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. • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cJ 6 - 039 Well History File Identifier Organizing (done) \wo-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: ( Maria) Date: I I/51/5P /s/ Ili P Project Proofing rdBY: . .. Date: ` I 6 /5 /s/ Scanning Preparation x 30 = Le) + aa = TOTAL PAGES g 3 (Count does not include cover sheet) 0/1 BY: �. .� Date: 1115)15" ts/ Production Scanning Stage 1 Page Count from Scanned File: 'I- (Count does include cover heet) Page Count Matches Number in Scanning Pr paration: ES NO BY: legb Date: II/5 /57. /s/ y14Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage I + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc • s In . - C7 • N p .0. .N- 0 E w N NN Z \ , C a F5 < a) 0 < N N LL U 0 O 0 O. O N AO 0) 0 (01 Z rn < Z Z Z < < m o) J m m J N N I, I cc) >, a CO u) 0 0 CO CO 0 0 ca 0 0 co >. 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Date Comp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband1 1P617015 215-089 ` 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 •6/23/2015 50-029-22684-01 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 23'FNL, 14'FWL, Sec.29,T12N, R9E, UM .6/26/2015 -KRU 3F-18A and 3F-18APB1 Top of Productive Interval: 9. KB(ft above MSL): • 96' 17. Field/Pool(s): 2244'FNL, 164'FEL, Sec. 30,T12N, R9E, UM GL(ft above MSL): .42' Kuparuk River Field/Kuparuk Oil Pool , Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 364'FNL, 182'FWL, Sec.29,T12N, R9E, UM •9335'MD/6085'TVD ADL 25643 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit. Surface: x- 508514 y- 5985800 Zone- 4 •9335'MD/6085'TVD 2574 TPI: x- 508346 y- 5983579 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 508684 y- 5985460 Zone- 4 nipple @ 516'MD/516'TVD 1624'MD/1546'TVD 5. Directional or Inclination Survey: Yes • (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) •6540'MD/5935'TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 42' 121' 42' 121' 24" 262 sx AS I 7.625" 29.7# L-80 41.5' 3481' 41.5' 3180' 9.875" 800 sx AS III,290 sx Class G 5.5"x3.5" 15.5x9.3# L-80 37' 6858' 37' 6227' 6.75" 200 sx Class G 2.375" 4.6# L-80 7398' 9335' 6025' 6085' 3" slotted liner 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 6321' no packer slotted liner from 7409'-9332'MD 6025'-6085'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. c4 = '4St;�°=a� Was hydraulic fracturing used during completion? Yes El No ❑✓ k T.-L.5 Per 20 AAC25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6274-6600' 18 bbls cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - . Form 10-407 Revised 5/2015 V 71,- ei Z // CONTINUE Submit ORIGINIAL onl PAGE 2 A 1'7--/'" .1k8 9145 RBDM AUG 2 7 2015 Y 28. CORE DATA, Conventional Core Yes ❑ No ❑- Sidewall Cores: ! ❑ No ❑✓ 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. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No LI Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1624' 1546' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk A6 6612' 5991' Kuparuk A5 6619' 5996' Kuparuk A4 6632' 6002' Kuparuk A3 6644' 6008' NONE 3F-18APB1 total depth 8622' Formation at total depth: Kuparuk A3 f 31. List of Attachments: Summary of Daily Operations,wellbore schematic,directional survey Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips @ 265-6312 Email: Ron.Phillipscop.com Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: Vari Phone: 263-4372 Date: f 22—/.S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 and Ground Level 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 5/2015 Submit ORIGINAL Only i KUP PROD 3F-18A Conoc Phill ps , Well Attributes 411 Max Angle&MD TD AL.„1fa,Inc, Wellbore API/DWI Field Name Wellbore Status Incl(") MD(ftKB) Act Blm(ftKB) .3nocavhimpc / 500292268401 KUPARUK RIVER UNIT PROD 94.73 7,720.28 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3F-18A,7/21120152:39'09 PM SSSV:NIPPLE 150 12/6/2009 Last WO: 7/11/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - - -- �w,(,) - -Last Tag: Rev Reason:SIDETRACKED,ADD LATERALS smsmith 7/20/2015 36.8 HANGER, lu;Wsl L1 8 L2(off main wellbore),SET PACKER,SET Casing Strings -"_, .-- „ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/LenII...Grade Top Thread SURFACE 75/8 6.875 41.5 3,481.3 3,180.2 29.70 L-80 BTC-MOD CONDUCTOR;42.0-121.0 j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"03.5" 51/2 4.950 36.8 6,858.0 6,029.8 15.50 L-80 LTC-MOD SI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;516.1 :ilt A LINER 23/8 1.992 7,397.5 9,335.0 6,084.6 4.60 L80 STL Liner Details Nominal ID II Top(ftKB) Top(TVD)(ftKB)_Top Incl("1 Item Des Com (in) GAS LIFT;8,7399 7,397.5 6,025.2 88.63 BILLET BAKER ANCHORED ALUMINUM BILLET 1.000 AB 7,734.2 6,032.1 94.66 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 I 8,544.7 6,059.5 90.26 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 V Tubing Strings "' IL Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection SURFACE;41,5-3,481.3-A TUBING 31/2 2.992 36.8 6,333.3 5,745.5 9.30 L-80 IBT Completion Details GAS LIFT;3,947.7 r Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 368 36.8 0.00 HANGER FMC 31/2"x71/16"5M TBG Hanger w/3 1/2"IBT Pup 3.500 IN 516.1 513.7 13.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 GAS LIFT;4,960.8 - - 6,277.4 5,694.3 23.45 NIPPLE Cameo 2.812""DS"Nipple 2.812 6,320.4 5,733.8 23.57 SEAL ASSY Baker Seal Assembly 80-40 GBH22 w/locator(2.00' 3.000 spaceout) GAS LIFT;5,696.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (.) Des Com Run Date ID(In) 6,277.0 5,693.9 23.45 CATCHER 7/15/2015 GAS LIFT;6,223.8 6,401.0 5,807.6 23.78 KB PACKER 7/15/2015 1.810 In Perforations&Slots Shot Dens IF Top(ND) Btm(TVD) (shots/f NIPPLE;6277.4 11,10 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn CATCHER;6,277.0 _ 7,409.3 7,733.8 6,025.5 6,032.2 A-3,3F-18A 6/28/2015 APERF Slotted Liner I 7,735.0 8,544.3 6,032.1 6,059.5 A-3,3F-18A 6/28/2015 APERF Slotted Liner 11 8,545.6 9,332.8 6,059.5 6,084.4 A-3,3F-18A 6/28/2015 APERF Slotted Liner IMandrel Inserts SEAL ASSY;6,320.4 - St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,739.9 2,516.0 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.156 1,294.0 7/16/2015 9 2 3,947.7 3,594.7 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.156 1,285.0 7/16/2015 9 KB PACKER;6,401.0 I. 3 4,960.7 4,500.0 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.156 1,295.0 7/16/2015 9 4 5,696.8 5,163.7 CAMCO KBG-2- 1'GAS LIFT GLV BTM 0.188 1,501.0 7/16/2015 APERF;6,412.0-8419.0 9 APERF;6,419.0-6,425.0 5 6,223.8 5,645.1 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0'7/15/2015 APERF;6,425.0-6,428.0 il 9 s Notes:General&Safety APERF;6,480.0-6,490.0 il End Date Annotation NOTE 1. Iil[ok, WINDOW;6,539.6-6,644.2 I APERF;6,628.5-7,368.2 AL2 LINER;6,402.2-9,867.0 Ill PRODUCTION 5.5'83.5`,36.8- 6,858.0 APERF;6,698.9-8,038.2 APERF;7,409.37,733.8 11111 lr APERF;7,735.0-8544.3 ikl APERF;8,545.5-9,332.8 I AL1 LINER;6,665.0-9,300.0 A LINER;7,397.5-9,335.0 3F-18 PRE-RIG WELL WORK DATE SUMMARY • • 5/10/2014 TAG TD @ 6634' SLM; UNABLE TO DRIFT THROUGH KNOWN OBSTRUCTION @ 6384' SLM W/2.69" DMY WRP; PUMP 75 BBLS OF DIESEL W/776; UNABLE TO DRIFT PASS 6384' SLM W/2.69" DMY WRP OR 2.55" CBP; DRIFT CLEANLY W/2 1/8" DMY IBP DOWN TO 6630' SLM. READY FOR E-LINE. 5/27/2014 TAG FILL AT 6668'. LOG MULTIFINGER CALIPER FROM TAG TO SURFACE. LOG CORRELATED TO SLB CEMENT BOND LOG DATED JULY 27 2006. JOB COMPLETE. 7/31/2014 DRIFTED TBG WITH 2" BLR ASS'Y&TAG @ 6630' SLM (EST. 24'OF FILL/NO SAMPLE OBTAINED); MEASURED BHP @ 6660' RKB (2968 PSI). BRUSH n' FLUSH KNOWN TIGHT SPOT @ 6380' SLM. DRIFT TBG WITH 17.5'x 2.625" DMY WHIP STOCK(UNABLE TO PASS KNOWN TIGHT SPOT @ 6380'SLM). JOB COMPLETE. 12/6/2014 B&C CTU#1: DRESS 'WRINKLE' IN 3-1/2" LINER AT 6386' CTMD WITH BAKER RH MOTOR AND 2.80"OD DIAMOND STRING MILL WITH 2.80" DIAMOND PARABOLIC MILLS. MULTIPLE PASSES WITH GOOD MOTOR WORK. ABLE TO DRY DRIFT PROBLEM AREA. READY FOR SLICKLINE TO REATTEMPT DUMMY WHIPSTOCK DRIFT. 12/9/2014 UNABLE TO DRIFT THROUGH BAD SPOT W/2.62"WHIP STOCK DRIFT @ 6390' SLM, JOB COMPLETE 1/8/2015 RIH WITH 2.63"WHIPSTOCK DRIFT, MADE IT THROUGH THE PROBLEM AREA OF 6420'WITHOUT NOTICING ANY WEIGHT CHANGES, RIH TO 6600' CTMD, MAKE 3 PASSES FROM 6350' CTMD TO 6600' CTMD TO CONFIRM NO ISSUES THROUGH PROBLEM AREA, F/P TBG TO 6600' CTMD, JOB COMPLETE. 3/13/2015 (PRE-CTD) FUNCTION T LDS ALL OK, T POT PASSED, T PPPOT PASSED, IC POT PASSED, IC PPPOT PASSED 3/19/2015 (PRE-CTD) MITOA- IN PROGRESS 3/20/2015 (PreCTD) : MIT-IA(PASSED)TO 3000 PSI, MIT-OA(FAILED)TO 1800 PSI. 4/4/2015 (PRE-CTD) : SCLD PASSED TO 1400 PSI. 6/1/2015 LATE START DUE TO TRACTOR SWAP AND T-BAR ISSUES, RIH AND DRIFT TBG WITH 2.65" NOZZLE AND NIPPLE LOCATOR, HARD TAG AT 6636' CTMD (A- 3 PERFS), LOCATE NIPPLE AT 6259'CTMD (-18'CORRECTION), F/P TBG, JOB IN PROGRESS. 6/2/2015 PERFORM WEEKLY BOP TEST, RIH FIND "DS"NIPPLE, CORRECT TO MID ELEMENT, SET CBP @ 6600' MID ELEMENT, PERFORM INJECTION TEST, @ 1 BPM= CTP 1576, WHP 798, IA 257, OA 395, 2BPM= CTP 3335, WHP 856, IA 251, OA 396 ****JOB IN PROGRESS**** 6/3/2015 RIH TO CBP, CORRECT TO 6600' PICK UP 5' LAY IN 14 BBLS, TRY TO BUILD SQUEEZE PRESSURE OF 1,000, NOT ABLE TO ACHIEVE PRESSURE. CONTAMINATE CMT AND CHASE OUT OF HOLE. JOB IN PROGRESS 6/4/2015 RIH TO FLAG AT M 6263' E 6260', CORRECT TO 6274' END OF TOOLS. BATCH UP 18 BBLS OF CEMENT 11 OF WHICH HAVE CemNet IN IT, LAY IN CEMENT WHILE GETTING 1:1 RETURNS, DID HESITATION SQUEEZE AND WAS ABLE TO REACH 1000 PSI, DROPPED 7/8" BALL FOLLOWED WITH 60 BBLS POWER VIS. CLEANED OUT DOWN TO 6340', CHASED OUT OF HOLE SLOWING FOR ALL JEWELRY. ****LET SET FOR 72 HRS JOB IN PROGRESS**** 6/10/2015 Initial tubing pressure test pre-milling was 1,252 psi and fell to 1,232 after ten minutes. Correlated depth to DS Nipple and painted flag. Milled cement from 6,340'to 6,380'. Unable to get past this area of known "wrinkle" in pipe. Several stalls then lost circulation pressure. Inspected BHA once on surface and determined that motor was bad. Will return and run a 2.80" Diamond Speed Bit. Well freeze protected. ****Job in Progress**** 6/11/2015 Perform Weekly BOP Test and change pack-offs. Mill out cement with a 2.79" Diamond Speed Bit from 6,380'to 6,420').Average ROP was < .44 fpm. Will return in morning and drill out remaining170'with bi-center bit if able to now pass through the "wrinkled" area. Well freeze protected. ****Job in Progress**** 6/12/2015 Sussessfully dry drift bi-center bit through "wrinkle"area and when POOH was able to spin bi-center bit back throllwith no issues. Milled cement from 6,330.equested depth of 6,590'. Average R = .66 fpm. Wellbore circulated clean with seawater and freeze protected. Communicated with town engineer that Final Pressure Test @ 1,200 psi had leak rate of 1 psi per second. Ready for BPV and DHD. ****Job in Progress****. 6/15/2015 (PRE-CTD): TREE VALVE TEST, DDT MV, SSV, SV(PASSED), PPT MV, SSV, SV (PASSED). S rnochiIIips Time Log & Summary 4Ve1/view Web Reporting Report Well Name: 3F-18 Rig Name: NABORS CDR2-AC 1 Job Type: DRILLING SIDETRACK Rig Accept: 6/21/2015 9:00:00 AM Rig Release: 7/8/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/20/2015 24 hr Summary RDMO 1F 15:00 20:00 5.00 0 0 MIRU MOVE RURD P Prep for to move sub and pits off of well. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Leave 1F pad enroute to 3F pad 06/21/2015 Complete MIRU, BOPE test, Witness waived by C. Sheve,AOGCC, PT PDL&TT line. Trim 17'CT and rehead 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Arrive on 3F pad, De jeep units, Status well, Prep cellar 02:00 04:00 2.00 0 0 MIRU MOVE MOB P Spot units on well 04:00 08:00 4.00 0 0 MIRU MOVE RURD P MIRU on 3F-18 08:00 09:30 1.50 0 0 MIRU WHDBO NUND P Nipple up BOP 09:30 10:30 1.00 0 0 MIRU WHDBORURD P Prep rig to conduct BOP test **Note: Rig accepted at 09:00 hours 10:30 19:30 9.00 0 0 MIRU WHDBO BOPE P PJSM-Test BOPE ""Note: Test waived by Chuck Scheve at 5:54 am on 6/21/15 M/U nozzle, fill coil and PT inner reel iron and packoffs, End of BOPE test, no failures 19:30 20:00 0.50 0 0 MIRU WHDBO PRTS P PT PDL&TT line 20:00 21:00 1.00 0 0 MIRU WHDBOOTHR P PJSM, R/U and pull BPV. No pressure under BPV 21:00 23:00 2.00 0 0 MIRU RIGMNT CTOP P Cut 17'of CT to remove flat spot, Prep coil and rehead, Pull test to 35K, PT to 4K 23:00 23:30 0.50 0 0 MIRU RIGMNT OTHR P Run valve checklist, R/D test equipment and re heading tools 23:30 00:00 0.50 0 0 SLOT WELLPF PULD P PJSM, P/U BHA#1, BOT under reamer and BOT straight motor and 10'pup. M/U coil track to injector and surface test tool 06/22/2015 RIH with BHA#1 Under reamer. Under ream below damaged pipe section 6416. Set whip stock @ 6540. Unable to get.6°motor past 6416, M/U straight motor. Mill damaged pipe 6416. mill window 6539.6 to 6542 00:00 00:42 0.70 0 63 SLOT WELLPF PULD P Continue making up BHA#1, Surface test MWD 00:42 02:30 1.80 63 6,340 SLOT WELLPF TRIP P RIH, EDC open 02:30 02:36 0.10 6,340 6,370 SLOT WELLPF DLOG P Log K1 for+5.5', PUW=27K Page 1 of 14 11,TimeLogs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:36 03:06 0.50 6,370 6,428 SLOT WELLPF TRIP P Trip in to 6428, circ bottoms up, close EDC 03:06 03:54 0.80 6,428 6,490 SLOT WELLPF REAM P Pumps on 1.7 BPM @ 3310 PSI FS, BHP=2835, Ream down 2 FPH 03:54 04:00 0.10 6,480 6,490 SLOT WELLPF REAM P Stop at 6480, S/D pump and P/U, PUW=30K, RBIH to 6490 and start reaming down from there, 04:00 05:00 1.00 6,490 6,590 SLOT WELLPF REAM P 6490, ream down, 1.7 BPM @ 3300 PSI FS, BHP=2860, IA=485, OA=484 05:00 05:12 0.20 6,590 6,590 SLOT WELLPF CIRC P Slowly ream uphole waiting for milling fluid to get to reamer-4BBIs, 05:12 06:42 1.50 6,590 63 SLOT WELLPF TRIP P Open EDC,Trip out 06:42 07:42 1.00 63 63 SLOT WELLPF OWFF P Check well for flow, PJSM,still residual at the shaker,close choke and monitor for another 20 mins. looks good, 07:42 08:42 1.00 63 0 SLOT WELLPF PULD P LD under-reamer BHA#1 08:42 09:42 1.00 0 74 SLOT RPEQP1 PULD P MU WS setting BHA#2 09:42 10:57 1.25 74 6,350 SLOT RPEQP1TRIP P RIH with 3.5', Baker Monobore XL WS, 10:57 11:12 0.25 6,350 6,376 SLOT RPEQP1 DLOG P Tie into the K1 marker correction of plus 5.5 ft, PUW 26k 11:12 11:42 0.50 6,376 6,550 SLOT RPEQP1TRIP P Continued in hole to 6550.5 ft, ****Note: Seen 6417 ft, 5k bobble RIH with WS through wrinkled tubing. 11:42 11:57 0.25 6,550 6,550 SLOT RPEQP1 TRIP P Set TOWS at 6540 ft 20 LOHS 11:57 12:57 1.00 6,550 73 SLOT RPEQP1TRIP P POOH 12:57 13:27 0.50 73 73 SLOT RPEQP1 OWFF P Check well for flow, PJSM 13:27 13:57 0.50 73 0 SLOT RPEQPI PULD P LD WS setting tools 13:57 14:27 0.50 0 73 PROD1 WHPST PULD P MU Window milling BHA 14:27 15:27 1.00 73 6,350 PROD1 WHPST TRIP P RIH with 0.6 ako motor and new window mill with used string reamer 2.79 no-go. 15:27 15:42 0.25 6,350 6,376 PROD1 WHPST DLOG P Log into the K1 correction of plus 6.0 ft, 15:42 15:57 0.25 6,376 6,422 PROD1 WHPST TRIP P Continue RIH to TOWS 15:57 16:15 0.30 6,422 6,422 PROD1 WHPST TRIP T Set down 6422 ft, 7k DHWOB, PUW 32k, Discuss with town on plan forward, desicion was made to POOH for a straight motor. 16:15 17:09 0.90 6,422 73 PROD1 WHPST TRIP T POOH 17:09 17:39 0.50 73 73 PROD1 WHPST OWFF T Check for well for flow, PJSM 17:39 19:09 1.50 73 62 PROD1 WHPST PULD T Lay down BHA#3.6°motor, M/U BHA#4 with 2 1/8"BOT straight Motor. M/U to coil and test 19:09 20:15 1.10 62 6,340 PROD1 WHPST TRIP T Trip in hole 20:15 20:21 0.10 6,340 6,360 PROD1 WHPST DLOG T Log K1 for+5.5' Page 2 of 14 • •Time'Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:21 20:39 0.30 6,360 6,430 PROD1 WHPST TRIP T Continue trip in, Set down @ 6418, PUW=27K, Bring on pumps and mill down 6416 to 6430 20:39 21:09 0.50 6,430 6,540 PROD1 WHPST TRIP P Pumps to min rate, continue in hole, . Tag TOWS @ 6540. PUH to 6475 and ream down through weight bobbles observered RIH 21:09 00:00 2.85 6,540 6,543 PROD1 WHPST MILL P 6439.6', Start time milling window pre procedure and BOT rep. 1.74 BPM ©3160 PSI FS, BHP=3334, RIW=13.5K 06/23/2015 Complete milling window 6540 to 6545, Drill build, 6545'to 7000'.Trip out for lateral drilling BHA 00:00 03:06 3.10 6,543 6,547 PROD1 WHPST WPST P Continue milling window, 1.7 BPM @ 3160 PSi FS 03:06 05:06 2.00 6,547 6,554 PROD1 WHPST WPST P Goto 2 FPH, 7'down from pinch point. 6544.2 weight started coming down estimate BOW 05:06 05:51 0.75 6,554 6,554 PROD1 WHPST REAM P 6554', cut rathole short due to straight motor, Back ream and dry drift window 05:51 06:06 0.25 6,554 6,395 PROD1 WHPST REAM P PUH,to 6395 ft, dry drift down through tight spots to top of window 6530 ft 06:06 07:21 1.25 6,395 72 PROD1 WHPST WPST P POOH 07:21 07:36 0.25 72 0 PROD1 WHPST SFTY P PJSM, Undeploy window milling BHA#4 07:36 08:36 1.00 0 0 PROD1 WHPST PULD P Undeploy milling BHA#4 08:36 10:30 1.90 0 73 PROD1 DRILL PULD P MU build BHA#5, PD BHA#5,test MWD. Stab on wellhead. 10:30 12:36 2.10 73 6,554 PROD1 DRILL TRIP P RIH w/BHA#5,tie-in to K1 for+6' correction, PUW=28K, small bobble through tubing buckle @ 6,430', continue in hole. 12:36 15:00 2.40 6,554 6,620 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,055 PSI, BHP=3,645 PSI, CTW=10K, WOB=1.75K, ROP=50. 15:00 16:15 1.25 6,620 6,689 PROD1 DRILL DRLG P Continue drilling same parameters, change tool face to 30-40 left. 16:15 16:27 0.20 6,689 6,340 PROD1 DRILL WPRT P PUH for K1 tie-in, log RA. 16:27 16:57 0.50 6,340 6,688 PROD1 DRILL DLOG P Log K1 for +.5', RBIH to 6550 and log RA marker @ 6546.5, TOWS=6540' 16:57 17:03 0.10 6,688 6,689 PROD1 DRILL WPRT P RBIH to drill build 17:03 19:21 2.30 6,689 6,811 PROD1 DRILL DRLG P 6689', Drill, 1.5 BPM @3011PSI FS, BHP=3708 19:21 19:51 0.50 6,811 6,811 PROD1 DRILL WPRT P Wiper to window, PUW=26K 19:51 21:45 1.90 6,811 7,000 PROD1 DRILL DRLG P 6811', Drill 1.66 BPM @ 3220PSl FS, BHP=3660 21:45 23:03 1.30 7,000 76 PROD1 DRILL TRIP P 7000', Call EOB/Turn POOH, PUW=26K 23:03 23:51 0.80 0 0 PROD1 DRILL PULD P At surface, PJSM, PUD build BHA# 5 23:51 00:00 0.15 0 PROD1 DRILL PULD P M/U BHA#6, prep for PD Page 3 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/24/2015 24 hr Summary Drill lateral 7000'to 8524',Swap Mud 00:00 02:24 2.40 0 72 PROD1 DRILL PULD P M/U BHA#6, lateral section BHA with.5°ako motor and rebuilt bi center. PD into well, M/U coil and surface test tools 02:24 03:54 1.50 72 6,350 PROD1 DRILL TRIP P Trip in hole EDC open 03:54 04:00 0.10 6,350 6,369 PROD1 DRILL DLOG P Log K1 for+7', PUW=24K, Close EDC 04:00 04:24 0.40 6,369 7,000 PROD1 DRILL TRIP P Continue in well, Clean pass through window and krinkle area, RIW=12K 04:24 07:06 2.70 7,000 7,360 PROD1 DRILL DRLG P 7000',drill ahead, 1.66 BPM @ 3390 PSI FS, BHP=3681,WHP=240 07:06 07:48 0.70 7,360 7,360 PROD1 DRILL WPRT P Wiper to 6,650', PUW=26K, RBIH. 07:48 10:00 2.20 7,360 7,600 PROD1 DRILL DRLG P Start pumping new mud system,9.4 ppg Flo-Pro. Drill ahead: 1.60 BPM ©3,760 PSI, BHP=3,835 PSI, CTW=BK,WOB=1.5K, ROP=110. New mud at bit 7,430'. 10:00 11:00 1.00 7,600 7,600 PROD1 DRILL WPRT T GEO called for wiper trip,slow wiper 5 fpm to 7,290', GEO challenged. RBIH @ 10:50. 11:00 12:24 1.40 7,600 7,710 PROD1 DRILL DRLG P Drill ahead: 1.60 BPM @ 3,890 PSI, BHP=3,820 PSI, CTW=BK, WOB=1K, ROP=80. 12:24 13:03 0.65 7,710 7,710 PROD1 DRILL WPRT P Wiper to 6,800', PUW=27K, RBIH @ 12:50. 13:03 16:36 3.55 7,710 8,060 PROD1 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,990 PSI, BHP=3,815 PSI, CTW=6.2K, WOB=1.5K, ROP=100. 16:36 17:12 0.60 8,060 6,565 PROD1 DRILL WPRT P Wiper for tie-in, PUW=27K 17:12 17:18 0.10 6,565 6,585 PROD1 DRILL DLOG P Log RA Marker for+.5' 17:18 17:54 0.60 6,585 8,060 PROD1 DRILL WPRT P Wiper trip back to bottom 17:54 21:36 3.70 8,060 8,360 PROD1 DRILL DRLG P 8060', Drill, 1.6 BPM @ 3810 PSI FS, BHP=3780 21:36 22:18 0.70 8,360 8,360 PROD1 DRILL WPRT P Wiper to 7300', PUW=25K 22:18 00:00 1.70 8,360 8,524 PROD1 DRILL DRLG P 8360', Drill, 1.6 BPM @ 3880 PSI FS, BHP=3870 06/25/2015 Drill to 8623', Out of target. POOH for billet. Run OH anchored billet to 7750.Trip out for drill by BHA. Trip in and start kicking off 00:00 00:24 0.40 8,524 8,546 PROD1 DRILL DRLG P 8524', Drill 1.6 BPM @ 3880 PSI FS, BHP=3838 00:24 02:12 1.80 8,546 8,546 PROD1 DRILL WPRT T 8546, Geo wiper, PUW=25K 02:12 04:00 1.80 8,546 8,600 PROD1 DRILL DRLG P Options discussed with town, Turn down to 80°inc.to P/U pay zone, 1.60BPM @ 3880PS1 FS 04:00 04:24 0.40 8,600 8,600 PROD1 DRILL WPRT P Wiper trip through HRZ up to 8500, re run res tool through interval, PUW=25K Trip looked good. Page 4 of 14 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:24 06:39 2.25 8,600 8,623 PROD1 DRILL DRLG P 8600', Drill 1.6 BPM @ 3838 PSI FS, BHP=3936, BHA wiper @ 6,817', ratty drilling,several restarts. Got alarm at shale shaker, one shaker motor had vibrated loose and was laying shaker pan. Divert returns to tiger tank. Decide to POOH for plug back assembly. 06:39 07:51 1.20 8,623 76 PROD1 DRILL TRIP T POOH w/BHA#6 07:51 09:27 1.60 76 0 PROD1 DRILL PULD T PJSM. PUD BHA#6, LD BHA. Continue making repairs to shaker motor. 09:27 11:21 1.90 0 73 PROD1 STK PULD T PJSM. MU/PD BHA#7 plug back assembly. Shaker work completed. 11:21 14:00 2.65 73 7,776 PROD1 STK TRIP T RIH w/BHA#7 OH anchored billet, tie-in K1 for+6'correction, continue in hole, no issues through tight spot @ 6,420', RIH to set depth© 7,776.4, OH anchor orientation 170 deg, PUW=24, release from billet, set down 3K on billet, TOB @ 7,765'. 14:00 15:45 1.75 7,776 76 PROD1 STK TRIP T POOH w/BHA#7 15:45 19:09 3.40 76 73 PROD1 STK PULD T PJSM, PUD BHA#7, M/U and PD BHA#8 with .7°motor and RB bi center. M/U to coil and surface test tool 19:09 20:21 1.20 73 6,350 PROD1 STK TRIP T RIH BHA#8, EDC open 20:21 20:33 0.20 6,350 6,376 PROD1 STK DLOG T Log K1 for+5.5', Close EDC, PUW=24K 20:33 21:03 0.50 6,376 7,765 PROD1 STK TRIP T Continue in hole, Dry tag TOB @ 7765.4 21:03 00:00 2.95 7,765 7,765 PROD1 STK MILL T Bring pumps on 1.5 BPM©3698 PSI FS, BHP=3750, tag up at 7760.6.very sticky,stacking out and stalling. Run different pump rates. Hanging up before getting on billet. finally get going J6/26/2015 Drill"A"lateral to plan TD @ 9334, Pump sweeps perform swab wiper 00:00 01:54 1.90 7,765 7,780 PROD1 STK DRLG T Drilling-stalling 1.55 BPM @ 3880PS1 FS, BHP=3813 01:54 02:00 0.10 7,780 7,780 PROD1 STK WPRT T PUH to drift billet area, Looks good, PUW=24K 02:00 04:06 2.10 7,780 8,065 PROD1 DRILL DRLG T 7780', Drill ahead, 1.55 BPM @ 3730PSI FS, BHP=3800 04:06 04:54 0.80 8,065 8,065 PROD1 DRILL WPRT T Wiper to 7065 with 5 X 5 sweeps, PUW=25K 04:54 07:00 2.10 8,065 8,360 PROD1 DRILL DRLG T 8065', Drill ahead, 1.45BPM @ 3664PSI FS, BHP=3775, RIW=11 K 07:00 07:51 0.85 8,360 8,360 PROD1 DRILL WPRT T Wiper to window, PUW=26K, RBIH. 07:51 11:09 3.30 8,360 8,622 PROD1 DRILL DRLG T Drill ahead:1.54 BPM @ 3,900 PSI, BHP=3,915 PSI, CTW=6K, WOB=1.3K, ROP=80. BHA wiper @ 8,487'. Start pumping new mud, new mud at bit 8,550'. Off trouble time. Page 5 of 14 ' Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:09 11:36 0.45 8,622 8,665 PROD1 DRILL DRLG P Drill ahead:1.54 BPM @ 3,710 PSI, BHP=3,920 PSI, CTW=4K, WOB=1.7K, ROP=80. 11:36 13:27 1.85 8,665 8,665 PROD1 DRILL WPRT P Wiper for tie-in, PUW=26K,tie-in RA tag for+2.5'correction, RBIH. 13:27 15:27 2.00 8,665 8,965 PROD1 DRILL DRLG P Drill ahead:1.55 BPM @ 3,650 PSI, BHP=3,825 PSI, CTW=8.5K,WOB= .7K, ROP=150. 15:27 16:18 0.85 8,965 8,965 PROD1 DRILL WPRT P Wiper trip, PUW=25.5K, RBIH. 16:18 18:00 1.70 8,965 9,200 PROD1 DRILL DRLG P Drill ahead:1.50 BPM @ 3,650 PSI, BHP=3,895 PSI, CTW=6K,WOB= 1.1K, ROP=145. 18:00 18:54 0.90 9,200 9,200 PROD1 DRILL WPRT P Wiper to 8400', PUW=26K 18:54 20:24 1.50 9,200 9,334 PROD1 DRILL DRLG P 9200', Drill 1.55 BPM @ 3650 PSI FS, BHP=3920, 20:24 23:24 3.00 9,334 72 PROD1 DRILL WPRT P 9334', Call TD, 10 X 10 Sweeps heading down, Chase sweeps to swab 23:24 00:00 0.60 72 3,741 PROD1 DRILL WPRT P At surface, Reset counters, RIH 06/27/2015 Complete wiper trip, Lay in liner running pill, M/U Completion non ported bull nose, 64 jts liner and shorty deployment sleeve. Did not get to TD. POOH and shorten liner to 26 jts, 790', RIH 00:00 00:24 0.40 3,741 6,330 PROD1 DRILL WPRT P RIH after chasing sweeps to swab valve 00:24 00:30 0.10 6,330 6,385 PROD1 DRILL DLOG P Log K1 for+12.5'correction 00:30 00:48 0.30 6,385 6,570 PROD1 DRILL WPRT P RIH to 6459, Close EDC 00:48 00:54 0.10 6,570 6,582 PROD1 DRILL DLOG P Log RA to double check 12.5' correction, No correction 00:54 02:00 1.10 6,582 9,335 PROD1 DRILL WPRT P Continue in to confirm TD 02:00 04:36 2.60 9,335 105 PROD1 DRILL TRIP P Tag TD @ 9335, POOH on beaded liner pill followed with 11.8 PPG completion fluid, Paint EOP flag @ 7200&4400 04:36 05:06 0.50 105 105 PROD1 DRILL OWFF P At surface, perform 30 Min no flow, PJSM to lay down BHA#8 05:06 06:33 1.45 105 0 PROD1 DRILL PULD P Lay down BHA#8. Prep floor to run liner. 06:33 10:33 4.00 0 1,970 COMPZ CASING PUTB P PJSM. MU Lower liner assembly: bull nose, one pup,64 jts slotted, and shorty deployment sleeve. PJSM. MU BHA#9. 10:33 13:15 2.70 1,970 8,205 COMPZ CASING RUNL P RIH w/BHA#9 liner assembly,tie-in EOP flag @ 4,400'for+4.5' correction,continue in hole,started stacking @ 8,138',work down to 8,187'set down,work down to deepest depth 8,205'. Cycled pipe 20 times up/down, heaviest PUW=40K, unable to get back down to 8,205', tag up @ 8,186'. Call townfor plan B. 13:15 15:15 2.00 8,205 1,970 COMPZ CASING PULL T POOH w/liner assembly,waiting on plan B. 15:15 15:45 0.50 1,970 1,970 COMPZ CASING OWFF T No Flow Check -_ _ Page 6 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 18:00 2.25 1,970 1,000 COMPZ CASING PULL T PJSM. Prep floor to LD liner. LD 38 jts slotted liner. 18:00 20:18 2.30 1,000 790 COMPZ CASING PULL T Crew change, Valve checklist, PJSM lay down liner 20:18 20:54 0.60 790 834 COMPZ CASING PULD T PJSM, M/U Coil track to loner, M/U to coil and surface test 20:54 21:54 1.00 834 5,230 COMPZ CASING TRIP T Trip in well, EDC closed 21:54 22:00 0.10 5,230 5,234 COMPZ CASING DLOG T Stop and correct to flag, +4.5', PUW=22K 22:00 22:30 0.50 5,234 7,120 COMPZ CASING TRIP T Continue in hole 22:30 22:36 0.10 7,120 7,138 COMPZ CASING DLOG T Tie into K1 for+3'correction 22:36 00:00 1.40 7,138 8,734 COMPZ CASING TRIP T Continue in hole, Clean trip through window and past 8100 to 8205 area. Set down and start working liner from 8667. Get to hard bottom©8734. Deployment sleeve @ 7942 36/28/2015 Run"A"liner in 3 segments, 9335 to TOLB@ 7397, Drill off liner top billet to 7399 00:00 01:06 1.10 8,734 9,335 COMPZ CASING TRIP P Bring pumps on in compression.75 for 30 seconds. Work pipe past 8734 to 9016 set down.work to 9020 roll pump in compression. set down© 9132 work pipe, roll pump get to 9293 work pipe, roll pump,get to 9339 in compression, Call bottom 9335', Pump off liner 01:06 02:12 1.10 9,335 6,330 COMPZ CASING TRIP P release from liner, PUH pumping across top, Reset depth to liner left in hole, Paint EOP flag©7600' 02:12 02:18 0.10 6,330 6,348 COMPZ CASING DLOG P Log K1 for+.5' 02:18 03:30 1.20 6,348 58 COMPZ CASING TRIP P Continue trip out, Paint EOP flag ©5600' 03:30 04:00 0.50 58 58 COMPZ CASING OWFF P At surface, 30 Min flow check 04:00 04:30 0.50 58 0 COMPZ CASING PULD P PJSM, Lay down BHA#10"A" lateral lower liner segment running tools 04:30 07:00 2.50 0 855 COMPZ CASING PUTB P PJSM, P/U BHA#11, ported deployment sleeve, 27 jts slotted liner, shorty deployment sleeve 07:00 10:00 3.00 855 8,545 COMPZ CASING RUNL P RIH w/middle liner assembly,tie-in EOP flag for+4.5'correction, continue in hole to set depth, PUW=34K,set down 3K @ 8,545', release from liner, PUW=27K, subtract 810'from counter. 10:00 11:00 1.00 8,545 66 COMPZ CASING TRIP P POOH w/BHA#11, paint EOP flag @ 6,000', continue OOH. 11:00 11:30 0.50 66 66 COMPZ CASING OWFF P Flow check, no flow. 11:30 11:51 0.35 66 0 COMPZ CASING PULD P PJSM. LD BHA#11 11:51 13:09 1.30 0 398 COMPZ CASING PUTB P PJSM. MU Upper liner assembly: bull nose, 11 jts slotted, OH anchored billet. MU BHA#12,test tool. Page 7 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:09 15:39 2.50 398 7,735 COMPZ CASING RUNL P RIH w/BHA#12, tie-in EOP flag for +5.2'correction, continue in hole to set depth, PUW=27.5, set down 2.5K, release from liner assembly, PUW=27K. PUH to 7,300', reset depth. 15:39 17:03 1.40 7,735 80 COMPZ CASING TRIP P POOH w/BHA#12 17:03 17:33 0.50 80 80 COMPZ CASING OWFF P Flow check, no flow. 17:33 18:45 1.20 80 0 COMPZ CASING PULD P PJSM. LD BHA#12. Perform BOP function test. 18:45 20:00 1.25 0 72 PROD2 STK PULD P PJSM. M/U BHA#13 Lareral drilling with .7°AKO motor and re built Hycalog bi center 20:00 21:18 1.30 72 6,350 PROD2 STK TRIP P RIH with EDC open 21:18 21:24 0.10 6,350 6,379 PROD2 STK DLOG P Log K1 for+6'correction 21:24 21:48 0.40 6,379 7,397 PROD2 STK TRIP P RIH, Dry tag billet @7397, PUH roll hole to 9.4PPG FloPro 21:48 22:48 1.00 7,397 7,200 PROD2 STK CIRC P Displacing well to 9.4 FloPro 22:48 23:06 0.30 7,200 7,397 PROD2 STK TRIP P RIH 23:06 00:00 0.90 7,397 7,399 PROD2 STK MILL P Mill off billet, 1.5BPM @ 3460 PSI FS, BHP=3735 06/29/2015 Drill AL1 lateral 7399 to 8910, Perform mud swap 00:00 00:42 0.70 7,399 7,450 PROD2 DRILL DRLG P 7399, See loss of DH weight, P/U speed, 1.5 BPM @ 3460 PSI FS, BHP=3742 00:42 00:48 0.10 7,450 7,450 PROD2 DRILL WPRT P Drift billet area, PUW=26K, Looks good 00:48 03:36 2.80 7,450 7,700 PROD2 DRILL DRLG P 7450', Drill, 1.5BPM @ 3460 PSI FS, BHP=3820 03:36 04:36 1.00 7,700 7,700 PROD2 DRILL WPRT P 7700',Wiper to 6600', PUW=27K 04:36 08:00 3.40 7,700 8,010 PROD2 DRILL DRLG P 7700', Drill 1.5 BPM @ 3460 PSI FS, BHP=3810 08:00 08:45 0.75 8,010 8,010 PROD2 DRILL WPRT P Wiper trip, PUW=27, RBIH. 08:45 13:30 4.75 8,010 8,310 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3750 PSI, BHP=3,825 PSI, CTW=8.5K, WOB=1.4K, ROP=65 13:30 15:00 1.50 8,310 8,310 PROD2 DRILL WPRT P Wiper trip for tie-in, PUW=27K, tie-in for+3'correction, RBIH. 15:00 19:18 4.30 8,310 8,610 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3750 PSI, BHP=3,815 PSI, CTW=8.5K, WOB=1.3K, ROP=55. Start mud swap, new mud at bit 8,434'. 19:18 20:12 0.90 8,610 8,610 PROD2 DRILL WPRT P 8610',Wiper to 7610, PUW=27K 20:12 23:12 3.00 8,610 8,910 PROD2 DRILL DRLG P 8610 Drill, 1.52 BPM @ 3400 PSI FS, BHP=3840 23:12 00:00 0.80 8,910 8,300 PROD2 DRILL WPRT P 8910 Wiper to 7710'with 5 X 5 sweeps, PUW=26K 06/30/2015 Drill AL1 lateral from 8,910-ft to extended TD at 9,400-ft. Pump sweeps,wiper to swab. Lay in liner running pill from 9,300-ft. M/U non ported bull nose,42 jts slotted and shorty deployment sleeve to BHA#14. RIH with lower AL1 liner assembly. __. _. Pana 8 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:48 0.80 8,310 8,910 PROD2 DRILL WPRT P Continue wiper from 8910 00:48 03:54 3.10 8,910 9,210 PROD2 DRILL DRLG P 8910', Drill ahead, 1.54 BPM @ 3550 PSI FS, BHP=3875 03:54 04:54 1.00 9,210 6,570 PROD2 DRILL WPRT P 9210 Wiper to window with tie in, PUW=26K, Pumped 5 X 5 sweeps 04:54 05:00 0.10 6,570 6,586 PROD2 DRILL DLOG P Log RA marker for+3.5' 05:00 06:09 1.15 6,586 9,212 PROD2 DRILL WPRT P Continue wiper trip back to bottom 06:09 08:42 2.55 9,212 9,400 PROD2 DRILL DRLG P Drill ahead: 1.53 BPM @ 3,750 PSI, BHP=3,940 PSI, CTW=8K, WOB=2K, ROP=75. Extended TD to 9,400'. Pumped 10 X 10 sweep. 08:42 11:36 2.90 9,400 72 PROD2 DRILL WPRT P Chase sweeps to swab, logged MAD pass 6,800'to 6,560', continue OOH. 11:36 14:18 2.70 72 9,400 PROD2 DRILL TRIP P Reset counter. RBIH for corrected TD,tie-in K1 for+6.5'correction,tag TD @ 9,400'. Start pumping completion fluid. PUH to 9,300'. 14:18 17:24 3.10 9,400 72 PROD2 DRILL DISP P POOH laying in liner pill/completion fluid 17:24 18:09 0.75 72 72 PROD2 DRILL OWFF P At surface, monitor well for flow, crew change out, PJSM. 18:09 18:45 0.60 72 0 PROD2 DRILL PULD P LD BHA#12 18:45 19:30 0.75 0 0 COMPZ CASING PUTB P PJSM-Prep floors to run liner, service top drive. 19:30 21:30 2.00 0 1,262 COMPZ CASING PUTB P PJSM-MU AL1 lower liner assembly, bull nose,42 jts slotted and shorty deployment sleeve. Tripping drill performed, safety joint inspected by Baker rep. 21:30 22:33 1.05 1,262 1,306 COMPZ CASING PULD P PJSM-MU AL1 lower liner assembly to BHA#14, MU to CoilTrak, surface test. 22:33 00:00 1.45 1,306 6,960 COMPZ CASING RUNL P RIH with BHA#14,tie in at EOP flag at 5,100-ft for plus 5-ft correction, PUW 28k at window. 07/01/2015 Ran"AL1"liner in 3 segments 9,300-ft to top of anchored aluminum liner top billet at 6,662-ft. Drill off billet to 6,667-ft,drilling AL2 build section in progress. 00:00 01:21 1.35 6,960 9,300 COMPZ CASING RUNL P Continue RIH with BHA#14, no correction at K1, lost push at 9,227-ft, PUW 32k,work to 9,261-ft, roll pump,work to 9,300-ft 01:21 01:30 0.15 9,300 8,038 COMPZ CASING RUNL P 9,300-ft, Release from liner, PUW 26k,good WOB change, reset depth to liner left in hole,top of liner at 8,038-ft. 01:30 03:24 1.90 8,038 44 COMPZ CASING TRIP P POOH pumping over the top, paint EOP flag's at 6,500-ft and 5,000-ft 03:24 03:54 0.50 44 44 COMPZ CASING OWFF P At surface, monitor well for flow, PJSM. 03:54 04:21 0.45 44 0 COMPZ CASING PULD P LD BHA#14 04:21 07:33 3.20 0 1,341 COMPZ CASING PUTB P PJSM-MU AL1 middle liner assembly, ported bull nose,44 jts slotted, 3 pups 9.10-ft, 9.42-ft,2.81-ft and shorty deployment sleeve. __Page 9 of 14 •Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:33 08:12 0.65 1,341 1,406 COMPZ CASING PULD P PJSM-MU AL1 middle liner assembly to BHA#15, MU to CoilTrak, surface test. 08:12 10:09 1.95 1,406 8,038 COMPZ CASING RUNL P RIH w/BHA#15, tie-into K1 no correction,continue in hole,tag up on lower assembly©8,038'. PUW=31 K,set down 5K, release from liner, PUW=25K. Reset depth. 10:09 11:12 1.05 8,038 56 COMPZ CASING TRIP P POOH w/BHA#15 11:12 11:42 0.50 56 56 COMPZ CASING OWFF P Flow check, no flow. 11:42 12:06 0.40 56 0 COMPZ CASING PULD P PJSM. LD BHA#15 12:06 12:57 0.85 0 73 COMPZ CASING PULD P PJSM. MU OH anchored billet assembly, MU BHA#16,test tools. 12:57 14:51 1.90 73 6,675 COMPZ CASING TRIP P Open EDC. RIH w/BHA#16,tie-in K1 for+6'correction,continue in hole, PUW above window 27K, tag up on middle liner assembly @ 6,675', release from billet, PUW=27K. 14:51 16:00 1.15 6,675 66 COMPZ CASING TRIP P POOH for drilling assembly 16:00 16:30 0.50 66 66 COMPZ CASING OWFF P Flow check, no flow. 16:30 16:51 0.35 66 0 COMPZ CASING PULD P PJSM. LD BHA#16 16:51 18:15 1.40 0 0 COMPZ CASING PRTS P Pressure test new ODS PDL, crew change out 18:15 19:39 1.40 0 72 PROD3 STK PULD P PJSM-MU BHA#17 Drilling assembly, 1.9°AKO motor with HCC RB Bi-center bit, changed out float valves, MU to CoilTrak,surface test. 19:39 20:57 1.30 72 6,350 PROD3 STK TRIP P RIH with EDC open. 20:57 21:03 0.10 6,350 6,375 PROD3 STK DLOG P Tie in at K1 for plus 6-ft correction. 21:03 21:15 0.20 6,375 6,530 PROD3 STK TRIP P RIH, PUW above window 28k. 21:15 22:30 1.25 6,530 6,400 PROD3 STK DISP P Displace hole over to 9.4 ppg FloPro drilling fluid above window, close EDC. 22:30 22:45 0.25 6,400 6,662 PROD3 STK KOST P RIH dry tag top of liner at 6,662.5-ft, PUH 28k. 22:45 00:00 1.25 6,662 6,667 PROD3 STK KOST P 6,662-ft, Drill off billet 1.5 bpm at 3,577 psi, BHP 3,661 psi, aluminum across shaker at bottoms up, drilled off billet quickly 37/02/2015 Drill build section from 6,667-ft to 6,825-ft. POOH. PUD/LD BHA#17. MU/PD/RIH with BHA#18. Drill ahead AL2 lateral from 6,825-ft to 7,872-ft. Perform mud swap. Drilling in progress 00:00 00:15 0.25 6,667 6,672 PROD3 STK KOST P 6,667-ft, Drilling off billet 1.53 bpm at 3,611 psi, BHP 3,667 psi. 00:15 00:39 0.40 6,672 6,700 PROD3 DRILL DRLG P 6,672-ft, Drill ahead build section 1.53 bpm at 3687 psi, BHP 3,669 psi,WH 127, IA 243, OA 283 00:39 00:48 0.15 6,700 6,700 PROD3 DRILL TRIP P POOH to 6,635-ft, PUW 28k, RBIH, drift billet area clean. Page 10 of 14 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:48 03:18 2.50 6,700 6,825 PROD3 DRILL DRLG P 6,700-ft, BOBD 1.54 bpm at 3,679 psi, BHP 3,685 psi,WH 129, IA 244, OA 290 03:18 05:00 1.70 6,825 72 PROD3 DRILL TRIP P 6,825-ft, Build TD called, POOH for drilling assembly 05:00 07:06 2.10 72 0 PROD3 DRILL PULD P PJSM-Undeploy and LD BHA#17. PT PDL. 07:06 08:24 1.30 0 72 PROD3 DRILL PULD P MU/PD BHA#18 08:24 10:24 2.00 72 6,825 PROD3 DRILL TRIP P RIH w/lateral drilling assembly, tie-in to K1 +9'correction, PUW=26K, continue in hole. 10:24 13:33 3.15 6,825 7,175 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,805 PSI, BHP=3,720 PSI, CTW=10.5K, WOB=1.8K, ROP=110. GEO wiper @ 7,046'. 13:33 14:18 0.75 7,175 7,150 PROD3 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 14:18 17:06 2.80 7,150 7,525 PROD3 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,820 PSI, BHP=3,765 PSI, CTW=9.3K, WOB=1.3K, ROP=135. 17:06 17:48 0.70 7,525 7,525 PROD3 DRILL WPRT P Wiper to 6,700', PUW=26K, RBIH. 17:48 19:42 1.90 7,525 7,665 PROD3 DRILL DRLG P 7,525-ft, BOBD 1.53 bpm at 3,861 psi, BHP 3,770 psi,WH 60, IA 480, OA 430 19:42 20:36 0.90 7,665 7,665 PROD3 DRILL WPRT P Geo.wiper to 7,425-ft, PUW 28k, RBIH. 20:36 00:00 3.40 7,665 7,872 PROD3 DRILL DRLG P 7,665-ft, BOBD 1.53 bpm at 3,798 psi, BHP 3,792 psi,WH 100, IA 535, OA 460, CTW 8.4k,WOB 1.4k, ROP 40 **Note: Begin mud swap, pump sweeps, new mud at bit at 7,763-ft. 37/03/2015 Drill ahead AL2 lateral from 7,872-ft to 9,344-ft. Drilling in progress. 00:00 00:06 0.10 7,872 7,875 PROD3 DRILL DRLG P Drill ahead 1.55 bpm at 3,603 psi, BHP 3,788 psi,WH 199, CTW 5.6k, WOB 2.1k, ROP 29 00:06 00:42 0.60 7,875 6,565 PROD3 DRILL WPRT P Wiper for tie in, PUW 29k. 00:42 00:51 0.15 6,565 6,590 PROD3 DRILL DLOG P Log RA for plus.5-ft correction. 00:51 01:24 0.55 6,590 7,875 PROD3 DRILL WPRT P Wiper in hole, RIW 10.9k 01:24 04:57 3.55 7,875 8,175 PROD3 DRILL DRLG P 7,875-ft, BOBD at 3,650 psi, BHP 3,805 psi, CTW 8.4k,WOB 1.8k, ROP 60. 04:57 05:42 0.75 8,175 8,175 PROD3 DRILL WPRT P Wiper trip to 7,175-ft, PUW 28k, RBIH 05:42 08:21 2.65 8,175 8,475 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,760 PSI, BHP=3,860 PSI, CTW=BK, WOB=1.7K, ROP=115. 08:21 09:09 0.80 8,475 8,475 PROD3 DRILL WPRT P Wiper to 7,475', PUW=26K, RBIH. 09:09 11:24 2.25 8,475 8,775 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,850 PSI, BHP=3,885 PSI, CTW=9K, WOB=1.9K, ROP=135. 11:24 13:15 1.85 8,775 8,775 PROD3 DRILL WPRT P Wiper for tie-in, PUW=26K, RA tie-in for+2.5'correction, RBIH. Page 11 of 14 Time'Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/03/2015 24 hrSummary Drill ahead AL2 lateral from 7,872-ft to 9,344-ft. Drilling in progress. 13:15 16:27 3.20 8,775 9,075 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,890 PSI, BHP=3,882 PSI, CTW=4K, WOB=1.3K, ROP=95. 16:27 17:57 1.50 9,075 9,075 PROD3 DRILL WPRT P Wiper trip to 7,575', PUW=26K, RBIH. 17:57 22:24 4.45 9,075 9,319 PROD3 DRILL DRLG P 9,075-ft, BOBD 1.52 bpm at 3,879 psi, BHP 3,872 psi, CWT 7.0k,WOB 1.4k, ROP 90. 22:24 23:30 1.10 9,319 9,319 PROD3 DRILL WPRT P Wiper trip to 8,000-ft, RBIH 23:30 00:00 0.50 9,319 9,344 PROD3 DRILL DRLG P 9,319-ft, BOBD 1.50 bpm at 3,894 psi, BHP 3,940 psi, CWT 5.6k,WOB '1.1k, ROP 45 07/04/2015 Drill ahead AL2 lateral from 9,344-ft to extended TD at 9,867-ft. Pump sweeps,wiper to swab. Lay in 11.8 ppg K-Formate beaded liner running pill from confirmed TD 9,867-ft. M/U non-ported bull nose,35 jts slotted and shorty to BHA#19. 00:00 05:48 5.80 9,344 9,620 PROD3 DRILL DRLG P 9,344-ft, BOBD 1.50 bpm at 3,894 psi, BHP 3,940 psi, CWT 5.6k,WOB 1.1k, ROP 45, hit ankerite 9,434'to 9,464'. 05:48 08:39 2.85 9,620 9,620 PROD3 DRILL WPRT P Wiper trip for tie-in, PUW=25K,tie-in for+4.5'correction, no issues through A4-5 shale zone, RBIH. Starting pumping new mud. 08:39 11:57 3.30 9,620 9,867 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,590 PSI, BHP=4,005 PSI, CTW=4K, WOB=1.3K, ROP=90. New mud at bit 9,627'. BHA wiper @ 9,737'& 9,784', PUW=25K. Continue drilling to TD @ 9,867'. Pump 10 X 10 sweeps. 11:57 14:27 2.50 9,867 73 PROD3 DRILL WPRT P Chase sweeps to swab, hole clean, no issues. 14:27 17:09 2.70 73 9,867 PROD3 DRILL TRIP P Tag up, reset depth, RBIH.Tie-in to K1 for+7.5'correction, continue in hole for corrected TD©9,867'. 17:09 19:48 2.65 9,867 72 PROD3 DRILL DISP P POOH laying in 11.8 ppg K-Formate beaded liner pill, completion fluid to surface, paint flags at 8,600-ft and 5,300-ft. 19:48 20:18 0.50 72 72 PROD3 DRILL OWFF P On surface, monitor well for flow, PJSM. 20:18 21:00 0.70 72 0 PROD3 DRILL PULD P LD BHA#18, bit condition 1-1-B U-G-X-I-P N-TD 21:00 21:30 0.50 0 0 COMPZ CASING PUTB P Prep floor for running liner, service top drive. 21:30 23:24 1.90 0 1,095 COMPZ CASING PUTB P PJSM-M/U bull nose,35jts slotted, shorty deployment sleeve. 23:24 00:00 0.60 1,095 1,139 COMPZ CASING PULD P PJSM-M/U lower liner assembly to BHA#19. 07/05/2015 Ran"AL2"liner in 3 segments to top of lower SBR at 6,531-ft. Begin bi-weekly BOPE test,witness waived by AOGCC rep, Jeff Jones at 15:00 on 7-5-15. 00:00 00:30 0.50 1,139 1,139 COMPZ CASING PUTB P M/U lower liner assembly and BHA #19 to CoilTrak,surface test Page 12 of 14 Time.Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 03:30 3.00 1,139 9,867 COMPZ CASING RUNL P RIH w/BHA#19,tie-in to EOP flag for plus 4.9-ft correction, PUW 29k, continue in hole,sat down at 9,192-ft, PUW 34k,work past easily, sat down at 9,815-ft, roll pump to work liner down,tag up at 9,867-ft. PUW 35k,set down 5k, release from liner, PUW 25k. Reset depth. 03:30 05:45 2.25 9,867 44 COMPZ CASING TRIP P POOH with BHA#19, paint EOP flags. 05:45 06:15 0.50 44 44 COMPZ CASING OWFF P On surface, monitor well for flow. 06:15 07:00 0.75 44 0 COMPZ CASING PULD P PJSM. LD BHA#19 07:00 10:30 3.50 0 1,448 COMPZ CASING PUTB P PJSM. Prep floor. MU second liner assembly bull nose,45 jts slotted, shorty. MU BHA#20, replace checks. 10:30 12:54 2.40 1,448 8,772 COMPZ CASING RUNL P RIH w/BHA#20,tie-in EOP flag for +4.5'correction, continue in hole,tag up @ 8,772', small weight bobbles last 25', PUW=29K, set down 3K, release from liner. PUH, PUW=26K, reset counter-1,404'. 12:54 14:21 1.45 8,772 56 COMPZ CASING TRIP P POOH w/BHA#20, paint EOP flags ©6,400'&5,600'. 14:21 14:51 0.50 56 56 COMPZ CASING OWFF P On surface, monitor well for flow. 14:51 15:21 0.50 56 0 COMPZ CASING PULD P PJSM. LD BHA#20 15:21 17:30 2.15 0 881 COMPZ CASING PUTB P PJSM. Prep floor. MU third liner assembly bull nose, 25 jts slotted,3 jts solid, SBR deployment sleeve. MU BHA#21, 17:30 19:39 2.15 881 7,368 COMPZ CASING RUNL P RIH w/BHA#21,tie-in EOP flag for plus 4.6-ft correction,continue in hole,tag up©7,365-ft, PUW 31k, set down solid 8k, release from liner. PUW 27k, reset counters, PUH and log K1 for plus 2.5-ft correction, liner set at 7,368-ft 19:39 20:33 0.90 7,368 44 COMPZ CASING TRIP P POOH with BHA#21. 20:33 21:03 0.50 44 44 COMPZ CASING OWFF P On surface, monitor well for flow. PJSM 21:03 21:30 0.45 44 0 COMPZ CASING PULD P LD BHA#21 21:30 23:45 2.25 0 0 COMPZ CASING RURD P Prep for BOPE test,jet stack, grease tree and stack, load coil and stack. 23:45 00:00 0.25 0 0 COMPZ WHDBO PRTS P PJSM- PT inner reel iron and packoffs. 37/06/2015 Complete BOPE test. Ran Upper AL2 Sweel Packer assembly to 6,534-ft,top of upper SBR at 6,401-ft. Spot inhibited seawater around bcak side of swell packer from 6,630-ft to 6,401-ft. Displace well to inhibited seawater from 6,401-ft. Freeze protect from 2,500-ft. 00:00 12:00 12.00 0 0 COMPZ WHDBO BOPE P Test BOPE 250/3500, annular 2500. **Note: Test waived by Jeff Jones at 15:00 pm on 7/5/15 Page 13 of 14 Time.Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 0 0 COMPZ WHDBO CIRC P PJSM. LD BOP test equipment. PJSM. Circulate coil back to 11.8 ppg Formate. 13:30 14:00 0.50 0 0 COMPZ CASING OWFF P Monitor for flow, no flow. 14:00 16:00 2.00 0 174 COMPZ CASING PULD P PJSM. MU Final liner assembly: Seal assembly,5'pup,XO, Halliburton swell packer assy,XO, 3 jts solid, SBR deployment sleeve. MU BHA#22. 16:00 17:45 1.75 174 6,534 COMPZ CASING RUNL P RIH w/BHA#22,tie-in for plus 6.5-ft correction, PUW 30k, RBIH, sting into SBR to 6,534.5-ft,top of upper SBR at 6,401-ft. 17:45 18:36 0.85 6,534 6,534 DEMOB WHDBO DISP P On line with corrosion inhibited seawater 1.18 bpm at 2,267 psi while sitting on SBR, returns from 6,630-ft up backside of swell packer for 15 bbls. 18:36 19:48 1.20 6,534 2,550 DEMOB WHDBO DISP P POOH loading well with corrosion inhibited seawater 19:48 21:45 1.95 2,550 44 DEMOB WHDBO FRZP P PJSM-RU LRS, P/T lines and equipment,freeze protect from 2,500-ft, RDMO LRS. 21:45 23:15 1.50 44 0 DEMOB WHDBO PULD P PJSM-Un-deploy/LD BHA#22 23:15 00:00 0.75 0 0 DEMOB WHDBO MPSP P PJSM-Bring in FMC equipment, Set BPV. 07/07/2015 Set BPV. Flush surface lines. Blow down Coil with N2.Swap out 2"reels. 00:00 01:00 1.00 0 0 DEMOB WHDBO MPSP P Set BPV. Off load FMC equipment. 01:00 05:00 4.00 0 0 DEMOB WHDBO RURD P PJSM-Flush coil and surface lines. SLB N@ caught behind move on Prudhoe side of river. remove counters,continue with rig down. 05:00 07:00 2.00 0 0 DEMOB WHDBO RURD P PJSM with SLB N2 crew, RU, cool down and P/T lines, blow down coil, RDMO SLB N2. 07:00 00:00 17.00 0 0 DEMOB WHDBO CTOP P Reel Swap Remove inner reel iron, unstab coil, remove counters, PJSM with Peak to remove and install reels, change out stripper brass 37/08/2015 Reel swap 00:00 06:15 6.25 0 0 DEMOB WHDBO CTOP P Finish changing out stripper brass, remove reel wrap and banding from reel, MU and pull test grapple,stap coil into injector and install inner reel iron and bulk head, install counters. 06:15 07:00 0.75 DEMOB Check tree bolts, all bolts loose on tree swab. 0 0 DEMOB PJSM-with Peak, complete rig move checklist, RDMO CDR2 to 2H-14 **Note: Rig release at 06:00 hours PPage14of14 • • :2 L,. Z Nto MI W• 2 4Z Ca N O. 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Attn:Ricky Elgaricio i r'� ) ATO 3-344 i r 700 G Street Anchorage,AK 99510 E\U G 2 6 26L 2 BP Exploration(Alaska)Inc. 1 1 Ir I Petrotechnical Data Center,LR2-1 .� a 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 1 1 I Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC 1 1 I 2 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 cn co u O LC) t ) 'r NI 7-I 11i mil kilo o 0 sf 0 < ' N Q I C t V3 O CL RS 0 aw W Ce a H ,, Q Z a) .— s = = u) VI" O °' a 4 ,_ 0 Co U > Nmbilep O .g Y N L N c N co c4 00 cV > V O a a o (CS w 0 M 2 CO 0 N. . . 0 YlZ 1 W n a = rn �W d O o aCO 0 o t N N O 0) V U) u) O g 2 ry m 1"' N T R O O O O N s U 2 0 N N LO I` V .O 7 'O in r c/) N N Tri H W CO OD CO U. 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N V S PTP 2-15--07 Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Thursday,June 25, 2015 9:50 AM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA); 'Jim Regg ((907) 301-6470)' Cc: Venhaus, Dan E; Starck, Kai;Ohlinger,James 1; Burke,Jason; Phillips, Ron L; Pohler, Cody J; Nabors CDR2 Company Man;Soper, Michael K(Baker Hughes INTEQ); Nabors CDR2 Directional Driller; Nabors CDR2 MWD Engineer; Nabors CDR2 Wellsite Geologist; Strumness, Laura A;Crews,Jennifer R; Krysinski, Marina L Subject: Plugback While Drilling KRU 3F-18A(PTD 215-089) Follow Up Flag: Follow up Flag Status: Flagged Victoria, ConocoPhillips expects to plugback and redrill the KRU 3F-18A lateral (PTD#215-089)due to GEOLOGIC COMPLEXITY. The KRU 3F-18APB1 plugback will be from 7765' MD to 8622' MD, which is TD achieved in the 3F- I8APB1. The 3F-18A lateral will be redrilled to the original proposed TD, and the plugback is not expected to remain open to production without liner installed. Nabors CDR2-AC expects to begin redrilling the 3F-18A lateral on 6/2512015. Thanks much for your help. Please contact me if you have any questions. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 1 likCEIVED • JUL 2 7 201J Letter of Transmittal AOGCC F./1M BAKER Date: DATA LOGGED July 24, 2015 7/251/20155 HUGHES M K BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 i Please find enclosed the directional survey data for the following well(s): 3F-18APB1 2. 1 5IQ 6 g 2 6 0 7 3 3F-18A 21 5089 26 072 3F-18AL1 21 5090 26 074 3F-18AL2 21 5091 26 075 2H-14A 21 5094 26 076 2H-14AL1 2 1 5096 26 077 (6) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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O g 7 RT WVWVW ,kD) << g C < m V - 0) O) O) 0) N (n O 7 a V m (D `G N OVD OD CO((p o h0) w w CO (p A N A N V O N v V F. n 1 CU XJ Z _ m -01 °n • i ' m mmm mmODamw » N N CN N A A A j O --I W W O (NT O > w 8 f0)1 N m CO > O 0 7' 7' m (ND Co COWV -W' O> A O CO fll 3 co co W ii O CO CO ° N C O V A A CO V O O O C w N O O C C OONNVvA O co W N co m N (D m pp NN -. N jD O A W CO N (N)1 m • n �. (O O (O V V O O O CO CO CO A O O J W V O > CO 0 (T W A A O'. m 3 3 M 3 8 3 3 3 ",--to-,,,,,,,2", P:1 o o o o o 0 0 o m rn N N N N N N N N •G M 0 H 0 o y r a D O o „1 n m (l) o' Cl) D I C111011,, CD ' Z as Mt' i��91 N iip ; - OF 1 • • 0,1:N //7, sem THE STATE Alaska Oil andGas 441 ,; rzioA Conservation Commission „.1.,,,,,_ __=_,. tLAsKA. LitiS*}� _,�=_ 333 West Seventh Avenue � : GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^`nrr Main: 907.279.1433 OFALAS143' Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3F-18A ConocoPhillips Alaska, Inc. Permit No: 215-089 Surface Location: 23' FNL, 14' FWL, Sec. 29, T12N, R9E, UM Bottomhole Location: 505' FNL, 191' FWL, Sec. 29, T12N,R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, L'Yel Cathy . Foerster Chair DATED this 2 day of June, 2015. RECEIVED STATE OF ALASKA 0 • 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 r PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil 0- Service-Winj ❑ Single Zone 0.- ic.Specify if well is proposed for: Drill ❑ Lateral I Stratigraphic Test❑ Development-Gas 1111 Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill 0 • Reentry C Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: "U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc., Bond No. 59-52-180 ' KRU 3F-18A k 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9340' N TVD: 5936' + Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:23'FNL, 14'FWL,Sec.29,T12N,R9E, UM \ ADL 25643 ., Kuparuk Oil Pool- Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2452'FNL, 113'FEL,Sec.30,T12N, R9E, UM 2574 6/3/2015 Total Depth: 9.Acres in Property: 14.Distance to 505'FNL, 191'FWL,Sec.29,T12N, R9E,UM 2459 " Nearest Property: 16630' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 96 feet 15.Distance to Nearest Well Open Surface:x- 508514 y- 5985800 Zone- 4 . GL Elevation above MSL: 42 feet to Same Pool: 3F-04,1513 16.Deviated wells: Kickoff depth: i 6540 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: ` 93° deg Downhole: psig 3Z131✓T'� Surface:2683 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 1990' 7350' 6032' 9340' 5936' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 6868' 6236' none 6793' 6167' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 262 sx AS I 121' 121' Surface 3440' 7.625" 800 sx AS III,290 sx CI G 3481' 3180' Production 6821' 5.5" 200 sx CI G 6858' 6227' Perforation Depth MD(ft): Perforation Depth TVD(ft): 6412-6428, 6480-6490, 6621-6641, 6664-6684 5818-5832, 5880-5889, 6009-6027, 6048-6067 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 correct. Contact Ron Phillips @ 265-6312 Email Ron.Phillipscop.com Printed e . Venhaus Title CTD Engineering Supervisors Signature , ,, „ v Phone:263-4372 Date 5)1\16 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: Iv_ osy 50- C12.1 —a9 6 0-01-0 I Date: 4_2_,- t5 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed re?-thane,gas hydrates,or gas contained in shales: Other: /3O P t5 t 7'-0 3 57)0 pS im�l�s req'd: Yes No [ Mud log req'd: Yes❑ No W. f})y)vi Gr r pre.ye-0 'rr-r t(s Z 2S 'assures: Yes [7 No Directional svy req'd: Yesgl No Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No[/� Approved by: P t/— _" - APPROVED BY THE COMMISSIONER COMMISSION Date:6.--2_-/s-- Form 10-40' '^ vised 10/2012) T s e iI I I r h from the date of approval(20 AAC 25.005(8)) �� S�.0e is VTL. 5/z77is 400r i 5 • • ConocoPhillips RECEWED Alaska MAY 2 2 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360AOCC May 20, 2015 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 a tri-lateral out of the Kuparuk Well 3F-18 using the coiled tubing drilling rig, Nabors CDR2-AC.✓ CTD operations are scheduled to begin in June 2015. The objective will be to drill laterals KRU 3F-18A, 3F- 18AL1 &3F-18AL2 targeting the Kuparuk A2/A3-sands. A separate sundry application is attached to plug the KRU 3F-18 (196-112) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A&C-sand perfs in 3F-18. Attached to this application are the following documents: — 10-401 Applications for 3F-18A, 3F-18AL1 & 3F-18AL2 — Detailed Summary of Operations — Directional Plans for 3F-18A, 3F-18AL1 & 3F-18AL2 — Proposed CTD Schematic — 10-403 Application to Abandon KRU 3F-18 (196-112) — Operations Summary in support of the 10-403 application If you have any questions or require additional information please contact me at 907-265-6312.. Sincerely, oZo?1 Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • S ASKA AL Kuparuk CTD Laterals NABOR 3F-18A, 3F-18AL1 & 3F-18AL2 Application for Permit to Drill Document 211C 1. Well Name and Classification 2 (Requirements of 20 AA C 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AA C 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 AA C 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AA C 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 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 3F-18A, 3F-18AL1 &3F-18AL2 7 Attachment 2: Current Well Schematic for 3F-18 7 Attachment 3: Proposed Well Schematic for 3F-18A CTD Laterals 7 Page 1 of 7 May 20, 2015 POPApplication: 3F-18A, 3F-18AL1 &-18AL2 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 3F-18A, 3F-18AL1 & 3F-18AL2. All laterals will be classified as"Development— Off' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Two laterals will target the A3 sand package and one will target the A2 sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 3F-18A, 3F-18AL1 & 3F-18AL2. 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. 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 3500 psi. Using the maximum formation pressure in the area of 3281 psi in well 3F-04, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2683 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 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)) A static bottom hole pressure of 3F-18 in July 2014 indicated a reservoir pressure of 2968 psi @ 6045' TVD or 9.4 ppg EMW. The highest pressure in an offset wells is at the 3F-04 well to the east with 3281 psi @ 5984' TVD or 10.5 ppg EMW. Using the 3F-04 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2683 psi. All the surrounding pressures are between 9.3 ppg and 10.5 ppg EMW in the A-sand formation. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled but the 3F and surrounding pads have injected gas. There is a distinct potential that free gas could be associated with any formation influx. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) An expected risk of 3F-18 is the hole stability through the A6, A5 &A4 basal shales. We will use MPD techniques to target a constant 11.8 ppg formation pressure while drilling and completing all laterals. There is a risk of differential sticking since we're drilling past the 3F-09 well and toward the 2U-12 which last tested at 7.8 ppg EMW (2409 psi @ 5933' TVD) in May 2015. There are limited backup window exit locations in 3F-18. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 May 20, 2015 PIPApplication: 3F-18A, 3F-18AL1 &-18AL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3F-18A 7350' 9340' 6032' 5936' 2%", 4.7#, L-80, ST-L slotted liner; with aluminum billet 3F-18ALI 6700' 9300' 6098' 6002' 2%", 4.7#, L-80, ST-L slotted liner with aluminum billet 3F-18AL2 6400' 9650' 5959' 5863' 2%", 4.7#, L-80, ST-L slotted liner with deployment sleeve & liner-top packer Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.50 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 7-5/8" 29.7 L-80 BTC-MOD 0' 3481' 0' 3180' 6890 4790 Prod 5112x 15.5 L-80 LTC-MOD 0' 6339' 0' 5751' 7000 4990 Casing 3-1/2" Tubing 3 '/" 9.3 L-80 EUE-MOD 6339' 6858' 5751' 6227' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-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 Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.4 ppg) — Drilling operations: Chloride-based FloVis mud (9.4 ppg)./This mud weight should hydrostatically balance reservoir pressure. However, if increased formation pressure is encountered then overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3F-18 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. — Kill Weight fluid: Two wellbore volumes of 12.9 ppg kill weight fluid will be stored at DS 1B in the is Kuparuk field, and is accessible for trucking to the rig during CTD operations. Page 3 of 7 May 20, 2015 PAPApplication: 3F-18A, 3F-18AL1 &-18AL2 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. 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. Pressure at the 3F-18 Window(6540' MD, 5935' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.4 ppg) 2901 psi 2901 psi Mud Hydrostatic(9.4 ppg) 2901 psi 2901 psi Annular friction (i.e. ECD, 0.090 psi/ft) 589 psi 0 psi Mud + ECD Combined 3490 psi 2901 psi (no choke pressure) (overbalanced (balanced -0 psi) -589 psi) Target BHP at Window(11.8 ppg) 3642 psi 3642 psi Choke Pressure Required to Maintain Target BHP 152 psi 741 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 not for an exploratory or stratigraphic test 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. Page 4 of 7 May 20, 2015 • PTD Application: 3F-18A, 3F-18AL1 & 3F-18AL2 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 3F-18 is a Kuparuk A/C-sand producer(development)well equipped with 3'/2"tubing and 3'/2" production liner. Three laterals from well 3F-18 will be drilled,two to the north(3F-18A&AL1)to recover reserves from rock producing mother bore and one to the south(3F-18AL2)to access A pay faulted out of 3F-09. CTD operations will target the Kuparuk A2 &A3 sands. Well 3F-18 was completed in the Kuparuk A-sand in 1996 with a single completion. The C-sand was perforated in 1999,but no change in rate was observed and it is assumed that the C-sand has been contributing throughout the life of the well. A RWO was completed in 2008 to replace the 3.5"tubing due to external corrosion.Well 3F-18 has been shut-in since 2011 due to rock production.Video logging of the production liner shows erosion of both the A-and C-sand perforations to be the cause of the rock production. Prior to CTD operations, an IBP will be set above the A-sand perfs and the C-sand perfs will be squeezed with cement. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A/C-sand perfs in this manner. After setting an IBP above the A-sands and squeezing cement into the C-sand perfs, the cement will be drilled out pre-rig. Nabors CDR2-AC drilling rig will set a whipstock in the 3'/2"liner at the planned kickoff point. All three laterals will exit through the 3'/2" liner at 6540' MD and will target the A2 and A3 sands. All three laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 3'/2"liner at 6400. A 3'/2"x 2%" liner-top packer will provide redundant isolation of the squeezed C-sand perfs. Pre-CTD Work 1. Pump: Load hole with seawater. 2. E-line: Drift for 2-1/8" IBP and set an IBP at 6,600'. Get a SBHP test. 3. Pump: Perform infectivity test. 4. Slickline: Drift tubing,tag top of fill. 5. Coil: Cement squeeze the C-sand perfs in the 3-1/2" liner,then clean out to 6450'. 6. Coil: Pressure test cement squeeze. Mill cement with Bi-center bit down to 6590' (40' past the base of the whipstock). Pressure test cement squeeze again. 7. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16"BOPE,test. 2. 3F-18A Sidetrack(A3 sand- north) a. Set whipstock at 6540' MD b. Mill 2.80"window at 6540' MD c. Drill 3"bi-center lateral to TD of 9340' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7350' MD 3. 3F-18AL1 Lateral(A2 sand-north) a. Kick off of the aluminum billet at 7,350' MD b. Drill 3"bi-center lateral to TD of 9,300' MD c. Run 2%" slotted liner from TD up to 6700' MD Page 5of8 May 20, 2015 P1PApplication: 3F-18A, 3F-18AL1 &3r-18AL2 4. 3F-18AL1 Lateral (A3 sand - south) a. Kick off of the aluminum billet at 6700' MD b. Drill 3"bi-center lateral to TD of 9650' MD c. Run 23/8" slotted liner from TD up to 6400' MD, inside the 31/2" liner(above C-sand perfs). Includes swell packer on 2%"blank liner below the squeezed C-sand perfs. 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Install 31/2" liner-top packer on 23/8" liner at 6400' MD. 3. Obtain static BHP. Install GLV's. 4. Return to production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, 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 slickline lubricator. 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 slickline. — 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 3F-18 CTD laterals will be displaced to an overbalancing fluid (12.0 ppg NaBr) prior to running liner. See the "Drilling Fluids" section for more details. — 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. Page 6 of 7 May 20, 2015 PAPApplication: 3F-18A, 3F-18AL1 &-18AL2 14. Disposal of Drilling Mud and Cuttings ,- (Requirements of 20 AAC 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). 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 openhole section. ✓ — Distance to Nearest Property Line and nearest well in the same pool. -Distar kw-Ai r ®tia x$ � � ' , test Welt 3F-18A 02 16,630' 1,513' 3F-04 3F-18AL1 01 16,630' 1,500' 3F-04 3F-18AL2 05 17,150' 752' 2U-12 16. Attachments Attachment 1: Directional Plans for 3F-18A, 3F-18AL1 & 3F-18AL2 Attachment 2: Current Well Schematic for 3F-18 Attachment 3: Proposed Well Schematic for 3F-18A CTD Laterals Page7of7 May 20, 2015 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3F Pad 3F-18 3F-18A Plan: 3F-18A_wp02 Standard Planning Report 08 May, 2015 BAKER HUGHES V1 ConocoPhillips W •Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 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 3F Pad Site Position: Northing: 5,985,734.46 usft Latitude: 70°22'20.081 N From: Map Easting: 508,662.33 usft Longitude: 149°55'46.550 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07 ° Well 3F-18 Well Position +N/-S 0.00 usft Northing: 5,985,800.31 usft Latitude: 70°22'20.730 N +E/-W 0.00 usft Easting: 508,513.75 usft Longitude: 149°55'50.895 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3F-18A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 8/1/2015 18.66 80.93 57,554 Design 3F-18A_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,514.85 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft)�j (usft) (usft) (°) 0.00 0.00 0.00 0.00 5/8/2015 3:13:27PM Page 2 COMPASS 5000.1 Build 61 ✓ 1Lill ConocoPhillips 0 Planning Report W BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°I100ft) (°I100ft) (°/100ft) (°) Target 6,514.85 24.08 185.43 5,815.62 -2,610.50 -340.80 0.00 0.00 0.00 0.00 6,540.00 23.95 185.36 5,838.59 -2,620.69 -341.76 0.53 -0.52 -0.28 -167.67 6,561.00 26.73 183.12 5,857.57 -2,629.66 -342.41 14.00 13.24 -10.64 340.00 6,700.22 88.00 165.43 5,929.48 -2,739.41 -324.83 45.00 44.01 -12.71 340.00 6,900.22 90.00 75.43 5,933.93 -2,830.53 -169.59 45.00 1.00 -45.00 270.00 7,070.22 92.92 358.95 5,928.82 -2,705.05 -74.29 45.00 1.72 -44.99 273.00 7,280.00 90.30 344.49 5,922.90 -2,498.11 -104.43 7.00 -1.25 -6.89 260.00 7,600.00 90.66 6.89 5,920.18 -2,181.06 -128.33 7.00 0.11 7.00 89.00 7,790.00 90.41 353.59 5,918.39 -1,991.49 -127.54 7.00 -0.13 -7.00 269.00 7,990.00 87.99 7.38 5,921.19 -1,792.02 -125.86 7.00 -1.21 6.90 100.00 8,190.00 87.81 21.39 5,928.55 -1,598.90 -76.33 7.00 -0.09 7.00 91.00 8,410.00 87.89 5.98 5,936.85 -1,385.94 -24.49 7.00 0.04 -7.00 270.00 8,510.00 90.29 12.55 5,938.44 -1,287.32 -8.39 7.00 2.40 6.58 70.00 8,610.00 90.29 5.55 5,937.93 -1,188.63 7.33 7.00 0.00 -7.00 270.00 8,810.00 90.04 19.55 5,937.36 -993.90 50.70 7.00 -0.13 7.00 91.00 9,010.00 90.04 5.55 5,937.22 -799.16 94.05 7.00 0.00 -7.00 270.00 9,240.00 90.04 21.65 5,937.07 -576.35 147.97 7.00 0.00 7.00 90.00 9,340.00 90.64 14.68 5,936.47 -481.39 179.12 7.00 0.61 -6.97 275.00 5/8/2015 3:13:27PM Page 3 COMPASS 5000.1 Build 61 •ConocoPhillips • Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1-5 +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 6,514.85 24.08 185.43 5,815.62 -2,610.50 -340.80 -2,610.50 0.00 0.00 5,983,189.68 508,175.96 TIP 6,540.00 23.95 185.36 5,838.59 -2,620.69 -341.76 -2,620.69 0.53 -167.67 5,983,179.49 508,175.01 KOP 6,561.00 26.73 183.12 5,857.57 -2,629.66 -342.41 -2,629.66 14.00 -20.00 5,983,170.53 508,174.36 End 14 dls,Start 45 dls 6,600.00 43.61 174.52 5,889.35 -2,651.98 -341.60 -2,651.98 45.00 -20.00 5,983,148.21 508,175.20 6,700.00 87.90 165.44 5,929.47 -2,739.20 -324.89 -2,739.20 45.00 -12.89 5,983,061.02 508,192.01 6,700.22 88.00 165.43 5,929.48 -2,739.41 -324.83 -2,739.41 45.00 -8.86 5,983,060.80 508,192.07 4 6,800.00 88.58 120.51 5,932.62 -2,817.00 -266.29 -2,817.00 45.00 -90.00 5,982,983.29 508,250.69 6,900.00 90.00 75.53 5,933.93 -2,830.59 -169.80 -2,830.59 45.00 -88.59 5,982,969.81 508,347.18 6,900.22 90.00 75.43 5,933.93 -2,830.53 -169.59 -2,830.53 45.00 -88.00 5,982,969.87 508,347.40 5 7,000.00 92.12 30.57 5,931.98 -2,772.03 -91.94 -2,772.03 45.00 -87.00 5,983,028.45 508,424.98 7,070.22 92.92 358.95 5,928.82 -2,705.05 -74.29 -2,705.05 45.00 -87.87 5,983,095.45 508,442.55 End 45 dls,Start 7 dls 7,100.00 92.55 356.89 5,927.40 -2,675.33 -75.37 -2,675.33 7.00 -100.00 5,983,125.16 508,441.43 7,200.00 91.31 350.00 5,924.02 -2,576.10 -86.77 -2,576.10 7.00 -100.10 5,983,224.37 508,429.92 7,280.00 90.30 344.49 5,922.90 -2,498.11 -104.43 -2,498.11 7.00 -100.33 5,983,302.33 508,412.18 7 7,300.00 90.33 345.89 5,922.79 -2,478.78 -109.54 -2,478.78 7.00 89.00 5,983,321.65 508,407.04 7,400.00 90.44 352.89 5,922.11 -2,380.55 -127.94 -2,380.55 7.00 89.01 5,983,419.85 508,388.53 7,500.00 90.56 359.89 5,921.24 -2,280.82 ' -134.24 -2,280.82 7.00 89.05 5,983,519.57 508,382.12 7,600.00 90.66 6.89 5,920.18 -2,181.06 -128.33 -2,181.06 7.00 89.12 5,983,619.33 508,387.91 8 7,700.00 90.53 359.89 5,919.13 -2,081.30 -122.43 -2,081.30 7.00 -91.00 5,983,719.08 508,393.70 7,790.00 90.41 353.59 5,918.39 -1,991.49 -127.54 -1,991.49 7.00 -91.07 5,983,808.87 508,388.48 9 7,800.00 90.29 354.28 5,918.33 -1,981.55 -128.60 -1,981.55 7.00 100.00 5,983,818.81 508,387.42 7,900.00 89.08 1.17 5,918.88 -1,881.70 -132.57 -1,881.70 7.00 100.00 5,983,918.65 508,383.34 7,990.00 87.99 7.38 5,921.19 -1,792.02 -125.86 -1,792.02 7.00 99.97 5,984,008.33 508,389.94 10 8,000.00 87.98 8.08 5,921.54 -1,782.12 -124.52 -1,782.12 7.00 91.00 5,984,018.23 508,391.27 8,100.00 87.88 15.08 5,925.16 -1,684.28 -104.47 -1,684.28 7.00 90.98 5,984,116.08 508,411.21 8,190.00 87.81 21.39 5,928.55 -1,598.90 -76.33 -1,598.90 7.00 90.72 5,984,201.48 508,439.24 11 8,200.00 87.81 20.69 5,928.93 -1,589.58 -72.75 -1,589.58 7.00 -90.00 5,984,210.81 508,442.82 8,300.00 87.83 13.68 5,932.74 -1,494.17 -43.24 -1,494.17 7.00 -89.97 5,984,306.24 508,472.21 8,400.00 87.88 6.68 5,936.48 -1,395.88 -25.59 -1,395.88 7.00 -89.71 5,984,404.54 508,489.75 8,410.00 87.89 5.98 5,936.85 -1,385.94 -24.49 -1,385.94 7.00 -89.44 5,984,414.48 508,490.84 12 8,500.00 90.05 11.90 5,938.47 -1,297.10 -10.51 -1,297.10 7.00 70.00 5,984,503.33 508,504.72 8,510.00 90.29 12.55 5,938.44 -1,287.32 -8.39 -1,287.32 7.00 69.89 5,984,513.11 508,506.82 13 8,600.00 90.29 6.25 5,937.98 -1,198.58 6.30 -1,198.58 7.00 -90.00 5,984,601.86 508,521.42 8,610.00 90.29 5.55 5,937.93 -1,188.63 7.33 -1,188.63 7.00 -90.03 5,984,611.81 508,522.44 14 8,700.00 90.18 11.85 5,937.56 -1,099.71 20.95 -1,099.71 7.00 91.00 5,984,700.73 508,535.94 8,800.00 90.05 18.85 5,937.36 -1,003.34 47.41 -1,003.34 7.00 91.03 5,984,797.12 508,562.29 8,810.00 90.04 19.55 5,937.36 -993.90 50.70 -993.90 7.00 91.04 5,984,806.57 508,565.57 15 5/8/2015 3:13:27PM Page 4 COMPASS 5000.1 Build 61 Vaal ConocoPhillips • Planning Report • BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-1N Section Rate Azimuth Northing Easting (usft) (o) (0) (usft) (usft) (usft) (usft) (°/100ft) (0) (usft) (usft) 8,900.00 90.04 13.25 5,937.29 -907.61 76.10 -907.61 7.00 -90.00 5,984,892.88 508,590.87 9,000.00 90.04 6.25 5,937.23 -809.11 93.02 -809.11 7.00 -90.00 5,984,991.39 508,607.68 9,010.00 90.04 5.55 5,937.22 -799.16 94.05 -799.16 7.00 -90.01 5,985,001.34 508,608.70 16 9,100.00 90.04 11.85 5,937.16 -710.25 107.66 -710.25 7.00 90.00 5,985,090.26 508,622.21 9,200.00 90.04 18.85 5,937.10 -613.87 134.12 -613.87 7.00 90.00 5,985,186.65 508,648.55 9,240.00 90.04 21.65 5,937.07 -576.35 147.97 -576.35 7.00 90.01 5,985,224.19 508,662.36 17 9,300.00 90.40 17.47 5,936.84 -519.83 168.05 -519.83 7.00 -85.00 5,985,280.73 508,682.37 9,340.00 90.64 14.68 5,936.47 -481.39 179.12 -481.39 7.00 -85.02 5,985,319.17 508,693.40 Planned TD at 9340.00 5/8/2015 3:13:27PM Page 5 COMPASS 5000.1 Build 61 • trig 414. ConocoPhillips • Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3F-18A_T02 0.00 0.00 5,928.00 -4,241.491,140,070.08 5,982,856.00 1,648,474.00 70°7'31.601 N 140°44'45.809 W -plan misses target center by 1139897.16usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18A_Faultl 0.00 0.00 0.00 -4,241.491,140,070.08 5,982,856.00 1,648,474.00 70°7'31.601 N 140°44'45.809 W -plan misses target center by 1139912.61 usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Rectangle(sides W430.00 H1.00 D0.00) 3F-18A_Fault2 0.00 0.00 0.00 -2,344.491,140,239.25 5,984,753.00 1,648,641.00 70°7'49.768 N 140°44'32.747 W -plan misses target center by 1140077.11 usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Rectangle(sides W360.00 H1.00 D0.00) 3F-18A_T05 0.00 0.00 5,937.00 -2,344.491,140,239.25 5,984,753.00 1,648,641.00 70°7'49.768 N 140°44'32.747 W -plan misses target center by 1140061.65usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18A_T04 0.00 0.00 5,938.00 -2,867.421,140,129.65 5,984,230.00 1,648,532.00 70°7'44.853 N 140°44'38.145 W -plan misses target center by 1139953.02usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18A T06 0.00 0.00 5,936.00 -2,027.551,140,324.62 5,985,070.00 1,648,726.00 70°7'52.719 N 140°44'28.934 W -plan misses target center by 1140146.55usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18 CTD Polygon Sou 0.00 0.00 0.00 -4,059.001,139,659.24 5,983,038.00 1,648,063.00 70°7'33.979 N 140°44'56.741 W -plan misses target center by 1139501.20usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Polygon Point 1 0.00 0.00 0.00 5,983,038.00 1,648,063.00 Point2 0.00 -146.38 333.87 5,982,892.01 1,648,397.00 Point3 0.00 -1,153.24 109.76 5,981,885.00 1,648,174.06 Point4 0.00 -2,049.08 -120.24 5,980,988.99 1,647,945.10 Point 5 0.00 -3,256.90 -392.58 5,979,780.98 1,647,674.16 Point 6 0.00 -3,166.46 -787.52 5,979,870.96 1,647,279.16 Point 7 0.00 -2,277.56 -613.54 5,980,759.97 1,647,452.11 Point8 0.00 -1,228.76 -334.37 5,981,808.98 1,647,730.06 Point 9 0.00 -347.92 -104.39 5,982,690.00 1,647,959.02 Point 10 0.00 0.00 0.00 5,983,038.00 1,648,063.00 3F-18A_T03 0.00 0.00 5,918.00 -3,527.351,140,015.88 5,983,570.00 1,648,419.00 70°7'38.614 N 140°44'44.257 W -plan misses target center by 1139840.83usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18A_T01 0.00 0.00 5,929.00 -4,285.21 1,139,820.00 5,982,812.00 1,648,224.00 70°7 31.545 N 140°44'53.135 W -plan misses target center by 1139647.23usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Point 3F-18 CTD Polygon Nor 0.00 0.00 0.00 -4,381.021,139,651.88 5,982,716.00 1,648,056.00 70°7'30.863 N 140°44'58.348 W -plan misses target center by 1139494.89usft at 9340.00usft MD(5936.47 TVD,-481.39 N, 179.12 E) -Polygon Point 1 0.00 0.00 0.00 5,982,716.00 1,648,056.00 Point 2 0.00 -144.52 467.89 5,982,572.03 1,648,524.01 Point 3 0.00 855.47 565.99 5,983,572.03 1,648,620.96 Point4 0.00 1,703.48 635.91 5,984,420.03 1,648,689.91 Point 5 0.00 2,510.33 849.81 5,985,227.04 1,648,902.87 Point 6 0.00 2,635.66 553.92 5,985,352.02 1,648,606.87 Point 7 0.00 1,869.86 298.06 5,984,586.01 1,648,351.90 Point8 0.00 917.93 152.01 5,983,634.01 1,648,206.95 Point 9 0.00 0.00 0.00 5,982,716.00 1,648,056.00 5/8/2015 3:13:27PM Page 6 COMPASS 5000.1 Build 61 •ConocoPhillips • Planning ReportBAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 3F-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3F-18 @ 96.00usft(3F-18) Site: Kuparuk 3F Pad North Reference: True Well: 3F-18 Survey Calculation Method: Minimum Curvature Wellbore: 3F-18A Design: 3F-18A_wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,340.00 5,936.47 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 6,514.85 5,815.62 -2,610.50 -340.80 TIP 6,540.00 5,838.59 -2,620.69 -341.76 KOP 6,561.00 5,857.57 -2,629.66 -342.41 End 14 dls,Start 45 dls 6,700.22 5,929.48 -2,739.41 -324.83 4 6,900.22 5,933.93 -2,830.53 -169.59 5 7,070.22 5,928.82 -2,705.05 -74.29 End 45 dls,Start 7 dls 7,280.00 5,922.90 -2,498.11 -104.43 7 7,600.00 5,920.18 -2,181.06 -128.33 8 7,790.00 5,918.39 -1,991.49 -127.54 9 7,990.00 5,921.19 -1,792.02 -125.86 10 8,190.00 5,928.55 -1,598.90 -76.33 11 8,410.00 5,936.85 -1,385.94 -24.49 12 8,510.00 5,938.44 -1,287.32 -8.39 13 8,610.00 5,937.93 -1,188.63 7.33 14 8,810.00 5,937.36 -993.90 50.70 15 9,010.00 5,937.22 -799.16 94.05 16 9,240.00 5,937.07 -576.35 147.97 17 9,340.00 5,936.47 -481.39 179.12 Planned TD at 9340.00 5/8/2015 3:13:27PM Page 7 COMPASS 5000.1 Build 61 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3F Pad 3F-18 3F-18A 3F-18A_wp02 Travelling Cylinder Report 07 May, 2015 BAKER HUGHES ,..-' • •Baker Hughes INTEQ rf il' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3F-18 Project: Kuparuk River Unit TVD Reference: 3F-18 @ 96.00usft(3F-18) Reference Site: Kuparuk 3F Pad MD Reference: 3F-18 @ 96.00usft(3F-18) Site Error: 0.00usft North Reference: True Reference Well: 3F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 3F-18A Database: OAKEDMP2 Reference Design: 3F-18A_wp02 Offset TVD Reference: Offset Datum Reference 3F-18A wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,514.85 to 9,340.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,124.40usft Error Surface: Elliptical Conic Survey Tool Program Date 5/7/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 184.00 6,514.85 3F-18(3F-18) MWD MWD-Standard 6,514.85 9,340.00 3F-18A_wp02(3F-18A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C'1 (") 9,340.00 6,032.47 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 3F Pad 3F-01 -3F-01 -3F-01 Out of range 3F-03-3F-03-3F-03 Out of range 3F-04-3F-04-3F-04 8,950.00 5,925.00 1,024.61 161.05 872.28 Pass-Major Risk 3F-09-3F-09-3F-09 6,800.00 6,875.00 919.58 179.84 742.76 Pass-Major Risk 3F-10-3F-10-3F-10 8,100.00 6,350.00 1,100.57 188.36 912.61 Pass-Major Risk 3F-11 -3F-11 -3F-11 Out of range 3F-12-3F-12-3F-12 Out of range 3F-18-3F-18-3F-18 6,550.00 6,550.00 0.13 2.33 -0.87 FAIL-Major Risk 3F-18-3F-18AL1 -3F-18AL1_wp01 7,350.00 7,350 00 0.00 0.22 -0.22 FAIL-Minor 1/10 3F-18-3F-18AL2-3F-18AL2_wp05 6,724.29 6,725.00 4.09 0.90 3.19 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/7/2015 1:18:23PM Page 2 of 10 COMPASS 5000.1 Build 65 0 0 Baker Hughes INTEQ ,A�III ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3F-18 Project: Kuparuk River Unit TVD Reference: 3F-18 @ 96.00usft(3F-18) Reference Site: Kuparuk 3F Pad MD Reference: 3F-18 @ 96.00usft(3F-18) Site Error: 0.00usft North Reference: True Reference Well: 3F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 3F-18A Database: OAKEDMP2 Reference Design: 3F-18A_wp02 Offset TVD Reference: Offset Datum Reference Depths are relative to 3F-18 @ 96.00usft(3F-18) Coordinates are relative to:3F-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.06° Ladder �/y� - -- PI t 1 I I 1 1200— 1 ' 1 1 1 1 1 1 1 1 Q 1 I JJ J It C 1 Q I el 11 I I I 1 To I A,I I I cEO I I I 1 I 1 I I 0I I I I O I I I Q J J _— J J __ O I I 7)71I ( I I I I I O I I I /�/�/� 1 U I o I 1 O I I I I, _ _ I J J J J J O O . i I I • 0 1 I I I 330— - I _. i I I I I I I I I I I I I 1 I I I J J ___ I J I I I I I I I I I I 0 I I I I 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND $ 3F-04,3F-04,3F-04V1 -9- 3F-10,3F-10,3F-10V1 4E- 3F-18,3F-18AL1,3F-18AL1 vuri31V0 —A— 3F-09,3F-09,3F-09 V2 -e- 3F-18,3F-18,3F-18 VO $ 3F-18,3F 18AL2,3F-18AL2_w4O5VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/7/2015 1:18:23PM Page 10 of 10 COMPASS 5000.1 Build 65 • • W .We om .41-- - _- 1 - - L,__: N • T - 0 a 74-_ _ _ _-__ _ -- % __ __ __- _ __-_ _ _'__reli777 7-1-7! _ - - -`y-j--- 7-7717-777-7r;n 0 ES c i & &Uifi^ - � - o di W ,d d d _SBS- _ Maa• • . 74 aa¢¢co . _ m U 2 -- l=ar -•IN =MN NOW N \ • • µ �_ • 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Comment H2S(ppm) Date Annotation End Date KB-Grd)ft) `Rig Release Date 3F-18,8/3/20143x25:00 PM SSSV:NIPPLE 150 Last WO: 12/4/2008 7/11/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,,_,.___..,__...............................____,.._.._;9 Last Tag:SLM 6,630.0 7/31/2014 Rev Reason:TAG,H2S hipshkf 8/3/2014 HANGER 36I`i8 �itl#I Casing Strings Casing Description OD(in) ID)in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15,062 42.0 121.0 121.0 62.50 H-40 WELDED 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread �. SURFACE 75/8 6.875 41,5 3,481.3 3,180.2 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 512 4.950 36.8 6,858.0 6,227.0 15.50 L-80 LTC-MOD Tubing Strings ..i,,Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;42.0-121.0 ,, TUBING 31/2 2.992 36.8 6,333.3 5,745.5 9.30 L-80 IBT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) NIPPLE;516.1 li 4 ,, 36.8 36.8 0.10 HANGER FMC 31/2"x71/16"5M TBG Hanger w/3 1/2"IBT Pup 3.500 516.1 513.7 13.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 6,277.4 5,694.3 23.45 NIPPLE Camco 2.812""DS"Nipple 2.812 6,320.4 5,733.8 23.57 SEAL ASSY Baker Seal Assembly 80-40 GBH22 w/locator(2.00' 3.000 spaceout) GAS LIFT,27399 Perforations&Slots Shot Dens Top(TVD) Btm)T/D) (shotsff Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,412.0 6,419.0 5,817.6 5,824.0 C-4,3F-18 2/4/1999 4.0 APERF 2 12"HC-DP,180 deg pH,+1-90 deg 6,419.0 6,425.0 5,824.0 5,829.5 C-4,3F-18 12/26/1998 4.0 APERF 21/2"HC-DP,180 deg pH,+1-90 deg SURFACE;41.53,481.3 6,425.0 6,428.0 5,829.5 5,832,3 C-4,3F-18 2/4/1999 4.0'APERF 2 1/2"HC-DP,180 deg pH,+/-90 deg 6,480.0 6,490.0 5,879.8 5,888.9 C-1,3F-18 5/112002 6.0 APERF 2.5"HSD,PJ DP,60 deg GAS LIFT;3,947.7 pH 6,621.0 6,641.0 6,008.7 6,027.1 A-3,3F-18 727/1996 4.0 IPERF 2 1/2"HSD,180 deg pH 6,664.0 6,684.0 6,048.2 6,066.6 A-3,A-2,3F- 3/22/2009 6.0 APERF 2 1/8"PJ,45 deg phase 18 Mandrel Inserts il GAS LIFT;4,960.8 St ati C on Nn 2Top(TVD) Valve Latch Port Size TRO Run Top)ftKB) (ftKB) Make Madel 00(in) Sam Type Type (in) (psl) Run Date_ ,739.9 2,516.0 Camco KBG-2-9 1 Gas Lift DMY IN 0.000 0.0 7/11/2011 2 3,947.7 3,594.7 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 7/11/2011 GAS LIFT,5,696.8 3 4,960.7 4,500.0 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 7/10/2011 ' 4 5,696.8 5,163.7 Camco 'KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 8/10/2009 5 6,223.8 5,645.1 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 12/6/2008 - GAS LIFT,6.223.6 Notes:General&Safety -- End Date Annotation 10/10/2005 NOTE:Surface CSG patch @ bottom of mandrel hgr,39"L X 8"OD,X65 pipe 4/9/2008 NOTE:NIPPLE @ 517'w/2.812"ID,BUT GAUGED TO 2.80" NIPPLE;6.277.4 ti 12/6/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 7/19/2011 NOTE:RAN VIDEO ON CASING DAMAGE IN 3.5 LINER FROM 6625'-6632 SEAL ASSY;6,320.4 I!�J APERF;6,412.0-6419.0 APERF;6,419.66,425.0 APERF;6,425.06826.0 APERF;6,480.0-6,490.0 (PERF;6,621.66,641.0 APERF;6864.08,684.0 PRODUCTION 5.5"z3.5";36.8- J w 6,858.0 • • Bettis, Patricia K (DOA) PTD From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Tuesday, May 26, 2015 2:06 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3F-18 Laterals: Permit to Drill Applications Patricia, Sidetrack 3F-18A will target the Kuparuk A3 sand to the north. Lateral 3F-18AL1 will target the Kuparuk A2 sand to the north. Lateral 3F-18AL2 will target the Kuparuk A3 sand to the south. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, May 26, 2015 1:58 PM To: Phillips, Ron L Subject: [EXTERNAL]KRU 3F-18 Laterals: Permit to Drill Applications Good afternoon Ron, Please clarify which wells will target the Kuparuk A2 sand and which will target the Kuparuk A3 sand. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • 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. S TRANSMITTAL LETTER CHECKLIST WELL NAME: KR( 3F-/ A- PTD: aic-oZ35 i/Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: '4 ( POOL: K c,,/J( 1 l J .J k 1( ?lbf 0l I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • El N , 0, 0 : a) N , W 20 u; co, Q a U, y N. O C.) �: a N O, Z 'C o. C11 c. 0 o v. ui a' , �. 0 w -c , O'. a)' C'. C (a y Ca, 0' 0 ° o N. E O m 3 m. E. m' o' a rn as' d C 3' C .� aa) 3 m. 06 a LL 0 co 0) 3 0 �' a a a) '3 a v co .0 a O E 0.) ii -cI- , , O. oa4), �, o: E moo' Co)' _' w. a) co' ct •V, O' E. p_ 0 , N' a0_ 4 ' E a CC U0i C � IL c O -: O y c c 0 0 a), - o o O N O �: Q O N N N N. �� y. N p O co co LL O, �� � N, o m °o' Y' " L' 3 co CO o ,- .N Z N 0 CO Z y v Co 0 D' 0' 0' o a ° >' u) cc = o' vi 1° c o 7 0 Z O. co, < M• M, O. 7 U U. 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