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216-168
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COC1 0 0 0 E uj> m Ce y 0 0 0 W E a O d CO CO co a) OC o c y = N •' M men ce ami V 0 a� cC LO a' O M d z a O oc 20 a 0 0 co O C c U :.~ U U U Io 2 a) o o J a) o •a N - 0 V a o a a as m I E a 0 Eo E E E E a -o 0 a'To ami ¢ d o a z W W 3 I z 0 a 0' 0 0 0 0 RECEIVED • STATE OF ALASKA • MA 0 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANN-66C 1 a.Well Status: Oil 0 Gasp SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or u 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/8/2047. 23113. 216-168/ • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 2/2/2017 50-103-20675-61-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: u- 16.Well Name and Number: Surface: 5182'FNL,4722'FEL,Sec 1,T11N,R8E, UM 2/5/2017 Z/t,f 1�- KRU 2T-41L1-01 Top of Productive Interval: 9.Ref Elevations: KB:103.8 17.Field/Pool(s): 1733'FNL, 1069'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: 3694'FNL, 1923'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 11353/5950 ' ALK 2560 TPI: x- 497321 y- 5968248 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 496467 y- 5966287 Zone-4 N/A 1583/1450 5.Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral To Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 (ft MSL) I N/A c1l Z 1 55c: , 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 wit in 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 Clagg G 2 3/8 4.6 L-80 7472 11353 5869 5950 3 Liner 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 4.5"x3.5" 7479 6892'MD/5432'ND, 6992'MD/5509'ND and SLOTTED LINER @ 7472-7543 MD and 5870-5920 ND 7472"MD/5869'ND SLOTTED LINER @ 8734-9009 MD and 5951 -5934 ND r 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. SLOTTED LINER9114-11353 MD and 5928-5950 D >;' °e NZ I--I'-3.. Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information 1:.LL DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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 -. 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 Form 10-407 Rev'sed/11/2015 Vrt._ NT NUED ON PAGE 2 Submit ORIGINIAL onl6 '6 3/4/i 7-- /z�' RBDNIS i,1, MAR 1 2017 • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 111 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 9151 5927 information, including reports,per 20 AAC 25.071. Kuparuk A 5958-, TD 11353 5950 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 report.production or well test results.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan 263-4180 Email: Mike.Callahanacop.com Printed Name: K.Starck Title: CTD Director p Signature: V � ��-- �S Phone: 263-4093 Date: 3/" (1-7 INSTRUCTIONS General: This form and t'- ;quired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • S 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) I,} I ZXP Liner Top Packer @ 6993' MD(4.93" ID) RA Marker in 5-1/2" Liner @ 7244' 7-5/8"29.7#L-80 shoe @ 7222' MD — 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 Baker FA-1 Packer @ 7472' MD 3-1/2" HES D nipple @ 7477' RKB(2.75" min ID) NOM KOP@7525' MD A-sand perfs 7490' 2T-41L1-01 wp01 7550' MD �— TD @ 11,353' MD ------------------------------------ 5-1/2" 17#P-110 shoe @ 7947' MD 2T-41L1 wp05 TD @ 11,357' MD Billet at 9173' MD KUP P OD 2T-41 L1-01 Conoc©Phitlips c, Well Attribt Max AngS D TD Alr?Skis.ltlW. Wellbore APUUWI Field Name Wellbore Status ncl C) MD( ) Act Btm(ftKB) ConocoPhillips 501032067561 KUPARUK RIVER UNIT PROD 97.39 9,290.49 11,353.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2T-41L1-01,3/7/2017 11 21 58 AM SSSV:NIPPLE 65 12/5/2016 Last WO: 27.50 11/28/2013 Varocal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason'SIDETRACT,H2S 8 GLV C/O pproven 3/6/2017 HANGER,234--+ L1 Casing Strings DIP El Casing Descript�OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Liner,All-01 Lateral 23/8 1.992 7,471.6 11,353.0 4.60 L-80 STL Liner Details air 11; Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) 7,471.6 5,869.0 43.87 Shorty Shorty Deployment Sleeve 1.920 Deployment Sleeve 9,112.7 5,928.1 91.68 Shorty Shorty Deployment Sleeve 1.920 CONDUCTOR,27.5-133.5 1 Deployment Sleeve NIPPLE,,4114 Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(lb) Date 12/12/2013 .� Proppant Designed(Ib) Proppant In Formation(lb) Date 9/3/2014 Proppant Designed(Ib) Proppant In Formation(Ib) Date I — 58,700.0 47,500.0 1/10/2016 Notes:General&Safety End Date Annotation Note. GAS LIFT,3,192.0 SURFACE;28.5-3,196.9 tz GAS LIFT,4,912.9 GAS LIFT;5,802.1 GAS LIFT;6,418.2 GAS LIFT,6,785.2 NIPPLE;6,844.2 ha a; SEAL ASSY;6,862.2, PBR;6,867.2 I XO Thread,6,890.6 PACKER;6,892.4 XO Thread,8,899.0 r. i INTERMEDIATE,25.6-7,222.2 '. Radioactive Marker;7,244.3 IPERF,7,368.0-7,388 0 BLAST RING,7,3539 Hydraulic Fracture,7,368,0 1 IPERF;7,388.0-7,4080 XO Thread,7,455.4 lit SLEEVE-O;7,457.4 SEAL ASSY;7,471 6 PACKER;7,472.0 I 11 NIPPLE,7,476.8` '..�.'. WLEG,7,478-1` I,a IPERF,7,490.0-7,5100 HPBD;7,490.01 FRAC,7,490.0 IPERF,7,510.0-7,530.0 WHIPSTOCK-MONOBORE; 7,525.0 IPERF,7,530.0-7,550.0 LINER;6,992.5-7,946.5 a Liner,Al-01 Lateral,7,471.0- 1 I 11,353.0 tit:-..: !perations Summary (with Timelogepths) _` 21-41 ccnaniiil� re ' 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 (ftKE) End Depth(ftKE)` 1/20/2017 1/20/2017 9.00 MIRU MOVE DMOB P Jack up tool house,jack up sub and 09:00 18:00 service. 1/20/2017 1/21/2017 6.00 MIRU MOVE DMOB P Get sub and service hooked to moving 18:00 00:00 trucks.Move CDR3 from 3H pad to 2T pad 1/21/2017 1/21/2017 2.50 MIRU MOVE MOB P Sub spotted 0.0 0.0 00:00 02:30 1/21/2017 1/21/2017 1.50 MIRU MOVE MOB P Pits spotted 0.0 0.0 02:30 04:00 1/21/2017 1/21/2017 5.25 MIRU MOVE RURD P Rigging up interconnect, PUTZ, 0.0 0.0 04:00 09:15 COMMS established,TT&hardlines rigged up.Tool house spotted. 1/21/2017 1/21/2017 2.74 MIRU MOVE RURD P Steam cellar,replace SSV pop-off in 0.0 0.0 09:15 11:59 cellar. Attempt to locate and install 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..Check tree bolts,Change 0.0 0.0 11:59 16:29 out riser,get RKB's.prep for BOPE test **Accept Rig at 16:30 1/21/2017 1/21/2017 2.00 MIRU WHDBOP RURD P Grease BOPS,choke manifold, MM 0.0 0.0 16:29 18:29 and R valves. Change out MP line 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 1/21/2017 1/21/2017 3.00 MIRU WHDBOP RURD P Fluid pack coil 0.0 0.0 19:05 22:05 1/21/2017 1/22/2017 1.92 MIRU WHDBOP BOPE P Test BOPE,4,200 psi high/250 psi 0.0 0.0 22:05 00:00 low/2,500 annular preventor. *Witness waived by AOGCC Inspector,Guy Cook. 1/22/2017 1/22/2017 5.50 MIRU WHDBOP BOPE P Test BOPE,4,200 psi high/250 psi 0.0 0.0 00:00 05:30 low/2,500 annular preventor. *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 1/22/2017 1/22/2017 3.00 MIRU WHDBOP MPSP P PJSM,pull BPV. 0.0 0.0 06:00 09:00 1/22/2017 1/22/2017 1.50 MIRU WHDBOP PRTS P Test PDL's,bleed off lubricator and 0.0 0.0 09:00 10:30 blow down.Blow down chokes A&B, 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 to set depth,tie into K1 75.0 7,436.0 12:45 15:57 for a-9'correction.Weight check, PUW=3K. 1/22/2017 1/22/2017 0.20 SLOT RPEQPT TRIP T Set downl l K WOB at 2.750"D- 7,436.0 7,490.0 15:57 16:09 Nipple.Attempted 0,90, 180,and 270 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 Aerations Summary (with Timelog epths) 21-41 conocoPhiHiiips 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 (EKE) 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 ' vperations Summary (with Timelog!pths) 2T-41 Cillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/23/2017 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&down,seeing motor work 7,470.0 7,470.0 15:00 15:45 close to stalls at 7478'MD 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 15:45 20:00 with town.Decision made to circulate 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 PUH after 3 bottoms up to see how 7,535.0 7,468.0 20:00 20:09 nipple area is behaving,1.3 bpm at 5.2 fpm through nipple. 1/23/2017 1/23/2017 0.15 SLOT RPEQPT TRIP T RBIH to drift nipple down to WS set 7,468.0 7,488.0 20:09 20:18 depth at 1.3 bpm.Clean 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 PUH to tie into K1 &RA tag.PUW= 7,488.0 7,250.0 20:35 20:56 36K 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 1/24/2017 1/24/2017 0.50 SLOT RPEQPT TRIP T POOH, 265.0 75.0 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,PU BHA#4,whipstock drift/ 0.0 83.0 03:00 04:42 venturi junk basket&PD.EDC open 1/24/2017 1/24/2017 1.40 SLOT RPEQPT TRIP T RIH W BHA#4,stop to downsize 83.0 6,800.0 04:42 06:06 shaker screens,taking vise fluid over the end.contin to RIH. 1/24/2017 1/24/2017 0.80 SLOT RPEQPT CTOP T Close EDC,Pumps to 1.53 bpm, 1.10 6,800.0 6,900.0 06:06 06:54 bpm returns,Wt Ck 34 k lbs, venturi past 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 tperations Summary (with Timelog Depths) 2T-41 ConocoPhillips 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 (EKE) ± End Depth(ftKB). 1/24/2017 1/24/2017 0.10 SLOT RPEQPT TRIP T Continue to RIH, 7,310.0 7,400.0 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 08:12 venturi 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 surface,bump up,space out, 72.0 0.0 17:54 19:54 handover to night tour,PJSM,PUD 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 w/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 y" !perations Summary (with Timelog Depths) 2T-41 ConocoPhillips 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,Reaming passes gettings 4s and 7,550.0 7,526.0 07:18 09:18 5s while reaming,reduced rate to 1.3 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 the K1 for a-9 correction, 7,220.0 7,290.0 16:48 17:00 closed EDC,Wt Chk,36k lbs 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 up and re-survey 7632'and 7,665.0 7,665.0 20:48 21:06 7662',DLS are running 45 to 49° 1/25/2017 1/26/2017 2.90 PROD1 DRILL DRLG P OBD, 10K CTW, 1.8 bpm,4386 psi 7,665.0 7,828.0 21:06 00:00 CT,740 psi on-btm diff., 1.4K WOB, 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 fUhr.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 Operations Summary (with Timelog Depths) k i 2T-41 t,onocoPhirHpps 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) y End Depth(ftKB) 1/26/2017 1/26/2017 0.20 PROD1 DRILL TRIP P Ran back down to CMU,slowed to 4 7,280.0 7,462.0 01:30 01:42 FPM,sat down 3.2K at 7462',micro 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 PJSM,complete PD,Check pack offs, 0.0 75.0 06:48 08:42 and upper checks. 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 rate at 1.80 bpm,RIH Wt 11 k lbs, 7,900.0 8,106.0 11:00 13:12 768 psi diff, 1.60 bpm out. OBD,CT 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,BOT unable to find a surface 7,800.0 64.0 14:24 16:18 issue,Hydraulic Orienting Tool 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 !perations Summary (with Timelog!pths) 2T-41 ConocoPhillips 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 ft/hr 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 Pull wiper#3 early,PUH,44 k lbs, 9,465.0 7,507.0 15:24 15:54 open EDC. 1/27/2017 1/27/2017 0.70 PROD1 DRILL CIRC P Pump a bottoms up,pumps off, 7,507.0 7,511.0 15:54 16:36 calibrate pressure at the window,close 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 w/weight transfer to get 9,565.0 9,565.0 18:00 18:48 started drilling 1/27/2017 1/27/2017 0.20 PROD1 DRILL WPRT P Pull 200'wiper trip up to 9360 ft, RBIH 9,565.0 9,565.0 18:48 19:00 to drill 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 ft/hr 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 ^h !perations Summary (with Timelog!pths) ,...4.t,,, 2T-41 imps 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 (ftK6) End Depth(ftK6) 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 ., ,, ,, i operations Summary (with Timelog Depths) f 2T-41 +ConocoPhitiips A�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) 1/28/2017 1/28/2017 1.00 PROD1 DRILL TRIP T Call town,discuss path forward 7,535.0 7,535.0 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 Bump up,Space out,PUD&LD BHA 72.0 0.0 12:00 14:00 #10 1/28/2017 1/28/2017 2.20 PROD1 DRILL PULD T Set motor to 0.78°AKO,PU and PD 0.0 63.0 14:00 16:12 w/EDC closed(checks not holding) BHA 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 are holding,continue 63.0 0.0 21:00 22:30 w/PUD BHA#11,inspect ERD,no 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 Trip in to 112 ft,close EDC and test, 63.0 1,150.0 23:42 00:00 shallow test good at 1.4 bpm,320 psi diff.,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 at 7535.1',w/3K at 3 7,282.5 7,535.0 01:18 01:30 FPM, 11K RIH Wt,Pick-up 35K, Page 9/20 Report Printed: 2/13/2017 !perations Summary (with Timelog 6epths) 4 a , 4 ws 2T-41 Km ConocoPhillips 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 02:42 263 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 PJSM,clear clean floor,prep for 0.0 0.0 06:18 06:30 BOPE function test,vac stack. 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, PU&PD BHA#13, ERD L1 0.0 78.0 06:48 08:48 Lateral assembly with agitator,0.5° AKO 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 Tie it to K1,-9.5'correction,close 7,265.0 7,292.0 10:24 10:36 EDC, 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 0 e 4 let ` Operations Summary (with Timelog Depths) s 21-41 GoreocoPhitlips` Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1/29/2017 1/29/2017 1.10 PROD1 DRILL DRLG P RIH Wt 3 k lbs, 1.80 bpm,CT 5160 9,919.0 9,988.0 14:30 15:36 psi,diff 1276 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 lbs, 1.77 bpm,CT 5157 9,988.0 10,063.0 16:12 16:54 psi,diff 1262 psi, 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 Long wiper to window,clean up 5.5" 10,063.0 7,560.0 16:54 18:12 section of liner PU Wt,42 klbs 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 to drill,saw 3K bobble at 8475', 7,590.0 10,063.0 18:24 19:24 back reamed lx and cleaned up, 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 Drill ahead w/marginal weight 10,063.0 10,158.0 19:24 20:48 transfer,-2.6K to-5.6K CT Wt,5260, frequent 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 Lower rate to 1.2 bpm,per Geo&DD 10,632.0 10,763.0 04:18 05:48 to build angle to 92°,drilling w/-4 to 6K CT Wt,3958 psi CT,890 psi diff, 1.1K WOB,90 ft/hr ROP. Page 11/20 Report Printed: 2/13/2017 Operations Summary (with Timelog Depths) a 2T-41 C.onoccehiHtiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End.Depth(ftKB) 1/30/2017 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,both the high gamma areas, 7,579.0 10,763.0 07:42 08:54 8445-8475'and 8650'were clean on the way in hole. 1/30/2017 1/30/2017 2.20 PROD1 DRILL DRLG P 1.71 bpm,CT 4945 psi,diff 1144 psi, 10,763.0 10,956.0 08:54 11:06 RIH Wt 4.3 k lbs,Drill with neg surface weight,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 for a 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 wiper 800',PU Wt 50 k lbs, 10,956.0 10,154.0 11:06 11:30 troubles RBIH,launch 5X5 low x high vis(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 4685 psi,diff 1050 psi 10,956.0 11,009.0 11:54 12:18 OBD,CT Wt3.4 k lbs,WOB 1.72,CT 4960 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 Load pill pit w 9 bbls of LVT mineral oil 10,990.0 10,990.0 13:06 16:12 to the back side,Let soak-20 min, 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 mineral oil,stack to-10 and pull 10,990.0 11,002.0 16:12 17:12 to 80 k 4 times.relaxing ECD to 11.1 ppg. 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 17:54 sequester LVT returns in pill pit. Start draining LVT tote into pill pit. 1/30/2017 1/30/2017 1.70 PROD1 DRILL CIRC T Add 1 tote of LVT,pump 19 bbls LVT 11,002.0 11,002.0 17:54 19:36 to bit,hold-1K CT Wt while circulating,pump 17 bbls(OH volume) out bit, 1/30/2017 1/30/2017 0.70 PROD1 DRILL OTHR T Shutdown and soak for 30 min. Cycle 11,002.0 11,002.0 19:36 20:18 coil 4X from-12K to 78K at 75 FPM. Relax pipe to-1K,pump ECD from 11.18 to 11.33 ppg. Page 12/20 Report Printed: 2/13/2017 Operations Summary (with Timelog Depths) u syr x y 2T-41 Phillips ` Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)'d 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 at 4,690 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 • • - Operations Summary (with Timelog Depths) ts4-0;,,,,, :;,,,,,, 4; * t 2T-41 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 (ftK8) End Depth(ftKS). 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 COMPZ1 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 COMPZ1 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 RIH,w/upper liner section with 12 jts 547.9 895.0 13:27 14:57 and OH Anchored billet,EDC closed, 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 ASP.:-00fi !erations Summary (with Timelog epths) z { . 2T-41 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) 2/1/2017 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 09:30 at 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 bSa ,MEINi, .. Aerations Summary (with Timelog f?pths) 2T-41 .' f t®Phitiips roc mtark.a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(Er) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS) 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 PJSM,PU/MU/PD lateral drilling 0.0 80.1 16:30 18:42 BHA#17 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 12.0 ft 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, 1.79 bpm at 4,114 psi,BHP 9,602.0 9,775.0 11:39 15:30 3567,WHP 90, IA 171,OA 368 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 BOBD 1.67 bpm at 4,551 psi,BHP 9,775.0 9,864.0 16:30 18:42 3,670,WHP 100, IA 393,OA 376 Page 16/20 Report Printed: 2/13/2017 ., 4 • i Operations Summary (with Timelog Depths) '1:12' ' ?,.4 21-41 C'orioc oPhilhps 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 Differential pressure low,circ pressure 9,864.0 65.0 18:42 21:48 low at this rate.Off-500 to 600 PSI in 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 Agitator has large crack-Through 0.0 23:48 00:00 inspection of other BHA componets 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 M/U BHA#19 with.5°WFT motor and 0.0 80.8 00:24 02:24 re run Hyc bi center bit,Pressure 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 Continue trip in,weight bobble @ 7,311.0 9,865.0 04:18 05:18 7531'continue in 2/4/2017 2/4/2017 0.50 PROD2 DRILL DRLG P OBD 1.69 bpm at 5,420 psi,BHP 9,865.0 9,915.0 05:18 05:48 3,705,WHP 127, IA 579,OA 381 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 BOBD 1.69 bpm at 5,516 psi,BHP 9,915.0 10,075.0 06:18 08:18 3758,WHP 129,IA 581,OA 381 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 BOBD, 1.62 bpm at 5,596 psi,BHP 10,075.0 10,290.0 08:48 10:54 3747,WHP 130, IA 582,OA 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 BOBD, 1.60 bpm at 5350 psi,BHP 10,290.0 10,599.0 11:54 15:09 3835,IA 622,OA 385 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 1.69 bpm at 5,580 psi,BHP 10,599.0 10,761.0 16:09 18:15 3,883,WHP 120, IA 690,OA 387 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=1.6K.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 gi :,' Operations Summary (with Timelog Depths) off, `�, , ` 2T-41 ComcoPhithps ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X - Operation MKS) End Depth(ftK6)` 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 wiper trip to swab, Perform 3,555.0 65.0 00:00 00:54 jog at surface 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 Continue back in well,Clean pass 7,298.0 10,900.0 02:30 04:12 through window,Clean down to 10900',Past L1 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 @ 4800PSI 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 BOBD 1.6 bpm at 5700 psi,BHP 10,913.0 11,052.0 04:42 08:12 3825,WHP 120,IA 850,OA 398 ****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 1.59 bpm at 5694 psi,BHP 11,052.0 11,128.0 08:27 09:27 3872,WHP 129, IA 850,OA 398 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 BOBD 1.58 bpm at 5893 psi,BHP 11,128.0 11,350.0 10:27 14:12 3835,WHP 119„ IA 895,OA 399 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 IA pressure increase to 1000 5,812.0 5,812.0 16:27 17:57 psi,attempt to bleed pressure,shut in 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 into K1 for-12'correction, 7,280.0 7,299.0 19:51 20:03 PUW=36K 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 • 4110 az ,„ ��= Operations Summary (with Timelog Depths) ` 2T-41 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase .Op Code Activity Code Time P-TX Operation (EKE) End Depth MKS) 2/5/2017 2/6/2017 2.45 PROD2 DRILL TRIP P Trip out pumping 11.0 PPG beaded 11,353.0 2,028.0 21:33 00:00 liner running pill followed by 11.0 completion 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 L1-01 lower liner segment with 55 0.0 2,284.5 13:30 17:30 jts of slotted liner and shorty 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 20.5' 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 RIH,set down on bottom 5 9,480.0 11,353.0 20:45 21:30 k,PUW 56 k,minus 5.8 k DHWOB, set 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 11.0 getting 10.7 7,499.0 7,499.0 00:00 00:54 back.Bleed down IA from 600 PSI to 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 .,,,, • Operations Summary (with Timelog Depths) x _ „, 2T-41 C®noccsPhiUUipa ,_ 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,P/U coil track and make up to 1,639.8 1,685.3 07:36 08:24 liner,Surface test tools,Tag up and set counters 2/7/2017 2/7/2017 1.40 COMPZ2 CASING TRIP P Trip in well,EDC shut pumping min 1,685.3 7,385.0 08:24 09:48 rate 2/7/2017 2/7/2017 0.10 COMPZ2 CASING DLOG P Tie into flag for-20.5' 7,385.0 7,365.0 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 window 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 in well,Set down at 9112, 8,896.0 9,112.0 10:30 10:42 PUW=45K,release from line, PUW=39K.PUH 2/7/2017 2/7/2017 1.50 COMPZ2 MOVE CIRC P PUH-circulate well bore to seawater, 9,112.0 7,450.0 10:42 12:12 reset counters 2/7/2017 2/7/2017 1.50 COMPZ2 MOVE TRIP P Trip out of hole,Freeze protect from 7,450.0 35.0 - 12:12 13:42 2500' 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 I down 2/7/2017 2/7/2017 2.00 COMPZ2 MOVE WWSP P PJSM,blow down stack&lines,load 0.0 0.0 16:00 18:00 BPV Lubricator 2/7/2017 2/7/2017 1.50 DEMOB WHDBOP MPSP P Set BPV 0.0 0.0 18:00 19:30 2/7/2017 2/8/2017 4.50 DEMOB WHDBOP RURD P Blow down TT lines,breakdown hard 0.0 0.0 19:30 00:00 lines to TT,rig move prep check list, - begin ND BOP,freeze protect tree, continue to prepare for move. 2/8/2017 2/8/2017 2.00 DEMOB WHDBOP RURD P Continue ND BOPE,continue rig 0.0 0.0 00:00 02:00 move check list 2/8/2017 2/8/2017 2.50 DEMOB WHDBOP RURD P Hook up shop and 1/2 Way house. 0.0 0.0 02:00 04:30 Stage at 2A-Pad. 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 to Alpine- RIG RELEASE 0.0 0.0 07:00 00:00 2/9/17-00:00 Page 20/20 Report Printed: 2/13/2017 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2T Pad 2T-41L1-01 50-103-20675-61 Baker Hughes INTEQ Definitive Survey Report HUGHES 10 February,2017 • • ConocoPhillips N�11 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 @ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad MD Reference: 2T-41 76.3+27.5 @ 103.80usft(Doyon 141) Well: 2T-41 North Reference: True Wellbore: 2T-41L1-01 Survey Calculation Method: Minimum Curvature Design, 2T-41L1-01 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States is Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2T-41 Well Position +N/-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-41L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (1 mal) BGGM2016 1/1/2017 17.75 80.92 57,539 Design 2T-41L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 9,151 38 Vertical Section: Depth From(TVD) eNIS -' +E/-W Direction (usft) (usft) (usft) : (°) 27.50 0.00 0.00 200.00 2/10/2017 4:19:29PM Page 2 COMPASS 5000.1 Build 74 • i ConocoPhillips 1e,- ConocoPhillips Definitive Survey Report BAKER NS LES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River unit TVD Reference: 2T-41:76.3+27.5 la 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 Wellbore: =2T-41L1-01 Survey Calculation Method: Minimum Curvature Design: 2T-41L1-01 Database: EDM Alaska NSK Sandbox Survey Program Date 2/10/017 From To Survey Survey (usft)y (usft) ,Survey(Wellbore) Tool Name Description Start Date End Date 104.27 755.05 2T-41 Gyro I(2T-41) GYD-GC-SS Gyrodata gyro single shots 11/7/2013 1 791.73 3,106.62 2T-41 MWD I(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/7/2013 3,184.52 3,184.52 2T-41 MWD II(2T-41) INC+TREND Inclinometer+known azi trend 11/14/2013 3,213.03 7,175.74 2T-41 MWD III(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSCC 12/12/2013 1 7,241.37 7,241.37 2T-41 MWD IV(2T-41) INC+TREND Inclinometer+known azi trend 12/12/2013 7,277.22 7,426.14 2T-41 MWD V(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2013 7,525.00 9,151.38 2T-41L1(2T-41L1) MWD MWD-Standard 1/22/2017 1/31/2017 9,172.00 11,303.96 2T41L1-01(2T-41L1-01) MWD MWD-Standard 2/1/2017 2/5/2017 iii Survey Varl al MD Inc Aft ND NDSB +Ni-S +El-W N in E�LrQ DtwS section Survey Tool Name Annotation iu )' C) () i>�A' (rift) (usft) (hift) in) (N) (°1100'} go 9,151.38 91.94 187.93 5,926.87 5,823.07 -1629.37 -1,625.27 5,968,248.29 497,321.06 11.15 2,274.92 MWD(7) TIP 9,172.00 91.W 191.14 5,926.34 5,822.54 -1,849.69 -1,628.69 5,968,227.97 497,317.64 16.22 2,295.19 MWD(8) KOP t. 9,200.16 91.20 191.10 5,925.80 5,822.00 -1,877.32 -1,634.12 5,968,200.35 497,312.21 0.72 2,323.01 MWD(8) 9,230.46 9211 191.30 5,924.92 5,821.12 -1,907.03 -1,640.00 5,968,170.64 497,30632 3.07 2,352.94 MWD(8) 9,262.56 95.60 191.50 5,92277 5,818.97 -1,938.42 -1,646.33 5,968,139.25 497,299.99 10.89 2384.60 MWD(8) 1 9,290.47 97.39 191.63 5,919.61 5,815.81 -1,965.59 -1,651.89 5,968,11209 497294.43 643 241203 MWD(8) 9,320.06 9729 191.68 5,915.83 5,812.03 -1,994.33 -1,657.82 5,968,083.35 497,288.50 0.38 2,441.07 MWD(8) 9,35127 95.38 186.28 5,91238 5,808.58 -2,024.96 -1,662.66 5,968,05273 497,283.66 18.25 2,471.50 MWD(8) 9,382.60 93.47 183.69 5,909.96 5,806.16 -2,056.07 -1,66537 5,968,02162 497,280.94 10.25 2,501.67 MWD(8) i 9,41511 91.35 186.06 5,908.60 5,804.80 -2,088.43 -1,668.13 5,967,989.26 497,278.17 9.78 2,533.02 MWD(8) i 9,440.27 89.42 184.98 5,908.43 5,804.63 -2113.47 -1,670.55 5,967,964.22 497,275.75 8.79 2,557.38 MWD(8) 9,470.18 87.94 183.49 5,909.12 5,80532 -2143.29 -1,672.76 5,967,934.41 497,27354 7.02 2,586.15 MWD(8) 9,500.44 88.04 188.31 5,910.18 5806.38 -2173.36 -1,67587 5,967,904.34 497,270.43 15.92 2,615.47 MWD(8) 9,530.53 87.82 189.43 5,91127 5,80747 220307 168050 5,967,874.63 497,265.79 379 264498 MWD(8) 955984 8742 19534 591248 5808682,23166 168678 5967,846.04 497,25951 2019 267399 MWD(8) 2/10/2017 4.19:29PM Page 3 COMPASS 5000.1 Build 74 • s 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: 12T-41:76.3+27.5 aQ 103.80usft(Doyon 141) Site: Kuparuk 2T Pad MD Reference: ` 2T-41:76.3+27.5 ifg 103.80usft(Doyon 141) Well: 2T-41 North Reference: True Wellbore: 27-41L1-01 Survey Calculation Method: Minimum Curvature Design: 2T-41L1-01 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +Ef-W Northing Easting OLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (R) 9,590.00 87.97 194.48 5,913.70 5,809.90 -2,260.79 -1,694.53 5,967,816.93 497,251.75 3.38 2,704.01 MWD(8) 9,61665 88.09 194.98 5,914.61 5,810.81 -2,286.54 -1,701.31 5,967,791.17 497,244.97 1.93 2,730.53 MWD(8) 9,649.53 87.58 197.81 5,915.86 5,812.06 -2,318.06 -1,710.58 5,967,759.66 497,235.70 8.74 2763.32 MWD(8) 9,680.61 86.90 199.08 5,917.35 5,813.55 -2,347.51 -1,720.40 5,967,730.22 497,225.87 4.63 2,794.35 MWD(8) 9,710.38 89.91 201.13 5,918.18 5,814.38 -2,375.45 -1,730.63 5,967,702.28 497,215.64 12.23 2824.10 MWD(8) 9,740.46 90.34 202.99 5,918.12 5,814.32 -2,403.33 -1,741.93 5,967,674.41 497,204.34 6.35 2,854.16 MWD(8) ( 9,770.31 89.79 205.31 5,918.08 5,814.28 -2,430.56 -1,754.14 5,967,647.18 497,192.13 7.99 2,883.93 MWD(8) 9,800.35 91.69 208.61 5,917.69 5,813.89 -2,457.33 -1,767.75 5,967,620.41 497,178.51 12.67 2913.74 MWD(8) 9,830.44 90.52 208.99 5,917.11 5,813.31 -2,483.69 -1,782.25 5,967,594.05 497,164.01 4.09 2,943.47 MWD(8) e 9,869.31 88.93 210.09 5,917.30 5,813.50 -2,517.51 -1,801.41 5,967,560.25 497,144.85 4.97 2,981.80 MWD(8) 9,900.50 88.80 210.48 5,917.92 5,814.12 -2,544,44 -1,817.13 5,967,533.32 497,129.12 1.32 3,012.48 MWD(8) 9,929.36 89.66 214.74 5,918.31 5,814.51 -2,568.74 -1,832.68 5,967,509.02 497,113.57 15.06 3,040.64 MWD(8) 9,961.63 90.25 215.52 5,918.33 5,814.53 -2,595.13 -1,851.25 5,967,482.64 497,095.00 303 3,071.79 MWD(8) 9,991.81 91.01 217.04 5,918.00 5,814.20 -2,619.46 -1,869.11 5,967,458.32 497,077.14 5.63 3,100.76 MWD(8) 10,019.33 90.74 219.29 5,917.58 5,813.78 -2,641.09 -1,886.11 5,967,436.69 497,060.14 8.23 3,126.90 MWD(8) 10,051.76 91.78 221.67 5,916.87 5,813.07 -2,665.75 -1,907,16 5,967,41203 497,039.09 8.01 3,157.27 MWD(8) 10,082.08 90.80 222.49 5,916.18 5,812.38 -2,688.25 -1,927.47 5,967,389.54 497,018.77 4.21 3,185.36 MWD(8) 10,111.71 92.33 226.41 5,915.37 5,811.57 -2,709.39 -1,948.21 5,967,368.41 496,998.04 1420 3,212.32 MWD(8) 10,131.64 92.09 227.82 5,914.61 5,810.81 -2,722.94 -1,962.80 5,967,354.86 496,983.44 7.17 3,230.04 MWD(8) t 10,161.60 90.74 228.28 5,913.87 5,810.07 -2,742.96 -1,985.07 5,967,334.84 496,961.17 4.76 3,256.47 MWD(8) q 10,191.94 89.75 229.43 5,913.74 5,809,94 -2,762.92 -2007.92 5,967,314.89 496,938.32 5.00 3,283.05 MWD(8) 10,222.79 88.34 230.04 5,914.25 5,810.45 -2,782.86 -2,031.46 5,967,294.95 496,914.79 4.98 3,309.83 MWD(8) 10,262.00 89.36 227.04 5,915.04 5,811.24 -2,808.81 -2,060.83 5,967,269.01 496,885.41 8.08 3,344.26 MWD(8) 10,290.63 89.97 226.37 5,915.20 5,811.40 -2,828.44 -2,081.67 5,967,249.38 496,864.57 3.16 3,369.84 MWD(8) 10,314.47 90.15 224.62 5,915.18 5,811.38 -2,845.15 -2098.67 5,967,232.68 496,847.57 7.38 3,391.36 MWD(8) 10,342.30 69.05 223.34 5,915.37 5,811.57 -2,865.18 -2,117.99 5,967,212,65 496,828.24 6.06 3,416.78 MWD(8) 10,371.45 68.87 221.91 5,915.90 5,812.10 -2,886.62 -2,137.73 5,967,191.22 496,808.51 4.94 3,443.69 MWD(8) s 10,401.36 89.23 220.76 5,916.40 5,812.60 -2909.08 -2,157.48 5,967,168.77 496,788.75 4.03 3,471.54 MWD(8) 10,430.07 88.80 217.97 5,916.89 5,813.09 -2,931.27 -2175.69 5,967,146.58 496,770.55 9.83 3,498.62 MWD(8) 10,471.45 89.48 215.09 5,917.51 5,813.71 -2,964.51 -2,200.31 5,967,113.34 496,745.92 7.15 3,538.28 MWD(8) 10,501.51 8985 214.14 591769 5,813.89 298925 221739 596708861 496,728.84 3.39 3,567.37 MWD(8) 2/10/1017 4:19:29PM Page 4 COMPASS 5000.1 Build 74 • III ConocoPhillips ConocoPhillips Definitive Survey Report BAKE 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) Site: Kuparuk 2T Pad MD Reference: 2T-41:76.3+27.5 @ 103.80usft(Doyon 141) Well; 2T-41 North Reference: True i Wellbore: 2T-41L1-01 Survey Calculation Method: Minimum Curvature Design: 2T-41L1-01 Database: EDM Alaska NSK Sandbox Survey '. . Map Map Vertical ', MD Inc Azi TVD TVDSS +N0-S .E/-W DLS Northing Casting Section Survey Tool Name Annotation (usnl (°) (°I (usft) (usft) (asft) (ustt) (n) (n! (°noo•) (rt) 10,531 48 88.89 212.88 5,918 02 5,814.22 -3014.24 -2233.93 5,967,063.63 496,712.30 5.29 3,596.51 MWD(8) 10,561 84 89.32 211.09 5,918.49 5,814.69 -3,039.98 -2,250.01 5,967,037.89 496,696.22 6.06 3,626.20 MWD(8) 10,591.66 89.08 210.08 5,918.91 5,815.11 -3,065.65 -2,265.18 5,967,012.22 496,681.04 3.48 3,655.51 MWD(8) 10,621.50 87.05 208.83 5,919.92 5,816.12 -3,091.62 -2,279.85 5,966,986.26 496,666.38 7.99 3,684.92 MWD(8) 10,650.85 85.48 205.32 5,921.83 5,818.03 -0117.69 -2,293.18 5,966,960.19 496,653.05 13.08 3,713.98 MWD(8) 10,682.81 87.79 204.69 5,923.71 5,819.91 -3,146.60 -2,306.66 5,966,931.29 496,639.56 7.49 3,745.76 MWD(8) 10711.96 88.16 203.97 5,924.74 5,820.84 -3,173.15 -2,318.66 5,966,904.75 496,627.55 2.78 3,774.81 MWD(8) 10,741.00 87.54 199.65 5,925.83 5,822.03 -3,200,08 -2,329.44 5,966,877.81 496,616.77 15.02 3,803.81 MWD(8) 10,770.21 86.53 199.73 5,927.34 5,823.54 -3,227.55 -2,339.27 5,966,850.35 496,606.94 3.47 3,832.98 MWD(8) 10,800.70 86.55 203.60 5,929.18 5,825.38 -3,255.83 -2,350.50 5,966,822.08 496,595.70 12.67 3,863.40 MWD(8) 10,830.94 86.22 199.88 5,931.08 5,827.28 -3,283.85 -2,361.68 5,966,794.05 496,584.52 12.33 3,893.56 MWD(8) 10,844.60 86.19 198.99 5,931.99 5,82019 -3,296.71 -2366.22 5,966,781.20 496,579.99 6.50 3,907.19 MWD(8) 10,875.66 87.76 198.02 5,933.63 5,829.83 -3,326.12 -2,376.06 5,966,751.80 496,570.14 5.94 3,938.19 MWD(8) 10,908.18 88.04 197.96 5,934.82 5,831.02 3,357.03 -2,386.10 5,966,720.89 496,560.10 0.88 3,970.67 MWD(8) 10,940.19 85.42 199.31 5,936.65 5,832.85 -3,387.31 -2,396.31 5,966,690.62 496,549.89 9.20 4,002.61 MWD(8) 10,970.31 85.14 196.32 5,939.12 5,835.32 3,415.88 -2,405.49 5,966,662.04 496,540.70 9.94 4,032.61 MWD(8) 10,999.86 87.12 194.83 5,941.12 5,837.32 -3,444.28 -2,413.41 5,966,633.65 496,532.78 8.38 4,062.00 MWD(8) 1 11,030.08 87.33 193.41 5,942.58 5,838.78 -3,473.55 -2,420.77 5,966,604.38 496,525.42 4.74 4,092.02 MWD(8) 11,059.90 89.14 193.68 5,943.50 5,839.70 -3,502.53 -2,427.75 5,966,575.41 496,518.43 6.14 4,121.64 MWD(8) 11,090.48 90.34 192.73 5,943.64 5,839.84 -3,532.30 -2,434.73 5,966,545.65 496,511.44 5.00 4,152.00 MWD(8) g 11,120.36 90.83 191.86 5,943.33 5,839.53 -3,561.49 -2441.10 5,966,516.46 496,505.08 3.34 4,181.61 MWD(8) $ 11,149.98 90.31 192.46 5,943.04 5,839.24 -3,590.45 -2,447.34 5,966,487.51 496,498.83 2.68 4,210.95 MWD(8) 11,180.36 88.01 192.87 5,943.48 5,839.68 -3,620.08 -2,454.00 5,966,457,87 496,492.17 7.69 4,241.08 MWD(8) `t 11,210.35 87.48 190.30 5,944.66 5,840.86 -3,649.44 -2,460.01 5,966,428.52 496,486.15 8.74 4,270.72 MWD(8) t j 11,239.68 87.67 189.14 5,945.91 5,842.11 3,678.32 -2,464.96 5,966,399.65 496,481.20 4.00 4,299.55 MWD(8) 1 11,27076 87.52 188.17 5,947.46 5,843.66 -3,714.94 -2,470.54 5,966,363.02 496,475.62 2.64 4,335.88 MWD(8) 11,303.96 88.62 186.14 5,948.38 5,844.58 3,741.91 -2,473.92 5,966,336.06 496,472.23 048 4,362.38 MWD(8) 11,353.00 88.62 186.14 5,949 56 5,845.76 3,790.66 -2479.16 5,966,287.32 496,466.98 0.00 4,409.98 PROJECTED to TD 21102017 4:19:29PM Page 5 COMPASS 5000.1 Build 74 '•y VHF ?At 1cQ y4• • THE STATE Alaska Oil and Gas ti� ufA LAsKA Conservation Commission it 1i}£ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ri Main: 907.279.1433 SFA .S' Fax: 907.276.7542 www.aogcc.alaska.gov March 7, 2017 Mr. Shon Robinson Manager, Drilling & Wells ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-004 Notice of Violation—Closeout Failure to Test BOPE Nabors CDR3AC Dear Mr. Robinson: Thank you for ConocoPhillips Alaska Inc. (CPAI)'s explanation dated March 1, 2017 regarding the late test of blowout prevention equipment (BOPE) on Nabors Rig CDR3AC. The Alaska Oil and Gas Conservation Commission (AOGCC) is satisfied with corrective actions being implemented by CPAI which are intended to prevent recurrence of this noncompliance. CPAI raises a question about AOGCC's inclusion in the notice of violation that BOPE tests"must be completed at intervals to not exceed 14 days between tests." CPAI correctly notes that AOGCC has accepted BOPE tests that commence on the due date as satisfying the test interval requirements. AOGCC review of BOPE test data for rigs operating in Alaska shows that rig operations frequently commence BOPE tests during the latter hours of the due date,placing themselves at risk for a non- compliant late BOPE test. CPAI's review of the Nabors CDR3AC test indicates there were numerous opportunities to comply with testing interval requirements. AOGCC encourages CPAI rig personnel involved with BOPE testing to take advantage of testing opportunities and to be conservative in decisions so BOPE tests can be complete on the due date. The AOGCC does not intend to pursue any further enforcement action regarding this late test in Nabors CDR3AC. Sincerely, Cathy P. Foerster Chair cc: AOGCC Inspectors(via email) RECEIVE° MAR 01 2017 Shon Robinson AOGCC Manager V�d �✓ Drilling&Wells ConocoPhi Iii ps Phone 907-265-6306 Mobile 907-360-9011 Email: shon.d.robinson@cop.com March 1, 2017 Hand Delivered Commissioner Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Docket Number OTH-17-004 Notice of Violation — Failure to Test BOPE Nabors CDR3AC Kuparuk River Unit 2T-41L101 (PTD 2161680) Dear Commissioner Foerster: ConocoPhillips has received the AOGCC's Notice of Violation dated February 16, 2017 related to drilling of the KRU 2T-41L1-01 lateral (PTD #216-168) (attached). Below is a timeline of events that led up to the delayed BOPE test. 1. January 22, 0530 hrs — Nabors CDR3-AC BOPE test was completed prior to drilling 2T-41L1 (PTD #216-167). • The 14-day test interval required that the next BOPE test occur by 0000 hrs on February 6, 2017. 2. February 4, 1239 hrs — The Nabors CDR3 Rig Supervisor submitted a notification to the AOGCC Slope Inspector that a BOPE test was anticipated on February 5 at 1240 hrs. • The AOGCC Slope Inspector waived the opportunity to witness the BOPE test. 3. February 5, 1627 hrs—TD was called in 2T-41L1-01 lateral (PTD#216-168). • This was the final CTD lateral planned in 2T-41. • The rig crew performed a wiper trip to surface in preparation for laying in completion fluid and running liner. 4. February 5, 1809 hrs—The BHA reached surface from the wiper trip. • Simultaneously, the night rig crew and Rig Supervisor began their tour. • The day and night Rig Supervisors jointly assessed that they had sufficient time to trip in hole and lay in kill-weight completion brine prior to beginning the BOPE test. 5. February 6, 0036 hrs—The BHA once again reached surface after having laid in kill-weight completion brine. • The rig crew performed a 30-minute no-flow test prior to laying down the BHA and preparing for the BOPE test. 6. February 6, 0300 hrs—The BOPE pressure test began. • The test was successful with 0 failures. • The test was completed at 1300 hrs. • 7. February 6, 1153 hrs — The ConocoPhillips' CTD Superintendent informed the AOGCC via email that the BOPE test began 3 hours beyond the 14-day deadline, and that ConocoPhillips would investigate the events that led to it. The full results of our investigation are set forth in this letter. The AOGCC has requested a copy of a completed investigation report, but ConocoPhillips has no report to provide. We believe the facts are reasonably clear, and additional investigation and documentation is not necessary to improve future compliance. The core issue is that ConocoPhillips misjudged the time required to trip in hole and lay in completion brine, and we were not sufficiently conservative to be sure that the operation could be finished in time to begin the BOPE test before the deadline. ConocoPhillips has already begun implementing the following steps to prevent recurrence: • ConocoPhillips leadership has developed training material and is in the process of reviewing this material with all ConocoPhillips Alaska Drilling and Wells supervisors, clearly defining the AOGCC's timing requirements for BOPE test notification and initiation. A copy of the current draft of the training material is attached here. The material is being presented to on-site supervisors for rotary drilling, coiled tubing drilling, workover, and all through-tubing operations. In addition, ConocoPhillips' leadership will personally reiterate the importance of diligently heeding these requirements during field visits in March. The draft slides provided with this letter show the substance of the materials being provided; the slides themselves may be revised and improved over time. • ConocoPhillips will develop a BOPE Testing training module integrating information similar to the attached training materials. The BOPE Testing training module will be required periodic training for all ConocoPhillips Alaska rig supervisors and engineers. • ConocoPhillips leadership has emphasized our expectation of Alaska rig service providers and well service units that their on-site personnel likewise commit to full adherence to AOGCC BOPE test requirements. The objective is to ensure that all on-site team members feel empowered to challenge decisions that could potentially lead to operating outside of strict compliance with AOGCC BOPE test requirements. On a related issue, we note that AOGCC refers in its letter to BOPE tests being completed by the 14-day deadline. The longstanding practice of AOGCC and operators is that a test complies with the 14-day rule if it is started before the end of the 14th day, with pressure being applied to the BOPE. This practice takes into account the reality that BOPE testing times vary, depending on a variety of factors during the course of the test. ConocoPhillips regrets the error that led to late testing, and we are committed to protecting against recurrence. We are available, on request, to review this issue with the AOGCC. If AOGCC has any question you can contact me at 265-6305 or Randall Kanady at 265-4126. Sincere) , W Shon D. Robinson Manager Drilling &Wells ConocoPhillips Alaska, Inc. SDR:rbk Enclosures 2 `'or T�� THE STATE Alaska Oil and Gas \ 1%ice sA fAo LASI�:A Conservation Commission _ } St#= 333 West Seventh Avenue perrt.,=-� = Vf —1 GOVERNOR BILL WALKER Anchorage,Alaska 99501-3572 Main:907.279.1433 ACAs Fax: 907.276.7542 www.aogcc.alaska.gov February 16,2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7210 Mr. Kai Starck Coil Tubing Drilling Director ConocoPhiIlips Alaska, Inc. P. O. Box 100360 Anchorage,AK 99510-0360 Re: Docket Number: OTH-17-004 Notice of Violation—Failure to Test BOPE Nabors CDR3AC Kuparuk River Unit 2T-41L101 (PTD 2161680) Dear Mr. Starck: ConocoPhillips Alaska Inc(CPAI)recently completed development drilling operations at Kuparuk River Unit 2T-41L1-01 pursuant to Permit-to-Drill 2161680, approved on December 21, 2016. During development drilling operations testing of blowout prevention equipment(BOPE)must be completed.at intervals not to exceed 14 days between tests. Refer to 20 AAC 25.035. Failure to test BOPE within 14 days is a violation of AOGCC regulations. The BOPE test was required to be completed by February 5, 2017 and was accurately acknowledged in the test notice received from the Nabors CDR3AC representative on February 4, 2017(copy attached). An AOGCC Inspector acknowledged receipt of the planned test notice and waived witness. By email dated February 6, 2017 AOGCC was alerted that the ROPE test was scheduled to begin at "2400 on Feb 5th" but"was not started until about 0300" on February 6. The email mentions that CPAI is"investigating what events led to the late start". The test report received by AOGCC on February 7,2017 confirmed the BOPE test start time with no explanation. Within 14 days of receipt of this letter,you are requested to provide the AOGCC with what has or will be done in the future to prevent its recurrence at on CPAI operated rigs in Alaska. CPAI is also requested to provide a copy of its completed investigation report. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. • Mr.Kai Starck February 16,2017 Page 2 of 2 • Sincerely, Cathy P. oerster Chair, Commissioner Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • Question Answer Submission Date 2017-02-04 12:38:56 Type of Test Requested: ROPE Requested Time for 02-05-2017 12:40 PM I Inspection Location Nabors CDR3, Pad 2T, Well 41, Kuparuk Field Name Scott Kiser E-mail ncdr3cm@conocophillips.com IPhone Number (907) 6706050 Company ConocoPhillips Other Information: Will update 2/5/17 in the AM. 's t Address 0 • b.f.) 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(..) < (13 i(i < CU (1) 0-- 0 75 < cu -c w _c 0 C 0 D4 OIL, 0 _C I— L... U) (N CD (N 0 +.• O I i I I i 0 • *‘'\\ OF T� y*. '\\Iy/'sem THE STATE Alaska Oil and Gas Conservation Commission __` _ �, ofALASI�;A 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov February 16, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7210 Mr. Kai Starck Coil Tubing Drilling Director ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-004 Notice of Violation—Failure to Test BOPE Nabors CDR3AC Kuparuk River Unit 2T-41L101 (PTD 2161680) Dear Mr. Starck: ConocoPhillips Alaska Inc(CPAI)recently completed development drilling operations at Kuparuk River Unit 2T-41L1-01 pursuant to Permit-to-Drill 2161680, approved on December 21, 2016. During development drilling operations testing of blowout prevention equipment(BOPE)must be completed at intervals not to exceed 14 days between tests. Refer to 20 AAC 25.035. Failure to test BOPE within 14 days is a violation of AOGCC regulations. The BOPE test was required to be completed by February 5, 2017 and was accurately acknowledged in the test notice received from the Nabors CDR3AC representative on February 4, 2017 (copy attached). An AOGCC Inspector acknowledged receipt of the planned test notice and waived witness. By email dated February 6, 2017 AOGCC was alerted that the BOPE test was scheduled to begin at "2400 on Feb 5th" but "was not started until about 0300" on February 6. The email mentions that CPAI is "investigating what events led to the late start". The test report received by AOGCC on February 7,2017 confirmed the BOPE test start time with no explanation. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with what has or will be done in the future to prevent its recurrence at on CPAI operated rigs in Alaska. CPAI is also requested to provide a copy of its completed investigation report. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. 11111 i Mr.Kai Starck February 16,2017 Page 2 of 2 Sincerely, Cathy P. oerster Chair, Commissioner Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Question Answer Submission Date 2017-02-04 12:38:56 Type of Test Requested: BOPE Requested Time for 02-05-2017 12:40 PM Inspection Location Nabors CDR3, Pad 2T, Well 41, Kuparuk Field Name Scott Kiser E-mail ncdr3cm@conocophillips.com Phone Number (907) 6706050 Company ConocoPhillips Other Information: Will update 2/5/17 in the AM. Address U.S. Postal Service— CERTIFIED MAIL° RECEIPT d 1-1Domestic Mail Only rU For delivery information,visit our website at www.usps.com'5. ca Certified Mail Fee e-4 Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ ❑Return Receipt(electronic) $ Postmark O 0 Certified Mail Restricted Delivery $ Here ❑Adult Signature Required $ ❑Adult Signature Restricted Delivery$ O Postage Total Postage and Fees $ Mr. Kai Starck Ln Sent To Coil Tubing Drilling Director rg 0 Street and Apt.No.or PO Box No. ConocoPhillips Alaska, Inc. r` P.O. Box 100360 City,State,ZIP+4® Anchorage,AK 99510-0360 PS Form 3800,April 2015 PSN 753. S SENDER: COMPLETE THIS SECTION COMPLETE Tr;IS SECTION ON DELIVERY ■ Complete ur items 2,and s A. Signet /7i • Print your name and address on the reverse X /,/� Agent so that we can return the card to you. ' Addressee ■ Attach this card to the back of the mailpiece, B.�-'-ceived by, ted ame) C. Date of Delivery or on the front if space permits. 1 C o .�� � .N7/7 1, D. Is delivery address different from item 1? O Yes If YES,enter delivery address below: 0 No Mr. Kai Starck Coil Tubing Drilling Director RECEIVED ConocoPhillips Alaska, Inc. P.O. Box 100360 FEB 2 2 2017 Anchorage,AK 99510-0360 3. Service Type ' C Priority Mail Express® (I t 1 111 1 I 11111111111 I 1 I)VIII I 111111111 I'II11I III 12 Adult Signature ❑Registered Mail I ❑Adult Signature Restricted Delivery ❑Registered Mail Restricted ❑Certified Mail® Delivery 9590 9402 1823 6104 6490 13 0 Certified Mail Restricted Delivery 0 Return Receipt for ❑Collect on Delivery Merchandise 0 Collect on Delivery Restricted Delivery 0 Signature Confirmation•", 2. Artlele Number(Transfer from servire label) ;tired Mail ❑Signature Confirmation 7 015 1660 0000 1487 7210 lured Mail Restricted Delivery Restricted Delivery ,_✓er$500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • r STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regqaalaska.gov AOGCC.Inspectors a(�.alaska.gov phoebe.brooks(aialaska.gov Contractor: Nabors Rig No.: CDR3AC DATE: 2/6/17 Rig Rep.: CZ Coyne/N Wheeler Rig Phone: 670-6051 Operator: Conoco Phillips Alaska Op. Phone: 670-6050 Rep.: S Kiser/J Newell E-Mail ncdr3tp@conocophillips.com Well Name: 2T-41L1-01 PTD# 2161680 Sundry# Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Test Pressure(psi): Rams: 250/4200 Annular: 250/2500 Valves: 250/4200 MASP: 3632 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Misc. NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator P P #2 Rams 1 2"Combi P Meth Gas Detector P P #3 Rams 1 2 3/8"Combi P H2S Gas Detector P P #4 Rams 1 2 3/8"Combi P MS Misc 0 NA #5 Rams 1 Blind/Shear P #6 Rams 1 2"Combi P Quantity Test Result Choke Ln.Valves 2 2 1/16" P Inside Reel valves 1 P HCR Valves 4 2 1/16" P Kill Line Valves 7 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 2 2 1/16"M.P. P Time/Pressure Test Result System Pressure(psi) 3100 P CHOKE MANIFOLD: Pressure After Closure(psi) 2250 P Quantity Test Result 200 psi Attained(sec) 25 P No.Valves 12 P Full Pressure Attained(sec) 73 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 •P Nitgn. Bottles#&psi(Avg.): 4 X 1900 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 Test Time: 8.0 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Bleeder valve#2 and 4 falied, replaced both valves and retest, all good. LEL and H2S alarms tested.Verified flow through micromotion meter. Pit alarms tested. AOGCC Inspection 24 hr Notice Yes Date/Time 2/04/2017 12:39 Waived By Brian Bixby Test Start Date/Time: 2/6/2017 3:00 (date) (time) r Witness Test Finish Date/Time: 1/22/2017 13:00 PM 211» Form 10-424(Revised 11/2015) CDR3 2T-41 BOP Test Report 02-06-17.xlsx • • Regg, James B (DOA) From: AOGCC Inspection Request Posted At: Saturday, February 04, 2017 12:39 PM Conversation: AOGCC Inspection Request- Submission (2017-02-04 12:38:56) Posted To: AOGCC Inspection Request Subject: AOGCC Inspection Request - Submission (2017-02-04 12:38:56) Submission Date : 2017-02-04 12:38:56 IP Address : 138.32.11.66 Type of Test Requested: : BOPE Requested Time for Inspection : 02-05-2017 12:40 PM Location : Nabors CDR3, Pad 2T, Well 41, Kuparuk Field Name : Scott Kiser E-mail : ncdr3cm@conocophillips.com Phone Number : (907) 6706050 Company : ConocoPhillips Other Information: : Will update 2/5/17 in the AM. View article... 1 i Regg, James B (DOA) From: Noble, Robert C (DOA) Sent: Tuesday, February 14, 2017 9:56 AM To: Regg,James B (DOA) Subject: FW:AOGCC Test Witness Notification Request: BOPE, Nabors CDR3, Pad 2T,Well 41, Kuparuk Field Jim This is all I can find on CDR3 From: Bixby, Brian D (DOA) Sent: Sunday, February 05, 2017 7:14 AM To: Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: Re: AOGCC Test Witness Notification Request: BOPE, Nabors CDR3, Pad 2T,Well 41, Kuparuk Field Thanks for the update. Witness for this test is waived. Thanks, Brian Sent from my iPhone On Feb 5, 2017, at 6:43 AM,Nabors CDR3 Company Man <NaborsCDR3CompanyMan!,conocophillips.com> wrote: Brian, We are still drilling ahead, I can update you at 12:00 noon today as to timing of BOP test time. Perry Klein /Jim Newell Scott Kiser /Jeff Connelly Wells Supervisor Nabors CDR3-AC Company Rep. 907-670-6050 ncdr3cm@conocophillips.com From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent:Saturday, February 04, 2017 1:37 PM To: Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bav@alaska.gov> Subject: [EXTERNAL]Re: AOGCC Test Witness Notification Request: BOPE, Nabors CDR3, Pad 2T, Well 41, Kuparuk Field 1 • Yes please do update in the morning.' Thanks, Brian Sent from my iPhone On Feb 4, 2017, at 12:39 PM, Scott Kiser<noreply(aformresponse.com> wrote: Question Answer Type of Test Requested: BOPE Requested Time for 02-05-2017 12:40 PM Inspection Location Nabors CDR3, Pad 2T, Well 41, Kuparuk Field Name Scott Kiser E-mail ncdr3cm@conocophillips.com Phone Number (907) 6706050 Company ConocoPhillips Other Information: Will update 2/5/17 in the AM. 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N. n N ri ri <-1ri ri e-i ri r•1 r-+ ri .-1 .. .-1 ri ri ri ri lD N ri V Cr) m 111 00 00 NI", N lD CD VI te+ ri a-1i N O r-1i N (N N .-1 N 0 ri ri ri N O r♦ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \M 01 CYI Cf) O 0 0 O 0Hi Hi Hi Hi 0 0 0 �1 Hi Hi Hi 0 0 0 0 0 N C) F- W CL 0 m E U, fn 00LU • U U U U U U U U U U (-JO U U (-) L-) C) Q Q Q Q Q QQQ Q Q QQQ Q Q Q E m en en en M en en en M M m m M M m Cr) U) SO- CC CC a CC a: K a CC a a a a a a s a: C d N O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 i U U U U U U U U 0 U U U U 0 0 U CO In V1 L. L VI Vf V) VI V1 U, VI V)VI V)N VI V) O o 0 o o 0 o o o o 0 o o 0 o o LI f6 (0 f0 110 f6 to f0 (13 f6 f6 CO CO f6 to f6 f6 0 O) Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z F- RE CD in 216-168 2 1 6 1 6 8 CEIV�C3 2 8 0 0 5 BAKER PRINT DISTRIBUTION LIST HUGHES FEB 17 2017 Please sign and return one copy of this transmittal form to: COMPANY Q�py l+ti�f laska,Inc. ConocoPhillips Alaska, Inc. /���,J�v�� Tom Osterkamp DATA LOGGED WELL NAME 2T-41L1-01 700 G Street. M K.BEND R 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(@.bakerhughes.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)) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I*tIN I S #OF COPIES #OF COPIES #OF COPIES 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 1 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 *** 0 I 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 co • s uln T' '''o co o 'co gl Al 1 `m2 a= m 0ill 0 > I O. 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N VOOORNuOONOOOO mOOV OO O pONa N NU) NNNNN NNNN CO QNm mmm00 0 ,- ,-.. .-.. N. (SINN M N et R u 8C cc O O O O O O O O O O O O O O O O O OV p ► r _ d N 3 U 0. iA 'S o 0 • • iRECEIVED • 2 1 6 1 6 8 27976 FEB 15 2017 Letter of Transmittal AOGCC BAKER Date: DATALOGGED` / February 10, 2017 11 M.K.BENDER HUGHES 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@B akerHughes.com � � • • LO c, N ►�1_ 140m GGA " U o r 1 N V W =2 0 N 0.U Luw < CC iC t CU O o_ W Ce Q I— >, 0 ( Z a) ._ �, - _ ...E _ a� •— .., _c \ 0 _ ON. V O a) a LO _ — o cNi 0 v N p 0 '~ 6 C O ,C N r1" C ca U O a a 7 r CO C) �i V Y N CO 0 o a 0 0 0 4 :_ R _ ... x co rrrni o "Z"; Itt o co O.O t 'fit 8 a- 3 - 'gip ' ; j- °'� hi J C C > O) 7 i O O - [- y g C O I - iS 3 - I J co J U NQ Q '. 1 b a O O X NF 4 �,,. - Y, @ @m i) 4. N N Z , + + O m ' 3 M M O Y O ' N .. .. C Q a - d F, -O N N H .E W U O- m J ^ a N M . N N 3 O mo rn ' �� ..C c = o m MQ O _ _ Q C L r t IA d N F CV Z N C O • W 0 O O O - . Z Z N- z O O O -y Lt N O '' g L .. C a= a0v0 pQ a .? m ) z d N N 6&. 'J E N J ii F U 3 3 J J $ a Q N F Z W F C7 F- O OC a o_ V V V Y Q Z Q N m r _ cri C� Y Y N N N C �r a O V d Z. N C t1 fl N. I5 0 o• g .G O) o y CO 0 N Q. En .2 `c.c.,. 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N U d u) s S? 0 CO O 0 • • • Loepp, Victoria T (DOA) From: Starck, Kai <Kai.Starck@conocophillips.com> Sent Monday, February 06,2017 11:53 AM To: Loepp,Victoria T(DOA) Cc Regg,James B(DOA) Subject: FW: BOP Testing on CDR3,well 2T-41L1-01, PTD:216-168 Follow Up Flag: Follow up Flag Status: Flagged Victoria, CDR3 is currently completing the CTD sidetracks on KRU 2T-41L1-01, PTD#216-168. The last BOP pressure test was completed at 0530 on Jan 22nd which would make the deadline for the next test to begin at 2400 on Feb.5th. A BOP function test was performed on Jan.29th. The rig personnel had given proper notification of the upcoming test to the slope based inspectors and the witnessing of the test had been waived by Brian Bixby. Late this morning I was informed that the BOP test on CDR3 was not started until about 0300 this morning, Feb 6th. We are investigating what events led to the late start. Kai Starck Coiled Tubing Drilling Director ConocoPhillips Alaska, Inc. 700 G Street Anchorage, AK 99501 907-263-4093 office 907-240-0691 cell 1 VOF Tit, 0 0 ,,,,\���y/y'c. THE STATE Alaska Oil and Gas N ofLASI�:A Conservation Commission AWs, I tis 333 West Seventh Avenue ' r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r.', Main: 907.279.1433 04,ALAS�� 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-41L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-168 Surface Location: 5182' FNL, 4722' FEL, Sec. 1, T11N, R8E, UM Bottomhole Location: 3618' FNL, 1983' 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, V-,.,4 Pa?-4.1-,....,_ Cathy P. Foerster Chair, Commissioner 4DATED this d y of December, 2016. RECEIVED STATE OF ALASKA ALIDA OIL AND GAS CONSERVATION COMMIIIDN DEC 0 8 2016 PERMIT TO DRILL /� 20 AAC 25.005 AUGCC la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1c.Specify if well is proposed for: Drill ❑ Lateral •❑� Stratigraphic Test ❑ Development-Oil 2 • Service- Winj ❑ Single Zone ❑✓ ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ AT 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. -8$88 2C -.c9sa)so KRU 2T-41L1-01 , 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11350' ' TVD: 5950' 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,RO8E,UM • ADL 0025569 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1133'FNL,1962'FEL,Sec. 11,T11 N,RO8E,UM 2667 12/12/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3618'FNL,1983'FEL,Sec 11,T11N,RO8E,UM 2560 8590' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): i 104' 4, 15.Distance to Nearest Well Open Surface: x-498947 y-5970077 Zone-4 i GL Elevation above MSL(ft): 76 2.84-'',V to Same Pool: 986'2T-14 16.Deviated wells: Kickoff depth: 7880 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98 degrees• Downhole: 4203 psi • 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 3830' 7520' 5904' 11350' 5950' 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 ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contac, Ron Phillips @ 265-6312 Email Ron.L.Phillips(a cop.com Printed Name Kai Starck Title CTD Director Signature Phone 263-4093 Date f Z- -/ Commission Use Only Permit to DrillAPI Number: Permit Approval See cover letter for other Number: DZ)6 /(� 50-1-03 02O( 75-6l -00 Date: /2.- 2.(- I (,t. requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [( Other: Ban fire 42420 p5-1Samples req'd: Yes❑ No[i Mud log req'd:Yes Not L f D 6/7 ,56 measures: Yes No 4 Directional svy req'd:Yes Di No❑ li-y�vi(/ }� pr-z-til Pte-17 �5� / v �5 pac� : Yes❑ No u Inclination-only svy req'd:Yes❑ No[� 4 Voi ria h C{ fO 2 v4A-C 25--of S�bj Post initial injection MIT req'd:Yes❑ No rum' 15 1 i---a V?ted fv a 11 a (A-I 71-P-2 t X I eke f[ pai y-)-1-- h:' b -e- rnil /12oini G�/Ony 7I-k/ p - i ia> v / . (2...NIL / / APPROVED BY / Approved by: / COMMISSIONER /THE COMMISSION Date: /Z-2J 4 Lr f . / 1 /S, v1212120At 1 INA Lnths te ( � Submit Form and Form 10-461('evised 11/2015) h e i nT! from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska DEC 0 8 2015 P.O. BOX 100360 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, aer, Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer • `4,4 Kuparuk CTD Laterals NABOBS ALASKA 1‘". 2T-41L1 and 2T-41L1-01 J oPh P Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)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 • PTCOpplication: 2T-41L1 &2T-41L1-01 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 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 AA C 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 PTL plication: 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 MD MD TVDSS TVDSS Liner Details 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 (ppfJ 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 • PTDtplication: 2T-41 L1 &2T-41 L1-01 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 Target BHP 258psi 860 psi 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 110 PTfpplication: 2T-41L1 &2T-41L1-01 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 1'll 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. Pull BPV. 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 December 5, 2016 • PTpplication: 2T-41L1 &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 2%" 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 (1R-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 iplication: 2T-41L1 & 2T-41L1-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 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) Lateral Name Distance 2T-41L1 8,590' 2T-41L1-01 8,590' — Distance to Nearest Well within Pool Laterall`Came Distance Well 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 i 0 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2T Pad 2T-41 2T-41L1-01 Plan: 2T-41 L1-01_wp00 Standard Planning Report 02 December, 2016 r' 1 BAKER HUGHES • • ConocoPhillips Vaal 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-41L1-01 Design: 2T-41L1-01_wp00 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: 0.000in 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 +E/-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-41L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2016 1/1/2017 17.75 80.92 57,539 Design 2T-41 L1-01 wp00 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,880.00 'Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) -76.30 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (0) Target .:,ate: .: 7,880.00 92.88 98.08 5,844.75 -982.87 -2,390.52 0.00 0.00 0.00 0.00 7,950.00 97.78 98.08 5,838.26 -992.66 -2,321.54 7.00 7.00 0.00 0.00 8,020.00 94.95 102.11 5,830.50 -1,004.86 -2,253.07 7.00 -4.04 5.75 125.00 8,350.00 85.79 123.34 5,828.35 -1,131.50 -1,950.76 7.00 -2.77 6.43 113.00 8,550.00 90.65 136.48 5,834.59 -1,259.46 -1,797.83 7.00 2.43 6.57 70.00 8,950.00 91.51 164.47 5,826.90 -1,604.00 -1,602.69 7.00 0.22 7.00 88.00 9,070.00 90.04 172.74 5,825.27 -1,721.52 -1,579.02 7.00 -1.22 6.89 100.00 9,270.00 88.83 186.69 5,827.25 -1,921.01 -1,578.03 7.00 -0.60 6.97 95.00 9,695.00 88.99 216.45 5,835.53 -2,311.74 -1,732.50 7.00 0.04 7.00 90.00 9,795.00 88.99 209.45 5,837.29 -2,395.59 -1,786.85 7.00 0.01 -7.00 270.00 10,095.00 89.78 230.43 5,840.55 -2,624.31 -1,978.36 7.00 0.26 7.00 88.00 10,395.00 89.08 209.44 5,843.59 -2,853.03 -2,169.87 7.00 -0.23 -7.00 268.00 10,570.00 89.10 221.70 5,846.39 -2,995.09 -2,271.45 7.00 0.01 7.00 90.00 10,970.00 90.14 193.71 5,849.11 -3,345.71 -2,455.57 7.00 0.26 -7.00 272.00 11,070.00 90.14 200.71 5,848.87 -3,441.17 -2,485.14 7.00 0.00 7.00 90.00 11,350.00 90.80 181.12 5,846.54 -3,714.75 -2,537.92 7.00 0.24 -7.00 272.00 12/2/2016 3:58:09PM Page 2 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: 21-41 Survey Calculation Method: Minimum Curvature Wellbore: 2T-41L1-01 Design: 2T-41 L1-01_wp00 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) 7,880.00 92.88 98.08 5,844.75 -982.87 -2,390.52 982.87 0.00 0.00 5,969,094.82 496,556.01 TIP/KOP 7,900.00 94.28 98.08 5,843.50 -985.67 -2,370.76 985.67 7.00 0.00 5,969,092.01 496,575.77 7,950.00 97.78 d 98.08 5,838.26 -992.66 -2,321.54 992.66 7.00 0.00 5,969,085.01 496,624.98 Start 7 dls 8,000.00 95.76 100.96 5,832.36 -1,000.88 -2,272.58 1,000.88 7.00 125.00 5,969,076.79 496,673.94 8,020.00 94.95 102.11 5,830.50 -1,004.86 -2,253.07 1,004.86 7.00 125.34 5,969,072.81 496,693.44 3 8,100.00 92.74 107.27 5,825.13 -1,025.10 -2,175.89 1,025.10 7.00 113.00 5,969,052.56 496,770.61 8,200.00 89.96 113.69 5,822.77 -1,060.06 -2,082.30 1,060.06 7.00 113.35 5,969,017.59 496,864.19 8,300.00 87.17 120.12 5,825.28 -1,105.26 -1,993.20 1,105.26 7.00 113.50 5,968,972.38 496,953.27 8,350.00 85.79 123.34 5,828.35 -1,131.50 -1,950.76 1,131.50 7.00 113.34 5,968,946.13 496,995.70 4 8,400.00 86.99 126.63 5,831.50 -1,160.11 -1,909.89 1,160.11 7.00 70.00 5,968,917.52 497,036.57 8,500.00 89.43 133.20 5,834.62 -1,224.21 -1,833.27 1,224.21 7.00 69.79 5,968,853.42 497,113.17 8,550.00 90.65 136.48 5,834.59 -1,259.46 -1,797.83 1,259.46 7.00 69.59 5,968,818.17 497,148.61 5 8,600.00 90.77 139.98 5,833.97 -1,296.74 -1,764.53 1,296.74 7.00 88.00 5,968,780.88 497,181.90 8,700.00 91.00 146.98 5,832.43 -1,377.04 -1,705.06 1,377.04 7.00 88.04 5,968,700.58 497,241.35 8,800.00 91.22 153.97 5,830.49 -1,463.99 -1,655.82 1,463.99 7.00 88.15 5,968,613.64 497,290.57 8,900.00 91.42 160.97 5,828.18 -1,556.28 -1,617.54 1,556.28 7.00 88.29 5,968,521.36 497,328.84 8,950.00 91.51 164.47 5,826.90 -1,604.00 -1,602.69 1,604.00 7.00 88.45 5,968,473.64 497,343.67 6 9,000.00 90.90 167.92 5,825.85 -1,652.53' -1,590.77 1,652.53 7.00 100.00 5,968,425.10 497,355.59 9,070.00 90.04 172.74 5,825.27 -1,721.52 -1,579.02 1,721.52 7.00 100.07 5,968,356.13 497,367.33 7 9,100.00 89.86 174.84 5,825.30 -1,751.34 -1,575.77 1,751.34 7.00 95.00 5,968,326.31 497,370.57 9,200.00 89.25 181.81 5,826.08 -1,851.23 -1,572.85 1,851.23 7.00 95.00 5,968,226.42 497,373.48 9,270.00 88.83 186.69 5,827.25 -1,921.01 -1,578.03 1,921.01 7.00 94.94 5,968,156.66 497,368.28 8 9,300.00 88.83 188.79 5,827.86 -1,950.73 -1,582.07 1,950.73 7.00 90.00 5,968,126.94 497,364.24 9,400.00 88.85 195.79 5,829.89 -2,048.35 -1,603.35 2,048.35 7.00 89.96 5,968,029.33 497,342.95 9,500.00 88.88 202.80 5,831.88 -2,142.66 -1,636.37 2,142.66 7.00 89.82 5,967,935.04 497,309.93 9,600.00 88.93 209.80 5,833.80 -2,232.24 -1,680.63 2,232.24 7.00 89.68 5,967,845.47 497,265.65 9,695.00 88.99 216.45 5,835.53 -2,311.74 -1,732.50 2,311.74 7.00 89.54 5,967,765.98 497,213.77 9 9,700.00 88.99 216.10 5,835.62 -2,315.77 -1,735.46 2,315.77 7.00 -90.00 5,967,761.95 497,210.82 9,795.00 88.99 209.45 5,837.29 -2,395.59 -1,786.85 2,395.59 7.00 -89.99 5,967,682.15 497,159.42 10 9,800.00 89.01 209.80 5,837.38 -2,399.94 -1,789.32 2,399.94 7.00 88.00 5,967,677.80 497,156.95 9,900.00 89.26 216.79 5,838.90 -2,483.46 -1,844.17 2,483.46 7.00 87.99 5,967,594.29 497,102.09 10,000.00 89.52 223.79 5,839.97 -2,559.69 -1,908.80 2,559.69 7.00 87.89 5,967,518.08 497,037.47 10,095.00 89.78 230.43 5,840.55 -2,624.31 -1,978.36 2,624.31 7.00 87.81 5,967,453.48 496,967.90 11 10,100.00 89.76 230.08 5,840.57 -2,627.50 -1,982.20 2,627.50 7.00 -92.00 5,967,450.29 496,964.06 10,200.00 89.52 223.09 5,841.19 -2,696.19 -2,054.80 2,696.19 7.00 -92.00 5,967,381.62 496,891.46 10,300.00 89.29 216.09 5,842.23 -2,773.20 -2,118.48 2,773.20 7.00 -91.96 5,967,304.63 496,827.77 10,395.00 89.08 209.44 5,843.59 -2,853.03 -2,169.87 2,853.03 7.00 -91.88 5,967,224.81 496,776.38 12 10,400.00 89.08 209.79 5,843.67 -2,857.37 -2,172.34 2,857.37 7.00 90.00 5,967,220.47 496,773.91 10,500.00 89.08 216.79 5,845.28 -2,940.90 -2,227.19 2,940.90 7.00 89.99 5,967,136.96 496,719.05 10,570.00 89.10 221.70 5,846.39 -2,995.09 -2,271.45 2,995.09 7.00 89.88 5,967,082.78 496,674.78 12/2/2016 3:58:09PM Page 3 COMPASS 5000.1 Build 74 111 w ConocoPhillips Vain 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-41L1-01 Design: 2T-41 L1-01_wp00 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) 13 10,600.00 89.17 219.60 5,846.85 -3,017.84 -2,290.99 3,017.84 7.00 -88.00 5,967,060.03 496,655.24 10,700.00 89.42 212.60 5,848.08 -3,098.59 -2,349.87 3,098.59 7.00 -87.97 5,966,979.30 496,596.36 10,800.00 89.69 205.61 5,848.85 -3,185.91 -2,398.48 3,185.91 7.00 -87.88 5,966,892.00 496,547.75 10,900.00 89.95 198.61 5,849.17 -3,278.50 -2,436.09 3,278.50 7.00 -87.83 5,966,799.42 496,510.13 10,970.00 90.14 193.71 5,849.11 -3,345.71 -2,455.57 3,345.71 7.00 -87.81 5,966,732.22 496,490.64 14 11,000.00 90.14 195.81 5,849.04 -3,374.72 -2,463.21 3,374.72 7.00 90.00 5,966,703.22 496,482.99 11,070.00 90.14 200.71 5,848.87 -3,441.17 -2,485.14 3,441.17 7.00 90.01 5,966,636.77 496,461.05 15 11,100.00 90.21 198.62 5,848.77 -3,469.42 -2,495.24 3,469.42 7.00 -88.00 5,966,608.53 496,450.96 11,200.00 90.45 191.62 5,848.19 -3,565.90 -2,521.30 3,565.90 7.00 -88.01 5,966,512.06 496,424.88 11,300.00 90.69 184.62 5,847.19 -3,664.83 -2,535.42 3,664.83 7.00 -88.05 5,966,413.15 496,410.75 11,350.00 90.80 181.12 5,846.54 -3,714.75 -2,537.92 3,714.75 7.00 -88.12 5,966,363.23 496,408.24 Planned TD at 11350.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape C) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2T-41L1-01_T01 0.00 0.00 5,854.00 -3,936.891,137,648.90 5,965,981.00 1,636,481.00 70°5'5.477 N 140°51'40.981 W -plan misses target center by 1139223.65usft at 9200.00usft MD(5826.08 TVD,-1851.23 N,-1572.85 E) -Point 2T-41L1_Fault1_M 0.00 0.00 0.00 -1,302.551,138,221.58 5,968,615.00 1,637,054.00 70°5 30.214 N 140°51'13.300 W -plan misses target center by 1139809.45usft at 9200.00usft MD(5826.08 TVD,-1851.23 N,-1572.85 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 2T-41 CTD Polygon' 0.00 0.00 0.00 -4,718.051,137,096.95 '5,965,200.00 1,635,929.00 70°4'58.703 N 140°52'0.070 W -plan misses target center by 1138688.31 usft at 9200.00usft MD(5826.08 TVD,-1851.23 N,-1572.85 E) -Polygon Point 1 0.00 0.00 0.00 5,965,200.00 1,635,929.00 Point2 0.00 -197.90 631.10 5,965,002.03 1,636,560.01 Point 3 0.00 1,563.38 1,151.82 5,966,763.06 1,637,080.92 Point 4 0.00 2,791.61 1,738.64 5,967,991.09 1,637,667.86 Points 0.00 3,277.65 1,701.54 5,968,477.08 1,637,630.83 Point6 0.00 3,721.62 1,294.42 5,968,921.07 1,637,223.81 Point7 0.00 3,857.53 751.34 5,969,057.04 1,636,680.81 Point 8 0.00 3,766.42 207.30 5,968,966.01 1,636,136.81 Point 9 0.00 3,123.37 280.43 5,968,323.02 1,636,209.84 Point 10 0.00 3,151.47 823.48 5,968,351.04 1,636,752.84 Point 11 0.00 2,924.49 1,049.54 5,968,124.05 1,636,978.85 Point 12 0.00 1,690.27 524.73 5,966,890.03 1,636,453.91 Point 13 0.00 0.00 0.00 5,965,200.00 1,635,929.00 2T-41 L1_Fault1 0.00 0.00 5,816.00 -1,302.551,138,221.58 5,968,615.00 1,637,054.00 70°5'30.214 N 140°51'13.300 W -plan misses target center by 1139794.56usft at 9200.00usft MD(5826.08 TVD,-1851.23 N,-1572.85 E) -Polygon Point 1 5,816.00 0.00 0.00 5,968,615.00 1,637,054.00 Point2 5,816.00 1.00 1.00 5,968,616.00 1,637,055.00 12/2/2016 3:58:09PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2T Pad 2T-41 2T-41L1-01 2T-41 L1-01_wp00 Travelling Cylinder Report 02 December, 2016 r' 1 BAKER HUGHES • • Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-41 Project: Kuparuk River Unit TVD Reference: 21-41:76.3+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-41L1-01 Database: OAKEDMP2 Reference Design: 2T-41 L1-01_wp00 Offset TVD Reference: Offset Datum Reference 2T-41 L1-01_wp00 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,880.00 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 I(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 II(2T-41) INC+TREND Inclinometer+known azi trend 3,213.03 7,175.74 21-41 MWD 111(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,241.37 7,241.37 21-41 MWD IV(2T-41) INC+TREND Inclinometer+known azi trend 7,277.22 7,426.14 21-41 MWD V(2T-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,426.14 7,880.00 2T-41 L1_wp05(2T-41L1) MWD MWD-Standard 7,880.00 11,350.00 2T-41L1-01_wp00(2T-41L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name O C') 1 11,350.00 5,950.34 2 3/8" 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 2T-08-2T-08A-2T-08A Out of range 2T-08-2T-08AL1-2T-08AL1 Out of range 2T-09-21-09-2T-09 Out of range 2T-09-2T-09L1-2T-09L1 Out of range 21-09-2T-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 8,526.35 6,550.00 71.44 4.87 68.53 Pass-Minor 1/10 2T-12-2T-12A-21-12A 8,493.88 6,550.00 192.83 7.20 192.31 Pass-Minor 1/10 2T-13-2T-13-2T-13 Out of range 2T-14-2T-14-2T-14 11,059.73 7,150.00 986.22 254.57 762.88 Pass-Major Risk 2T-15-2T-15-2T-15 Out of range 2T-16-21-16-21-16 Out of range 21-17-21-17-21-17 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/2/2016 2:19:53PM Page 2 COMPASS 5000.1 Build 74 • • `' Baker Hughes INTEQ Fdii. 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-41L1-01 Database: OAKEDMP2 Reference Design: 2T-41 L1-01_wp00 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-18-2T-18-2T-18 Out of range 2T-19-2T-19-27-19 Out of range 27-20-2T-20-2T-20 Out of range 27-201-2T-201-2T-201 Out of range 2T-21-2T-21-2T-21 Out of range 27-36-2T-36-27-36 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 27-40-2T-40-27-40 Out of range 27-40-2T-40L1-2T-40L1 Out of range 27-41-2T-41-2T-41 7,880.00 7,150.00 595.29 6.42 589.28 Pass-Major Risk 2T-41-2T-41L1-2T-41 L1_wp05 7,899.99 7,900.00 0.36 0.63 -0.23 FAIL-Minor 1/10 Offset Design Kuparuk 2T Pad- 2T-12-2T-12-2T-12 Offset Site Error: 0.00 usft 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 +N/-6 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) Pn (usft) (usft) (usft) 8,525.71 5,938.54 6,812.00 6,150.34 22.39 17.57 -90.12 -1,382.95 -1,954.84 5 280.89 2.57 279.13 Pass-Minor 1/10 8,525.74 5,938.54 6,800.00 6,139.95 22.39 17.53 -90.78 -1,378.71 -1,950.60 5 269.32 4.70 264.70 Pass-Minor 1/10 8,525.79 5,938.54 6,775.00 6,118.31 22.39 17.39 -92.35 -1,369.86 -1,941.75 5 245.33 4.72 240.68 Pass-Minor 1/10 8,525.85 5,938.54 6,750.00 6,096.69 22.39 17.25 -94.24 -1,360.99 -1,932.87 5 221.56 4.74 216.87 Pass-Minor 1/10 8,525.90 5,938.54 6,725.00 6,075.08 22.39 17.11 -96.59 -1,352.09 -1,923.97 5 198.08 4.75 193.34 Pass-Minor 1/10 8,525.96 5,938.54 6,700.00 6,053.50 22.39 16.97 -99.54 -1,343.18 -1,915.04 5 175.00 4.77 170.23 Pass-Minor 1/10 8,526.02 5,938.54 6,875.00 6,031.93 22.39 16.83 -103.37 -1,334.24 -1,906.09 5 152.51 4.78 147.72 Pass-Minor 1/10 8,526.08 5,938.54 6,650.00 6,010.39 22.39 16.69 -108.47 -1,325.28 -1,897.12 5 130.92 4.80 126.14 Pass-Minor 1/10 8,526.15 5,938.54 6,625.00 5,988.86 22.39 16.55 -115.50 -1,316.30 -1,888.12 5 110.74 4.82 106.04 Pass-Minor 1/10 8,526.21 5,938.54 6,600.00 5,967.36 22.39 16.41 -125.40 -1,307.30 -1,879.10 5 92.91 4.83 88.44 Pass-Minor 1/10 8,526.28 5,938.54 6,575.00 5,945.87 22.39 18.27 -139.33 -1,298.28 -1,870.05 5 79.03 4.85 75.10 Pass-Minor 1/10 8,526.35 5,938.54 6,550.00 5,924.40 22.39 18.13 -157.57 -1,289.23 -1,860.98 5 71.44 4.87 68.53 Pass-Minor 1/10,CC,ES,SF 8,526.41 5,938.54 6,525.00 5,902.95 22.39 15.99 -177.61 -1,280.17 -1,851.88 5 72.15 4.88 70.66 Pass-Minor 1/10 8,526.48 5,938.54 6,500.00 5,881.52 22.39 15.85 164.78 -1,271.08 -1,842.76 5 80.95 4.90 80.53 Pass-Minor 1/10 8,526.56 5,938.54 6,475.00 5,860.11 22.39 15.71 151.57 -1,261.97 -1,833.62 5 95.63 4.92 95.21 Pass-Minor 1/10 8,526.63 5,938.54 6,450.00 5,838.72 22.39 15.56 142.22 -1,252.84 -1,824.45 5 113.93 4.93 113.51 Pass-Minor 1/10 8,526.70 5,938.54 6,425.00 5,817.35 22.39 15.42 135.57 -1,243.68 -1,815.25 5 134.39 4.95 133.97 Pass-Minor 1/10 8,526.78 5,938.54 6,400.00 5,796.00 22.39 1528 130.72 -1,234.51 -1,806.03 5 156.16 4.96 155.75 Pass-Minor 1/10 8,526.86 5,938.54 6,375.00 5,774.67 22.39 15.14 127.06 -1,225.31 -1,796.79 5 178.76 4.98 178.35 Pass-Minor 1/10 8,526.93 5,938.54 6,350.00 5,753.36 22.39 15.00 124.22 -1,216.10 -1,787.52 5 201.92 5.00 201.50 Pass-Minor 1/10 8,527.01 5,938.54 6,325.00 5,732.07 22.39 14.86 121.96 -1,206.86 -1,778.23 5 225.46 5.01 225.04 Pass-Minor 1/10 8,527.09 5,938.54 6,300.00 5,710.80 22.39 14.72 120.12 -1,197.60 -1,768.92 5 249.27 5.03 248.85 Pass-Minor 1/10 8,527.17 5,938.54 6,275.00 5,689.55 22.39 14.58 118.60 -1,188.32 -1,759.58 5 273.28 5.05 272.86 Pass-Minor 1/10 8,527.25 5,938.54 6,250.00 5,668.31 22.39 14.44 117.32 -1,179.01 -1,750.21 5 297.45 5.06 297.03 Pass-Minor 1/10 8,527.34 5,938.54 6,225.00 5,647.10 22.39 14.30 116.23 -1,169.69 -1,740.82 5 321.73 5.08 321.32 Pass-Minor 1/10 8,527.42 5,938.54 6,200.00 5,625.92 22.39 14.17 115.28 -1,160.33 -1,731.40 5 346.11 5.09 345.69 Pass-Minor 1/10 8,527.50 5,938.54 6,175.00 5,604.78 22.39 14.03 114.45 -1,150.93 -1,721.94 5 370.55 5.11 370.14 Pass-Minor l/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/2/2016 2.19:53PM 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O 'O t` N N N N 4 q b 'O l� C; 00 (ui sn OSS) (+)unioN/(-)q nos a u 0 "' n C + 0 CO U v • • 2T-41 Proposed CTD Schematic Modified by RLP 11/23/16 lJ 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) 1 Baker Premier Packer @ 6892' MD(2.87" ID) IKf ZXP Liner Top Packer @ 6993' MD(4.93" ID) - RA Marker in 5-1/2" Liner©7244' 7-5/8"29.7#L-80 shoe @ 7222' MD 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 Baker FA-1 Packer @ 7472' MD 11111111.1 3-1/2" HES D nipple @ 7477' RKB(2.75"min ID) 11111111 - - " 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 .• . KUP PROD III 2T-41 Conoco'Phillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(988) Act Btm(ftKB) ccnocWrtvorpt : 501032067500 KUPARUK RIVER UNIT PROD 57.72 3,106.62 7,988.0 ••- Comment H2S(ppm) Oats Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2T-41.7/10/201611:55:09 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 fki.( Casing Strings le Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) 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 Desedptlon OD(In) ID(in) Tap(111(8) Set Depth(WO) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.5 3,196.9 2,580.0 45.50 L-60 Hydril 563 Casing Doesdptlon OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread ae1 ` INTERMEDIATE 75/8 6.875 25.6 7,222.2 5,684.6 29.70 L-80 Hydril 563 Casing DescriptionOD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread LINER 51/2 4.892 6,992.5 7,946.5 6,212.3 17.00 P-110 DWC-C Liner Details Nominal ID Top(ORB) Top(TVD)(111(8) Top Incl(°) Item Das Com (in) CONDUCTOR;27.5-133.5 6,992.5 5,508.6 39.93 PACKER °HRDE":ZXP LINER TOP PACKER w/10'TIE- 4.930 BACK SLEEVE NIPPLE:413.4 ill 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 �� Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(,..Wt(15/f5 Grade Top Connection -' TUBING 31/2 2.992 23.4 6,884.9 5,426.2 9.30 L-80 EUE c Completion Details Nominal IO Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (In) 23.4 23.4 0.00 HANGER FMC TUBING HANGER 3.958 24.1 24.1 0.00- FMC TUBING HANGER 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 :, t� 413.4 412.6 7.09 NIPPLE CAMCO DS NIPPLE SURFACE:28.5-3,198.9- I 2.875 8,844.2 5,394.9 39.44 NIPPLE HES"X"NIPPLE 2,812 6,882.2 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(Ib/ft) Grade Top Connection STACKER PACKER 31/2 2.992 6,867.2 7,473.3 5,870.3 9.20 P-110 Hydril 563 Completion Details P Nominal ID Top(ftKB) Top(TVD)(fIKB) Top Incl I") Item Des Com (In) GAS LIFT;4,912.9 6,867.2 5,412.6 39.63 PBR BAKER 80-40 PBR w/20'Stroke,Pinned w/40,000# 3.000 Shear 6,892.4 5,431.9 39.85 PACKER 'BAKER PREMIER PACKER 659-287 2.870 GAS LIFT;5,802.1 7,353.9 5,783.3 42.77 BLAST RING CARBIDE BLAST RING on 2 jts P-110 pipe(overlap C 2.992 sand pelf's+5')50'of blast rings. 7,457.4 5,858.8 43.67 SLEEVE-0 3.5 CMU SLIDING SLEEVE 2.813'X'PROFILE 2.813 GAS LIFT;8,418.2 - (OPENED 1/7/2016) 7,471.6' 5,869.0 43.87 SEAL ASSY 'KBH-22 ANCHOR SEAL ASSY 2.990 Tubing Description String Ma...ID(in) Top(9KB) Set Depth(ft..Set Depth(TVD))...Wt(Ib/ft) Grade Top Connection FA PACKER 4.55 3.000 7,472.0 7,479.0 5,874.4 9.20 L-80 GAS LIFT;6,785.2 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des _ Com (In) 7,472.0 5,869.3 43.87 PACKER BAKER FA-1 PRODUCTION PACKER(4.55 OD AND - 3.000 NIPPLE;6,844.2 3.0 ID are for the Packer not the tubing.WV chooses Ili longest section In tubing) SEAL ASSY;6,862.21 - 7,476.8 5,872.8 43.94'NIPPLE HES 2.75"D"NIPPLE 2.750 PBR;8,8872 ,a 7,478.1 5,873.7 43.95 WLEG WIRELINE GUIDE SHEAR OUT SUB-(WLEG has not 2.950 50 Thread;5,890.6 4' '1 been sheared open) PACKER;8,892.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) X0 Thread;6,899.0 Top(ND) Top Incl Top(MB) (ftKB) (°) Des Corn 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 Dena• Top(ND) Btm(TVD) (shots/f _ Top(ftKB) Btm(ftKB) (f6(B) (ftKB) Zone Date t) Type Com 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 7,388.0 7,408.0 5,808.2 5,822.9 C-4,2T-41 11/25/2013 6.0 (PERF 3 3/8 Millenum Gun,25 INTERMEDIATE:25.6-7,222.2- Gram 60 Deg Phase Radioactive Marker;7,244.3-, 7,490.0 7,510.0' 5,882.3 5,896.6 A-3,2T-41 11/25/2013 6.0 (PERF 31/8 Millenum Gun,21 IPERF;7,388.0-7,388.0 Gram 60 Deg Phase Sand Frac;7,366.0 IM 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:7,388.0-7,408.0 Gram 60 Deg Phase Sand Frac;7,388.01 1 I w 7,530.0 7,550.0 5,910.9 5,925.1 A-3,2T-41 11/25/2013 6.0 (PERF 31)8 Millenum Gun,21 Gram 60 Deg Phase Stimulations&Treatments XO Thread;7,455.4 Min Top Max Btm SLEEVE-0;7,4574 Ill Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 7,490.0 7,550.0 5,882.3 5,925.1 FRAC 12/12/201 "A°Sand Frac w/25#Linear/X-Linked Gel Placing SEAL ASSY;7,471AIl '_ 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 bb(s meth spear down tubing/pumped 720 bbis sea water at 180 bbis x 4,pumped 5 bbis meth/ pumped 20 bbis freeze protect NIPPLE;7,470.6 Sir, 7,368.0 7,408.0 6,793.6 5,808.2 Sand Frac 1/10/2016 PERFORMED C-SAND FRACTURE TREATMENT WLEG;7,476.1 I AT 20 BPM,PLACING 47K#OF 16/20 FRAC SAND IPERF;7,490.0-7,510.0A (47% DESIGN).WELL SCREENED OUT ON 5 FRAC;7,490.01 PPA STAGE HPBD;7,490.0 IPERF;7,510.0-7,530.0 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 I AT 20 BPM,PLACING 47K#OF 16/20 FRAC SAND (47%OF DESIGN).WELL SCREENED OUT ON 5 • PPA STAGE LINER;6,992.5-7,948.5 • • 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. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: /.R, (,L a / -)1/ 1../ - 0/ PTD: 02,l (p - f(a Y /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: kit .l(�n k 1 \ii l POOL: gUyicurk.4J�f‘/k•tT I 4/U4 Check Box for Appropriate Letter I 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. a/3-)'/!0 , API No. 50-103 - ,2067.c. -Oa - 00 . V (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 Cl)NI , , , , , , , Q o , , , , , , co o , , , ' , CD i O D 3 E c , a m > 'fi , , M' , p Z 0 C (0 Oy a 0' a) .o 3' CO o N 3 a) , , o o a) , 3 N. 0S a ' E) d D - y N' ' ca0 lL' p d' Q > �, - ' o' i a) •c j 0 Y - 1' W' a, y E y, a' a , is Qa rn 3' Y' °c' :?, , , D c c o N , a 3 Z a /� °° y' ° vi > N �? 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