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• 0 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. a15 - a g Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: p‘lor Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: ISD Date: I ( 1C1//5' /s/ (1(10 4 Project Proofing r BY: (Maria) Date: ` 1 !S /sl114 r • JJJ Scanning Preparation ____c2___x 30 = &la + 02 9 = TOTAL PAGES U S (Count does not include de cover sheet) IA( BY: C Maria ' '[i' Date: [crii /s/ Production Scanning _q_9._ Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 411. Date: I I f e fi S /s/ Stage 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 1 + 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 111 • o ..) o a • n Q LL e'i c0 .N .N • 2 • • m • p ' 7. oco C U LL N NJ QaQ o 7 O a d ° °ZI c a) aL) 0 a! O D }I «0 N Z (>/� CO J J— LE— J Jit Z N > cf) >co N 0 CC (n CC (n 3 FT ~ _ _ _ _ U > V O O N J > J F ° 0 0 ' Z O 0 ,- ,-- 0 0 0 0 > � ° p pp m CO p Lii111 N 2 to N 2 to W a (i) : > 1- 0- 0_ > coCUa) Q o 0 J m a) Jrn UJ a) a) Ja) LL J J J J J J J C) C) C) C) C) C) 0)Y Y D LL IL LL LL LL pLL D CLL LL LL LL LL LL LLJU p wCt _ CC O C a ap 0 c uam a62g@ aauuacuV - Z 0 d!: LL LL,�.. LL U LLQ LL Do p it LL LL LL it it it,. 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No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #UI-I'KIN I S #OF COPIES #OF COPIES#OF COPIES 4 4 4 4 4 4 4 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 1 1 Petrotechnical Data Center,LR2-1 .. �t I 900 E.Benson Blvd. n Anchorage,Alaska 99508 AUG 2 6 L"i Attn:Dodie Stinson VC)! *; ; 3 Chevron/KRU Rep 1 1 1 1 Attn:Glenn Frederick P.O.Box 196247 I Anchorage,AK 99519 4 State of Alaska -AOGCC 1 1 2 I 1 Attn:Makana Bender 1333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 ).),I G 2 6 t u Li; i a�\ iar. _ [ ]l 5 DNR-Division of Oil&Gas *** I I I 1 I I 1 I I Attn:Sean Clifton i 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 i***Stamp"confidential"on all material deliver to DNR . 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(O CO- (0 (O (O CO- co- (D u) (O 6 O O N 0) (0 _ 7 r 7 N N. O O OD (MCO O 0 N O COO N 7 CO 7 u) CO N O O f` 7 N O cd r t` .. (p NO u .— N 0) 7 OY Na N M M ch (' MO O O 0 O O O O 0 M M l7 MN M V <6 (O (O 6 O N U) u) O 6 (O (O 6 O U) (O (O O (D C (O Y CO N r. CO u) CO 0 O 0 M 0 0) N CO 7 CO N 77 7 Q 'C co. co.7C) N 7 N 7N NNyO u) to O CO O 7 m co u) N co N = (0 C i M M M A A M M A M 2„';') 2) 2, M M M O O n 't 2 M m in CL CL Y! • ` J J (n (O 7 NO M NO O) 0) 7 N (O (O N0 7 NO W (O O N N • 0 co CO "— 7 M O .- M aD (O d 7 O O NO 7 N (O d d p ] = LL LL � = NO u) N M 7 N O O) O O N a, N • O O ▪ U Y Y .- �• m rn Ch m m rn m os co m Cr, rn a, co Nn w • ND m Z Q. Q NI- 0 cn UN (O 0) CO 7 M N r O CO CO CO O CO 0 N 0 = (() O r CO CO Cr O CO N N f0 N N N N u) N N N O V' O O O O O d u) O O O 7 cY O N O d d cd (p T 4i Q y 2 2 W O7) 8 O O O O N O O N N N M M M R 0 U O `• O r a) d y M U d in Q (i) • 111,1 215086 216085 i • 25 990 25 9- 88 � 5g89 Letter of Transmittal FANII RECEIVED BAKER Date: June 24 2015 EN DATA LOGGED JUN 2 5 2015 nB HUGHES K BENDER AO GcC To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1F-19L1PB1 ,rte ps 1F-19L1 �" 1F-19L1-01 (3) 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 3 LL LL I.1_ C °,,, m m m m m 00 W m 06000 W W W W W ..0U Y Y e- r r M h U Nr M m V V M N rN W W W W N W W N N O 71- - 2) Q 0 0 0 0 O O (upi O O O v N 0 N 0 0 0 0; N6 C C d .. ❑ N N CO Mg m O O O O r W N N M N C1 0 .Or O 0 O 0 O Q a N .. .a m N O U 0 O 0 L aN 0) y U a Co- 5 3 ❑ co Y g 's • • RECEIVED 0 STATE OF ALASKA • JUL 17 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANCAlfficc la.Well Status: Oil Li , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20nnc25.1O5 20nnc25.110 Development Q' Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: a 6/20/2015 -215-085 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 •6/4/2015 • 50-029-22660-60/50-029-22660-70 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 668'FNL, 92'FEL,Sec. 19,T11 N, R10E, UM .6/13/2015 KRU 1F-19L1 /KRU 1 F-19L1 PB1 Top of Productive Interval: 9. KB(ft above MSL): 118' 17. Field/Pool(s): 1995'FSL,674'FEL,Sec. 17,T11 N, R10E, UM GL(ft above MSL): 41' . Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1227'FNL,892'FEL,Sec. 17,T11 N, R10E, UM 11265'MD/6300'TVD ADL 25652 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539884 y- 5958860 Zone- 4 .11265'MD/6300'TVD 2578 TPI: x- 544557 y- 5961548 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 544321 y- 5963605 Zone- 4 nipple @ 508'MD/508'TVD 1468'MD/1468'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) • 8996'MD/6228'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" 232 sx AS I 7.625" 29.7# L-80 41' 4557' 41' 3822' 9.875" 690 sx AS III,400 sx CI G 5.5"x 15.5# L-80 39' 8772' 39' 6058' 6.75" 230 sx Class G 3.5" 9.3# L-80 8772' 9450' 6058' 6580' 6.75" included above 2.375" 4.6# L-80 9050' 11265' 6263' 6300' 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" 8772' 6887'MD/4990'TVD slotted liner 9200'-11265'MD 6339'-6300'TVD 'LETIOh , 1111I 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑1 * Per 20 AAC 25.283(i)(2)attach electronic and printed information .. ^¢-- - DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 7/4/2015 gas lift oil • Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/7/2015 9.5 hours Test Period -4.165 222 236 176 Bean 1496 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 151 24-Hour Rate -► 387 • 580 - 590 - 24 API Form 10-407 Revised 5/2015 VT4 G/24/5 /CONTINUED ON PAC tics AUG 2 8 2015 Submit ORIGINIAL onl 28.CORE DATA Conventional Core Yes ❑ No ❑✓ Sidewall Cores: S ❑ 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 Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1468' 1468' Attach separate pages to this form, if needed,and submit detailed test information, including reports, per 20 AAC 25.071. Kuparuk B3 8996' 6228' Top Kuparuk B2 9030' 6254' Top Kuparuk B1 9080' 6285' Top Kuparuk A6 9150' 6319' Top Kuparuk A5 9173' 6330' Top Kuparuk A4 9230' 6351' 1 F-19L1 PB1 KOP B2 9056' 6274' total depth 11408' 6331' Formation at total depth: Kuparuk A4 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: Cody Pohler @ 265-6435 Email: Cody.J.Pohler@cop.com (.JP Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: Phone: 263-4372 Date: 7— --(5 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing 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 ",r 4�' KUP PROD 1F-19L1 N,--- 4c-ConocoPhillips Well Attributes II Max Angle&MD TD Xaskr"1 Inc ,i Wellbore API/OWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) t ntEe tylnps d 500292266060 KUPARUK RIVER UNIT PROD 100.80 11,205.74 ••• Comment H2S(ppm) Date Annotation End Dale KB-Grd(ft) Rig Release Date 1F-19L1,7/1412015 5'27'01 PM SSSV: NIPPLE 80 8/14/2012 Last WO: 3/23/1996 vertical scnema8c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date g_ Last Tag: Rev Reason:ADD LATERALS L1(elf main smsmith 7/14/2015 6= -__ wellbore),L1-01 ® Casing Strings HANGER;36.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...W6Len(I...Grade Top Thread ( L1 LINER 2 3/8 1.992 9,050.8 11,264.0 6,299.9 4.60 L-80 STL Liner Details �: Nominal ID € a Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) I 9,050.8 6,267.3 49.72 BILLET BAKER OPEN HOLE ANCHORED ALUMINUM 1.000 LINER TOP BILLET 9,080.1 6,285.1 55.51 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot Dens `A-A'‘CONDUCTOR;420-1210" l�� Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,081.0 9,200.5 6,285.5 6,339.3'A-4,1F-19L1 6/13/2015 - APERF Slotted Liner Notes:;General&Safety End Date Annotation NOTE: NIPPLE;5083 II GAS LIFT,2625.5 111 I GAS LIFT;4305A 4 SURFACE;41.6-4,557.1-a I GAS LIFT;5 863 8 111 11 al GAS LIFT',6,812.4 II ti I PBR;68728 1-t ANCHOR;6,886 6 NI PACKER;6,887.3 L NIPPLE;6965 2 SEAL ASSY;8,771 3 PACKER;8,9680 WHIPSTOCK;8,9950 L1-01 LINER',8,9733-10,394.0 PRODUCTION 5.5•x3.5-087721 38.7-9,450 2 APERF;9,080.9 9 200.4 I 1+i L1 LINER;9,050.8-11,264.0 r KUP PROD • 1F-19 ConocoPhillips 2 Well Attributes Max Angle&MD TD Alaska Inc, is b Wellbore API/UWI Field Name Wellbore Status Incl('1 MD(ftKB) Act Btm(ftKB) _ yf,IIkir 500292266000 KUPARUK RIVER UNIT PROD 63.78 5,520 93 9,457.0 ..;-F Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-19,7/14/2015 5:26'59 PM SSSV:NIPPLE 80 8/14/2012 Last WO: 6/14/2014 3/23/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _.... _.__. Last Tag:SLM 9,136.0 1/13/2015 Rev Reason:ADD LATERALS L1(off main smsmith 7/14/2015 te°,,, wellbore),L1-01 iim s 8 ( Casing Strings HANGER;36CZcie 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 62 50 H-40 WELDED [� " Casing •Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 75/8 6.875 41.6 4,557.1 3,821.9 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 51/2 4.950 38.7 9,450.2 6,579.6 15.50 L-80 LTC-MOD 1. 5.5"x3.5"@8772' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW 51/2 4.950 9,055.5 9,061.0 6,278.1 Tubing Strings f Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 'AlCONDUCTOR;42.0-121.0 A"TUBING WO(Upper) 31/2 2.992 36.8 6,887.3 4,990.2 9.30 L-80 )BTM Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 36.8 HANGER FMC TUBING HANGER 3.500 NIPPLE;508.3 508.3 508.3 0.24 NIPPLE CAMCO"DS"NIPPLE 2.875 it 6,869.6 4,980.9 58.24 SEAL ASSY PBR SEAL ASSEMBLY with Space-out 3' 2.990 I6,872.8 4,982.6 58.25 PBR PBR 80-40 SPECIAL TRIM(4.78"OD) 4.010n 6,886.8 4,990.0 58.29 ANCHOR KBH-22 ANCHOR SEAL ASSEMBLY 3.000 Tubing Description 'Siring Ma..I ID(in) (Top(ftKB ) ret Depth(ft...ISet Depth(TVD)(...I Wt(Ib/ft) (Grade (Top Connectio TUBING WO(Lower) 31/2 2.992 6,887.31 8,772.3 6,059.2 9.30 L-80 (BTM Completion Details IINominal ID GAS LIFT;2,625.5IL Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 6,887.3 4,990.2 58.29 PACKER BAKER 45-FA-36 PRODUCTION PACKER 3.020 6,965.2 5,030.7 59.16 NIPPLE HES'X'NIPPLE 2.812 i:: 8,771.3 6,058.5 41.94 SEAL ASSY BAKER 80-40 GBH-22 LT SEAL ASSY w/1'space-out 2.990 GAS LIFT;4,305.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Illi" iy 4 Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 8,968.0 6,207.1 40.40 PACKER LINER TOP PACKER 6/27/2015 1.800 8,995.0 6,227.7 40.28 WHIPSTOCK 3.5"MONO XL THRU-TUBING WHIPSTOCK 6/9/2015 W/TOWS,SET 15 DEG LEFT OF HIGH SIDE SURFACE;41.6-4,557.1-' 9,054.0 6,272.8 40.01 WHIPSTOCK 3.5"MONO XL THRU-TUBING WHIPSTOCK 5/9/2015 W/TOWS,SET 9 DEG LEFT OF HIGH SIDE 9,400.0 6,540.5 38.89 FISH TWO 6"LONG SEALING ELEMENTS LEFT IN 7/19/2014 GAS LIFT;5,863.8I HOLE AFTER PULLING IBP al Perforations&Slots IIShot • Dens GAS LIFT;6,812.4 Top(TVD) Bbn(TVD) (shutoff Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,124.0 9,136.0 6,326.5 6,335.8 A-5,1F-19 2/21/2009 6.0 APERF 2"PJ HSD CHARGES ar 9,156.0 9,176.0 6,351.2 6,366.6 A-4,1F-19 5/20/1996 4.0 IPERF 2.5"Hollow Case;180 II deg.PhasE;54 deg _- CCW Orient FOR;6,872.8 [ 9,161.0 9,171.0 6,355.1 6,362.8 A4,1F-19 9/29/2006 6.0 RPERF 2"HSD BH 2006 r ANCHOR;6,886.8 ,: Powerfow PACKER;6,887.3 MIF 9,183,0 9,198.0 6,372.0 6,383.6 A-4,1F-19 2/20/2009 6.0 APERF 2"PJ HSD CHARGES Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Bim(TVD) 1, (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com NIPPLE;6,965.2 9,156.0 9,176.0 6,351.2 6,366.6 FRAC A-SAND 10/2/2006 BREAKDOWN,DATA FRAC AND A-SAND FRACTURE TREATMENT DESIGNED FOR 158,000#16/20 W/YF150D.PUMPED 176240# 16/20 TO COMPLETION 10 PPA ON FORMATION, ADJUSTED PAD FROM 260 BELS TO 240 BBLS SEAL ASSY;8,771.3 Mandrel Inserts St ati PACKER;8,968.0 ird H Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) _ Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1.- 2,625.6 2,588.2 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.156 1,341.0 6/28/2015 T 9 I 2 4,305.4 3,697.9 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.156 1,323.0 6/28/2015 9 I WINDOW;8,996.0-9,000.0, 1 3 5,863.8 4,472.8 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.156 1,345.0 6/30/2015 WHIPSTOCK;8,995.0 iii9 I 4 6,812.4 4,950.7 CAMCO KBG-2- 1 GAS LIFT OV Integra 0.188 0.0 6/30/2015 Ped;9,039.8-9.069.3, - -- 9 I L1-01 LINER;8,973.3-10,394.0 - Notes:General&Safety End Date Annotation WHIPSTOCK;9,054.01 9/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 WINDOW;9,055.5-9,061.0 APERF;9,124.0-9,136.0 !PERE;9,156.0-9,176.0A _RACASAND;9,17.0 RPERF;g,161.0-9,171.0 . APERF;9,783.0-9,198.0 FISH;9,400.0 f PRODUCTION 5.5-x3.5Ve772';38.7-9,450.2 1F-19 PRE AND POST RIG WELL WORK DATE SUMMARY • • PRE-RIG WELL WORK 4/17/2015 (PRE-CTD): T POT(PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT (PASSED), SCLD (IN PROGRESS). 4/18/2015 (PRE-RWO): SCLD PASSED. 4/19/2015 (PRE-CTD): SCLD (PASSED). 5/3/2015 MEASURE BHP @ 9170' RKB; BRUSH n' FLUSH X-NIP @ 6965' RKB; SET 2.81"XX PLUG &CATCHER @ 6965' RKB; PULLED GLV @ 5862' RKB. IN PROGRESS. 5/4/2015 PULLED GLV'S @ 2626', 4279', &6812' RKB; SET DV'S @ 2626', 4279', &5862' RKB (LEFT POCKET OPEN @ 6812' RKB FOR CIRC OUT). IN PROGRESS (LRS ON LOCATION PERFORMING CIRC OUT 220 BBLS CRW SW, FOLLOWED BY 45 BBLS U-TUBE FP). 5/5/2015 SET DV @ 6812' RKB; MIT IA ( PASS); PULL CATCHER AND PLUG @ 6965' RKB. READY FOR E-LINE (WHIPSTOCK). 5/8/2015 UNABLE TO GET WHIPSTOCK TO ROLL OVER TO THE TOP SIDE.WILL COME BACK TOMORROW MAKE ADJUSTMENTS TO WEIGHT BARS, AND ATTEMPT AGAIN TOMORROW. 5/9/2015 SET BAKER WHIPSTOCK WITH TOP OF WHIPSTOCK AT 9054'. TOP OF WHIPSTOCK WAS ORIENTED 9 DEGREES LEFT OF HIGH SIDE. 5/14/2015 (PRE-CTD): TREE VALVE TEST: MV, SSV, LOWER SV, UPPER SV-ALL PASSED. POST-RIG WELL WORK 6/27/2015 DRIFT TO DEPLOYMENT SLEEVE IN LINER @ 8973' RKB & BRUSH SEAL BORE, SET KB PACKER IN DEPLOYMENT SLEEVE ***SEE WSR FOR DETAILS**** LOG SBHPS @ 8950' RKB, PRES/TEMP = 3225#/157degF & GRADIENT STOP @ 8817' RKB, PRES/TEMP = 3174#/155degF, SET 2.75"CATCHER ON TOP OF PACKER @ 8968' RKB....JOB IN PROGRESS. 6/28/2015 PULL& BEGIN SETTING NEW LIVE GAS LIFT DESIGN *****SEE WSR DETAILS***** JOB IN PROGRESS. WILL RETURN AFTER 9ES RIG JOB. 6/30/2015 COMPLETED SETTING OF GAS LIFT DESIGN. PULLED CATCHER FROM TOP OF PACKER @ 8968' RKB. PERFORMED PASSING 400 PSI DRAWDOWN TEST ON IA. *JOB COMPLETE • ConoeoPhillips Time Log & Summary Wel!vie.,Web Reporting Report Well Name: 1F-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/2/2015 12:00:00 AM Rig Release: 6/20/2015 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/01/2015 24 hr Summary ND BOP stack from 2G-14. Rig down CDR2. Prep for rig move to 1F-Pad. Pull subs off 2G-14. Preform site inspection. Move rig modules/shop to 1F-pad. Spot subs over 1F-19. MIRU, berm cellar, hook-up interconnect, PUTZ, and landings, spot shop. Start nippling up BOP stack. 00:00 01:00 1.00 0 0 MIRU MOVE RURD P ND BOP stack and secure cellar 01:00 04:00 3.00 0 0 MIRU MOVE RURD P Rig move checklist. Blow down steam lines. 04:00 09:30 5.50 0 0 MIRU MOVE RURD P Complete rig down checklist. Disconnect highline power. Rig maintenance, grease choke maniflod. Prep for SOWS. 09:30 12:00 2.50 0 0 MIRU MOVE MOB P PJSM. Hook-up sows, pull modules off 2G-14 and install jeeps. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Move rig modules from 2G-Pad to 1 F-Pad. 18:00 20:30 2.50 0 0 MIRU MOVE MOB P Arrive on 1F-Pad. Remove jeeps, spot rig modules over 1 F-19. 20:30 00:00 3.50 0 0 MIRU MOVE RURD P PJSM. MIRU CDR2, berm cellar, hook-up interconnect,complete pre-spud checklist. Rig accept:06-01-15 at 24:00 HRS 36/02/2015 Complete NU of BOP stack. Perform initial BOPE test, Pull TWC. Perform slack management. Rehead CTC. Test PDL's. 00:00 02:00 2.00 0 0 MIRU WHDBO NUND P Complete nippling up BOP stack, check tree flange bolts, found two loose, 10 minutes to tighten,grease stack,change-out riser,secure stack. Fluid pack stack,shell test. 02:00 09:30 7.50 0 0 MIRU WHDBO BOPE P Perform initial BOPE test 250/4000 psi;annular 2500 psi.Test waived by Matt Herrera(AOGCC). 09:30 11:00 1.50 0 0 MIRU WHDBO MPSP P PJSM. PT tiger tank line, attempt to retest swab vlaves, leaking by master and BPV. 11:00 16:30 5.50 0 0 MIRU WHDBO MPSP T PJSM. Called out FMC, pulled BPV, set ISA BPV. Fluid pack and test swab and tango valves, good test. Pull ISA BPV, LD FMC equipment. 16:30 20:09 3.65 0 0 SLOT WELLPF CTOP P Fluid pack reel,test inner reel iron, and stripper. Pump slack management, cut 124'coil to find wire. 20:09 22:51 2.70 0 0 SLOT WELLPF CTOP P PJSM.Test E-Line, rehead CTC. Pull test 35K, rehead UQC and meg test. PT CTC,good test. 22:51 00:00 1.15 0 0 SLOT WELLPF PRTS P PJSM. PT PDL's Page 1 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/03/2015 24 hr Summary RIH w/BHA#1 nozzle assembly to 9,025'. Displace well over to 9,4 ppg used mud system. Perform injectivity test. Squeeze total of 43 bbls 100 LSRV pill to formation max pressure 2,000 psi. Bleed off wellhead. LD BHA#1. PD BHA#2, RIH w/milling assembly,dry tag TOWS @ 9,056'. 00:00 00:30 0.50 0 0 SLOT WELLPF PRTS P Complete PDL test. 00:30 01:30 1.00 0 17 SLOT WELLPF PULD P PJSM. MU BHA#1, nozzle assembly 01:30 03:30 2.00 17 9,025 SLOT WELLPF DISP P RIH w/nozzle assembly,while circulating seawater© 1.25 BPM. 03:30 05:45 2.25 9,025 9,025 SLOT WELLPF DISP P Displace hole over to 9.3 ppg used mud system @ 1.25 BPM© 1,675 psi, mud at nozzle, pumping 1.29 bpm in getting .70 bpm back. Have gas cut returns. had to take 77 bbls of used mud to tiger tank. Lost 34 bbls to formation.Able to get returns cleaned up without gas. 05:45 08:00 2.25 9,025 17 SLOT WELLPF TRIP P POOH to surface circulating ooh. 08:00 08:15 0.25 17 17 SLOT WELLPF OWFF P On Surface. Shut down pumps. Monitor WHP; 500 psi and falling. Settled out to 200 psi. 08:15 09:00 0.75 17 17 SLOT WELLPF OTHR T Call town, discuss plan forward. 09:00 13:45 4.75 17 17 SLOT WELLPF DISP P Start pumping 100k LSRV fluid(43 bbls)WHP to start 200 psi. Pump @ .5 BPM @ 750 psi,WHP started rising some back to down to .3 BPM @ 870 psi. Settled out @.2 to.3 BPM to stay under 900 psi pressure. 13:45 16:15 2.50 17 17 SLOT WELLPF DISP P Have 43 bbls of the 100k LSRV pumped. Swap to 9.3 used mud to chase pill to perfs. 16:15 17:00 0.75 17 17 SLOT WELLPF DISP P Get call from town. Get the ok to raise Max WHP to 2000 psi. Kick up rate; .8 BPM @ 1350 psi 1 BPM @ 1467 psi 1.3 BPM @ 1677 psi Back down to 1 BPM when pill hit perfs.WHP @ 1850 psi. Squeeze 21 bbls of pill into the perfs. Shut down @ 1950 psi WHP. 17:00 18:00 1.00 17 17 SLOT WELLPF OWFF P Bleed down to 880 after 20 minutes. Push the rest of the pill into the perfs. Shut down,well bled back off to 900 psi. 18:00 19:30 1.50 17 0 SLOT WELLPF PULD P Change out. Conduct PJSM. Shut in &bleed off. Maintain 650 psi MP. LD BHA#1, clear rig floor. 19:30 21:45 2.25 0 74 PROD1 WHPST PULD P PJSM. PD BHA#2 milling assembly 0.6 AKO motor 21:45 00:00 2.25 74 9,065 PROD1 WHPST TRIP P RIH w/milling assembly,tie-in K1 for +9.5'correction,continue in hole, close EDC, shut down pump, dry tag TOWS @ 9,056.4'. PUH. Page 2 of 13 Time Logs • 4111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/04/2015 24 hr Summary Mill window exit @ 9,055',drill to 9077'. Back ream window&dry drifted clean. POOH, PUD BHA#2, PD BHA#3, stuck BHA in stack, parted S/L. Bleed off wellhead,flow check, retrieve parted S/L and BHA. Make up to injector. Start in hole with BHA, in progress. 00:00 00:06 0.10 9,065 9,056 PROD1 WHPST TRIP P RBIH to TOWS while pumping @ 9,055.5' 00:06 04:45 4.65 9,056 9,059 PROD1 WHPST WPST P Start milling window @ 1.50 BPM, 1 FPH as per well plan. BHP=3,725 psi, CTW=12.6K,WOB=1.85K. Had to PUH due to shaker issues. 04:45 06:15 1.50 9,059 9,059 PROD1 WHPST RGRP T Have to shut down shaker.Welder needed to make repair. 06:15 14:15 8.00 9,059 9,077 PROD1 WHPST WPST P Pumps up, 1.50 BPM @ 2850 psi FS.Continue milling window @ 9059' BHP 3709 psi 14:15 15:45 1.50 9,077 9,041 PROD1 WHPST REAM P Drilled 21'past wndow to 9077'. Pull up 27k, back ream window several times. Dry drift clean. Pull up to 9041'open edc, pump 5 x 5 sweep 15:45 17:15 1.50 9,041 74 PROD1 WHPST TRIP P @ 9041',get sweep out of the bit. TOOH to surface. 17:15 19:51 2.60 74 0 PROD1 WHPST PULD P PJSM. PUD BHA#2, reconfigure BHA. 19:51 22:00 2.15 0 76 PROD1 DRILL PULD T PJSM. PD BHA#3, build drilling assembly,2.3 AKO motor, HCC short shank bit.Trouble working 2.3 bend motor through stack,stuck across stack/tree, parted W/L working through stack. Prep to bullhead KWF downhole. Call town, try flow check. Bleed wellhead to zero. 22:00 22:30 0.50 76 76 PROD1 DRILL OWFF T Monitor well 30 minutes, no flow. 22:30 23:27 0.95 76 76 PROD1 DRILL PULD T Remove PDL, remove parted wire and toolstring and LD, inspect BHA. Make up injector. 23:27 00:00 0.55 76 2,678 PROD1 DRILL TRIP P RIH w/BHA#3 build assembly 36/05/2015 Drill build section from 9,077'to 9270'. Kill well with 11.4 ppg, LD build BHA&Pick up lateral drilling BHA. Drilled ahead L1 lateral from 9,270'to 9,367',ankerite stringers,drilling in progress. 00:00 01:30 1.50 2,678 9,077 PROD1 DRILL TRIP P Continue in hole build drilling assembly,tie-in K1 for+10' correction, RIH. 01:30 06:45 5.25 9,077 9,270 PROD1 DRILL DRLG P Drill ahead: 1.52 BPM©3,050 PSI, BHP=3,760 PSI, CTW=10.5K, WOB=2.3K, ROP=40. Call build TD @ 9270' 06:45 09:45 3.00 9,270 9,034 PROD1 DRILL CIRC P Pull up, 30k off btm. Park at 9034'. Continue circulating to get btms up& maintain MP.Waiting on 11.7 fluid to get watered back to 11.4, swap fluid around in the pits. Build 10 bbl spacer. 09:45 11:45 2.00 9,034 88 PROD1 DRILL CIRC P @ 9034'start pumping 10 bbls spacer, followed by 11.4 KWF. Get 11.4 out bit&ahead a few bbls, pooh laying in 11.4 to surface. Page 3 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:15 0.50 88 89 PROD1 DRILL OWFF P OOH,watch well for 30 minutes for no flow check. Conduct PJSM for laying down BHA. 12:15 13:45 1.50 89 0 PROD1 DRILL PULD P Pop off, lay down BHA#3. Conduct PJSM for picking up BHA#4 13:45 14:45 1.00 0 72 PROD1 DRILL PULD P Pick up&deploy BHA#4.W/new 2.74"x 3.25"bit per town request. 14:45 16:30 1.75 72 8,750 PROD1 DRILL TRIP P RIH w/L1 Drilling assembly, BHA#4 recovering 11.4 while RIH. Start pump 9.3 flo-pro down coil starting at 2000'. 16:30 16:45 0.25 8,750 9,030 PROD1 DRILL DLOG P Log K-1 fora plus 9.5' RIH to 9030' 16:45 18:30 1.75 9,030 9,030 PROD1 DRILL CIRC P Park at 9030'. Continue swapping hole over to 9.3 flo-pro, recovering 11.4 KWF. 18:30 19:03 0.55 9,030 9,270 PROD1 DRILL DLOG P Log RA tag @ 9,062.5. Continue in hole. 19:03 00:00 4.95 9,270 9,367 PROD1 DRILL DRLG P BOBD: 1.45 BPM @ 3,140 PSI, BHP=3,810 PSI, CTW=10.4K, WOB=1.4K, ROP=40.Ankerite initially,stalled, mini wiper @ 9,331', PUW=28K. Continue drilling ankerite, ROP=6. 36/06/2015 Drill ahead L1 lateral from 9,367'to 9,977',drilling in progress. 00:00 10:00 10.00 9,367 9,422 PROD1 DRILL DRLG P Drill ahead: 1.40 BPM ©3,010 PSI, BHP=3,805 PSI, CTW=9.2, WOB=2.4K, ROP=6. Continue drilling ankerite stringers. ROP averaged 5.5 FPH. 10:00 11:45 1.75 9,422 9,430 PROD1 DRILL DRLG P @ 9422'. Raise rate from 1.42 BPM to 1.55, CTP 3358. ECD 11.87 BHP 3850 psi. Drill about 15 minutes, no improvement.drop rate back down to 1.45 BPM. 11:45 14:40 2.92 9,430 9,570 PROD1 DRILL DRLG P @ 9430'. Broke out to-60 FPH @ 9430'. Drill to 9570' 14:40 15:14 0.58 9,570 9,570 PROD1 DRILL WPRT P Wiper,29k off BTM,turn around @ 9000'. RBIH to BTM. 15:14 21:05 5.85 9,570 9,870 PROD1 DRILL DRLG P Drill ahead: 1.47 BPM @ 3,148 PSI, BHP=3,884 PSI, CTW=10.2, WOB=1.56K, ROP=50. 21:05 21:59 0.90 9,870 9,870 PROD1 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 21:59 23:59 2.00 9,870 9,977 PROD1 DRILL DRLG P Drill ahead: 1.42 BPM @ 3,170 PSI, BHP=3,874 PSI, CTW=7.8, WOB=2.7K, ROP=60. 06/07/2015 Drill ahead Li lateral from 9,977'to 10,920', mud swap to 9.0 ppg drilling fluid at 10,752'. Drilling in progress 00:00 04:15 4.25 9,977 10,170 PROD1 DRILL DRLG P Drill ahead: 1.42 BPM @ 3,190 PSI, BHP=3,895 PSI, CTW=8K, WOB=1.7K, ROP=50. One stall @ 10,166', PUW=31K. 04:15 05:30 1.25 10,170 10,170 PROD1 DRILL WPRT P Wiper for tie-in, PUW=29K,tie-in to RA tag for+2.5'correction, RBIH. 05:30 11:30 6.00 10,170 10,470 PROD1 DRILL DRLG P Drill ahead: 1.42 BPM @ 3,190 PSI, BHP=3,935 PSI, CTW=8K, WOB=1.6K, ROP=55. Page 4 of 13 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:30 1.00 10,470 10,470 PROD1 DRILL WPRT P 10470',wiper 29k off btm. 12:30 19:42 7.20 10,470 10,752 PROD1 DRILL DRLG P Drill ahead: 1.42 BPM @ 3,177 PSI, BHP=3,924 PSI, CTW=7K, WOB=1.51K, ROP=36,weight transfer isues. 19:42 20:36 0.90 10,752 10,752 PROD1 DRILL WPRT P Early wiper to 9,640-ft, PUW 31k. RBIH 8.3k RIW. Note: Begin Mud swap to 9.0 ppg 20:36 00:00 3.40 10,752 10,920 PROD1 DRILL DRLG P 10,752-ft, OBD 1.54 bpm at 3,235 psi, BHP 3,862 psi, CWT 6.8k,WOB 1.9k, ROP 50, IA 678, 0A 187. Note: New mud at bit at 10,752.8-ft., Lost 8 bbl of 9.4 ppg mud to formation today. 06/08/2015 Drill ahead L1 lateral from 10,920-ft to called TD 11,408-ft.Wiper to swab. RBIH. Stack out at 9,150-ft,several attempts to pass unsuccessful. POOH. Undeploy BHA#4. 00:00 03:12 3.20 10,920 11,070 PROD1 DRILL DRLG P 10,920-ft, OBD 1.55 bpm at 3,328 psi, BHP 3,933 psi, CWT 4.9k,WOB 1.8k, ROP 50, IA 699, OA 187. 03:12 04:21 1.15 11,070 9,090 PROD1 DRILL WPRT P Wiper up hole for tie-in, pull heavy @ 9,147', 5K overpull, pulled free.Tie-in RA tag for+3'correction. 04:21 05:03 0.70 9,090 11,070 PROD1 DRILL WPRT P RBIH. 05:03 11:39 6.60 11,070 11,370 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,310 PSI, BHP=3,855 PSI, CTW=6K, WOB=1.7K, ROP=45. BHA wiper @ 11,240', PUW=31K. 11:39 12:39 1.00 11,370 11,370 PROD1 DRILL WPRT P Wiper to 10,300', PUW=29K, RBIH. 12:39 15:39 3.00 11,370 11,408 PROD1 DRILL DRLG P Drill ahead: 1.45 BPM @ 3,185 PSI, BHP=3,885 PSI, CTW=5K, WOB=1.8K, ROP=15. Slow going, turning down to lower A4 pay, starting to lose push, resistivity dropping.Town held meeting about TD, TD was called. 15:39 19:00 3.35 11,408 72 PROD1 DRILL WPRT P Pump 10 X10 sweep, chase to swab. 19:00 20:33 1.55 72 8,750 PROD1 DRILL TRIP P AT surface, reeset counters, RIH 20:33 20:42 0.15 8,750 8,785 PROD1 DRILL DLOG P Tie in at Ki, plus 8.5-ft correction, PUW 25k, close EDC. 20:42 21:24 0.70 8,785 9,150 PROD1 DRILL TRIP T RIH pumps off, stack out 4-5k at 9,150-ft, make several attempts to pass at various speeds, rates and tool face with no success,confer with town. 21:24 22:45 1.35 9,150 72 PROD1 DRILL TRIP T POOH for D331 and 1.25 AKO motor. 22:45 00:00 1.25 72 0 PROD1 DRILL PULD T PJSM-Undeploy BHA#4, LD BHA #4, Bit condition 06/09/2015 Pick up D331 Mill BHA#5. Several attempts to pass unsuccessfully at 9,151-ft due to A6 shale. POOH. PUD BHA#5. MU BHA#6 3.5"monobore XL whipstock assembly. PD.Set top of WS 15° LOHS at 8,995-ft, bottom at 9005.5-ft. POOH. Page 5 of 13 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:36 0.60 0 0 PROD1 DRILL PULD T Undeploy and LD BHA#4, Bit condition 1-1-WT-A-X-I-PN-HP 00:36 01:18 0.70 0 0 PROD1 DRILL BOPE P PJSM-PU test joint, Function test BOPE, LD testing equipment. 01:18 03:00 1.70 0 62 PROD1 DRILL PULD T PJSM-MU and Deploy BHA#5, 1.25°AKO motor and 2.79"nogo D331 mill. 03:00 04:33 1.55 62 8,750 PROD1 DRILL TRIP T RIH with BHA#5 04:33 04:54 0.35 8,750 8,785 PROD1 DRILL DLOG T Tie in at K1 for plus 10-ft correction, PUW 26k, close EDC, RBIH. 04:54 05:54 1.00 8,785 9,151 PROD1 DRILL TRIP T RIH to 9151', set down 5.0 K,worked pipe unable to get past 9151'. PU with small amount of drag through window. 05:54 07:24 1.50 9,151 8,900 PROD1 DRILL CIRC T Circulate while waiting on orders. 07:24 07:54 0.50 8,900 9,151 PROD1 DRILL TRIP T RIH to 9151',set down 4.0K,worked pipe unable to work past 9151'. PUW 28K,set back down unable to work past 9145'. PU with small amount of drag through window. 07:54 10:18 2.40 9,151 8,483 PROD1 DRILL CIRC T POOH to 8483'. Circulate and wait on orders. Conduct flow test, bled pressure with WHP sustaining at 183 psi. Moved pipe, rolled pumps, and bled pressure. Conducted second flow test and WHP sustained at 12 psi. 10:18 11:09 0.85 8,483 9,000 PROD1 DRILL TRIP T POOH at 7365'20K overpull and -23K DH WOB, at 7185'6K overpull and-7K DH WOB. RIH to 9000'with no indication of issues at 7365' and 7185'. 11:09 13:09 2.00 9,000 77 PROD1 DRILL TRIP T POOH pumping at max rate and conduct flow check. Flow seen at shaker,well was shut-in(WHP=176 psi), and the decision was made to pressure undeploy BHA#5. 13:09 16:09 3.00 77 0 PROD1 DRILL PULD T PJSM-Undeploy and LD BHA#5. Gauged mill 2.79 no-go. 16:09 18:54 2.75 0 74 PROD1 RPEQP1 PULD T PJSM-MU and Deploy whipstock BHA#6 18:54 21:54 3.00 74 8,750 PROD1 RPEQP1 TRIP T RIH with BHA#6,slow down thru areas were pulled heavy on way out of hole. 21:54 22:06 0.20 8,750 8,780 PROD1 RPEQP1 DLOG T Tie in at K1 for plus 8-ft correction, PUW 27k, close EDC. 22:06 22:27 0.35 8,780 9,006 PROD1 RPEQP1WPST T RIH pumps off, position whipstock 15° LOHS with top at 8,995-ft, release off WS at 3,600 psi,stack 4k down. 22:27 00:00 1.55 9,006 74 PROD1 RPEQPI TRIP T POOH for window milling assembly. J6/10/2015 PUD BHA#5. PD BHA#6. Mill window exit 8,996-ft to 9,001-ft, rathole to 9,017-ft. Back ream window and dry drift clean. POOH. PUD BHA#7. PD BHA#8. RIH with BHA#8 00:00 01:30 1.50 74 0 PROD1 RPEQP1 PULD T PJSM-Un-deploy and LD BHA#6 Page-6 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:54 1.40 0 74 PROD1 WHPST PULD T PJSM-MU and deploy BHA#7 window milling assembly, MU to CoilTrak, surface test. 02:54 04:27 1.55 74 8,750 PROD1 WHPST TRIP T RIH with BHA#7 04:27 04:39 0.20 8,750 8,780 PROD1 WHPST DLOG T Tie in at K1 for plus 8.5-ft correction, PUW 26k, close EDC. 04:39 04:54 0.25 8,780 8,996 PROD1 WHPST TRIP T RIH,dry tag TOWS at 8,997-ft, PUW 27k, pumps on 1.5 bpm at 2,900 psi free spin, 344 differential, RBIH 04:54 13:24 8.50 8,996 9,006 PROD1 WHPST WPST T Start milling window 1.50 bpm at 3069 psi, 1 fph as per recomended practice, BHP 3,760 psi, IA 86, OA 145. 13:24 15:24 2.00 9,006 9,017 PROD1 WHPST WPST T Drill rat hole, 1.52 bpm at 3150 psi, WHP 210, BHP 3847, DHWOB 2.5k, ROP 7 fph, IA 456, OA 167, 15:24 16:39 1.25 9,017 9,017 PROD1 WHPST REAM T 9017 ft, ream window area as per RP from 9007 ft to 8994 ft, dry drift through window area clean 16:39 18:21 1.70 9,017 74 PROD1 WHPST TRIP T POOH,following MP schedule 18:21 20:18 1.95 74 0 PROD1 WHPST PULD T PJSM-Un-deploy BHA#7, both mills 2.79"nogo, PU BHA#8 20:18 20:48 0.50 0 0 PROD1 DRILL RGRP T Shaker welding repair in progress. 20:48 21:48 1.00 0 72 PROD1 DRILL PULD T PJSM-Deploy BHA#8, 1.25°AKO motor and used HCC 3.25"short shank bi-center bit, MU to CoilTrak, surface test. 21:48 00:00 2.20 72 9,017 PROD1 DRILL TRIP T RIH with BHA#8, EDC open,tie in at K1 for plus 9-ft correction, PUW 25k, close EDC. Continue in hole 36/11/2015 Drill build section 9,017-ft to 9,463-ft. POOH. PUD BHA#8. 00:00 04:24 4.40 9,017 9,107 PROD1 DRILL DRLG T 9,017-ft, OBD 1.5 bpm at 3,247 psi, BHP 3,863 psi,WHP 234, IA 165, OA 147. 04:24 05:24 1.00 9,107 9,107 PROD1 DRILL DLOG T PUH to 8,750-ft, PUW 28k, MADD pass,Tie in to K1 for plus.5-ft correction, RBIH, Log RA at 9,002-ft, TOWS at 8,995.5-ft. 05:24 14:24 9.00 9,107 9,230 PROD1 DRILL DRLG T 9,107-ft, BOBD 1.5 bpm at 3,330 psi, BHP 3,855 psi,WHP 151, IA 356, OA 1591 14:24 15:24 1.00 9,230 9,270 PROD1 DRILL DRLG T 9230 ft, bring 2 pumps online to try increasing ROP, 1.84 bpm at 8750 psi, BHP 3905,WHP 110, IA 594, OA 169, 15:24 15:54 0.50 9,270 9,270 PROD1 DRILL WPRT T 9270 ft,short wiper up hole to 9020 ft, PUW 27k 15:54 20:27 4.55 9,270 9,463 PROD1 DRILL DRLG T 9270 ft, BOBD 1.85 bpm at 4000 psi, WHP 64, BHP 3909, IA 582, OA 168 20:27 22:24 1.95 9,463 72 PROD1 DRILL TRIP T 9,463-ft,TD build section, POOH, PUW 28k. 22:24 00:00 1.60 72 0 PROD1 DRILL PULD T PJSM- Undeploy and LD BHA#8, bit condition 2-1-CT-N-X-I-PN-BHA Pate 7 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/12/2015 24 hr Summary PD BHA#9. BHA HOT tool malfunction at 8,780-ft. POOH. PUD BHA#9, PD BHA#10. Drill L1 lateral from 9,463-ft to 10,360-ft. New mud at 10,189-ft. Drilling in progress 00:00 01:30 1.50 0 72 PROD1 DRILL PULD T PJSM-MU/Deploy BHA#9, 0.5° AKO motor and HYC 3.25"Bi-center bit, MU to CoilTrak,surface test. 01:30 03:03 1.55 72 8,750 PROD1 DRILL TRIP T RIH with BHA#9 03:03 03:51 0.80 8,750 7,960 PROD1 DRILL DLOG T Tie in at K1 for plus 9-ft correction, lost communication with HOT tool, PUH while attempting to establish communication, PUW 26k, no joy. 03:51 05:15 1.40 7,960 72 PROD1 DRILL TRIP T POOH to replace HOT tool. 05:15 07:21 2.10 72 0 PROD1 DRILL PULD T PJSM- Undeploy and LD BHA#9, change out HOT tool. 07:21 09:21 2.00 0 72 PROD1 DRILL PULD T PJSM-MU/Deploy BHA#10 with 0.5°AKO motor and HYC 3.25" Bi-center bit, MU to CoilTrak, surface test. 09:21 11:18 1.95 72 8,789 PROD1 DRILL TRIP T RIH with BHA#10, EDC open, tie in at K1 for plus 8.5-ft correction, PUW 28k, close EDC. *"*Note: Baker down time ended with 8 total hrs. 11:18 11:39 0.35 8,789 9,463 PROD1 DRILL TRIP T RIH with BHA#10 11:39 14:15 2.60 9,463 9,750 PROD1 DRILL DRLG T 9463'BOBD 1.74 bpm at 3762 psi, WHP 100, BHP 3935, IA 417, OA 154 14:15 14:45 0.50 9,750 9,050 PROD1 DRILL WPRT T Wiper to 9050', PUW=28K, at 9148' pulled 4K over 14:45 15:06 0.35 9,050 9,750 PROD1 DRILL WPRT T RBIH,slight bobble at 9148' 15:06 18:24 3.30 9,750 10,060 PROD1 DRILL DRLG T 9750' BOBD 1.80 bpm at 3880 psi, WHP 75, BHP 3922, IA 553, OA 164 18:24 18:45 0.35 10,060 9,200 PROD1 DRILL WPRT T Wiper to 9,200-ft, PUW 28k 18:45 19:15 0.50 9,200 10,060 PROD1 DRILL WPRT T Wiper in hole, RIW 11.2k Note: Begin mud swap 19:15 22:42 3.45 10,060 10,360 PROD1 DRILL DRLG T 10,060-ft, OBD 1.80 bpm at 4,114 psi, BHP 3,965 psi,WHP 120, IA 690,OA 172 Note: New mud at bit at 10,189-ft 22:42 23:27 0.75 10,360 9,015 PROD1 DRILL WPRT T Wiper up hole for tie in, PUW 27k, slow pump 1 bpm, speed to 25 fpm at TF 57° LOHS,0.5k overpull 9,160-ft to 9,140-ft, RBIH. 23:27 23:39 0.20 9,015 9,045 PROD1 DRILL DLOG T Log RA for plus 3-ft correction, 23:39 00:00 0.35 9,045 9,875 PROD1 DRILL WPRT T Wiper in hole minimum rate,25 fpm at TF,slight bobble 0.5k at 9,150-ft, RIW 11k. 06/13/2015 Drill L1 lateral from 10,360-ft to called TD at 11,260-ft,Wiper to 9,170-ft.Tied in at top of A5 formation.Tag corrected TD at 11,265-ft. Lay in 9.0 beaded liner pill in open hole.Wiper to swab. RBIH to K1. 00:00 00:12 0.20 9,875 10,360 PROD1 DRILL WPRT T Continue wiper in hole, RIW 11k. Page 8 of 13 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:12 08:21 8.15 10,360 10,660 PROD1 DRILL DRLG T 10,360-ft, OBD 1.8 bpm at 3960 psi, BHP 4007 psi,WHP 238, IA 625, OA 168, hit anchorite at 10,542-ft 08:21 08:51 0.50 10,660 9,600 PROD1 DRILL WPRT T Wiper up hole to 9,600', PUW 28k 08:51 09:21 0.50 9,600 10,660 PROD1 DRILL WPRT T Wiper in hole, RIW 9.9k. 09:21 12:33 3.20 10,660 10,957 PROD1 DRILL DRLG T 10,660-ft, BOBD 1.8 bpm at 3710 psi, BHP 4068 psi,WHP 260, IA 875, OA 181 12:33 13:03 0.50 10,957 10,000 PROD1 DRILL WPRT T Wiper up hole to 10,000', PUW 34k 13:03 13:21 0.30 10,000 10,957 PROD1 DRILL WPRT T Wiper in hole, RIW 2.7k. 13:21 16:51 3.50 10,957 11,260 PROD1 DRILL DRLG T 10,957-ft, BOBD 1.8 bpm at 3753 psi, BHP 4101 psi,WHP 280, IA 203, OA 180 ""NOTE: TD L1 lateral 16:51 18:00 1.15 11,260 9,170 PROD1 DRILL WPRT T Wiper up hole to 9,170'pumping 10x10 sweep 18:00 18:18 0.30 9,170 9,230 PROD1 DRILL DLOG T Log top of A5 formation for plus 6-ft correction. 18:18 19:36 1.30 9,230 11,265 PROD1 DRILL TRIP T RIH, confirm TD at 11,265-ft, PUW 26k, circulate 9.0 ppg beaded liner running pill. 19:36 22:27 2.85 11,265 72 PROD1 DRILL CIRC T POOH laying in 9.0 ppg beaded liner running pill, slight overpull 0.5k at 9,150-ft.9 bpm,25 fpm at TF 55° LOHS, continue OOH to surface. 22:27 00:00 1.55 72 8,750 PROD1 DRILL TRIP T RBIH for tie in. 06/14/2015 Lay in 11.8 completion fluid from 9,120-ft. Run L1 liner assembly in 2 segments from 11,264-ft to 9,050-ft. Begin Bi-weekly BOPE test,witness waived by AOGCC Jeff Jones. 00:00 00:45 0.75 8,750 9,120 PROD1 DRILL DLOG P Tie in at K1 for a plus 10-ft correction, RIH to 9,120-ft. 00:45 02:45 2.00 9,120 72 PROD1 DRILL DISP P POOH laying in 11.8 ppg completion fluid to surface, paint EOP flags at 8,800-ft and 6,600-ft. 02:45 03:15 0.50 72 72 PROD1 DRILL OWFF P On surface, check for flow, PJSM- LD BHA 03:15 03:51 0.60 72 0 PROD1 DRILL PULD P LD BHA#10, bit condition 3-1-BT-N-X-I-B U-TD 03:51 04:21 0.50 0 0 COMPZ CASING PUTB P Prep floors for liner run. 04:21 09:42 5.35 0 2,063 COMPZ CASING PUTB P PJSM-MU bullnose, 69 jts 2 3/8" slotted,4 jts 2 3/8"solid,shorty deployment sleeve. 09:42 11:15 1.55 2,063 8,229 COMPZ CASING RUNL P RIH with 2 3/8"L1 liner, pumping minimum rate 11:15 11:21 0.10 8,229 8,229 COMPZ CASING RUNL P 6,600' EOP flag, for+7ft correction, PUW 30.5k 11:21 12:18 0.95 8,229 11,264 COMPZ CASING RUNL P Continue RIH with 2 3/8"L1 liner, pumping minimum rate, RIW 11.5k 12:18 12:33 0.25 11,264 11,264 COMPZ CASING RUNL P Set down on bottom with liner at 11,264', PUW 34k, release from liner PUW 27k. PUH remove BHA from counter and POOH. TOL at 9,080.11' Page 9 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:33 14:18 1.75 11,264 45 COMPZ CASING TRIP P POOH 14:18 14:48 0.50 45 45 COMPZ CASING OWFF P At surface, check well for flow, PJSM 14:48 15:18 0.50 45 0 COMPZ CASING PULD P LD liner tools 15:18 16:24 1.10 0 91 COMPZ CASING PUTB P PJSM-MU bullnose, 3 pup jts 2 3/8" solid liner, OH anchor, aluminum billet L1 assembly to BHA#12. 16:24 19:18 2.90 91 9,080 COMPZ CASING RUNL P RIH with 2 5/8"OH anchor and aluminum billet L1 assembly, close EDC at 7,200-ft, RIH pumps off,tie in at K1 for plus 8.5-ft correction, continue in hole. 19:18 19:27 0.15 9,080 9,050 COMPZ CASING RUNL P 9,080-ft, Stack 4k, PUW 30k,stack 2k, PU to neautral per BOT rep. release off OH anchored billet at 3,700 psi,top of billet at 9,050-ft. 19:27 21:06 1.65 9,050 91 COMPZ CASING TRIP P POOH 21:06 21:36 0.50 91 91 COMPZ CASING OWFF P AT surface,flow check, PJSM 21:36 22:30 0.90 91 0 COMPZ CASING PULD P LD BHA#12 setting tools 22:30 00:00 1.50 0 0 PROD2 WHDBO RURD P PJSM-Jet stack, grease choke and tree valves, valve check list. 06/15/2015 Test BOPE 250/4,000 psi,annular 2,500 psi. RIH with BHA#13. Roll hole to drilling fluid. Kicked off billet at 9,049-ft. Drilled L1-01 build section to 9,066-ft. Drilling in progress. 00:00 00:45 0.75 0 0 PROD2 WHDBO RURD P Continue BOP test prep, grease choke, BOP and tree valves, valve check list. 00:45 08:00 7.25 0 0 PROD2 WHDBO BOPE P PJSM-Begin Bi-weekly full BOPE test 250/4,000 psi, annular 2,500 psi. Test waived by AOGCC rep.Jeff Jones on 6/13/15 at 19:10. **Note: BOP Test 7hrs. 15 minutes 08:00 09:12 1.20 0 0 PROD2 WHDBO DISP P Swap reel back to KWF, flow check, and PJSM 09:12 10:24 1.20 0 72 PROD2 STK PULD P Install checks and MU BHA#13 10:24 12:24 2.00 72 8,750 PROD2 STK TRIP P RIH with BHA#13 12:24 12:39 0.25 8,750 8,750 PROD2 STK DLOG P Tie in for a correction of+9ft. 12:39 12:51 0.20 8,750 8,950 PROD2 STK TRIP P RIH with BHA#13 12:51 13:03 0.20 8,950 8,950 PROD2 STK DISP P Displace well over to 9.0 ppg Power Pro drilling fluid, PUW 27k 13:03 13:18 0.25 8,950 9,049 PROD2 STK TRIP P RIH and dry tag top of billet at 9,049'. 13:18 23:33 10.25 9,049 9,059 PROD2 STK KOST P Kick off billet as per town recommendations. 1.4 bpm @ 3130 psi,WHP 282, BHP 3954, IA 0, OA 132,difficult to get started,22 stalls, pumped lube pill, no joy, beaded pill, no joy, try different tool face,speed, pump rates, kicked off at 90°R, re-positioned to 70°, 1.68 bpm at 3,446 psi, BHP 3,892 psi,WHP 217, IA 0, OA 150. Page 10 of 13 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:33 00:00 0.45 9,059 9,066 PROD2 DRILL DRLG P 9,059-ft, Drill L1-01 build section 1.68 bpm at 3,629 psi, BHP 3,913 psi, WHP 219, IA 0, OA 152 36/16/2015 Drill L1-01 build section from 9,066-ft to 9395, Drill lateral 9395 to 9443 00:00 01:21 1.35 9,066 9,090 PROD2 DRILL DRLG P 9,066-ft, Drill L1-01 build section 1.68 bpm at 3,607 psi, BHP 3,915 psi, WHP 222, IA 0, OA 153, 01:21 01:27 0.10 9,090 9,090 PROD2 DRILL WPRT P 9,090-ft, PUH to 9,030-ft, PUW 28k, drift billet area clean. 01:27 08:27 7.00 9,090 9,185 PROD2 DRILL DRLG P BOBD 1.5 bpm at 3,160 psi, BHP 3,863 psi,WHP 199, IA 0, OA 152 08:27 09:03 0.60 9,185 9,185 PROD2 DRILL WPRT P Geo wiper to 9,095'. PUW 28k, RIW 11.5k 09:03 14:03 5.00 9,185 9,395 PROD2 DRILL DRLG P BOBD 1.5 bpm at 3,500 psi, BHP 3,907 psi,WHP 195, IA 0, OA 154 14:03 16:18 2.25 9,395 80 PROD2 DRILL TRIP P 9,395-ft,TD build section, POOH, PUW 29.5k 16:18 19:00 2.70 80 0 PROD2 DRILL PULD P PJSM- Undeploy and LD BHA#13, bit condition 19:00 20:18 1.30 0 72 PROD2 DRILL PULD P PJSM-MU/Deploy BHA#14, 0.6° AKO motor and HYC 3.25" Bi-center bit, MU to CoilTrak, surface test. 20:18 22:06 1.80 72 8,760 PROD2 DRILL TRIP P RIH, EDC Open 22:06 22:12 0.10 8,760 8,755 PROD2 DRILL DLOG P Log K1 for+8'correction 22:12 22:42 0.50 8,755 9,395 PROD2 DRILL TRIP P RIH to 8950', Stop and shut EDC, PUW=28K, Continue in, clean pass through window 22:42 00:00 1.30 9,395 9,443 PROD2 DRILL DRLG P Tag up and drill ahead from 9395, 1.5 BPM @ 3145 PSI FS, BHP=3904, RIW=9.2K with DHWOB=1.7K, Midnight depth 9443 06/17/2015 Drill lateral 9443 to 10170', Swap to new mud system 00:00 07:21 7.35 9,443 9,690 PROD2 DRILL DRLG P 9443', drill ahead, 1.49 BPM @ 3143PS1 FS, BHP=3932, MUD SWAP, new mud to bit @ 9567' 07:21 07:36 0.25 9,690 9,200 PROD2 DRILL WPRT P Wipers @ 9,200'w/PUW 34K 07:36 07:51 0.25 9,200 9,690 PROD2 DRILL WPRT P Wiper in hole, RIW 11.4K 07:51 11:51 4.00 9,690 9,868 PROD2 DRILL DRLG P 9,690', BOBD 1.80 bpm @ 3,654 PSI, BHP 3,996 psi,WHP 287, IA 21, OA 159 11:51 12:21 0.50 9,868 9,872 PROD2 DRILL DRLG P Trouble getting drop in inclination, PUH and work pipe down 1'at a time for three feet, inclination dropping, 12:21 15:00 2.65 9,872 9,930 PROD2 DRILL DRLG P BOBD 1.8 bpm at 3197 psi, BHP 3971,WHP 284, IA 45, 0A 165 15:00 15:45 0.75 9,930 9,015 PROD2 DRILL WPRT P 9930 ft,wiper up hole above window 8945 ft, PUW 27k, 15:45 16:00 0.25 9,015 9,015 PROD2 DRILL DLOG P Tie into the RA marker correction of Plus 3.0 ft 16:00 16:36 0.60 9,015 9,930 PROD2 DRILL WPRT P Wiper back in hole RIW 12k 16:36 20:24 3.80 9,930 10,046 PROD2 DRILL DRLG P 9930 ft, BOBD 1.8 bpm at 3197 psi, BHP 3980, IA 2, OA 163 Page 11 of 13 Time Logs 1111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:24 00:00 3.60 10,046 10,170 PROD2 DRILL DRLG P ROP consistently low, Pump last part of drill zone pill, ROP briefly up to-45 FPH, 1.8 BPM @ 3710 PSI FS, BHP=4000 06/18/2015 Drill 10170 to 10454. POOH to inspect BHA, Motor good clay on bit. C/O Bit and Motor, P/U Agitator 00:00 02:30 2.50 10,170 10,230 PROD2 DRILL DRLG P Continue drilling ahead, 1.81 BPM @ 3710PSi FS, BHP=4010 02:30 03:30 1.00 10,230 10,230 PROD2 DRILL WPRT P Wiper trip to 9090, PUW=33K, Good density out on bottoms up. No over pulls or setdowns 03:30 08:00 4.50 10,230 10,292 PROD2 DRILL DRLG P Tag bottom and stall, Drill ahead 1.8 BPM ©3708 PSI FS, BHP=4035. Trouble getting going, Not getting differential pressure 08:00 10:00 2.00 10,292 1,000 PROD2 DRILL TRIP P POOH, PUW 30.5K 10:00 10:15 0.25 1,000 1,000 PROD2 DRILL SFTY P PJSM at 1000',while POOH 10:15 11:45 1.50 1,000 0 PROD2 DRILL PULD P PUD Lateral BHA#14 11:45 12:45 1.00 0 0 PROD2 DRILL PULD P Check bit and motor, discuss with town BHA#15 12:45 13:30 0.75 0 0 PROD2 DRILL PULD P PJSM, MU and deploy BHA#15, wtih Agitator and new HYC bi-center bit. 13:30 14:30 1.00 0 0 PROD2 DRILL PULD T Stacked out on tools with cart, PJSM for change of scope, disconnect Upper quick and inspect coil, coil looks good, undeploy upper section of BHA,to inspect, 14:30 16:00 1.50 0 78 PROD2 DRILL PULD P PJSM, MU and deploy BHA#15, wtih Agitator and new HYC bi-center bit. Surface test agitator. 16:00 17:54 1.90 78 8,765 PROD2 DRILL TRIP P RIH with BHA#15 17:54 18:00 0.10 8,765 8,792 PROD2 DRILL DLOG P Tie-in for+8.5 ft. correction 18:00 19:48 1.80 8,792 10,292 PROD2 DRILL TRIP P RIH with BHA#15, clean pass through window, Pumping drill zone pill while running in open hole 19:48 00:00 4.20 10,292 10,454 PROD2 DRILL DRLG P Tag up and drill ahead, 1.5 BPM @ 3610PSi FS, BHP=3985, ROP 30-50FPH 06/19/2015 Drill 10454 to early TD @ 10661', Perform swab wiper. M/U L1-01 completion, RIH 00:00 03:00 3.00 10,454 10,533 PROD2 DRILL DRLG P Drill, 1.58 BPM ©3813 PSI FS, BHP=3965 03:00 04:06 1.10 10,533 10,533 PROD2 DRILL WPRT P Wiper to 9100', PUW=29.5K, Mix up Drill Zone pill 04:06 09:36 5.50 10,533 10,661 PROD2 DRILL DRLG P 1.55 BPM @ 3890 PSI FS, RIW=9K, BHP=4046, ROP still low pump 1OBBI drill zone pill. Discussion with town and TD was called early. 09:36 12:30 2.90 10,661 82 PROD2 DRILL WPRT P Pump 10X10 sweep, chase to swab. 12:30 14:00 1.50 78 8,765 PROD2 DRILL WPRT P AT surface, reset counters, RIH 14:00 14:15 0.25 8,765 8,789 PROD2 DRILL DLOG P Tie in for+9.0ft correction, PUW 28k ________ . __. _ Page 12 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 15:30 1.25 8,789 10,400 PROD2 DRILL TRIP P RIH to 10,400', RIW 11.0k Clean at the window and billet. 15:30 18:12 2.70 10,400 96 PROD2 DRILL TRIP P POOH while laying in beaded liner running pill and paint EOP flag @ 7400'. Clean at the window and billet. 18:12 18:42 0.50 96 96 PROD2 DRILL OWFF P At surface, PJSM, 30 Min flow check 18:42 19:48 1.10 96 0 PROD2 DRILL PULD P Flow check good, unstab injector and lay down BHA#15 19:48 20:18 0.50 0 0 COMPZ CASING OTHR P Prep floor for liner pick up 20:18 23:12 2.90 0 1,465 COMPZ CASING PUTB P PJSM, P/U L1-01 completion, Non ported bull nose,41 Jts slotted,4 Jts solid, 1 Slotted, 2 solid and seal bore deployment sleeve, M/U to coil track and injector. Surface test tool 23:12 00:00 0.80 1,465 4,842 COMPZ CASING TRIP P RIH with BHA#16, EDC closed 06/20/2015 Complete running L1-01 Liner 10,394 to TOL @ 8973 Freeze protect from 2500' 00:00 00:54 0.90 4,842 8,865 COMPZ CASING TRIP P Continue in with L1-01 completion 00:54 01:00 0.10 8,865 8,865 COMPZ CASING DLOG P Tie into 7400' EOP flag for+4.43, PUW=29K 01:00 01:24 0.40 8,865 10,150 COMPZ CASING TRIP P Continue in with liner 01:24 01:30 0.10 10,150 10,176 COMPZ CASING DLOG P Log K1 for+2.5' 01:30 01:42 0.20 10,176 10,394 COMPZ CASING TRIP P Continue in hole, Stop at 10394, PUW=34K, DHWOB-9K, Go back to set depth, Pumps on 1.4 BPM, PUW=27K, DHWOB=-2.5K 01:42 02:42 1.00 10,394 10,385 DEMOB WHDBO DISP P PUH to 10385', roll well to seawater, Subtract liner length left in hole 02:42 03:42 1.00 10,385 2,500 DEMOB WHDBO DISP P POOH on seawater, Stop @ 2500' 03:42 04:36 0.90 2,500 2,500 DEMOB WHDBO FRZP P PJSM w/LRS, Load coil with 30 BBIs diesel 04:36 05:36 1.00 2,500 0 DEMOB WHDBO TRIP P Continue out of well 05:36 06:36 1.00 0 0 DEMOB WHDBO PULD P Crew change, PJSM,valve check list. 06:36 08:06 1.50 0 0 DEMOB WHDBO PULD P Undpeloy and LD BHA#15 08:06 10:06 2.00 0 0 DEMOB WHDBO RURD P MU nozzle to jet BOPE 10:06 11:21 1.25 0 0 DEMOB WHDBO MPSP P PJSM-Load and test FMC lubricator. 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N N m N C (O C (O M r N CO m O O r CO 1-- 6 1- v N o cd n N- n r` (d r 6 r` ,- 6 av 6 >.NN M M M M O O O O O O O M O M M M M M (O (O (O f0 O m m m m m (O O (O 6 O f0 6 0 mU W Y ''(N0 C m N m ) O m O M OVO N (O 'C M N C C - '' m m CC N N O O - O m m CO m O O C) Q a Vm 6) M O n QcM V V V N V N O O '▪ ^ C ‘,Ti- co co CC C C C N co O N coup co ` C)_ a Q ... M MM co MMMMM MMMMMMMM> LL /t//�1 Y y m m a a y(. U 2 3 J ' p O N y N p C O (U (p O W O) M4 M 00 N ' M n N V O N N N- n C a a : r E V ^ (d ((i NO M V N O 6) O O N r N N O 6 6 O O ,- ,- ,- C P.- co O O O O O co m O O O O m m m m m m m U Y Y aM OV co M M V O co co N co co co co co op 0 co Vc N N O V O O O 6 OO O 6 O O O V N O of O O O 6 ((j N ❑ N (n m C 1 O CO m O N (O O N (O CO C r O co co Q) O O O O go N N N elm M C (O O• co U `p C L V O O O O O r r .- .- r r r r ^O a _ 9 cm m U E •O Y d m 7)41 7 CO N O a co 0 (C ti ®� Tye • THE STATE Alaska Oil and Gas f tr0 ,-s�— ®f LA KA. ConservationConservationCoCommission A CA ✓ = =- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O� p. Main: 907.279.1433 LA 5 Fax: 907.276.7542 www,aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0306 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-19L1 ConocoPhillips Alaska, Inc. Permit No: 215-085 Surface Location: 668' FNL, 92' FEL, Sec. 19, T11N,R10E, UM Bottomhole Location: 1000' FNL, 1001' FEL, Sec. 17, T11N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 196-052, API No. 50-029- 22660-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /°774,,, Cathy . Foerster Chair DATED this 2-v day of May, 2015. • . RECEIVED STATE OF ALASKA MAY 15 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil 111, Service-Willi ❑ Single Zone Q v lc.Specify if well is proposed for: Drill ❑ , Lateral (QStratigraphic Test 1111 Development-Gas LI Service-Supply LI Multiple Zone❑ Coalbed Gas El Gas Hydrates CI— Redrill ❑ Reentry I Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: , LJ Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. . Bond No. 59-52-180 , KRU 1F-19L1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11500'' TVD: 6226' , Kuparuk River Field . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:668'FNL,92'FEL,Sec. 19,T11N,R10E,UM ' ADL 25652 * Kuparuk River Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2363'FSL,608'FEL,Sec. 17,T11N, R10E,UM 2578 6/15/2015 Total Depth: 9.Acres in Property: 14.Distance to 1000'FNL, 1001'FEL,Sec. 17,T11N, R10E, UM 2480 ' Nearest Property: 29390 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: .118 feet 15.Distance to Nearest Well Open Surface:x- 539884 • y- 5958860 - Zone- 4 4 GL Elevation above MSL: , 41 feet to Same Pool: 1F-06,650 16.Deviated wells: Kickoff depth: , 9054 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 94° deg Downhole:4005 psig I Surface:3378 psig. 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2000' 9500' 6255' 11500' 6266' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9457' 6585' none 9385' 6529' 9400' Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 232 sx AS I 121' 121' Surface 4515' 7.625" 690 sx AS III,400 sx Cl G 4557' 3822' Production 9421' 5.5"x3.5" 230 sx Class G 9450' 6580' Perforation Depth MD(ft): Perforation Depth TVD(ft): 9124'-9136',9156'-9176',9183-9198' 6327'-6336',6351'-6367',6372'-6384' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Cody Pohler @ 265-6435 Email Codv.J.Pohlercop.com Printed Name D. haus Title CTD Engineering Supervisor CVP /°iik Signature �'�" Phone:263-4372 Date 5 If q(CS Commission Use Only Permit to Drill _ API Number: I Permit Approval ( See cover letter Number: t�IJ — ogs 50-O&9 —aa�G 0 -Go-o, Date: 5 f ' (5 Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: FiL Other: BO p i.e., 7-f to g DUCT 5 i Samples req'd: Yes No + Mud log req'd: Yes❑ No pigi fink 71,1 a r/�rr'V«fertz 5t)v Z-5-I)0 i) It2S measures: Yes No ❑ Directional svy req'd: Yes yi No❑ Spacing exception req'd: Yes ❑ No ❑f Inclination-only svy req'd: Yes No[/' APPROVEDBYTHE [` Approved by: �S� I� COMMISSION Date: J Form 10-401 (R ised 10/2012) Th i f r�4 A From the date of approval(20 AAC 25.005(g)) s/ 5���/� i/y`L 57 Z6,/ !„5 • • ConocoPh i l l i s RECEIVED p Alaska MAY 15 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC FLOC,CC April 28, 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 an application for a permit to drill a dual lateral from the existing well bore on KRU 1F-19 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin on June 15, 2015. The CTD objective will be to drill 2 laterals(1F-19L1 & 1 F- 19L1-01), targeting the A4 &A5 sands. This well will be classified as a development well. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 1F-19L1 & 1F-19L1-01 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6435. Sincerely, .411°/ 6 Cody Pohler Coiled Tubing Drilling Engineer 907-265-6435 • Kuparuk CTD Laterals NABORS ALASKA A 1 F-19L1 & 1 F-19L1-01 IJP C°°°`°P""P Application for Permit to Drill Document 211C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 1F-19L1 & 1F-19L1-01 7 Attachment 2: Current Well Schematic for 1F-19 7 Attachment 3: Proposed Well Schematic for 1F-19L1 & 1F-19L1-01 7 Page 1 of 7 5/14/2015 PTD Apkation: 1F-19L1 & 1F-19 L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document 1F-19L1 and 1F-19L1-01. These laterals will be classified as "Development— Oil" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A4 &A5 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1F-19L1 and 1F-19L1-01. 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 prgssure tested to 250 psi and to 4000 psi. Using the maximum formation pressure in the area of 4005 psi in the 1E-11, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3378 psi/ See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 4000 psi. 4. Drilling Hazards Information and Reservoir Pressure Li 4 (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.00 '(c)(4)(a)) A static bottom hole pressure of 1F-19 in May 2015 indicated a reservoir pressure of 2754 psi or 8.3 ppg equivalent mud weight. The maximum down hole pressure in the 1F-19 pattern is at 1E-11 with 4005 psi. It is not expected that reservoir pressure as high as 1E-11 will be encountered while drilling the 1F-19L1 and 1F- 19L1-01 due to the drilling path of the laterals. Using the 1E-11 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3378 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 1F pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1F-19 laterals will be drilling into an unstable shale. Managed pressure drilling will be used to reduce this risk. 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 5/14/2015 • PTD A 1fcation: 1F-19L1 & 1F-19L1-01 pp 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 IF-19L1 9,500' 11,500' 6,255' 6,266' 23/", 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 2%", 4.7#, L-80, ST-L slotted liner; 1F-19L1-01 9,050' 11,500' 6,155' 6,212' with a shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Conn. Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 42' 121' 42' 121' 1640 630 Surface 7-5/8" 29.7 L-80 BTC 42' 4557' 42' 3822' 7240 5410 Production 5%"x3'/" 15.5 L-80 LTC 39' 9,450' 39' 6579' 7240 5410 Tubing 3%" 9.3 L-80 IBTM 37' 6,887' 37' 4,990 10540 10160 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 PowerVis mud (9.9 qpg) — Drilling operations: Chloride-based Powervis mud (9.9 ppg). This mud weight will hydrostatically overbalance the reservoir pressure. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12 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 drillsite 18 in the Kuparuk field, and is accessible for trucking to the rig during CTD operations. Page 3 of 7 5/14/2015 • PTD AppTiCation: 1F-19L1 & 1F-19L1-01 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. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case a constant BHP of 11.4 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the fault blocks being drilled into. 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 1F-19 Window (9054' MD, 6273' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (8.3 ppg) 2754 psi 2754 psi Mud Hydrostatic (9.4 ppg) 3066 psi 3066 psi Annular friction (i.e. ECD, 0.060 psi/ft) 543 psi 0 psi Mud + ECD Combined 3609 psi 3066 psi (no choke pressure) (overbalanced (overbalanced —855 psi) —312 psi) at Window(11.4 ppg) 3814 psi 3814 psi Choke Pressure Required to Maintain Target 110 psi 653 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Page 4 of 7 5/14/2015 • • PTD Application: 1F-19L1 & 1F-19L1-01 Summary of Operations Background IF Well 2i1'ns a Kuparuk A-sand development well equipped with 5'/2"x 3'/2"tapered production casing. Two laterals will be drilled out of the 3'/2"towards the north of the mother bore. A mechanical whip-stock will be placed in the 3 '/2"casing at the planned kickoff point of 9,054' MD. We will mill a window and land the build section at 9,291' MD. From there we will pick up lateral drilling tools and drill the L1 to a depth of 11,500' in the A4 sand. We will run 2-3/8" slotted liner with an aluminum billet back up to 9,500' MD. We will kick off the L1-01 and drill to a depth of 11,500' MD in the A5 sand. We will run 2-3/8" slotted liner with shorty deployment sleeve up into the parent bore(9,050' MD). Pre-CTD Work • Slick-line: Perform dummy whip-stock run, dummy off all gas lift valves,MIT-IA test, and obtain a SBHP • E-Line: Set a mechanical whip-stock at 9054' MD Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1F-19L1 Lateral(A4 sand-North) i. Mill 2.80"window at 9054' MD ii. Drill 2.74"x 3.00"bi-center lateral to TD of 11,500' MD iii. Run 2%"slotted liner with an aluminum billet from TD up to 9,500' MD 3. 1F-19L1-01 Lateral(A5 sand -North) i. Kick off the billet at 9,500' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 11,500' MD iii. Run 2%" slotted liner with a shorty deployment sleeve from TD up into the parentbore 4. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Return to operations Page 5 of 7 5/14/2015 • PTD App cation: 1F-19L1 & 1F-19L1-01 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, so we will use the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via 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 — All the laterals will be displaced to an overbalancing fluid (11.6 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. • 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 Plan — 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 (measured to KPA boundary at closest point) Lateral Name Diistancex 1F-19L1 29,390' 1F-19L1-01 29,390' Page 6 of 7 5/14/2015 PTD Aptcation: 1 F-19L1 & 1 F-19L1-01 - Distance to Nearest Well within Pool (measured to offset well) Lateral Name Dia Vie ' , ,R Well 1F-19L1 650' 1F-06 1F-19L1-01 650' 1F-06 16. Attachments Attachment 1: Directional Plans for 1F-19L1 & 1F-19L1-01 Attachment 2: Current Well Schematic for 1F-19 Attachment 3: Proposed Well Schematic for 1F-19L1 & 1F-19L1-01 Page 7 of 7 5/14/2015 No-/ s 11110 KUP PROD 1F-19 Conoc Phillips ; Well Attributes Max Angle&MD TD 44 Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status not Et MD(ftKB) Act Btm(ftKB) cnnnm`Ruwps 500292266000 KUPARUK RIVER UNIT PROD 63.78 5,520.93 9,457.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-19,11/23/20143:09:41 PM SSSV:NIPPLE 80 8/142012 Last WO: 6/14/2014 1 3/23/1996 Vertical schematic.(actuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 9,311.0 2/5/2009 Rev Reason:PULL IBP hipshkf 11/23/2014 j � 'IHANGER,36.8 �ts - sifgStrings 1 r � II CasingDescription OD(in) ID(n) Top(ftKB) Set Depth(ftKB) Set Depth(ND) . WtlLen(I...Grade Top Thread 8CONDUCTOR16 15.062 42.0 121.0 62.50 H-40 WELDED i; 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.,.Grade Top Thread SURFACE 75/8 6.875 41.6 4,557.1 3,821.9 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread L PRODUCTION 5 12 4.950 38.7 9,450.2 6,579.6 15.50 L-80 LTC-MOD 5.5"x3.5"@8772' Tubing Strings Tubing Description String Ma...ID(in) Top IftKB) Set Depth(ft..Set Depth(TVD)I...Wt(I Mt) Grade Top Connection -A"1/4r CONDUCTOR,42.D-1zto i^TUBING WO(Upper) 3 1/2 2.992 36.8 6 887.3 4,990.2 9.30 L-80 IBTM Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal lD NIPPLE;508.3 L- 36.8 HANGER FMC TUBING HANGER (13.500 508.3 508.3 0.24 NIPPLE CAMCO"DS"NIPPLE 2.875 6,869.6' 4,980.9 58.24 SEAL ASSY PBR SEAL ASSEMBLY with Space-out 3' 2.990 6,872.8 4,982.6 58.25 PBR PBR 80-40 SPECIAL TRIM(4.78"OD) 4.010 GAS LIFT;2,625.5 IIH. 6,886.8 4,990.0 58.29 ANCHOR KBH-22 ANCHOR SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(lb/ft) Grade Top Connection ), TUBING WO(Lower) 31/2 2.992 6,887.3 8772.3 6,059.2 9.30 L-80 IBTM Completion Details in Top IftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com N (in) IID GAS LIFT,4,305.44 6,887.3 4,990.2 58.29 PACKER BAKER 45-FA-36 PRODUCTION PACKER 3.020 6,965.2 5,030.7 59.16 NIPPLE HES'X'NIPPLE 2.812 8,771.3- 6,058.5 41.94'SEAL ASSY BAKER 80-40 GBH-22 LT SEAL ASSY w/1'space-out 2.990 `' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl ): Top(ftKB) (ftKB) p) Des Com Run Date ID(in) 9,400.0 6,540.5 38.89 FISH TWO 6"LONG SEALING ELEMENTS LEFT IN 7/19/2014 SURFACE.41.6-4557.1- 4. HOLE AFTER PULLING IBP -6, ..�-31x ,kms -.1-1-'11-P r 1115;/ GAS LIFT;5,863.8 giti Dens Shot Top IND) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (8)(13) (ftKB) Zone Date t) Type Com 9,124.0 9,136.0' 6,326.5 6,335.8 A-5,1F-19 2/21/2009 6.0 APERF 2"PJ HSD CHARGES 9,156.0 9,176.0 6,351.2 6,366.6 A-4,1F-19 5/20/1996 4.0 IPERF 2.5"Hollow Case;180 en;54 deg CC Orient GAS LIFT;6,812.4 CCW 9,161.0 9,171.0 6,355.1 6,362.8 A-4,1F-19 9/29/2006 6.0 RPERF 2"HSD BH 2006 Powerfow 9,183.0 9,198.0 6,372.0 6,383.6 A-4,1F-19 2/20/2009 6.0 APERF 2"PJ HSD CHARGES H ;Stimulations&Treatments Min Top Man Btm • PBR;6,872.8 t=-.J. Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com ANCHOR;6,886.8 I 9,156.0 9,176.0 6,351.2 6,366.6 FRAC A-SAND 10/2/2006 BREAKDOWN,DATA FRAC AND A-SAND PACKER;6,887.3 FRACTURE TREATMENT DESIGNED FOR 158,000#16/20 W/YF150D.PUMPED 176240# 16/20 TO COMPLETION 10 PPA ON FORMATION, ADJUSTED PAD FROM 260 BBLS TO 240 BBLS Mandrel Inserts NIPPLE;6,965.2 _ 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' 2,625.6 2,588.2 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.156 1,342.0 7/21/2014 9 I 2 4,305.4 3,697.9 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.156 1,324.0 7/21/2014 9 I 3 5,863.8 4,472.8 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.188 1,346.0 7/20/2014 9 I SEAL ASSY;8.771.3 4 6,8124 4,950.7 CAMCO KBG-2- 1 GAS LIFT OV Integra 0.188 0.0 7/20/2014 9 I Notes:General&Safety 1, End Date Annotation 9/14/2010 NOTE View Schematic w/Alaska Schematic9.0 r s APERF;9,124.09,136.0 (PERF;9,156.0-9,176.0 R FRAC -SAN;9,1560 e.- FRAC AD;9,156.0` r APERF;9,183.09,198.0 w FISH;9,400.0--. PRODUCTION 5.5"x35" 8772';38.7-9,450.2 • 1F-19 Proposed CTD Schematic Modified by 1GE 3-1145 16"62#H-40 Conductor at 3-1/2"Camco DS nipple at 508'MD(2.875"min ID) 121'MD 3-1/2"9.2#L-80 IBT-Mod Tubing to surface 7-5/8",29.7#, L-80 3-1/2"Camco KBG-2 gas lift mandrels at 2626',4305',5364',& Surface Casing at — — 6812' 4557'MD Baker 80-40 seal assembly at 6873'MD Baker KBH-22 Anchor Seal Assembly at 6887'MD Baker 45-FA-36 Packer at 6887' 3-1/2"X-nipple at 6965'MD(2.812"min ID) Baker 80-40 GBH-22 seal assembly at 8771'MD, stung into GBH-22 SBE at 8722'in the 5'/2'x3'/2" tapered production casing N r-z-z Baker GBH-22 SBE at 3-1/2"monobare 'ems' 8722'MD whipstock at 9054'MD KOP@9054'MD 1F-19L1-01;Planned TD 11,500'MD I I 2W slotted liner with top at 9049'MD A-sand perfs 9124'-9136'MD 9156-9176'MD 9183'-9198' MD 1F-19L1, Planned TD 11,500'MD 2W slotted liner with billet at 9500'MD 5'/2'x 3'/2"tapered production casing 5'/2', 15.5 ppf,L-80, LTC-Mod 0'-8772'MD 3'/2', 9.3 ppf,L-80, EUE 8rd-Mod, 8772'-9450'MD • • N la 8 gi s /. o. . c I � :-67LL LL o„w„m 0 2$08 2 r • u.UoU§ v _ ... ...g �m mTm ... . lJ L3 '& LL I w & z I , I . _ o n , I v, O LL __.__ ...---.... _—_____ _ _ --_ ,--___ _ ._______ N I. v co 1 OO) • 4 o W• n2 , , ,L , W N O I b'a5 __ O . • 3- o c o _, d •• R __k I I o Ere .1..,77.-- o 0 @ 0 [�] as d IL59 - • • < o 1 �r^, - y i V I 005 0 e 1 boo m va I M>LL 1 LLO Wti OILL I: I. < I , 1 an,--,- y3a= 0 - 3r I f' 2. . _ _ �_ - , I i : o © I o0 o � o 4 1---- < , s I 1 In Q I I , o "O ` I U o 0 OOo h a o ' o O e o m 0M N O O 0 N 8 G O q 0 • O (ul/ sn 00z)(+)upioN/(-)u4nosu S • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1F Pad 1F-19 1F-19L1 Plan: 1F-19L1 wp06 Vi Standard Planning Report 22 April, 2015 IGS ��. rtI BAKER HUGHES • 4 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference Well 1F-19 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: . Mean Sea Level Project: Kuparuk River Unit MD Reference: li 1F-19 @ 118.00usft(1F-19) Site: Kuparuk 1F Pad North Reference: True Well: 1F-19 Survey Calculation Method: Minimum Curvature Wellbore: 1F-19L1 Design: 1 F-19L1_wp06 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 1F Pad Site Position: Northing: 5,958,365.15 usft Latitude: 70°17'49.903 N From: Map Easting: 539,591.86 usft Longitude: 149°40'45.817 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30° 1F-19 I Iii ntr.. ...... ,.K .,, u.... - Well Position +N/-S 0.00 usft Northing: 5,958,859.58 usft Latitude: 70°17'54.751 N I +E/-W 0.00 usft Easting: 539,883.64 usft Longitude: 149°40'37.234 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft - - I Wellbore1F-19L1 Oragrtetras Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 8/1/2015 18.75 80.91 57.552 s: . -- k, daG41 F 19L1,..wp06 i pik N .- tW „,......0...auip9111kh>Y%a:.3'jt. �- ',0. _ Audit Notes: Version: Phase: PLAN Tie On Depth: 9,023.32 ertical S ,` a. ,,0 Direction �' -76.50 0.00 0.00 0.00 4/22/2015 11:59:54AM Page 2 COMPASS 5000.1 Build 61 • • IA"ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox -,Eal Local Co-ordinate Reference: Well 1F-19 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1F-19 @ 118.00usft(1F-19) Site: Kuparuk 1F Pad North Reference: True Well: 1F-19 Survey Calculation Method: Minimum Curvature Wellbore: 1F-19L1 Design: 1 F-19L1_wp06 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°1100ft) (°/100ft) a-„ Target 9,023.32 40.15 65.38 6,131.31 2,653.20 4,669.68 0.00 0.00 0.00 0.00 9,054.00 40.00 64.91 6,154.79 2,661.50 4,687.60 1.10 -0.49 -1.53 -116.55 9,075.00 42.57 62.74 6,170.57 2,667.61 4,700.03 14.00 12.22 -10.35 330.00 9,145.00 66.66 48.62 6,210.94 2,700.29 4,746.02 38.00 34.42 -20.16 330.00 9,286.82 85.00 355.96 6,247.99 2,822.97 4,793.45 38.00 12.93 -37.13 -78.62 9,445.49 89.75 345.91 6,255.27 2,979.24 4,768.50 7.00 2.99 -6.34 295.00 9,695.49 89.46 328.41 6,257.01 3,208.74 4,671.84 7.00 -0.12 -7.00 269.00 9,790.00 92.25 322.41 6,255.60 3,286.50 4,618.23 7.00 2.96 -6.35 295.00 10,020.00 92.16 338.53 6,246.68 3,485.81 4,505.33 7.00 -0.04 7.01 90.00 10,120.00 91.06 345.44 6,243.87 3,580.81 4,474.43 7.00 -1.11 6.91 99.00 10,300.00 91.03 358.04 6,240.57 3,758.56 4,448.63 7.00 -0.01 7.00 90.00 10,370.00 87.88 1.80 6,241.24 3,828.53 4,448.53 7.00 -4.50 5.36 130.00 10,440.00 87.89 6.70 6,243.82 3,898.27 4,453.71 7.00 0.01 7.00 90.00 10,595.00 86.99 355.88 6,250.77 4,052.85 4,457.19 7.00 -0.58 -6.98 265.00 10,750.00 88.17 345.08 6,257.35 4,205.34 4,431.61 7.00 0.76 -6.96 276.00 10,850.00 89.39 351.97 6,259.48 4,303.26 4,411.73 7.00 1.23 6.89 80.00 10,950.00 91.79 358.55 6,258.45 4,402.85 4,403.48 7.00 2.39 6.58 70.00 11,100.00 93.57 348.19 6,251.42 4,551.48 4,386.23 7.00 1.19 -6.91 280.00 11,300.00 93.71 2.22 6,238.67 4,749.88 4,369.60 7.00 0.07 7.01 89.00 11,500.00 93.60 348.19 6,225.87 4,948.28 4,352.96 7.00 -0.06 -7.01 270.00 • 4/22/2015 11:59:54AM Page 3 COMPASS 5000.1 Build 61 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: 1 Well 1F-19 Company:" ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1F-19©118.00usft(1F-19) Site: Kuparuk 1F Pad North Reference: True Well: 1F-19 Survey Calculation Method: Minimum Curvature Wellbore: 1F-19L1 Design: 1 F-19L1_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Ni-S +61-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 9,023.32 40.15 65.38 6,131.31 2,653.20 4,669.68 2,653.20 0.00 0.00 5,961,537.26 544,538.71 TIP 9,054.00 40.00 64.91 6,154.79 2,661.50 4,687.60 2,661.50 1.10 -116.55 5,961,545.65 544,556.59 KOP 9,075.00 42.57 62.74 6,170.57 2,667.61 4,700.03 2,667.61 14.00 -30.00 5,961,551.84 544,568.98 End 14 dls,Start 38 dls 9,100.00 50.97 56.64 6,187.68 2,676.85 4,715.69 2,676.85 38.00 -30.00 5,961,561.15 544,584.60 9,145.00 66.66 48.62 6,210.94 2,700.29 4,746.02 2,700.29 38.00 -25.81 5,961,584.75 544,614.80 4 9,200.00 72.21 27.08 6,230.45 2,740.74 4,777.23 2,740.74 38.00 -78.62 5,961,625.37 544,645.79 9,286.82 85.00 355.96 6,247.99 2,822.97 4,793.45 2,822.97 38.00 -70.96 5,961,707.67 544,661.57 End 38 dls,Start 7 dls 9,300.00 85.39 355.13 6,249.09 2,836.06 4,792.43 2,836.06 7.00 -65.00 5,961,720.76 544,660.48 9,400.00 88.38 348.79 6,254.53 2,934.87 4,778.46 2,934.87 7.00 -64.93 5,961,819.48 544,645.99 9,445.49 89.75 345.91 6,255.27 2,979.24 4,768.50 2,979.24 7.00 -64.58 5,961,863.80 544,635.79 6 9,500.00 89.68 342.09 6,255.54 3,031.63 4,753.48 3,031.63 7.00 -91.00 5,961,916.10 544,620.50 9,600.00 89.56 335.10 6,256.20 3,124.68 4,717.01 3,124.68 7.00 -90.98 5,962,008.94 544,583.53 9,695.49 89.46 328.41 6,257.01 3,208.74 4,671.84 3,208.74 7.00 -90.93 5,962,092.76 544,537.93 7 9,700.00 89.59 328.13 6,257.05 3,212.58 4,669.47 3,212.58 7.00 -65.00 5,962,096.58 544,535.54 9,790.00 92.25 322.41 6,255.60 3,286.50 4,618.23 3,286.50 7.00 -65.00 5,962,170.22 544,483.91 8 9,800.00 92.25 323.11 6,255.21 3,294.46 4,612.18 3,294.46 7.00 90.00 5,962,178.14 544,477.82 9,900.00 92.23 330.12 6,251.29 3,377.84 4,557.24 3,377.84 7.00 90.03 5,962,261.23 544,422.44 10,000.00 92.18 337.12 6,247.44 3,467.31 4,512.87 3,467.31 7.00 90.30 5,962,350.45 544,377.60 10,020.00 92.16 338.53 6,246.68 3,485.81 4,505.33 3,485.81 7.00 90.57 5,962,368.91 544,369.96 9 10,100.00 91.28 344.06 6,244.27 3,561.52 4,479.69 3,561.52 7.00 99.00 5,962,444.48 544,343.92 10,120.00 91.06 345.44 6,243.87 3,580.81 4,474.43 3,580.81 7.00 99.17 5,962,463.74 544,338.56 10 10,200.00 91.05 351.04 6,242.39 3,659.09 4,458.13 3,659.09 7.00 90.00 5,962,541.92 544,321.85 10,300.00 91.03 358.04 6,240.57 3,758.56 4,448.63 3,758.56 7.00 90.10 5,962,641.32 544,311.82 11 10,370.00 87.88 1.80 6,241.24 3,828.53 4,448.53 3,828.53 7.00 130.00 5,962,711.29 544,311.35 12 10,400.00 87.88 3.90 6,242.35 3,858.47 4,450.02 3,858.47 7.00 90.00 5,962,741.24 544,312.68 10,440.00 87.89 6.70 6,243.82 3,898.27 4,453.71 3,898.27 7.00 89.92 5,962,781.05 544,316.16 13 10,500.00 87.53 2.51 6,246.22 3,958.02 4,458.52 3,958.02 7.00 -95.00 5,962,840.81 544,320.66 10,595.00 86.99 355.88 6,250.77 4,052.85 4,457.19 4,052.85 7.00 -94.83 5,962,935.62 544,318.82 14 10,600.00 87.02 355.53 6,251.04 4,057.82 4,456.82 4,057.82 7.00 -84.00 5,962,940.60 544,318.42 10,700.00 87.78 348.56 6,255.58 4,156.70 4,443.00 4,156.70 7.00 -83.98 5,963,039.39 544,304.08 10,750.00 88.17 345.08 6,257.35 4,205.34 4,431.61 4,205.34 7.00 -83.67 5,963,087.97 544,292.43 15 10,800.00 88.78 348.53 6,258.68 4,254.00 4,420.20 4,254.00 7.00 80.00 5,963,136.56 544,280.77 10,850.00 89.39 351.97 6,259.48 4,303.26 4,411.73 4,303.26 7.00 79.91 5,963,185.77 544,272.04 16 10,900.00 90.59 355.26 6,259.49 4,352.94 4,406.18 4,352.94 7.00 70.00 5,963,235.42 544,266.22 10,950.00 91.79 358.55 6,258.45 4,402.85 4,403.48 4,402.85 7.00 70.00 5,963,285.31 544,263.26 17 4/22/2015 11:59:54AM Page 4 COMPASS 5000.1 Build 61 • /gal ConocoPhillips Planning Report BAKER HUGHES Databases, EDM Alaska Sandbox Local .ordinate Reference: Well 1 F-19 ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Kuparuk River Unit 1F-19 @ 118.00usft(1F-19) Site: Kuparuk 1F Pad True Well. 1F-19 Survey tea cutationMethod: Minimum Curvature Wellbore: 1F 19L1 • tri:esign: 1 F-19L1_wp06 fanned Survey ecEIOn<. - � ns i r yy 66 ` ' {Usft} ° (us-) (usft) - v Y; 11,000.00 92.39 355.10 6,256.63 4,452.74 4,400.72 4,452.74 7.00 -80.00 5,963,335.17 544,260.24 11,100.00 93.57 348.19 6,251.42 4,551.48 4,386.23 4,551.48 7.00 -80.13 5,963,433.83 544,245.22 18 11,200.00 93.67 355.21 6,245.10 4,650.17 4,371.83 4,650.17 7.00 89.00 5,963,532.43 544,230.30 11,300.00 93.71 2.22 6,238.67 4,749.88 4,369.60 4,749.88 7.00 89.44 5,963,632.11 544,227.54 19 11,400.00 93.68 355.21 6,232.22 4,849.58 4,367.36 4,849.58 7.00 -90.00 5,963,731.80 544,224.77 11,500.00 93.60 348.19 6,225.87 4,948.28 4,352.96 4,948.28 7.00 -90.45 5,963,830.40 544,209.85 Planned TD at 11500.00 4/22/2015 11:59:54AM Page 5 COMPASS 5000.1 Build 61 110 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1F-19 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1F-19 @ 118.00usft(1F-19) Site: Kuparuk 1F Pad North Reference: True Well: 1F-19 Survey Calculation Method: Minimum Curvature Wellbore: 1F-19L1 Design: 1F-19L1_wp06 ' Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing -Shape (°) (°) (usft) (usft) (usft)' (usft) _ (u, q ;°° lude Longitude 1F-19L1_T07 0.00 0.00 6,226.00 -1,351.261,144,478.69 5,963,582.00 1,684,241.00 70°3'30.623 N 140°29'12.542 W -plan misses target center by 1139692.88usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19 CTD Polygon 0.00 0.00 0.00 -3,499.941,144,749.31 5,961,435.00 1,684,523.00 70°3'9.364 N 140°29'14.139 W -plan misses target center by 1139990.52usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Polygon Point 1 0.00 0.00 0.00 5,961,435.00 1,684,523.00 Point 2 0.00 -269.72 131.60 5,961,166.01 1,684,656.02 Point 3 0.00 -169.49 280.14 5,961,267.02 1,684,804.01 Point 4 0.00 1.31 322.04 5,961,438.02 1,684,845.00 Point5 0.00 269.47 296.45 5,961,706.01 1,684,817.99 Point 6 0.00 589.17 171.12 5,962,025.01 1,684,690.97 Point7 0.00 931.03 14.89 5,962,366.00 1,684,532.95 Point 8 0.00 1,319.04 19.93 5,962,754.00 1,684,535.93 Point9 0.00 1,757.33 -25.77 5,963,192.00 1,684,487.91 Point 10 0.00 2,408.81 -103.35 5,963,842.99 1,684,406.88 Point 11 0.00 2,346.72 -466.72 5,963,778.98 1,684,043.88 Point 12 0.00 1,710.18 -378.05 5,963,142.98 1,684,135.92 Point 13 0.00 1,263.79 -314.39 5,962,696.98 1,684,201.94 Point 14 0.00 827.79 -322.69 5,962,260.98 1,684,195.95 Point 15 0.00 448.92 -164.66 5,961,883.00 1,684,355.98 Point 16 0.00 186.08 -11.02 5,961,621.00 1,684,510.99 Point 17 0.00 0.00 0.00 5,961,435.00 1,684,523.00 • 1F-19L1_T01 0.00 0.00 6,249.00 -3,462.831,144,918.53 5,961,473.00 1,684,692.00 70°3'9.474 N 140°29'9.167 W -plan misses target center by 1140142.41 usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19L1_T04 0.00 0.00 6,247.00 -2,832.281,144,638.84 5,962,102.00 1,684,409.00 70°3'16.009 N 140°29'14.393 W -plan misses target center by 1139859.42usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19L1_T05 0.00 0.00 6,241.00 -2,540.901,144,574.38 5,962,393.00 1,684,343.00 70°3'18.932 N 140°29'14.966 W -plan misses target center by 1139793.55usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19L1_Faultl 0.00 0.00 0.00 -3,339.721,144,899.18 5,961,596.00 1,684,672.00 70°3'10.698 N 140°29'9.185 W -plan misses target center by 1140139.50usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Rectangle(sides W320.00 H1.00 D0.00) 1 F-19L1_T03 0.00 0.00 6,257.00 -3,044.991,144,767.73 5,961,890.00 1,684,539.00 70°3'13.753 N 140°29'11.648 W -plan misses target center by 1139989.38usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19L1_T06 0.00 0.00 6,260.00 -1,995.651,144,537.27 5,962,938.00 1,684,303.00 70°3'24.281 N 140°29'13.663 W -plan misses target center by 1139754.01 usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point 1F-19L1_T02 0.00 0.00 6,255.00 -3,337.711,144,898.19 5,961,598.00 1,684,671.00 70°3'10.719 N 140°29'9.204 W -plan misses target center by 1140121.38usft at 9286.82usft MD(6247.99 TVD,2822.97 N,4793.45 E) -Point � Casing Hole ( ®' °° Diameter Diameter 11,500.00 6,225.87 2 3/8" 2.375 3 000 4/22/2015 11:59:54AM Page 6 COMPASS 5000.1 Build 61 , . • • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: 'I Well 1F-19 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference:, Mean Sea Level Project: Kuparuk River Unit MD Reference: 1F-19 @ 118.00usft(1F-19) Site: Kuparuk 1F Pad North Reference: True Well: 1F-19 Survey Calculation Method: Minimum Curvature Wellbore: 1F-19L1 Design: 1 F-19L1_wp06 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S ':—.7:::.-..---''..:.7'., (usft) (usft) (usft) (usft) Comment 9,023.32 6,131.31 2,653.20 4,669.68 TIP 9,054.00 6,154.79 2,661.50 4,687.60 KOP 9,075.00 6,170.57 2,667.61 4,700.03 End 14 dls,Start 38 dls 9,145.00 6,210.94 2,700.29 4,746.02 4 9,286.82 6,247.99 2,822.97 4,793.45 End 38 dls,Start 7 dls 9,445.49 6,255.27 2,979.24 4,768.50 6 9,695.49 6,257.01 3,208.74 4,671.84 7 9,790.00 6,255.60 3,286.50 4,618.23 8 10,020.00 6,246.68 3,485.81 4,505.33 9 10,120.00 6,243.87 3,580.81 4,474.43 10 10,300.00 6,240.57 3,758.56 4,448.63 11 10,370.00 6,241.24 3,828.53 4,448.53 12 10,440.00 6,243.82 3,898.27 4,453.71 13 10,595.00 6,250.77 4,052.85 4,457.19 14 10,750.00 6,257.35 4,205.34 4,431.61 15 10,850.00 6,259.48 4,303.26 4,411.73 16 10,950.00 6,258.45 4,402.85 4,403.48 17 11,100.00 6,251.42 4,551.48 4,386.23 18 11,300.00 6,238.67 4,749.88 4,369.60 19 11,500.00 6,225.87 4,948.28 4,352.96 Planned TD at 11500.00 4/22/2015 11:59:54AM Page 7 COMPASS 5000.1 Build 61 . . • li • • • k. _ UI_ • • • • ■s • D • • • o Q= WI ^ CO d I 7 .� S T. p I O j ON J 0-__-_ _..._.._._..._ I .__ ......---T 0 - O oo h • M a m^ • 0 • I ". ..- 40k • 1:1111,1 o4 al..._.1\ 1 apo ........ 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N at OOh-CC) e-C")CD P U)N a-NON C)Cn -,M CCJ R NI C(NI V V V V'LO CC)CC)CC)CC')M N • N N N N N N N N N N N N N N N N N `t p Lt, L 05 TS O O CO CO OCD CO CO CO CD CD CD O CO CO CO CO CD CD . •• 0 00 0-','00 I • N Z co 'N W et.N c O e-.-M O O CO I C C)O)N O E. M • • • aMOI�CO�m�CY CC) O oO Y� 00>Cn�N.- OS CC)CtNCOCt)Lei CDN 6 CC)N.-VD.,CCS 00 CONCa7 CC) CO CO CO V CC)CY N N M V'CC) Cn V CC).1 V Ct in • N CO MM M C`O MM M M C)00 M M • • ... -........... -._L--�. .-......-�. ._-....-_.. --...... UCn O C)4D<7 N-CO Cn CD CO CO N CD CA SCA CD O N C�OC[)COOI�Ct N�00 CO CO ODM u)p-CO -" N mom CS O O CV C0 CC)CD CD CV CV��N-N-CO N CP y-<C•7 M I 0 • •• cam Iro ��V GOOD COTOOO CO W c0 00 W Of OCA O) W o + O O N O O O N to m 0 0 0 0 0 0 0 0 0 0 0 0 0 __ �.. ....._-... ...... ____. __.... M 0 0 0 00 V Ct 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 JN 07 et CC)CC)CO CC)CC)0006 CD CD CC)O O OO CS co CD 0 oo so vs e m a '0 000 N 00 CO 1e-0 MMCY CO N-C0 CD n-MC)C U CD 0)O)CD O)0)6)CD O O O O O O O O O e- Q Cr)O m O C).N Met CC)CO re-co as OO NCO V CC)CON000O)0 o N (ui sn 08)updau I °!1-aA anal V • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1F Pad 1F-19 1F-19L1 1F-19L1 jovp06 Travelling Cylinder Report 21 April, 2015 Mitt BAKER HUGHES • Baker Hughes INTEQ • ®aa® ConocoPhillips Travelling Cylinder Report BAKERHES C Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project: Kuparuk River Unit TVD Reference: 1F-19 @ 118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 @ 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1 F-19L1 Database: OAKEDMP2 Reference Design: 1 F-19L1_wp06 Offset TVD Reference: Offset Datum Reference 1F-19L1_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,023.32 to 11,500.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,345.85usft Error Surface: Elliptical Conic Survey Tool Program Date 4/21/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 1 466.15 9,023.32 1F-19(1F-19) MWD MWD-Standard 9,023.32 11,500.00 1 F-19L1_wp06(1F-191.1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,500.00 6,343.87 2 3/8" 2.375 3.000 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 1E Pad 1E-15-1E-15A-1E-15A 9,500.00 9,350.00 1,097.66 201.54 897.75 Pass-Major Risk Kuparuk 1F Pad 1F-01-1F-01-1 F-01 Out of range 1F-01-1F-01A-1F-01A Out of range 1F-01-1 F-01AL1-1F-01AL1 Out of range 1F-01-1 F-01APB1-1F-01A(wp04) Out of range 1F-01-1 F-01APB1-1 F-01APB1 Out of range 1F-06-1F-06-1F-06 11,316.25 9,400.00 620.57 319.93 308.21 Pass-Major Risk 1 F-13-1 F-13-1 F-13 Out of range 1F-19-1F-19-1F-19 9,074.98 9,075.00 0.54 5.57 -2.30 FAIL-Major Risk 1F-19-1F-19L1-01-1F-19L1-01_wp03 9,500.00 9,500.00 0.00 0.36 -0.22 FAIL-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 2 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • /dill Travelling Cylinder Report BAKER� HES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project: Kuparuk River Unit TVD Reference: 1F-19 @ 118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 @ 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error. 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1F-19L1 Database: OAKEDMP2 Reference Design: 1 F-19L1 wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1E Pad- 1E-15-1E-15A-1E-15A Offset Site Error: 0.00 usft Survey Program: 200-FINDER-MS,7632-MID Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +EW-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (l (usft) (usft) (usft) (usft) (usft) (usft) 9,286.82 6,385.99 8,750.00 6,386.64 80.59 27.59 87.36 2,920.39 6,126.89 2.687 1,337.40 211.42 1,125.87 Pass-Major Risk 9,300.00 6,367.09 8,775.00 6,387.96 80.63 27.76 86.59 2,938.55 6,109.78 2.687 1,321.74 210.26 1,111.40 Pass-Major Risk 9,300.00 8,367.09 8,800.00 6,390.15 80.63 27.94 86.63 2,958.07 6,094.32 2.687 1,308.07 211.05 1,096.94 Pass-Major Risk 9300.00 6,367,09 8,825.00 6,392.95 80.63 28.11 86.69 2,978.79 6,080.64 2.687 1,296.65 211.87 1,084.71 Pass-Major Risk 9,323.95 6,388.87 8,850.00 6,396.62 80.71 28.27 85.39 3,000.40 6,068.62 2.687 1,286.86 209.23 1077.65 Pass-Major Risk 9,333.59 6,369.50 8,875.00 6,401.01 80.74 28.42 84.96 3,022.59 6,057.98 2.687 1,278.98 208.66 1,070.39 Pass-Major Risk 9,350.00 6,370.46 8,900.00 6,403.62 80.79 28.58 84.05 3,045.43 6,048.23 2.687 1,272.32 207.10 1,065.36 Pass-Major Risk 9350.00 8,370.46 8,925.00 6,404.88 80.79 28.73 84.05 3,068.73 6,039.26 2.687 1,266.62 207.95 1,058.82 Pass-Major Risk 9,350.00 6,370.46 8,950.00 6,405.20 80.79 28.89 84.01 3,091.62 6,029.23 2.687 1,260.26 208.81 1,051.60 Pass-Major Risk 9,373.27 6,371.58 8,975.00 6,404.96 80.85 29.07 82.57 3,113.66 6,017.45 2.687 1,251.94 206.26 1,045.94 Pass-Major Risk 9,382.88 6,371.97 9,000.00 6,404.23 80.88 29.27 81.93 3,134.82 8,004.17 2.687 1,242.41 205.72 1,037.00 Pass-Major Risk 9,400.00 6,372.53 9,025.00 6,403.83 80.93 29.48 80.84 3,154.91 5,989.30 2.687 1,231.45 204.07 1,027.77 Pass-Major Risk 9,400.00 6,372.53 9,050.00 6,402.72 80.93 29.71 80.78 3,173.87 5,973.06 2.687 1,219.01 204.93 1,014.46 Pass-Major Risk 9,400.00 6,372.53 9,075.00 6,401.23 80.93 29.94 80.70 3,191.43 5,955.34 2.687 1,205.21 205.78 999.80 Pass-Major Risk 9,418.64 6,372.96 9,100.00 6,399.10 80.97 30.19 79.46 3,207.69 5,936.47 2.687 1,190.01 203.97 986.57 Pass-Major Risk 9,426.84 6,373.10 9,125.00 8,396.42 80.99 30.45 78.83 3,222.81 5,916.75 2.687 1,173.99 203.78 970.96 Pass-Major Risk 9,445.49 6,373.27 9,150.00 6,393.49 81.03 30.70 77.52 3,237.70 5,896.89 2.687 1,158.07 202.36 956.98 Pass-Major Risk 9,445.49 6,373.27 9,175.00 6,390.16 81.03 30.96 77.37 3,254.08 5,878.30 2.687 1,143.70 203.18 941.75 Pass-Major Risk 9,450.00 6,373.29 9,200.00 8,386.19 81.04 31.21 76.87 3,271.64 5,860.96 2.687 1,131.15 203.36 929.02 Pass-Major Risk 9,450.00 6,373.29 9,225.00 6,382.15 81.04 31.46 76.87 3,290.34 5,844.88 2.687 1,120.50 20423 917.44 Pass-Major Risk 9,472.01 6,373.39 9,250.00 6,377.87 81.08 31.70 74.92 3,310.10 5,830.19 2.687 1,111.43 201.93 910.97 Pass-Major Risk 9,482.04 6,373.45 9,275.00 6,373.30 81.10 31.93 73.98 3,330.87 5,817.06 2.687 1,104.60 201.40 904.75 Pass-Major Risk 9,500.00 6,373.54 9,300.00 6,368.76 81.14 32.16 72.49 3,352.62 5,805.61 2.687 1,100.03 199.79 902.02 Pass-Major Risk 9,500.00 6,373.54 9,325.00 6,384,60 81.14 32.38 72.27 3,375.27 5,795.89 2.687 1,097.60 200.68 898.63 Pass-Major Risk,CC 9,500.00 6,373.54 9,350.00 6,360.80 81.14 32.59 72.06 3,398.66 5,787.96 2.687 1,097.66 201.54 897.75 Pass-Major Risk,ES,SF 9,523.80 6,373.68 9,375.00 6,356.77 81.17 32.78 70.19 3,422.84 5,782.17 2.687 1,099.90 199.18 902.69 Pass-Major Risk 9,534.18 6,373.74 9,400.00 6,353.52 81.19 32.96 6929 3,447.08 5,778.12 2.687 1,104.44 198.64 907.90 Pass-Major Risk 9,550.00 6,373,85 9,425.00 6,351.19 81.21 33.12 68.07 3,471.86 5,775.77 2.687 1,111.04 197.43 915.94 Pass-Major Risk 9,550.00 6,373.85 9,450.00 6,349.53 81.21 33.27 67.98 3,498.79 5,775.16 2.687 1,119.55 198.14 923.70 Pass-Major Risk 9,550.00 6,373.85 9,475.00 6,349.07 81.21 33.42 67.95 3,521.77 5,775.85 2.687 1,129.76 198.83 933.21 Pass-Major Risk 9,57328 6,374.00 9,500.00 6,350.09 81.24 33.56 66.38 3,546.88 5,777.61 2.687 1,140.79 196.79 946.74 Pass-Major Risk 9,582.22 6,374.07 9,525.00 8,351.72 81.24 33.68 65.84 3,571.42 5,780.78 2.687 1,153.47 198.41 960.01 Pass-Major Risk 9,600.00 8,374.20 9,550.00 6,352.98 81.26 33.79 64.67 3,595.93 5,785.52 2.887 1,167.85 195.19 975.98 Pass-Major Risk 9,600.00 6,374.20 9,575.00 6,354.19 81.26 33.89 64.72 3,620.24 5,791.20 2.687 1,183.02 195.68 990.69 Pass-Major Risk 9,600.00 6,37420 9,600.00 6,355.61 81.26 33.98 64.79 3,644.09 5,798.55 2.687 1,199.82 196.13 1,007.07 Pass-Major Risk 9,600.00 6,374.20 9,625.00 6,357.33 81.26 34.05 64.87 3,667.28 5,807.72 2.687 1,218.23 196.52 1,025.12 Pass-Major Risk 9,619.70 6,374.35 9,650.00 6,359.13 81.28 34.12 63.58 3,690.19 5,817.54 2.687 1,236.94 195.40 1,045.61 Pass-Major Risk 9,626.41 6,374.41 9,675.00 6,360.51 81.28 34.20 63.17 3,713.53 5,826.40 2.687 1,25528 195.36 1,064.24 Pass-Major Risk 9,833.60 6,374.47 9,700.00 6,361.01 81.28 34.29 62.69 3,737.55 5033.27 2.687 1,272.31 195.37 1,081.49 Pass-Major Risk 9,650.00 6,374.60 9,725.00 6,361.03 81.29 34.41 61.55 3,762.06 5,838.17 2.687 1,288.06 195.08 1,098.02 Pass-Major Risk 9,650.00 6,374.60 9,750.00 6,361.21 81.29 34.55 81.55 3,786.86 5,841.30 2.687 1,302.41 195.57 1,111.85 Pass-Major Risk 9,650.00 6,374.60 9,775.00 6,361.49 81.29 34.72 61.55 3,811.72 5,843.85 2.687 1,316.61 196.14 1,125.48 Pass-Major Risk 9,664.85 6,374.73 9,800.00 6,361.77 81.30 34.90 60.53 3,836.59 5,846.41 2.687 1,330.92 196.21 1,140.07 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 3 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • Ifd'1111 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project Kuparuk River Unit TVD Reference: 1F-19 6 118,00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 6 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error 0.00usft Output errors are at 1.00 sigma Reference Weiibore 1F-19L1 Database: OAKEDMP2 Reference Design: 1 F-19L1 wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1F Pad- 1F-06-1F-06-1F-06 Offset site Error: 0.06 usft Survey Program: 200-FINDER-MS Rule Assigned:Major Risk Onset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toofface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NILS +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) r) (usft) (usft) (usftl (usft) (usft) lusft) 10,800.00 6,376.68 8325.00 5,761.51 84.71 40.27 -74.27 4,015.81 3,253.76 2.687 1,338.68 239.28 1,127.00 Pass-Major Risk 10,800.00 8,376.68 8,350.00 5,775.33 84.71 40,43 -74.50 4,033.33 3,265.05 2.687 1,319.50 239.57 1,107.24 Pass-Major Risk 10,800.00 6,376.68 8,375.00 5,789.08 84.71 40.59 -74.73 4,050.87 3,276.36 2.887 1,300.53 239.86 1,087.68 Pass-Major Risk 10,800.00 6,376.68 8,400.00 5,802.77 84.71 40.75 -74.97 4,068.45 3,287.70 2.687 1,281.78 240.15 1,068.32 Pass-Major Risk 10,820.72 6,377.08 8,425.00 5,816.44 84.80 40.91 -73.83 4,086.04 3,299.05 2.687 1,262.83 247.09 1,043.20 Pass-Major Risk 10,827.70 6,377.19 8,450.00 5,830,09 84.82 41.07 -73.63 4,103.62 3,310.42 2.687 1,244.18 249.62 1,022.04 Pass-Major Risk 10,834.77 6,377.29 8,475.00 5,843.74 84.85 41.24 -73.42 4,121.20 3,321.81 2.687 1,225.66 252.18 1,000.97 Pass-Major Risk 10,850.00 6,377.48 8,500.00 5,857.39 84.92 41.40 -72.67 4,138.77 3,333.21 2.687 1,207.33 257.32 977.89 Pass-MajOr Risk 10,850.00 6,377.48 8,525.00 5,871.05 84.92 41.56 -72.98 4,156.33 3,344.62 2.687 1,189.01 257.63 958.84 Pass-Major Risk 10,850.00 6,377.48 8,550.00 5,884.74 84.92 41.72 -73.29 4,173.86 3,356.05 2.687 1,170.93 257.94 940.02 Pass-Major Risk 10,864.92 6,377.59 8,575.00 5,898.45 84.99 41.88 -72.65 4,191.36 3,367.48 2.887 1,152.89 262.78 917.69 Pass-Major Risk 10,872.93 6,377.61 8,600.00 5,912.19 85.02 42.04 -72.47 4,208.83 3,378.92 2.687 1,135.02 285.51 897.14 Pass-Major Risk 10,881.02 6,377.61 8,625.00 5,925.93 85.06 42.21 -72.31 4,226.29 3,390.38 2.687 1,117.30 268.26 876.67 Pass-Major Risk 10,900.00 6,377.49 8,650.00 5,939.85 85.15 42.37 -71.43 4,243.75 3,401.87 2.687 1,099.84 274.28 853.89 Pass-Major Risk 10,900.00 8,377.49 8,675.00 5,953.34 85.15 42.53 -71.83 4,261.21 3,413.39 2.687 1,082.32 274.61 835.45 Pass-Major Risk 10,900.00 6,377.49 8,700.00 5,967.01 85.15 42.69 -72.25 4,278.67 3,424.93 2.687 1,065.08 274.93 817.27 Pass-Major Risk 10,914.12 6,377.30 8,725.00 5,980.64 85.23 42.85 -71.74 4,296.16 3,436.49 2.687 1,047.98 279.52 795.88 Pass-Major Risk 10,922.61 6,377.15 8,750.00 5,99422 8528 43.02 -71.62 4,313.88 3,448.03 2.687 1,031.11 282.39 775.98 Pass-Major Risk 10,931.20 6,376.96 8,775.00 8,007.77 85.32 43.18 -71.52 4,331.25 3,459.57 2.687 1,014.47 285.29 756.27 Pass-Major Risk 10,950.00 6,376.45 8,800.00 6,021.27 85.43 43.34 -70.73 4,348.85 3,471.10 2.687 998.15 291.17 734.46 Pass-Major Risk 11,100.00 6,369.42 8,825.00 6,034.74 86.17 43.51 -82.08 4,368.48 3,482.61 2.687 980.19 255.19 753.41 Pass-Major Risk 11,118.31 6,388.28 8,850.00 6,048.22 86.26 43.67 -81.23 4,384.13 3,494.10 2.687 961.48 261.34 728.00 Pass-Major Risk 11,12521 6,387.85 8,875.00 6,061.69 86.29 43.83 -8125 4,401.79 3,505.57 2.687 943.14 263.83 706.43 Pass-Major Risk 11,132.24 8,387.40 8,900.00 6,075.16 86.32 44.00 -81.29 4,419.47 3,517.01 2.687 925.01 266.37 685.01 Pass-Major Risk 11,150.00 6,366.28 8,925.00 6,088.58 86.40 44.16 -80.54 4,437.18 3,528.46 2.687 907.23 272.28 660.63 Pass-Major Risk 11,150.00 6,366.28 8,950.00 6,101.92 86.40 44.33 -81.15 4,454.94 3,539.95 2.687 889.42 272.60 641.61 Pass-Major Risk 11,150.00 6,36628 8,975.00 6,115.16 86.40 44.49 -81.77 4,472.74 3,551.47 2.687 871.94 272.91 622.92 Pass-Major Risk 11,150.00 6,386.28 9,000.00 6,128.31 86.40 44.68 -82.41 4,490.59 3,563.02 2.687 854.82 273.23 604.57 Pass-Major Risk 11,169.50 6,365.05 9,025.00 6,141.41 86.50 44.82 -81.63 4,508.45 3,574.62 2.687 837.63 279.84 560.16 Pass-Major Risk 11,177.35 6,364.55 9,050.00 6,154.48 86.54 44.99 -81.74 4,526.30 3,586.25 2.687 820.82 282.41 559.68 Pass-Major Risk 11,185.33 6,364.04 9,075.00 6,167.53 86.58 45.15 -81.87 4,544.14 3,597.93 2.687 804.26 28520 539.38 Pass-Major Risk 11,200.00 6,363.10 9,100.00 6,180.56 86.66 45.32 -81.53 4,561.97 3,609.85 2.687 788.00 290.03 517.35 Pass-Major Risk 11,200.00 6,363.10 9,125.00 6,193.57 86.66 45.49 -82.32 4,579.81 3,621.38 2.687 771.92 290.36 499.91 Pass-Major Risk 11,200.00 6,363.10 9,150.00 6,206.57 86.66 45.65 -83.15 4,597.67 3,633.09 2.687 756.35 290.69 482.97 Pass-Major Risk 11,218.63 6,361.91 9,175.00 6,219.55 86.76 45.82 -82.62 4,615.55 3,644.79 2.687 740.87 296.70 460.51 Pass-Major Risk 11,227.33 6,361.35 9,200.00 6,232.52 86.81 45.99 -82.87 4,633.45 3,656.46 2.687 725.89 299.66 441.53 Pass-Major Risk 11,236.18 6,360.78 9,225.00 8,245.48 86.87 46.15 -83.15 4,651.36 3,668.13 2.687 711.27 302.65 422.88 Pass-Major Risk 11,250.00 8,359.90 9,250.00 6,258.44 86.95 46.32 -83.10 4,66927 3,679.80 2.687 697.06 307.09 40321 Pass-Major Risk 11,250.00 6,359.90 9,275.00 6,271.41 86.95 46.49 -84.12 4,687.18 3,691.47 2.887 683.21 307.44 387.96 Pass-Major Risk 11,263.61 6,359.02 9,300.00 6,284.37 87.03 46.66 -84.18 4,705.10 3,703.13 2.687 669.76 311.79 369.18 Pass-Major Risk 11,273.04 6,358.41 9,325.00 6,297.33 87.10 46.83 -84.58 4,723.01 3,714.80 2.687 656.77 314.89 352.13 Pass-Major Risk 11,282.62 6,357.79 9,350.00 6,310.29 87.16 46.99 -85.03 4,740.92 3,726.47 2.687 644.23 318.00 335.56 Pass-Major Risk 11,300.00 6,356.67 9,375.00 6,323.25 87.27 47.16 -84.93 4,758.83 3,738.14 2.687 632.25 323.29 317.46 Pass-Major Risk 11,316.25 6,355.82 9,400.00 6,336.22 87.38 47.33 -87.40 4,776.75 3,749.80 2.687 620.57 319.93 308.21 Pass-Major Risk,ES,SF 11,383.51 6,351.28 9,425.00 6,349.18 87.81 47.50 -93.72 4,794.66 3,761.47 2.687 608.32 304.03 310.54 Pass-Major Risk 11,443.15 6,347.46 9,450.00 6,362.14 88.15 47.67 -99.52 4,812.57 3,773.14 2.887 595.13 289.02 311.05 Pass-Major Risk 11,495.85 6,344.13 9,475.00 6,375.10 88.42 47.83 -104.87 4,830.48 3,784.81 2.687 581.24 275.20 309.68 Pass-Major Risk,CC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 4 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ S Fail ConocoPhillips Travelling Cylinder Report BAKER NIUGIMS Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project: Kuparuk River Unit TVD Reference: 1F-19 @ 118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 CO 118.00usft(1F-19) Site Error. 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error. 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1F-19L1 Database: OAKEDMP2 Reference Design: 1 F-19L1 wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1F Pad- 1F-19-1F-19-1F-19 Offset Site Error: 0.06 usft Survey Program: 46644WD Rule Assigned:Major Risk Offset Well Error: 0.00 ush Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W.S +FAW Hole Size Centre Distance Deviation (oan) lush) (usft) haft) lusft) (usft) 1°l (uaft) (usR) (weft) (oft) (uso) luso) 9,025.00 6250.59 9,025.00 6,250.59 0.01 0.01 -1.97 2,653.65 4,670.66 2.687 0.00 2.70 -0.31 FAIL-Major Risk,CC 9,050.00 6,289.72 9,050.00 6,289.72 0.25 0.23 -0.25 2,660.41 4,685.27 2.687 0.00 4.14 -1.63 FAIL-Major Risk 9,074.98 6288.55 9,075.00 6,288.88 0.48 0.45 -141.01 2,667.25 4,699.80 2.687 0.54 5.57 -2.30 FAIL-Major Risk,ES,SF 9,099.44 8,305.33 9,100.00 8,308.08 0.73 0.67 -145.29 2,674.17 4,714.24 2.887 3.83 7.03 0.01 Pass-Major Risk 9,122.31 6,318.53 9,125.00 8,327.31 0.99 0.89 -147.99 2,681.18 4,728.60 2.887 10.96 8.42 6.37 Pass-Major Risk 9,142.83 6,328.07 9,150.00 6,346.57 1.23 1.11 -150.09 2,688.26 4,742.87 2.687 21.45 9.74 16.28 Pass-Major Risk 9,162.26 6,335.58 9,175.00 6,365.86 1.46 1.33 -156.18 2,695.43 4,757.06 2.687 34.29 10.83 28.40 Pass-Major Risk 9,180.00 6,341.95 9,200.00 6,385.19 1.66 1.55 -163.80 2,702.68 4,771.17 2.887 48.58 11.66 41.89 Pass-Major Risk 9,195.66 6,347.11 9,225.00 6,404.54 1.83 1.77 -171.03 2,709.98 4,785.21 2.687 6429 12.24 56.88 Pass-Major Risk 9,210.00 6,351.40 9,250.00 6,423.92 1.97 1.98 -177.75 2,717.17 4,799.28 2.687 81.36 12.63 73.38 Pass-Major Risk 9,220.00 6,354.13 9,275.00 6,443.31 2.07 2.20 176.99 2,724.23 4,813.38 2.687 99.86 12.91 91.22 Pass-Major Risk 9,230.00 6,356.63 9,300.00 6,462.73 2.16 2.42 172.07 2,731.16 4,827.53 2.887 119.00 13.09 110.22 Pass-Major Risk 9,240.00 6,358.89 9,325.00 8,482.16 2.25 2.63 187.42 2,737.94 4,841.72 2.887 139.20 13.16 130.21 Pass-Major Risk 9,247.37 6,360.40 9,350.00 6,501.60 2.31 2.85 163.76 2,744.60 4,855.96 2.687 160.14 13.22 150.99 Pass-Major Risk 9,253.84 6,361.60 9,375.00 6,521.06 2.36 3.06 160.57 2,751.15 4,870.22 2.687 181.68 13.25 172.41 Pass-Major Risk 9,260.00 6,362.65 9,400.00 6,540.52 2.41 3.28 157.64 2,757.69 4,884.49 2.687 203.66 13.22 194.35 Pass-Major Risk 9,264.48 6,363.34 9,425.00 6,559.98 2.45 3.49 155.35 2,764.24 4,898.76 2.687 226.01 13.23 216.85 Pass-Major Risk 9,270.00 6,364.12 9,450.00 6,579.44 2.49 3.71 152.86 2,770.78 4,913.02 2.687 248.67 13.18 239.38 Pass-Major Risk 9,270.00 6,364.12 9,457.00 6,584.88 2.49 3.77 152.64 2,772.61 4,917.02 2.687 255.06 13.25 245.71 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 5 of 8 COMPASS 5000.1 Build 65 • . Baker Hughes INTEQ • 1Pr® ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Wet 1F-19 Project: Kuparuk River Unit TVD Reference: 1F-19 @ 118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 @ 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Welt Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1F-19L1 Database: OAKEDMP2 Reference Design: 1F-19L1 wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1F Pad- 1F-19-1F-19L1-01-1 F-19L1-01_wp03 Offset Site error: 0.00 use Survey Program: 486-MW),9023-MWD,9500-MWD Rule Assigned:Minor 1/10 Offset Weft Error: 0.00 usf Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +py.S +F!-W Hole Size Centre Distance Deviation (uO) (ust) lust) (use) Piet) (usE) 1°1 (wt) (use) (ust) Wst) (use) (ust) 9,500.00 8,373.54 9,500,00 6,373.54 0.00 0.00 -17.91 3,031.63 4,753.48 2.687 0.00 0.36 -0.22 FAIL-Minor 1/10,CC,ES,SF 9,524.99 6,373.69 9,525.00 6,373.30 0.20 0.24 24.85 3,055.42 4,745.79 2.687 0.54 0.84 -0.10 FAIL-Minor 1/10 9,549.91 6,373.84 9,550.00 6,372.29 0.39 0.48 23.08 3,079.19 4,738.11 2.687 2.18 1.13 1.27 Pass-Minor 1/10 9,574,68 6,374.01 9,575.00 6,370.52 0.58 0.71 21.29 3,102.92 4,730.45 2.687 4.89 1.30 3.79 Pass-Minor 1/10 9,599.25 6,374.19 9,600.00 6,367.99 0.77 0.95 19.49 3,126.58 4,722.80 2.687 8.67 1.38 7.45 Pass-Minor 1/10 9,623.54 8,374.38 9,825.00 6,384.71 0.95 1.19 17.68 3,150.17 4,715.18 2.687 13.51 1.39 12.22 Pass-Minor 1/10 9,647.50 8,374.58 9,650.00 6,360.68 1.12 1.43 15.88 3,173.64 4,707.60 2.687 19.39 1.40 18.08 Pass-Minor 1/10 9,871.07 6,374.79 9,675.00 6,355.87 1.29 1.67 14.07 3,196.99 4,700.05 2.687 26.28 1.40 24.99 Pass-Minor 1/10 9,694.38 6,375.00 9,700.00 6,351.02 1.45 1.90 12.90 3,220.26 4,692.33 2.687 33.57 1.42 32.35 Pass-Minor 1/10 9,717.99 8,375.10 9,725.00 6,346.83 1.62 2.14 12.76 3,243.53 4,684.21 2.687 40.53 1.44 39.49 Pass-Minor 1/10 9,741.59 6,374.90 9,750.00 6,343.29 1.78 2.37 13.29 3,266.77 4,675.69 2.687 47.07 1.44 46.50 Pass-Minor 1/10 9,765.13 6,374.42 9,775.00 6,340.40 1.94 2.60 14.28 3,289.95 4,666.79 2.687 53.26 1.45 53.03 Pass-Minor l/10 9,788.53 8,373.86 9,800.00 6,338.18 2.09 2.84 15.63 3,313.05 4,657.51 2.687 59.17 1.44 58.94 Pass-Minor 1/10 9,814.22 8,372.65 9,825.00 6,336.61 2.25 3.08 20.08 3,336.06 4,647.85 2.887 64.45 1.42 64.22 Pass-Minor 1/10 9,840,53 6,371.62 9,850.00 6,335.70 2.42 3.31 24.33 3,358.95 4,637.84 2.687 68.54 1.40 68.32 Pass-Minor 1/10 9,867.22 6,370.57 9,875.00 6,335.25 2.60 3.55 28.14 3,381.64 4,627.35 2.687 71.39 1.38 71.17 Pass-Minor 1/10 9,894.21 6,369.52 9,900.00 6,334.82 2.78 3.79 31.28 3,404.00 4,616.19 2.687 72.92 1.30 72.69 Pass-Minor 1/10 9,921.32 6,368.46 9,925.00 6,334.41 2.97 4.03 33.81 3,426.01 4,804.35 2.687 73.06 1.20 72.84 Pass-Minor 1/10 9,948.40 6,387.41 9,950.00 6,334.00 3.17 4.26 35.76 3,447.65 4,591.84 2.687 71,80 1.05 71.57 Pass-Minor 1/10 9,975.37 8,366.38 9,975.00 6,333,62 3.37 4.50 37.39 3,469.29 4,579.33 2.887 69.80 0.81 69.57 Pass-Minor 1/10 10,002.27 6,365.35 10,000.00 6,333.27 3.58 4.73 38.99 3,491.30 4,567.48 2.687 67.74 0.47 67.52 Pass-Minor 1/10 10,029.02 6,384.35 10,025.00 6,332.94 3.80 4.96 40.54 3,513.87 4,558.32 2.687 65.83 0.46 65.40 Pass-Mirror 1/10 10,055.58 6,363.46 10,050.00 6,332.64 4.02 5.19 41.95 3,536.36 4,545.84 2.687 63.52 0.45 63.29 Pass-Minor 1/10 10,082.07 6,362.71 10,075.00 6,332,37 4.25 5.44 43.21 3,559.37 4,536.06 2.687 81.43 0.44 61.21 Pass-Minor l/10 10,108.48 6,362.09 10,100.00 6,332.12 4.48 5.68 44.32 3,582.68 4,526.98 2.687 59.37 0.43 59.15 Pass-Minor 1/10 10,134.93 6,361.59 10,125.00 6,331.90 4.72 5.93 45.29 3,606.22 4,518.62 2.687 57.34 0.42 57.11 Pass-Minor 1/10 10,161.37 8,361.10 10,150.00 6,331.70 4.97 6.18 46.19 3,630.02 4,510.99 2.687 55.27 0.41 55.04 Pass-Minor 1/10 10,187.73 6,360.62 10,175.00 6,331.52 5.22 6.43 47.00 3,654.05 4,504.08 2.687 53.18 0.40 52.95 Pass-Minor 1/10 10,214.01 6,360.14 10,200.00 6,331.34 5.47 6.89 47.69 3,678.27 4,497.91 2.687 51.07 0.38 50.85 Pass-Minor 1/10 10,240.20 6,359.66 10,225.00 6,331.16 5.73 6.95 48.25 3,702.68 4,492.48 2.687 48.96 0.38 48.73 Pass-Minor 1/10 10,288.31 6,359.18 10,250.00 6,330.98 5.99 7.21 48.66 3,727.23 4,487.81 2.687 48.85 0.38 46.62 Pass-Minor 1/10 10,292.34 6,358.71 10,275.00 8,330.80 6.26 7.47 48.90 3,751.92 4,483.88 2.687 44.74 0.36 44.52 Pass-Minor 1/10 10,317.71 6,358,38 10,300.00 6,330,62 6.52 7.74 48.52 3,776.72 4,480.71 2.687 42.78 0.35 42.55 Pass-Minor 1/10 10,342.79 6,358.52 10,325.00 6,330.53 6.79 8.01 47.56 3,801.60 4,478.28 2.687 41.23 0.35 41.00 Pass-Minor 1/10 10,387.82 6,359.16 10,350.00 6,330.62 7.05 8.28 48.24 3,826.54 4,476.60 2.687 40.08 0.35 39.85 Pass-Minor 1/10 10,393.51 6,360.11 10,375.00 6,330.90 7.33 8.55 45.14 3,851.52 4,475.65 2.687 39.14 0.35 38.91 Pass-Minor 1/10 10,419.21 8,361.06 10,400.00 6,331.37 7.61 8.82 44.06 3,878.51 4,475.45 2.687 38.13 0.35 37.90 Pass-Minor 1/10 10,444.57 6,361.99 10,425.00 8,332.02 7.89 9.09 42.35 3,901.50 4,475.99 2.687 37.06 0.35 36.84 Pass-Minor 1/10 10,488.84 6,362.93 10,450.00 8,332.85 8.16 9.36 39.16 3,926.45 4,477.26 2.687 36.51 0.35 36.29 Pass-Minor 1/10 10,493.14 6,363.93 10,475.00 6,333.87 8.43 9.64 37.97 3,951.35 4,479.28 2.687 36.71 0.35 36.49 Pass-Minor 1/10 10,517.35 6,384.99 10,500.00 6,335.08 8.70 9.91 38.72 3,976.18 4,482.03 2.687 37.70 0.35 37.47 Pass-Minor 1/10 10,541.44 6,366.10 10,525.00 8,336.31 8.97 10.18 40.14 4,000.98 4,484.77 2.687 39.23 0.35 39.01 Pass-Minor 1/10 10,565.45 6,367.26 10,550.00 6,337.41 9.23 10.46 41.13 4,025.88 4,486.77 2.687 41.00 0.35 40.78 Pass-Minor 1/10 10,589.40 8,368.48 10,575.00 6,338.37 9.49 10.74 41.70 4,050.83 4,488.02 2.687 42.97 0.35 42.75 Pass-Minor 1/10 10,813.40 6,369.72 10,600.00 6,339.20 9.75 11.02 41.92 4,075.81 4,488.52 2.687 45.08 0.36 44.86 Pass-Minor l/10 10,637.37 6,370.89 10,625.00 6,339.90 10.02 11.30 41.90 4,100.79 4,488.26 2.687 47.26 0.37 47.03 Pass-Minor 1/10 10,861.27 6,371.97 10,650.00 6,340.47 10.27 11.58 41.67 4,125.77 4,487.26 2.687 49.48 0.38 49.26 Pass-Minor 1/10 10,685.10 6,372.99 10,675.00 6,340.90 10.53 11.87 41.25 4,150.70 4,485.50 2.687 51.75 0.39 51.53 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 6 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • ®f:ll ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project: Kuparuk River Unit ND Reference: 1F-19©118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 I@ 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error. 0.0ousft Output errors are at 1.00 sigma Reference Wellbore 1F-19L1 Database: OAKEDMP2 Reference Design: 1 F-19L1_wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1F Pad- 1F-19-1F-19L1-01-1 F-19L1-01 wp03 onset Site Error: 0.00 use Survey Program: 466-MVS,9023-MVW,9500-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 use Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth .N/.S +EIyV Hole Sid Centre Distance Deviation lush) (usft) (usft) haft) (usft) (usft) () (usft) Watt) (usft) (use) (ush) (usft) 10,708.88 6,373.92 10,700.00 6,341.17 10.78 12.16 40.64 4,175.57 4,483.00 2.887 54.08 0.40 53.86 Pass-Minor 1/10 10,732.58 8,374.77 10,725.00 6,341.17 11.03 12.45 39.80 4200.36 4,479.79 2.687 56.54 0.40 56.31 Pass-Minor t/f0 10,757.00 6,375.57 10,750.00 6,340.91 11.29 12.74 39.61 4,225.05 4,475.87 2.687 59.06 0.41 58.84 Pass-Minor 1/10 10,783,69 8,376.30 10,775.00 8,340.39 11.56 13.03 41.17 4,249.61 4,471.25 2.687 60.78 0.42 60.55 Pass-Minor l/10 10,810.45 6,376.89 10,800.00 6,339.61 11.84 13.31 42.08 4,274.12 4,466.37 2.887 61.72 0.42 61.49 Pass-Minor 1110 10,837.21 6,377.33 10,825.00 6,338.57 12.11 13.59 42.87 4,298.74 4,462.17 2.687 62.68 0.42 62.43 Pass-Minor 1/10 10,884.05 6,377.59 10,850.00 6,337.26 12.39 13.86 43.56 4,323.46 4,458.68 2.687 63.61 0.42 63.39 Pass-Minor 1/10 10,890.99 6,377.56 10,875.00 6,335.70 12.68 14.14 44.23 4,348.26 4,455.91 2.687 64.54 0.42 64.32 Pass-Minor 1/10 10,917.93 6,377.23 10,900.00 6,334.02 12.97 14.42 44.77 4,373.07 4,453.38 2.687 65.00 0.42 64.77 Pass-Minor 1/10 10,944.79 6,376.61 10,925.00 6,332.53 13.26 14.71 44.74 4,397.82 4,450.16 2.687 64.09 0.41 63.86 Pass-Minor 1/10 10,969.11 6,375.82 10,950.00 6,331.24 13.53 14.99 41.45 4,422.47 4,448.20 2.687 62.23 0.40 62.00 Pass-Minor 1/10 10,992.94 6,374.92 10,975.00 6,330.15 13.80 15.28 37.49 4,447.00 4,441.51 2.687 60.20 0.39 59.97 Pass-Minor 1/10 11,016.90 8,373.89 11,000.00 6,329.25 14.07 15.56 33.90 4,471.49 4,436.56 2.687 58.31 0.38 58.08 Pass-Minor 1/10 11,041.02 6,372.74 11,025.00 8,328.55 14.34 15.84 31.49 4,496.11 4,432.30 2.687 57.12 0.38 56.89 Pass-Minor 1/10 11,065.17 6,371.47 11,050.00 6,328.05 14.62 16.13 30.41 4,520.85 4,428.78 2.667 56.61 0.37 56.39 Pass-Minor 1/10 11,089.22 6,370.08 11,075.00 6,327.74 14.89 16.41 30.67 4,545.69 4,425.98 2.687 56.84 0.38 56.61 Pass-Minorl/10 11,114.32 6,368.53 11,100.00 6,327.59 15.16 16.70 34.00 4,570.61 4,423.93 2.687 57.82 0.39 57.59 Pass-Minor tll0 11,140.47 6,366.89 11,125.00 6,327.47 15.45 16.99 39.01 4,595.57 4,422.63 2.687 59.00 0.40 58.77 Pass-Minor 1/10 11,166.71 6,365.23 11,150.00 6,327.40 15.74 17.27 43.92 4,620.57 4,422.10 2.687 60.29 0.41 60.06 Pass-Minor 1/10 11,193.07 6,363.55 11,175.00 6,327.36 16.03 17.56 48.71 4,645.56 4,422.33 2.687 61.67 0.42 61.45 Pass-Minor 1/10 11,219.52 6,361.85 11,200.00 6,327.37 16.32 17.85 53.40 4,670.54 4,423.32 2.687 63.14 0.43 62.92 Pass-Minor 1/10 11,246.07 6,380.15 11,225.00 6,327.41 16.62 18.13 57.97 4,695.48 4,425.08 2.687 64.69 0.45 64.46 Pass-Minor 1/10 11,272.77 6,358.43 11,250.00 6,327.50 16.93 18.42 6224 4,720.40 4,427.10 2.687 65.87 0.45 65.64 Pass-Minor 1/10 11,299.62 6,356.69 11,275.00 6,327.60 17.23 18.71 65.88 4,745.36 4,428.40 2.887 65.75 0.46 65.52 Pass-Minor 1/10 11,322.94 6,355.19 11,300.00 8,327.74 17.50 19.00 65.54 4,770.36 4,428.93 2.687 64.91 0.48 64.68 Pass-Minor 1/10 11,346.20 6,353.68 11,325.00 6,327.90 17.77 19.29 65.19 4,795.35 4,428.70 2.687 64.05 0.46 63.82 Pass-Minor 1/10 11,369.47 6,352.18 11,350.00 6,328.09 18,05 19.58 64.88 4,820.33 4,427.71 2.887 63.16 0.46 62.94 Pass-Minor 1/10 11,392.75 8,350.89 11,375.00 6,328.30 18.32 19.87 64.60 4,845.27 4,425.96 2.687 62.28 0.48 62.04 Pass-Minor 1/10 11,416.02 6,349.19 11,400.00 6,328.54 18.59 20.17 64,37 4,870.14 4,423.44 2.687 61.34 0.46 61.12 Pass-Minor 1/10 11,439.31 6,347.71 11,425.00 6,328,81 18.86 20.46 64.19 4,894.92 4,420.17 2.687 60.41 0.45 60.19 Pass-Minor 1/t0 11,462.60 6,346.23 11,450.00 6,329.11 19.13 20.76 64.05 4,919.59 4,416.15 2.887 59.47 0.45 59.24 Pass-Minor 1/10 11,485.90 6,344.76 11,475.00 6,329.43 19.40 21.06 63.97 4,944.13 4,411.37 2.687 58.52 0.45 58.29 Pass-Minor l/t0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 7 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • Frail ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1F-19 Project: Kuparuk River Unit TVD Reference: 1F-19 @ 118.00usft(1F-19) Reference Site: Kuparuk 1F Pad MD Reference: 1F-19 @ 118.00usft(1F-19) Site Error: 0.00usft North Reference: True Reference Well: 1F-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1F-191.1 Database: OAKEDMP2 Reference Design: 1 F-19L1_wp06 Offset TVD Reference: Offset Datum Reference Depths are relative to 1F-19 @ 118.00usft(1F-19) Coordinates are relative to:1F-19 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:0.30° Ladder Plot I 1400 I I I i I I t I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I I I 10E0- 1-13 E0 t I t t I I I I I I 1-13 I 1 t t 1 n V, 700— I I I I I I U I I I t i I I I I I i 0 C I I 1 i U I I I I t 30 I I I I I I i 1 I I t I I I 1 I I I I 1 i I I I I I I 1 I I I I I I 1 ' 0 2000 4000 6000 8000 10000 12000 Meastfed Depth LEGEND $ 1 E-15,1 E-15A,1 E-15A V0 - 1F-19,1F-19,1F-19V1 9( 1F-06,1F-06,1F-06 V1 -11k- 1F19,1F19L1-01,1F-19L1-01 ipO3V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/21/2015 3:41:32PM Page 8 of 8 COMPASS 5000.1 Build 65 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Friday, May 22, 2015 10:27 AM To: 'cody j.pohler@cop.com' Subject KRU 1F-19L1(PTD 215-085)Traveling Cylinder Report Cody, Please provide Traveling Cylinder Report. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp0,alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@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. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: /«tom. /F -1q1-.1 PTD: og/c'O$S /Development _Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: Aipc.f'b./( Rri JET( POOL: !I / ,�✓ ,t)/� �i 1 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. /56 - os-2„ API No. 50-0.23 (e(,o - - 00. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 0 0 To ' co o) o a) a � 0) N N rn' o U N. O �� � 3' ' o� C � 0, � a0, N'0 0 , '2 vi. `o. 3. �; 1 > .0 ' ' O' 0' ' ' ' a , , � � N. , • U - o' a' a' E O d �, , 0) 0.. rn 3 a 3 Y� �, mi mi . c' v. -o a) a) N co, . v rn m , , o. ca , O �' 3 v a. 0, J �� �� �� �, ';.• , 0 � � Y, a). E. x- �, 3. o' Tc a a a) 3 co ' a) d. �� a � E� g o I- O. v 0 aa) 3 °0. 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