75 COMPZ2 CASING PULD P MU and surface test Coiltrak tools 2,284.5 2,284.5 17:30 18:15 2/6/2017 2/6/2017 1.25 COMPZ2 CASING RUNL P RIH,with lower liner BHA#20 2,284.5 7,495.0 18:15 19:30 2/6/2017 2/6/2017 0.25 COMPZ2 CASING RUNL P Correct to the EOP flag correction of 7,495.0 7,495.0 19:30 19:45 minus 2/6/2017 2/6/2017 0.75 COMPZ2 CASING RUNL P Continue RIH,RIW 9 k 7,495.0 9,480.0 19:45 20:30 2/6/2017 2/6/2017 0.25 COMPZ2 CASING DLOG P Log the K1 correction of plus 7.5'. 9,480.0 9,480.0 20:30 20:45 2/6/2017 2/6/2017 0.75 COMPZ2 CASING RUNL P Continue PUW 56Ik,minus set down 5 n o bottom WOB5 9,480.0 11,353.0 20:45 21:30 kset back down 11,353',bring pump up to 1.5 bpm at 3,500 psi,0.88 bpm returns,differental pressure 1,150 psi. PUW 39 k,PUH 50'and remove liner length from BHA. 2/6/2017 2/6/2017 0.70 COMPZ2 CASING TRIP P POOH 9,085.0 7,499.0 21:30 22:12 2/6/2017 2/7/2017 1.80 COMPZ2 CASING CIRC P Stop at window,MW out©10.7 7,499.0 7,499.0 22:12 00:00 circulate to get MW up to 11.0,IA=600 PSI.Loosing-12 BPH 2/7/2017 2/7/2017 0.90 COMPZ2 CASING CIRC P Continue to circ in Bleed down 1.0 getting m 600 PSI to 7,499.0 7,499.0 00:00 00:54 back.200PSI Came right back to 600.Flow check well.Pass no flow.POOH filling across top 2/7/2017 2/7/2017 1.60 COMPZ2 CASING TRIP P Trip out pumping across top,Paint 7,499.0 26.0 00:54 02:30 EOP flag @ 7300; 2/7/2017 2/7/2017 0.50 COMPZ2 CASING OWFF P At surface perform 30 Min no flow. 26.0 26.0 02:30 03:00 2/7/2017 2/7/2017 1.00 COMPZ2 CASING PULD P PJSM,Lay down BHA on dead well, 26.0 0.0 03:00 04:00 Prep rig floor for tubing ops 2/7/2017 2/7/2017 3.60 COMPZ2 CASING PUTB P PJSM,P/U L1-01 upper liner sement 0.0 1,639.8 04:00 07:36 with ported bull nose, 10'Pup,3 Jts blank,7 Jts slotted,39 Jts blank,2 Jts slotted with shorty deployment sleeve Page 19/20 Report Printed: 2/13/2017 0 S °' '`f,i,...1,,,,. . v Operations Summary (with Timelog Depths) ,., _,,,„ , ,, 2T-41 ailfips` ` 8f.r.As Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/7/2017 2/7/2017 0.80 COMPZ2 CASING PULD P PJSM, Surface test t/U coil track nd Tag upe uap to 1, 639.8 1,685.3 07:36 08:24 linerset counters 2/7/2017 2/7/2017 1.40 COMPZ2 CASING TRIP P Tripp in well,EDC shut pumping min 1,685.3 7,385.0 08:24 09:48 7,385.0 7,365.0 2/7/2017 2/7/2017 0.10 COMPZ2 CASING DLOG P Tie into flag for-20.5' 09:48 09:54 2/7/2017 2/7/2017 0.50 COMPZ2 CASING TRIP P Continue in well,clean trip through 7,365.0 8,880.0 09:54 10:24 2/7/2017 2/7/2017 0.10 COMPZ2 CASING DLOG P Log K1 for+6.5',Minus 13'overall 8,880.0 8,896.0 10:24 10:30 2/7/2017 2/7/2017 0.20 COMPZ2 CASING TRIP P Continue in45K,well,Set release from down I net 9112, 8,896.0 9,112.0 10:30 10:42 PUW=39K.PUH 2/7/2017 2/7/2017 1.50 COMPZ2 MOVE CIRC P PUHt counters circulate well bore to seawater, 9,112.0 7,450.0 10:42 12:12 2/7/2017 2/7/2017 1.50 COMPZ2 MOVE TRIP P Trip 2500'out of hole,Freeze protect from 7,450.0 35.0 12:12 13:42 2/7/2017 2/7/2017 2.30 COMPZ2 MOVE PULD P At surface,Lay down BHA#20,blow 35.0 0.0 13:42 16:00 2/7/2017 2/7/2017 2.00 COMPZ2 MOVE WWSP P PJSM,Bp Lubricator a down stack&lines,load 0.0 0.0 16:00 18:00 0.0 0.0 2/7/2017 2/7/2017 1.50 DEMOB WHDBOP MPSP P Set BPV 18:00 19:30 2/7/2017 2/8/2017 4.50 DEMOB WHDBOP RURD P Blow town TT TT,rig Iines,breakwn rnove prep deck list, n 0.0 0.0 19:30 00:00 linebegin ND BOP,freeze protect tree, continue to prepare for move. 2/8/2017 2/8/2017 2.00 DEMOB, WHDBOP RURD P Continue e cheNkDlBOPE,continue rig 0.0 0.0 00:00 02:00 t 2/8/2017 2/8/2017 2.50 DEMOB WHDBOP RURD P Stageookat sho2A-p add 1/2 Way house. 0.0 0.0 02:00 04:30 2/8/2017 2/8/2017 2.00 DEMOB MOVE MOB P Continue working rig move check list 0.0 0.0 04:30 06:30 2/8/2017 2/8/2017 0.50 DEMOB MOVE SFTY P PJSM/Planning session with NES for 0.0 0.0 06:30 07:00 move to Alpine 2/8/2017 2/9/2017 17.00 DEMOB MOVE MOB P MOB t7o Alpin00:0RIG RELEASE 0.0 0.0 07:00 00:00 Page 20/20 Report Printed: 2/13/2017 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2T Pad 2T-41L1 50-103-20675-60 Baker Hughes INTEQ Definitive Survey Report HUGHES 10 February,2017 • • ConocoPhillips WahlI ConocoPhillips Definitive Survey Report BAIICER IIWGI1E5 Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 '..Project: Kuparuk River Unit TVD Reference: 2T-41 76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad MD Reference: 2T-41 76.3+27.5 @ 103.80usft(Doyon 141) Well: 2T-41 North Reference: True Welibofae 2T-41L1 Survey Calculation Method: Minimum Curvature Design: 2T-41L1 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level 1 Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2T-41 Well Position *Ni-S 0.00 usft Northing: 5,970,077.25usft Latitude: 70°19'46.127 N +E/-W 0.00 usft Easting: 498,946.43usft Longitude: 150°0'30.762 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 76.30 usft Wellbore 2T-41L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (°j (1T) BGGM2016 1/1/2017 17.75 80.92 57,539 Design 2T-41L1 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 7,426.14 Vertical Section: Depth From(TVD) +N(S +EI-W Direction (usft) (tesrt) (nett) 1°) 27.50 0.00 0.00 180.00 2/1012017 4:14:47PM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips Ed'EAU ConocoPhillips Definitive Survey Report HUGHES -Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit ND Reference: 2T-41:76.3+27.5 @ 103.80usfl(Doyon 141) t Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Well: 2T41 North Reference: True Wellbore: 2T-41L1 Survey Calculation Method: Minimum Curvature Design: 2T-41L1 Database: EDM Alaska NSK Sandbox Survey Program Date 2/9/2017 From To Survey Survey (usft) (usft) Survey(Wellbore) TOO)N11110 Description Start Date End Date 104.27 755.05 27-41 Gyro I(2141) GYD-GC-SS Gyrodata gyro single shots 11/7/2013 791.73 3,106.62 2T41 MWD 1(2T41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/7/2013 lIl 3,184.52 3,184.52 2T-41 MIND II(2T41) INC+TREND Inclinometer+known azi trend 11/14/2013 a 3,213.03 7,175.74 2T-41 MWD 111(27-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2013 7,241.37 7,241.37 2T-41 MWD IV(2T-41) INC+TREND Inclinometer+known azi trend 12/12/2013 I7,277.22 7,426.14 2T41 MWD V(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2013 7,525.00 11,299.96 2T-41L1(2T41L1) MWD MWD-Standard 1/22/2017 1/31/2017 i Survey Map Map Vertical MD Inc Ari NDTVDSS +NIS +EI-W Northing Eastin OLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) r/100')(°I100') (ft) Survey Tool Name Annotation ' 7,426.14 43.25 350.75 5,836.08 5,732.28 -1,297.53 -2,508.18 5,968,780.21 496,438.32 1.15 1,297.53 MWD+IFR-AK-CAZ-SC(6) TIP 7,52500 44.59 351.47 5,907.29 5,803.49 -1,229.78 -2,518.77 5,968,847.95 496,427.74 1 45 1,229.78 MWD(7) KOP 7,550.10 48.16 351.50 5,924.61 5,82081 -1,211.81 -2,521.46 5,968,865.91 496,425.05 14.22 1,211.81 MWD(7) 7,580.66 6212 351.50 5,942.03 5,838.23 -1,187.07 -2,52516 5,968,890.65 496,421.36 45.68 1,187.07 MWD(7) 7,606.19 74.08 35242 5,951.53 5,84773 -1,16366 -2,528.46 5,968,914.06 496,418.06 46.97 1,163.66 MWD(7) 7,635.88 88.71 351.02 5,95596 5,852.16 -1,134.69 -2,532.68 5,968,943.03 496,41384 49.49 1,134.69 MWD(7) j 7,665.56 80.06 0.91 5,956.28 5,852.48 -1,105.12 -2534.77 5,968,97259 496,411.76 3363 1,105.12 MWD(7) 7,695.55 91.69 13.57 5,955.82 5,85202 -1,075.44 -2,53100 5,969,002.28 496,41554 42.56 1,075.44 MWD(7) 7,725.62 90.80 25.60 5,955.17 5,851.37 -1,047.16 -2,520.94 5,969,030.54 496,425.60 40.11 1,047.16 MWD(7) 7,755.40 90.18 37.37 5,954.91 5,851.11 -1,021.81 -2505.41 5,969,055.89 496,441.13 39.58 1,021.81 MWD(7) 7,785.72 91.41 48.79 5,954.49 5,850.69 -999.71 -2,484.74 5,969,077.99 496,461.80 37.88 999.71 MWD(71 7,815.43 91.87 60.78 5,953.64 5,849.84 -982.61 -2,460.52 5,969,095.08 496,486.02 40.37 982.61 MWD(7) 7,845.91 91.90 72.69 5,95263 5,848.63 -970.60 -2,432.58 5,969,107.09 496,513.95 39.05 970.60 MWD(7) 7,870.61 9209 83.40 5,951.77 5,847.97 -96550 -2,408.47 5,969,11219 496,538.06 43.34 965.50 MWD(7) ) 7,900.64 9212 91.15 5,950.66 5,846.86 -964.07 -2,378.52 5,969,113.61 496,568.02 25.79 964.07 MWD(71 7,930.58 9000 94.52 5,950.11 5,846.31 -965.55 -2,348.63 5,969,112.12 496,597.90 1330 965.55 MIND(71 ......... ._ ,....,.,. ,•,„„..,.. ,................ _-.mm...----- -„----.-..,.......o,.- „„mom.-,...-. .. .. „e ...,...,. ...........,,,... I 2/10/2017 4:14:47PM Page 3 COMPASS 5000.1 Build 74 0 • ConocoPhillips ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 2T-41:76.3+27.5 @ 103.80utS(Doyon 141) , Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 it 103.80usft(Doyon 141) . Well: 2T-41 North Reference: True j Wellbore: 2T-41L1 Survey Calculation Method: Minimum Curvature &§ Design: 2T-41L1 Database: EDM Alaska NSK Sandbox Survey MD Inc Ad ND NDSS +Nl-S +E(-W Map Map DLS Vertical (usft) (°) {°) (usft) (usft) (usft) (usft) Northing Ea sting {°N00') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,960.63 89.60 98.32 5,950.22 5,846.42 -968.91 -2,318.77 5,969,108.76 496,627.76 12.72 968.91 MWD(7) 7,990.76 89.14 102.87 5,950.55 5,846.75 -974.45 -2,289.16 5,969,103.22 496,657.36 15.18 974.45 MWD(7) 8,020.52 90.46 107.05 5,950.65 5,846.85 -982.13 -2,260.42 5,969,095.54 496,686.10 14.73 982.13 MWD(7) 8,050.40 89.85 112.69 5,950.57 5,846.77 -992.28 -2,232.33 5,969,085.38 496,714.18 18.99 992.28 MWD(7) 8,081.44 89.82 116.45 5,950.66 5,846.86 -1,005.19 -2,204.10 5,969,072.47 496,742.40 12.11 1,005.19 MWD(7) 8,110.70 nail 120.53 5,950.93 5,847.13 -1,019.14 -2,178.39 5,969,058.52 496,768.11 14.15 1,019.14 MWD(7) 8,140.21 87.39 124.46 5,951.83 5,848.03 -1,034.98 -2,153.52 5,969,042.67 496,792.98 14.53 1,034.98 MWD(7) 8,170.33 87.51 128.47 5,95317 5,849.37 -1,052.86 -2,129.33 5,969,024.79 496,817.17 13.31 1,052.86 MWD(7) I 8,200.44 86.86 132.28 5,954.65 5,850.85 -1,072.34 -2,106.42 5,969,005.31 496,840.07 12.82 1,072.34 MWD(7) 8,230.08 87.14 136.52 5,956.21 5,852.41 -1,093.04 -2,085.28 5,968,984.61 496,861.21 14.32 1,093.04 MWD(7) 8,260.75 86.90 140.50 5,957.80 5,854.00 -1,115.98 -2,064.99 5,968,961.67 496,881.49 12.98 1,115.98 MWD(7) 8,290.33 9025 140.40 5,958.54 5,854.74 -1,138.78 -2,046.16 5,968,938.87 496,900.31 11.33 1,138.78 MWD(7) 8,320.72 90.46 135.91 5,958.35 5,854.55 -1,161.41 -2,025.90 ,5,968,916.24 496,920.57 14.79 1,161.41 MWD(7) 8,350.41 88.86 134.50 5,958.52 5,854.72 -1,182.48 -2,004.98 5,968,895.17 496,941.48 7.18 1,182.48 MWD(7) 8,380.48 89.05 131.38 5,959.07 5,855.27 -1,202.96 -1,982.97 5,968,874.69 496,963.49 10.39 1,20296 MWD(7) 8,410.52 90.46 127.27 5,959.20 5,855.40 -1,221.99 -1,959.74 5,968,855.66 496,986.71 14.46 1,221.99 MWD(7) 8,440.14 91.14 124.23 5,958.79 5,854.99 -1,239.29 -1,935.71 5,968,838.35 497,010.74 10.52 1,239.29 MWD(7) 8,464.92 89.97 122.29 5,958.55 5,854.75 -1,252.88 -1,914.99 5,968,824.76 497,031.46 9.14 1,25288 MWD(7) t 8,489.95 89.94 122.83 5,958.57 5,854.77 -1,266.35 -1,893.89 5,968,811.29 497,052.55 2.16 1,266.35 MWD(7) 8,520.40 88.28 124.83 5,959.04 5,855.24 -1,283.30 -1,868.60 5,968,794.34 497,077.83 8.54 1,283.30 MWD(7) 8,550.44 91.17 127.69 5,959.18 5,855.38 -1,301.06 -1,844.39 5,968,776.57 497,102.05 13.53 1,301.06 MWD(7) 8,588.60 91.90 129.23 5,958.16 5,854.36 -1,324.79 -1,814.52 5,968,752.85 497,131.91 4.46 1,324.79 MWD(7) 8,610.88 91.60 132.60 5,957.48 5,853.68 -1,339.37 -1,797.69 5,968,738.26 497,148.73 15.18 1,339.37 MWD(7) 6,640.37 93.10 135.77 5,956.27 5,852.47 -1,359.90 -1,776.56 5,968,717.73 497,169.85 11.88 1,359.90 MWD(7) 8,670.20 93.53 139.21 5,954.55 5,850.75 -1,381.85 -1,756.44 5,968,695.78 497,189.97 11.60 1,381.85 MWD(7) 8,700.96 93.63 141.97 5,952.63 5,848.83 -1,405.57 -1,736.96 5,968,672.06 497,209.45 8.96 1,405.57 MWD(7) 1 8,730.70 93.35 145.19 5,950.81 5,847.01 -1,429.45 -1,719.33 5,968,648.18 497,227.07 10.85 1,429.45 MWD(7) 1 8,760.26 93.72 148.49 5,948.99 5,845.19 -1,454.15 -1,703.20 5,968,623.48 497,243.20 11.21 1,454.15 MWD(7) 8,791.41 94.09 15202 5,946.87 5,843.07 -1,481.13 -1,687.78 5,968,596.51 497,258.61 11.37 1,481.13 MWD(7) • 8,821.44 90.92 155.26 5,945.56 5,841.76 -1,508.00 -1,674.47 5,968,569.63 497,271.92 15.09 1,508.00 MWD(7) 8,850.78 91.38 158.34 5,944.97 5,841.17 1,53496 -1,662.91 5,966,54267 49728347 10.61 153496 MWD(7) Y102017 4:14:47PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips Definitive Survey Report BAKERHUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5(01 103.80usft(Doyon 141) Well: 2T-41 North Reference: True 16.Wellbore: 27-41L1 Survey Calculation Method: Minimum Curvature Design: 2T-41L1 Database: EDM Alaska NSK Sandbox Survey MD Glc Azi TVD TVDSS +NI-5 +El-W Map Map DLS Vertical Northing Easting Section Survey Tool Name Annotation (usft) n (°) (usft) (usft) (usk) (usit) (ft) in) (°/100') (n) 8,880.95 93.47 161.54 5,943.69 5,839.89 -1,563.27 -1,652.57 5,968,514.37 497,293.80 12.66 1,563.27 MWD(7) 8,910 90 91.54 164.63 5,942.38 5,838.58 -1,591.89 -1,643.87 5,968,485.75 497,302.50 12.16 1,591.89 MWD(7) I 8,940.92 94.46 16663 5,940.81 5,837.01 -1,620.93 -1,636.43 5,968,456.71 497,309.94 11.78 1,620.93 MWD(7) 8,971.54 95.75 169.24 5,938.09 5,834.29 -1,650.75 -1,630.06 5,968,426.89 497,316.31 9.48 1,650.75 MWD(7) 9,001.30 95.93 172.98 5,935.06 5,831.26 -1,680.00 -1,625.48 5,968,397.65 497,320.88 12.52 1,680.00 MWD(7) i 9,031.29 94.18 175.09 5,932.41 5,828.61 -1,709.70 -1,622.38 5,968,367.94 497,323.98 9.12 1,709.70 MWD(7) 9,061.06 94.03 178.45 5,930.28 5,826.48 -1,739.35 -1,620.70 5,968,338.30 497,325.64 11.27 1,739.35 MWD(7) 9,091.45 91.90 180.96 5,928.71 5,824.91 -1,769.69 -1,620.55 5,968,307.96 497,325.79 10.82 1,769.69 MWD(7) 9,120.12 91.60 184.46 5,927.83 5,824.03 -1,798.31 -1,621.90 5,968,279.35 497,324.44 12.25 1,798.31 MWD(7) 9,151.38 81.94 187.93 5,926.87 5,823.07 -1,829.37 -1,625.27 5,968,248.29 497,321.06 11.15 1,829.37 MWD(7) 9,181.03 90.58 191.10 5,926.22 5,822.42 -1,858.60 -1,630.17 5,968,219.06 497,316.16 11.63 1,858.60 MWD(7) 9,210.53 91.57 194.02 5,925.66 5,821.86 -1,887.39 -1,636.59 5,968,190.28 497,309.74 10.45 1,887.39 MWD(7) i. 9,241.60 92.21 198.40 5,924.64 5,820.84 -1,917.20 -1,645.25 5,968,160.48 497,301.07 14.24 1,917.20 MWD(7) 9,271.50 92.55 197.54 5,923.40 5,819.60 -1,945.61 -1,654.47 5,968,132.06 497,291.85 309 1,945.61 MWD(7) 9,300.76 93.69 193.60 5,921.80 5,818.00 -1,973.75 -1,662.31 5,968,103.93 497,284.01 14.00 1,973.75 MWD(7) 9,331.08 94.80 190.07 5,919.56 5,815.76 -2,003.34 -1,668.51 5,968,074.34 497,277.80 12.17 2,003.34 MWD(7) q 9,361.16 92.24 186.91 5,917.71 5,813.91 -2,033.03 -1,672.94 5,968,044.66 497,273.37 1350 2,033.03 MWD(7) 9,390.80 92.21 185.29 5,916.56 5,812.76 -2,062.48 -1,676.09 5,968,015.21 497,270.22 5.46 2,062.48 MWD(7) 9,420.51 90.92 184.88 5,915.75 5,811.95 -2,092.06 -1,678.72 5,967,985.64 497,267.58 4.56 2,092.06 MWD(7) 9,450.90 90.49 188.03 5,915.37 5,811.57 . -2,122.25 -1,682.14 5,967,955.45 497,264.16 10.46 2122.25 MWD(7) 9,481.32 88.83 189.71 5,915.55 5,811.75 -2,152.30 -1,686.83 5,967,925.40 497,259.47 7.76 2,152.30 MWD(7) 9,511.40 87.24 192.52 5,916.59 5,812.79 -2,181.80 -1,692.62 5,967,895.91 497,253.67 10.73 2,181.80 MWD(7) I9,540.72 86.65 196.06 5,918.15. 5,814.35 -2,210.17 -1,699.85 5,967,867.54 497,246,44 12.22 2,210.17 MWD(7) i 9,570.07 86.49 199.03 5,919.91 5,816.11 -2238.10 -1,708.68 5,967,839.62 497,237.61 10.12 2238.10 MWD(7) 9,600.50 86.59 201.37 5,921.74 5,817.94 -2,266.60 -1,719.17 5,967,811.12 497,227.12 768 2,266.60 MWD(7) 9,630.56 88.41 203.46 5,923.05 5,819.25 -2,294.36 -1,730.62 5,967,783.36 497,215.66 9.21 2294.36 MWD(7) f 9,660.10 90.31 205.80 5,923.38 5,819.58 -2,321.21 -1,742.93 5,967,756.52 497,203.35 10.20 2321.21 MWD(7) 9,690.29 88.34 206.03 5,923.74 5,819.94 -2,348.36 -1,756.12 5,967,729.37 497,190.16 6.57 2348.36 MWD(7) 9,720.30 87.42 205.70 5,924.85 5,821.05 -2,375.34 -1,769.20 5,967,702.39 497,177.07 3.26 2375.34 MWD(7) 9,752.34 88.86 210.19 5,925.89 5,822.09 -2,403.63 -1,784.20 5,967,674.11 497,162.07 14.71 2,403.63 MWD(7) 9.781.25 87.51 210.76 5,926.81 5,823.01 -2,428.53 -1,798.86 5,967,649.22 497,147.41 5.07 2,428.53 MWD(7) 2/10/2017 4:14:47PM Page 5 COMPASS 5000.1 Build 74 i i ConocoPhillips ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit ND Reference: 2T-41:76.3+27.5 @ 103.80us6(Doyon 141) Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Well: 2T-41 North Reference: True •€€Wellbore: 2T-41L1 Survey Calculation Method: Minimum Curvature Design: 2T-41L1 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD toe Aa( T1fD- TVDSS +N/-S +El-W NorthingEasting DLS Section Survey Tool Name Annotation tumel Ci {u5[ , (usft) (usk) (usft) (ft) (it) (1/1001 (n) 9,810.16 88.40 212.22 5,927.84 5,82404 245316 -1,813.95 5,967,624.59 497,132.32 591 2,453.16 MWD(7) 1. 9,840.26 89.69 214.14 5,928.34 5,824.54 -2,478.35 -1,830.42 5,967,599.40 497,115.85 7.68 2,478.35 MWD(7) 9,870.02 89.39 214.93 5928.58 5,824.78 -2,502.87 -1,847.29 5,967,574.89 497,098.97 2.84 2,502.87 MWD(7) 9,801.41 88.19 216.31 5,929.24 5,825.44 -2,528.38 -1,865.57 5,967,549.39 497,080.70 5.83 2528.38 MWD(7) I 9,930.28 88.09 218.53 5,930.18 5,826.38 -2,551.29 -1,883.10 5,967,526.48 497,063.16 7.69 2,551.29 MWD(7) I9,962.03 87.45 219.30 5,931.41 5,827.61 -2,575.98 -1,903.03 5,967,501.80 497,043.23 3.15 2,575.98 MWD(7) 9,990.04 85.45 220.62 5,933.15 5,829.35 -2,597.40 -1,920.98 5,967,480.38 497,025.28 8.55 2,597.40 MWD(7) k 10,019.75 85.39 222.25 5,935.52 5,831.72 -2,619.60 -1,940.58 5,967,458.18 497,005.68 5.47 2,619.60 MWD(7) 1 10,049.74 86.52 224.25 5,937.64 5,833.84 -2,641.39 -1,961.08 5,967,436.40 496,985.18 7.65 2,641.39 MWD(7) I. 10,080.09 86.68 226.69 5,939.44 5,835.64 -2,662.64 -1,982.67 5,967,415.16 496,963.58 8.04 2,662.64 MWD(7) 10,110.22 85.63 228.58 5,941.46 5,837.66 -2,682.89 -2,004.88 5,967,394.91 496,941.37 7.16 2,682.89 MWD(7) 10,140.13 85.66 230.13 5,943.73 5,839.93 -2,702.32 -2,027.51 5,967,375.48 496,818.74 5.17 2702.32 MWD(7) 10,165.14 85.54 228.85 5,945.65 5,841.85 -2,718.52 -2,046.47 5,967,359.29 496,899.78 5.13 2,718.52 MWD(7) I 10,195.16 86.40 227.05 5,947.76 5,843.96 -2,738.57 -2,068.70 5,967,339.24 496,877.55 6.63 2738.57 MWD(7) 10,225.31 88.86 225.93 5,949.00 5,845.20 -2,759.31 -2,090.55 5,967,318.51 496,855.70 8.96 2,759.31 MWD(7) 10,255.29 90.61 225.24 5,949.14 5,845.34 -2,780.29 -2,111.96 5,967,297.53 496,834.29 6.27 2,780.29 MWD(7) 10,285.34 91.90 224.12 5,948.48 5,844.68 -2,801.65 -2,133.09 5,967,276.18 496,813.16 5.68 2,801.65 MWD(7) 10,315.37 92.21 223.07 5,947.41 5,843.61 -2,823.39 -2,153.78 5,967,254.45 496,792 47 3.64 2823.39 MWD(7) 10,345.40 90.86 220.79 5,946.60 5,842.80 -2,845.72 -2,173.84 5,967,232.12 496,772.41 8.82 2845.72 MWD(7) 10,375.72 90.43 220.04 5,946.26 5,842.46 -2868.80 -2,193.49 5,967,209.04 496,752.75 2.85 2,868.80 MWD(7) 10,405.73 90.00 218.05 5,946.15 5,842.35 -2,892.11 -2212.40 5,967,185.74 496,733.85 6.78 2,892.11 MWD(7) 10,435.86 90.03 216.19 5,946.14 5,842.34 -2916.13 -2,230.58 5,967,161.72 496,715.66 6.17 2916.13 MWD(7) 10,475.92 90.86 215.06 5,945.83 5,842.03 -2948.69 -2,253.91 5,967,129.17 496,692.33 3.50 2,948.69 MWD(7) 10,505.17 88.28 210.93 5,946.05 5,842.25 -2973.22 -2269.83 5,967,104.65 496,676.40 16.65 2,873.22 MWD(7) 1 10,530.84 89.79 209.46 5,946.48 5,842.68 -2,995.40 -2,282.74 5,967,082.47 496,663.49 8.21 2995.40 MWD(7) I10,561.08 88.44 205.15 5,946.95 5,843.15 -3,022.26 -2,296.61 5,967,055.61 496,649.63 14.93 3,022.26 MWD(7) 1 10,590.68 89.33 202.40 5,947.53 5,843.73 -3,049.34 -2,308.54 5,967,028.54 496,637.69 9.76 3,049.34 MWD(7) 10,620.57 88.96 200.05 5,947.97 5,844.17 -3,077.20 -2,319.36 5,967,000.69 496,626.87 7.96 3,077.20 MWD(7) , 10,645.72 95.12 199.41 5,948.17 5,844.37 -3,100.87 -2,327.85 5,966,977.02 496,618.38 5.27 3,100.87 MWD(7) 10,676.06 92.95 199.05 5,947.36 5,843.56 -3,129.50 -2337.84 5,966,948.39 496,608.39 9.40 3,129.50 MWD(7) a 10,705.04 94.23 197.23 5,945.55 5,841.75 -3,156.99 -2,346.84 5,966,920.91 496,599.38 7.67 3,156.99 MWD(7) 2/10/2017 4:14:47PM Peg.6 COMPASS 5000.1 Build 74 • i ConocoPhillips KER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 2T-41:76.3+27.5 @ 103.80ustt(Doyon 141) Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Well: 21-41 North Reference: True Wellbore: `2T41 L1 Survey Calculation Method: Minimum Curvature Design: 2T41 L1 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W DLS (KA)`' (°) f°) (usft) (usft);. (usk) (uhft). Northing(ft) Easting Seaton Survey Toot Nanne Annotation 10,742.64 94.88 194.53 5,942.56 5,838.76 -3,193.03 -2,357.10 5,966,884.87 496,589.12 7.36 3,193.03 MWD(7) 10,780.38 91.81 191.68 5,940.36 5,836.56 -3,229.72 -2365.64 5,966,848 18 496,580.58 11.09 3,229.72 MWD(7) 10,817.05 93.07 189.53 5,938.80 5,835.00 -3,265.73 -2,372.38 5,966,812.18 496,573.83 6.79 3,265.73 MWD(7) 10,838.62 93.96 188.02 5,937.47 5,833.67 -3,287.01 -2,375.66 5,966,790.91 496,570.54 8.11 3,287.01 MWD(7) 10,868.38 92.70 187.60 5,935.74 5,831.94 -3,316.44 -2,379.70 5,966,761.48 496,566.50 4.46 3,316.44 MWD(7) 10,899.72 91.53 187.57 5,934.59 5,830.79 -3,347.48 -2383.83 5,966,730.44 496,562.37 3.73 3,347.48 MWD(7) 10,931.84 92.61 186.42 5,933.43 5,829.63 -3,379.34 -2,387.74 5,966,698.58 496,558.45 4.91 3,379.34 MWD(7) 10,959.60 91.78 187.50 5,932.36 5,828.56 -3,406.88 -2,391.10 5,966,671.05 496,555 09 4.90 3,406.88 MWD(7) 10,989.28 90.06 187.44 5,931.89 5,828.09 -3,436.30 -2,394.96 5,966,641.63 496,551.23 5.80 3,436.30 MWD(7) l 11,020.24 90.64 185.67 5,931.70 5,827.90 -3,467.06 -2,398.50 5,966,610.88 496,547.69 6.02 3,467.06 MWD(7) l 11,050.30 91.26 183.55 5,931.20 5,827.40 -3,497.01 -2,400.91 5,966,580.92 496,545.27 7.35 3,497.01 MWD(7) 11,080.30 91.20 181.90 5,930.56 5,826.76 -3,526.97 -2,402.34 5,966,550.97 496,543.84 5.50 3,526.97 MWD(7) I 11,105.30 90.61 180.75 5,930.16 5,826.36 -3,551.96 -2,402.92 5,966,525.98 496,543.26 5.17 3,551.96 MWD(7) 11,133.75 91.23 178.73 5,929.70 5,825.90 -3,580.40 -2,402.79 5,966,497.54 496,543.38 7.43 3,580.40 MWD(7) i 11,165.16 90.31 176.29 5,929.28 5,825.48 -3,611.78 -2,401.42 5,966,466.17 496,544.74 8.30 3,611.78 MWD(7) 11,190.12 90.31 174.64 5,929.15 5,825.35 -3,636.66 -2399.45 5,966,441.29 496,546.71 6.61 3,636.66 MWD(7) 11,220.33 89.88 172.21 5,929.10 5,825.30 -3,666.67 -2395.99 5,966,411.28 496,550.17 8.17 3,666.67 MWD(7) 11,249.92 90.68 170.22 5,928.95 5,825.15 -3,695.91 -2,391.47 5,966,382.05 496,554.68 7.25 3,695.91 MWD(7) 11,275.00 90.98 168.94 5,928.59 5,824.79 -3,720.57 -2,386.94 5,966,357.38 496,559 21 5.24 3,720.57 MWD(7) 11,299.96 90.49 167.75 5,928.27 5,824.47 -3,745.02 -2381.89 5,966,332.94 496,564.25 5.16 3,745.02 MWD(7) 11,357.00 90.49 167.75 5,927.78 5,823.98 -3,800.75 -2369.79 5,966,277.21 496,576.34 0.00 3,800.75 PROJECTED to TD 2110/2017 4:14:47PM Page 7 COMPASS 5000.1 Build 74 RECEry • 2 1 6 1 6 7 wan2 8 0 0 4 BAKER FEB 17 2017 PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY iocaPiAlaska,Inc. ConocoPhillips Alaska,Inc. Tom Osterkamp DATA LOGGED WELL NAME 2T-41L1 700 G Street. 2'i2.L2017 M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 5,2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhuohes.com TODAYS DATE February 15,2017 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO)1 LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-1-KIN I S #OF COPIES #OF COPIES #OF COPIES 4 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 1 1 Attn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • 0 to e— C) w CD e— CO alW N N �. 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O • N O n co 0) M 0 0 0 C0 0 N M N 0 O O) (0 O) n s V 7 0 CO (D 07 M N CO N N CO O M 0 M N 7 n 0) N C C d y n n 0 0 0 co 0) 0) O 0 0 0 _ _ _ N N N CO M , O a v 0 0 0 0 0 0 0 0 0 U _ N. a rn N E• i %) d 'd y = \o U d y o 0) ... a • 0 RECEIVED • 21 6 1 6 7 27975 FEB 15 2017 Letter of Transmittal FAWN AOGCC BAKER Date. DATA LOGGED z i� /201'7HUGHES February 10, 2017 M K BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1H-16A 1H-16AL1PB1 1H-16AL1 3H-22L1 CD in 1H-16A 216-159 27967 3H-22L1-02 3H-22L1-03PB1 CD in 3H-22L1 216-145 27970 3H-22L1-03PB2 CD in 2T-41L1 216-167 27975 3H-22L1-03 2T-41L1 2T-41L1-01 (10) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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O ^, Ni O O N) t0 V' Ci N O O NU (n Oi (D m co W N) V V 0) 0) 0) t0 C) (+) (h M 0 0) C) N N N N N N N N > m m m m m m m m m m m m o, co co m m m m cD m U .€ 1- v N Cn Cn Cn Cn Cn Cn Cn CO N Cn Cn CO Cn Cn Cn Cn (n N (n CO C Y y • : E co co CO) NO OaD NN Nm O V r o O o Co m V N V N (o _ { iC to OtoOOCoVto V CO Co m r r CN N NN N . � .QC * V O N � r co aDWCWn Cmm O orf r dr r rO mN 1O'- rm "O ir C > H L 2' N - ap C J CJ m Or D W O O)i1- 8 ` 7 J Or Si O Cto CO N O O N O CO N N 8 m (O 0) N NOd d 7 V V' cm d' m mCMm mV z,--, mV O O O O O z.,-, O O Ni O mO mO m U NNN a OT N Nr OO CD O•> d' lD (n (N WNroN ONVOO OLLrlFN CNOmOU CNO Co7OCO co ai m Oi o 0 o ui cb o o m r mCo v, o C O m p m m m mD N O O O CDN N N N co_ r.y• ' C . p C >. 2 O O O O O O O O . . ,_ ,_ ,_ .- ,_ r OO YCC o _a a) d v € co V In ,J-.?;',,ii -''- o d co , 1110 0 yoF T„ 0 • .4t-.\ 11/7„..,,\ THE STATE Alaska Oil and Gas N -i o f Conservation Commission -_ __ ALAS <:A 'it7 , -- _ 333 West Seventh Avenue k ,1.,7m111* Anchorage, Alaska 99501-3572 " `± * r GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALASV.' Fax: 907.276.7542 www.aogcc.alaska.gov Kai Starck CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-41L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-167 Surface Location: 5182' FNL, 4722' FEL, Sec. 1, T11N, R8E, UM Bottomhole Location: 3765' FNL, 1967' FEL, Sec. 11, RO8E, UM Dear Mr. Starck: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 213-146, API No. 50-103- 20675-00-00. Production should continue to be reported as a function of the original API number stated above. 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, P3cL- Cathy . Foerster Chair, Commissioner DATED this21 day of December, 2016. RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMOON DEC 0 8 2016 PERMIT TO DRILL 20 AAC 25.005 , ' 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+0 Stratigraphic Test ❑ Development-Oil ❑✓ .j Service- Winj ❑ Single Zone III, Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 8Q & 6 841,24-26se. 595a I eroU KRU 2T-41L1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11350'` TVD: 5942' ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Field/Kuparuk Oil Pool Surface: 5182'FNL,4722'FEL,Sec.1,T11N,R8E,UM ADL 0025569 ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 886'FNL,1834'FEL,Sec. 11,T11N,RO8E,UM 2667 12/12/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3765'FNL, 1967'FEL,Sec 11,T11N,RO8E, UM 2560 4 8590' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 104' •015.Distance to Nearest Well Open Surface: x-498947 y-5970077 Zone-4 • GL Elevation above MSL(ft): , • to Same Pool: 968'2T-14 16.Deviated wells: Kickoff depth: 7525' feet - 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees • Downhole: 4203 psi 6 Surface: 3632 psi • 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) 3" 2.375" 4.7# L-80 ST-L 3470' 7880' 5949' 11350' 5942' Slotted 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): 7946' 6213' None 7946' 6213' None Casing Length Size Cement Volume MD TVD Conductor/Structural 133' 16" Driven 134' 134' Surface 3197' 10-3/4" 1596 sx Class G, 194 sx Class G 3197' 2580' Intermediate 7222' 7-5/8" 276 sx Class G, 158 sx Class G,82 7222' 5685' sx Class G Liner 7947' 5-1/2" 133 sx Class G 7947' 6212' Perforation Depth MD(ft): 7368'-7408',7490'-7550' Perforation Depth TVD(ft): 5793'-5822',5882'-5925' 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 0 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ron Phillips @ 265-6312 Email Ron.L.PhillipsCa cop.com Printed Name Kai Starck Title CTD Director Signature �` Phone 263-4093 Date (2- '7- ' '6 • Commission Use Only Permit to Drill I / API Number: Permit Approval See cover letter for other j{ o — I( ?— 103—AC �, --(aO - / Z(—) � requirements. Number: 50- � �� Date: 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: Z Other:‘,66p ../-e.-.51---- �U 4 uD 12 5 f Samples req'd: Yes Nolg Mud log req'd:Yes❑ No /I-,-z v i//C` p ri'`t'i"y��5 Z P§sll, 7asures: Yes No,❑( Directional svy req'd:Yes[�No DJ Spacing exception req'd: Yes El Nod Inclination-only svy req'd:Yes❑ No✓l Post initial injection MIT req'd:Yes❑ No[P'/ <)C-z- t,`z--I2--4LL APPROVED BY Approved by: I� COMMISSIONER THE COMMISSION Date�Z -21 i l 0 9vi se 1/7112/70/113RI o IN ^ ,� Oval(2 Submit Form and Form 10-401(Revised 11/2015) ta INA the from the date of approv I(20 AAC 25.005(g)) Attachments in Duplicate • • RECEIVED ConocoPhillips DEC 0 8 Nth Alaska P.O. BOX 100360 AOGOC VV1IV ANCHORAGE,ALASKA 99510-0360 December 5, 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the Kuparuk well 2T-41 well using the coiled tubing drilling rig, Nabors CDR2-AC or Nabors CDR3-AC.✓ To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin December 20, 2016. The objective will be to drill laterals KRU 2T-41L1 and 2T- 41L1-01 targeting the Kuparuk A-sands. Attached to this application are the following documents: — 10-401 Applications for 2T-41L1 and 2T-41L1 -01 — Detailed Summary of Operations — Directional Plans for 2T-41L1 and 2T-41L1 -01 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6312. Sincerely, s'.).E/4. Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • '41,44, '6 K.uparuk CTD Laterals �NABOBS ALASKA 2T-41L1 and 2T-41L1-01 �✓11 ConocoPhillips Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 2T-41L1 and 2T-41L1-01 laterals 7 Attachment 2: Current Well Schematic for 2T-41 7 Attachment 3: Proposed Well Schematic for 2T-41L1 and 2T-41L1-01 laterals 7 Page 1 of 7 December 5, 2016 PTDApplication: 2T-41L1 & 2T-41 L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2T-41L1 and 2T-41L1-01. Both laterals will be classified as"Development-Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of the 2T-41L1 and 2T-41L1-01 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC and CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,200 psi. Using the maximum formation pressure in the area of 4203 psi in 2T-09 injector(i.e. 14.17 ppg EMW), the maximum potential surface pressure in 2T-41, assuming a gas gradient of 0.1 psi/ft, would be 3,632 1 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 2T-41 was measured to be 2,316 psi (7.7 ppg EMW) on 9/23/2014. All of the wells in the 2T-41 vicinity are between 7.3 ppg and 10.5 ppg. The combined A and C sand SBHP readings suggest pressures will be close to 7.5 ppg. The maximum downhole pressure in the 2T-41 vicinity, is the 2T-09 at 4203 psi or 14.17 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; no gas injection has been performed in this area, so low probability of encountering gas. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2T-41 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2T-41 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 December 5, 2016 PTDpplication: 2T-41L1 & 2T-41L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name Liner Details MD MD TVDSS TVDSS 2T-41L1 7880' 11,350' 5845' 5,838' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2T-41L1-01 7,520' 11,350' 5,800' 5,847' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 65 H-40 Welded 28' 134' 28' 134' 1,640 670 Surface 10-3/4" 45.5 L-80 Hydrill 563 29' 3197' 29' 2580' 5,210 2,470 Intermediate 7-5/8" 29.7 L-80 Hydrill 563 26' 7222' 26' 5685' 4,790 6,890 Production 5-1/2" 17 P-110 DWC-C 6993' 7947' 5509' 6212' 10,640 7,460 Tubing 3-1/2" 9.3 L-80 EUE 23' 6885' 23' 5426' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC or CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC or CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 ppg)✓While this mud weight will hydrostatically overbalance the reservoir pressure, overbalanced conditions will also be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg Formate completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice / Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3"Blowout Prevention Equipment Information". In the 2X-13 laterals we will target a constant BHP of 11.4 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 December 5, 2016 • PTD Application: 2T-41L1 &2T-41L1-01 Pressure at the 2T-41 Window (7525' MD, 5907' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (7.5 ppg) 2304 psi 2304 psi Mud Hydrostatic (8.6 ppg) 2641 psi 2641 psi Annular friction (i.e. ECD, 0.080 psi/ft) 602 psi 0 psi Mud + ECD Combined 3243 psi 2641 psi (no choke pressure) (overbalanced —939 psi) (overbalanced —337 psi) Target BHP at Window(11.4 ppg) 3502 psi 3502 psi Choke Pressure Required to Maintain 258psi 860 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2T-41 was originally drilled and completed in 2013 as a Kuparuk A/C-sand producer. A-sand producing 100%with C-sand 0%. The C-sand was stimulated with a fracture treatment in January 2016 resulting in the C-sand producing 19%with A-sand 81%. The primary objective of the 2T-41 laterals is to recover A-sand resources stranded post 2T-12A P&A, supported by 2T-15 and 2T-09. Nabors CDR2 or CDR3 will set a whipstock and mill a 2.80"window off the whipstock at 7525'. Two laterals will be drilled to the east of the parent well with the laterals targeting the Kuparuk A3 sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2"tubing tail. Page 4 of 7 December 5, 2016 • PTDfIication: 2T-41L1 & 2T-41L1-01 pp Pre-CTD Work 1. RU Slickline: Perform a dummy whipstock drift. 2. Prep site for Nabors CDR2-AC or CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2T-41L1 Lateral(A3 sand-East) / a. RIH and set a Baker 3-1/2"x 5-1/2"TT whipstock at 7525' MD. b. Mill 2.80"window at 7525' MD. c. Drill 3"bi-center lateral to TD of 11,350' MD. d. Run 2%" slotted liner with an aluminum billet from TD up to 7880' MD. 3. 2T-41-01 Lateral(A3 sand-East) a. Kick off of the aluminum billet at 7880' MD. b. Drill 3"bi-center lateral to TD of 11,350' MD. c. Run 2%" slotted liner from TD up into the tubing at 7520' MD. 4. Freeze protect, set BPV,ND BOPE, and RDMO Nabors CRD2-AC or CDR3-AC. Post-Rig Work 1. Pu11 BPV. 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 December 5, 2016 • PTD Application: 2T-41 L1 &2T-41L1-01 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick-line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2T-41 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 23/" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 25.005(c)(14)) • No annular injection on this well. `/ • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. / • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 December 5, 2016 PTD! lication: 2T-41L1 & 2T-41L1-01 pp 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA C 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section✓ — Distance to Nearest Property Line (measured to KPA boundary at closest point) Latera[ Name: ,:p nce; 21-41L1 8,590' 2T-41L1-01 8,590' — Distance to Nearest Well within Pool Lateral Named Distance ,;g =:Wel[ 2T-41L1 968' 2T-14 2T-41L1-01 986' 2T-14 16. Attachments Attachment 1: Directional Plans for 2T-41L1 and 2T-41L1-01 laterals. Attachment 2: Current Well Schematic for 2T-41 Attachment 3: Proposed Well Schematic for 2T-41L1 and 2T-41L1-01 laterals. Page 7 of 7 December 5, 2016 S S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2T Pad 2T-41 2T-41L1 Plan: 2T-41 L1_wp05 Standard Planning Report 02 December, 2016 r' 1 BAKER HUGHES • ConocoPhillips /Gill ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2T-41 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad North Reference: True Well: 2T-41 Survey Calculation Method: Minimum Curvature Wellbore: 2T-41L1 Design: 2T-41 L1_wp05 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 Site Kuparuk 2T Pad Site Position: Northing: 5,970,382.43 usft Latitude: 70°19'49.129 N From: Map Easting: 498,944.93 usft Longitude: 150°0'30.807 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 2T-41 Well Position +N/-S 0.00 usft Northing: 5,970,077.25 usft Latitude: 70°19'46.127 N +El-W 0.00 usft Easting: 498,946.43 usft Longitude: 150°0'30.762 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 76.30 usft Wellbore 2T-41L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 1/1/2017 17.75 80.92 57,539 Design 2T-41L1 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,426.14 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) -76.30 0.00 0.00 180.00 12/2/2016 3:57:00PM Page 2 COMPASS 5000.1 Build 74 1 • ConocoPhillips Iran ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2T-41 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 21-41:76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad North Reference: True Well: 2T-41 Survey Calculation Method: Minimum Curvature Wellbore: 2T-41L1 Design: 2T-41 L1_wp05 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (0) Target 7,426.14 43.25 350.75 5,732.28 -1,297.53 -2,508.18 0.00 0.00 0.00 0.00 7,525.00 44.59 351.47 5,803.49 -1,229.78 -2,518.77 1.45 1.36 0.73 20.70 7,550.00 48.09 351.47 5,820.75 -1,211.89 -2,521.45 14.00 14.00 0.00 0.00 7,643.13 90.00 351.47 5,853.32 -1,127.79 -2,534.07 45.00 45.00 0.00 0.00 7,880.00 92.88 98.08 5,844.75 -982.87 -2,390.52 45.00 1.21 45.01 87.00 7,980.00 92.25 105.06 5,840.28 -1,002.89 -2,292.71 7.00 -0.63 6.98 95.00 8,380.00 86.39 132.46 5,845.13 -1,193.36 -1,945.53 7.00 -1.46 6.85 102.00 8,580.00 91.23 145.60 5,849.29 -1,343.97 -1,814.76 7.00 2.42 6.57 70.00 8,980.00 92.03 173.60 5,837.69 -1,714.99 -1,676.74 7.00 0.20 7.00 88.00 9,100.00 90.55 181.87 5,834.98 -1,834.76 -1,672.01 7.00 -1.23 6.89 100.00 9,300.00 89.33 195.82 5,835.19 -2,031.89 -1,702.68 7.00 -0.61 6.97 95.00 9,500.00 89.35 209.82 5,837.52 -2,215.77 -1,780.04 7.00 0.01 7.00 90.00 9,600.00 89.35 202.82 5,838.65 -2,305.34 -1,824.35 7.00 0.00 -7.00 270.00 9,900.00 90.11 223.80 5,840.07 -2,554.65 -1,988.18 7.00 0.25 7.00 88.00 10,200.00 89.39 202.82 5,841.39 -2,803.96 -2,152.02 7.00 -0.24 -7.00 268.00 10,450.00 89.42 220.32 5,844.02 -3,016.12 -2,282.37 7.00 0.01 7.00 90.00 10,850.00 90.42 192.34 5,844.59 -3,371.08 -2,458.01 7.00 0.25 -7.00 272.00 10,950.00 90.42 199.34 5,843.86 -3,467.22 -2,485.28 7.00 0.00 7.00 90.00 11,350.00 91.31 171.35 5,837.69 -3,861.49 -2,522.15 7.00 0.22 -7.00 272.00 12/2/2016 3:57:00PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips Frill ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2T-41 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad North Reference: True Well: 2T-41 Survey Calculation Method: Minimum Curvature Wellbore: 21-41L1 Design: 2T-41 L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (0) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,426.14 43.25 350.75 5,732.28 -1,297.53 -2,508.18 1,297.53 0.00 0.00 5,968,780.21 496,438.32 TIP 7,500.00 44.25 351.29 5,785.63 -1,247.08 -2,516.15 1,247.08 1.45 20.70 5,968,830.65 496,430.36 7,525.00 44.59 351.47 5,803.49 -1,229.78 -2,518.77 1,229.78 1.45 20.31 5,968,847.95 496,427.74 KOP 7,550.00 48.09 351.47 5,820.75 -1,211.89 -2,521.45 1,211.89 14.00 0.00 5,968,865.83 496,425.06 End 14 dls,Start 45 dls 7,600.00 70.59 351.47 5,846.08 -1,169.63 -2,527.79 1,169.63 45.00 0.00 5,968,908.09 496,418.73 7,643.13 90.00 351.47 5,853.32 -1,127.79 -2,534.07 1,127.79 45.00 0.00 5,968,949.93 496,412.46 4 7,700.00 91.30 17.03 5,852.66 -1,071.55 -2,529.89 1,071.55 45.00 87.00 5,969,006.16 496,416.64 7,800.00 92.83 62.04 5,848.87 -996.43 -2,467.93 996.43 45.00 87.29 5,969,081.26 496,478.61 7,880.00 92.88 98.08 5,844.75 -982.87 -2,390.52 982.87 45.00 89.00 5,969,094.82 496,556.01 End 45 dls,Start 7 dls 7,900.00 92.75 99.48 5,843.77 -985.92 -2,370.78 985.92 7.00 95.00 5,969,091.76 496,575.75 7,980.00 92.25 105.06 5,840.28 -1,002.89 -2,292.71 1,002.89 7.00 95.07 5,969,074.78 496,653.80 6 8,000.00 91.95 106.43 5,839.55 -1,008.32 -2,273.48 1,008.32 7.00 102.00 5,969,069.35 496,673.04 8,100.00 90.48 113.28 5,837.42 -1,042.25 -2,179.50 1,042.25 7.00 102.05 5,969,035.41 496,767.00 8,200.00 89.00 120.12 5,837.87 -1,087.15 -2,090.22 1,087.15 7.00 102.20 5,968,990.50 496,856.27 8,300.00 87.54 126.97 5,840.89 -1,142.34 -2,006.96 1,142.34 7.00 102.17 5,968,935.30 496,939.51 8,380.00 86.39 132.46 5,845.13 -1,193.36 -1,945.53 1,193.36 7.00 101.96 5,968,884.28 497,000.93 7 8,400.00 86.87 133.77 5,846.31 -1,207.01 -1,930.95 1,207.01 7.00 70.00 5,968,870.63 497,015.50 8,500.00 89.29 140.35 5,849.66 -1,280.13 -1,862.91 1,280.13 7.00 69.92 5,968,797.51 497,083.52 8,580.00 91.23 145.60 5,849.29 -1,343.97 -1,814.76 1,343.97 7.00 69.70 5,968,733.67 497,131.67 8 8,600.00 91.28 147.00 5,848.86 -1,360.60 -1,803.66 1,360.60 7.00 88.00 5,968,717.03 497,142.76 8,700.00 91.51 154.00 5,846.42 -1,447.56 -1,754.46 1,447.56 7.00 88.03 5,968,630.08 497,191.94 8,800.00 91.72 161.00 5,843.59 -1,539.85 -1,716.22 1,539.85 7.00 88.20 5,968,537.80 497,230.16 8,900.00 91.90 168.00 5,840.43 -1,636.10 -1,689.52 1,636.10 7.00 88.40 5,968,441.55 497,256.85 8,980.00 92.03 173.60 5,837.69 -1,714.99 -1,676.74 1,714.99 7.00 88.62 5,968,362.66 497,269.61 9 9,000.00 91.78 174.98 5,837.02 -1,734.88 -1,674.75 1,734.88 7.00 100.00 5,968,342.77 497,271.60 9,100.00 90.55 181.87 5,834.98 -1,834.76 -1,672.01 1,834.76 7.00 100.05 5,968,242.90 497,274.33 10 9,200.00 89.94 188.84 5,834.55 -1,934.26 -1,681.34 1,934.26 7.00 95.00 5,968,143.42 497,264.99 9,300.00 89.33 195.82 5,835.19 -2,031.89 -1,702.68 2,031.89 7.00 95.03 5,968,045.80 497,243.63 11 9,400.00 89.33 202.82 5,836.36 -2,126.20 -1,735.74 2,126.20 7.00 90.00 5,967,951.51 497,210.57 9,500.00 89.35 209.82 5,837.52 -2,215.77 -1,780.04 2,215.77 7.00 89.92 5,967,861.95 497,166.25 12 9,600.00 89.35 202.82 5,838.65 -2,305.34 -1,824.35 2,305.34 7.00 -90.00 5,967,772.39 497,121.94 13 9,700.00 89.60 209.81 5,839.57 -2,394.92 -1,868.65 2,394.92 7.00 88.00 5,967,682.83 497,077.63 9,800.00 89.86 216.81 5,840.04 -2,478.44 -1,923.54 2,478.44 7.00 87.94 5,967,599.33 497,022.74 9,900.00 90.11 223.80 5,840.07 -2,554.65 -1,988.18 2,554.65 7.00 87.90 5,967,523.13 496,958.09 14 10,000.00 89.87 216.81 5,840.09 -2,630.86 -2,052.83 2,630.86 7.00 -92.00 5,967,446.94 496,893.43 10,100.00 89.63 209.81 5,840.53 -2,714.38 -2,107.71 2,714.38 7.00 -92.00 5,967,363.44 496,838.55 10,200.00 89.39 202.82 5,841.39 -2,803.96 -2,152.02 2,803.96 7.00 -91.97 5,967,273.88 496,794.24 15 12/2/2016 3:57:00PM Page 4 COMPASS 5000.1 Build 74 1 • ConocoPhillips ®® ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2T-41 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad North Reference: True Well: 2T-41 Survey Calculation Method: Minimum Curvature Wellbore: 2T-41L1 Design: 2T-41 L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 10,300.00 89.39 209.82 5,842.46 -2,893.53 -2,196.32 2,893.53 7.00 90.00 5,967,184.32 496,749.92 10,400.00 89.41 216.82 5,843.51 -2,977.04 -2,251.21 2,977.04 7.00 89.93 5,967,100.82 496,695.03 10,450.00 89.42 220.32 5,844.02 -3,016.12 -2,282.37 3,016.12 7.00 89.85 5,967,061.75 496,663.86 16 10,500.00 89.54 216.82 5,844.48 -3,055.21 -2,313.54 3,055.21 7.00 -88.00 5,967,022.67 496,632.69 10,600.00 89.79 209.82 5,845.06 -3,138.72 -2,368.44 3,138.72 7.00 -87.97 5,966,939.18 496,577.79 10,700.00 90.04 202.83 5,845.21 -3,228.29 -2,412.76 3,228.29 7.00 -87.93 5,966,849.62 496,533.46 10,800.00 90.30 195.83 5,844.91 -3,322.59 -2,445.84 3,322.59 7.00 -87.92 5,966,755.33 496,500.37 10,850.00 90.42 192.34 5,844.59 -3,371.08 -2,458.01 3,371.08 7.00 -87.94 5,966,706.85 496,488.19 17 10,900.00 90.42 195.84 5,844.22 -3,419.57 -2,470.17 3,419.57 7.00 90.00 5,966,658.37 496,476.02 10,950.00 90.42 199.34 5,843.86 -3,467.22 -2,485.28 3,467.22 7.00 90.03 5,966,610.72 496,460.91 18 11,000.00 90.54 195.84 5,843.44 -3,514.88 -2,500.38 3,514.88 7.00 -88.00 5,966,563.07 496,445.80 11,100.00 90.78 188.84 5,842.28 -3,612.50 -2,521.74 3,612.50 7.00 -88.03 5,966,465.47 496,424.44 11,200.00 91.00 181.84 5,840.73 -3,711.99 -2,531.04 3,711.99 7.00 -88.11 5,966,365.98 496,415.12 11,300.00 91.21 174.85 5,838.79 -3,811.87 -2,528.16 3,811.87 7.00 -88.22 5,966,266.12 496,417.99 11,350.00 91.31 171.35 5,837.69 -3,861.49 -2,522.15 3,861.49 7.00 -88.35 5,966,216.50 496,423.99 Planned TD at 11350.00 12/2/2016 3:57:00PM Page 5 COMPASS 5000.1 Build 74 • 0 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2T Pad 2T-41 2T-41L1 2T-41 L1_wp05 Travelling Cylinder Report 02 December, 2016 r' 1 BAKER HUGHES • • 1.7 Baker Hughes INTEQ EMI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Reference Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site Error: 0.00 usft North Reference: True Reference Well: 2T-41 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 2T-41L1 Database: OAKEDMP2 Reference Design: 2T-41 L1_wp05 Offset TVD Reference: Offset Datum Reference 2T-41L1_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,426.14 to 11,350.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,332.25 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/2/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 104.27 755.05 2T-41 Gyro 1(2T-41) GYD-GC-SS Gyrodata gyro single shots 791.73 3,106.62 2T-41 MWD I(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,184.52 3,184.52 2T-41 MWD 11(2T-41) INC+TREND Inclinometer+known azi trend 3,213.03 7,175.74 2T-41 MWD III(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,241.37 7,241.37 2T-41 MWD IV(2T-41) INC+TREND Inclinometer+known azi trend 7,277.22 7,426.14 2T-41 MWD V(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,426.14 11,350.00 2T-41L1_wp05(2T-41 L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,350.00 5,941.49 23/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2T Pad 2T-04-2T-04-2T-04 Out of range 2T-05-2T-05-2T-05 Out of range 2T-06-2T-06-2T-06 Out of range 2T-07-2T-07-2T-07 Out of range 2T-08-2T-08-2T-08 Out of range 21-08-2T-08A-2T-08A Out of range 21-08-2T-08AL1-2T-08AL1 Out of range 21-09-2T-09-2T-09 Out of range 2T-09-2T-09L1-21-09L1 Out of range 2T-09-2T-09L1-01-2T-09L1-01 Out of range 2T-10-2T-10-2T-10 Out of range 2T-10-2T-10L1-2T-10L1 Out of range 2T-10-2T-10L1-01-2T-10L1-01 Out of range 2T-10-2T-10L1-01 PB1-2T-10L1-01 PB1 Out of range 2T-11-2T-11-2T-11 Out of range 2T-12-2T-12-2T-12 8,510.97 6,600.00 29.74 4.79 25.64 Pass-Minor 1/10 2T-12-2T-12A-2T-12A 8,460.28 6,575.00 236.47 7.11 235.95 Pass-Minor 1/10 2T-13-2T-13-21-13 Out of range 2T-14-2T-14-2T-14 10,950.00 7,175.00 967.67 255.66 742.93 Pass-Major Risk 2T-15-2T-15-2T-15 Out of range 2T-16-2T-16-2T-16 Out of range 2T-17-2T-17-2T-17 Out of range 2T-18-2T-18-2T-18 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/2/2016 2:01:42PM Page 2 COMPASS 5000.1 Build 74 • • r ®,- Baker Hughes INTEQ II rd ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Reference Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Site Error: 0.00 usft North Reference: True Reference Well: 2T-41 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 2T-41L1 Database: OAKEDMP2 Reference Design: 2T-41L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2T Pad 2T-19-2T-19-2T-19 Out of range 2T-20-2T-20-2T-20 Out of range 2T-201-2T-201-2T-201 Out of range 2T-21-2T-21-2T-21 Out of range 2T-36-2T-36-2T-36 Out of range 2T-37-2T-37-2T-37 Out of range 2T-38-2T-38-2T-38 Out of range 2T-38-2T-38A-2T-38A Out of range 2T-39-2T-39-2T-39 Out of range 2T-40-21-40-2T-40 Out of range 2T-40-2T-40L1-2T-40L1 Out of range 2T-41-27-41-2T-41 7,525.00 7,525.00 0.00 1.89 -1.59 FAIL-Major Risk 2T-41-2T-41L1-01-2T-41L1-01_wp00 7,899.99 7,900.00 0.36 0.57 -0.10 FAIL-Minor 1/10 Offset Design Kuparuk 2T Pad- 2T-12-2T-12-2T-12 Offset Site Error: 0.00 soft Survey Program: 50-Copy of GYD-CT-CMS,4757-SEEKER MS Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth -FN/-..S +E1-W Hole Size Centre Distance Deviation (usft) (usft) (usft) loon) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 8,464.27 5,952.75 5,325.00 4,903.70 22.26 10.06 105.74 -826.10 -1,368.32 5 1,256.57 5.43 1,256.15 Pass-Minor 1/10 8,464.28 5,952.75 5,350.00 4,924.02 22.26 10.15 105.81 -835.42 -1,379.50 5 1,231.61 5.41 1,231.19 Pass-Minor 1/10 8,464.30 5,952.75 5,300.00 4,883.38 22.26 9.96 105.88 -816.80 -1,357.11 5 1281.53 5.44 1,281.11 Pass-Minor 1/10 8,464.31 5,952.75 5,375.00 4,944.36 22.26 10.25 105.88 -844.77 -1,390.65 5 1206.65 5.40 1,206.24 Pass-Minor 1/10 8,464.35 5,952.75 5,275.00 4,863.07 22.26 9.86 105.62 -807.52 -1,345.87 5 1,306.48 5.45 1,306.07 Pass-Minor 1/10 8,464.38 5,952.75 5,400.00 4,964.70 22.26 10.35 105.96 -854.13 -1,401.76 5 1,181.70 5.38 1,181.28 Pass-Minor 1/10 8,464.43 5,952.75 5,250.00 4,842.77 22.26 9.76 105.56 -798.27 -1,334.59 5 1,331.44 5.47 1,331.03 Pass-Minor 1/10 8,464.47 5,952.75 5,425.00 4,985.06 22.28 10.45 106.04 -863.51 -1,412.83 5 1,156.74 5.37 1,156.33 Pass-Minor 1/10 8,464.60 5,952.75 5,450.00 5,005.42 22.26 10.55 106.12 -872.91 -1,423.88 5 1,131.79 5.35 1,131.37 Pass-Minor 1/10 8,464.75 5,952.76 5,475.00 5,025.79 22.26 10.65 106.21 -882.34 -1,434.89 5 1,106.84 5.34 1,106.42 Pass-Minor 1/10 8,464.94 5,952.76 5,500.00 5,046.17 22.26 10.75 106.31 -891.78 -1,445.86 5 1,081.89 5.33 1,081.47 Pass-Minor 1/10 8,465.17 5,952.77 5,525.00 5,066.56 22.26 10.85 106.41 -901.25 -1,456.81 5 1,056.95 5.31 1,056.53 Pass-Minor 1/10 8,465.42 5,952.78 5,550.00 5,086.95 22.26 10.94 106.51 -910.74 -1,467.72 5 1,032.00 5.30 1,031.58 Pass-Minor 1/10 8,465.71 5,952.78 5,575.00 5,107.36 22.26 11.04 106.62 -920.24 -1,478.59 5 1,007.06 5.29 1,006.64 Pass-Minor 1/10 8,466.04 5,952.79 5,600.00 5,127.77 2226 11.14 106.74 -929.77 -1,489.43 5 982.12 5.27 981.70 Pass-Minor 1/10 8,466.39 5,952.80 5,625.00 5,148.19 2226 11.24 106.87 -939.32 -1,500.24 5 957.18 5.26 956.76 Pass-Minor 1/10 8,466.79 5,952.81 5,650.00 5,168.62 22.26 11.36 107.00 -948.89 -1,511.01 5 932.24 5.24 931.83 Pass-Minor 1/10 8,46724 5,952.83 5,675.00 5,189.08 22.26 11.48 107.13 -958.47 -1,521.71 5 907.31 5.23 906.89 Pass-Minor 1/10 8,467.74 5,952.84 5,700.00 5,209.58 22.26 11.60 10727 -968.06 -1,532.35 5 882.38 5.22 881.96 Pass-Minor 1/10 8,468.29 5,952.85 5,725.00 5,230.10 22.26 11.73 107.42 -977.66 -1,542.92 5 85744 5.20 857.03 Pass-Minor 1/10 8,468.89 5,952.87 5,750.00 5,250.65 2227 11.85 107.58 -987.26 -1,553.41 5 832.51 5.19 832.09 Pass-Minor 1/10 8,469.54 5,952.88 5,775.00 5,271.24 22.27 11.98 107.74 -996.88 -1,563.84 5 807.58 5.18 807.16 Pass-Minor 1/10 8,470.25 5,952.90 5,800.00 5,291.85 22.27 12.10 107.91 -1,006.51 -1,574.20 5 782.65 5.16 782.24 Pass-Minor 1/10 8,471.02 5,952.92 5,825.00 5,312.49 22.27 12.23 108.08 -1,016.15 -1,584.49 5 757.73 5.15 757.31 Pass-Minor 1/10 8,471.84 5,952.94 5,850.00 5,333.17 22.27 12.35 108.27 -1,025.80 -1,594.72 5 732.81 5.14 732.39 Pass-Minor 1/10 8,472.72 5,952.96 5,875.00 5,353.87 22.27 12.48 108.46 -1,035.46 -1,604.87 5 707.89 5.12 707.47 Pass-Minor 1/10 8,473.66 5,952.99 5,900.00 5,374.60 22.27 12.60 108.66 -1,045.13 -1,614.95 5 682.97 5.11 682.55 Pass-Minor 1/10 8,474.66 5,953.01 5,925.00 5,395.37 22.27 12.73 108.87 -1,054.81 -1,624.97 5 658.05 5.10 657.64 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/2/2016 2:01:42PM Page 3 COMPASS 5000.1 Build 74 M si • . 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[7 a (ut/}3sn OSS) (+)uuoN/(-)u;nos a O O C O N M V .17r • 0 2T-41 Proposed CTD Schematic Modified by RLP 11/23/16 IJ 3-1/2"Camco DS nipple @ 413' RKB (2.875" min ID) 16"65#H-40 shoe @ 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 134' MD 3-1/2"Camco gas lift mandrel @ 3196', 4913', 5802', 6418', 6785' RKB 10-3/4"45.5#L-80 3-1/2"HES X nipple @ 6844' RKB(2.812"min ID) shoe @ 3197' MD Baker 80-40 Seal Assembly @ 6862'MD(3"ID) Baker 80-40 PBR @ 6867' MD (3" ID) .11111.1.1 Baker Premier Packer @ 6892' MD (2.87"ID) *Mk ZXP Liner Top Packer @ 6993' MD(4.93" ID) _ _ RA Marker in 5-112" Liner @ 7244' 7-5/8"29.7#L-80 shoe @ 7222' MD _ NEW Blast Rings @ 7354' RKB (on P-110 with 50'of rings) 3-1/2"CMU Sliding Sleeve @ 7457' RKB(2.813' ID) C-sand perfs 7368' KBH-22 Anchor Seal Assembly @ 7472' MD -7408' MD EMI Baker FA-1 Packer @ 7472' MD I. 3-1/2" HES D nipple @ 7477' RKB(2.75"min ID) 11111.1 •4- KOP @ 7525' MD A-sand perfs 7490' 7550' MD 2T-41L1-01 wp01 TD @ 11,350' MD 5-1/2" 17#P-110 shoe @ 7947' MD 2T-41L1 wp05 TD @11,350' MD I.' `triKUP Pe • 2T-41 ConocoPhillips - &Wella Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) 501032067500 KUPARUK RIVER UNIT PROD 57.72 3,106.62 7,988.0 ••• Comment H28(ppm) Data Annotation End Date KB.Grd(ft) Rig Release Date DEVIATED-21.41,7/10/2018 11:55:09 AM SSSV:NIPPLE 14 3/20/2014 Last WO: 27.50 11/28/2013 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - -- - --------------Last Tag:SLM 7,660.0 7/9/2016 Rev Reason:TAG,H2S pproven 7/10/2016 HANGER;23.4-- VA];; Casing Strings iI . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(like) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 27.5 133.5 133.5 65.00 H-40 Welded Casing Desorlptlon OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Oct Depth(ND)...WULen(I...Grade Top Thread Tar/SURFACE 10 3/4 9.950 28.5 3,196.9 2,580.0 45.50 L-80 Hydril 563 Casing Description 00(ln) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WiLen(I...Grade Top Thread p, - INTERMEDIATE 75/8 6.875 25.6 7,222.2 5,684.6 29.70 L-60 Hydril 563 a. 'rarer' Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 51/2 4.692 6,992.5 7,946.5 6,212.3 17.00 P-110 DWC-C Liner Details Nominal ID Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) CONDUCTOR;27.5-133.5I 6,992.5 5,508.6 39.93 PACKER FIRM':ZXP LINER TOP PACKER w/1017IE- 4.930 BACK SLEEVE NIPPLE;413.4 7,012.3 5,523.8 39.91 NIPPLE -"RS"PACKOFF SEAL NIPPLE 4.880 7,015.1 5,526.0 39.91 HANGER "DG"FLEX LOCK LINER HANGER 4.810 �� rit. Tubing Strings Tubing Description Stang Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(15111) Grade Top Connection I I I TUBING 31/2 2.992 23.4 6,884.9 5,426.2 9.30 L-80 EUE Completion Details + Top(MB) Tap(ND)(ftKB) Top not(°) Into Des Com (In) t 23.4 23.4 0.00 HANGER FMC TUBING HANGER 3.958 I 24.1 24.1 0.00 FMC TUBING HANGER Nominal ID 57.9 57.9 0.23 XO Reducing X/04-1/2"IBTM Box X3-1/2"EUE Pin 2.992 GAS LIFT:3,192.0 { , SURFACE;28.5-3,1983- :' --- 413.4 412.6 7.09 NIPPLE CAMCO DS NIPPLE 2.875 p 6,844.2' 5,394.9 39.44 NIPPLE HES"X"NIPPLE 2.812 6,862.2 5,408.7 39.59 SEAL ASSY BAKER 80-40 PBR w/20'stroke 3.000 Tubing Description String Ma...ID(in) Top(ftKB) -Set Depth(ft..Set Depth(TVD))...Wt(16#Q Grade Top Connection - STACKER PACKER 3 1/2 2.992 6,867.2 7,473.3 5,870.3 9.20 P-110 Hydril 563 Completion Details GAS LIFT;4,912.9 -_, Top(ftKB) Top(ND)(ftKB) Top Inc(') Item Des Con, Nominal ID(ln) 6,867.2 5,412.6 39.63 PBR BAKER 80-40 PBR w/20'Stroke,Pinned WI 40,000# 3.000 Shear 6,892.4' 5,431,9 39.85 PACKER -BAKER PREMIER PACKER 659-287 2.870 GAS LIFT;5,802.1L -- 7,353.9 5,783.3 42.77 BLAST RING CARBIDE BLAST RING on 2 jts P-110 pipe(overlap C 2.992 sand perrs+5')50'of blast rings. 7,457.4 5,858.8 43.67 SLEEVE-O 3.5 CMU SLIDING SLEEVE 2.813'X'PROFILE 2.813 (OPENED 1/7/2016) GAS LIFT;6,418.2 - - 7,471.6 5,869.0 43.87 SEAL ASSY KBH-22 ANCHOR SEAL ASSY 2.990 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(tt..f Set Depth(TVD)I...Wt(lb/ft) Grade Top Cannecgan FA PACKER 4.55 3.000 7,472.0 7,479.01 5,874.4 9.20 L-80 GAS LIFT;6,785.2 Completion Details Top(ftKB) lop(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID (la) 7,472.0 5,869.3 43.87 PACKER BAKER FA-1 PRODUCTION PACKER(4.55 00 AND 3.000 NIPPLE;8,699.2 = 3.0 ID are for the Packer not the tubing.WV chooses longest section in tubing) SEAL ASSY;6,86221 _ 7,476.8' 5,872.8 43.94 NIPPLE HES 2.75"D"NIPPLE 2.750 PBR;6,8672 IL W., 7,478.1 5,673.7' 43.95 WLEG WIRELINE GUIDE SHEAR OUT SUB-(WLEG has not 2.950 xo Thread;6,690.6 been sheared open) PACKER:8,892.4 .: Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)xo Thread;6,599.8 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Cent Run Date ID(in) 7,244.3 5,701.4 40.54 Radioactive RA Tag installed in 5-1/2"liner,pin end of joint#18. 11/22/2013 Marker Perforations&Slots Shot Dens Top(ND) Btm(ND) (shoed( e Top(MB) Btm(RKB) (ftKB) (RIO) Zone Data t) Type Com I 7,368.0 7,388.0 5,793.6 5,808.2 C-4,2T-41 11/25/2013 6.0 IPERF 3 3/8 Millenum Gun,25 Gram 60 Deg Phase I 7,388.0 7,408.0 5,808.2 5,822.9 C-4,2T-41 11/25/2013 6.0 IPERF 3 3/8 Millenum Gun,25 INTERMEDIATE;25.6-7,2222-- Gram 60 Deg Phase Radioactive Marker;7,2442 7,490.0 7,510.0 5,882.3 5,896.6 A-3,2T-41 11/25/2013 6.0 IPERF 3 1/8 Millenum Gun,21 IPERF;7,368.0-7,388.0WmGram 60 Deg Phase Sand Frac;7,358.0 BLAST RING;7,353.9 --. I ) 7,510,0 7,530.0 5,896.6 5,910.9 A-3,2T-41 11/25/2013 6.0 IPERF 3 1/8 Millenum Gun,21 IPERF;7.308.0-7,408.0 Gram 60 Deg Phase Send Fret;7,388.0, I• 7,530.0 7,550.0 5,910.9 5,925.1 A-3,2T-41 11/25/2013 6.0 IPERF 31/8 Millenum Gun,21 in Gram 60 Deg Phase • Stimulations&Treatments XO Thread;7,455.9 Min Top Max Btm SLEEVE-O;7,457.4 Depth Depth Top(ND) Btto(TVD) (5K3) (ftKB) (ftKB) (ftKB) Type Date Corn r1 pr_ 7,490.0 7,550.0- 5,882.3 5,925.1 FRAC '12/12/201 "A"Sand Frac w/25#Unear/X-Linked Gel Placing SEAL ASSY;7,471.6 3 01201 LBS OF 16/20 Proppant(101%of Design) PACKER;7,472.0 ® 7,490.0 7,550.0 5,882.3 5,925.1 HPBD 9/3/2014 Pumped 5 bbls meth spear down tubing/pumped 720 Ibis sea water at 180 bbls x 4,pumped 5 bbls meth/ pumped 20 bbls freeze protect NIPPLE;7,476.8 I= 7,368.0 7,408.0 5,793.6 5,808.2 Sand Frac 1/10/2016 PERFORMED C-SAND FRACTURE TREATMENT WLEG;7,478.1 i AT 20 BPM,PLACING 47K#OF 16/20 FRAC SAND IPERF;7,490.0-7,510.0 (47%OF DESIGN).WELL SCREENED OUT ON 5 FRAC;7,490.01 PPA STAGE HP80;7,480.0 IPERF;7,510.0-7,590.0 , I. 7,368.0 7,408.0 5,808.2 5,822.9 Sand Frac 1/10/2016 PERFORMED C-SAND FRACTURE TREATMENT IPERF;7,530.0-7,550.0 , AT 20 BPM,PLACING 47K#OF 16/20 FRAC SAND (47%OF DESIGN).WELL SCREENED OUT ON 5 PPA STAGE LINER;8.992.5-7,948.5 • • 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. II! s TRANSMITTAL LETTER CHECKLIST WELL NAME: (1 , a. - 1'I I I. PTD: oZ 1Z0 /C) t Development _Service Exploratory _Stratigraphic Test Non-Conventional FIELD: K 1`/;( POOL: g,k �`V r1 XL/&&R V&C 61i 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. cc/3' I% , API No. 50- !0 3- A O(?5'- 00 - 0o. ✓ (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 0 N 1 , , , O, O ' a) Q . N 2o , a' , � S 3' 0 TD E m r c,� as =' o}12 •o vi ' o O' . L a> a a O CO 0 c , 0) ao' E Oa) 03' w a c c c 2 co , , , , 0 , 3. 3' a) -a O T to > i> a a`) 3, _c e a U _ cn a �, C O N� ` w O, 0' ;' O • a)' �, a O a n 0 0. o d' a N • - _ COo .N, 3 y1 afs- _ �; , I- O. m N O. 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