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Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. U .s - 0 L a Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Co r Items: ❑ Maps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: / BY: Maria Date: ta l 1±) /s/ 16(, f Project Proofing P BY: Maria Date: gii cc /s/ Ill)1 Scanning Preparation 3., x 30 = 12 0 + = TOTAL PAGES 4 L (Count does not include cover sheet) fI/JIBY: ariaDate: IUQ� / sI Production Scanning Stage 1 Page Count from Scanned File: CO 8- (Count does include cover heet) Page Count Matches Number in Scanning Preparation: ES NO BY: CP Date: bi I g I / /s! imp Stage I 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 o �, o I • o Ur N co - 0 0 e E EE 0 0 A 7 T m COCO CO CO• Z C NJJ JJEaaNN 'p a) c -, co co el 16 16 16 16 N - ',, �a c U) C C U) 3 3 c •8 coc ii iL U it it u) U) U) 6 � '' ° 0 0 co o o o 0 0 > 0 0 > F L- � 0 0 0 p N O W W Z Z E N u) U) N U) LO W W W Z O O D D co O O O O O O O O O Q > ,.- CoN (o CO6 J J - a. J J J J J J J J J C co co co it cococococococo co co ° 2 Y Y __ .-w J o O a O °) O O O O O O O a O O N HIM �• M d' 0 M co co co co co co •N co co V 0 0 O cII o)Q N a a. 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CO 15 I _N_01 _N N N _N C.) @ u) Ce 4 N W Z WO W O W W W W co a) O N m ` T W a '5 u) u) O LO O O O m wco CL cv J 0 O O O o o o o E y E 0 0 W •N N N N N N N ay 3 0 = 7 V N Z N aN N N N N N N N 0) O V V V 0. 0. 0. N U LL € W zo a) y V V P C 0 a) D. E - @ Z d vi °) Cr) Q 0 0) Cov) J d C J m -o E o.0 'o 2 o 0 / �cn a) li to C V, 20 0 = E co E a 1 1 H ... „ tn tip C ->_ E© I E IO r IN J M 0 I E pip 0 0P0 Oc E v I— 1- O _ v) o 2 • o ca c z` N 0 y f0 m > v — c a) E ch 5 o E w Y 0 m - cn • @ co U a) c Q a C 0 Q C— to Y a) C •u aI p m 0 Q Z o D E U 0 2 C) co z m m m m CO CO CO CO ,O O CO 0 0 0 0 0 0 0 cr, C CO CO CO CU Of CD CO N N LO CD TO w w w co Co w C VCO 0) m 0) m 0) 0) 0) 10 © >- © I M o 0 0 0 0 0 0 0 0 ' E o C 0 > O to OO O O O w W IP O } N.0 ~ r N. N r� r- N. 1 c WE a O NO O O O O O O I m W LO N N N N N N N N N a. a) rea c v2 2 N E E z a) 0 a) w m F. o N w O F m 0 0 o c OO Iii Z Q O Z C CO E C - U U U U U U U C .� 'V m J ., 0 •a C :."'g 0 0 pa o 0 0. af0i H E O 0 a 0 0 0 0 0 0 0 w o 2 a0) 0 0 a) 00 ¢ a 2 w w w w w w w z 0 a 0 0 0 CC 0 0 1 '^ o I o N CT, ,p M o O co Z N No U T o •••...iF N ° Z 9 J i O V Z 7 d 5 c o Ce < 112 O N a 3 Om J J U IXO. = 1 Lig V W z V v o Z Q V N m m J a. co O Om in c 0 • o a O N a E r en CB o U o el en Q t O O a. r M H t0 C z O N _ CO > v re M Y D a) d p Y a) Q z p m U E R z m 3 o > m • 1- v o m In 3 N I d F. _ ce 0 Ot.) o R U U E E o ID a 2 v (4ir- o zismti, 2ts-o! 3/ Fr 2-1 s-- 014 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration (Alaska) Inc. RECEIVE E��/ (mandatory) Petrotechnical Data Center, LR2-1 1l L/ Y WELL NAME 30-13L1-01,02,03,04 900 E. Benson Blvd. JUN 1 5 2015 (mandatory) Anchorage,Alaska 99508 FIELD Prudhoe Bay to acknowledge receipt of this data. AOGCC (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: March 31,2015 TODAYS DATE: 15-Jun-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: paula.lacey©bakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys PERSON ATTENTION #OF PRINTS #OF i'FtIN I S #OF COPIESn #OF PRINTS n n V V V V V V 1 BP North Slope EOA,PBOC,PRB-20(Office 109) Attn:D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 East Benson Boulevard Anchorage,AK,99519 2 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6'I BP Exploration(Alaska)Inc. I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 0 1 0 0 0 TOTALS FOR ALL PAGES: 0 0 1 0 0 0 i 21 5010 15717 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ �D E I V E D DATA L (mandatory) 795 East 94th Avenue 5 11512015 WELL NAME 30-13L1;-01;-02;-03;-04 Anchorage,Alaska 9951; K.BENDERAPR 2 4 2015 (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. AOGCC (mandatory) AOGCC COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: February 17,2015 TODAYS DATE: 22-Apr-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: (mandatory) paula.lacev(&bakerhuehes.com HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? 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 #Oh 1-KIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 1 1 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 IBP Exploration(Alaska)Inc. I I 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 !Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 1 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC I 1 1 2 1 IAttn:Makana Bender 333 W.7th Ave,Suite 100 (Anchorage,Alaska 99501 i 5(DNR-Division of Oil&Gas *** I 1 I I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR I I TOTALS FOR THIS PAGE: 0 4 5 5 5 0 TOTALS FOR ALL PAGES: 0 4 5 5 5 0 CD 0 O `" LL N N LIJ cq 0 ■ W CC Liu z dEo �CS= N Q I . U C RS t 0 RS 0 w e W w` .w I- n^' v' (i) Z •- •.... — •- = .. •- . CO 0. 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(2n V r CO CO O) 0) V CO CO (O I- 0 O CO u) u) 0 CO (O (O r O) 0) CO CO V CO O N 0 CO 0 M O 0 I, N OO O (O Q o 0 0 0 o ui ui ui ui 2 (d 0 ui (d o 0 0 0 0 0 N T N V I- O M (D O) N (O O V N- V I, o M N O C c .. m 0 w v_ u) (n (C) CD N N CD n N. n 0-o co co 0) 0) 0) o 0 0Lo Oco U £ N m - 0 W rL O co 0 00co co co co co co co co co coco co co CO N N N W O Q r N d N 7 0 0. y 'S 0 u) t STATE OF ALASKA APR 0 2 2015 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANYVOS la.Well Status: Oil ❑ • Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑• Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., "6 12.Permit to Drill Number: a ConocoPhillips Alaska, Inc. or Aband.: March,4'2015 215-010/ 3.Address: 6.Date Spudded: 13.API Number: P.0.Box 100360,Anchorage,AK 99510-0360 • February 18,2015 50-029-21803-61 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1041'FNL,2024'FWL,Sec.22,T13N, R9E,UM • February 19,2015 KRU 30-13L1-01 • Top of Productive Horizon: 8. KB(ft above MSL): 59'RKB 15.Field/Pool(s): 618'FSL,936'FWL,Sec.22,T13N, R9E,UM GL(ft above MSL): 24'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1084'FSL, 186'FEL,Sec.21,T13N, R9E, UM 10201'MD/6596'TVD Kuparuk Oil Pool . 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-525661 y- 6021779 Zone-4 .10201'MD/6596'TVD ADL 25513 • TPI: x-524593 y- 6018154 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-523469 y- 6018616 Zone-4 nipple @ 495'MD/495'TVD 2554 18.Directional Survey: Yes Q v No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1608'MD/1608'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res • 9502'MD/6630'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 110' 36' 110' _ 42" 175 sx AS I 9.625" 36# J-55 35' 4340' 35' 4046' 12.25" 1500 sx AS III,300 sx CI G,65 sx AS 7" 26# J-55 33' 7915' 33' 6872' 8.5" 395 sx Class G, 175 sx AS 2.375" 4.6# L-80 8963' 10201' 6629' 6596' 3" slotted liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 7594' 7438'MD/6478'TVD slotted liner from 8963'-10201'MD 6629'-6596'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. xr (arising Was hydraulic fracturing used during completion? Yes ii No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none All 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up ✓ Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(torr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ - Sidewall Cores Acquired? Yes ❑ No ❑✓ - If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 vri. CONTINUED ON REVERSE `i' 5))M Submit original only 57/ // 5- if IAA-- RBDMS�N APR 1 8 2015 G 29. GEOLOGIC MARKERS(List all formations and mai ncountered) 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1608' 1608' needed,and submit detailed test information per 20 AAC 25.071. Al DT/Al UT 9590' 6627' Al DT/Al UT 9988' 6630' Kuparuk Al 10100' 6614' Kuparuk A2 10201' 6596' N/A Formation at total depth: Kuparuk A2 ✓ 31 LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best P Contact: Cody Pohler @ 265-6435 Email Cody.J.Pohler@conocophillips.com C�)' 3/26/?O/s Printed Name 7aus Title: CTD Engineering Supervisor Signature Cf� - Phone 263-4372 Date —1 - Is INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP PROD 30-13L1-01 COnOCOPhiIIips Well Attributes Max Angle&MD TD Alaska,Inc. I Wellbore API/UWl Field Name Wellbore Status Incl(•) MD(ttKB) AM Bim(ft8B) Lraulrrip I" 500292180361 KUPAR UK RIVER UNIT PROD 100.68 10,130.38 10.201.0 ••• Comment 1125(ppm) Date Annotation End Dale KB-Grd(It) Rig Release Date 30.13L1-01371e20152.15:09 PM SSSV:NIPPLE 160 12/222013 Last WO: 34.98 5,2211988 Vertical schematic(*dual) An notation-I Depth(10(8) End Data Annotation Last Mod By End Date pyo 11st Tag Rev Reason:ADD LATERALS LI,L1-01,L1-02, smsmitll 3/18/2015 HANGER:33.0 IiI � L1-03.L1 04 ., . .. ..., . . ,. Casing Strings I Cooing Deacriptlls OD(In) ID(In) Top(NKR) 5e1 Depth(fIK8) Set Depth(TVD)... Wtllen(I...Grade Top Thread LINER LI-01 Liner Details 23/5 1.992 8.963.1 10.201.0 4.6011-80 ST-L ,./.....! Nominal ID Top MKS) Top(TVD)INKS) Top Inc(C.) hem Des Corn (In) 8,963.1 6.629.1 89.02 B)LLLT BAKLR LINLR TOP BILLLT(ALUMINUM) 1.900 r CONDUCTOR;36 7100 ' Perforations&Slots P Shot Dens NIPPLE:495.5 t Top(TVD) Bim(TVD) (shots/( . Top(EKE) Bun(ttKB) (ttKB) - (560) Zone Date 1) Type Com 1 8,972.1 10.200.5 6,629.3 6,596.6 A-1,30-131_1- 2/19/2015 SLOTS Slotted Liner 01 GAS UFT:2,512.0Notes:General&Safety End Date Annotation 3/18/2015 NOTE ADD LATERALS L1(off main wellbore),L1-01,L1-02,L1-03,L1-04 • BARRIER VLV;3,339.5 rlI GAS LIFT;3,894.0 II•• SURFACE:35.0-4,340.2-• f GAS LIFT;5,120.0 • GAS LIFT:6.07131j1._ GAS LIFT;6,8352 GAS LIE T.7.303:3 LOCATOR',7.4107 �� PSR;7,415.2 r PACKER,7,430.3 - NIPPLE;7,4926 . it xOEnlarging lTu89g1:7.504A ._ Liner;7,5054 WHIPSTOCK:7084.01 Liner:7,549.5 WINDOW L1:7.570.2-7,575.5 1 1.11 MULESHOE:7.593.3 APERF'7.812.0-7,842.0- APERF'.7.638.0-7,660.0 IPERF:7 6000-7,700 0 FRAC,7,B00.0�.L13 FISH:7,749.0 '-- FISH,7,749.0, PRODUCTION;53.07,915.1-, SLOTS,7,502.48.894.4- LINER L1-04:7.499.7-8,912.0 SLOTS:0$72.1-10,200.5 LINER LI-TI;8.853.1.10.201.0 ry. • KUP PROD 30-13 ConocoPhillips _f 1a7" Well Attributes Max Angle&MD TD ', -1`+-'//7 Wellbore API/UWI Field Name Wellbore Status r ncl C) MD(ftKB) Act Btm(ftKB) Alaska.Inc. ^ 500292180300 KUPARUK RIVER UNIT PROD 41.25 4,300.00 7,950.0 c,.,r,r.,n,aoP. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13.2/12/20159:0024 AM SSSV:NIPPLE 160 12/22/2013 Last WO: 12/2/2014 34.98 5/22/1988 Vertical schemal.(actual) -- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..............................HANGER;33.0 �,y ---'---..Last Tag:SLM 7,612.0 10/62014 Rev Reason:SET WHIPSTOCK hipshkf 2/8/2015 II;l'l1 Casing Strings 7Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 I-1-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' - (- SURFACE 95/8 8.921 35.0 4,340.2 4,047.5 36.00 J-55 BTC - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread N'-A-'a,PRODUCTION 7 6.276 33.0 7,915.1 6,872.2 26.00 J-55 BTC Tubing Strings Tubing Description Shing M...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;36.0-110.0- � TUBING WO 31/2 2.992 33.0 7,594.0 6,605.5 9.30 L-80 EUEM 8rd r-- Completion Details Nominal ID NIPPLE;495.5 SW Top(ftKB) Top(ND)(ftKB) Top Incl I) Item Des Com (In) 33.0 33.0 0.12 HANGER McEVOY GEN IV TUBING HANGER 2.950 495.5 495.5 0.80 NIPPLE CAMCO'DS'NIPPLE 2.875 I-' 3,339.6 3,279.6 32.31 BARRIER VLV HALLIBURTON LUBRICATOR VALVE(BARRIER 2.862 VALVE) GAS LIFT;2,512.0 7,410.7 6,456.0 35.82 LOCATOR 80-40 GBH-22 LOCATOR(bottom of locator spaced out 3.000 6';locator 1'+seals=22.73') 7,415.2 6,459.6 35.79 PBR BAKER 80-40 PBR 4.000 7,438.3 6,478.3 35.66 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 BARRIER VLV;3,339.5PI 7,492.6 6,522.5 35.36 NIPPLE HALLIBURTON X'NIPPLE 2.913 7,505.4 6,533.0 35.29 Liner Liner Joint w/6"Wearsox Bands,5-1/2"148 H-40 STC 4.950 SCC Box x Pin ._ 7,549.8 6,569.3 35.02 Liner Liner Joint w/6"Wearsox Bands,w/muleshoe 4.950 GAS LIFT;3,894.0lia 7,593.8 6,605.4 34.77 MULESHOE MULESHOE 4.950 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - Top(TVD) Top not Top(ftKB) (ftKB) C) Des Com Run Date ID(In) 7,564.0 6,580.9 34.94 WHIPSTOCK 3.5"x 5.5"BAKER THRU-TUBING,ORIENTATION 2/3/2015 0.000 AT 2 DEG LOHS 7,749.0 6,733.9 33.68 FISH TOOL STRING Lost Tool String downhole on 11/19/1988 0.000 SURFACE;35.0.4,340.2 a • 11/19/88;Unsuccessful attempts to recover;Note on Schematic TS @ 7749' 111:117,749.0 6,733.9 33.68 FISH 1 1/2"DV w/TG Latch Downhole 4/18/1989 0.000 GAS LIFT;5,120.0 Perforations&Slots r- Shot Dens Top(TVD) Btm(1VD) (shotsd Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,071.2--IFT 7,612.0 7,642.0 6,620.3 6,645.1 A-3,A-2,30- 4/5/1989 2.0 APERF 2-1/8"EnerJet,BH;60 13 deg phase - 7,638.0 7,668.0 6,641.8 6,666.6 A-2,30-13 4/5/1989 12.0 APERF 2-1/8"EnerJet;0 deg ph, down Ilrf 7,680.0 7,700.0 6,676.5 6,693.2 A-1,30-13 6/25/1988 8.0 IPERF 4-1/2"Ultrapak Csg;45 GAS LIFT;6,835.2 deg phase Stimulations&Treatments Min Top Max Btm '- Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com GAS LIFT;7,353.8-IIRE 7,680.0 7,700.0 6,676.5 6,693.2 FRAC 10/7/1988 FRAC A-SANDS w/GELLED DIESEL Mandrel Inserts r-- st ati on Top(ND) Valve Latch Port Size TRO Run LOCATOR;7,410.7 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,512.0 2,511.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/10/2014 PBR;7,415 2 PACKER;7,438.3 2 3,894.0 3,707.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/10/2014 3 5,120.0 4,646.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/10/2014 4 6,071.2 5,392.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/10/2014 NIPPLE;7,492.6 IN 5 6,835.2 5,995.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/10/2014 00 Enlarging(Tubing);7,504.4 F` 6 7,353.8 6,409.9 CAMCO MMG 11/2 GAS LIFT SPG RK 0.000 0.0 1/19/2015 Notes:General&Safety Liner,7,505.4 End Date Annotation 3/4/1998 NOTE:WAIVERED WELL:IA x OA COMMUNICATION 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 WHIPSTOCK;7,564.0 \--.----... 1/19/2014 NOTE:BARRIER VLV control lines/system @ Wellhea marked Open/Close ' Liner,2549.8 - 1/19/2014 NOTE:BARRIER VLV is NOT a safety valve,it does not fail to closed position MULESHOE;7,593.0 -41/ 2/12/2015 NOTE:MULESHOE IS ACTUALLY PART OF LAST LINER JOINT APERF;7,6120-7,642.0- _ _ _ . I 1 APERF;7,638.0-7,6680- FRAC;7.700.0 L A IPERF;7FRAC;7,680.0 FISH;7,749.0 FISH;7,749.0 PRODUCTION;33.0-7,915.1 30-13 PRE-RIG WELL WORK DATE SUMMARY 1/19/2015 SET BAITED PULLING TOOL ON BALL& ROD @ 7467' SLM; PULLED SOV& SET SPARTEK SPG @ 7353' RKB; MITIA 2500 PSI (PASSED). PULLED BAITED BALL& ROD. IN PROGRESS. 1/20/2015 PULLED 2.81" RHC PLUG BODY FROM 7492' RKB. TAGGED @ 7729' SLM. MEASURED BHP @ 7564' RKB: 3375 PSI. DRIFTED CLEANLY WITH DUMMY WHIPSTOCK TO 7600' RKB. READY FOR E-LINE. 2/3/2015 SET BAKER 3.5"x5.5"THRU-TUBING WHIPSTOCK. TOP OF WHIPSTOCK AT 7564' RKB. SET 2 DEG LOHS. CCL TO TOP OF WHIPSTOCK= 15'. CCL STOP DEPTH 7549'. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 7571.35' RKB. JOB COMPLETE 2/9/2015 (PRE-CTD): POSITIVE TREE VALVE TESTS: MV(PASSED), SSV(PASSED), SV(PASSED) DDT'S MV (PASSED), SSV(PASSED), SV(PASSED) Conocc hitlips Time Log & Summary Wel(view Web Reporting Report Well Name: 30-13 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 2/11/2015 1:00:00 PM Rig Release: 3/4/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/10/2015 24 hr Summary Finish RD from 1L-Pad. Move rig from 1L-Pad to 30-Pad. 12:00 15:00 3.00 0 0 MIRU MOVE RURD P Complete RD from 1L-04, prep rig modules for move to 30-Pad 15:00 23:00 8.00 0 0 MIRU MOVE MOB P Move CDR2 from 1L-Pad to 30-Pad 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Arrive on location. PJSM. Prep well site. 02/11/2015 MIRU CDR2. Begin initial BOPE test. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Finish prepping work site for rig modules.Spot rig modules over 30-13. 06:00 13:00 7.00 0 0 MIRU MOVE RURD P MIRU,berm cellar, RU PUTZ,steam, interconnect, pre spud checklist. Spot tiger tank, install hardline, continue rig up. 13:00 16:00 3.00 0 0 MIRU WHDBO NUND P PJSM. NU BOPE stack.Take 40 minutes to check all tree flange bolts for tightness, none were found lose. Prep floor for BOP test. Rig Accept: 13:00 on 02/11/15 16:00 00:00 8.00 0 0 MIRU WHDBO BOPE P Start initial BOP test 250/4000 psi, annular 2500 psi.Test waived by Lou Grimaldi @ 12:00 on 02/11/15. 02/12/2015 Complete BOPE test. Pull TWCV.Test PDL's and TT line. Pre Spud. Function test Halliburton DH Lubricator Valve. Bled gas in tubing to 0 psi, no flow test. MU BHA#1. 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE P Continue initial BOP test 250/4000 psi, annular 2500 psi. 01:00 06:00 5.00 0 0 MIRU WHDBO BOPE T Unable to get test on B3, B4, B7 and B8 valves, replaced failed C9, reflush stack,minimal frac sand present, unable to get test on any valves that passed test previously,troubleshoot. 06:00 09:00 3.00 0 0 MIRU WHDBO BOPE P Crew change,TP isolated leak issues. Greased B3 and B7, retest B3,B7,and C9,good test. Installed test sub,test all stack components. BOP test complete. 09:00 13:30 4.50 0 0 MIRU WHDBO PRTS P PJSM. LD BOP test equipment.Load coil,test inner reel iron. 13:30 16:00 2.50 0 0 MIRU WHDBO MPSP P PJSM. Load FMC lubrictor, pull TWC, RD FMC equipment. 16:00 19:00 3.00 0 0 MIRU WHDBO PRTS P Test PDL's,tiger tank line. Page 1 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 0 0 MIRU WELLPF SFTY P Pre Spud nights(Gary Corders crew) PJSM-Halliburton Lubricator valve test. 19:30 21:45 2.25 0 0 MIRU WELLPF CTOP P Function test HES Lubricator Valve, valve in open position due to unable to bleed tubing pressure down from 980 psi,close/open/close DH valve per procedure,valve working , 127cc fluid returned on each step in process, bleed tubing down,all gas at surface from 280 psi to 0 psi. 21:45 22:45 1.00 0 0 MIRU WELLPF OWFF P Monitor well for flow, PJSM for MU of BHA. Sniff night cap bleeder prior to removal, 0 psi on surface with wisper of gas from bleeder, High LEL, CO levels,will deploy first BHA for barrier. 22:45 00:00 1.25 0 76 PROD1 WHPST PULD P PJSM-MU BHA#1,deploy. 02/13/2015 Deploy BHA#1. Open DHLV valve. Swap to 9.6 ppg milling fluid, pump 60 bbl of Hi-vis 100k LSRV pill into A sand to control losses. Mill dual string window,TOW 7,570.2-ft, BOW 7,575.5-ft. Drill rathole to 7,589-ft. 00:00 00:48 0.80 0 76 PROD1 WHPST PULD P Finish Deploying BHA#1, MU to CoilTrak,surface test. 00:48 02:48 2.00 76 7,250 PROD1 WHPST TRIP P TIH with BHA#1, .6°AKO motor and 2.80"DSM window mill, EDC open pumping 1 bpm, 19 bbl away before returns at surface,stop at 215-ft, pressure up tubing to 1200 psi,open DHLV(127cc fluid return)tubing dropped to 800 psi,continue TIH pumipng 1 bpm. 02:48 03:00 0.20 7,250 7,285 PROD1 WHPST DLOG P Tie in to K1 marker, plus 3-1/2-ft correction. 03:00 03:09 0.15 7,526 7,526 PROD1 WHPST TRIP P Continue TIH, park and swap to 9.6 ppg milling fluid. 03:09 04:24 1.25 7,526 7,526 PROD1 WHPST DISP P Displace well to 9.6 ppg milling fluid all around, loosing-20 bph holding 11.8 ECD,performed static test TVD=6540', 9.6 ppg=BHP 3265, SITP 280 psi, confer with town, pump high vis pill, lower ECD at window to 11.4. 04:24 06:30 2.10 7,526 7,526 PROD1 WHPST DISP P Pump 20 bbl 100k LSRV pill, loosing —9 bph holding 11.4 ECD,shut in, squeeze hi-vis pill into formation, initial.5 bpm at 1605 psi,WH 495, ECD 11.8,final.5 bpm at 1750 psi, WH 833 psi, ECD 12.8, attempt to establish 1-1 returns, lost all returns for 5 mins, regain returns, not 1-1. 06:30 12:24 5.90 7,526 7,526 PROD1 WHPST DISP P Pump additional 40 bbl 100K LSRV pill,wait 20 mins,attempt to establish returns, pump 1.50 bpm in rate and 1.44 out, ECD=11.38. Move forward with milling operations. 12:24 12:54 0.50 7,526 7,570 PROD1 WHPST TRIP P Close ECD. RBIH,weight check 25K,dry tag whipstock. LPage 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:54 00:00 11.10 7,570 7,589 PROD1 WHPST WPST P Start time milling WS as per well plan. Pump 1.50 bpm @ 3205 psi, CTW=14.3K, ROP=1.TOW at 7,570.2-ft/BOW at 7,575.5-ft. mill rathole to 7,589-ft. Note: lost 111 bbl 9.6 ppg milling fluid in last 24 hr, average of 3.5 bph after hi-vis pill sqeezed. 02/14/2015 Back ream window, drift clean.TOOH.Close DHLV. LD BHA#1. MU BHA#2. Open DHLV. TIH. Drill build section 7,589-ft to 7,825-ft.TOOH. Close DHLV. LD BHA#2. Cut flat spot from coil 21-ft, perform slack management,cut another 40-ft coil,wire at 35-ft. Install CTC. Re-head and test. Opened DHLV for MP while cutting and re-heading. 00:00 02:09 2.15 7,589 7,589 PROD1 WHPST REAM P Back ream window exit 30°L/R, drift window with pumps down, clean,jet and jog BTP. 02:09 03:45 1.60 7,589 76 PROD1 WHPST TRIP P TOOH with BHA#1 for drilling assembly 03:45 04:21 0.60 76 76 PROD1 WHPST OWFF P PJSM-Close DHLV, bleed tubing above 550 psi to 200 psi, held, bleed to 0 psi, no flow test 15 minutes. PJSM-LD BHA. 04:21 05:15 0.90 76 0 PROD1 WHPST PULD P PJSM-LD BHA#1, magnets full, DSM and strimg mill both gauged 2.79"no-go. 05:15 07:00 1.75 0 72 PROD1 DRILL PULD P PJSM-MU BHA#2,test MWD, flushing choke,open EDC,fill coil/hole.Open HES lubicator valve. 07:00 08:48 1.80 72 7,589 PROD1 DRILL TRIP P RIH w/build drilling assembly,tie-in to K1 for+4'correction, continue in hole,weight check above window, PUW=26K, clean through window. 08:48 12:51 4.05 7,589 7,825 PROD1 DRILL DRLG P BOBD: 1.47 bpm @ 3,350 psi, BHP=3940,CTW=12.5K, WOB=1.7K, ROP=80. PUH once for tie-in @ 7,690', PUW=27K, correction was zero. 12:51 15:00 2.15 7,825 73 PROD1 DRILL TRIP P POOH for lateral drilling assembly, close HES lubricator valve, bleed off well. 15:00 19:30 4.50 73 0 PROD1 DRILL PULD P PJSM. LD BHA#2, check coil above connector,found flat spot(.119 flat spot)PJSM. MP during coil rehead. Cut 21-ft coil, should be in 20-ft into.175 wall pipe,still in .156 wall pipe, confer with town on pipe management. 19:30 00:00 4.50 0 0 PROD1 DRILL CTOP P PJSM-Install boot, perform slack management,cut 40-ft coil,61-ft total,find wire at 35', install CTC, rehead and test. 32/15/2015 Perform slack management. Close DHLV. MU BHA#3.Open DHLV.TIH. Drill L1 lateral 7,825-ft to 8,825-ft. Drilling in progress. 00:00 00:45 0.75 0 0 PROD1 DRILL CTOP P Continue slack management. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 02:36 1.85 0 72 PROD1 DRILL PULD P PJSM-Close DHLV, no flow, MU BHA#3, .5°AKO motor and Bi-center bit, MU to CoilTrak,surface test, Open DHLV. 02:36 04:09 1.55 72 7,250 PROD1 DRILL TRIP P TIH with BHA#3, EDC open, pumping new 9.4 ppg FloPro. 04:09 04:21 0.20 7,250 7,280 PROD1 DRILL DLOG P Tie in to K1 marker, plus 6-ft correction. 04:21 04:57 0.60 7,280 7,825 PROD1 DRILL TRIP P Continue in hole with BHA#3, new mud at bit at 7,540-ft,close EDC, PUW 29k,TIH,clean thru window. 04:57 07:06 2.15 7,825 8,025 PROD1 DRILL DRLG P 7,825-ft, OBD 1.50 bpm at 3,900 psi, BHP 3950,WH 0,CTW 12k, WOB 1.4k, ROP 60, IA 423, OA 0 07:06 07:48 0.70 8,025 8,025 PROD1 DRILL WPRT P Wiper to window, PUW=27K, RBIH. 07:48 10:21 2.55 8,025 8,225 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3950 PSI, BHP=3995 PSI, CTW=11.5K, WOB=1.8K, ROP=80 10:21 11:06 0.75 8,225 8,225 PROD1 DRILL WPRT P Wiper to window, PUW=26K, RBIH. 11:06 14:42 3.60 8,225 8,425 PROD1 DRILL DRLG P Drill ahead: 1.49 BPM @ 3825 PSI, BHP=4005 PSI, CTW=10.6K, WOB=2.2K, ROP=60 14:42 15:42 1.00 8,425 8,425 PROD1 DRILL WPRT P Wiper for tie-in, PUW=25K,tie-into RA for+.5'correction, RBIH. 15:42 18:42 3.00 8,425 8,625 PROD1 DRILL DRLG P Drill ahead: 1.49 BPM @ 3890 PSI, BHP=3986 PSI, CTW=10.9K, WOB=2.1 K, ROP=40 18:42 19:33 0.85 8,625 8,625 PROD1 DRILL WPRT P Wiper to window, PUW=28K, RBIH. 19:33 22:54 3.35 8,625 8,825 PROD1 DRILL DRLG P 8,625-ft, OBD 1.5 bpm at 3912 psi, BHP 4011 psi, CWT 11k,WOB 1.35k, ROP 55, IA 393, OA 0. 22:54 00:00 1.10 8,825 8,825 PROD1 DRILL WPRT P Wiper up hole, PUW=30K, RBIH from 7,835-ft. 02/16/2015 Drill L1 lateral 8,825-ft to 9,625-ft. New mud at bit at 9,553-ft. Drilling in progress. 00:00 03:33 3.55 8,825 9,025 PROD1 DRILL DRLG P 8,825-ft, OBD 1.48 bpm at 3933 psi, BHP 4028 psi, CWT 10.7k,WOB 2.6k, ROP 55, IA 466, OA 0. 03:33 05:12 1.65 9,025 9,025 PROD1 DRILL WPRT P Wiper for tie-in, PUW 29k,jet and jog BTP,tie-in to RA marker for plus 1'correction, RBIH. 05:12 10:18 5.10 9,025 9,225 PROD1 DRILL DRLG P 9,025-ft, OBD 1.5 bpm at 3957 psi, BHP 4050 psi, CWT 9.5k,WOB 2.5k, ROP 40, IA 526, OA 0. Drawing near to polygon, polygon moved. 10:18 11:33 1.25 9,225 9,225 PROD1 DRILL WPRT P Wiper trip, PUW=31K, RBIH. 11:33 15:03 3.50 9,225 9,425 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3905 PSI, BHP=4120 PSI, CTW=8.5K, WOB=1.7K, ROP=60 15:03 16:21 1.30 9,425 9,425 PROD1 DRILL WPRT P Wiper trip, PUW=30K, RBIH. Page 4 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:21 17:12 0.85 9,425 9,442 PROD1 DRILL DRLG P Drill ahead: 1.49 BPM @ 3860 PSI, BHP=4105 PSI, CM=9K, WOB=2.2K, ROP=35. PUH slowly, pump#2 issue, bringing on new fluids for mud swap. 17:12 18:12 1.00 9,625 PROD1 DRILL SVRG P Continue PUH slowly,trouble getting pump#1 primed, servicing pump#2 swabs. 18:12 19:12 1.00 9,442 9,442 PROD1 DRILL WPRT P Continue to PUH slowly, pump#1 primed, RBIH from 8,175-ft. 19:12 23:51 4.65 9,442 9,625 PROD1 DRILL DRLG P 9,442-ft, OBD 1.50 bpm at 3917 psi, BHP 4097 psi,WHP 0, CWT 9.6k, WOB 2.25k, ROP 40, IA 190, OA 0. **Note: New 9.4 ppg mud at bit at 9,553-ft,system#2. Mud system#1 drilled 1,728-ft w/.9%solids. 23:51 00:00 0.15 9,625 9,625 PROD1 DRILL WPRT P Wiper for tie-in, PUW 27k. 02/17/2015 Drill L1 lateral 9,625-ft to extended TD 10,348-ft.Wiper up into BTP. Pressure drop survey performed at TT. RBIH to confirm TD at 10,348-ft. Lay in 50 bbl of 100k LSRV,9.4 ppg beaded liner running pill, 9.4 ppg FloPro to surface, paint flags. 00:00 02:21 2.35 9,625 9,625 PROD1 DRILL WPRT P Continue wiper for tie-in,jet and jog BTP,tie-in to RA marker for plus 2' correction, RBIH. 02:21 05:15 2.90 9,625 9,825 PROD1 DRILL DRLG P 9,625-ft, OBD 1.50 bpm at 3983 psi, BHP 4099 psi,WHP 0, CWT 7.5k, WOB 2.5k, ROP 65, IA 46, OA 0. 05:15 06:15 1.00 9,825 9,825 PROD1 DRILL WPRT P Wiper up hole, PUW 27k, RBIH. 06:15 09:18 3.05 9,825 10,055 PROD1 DRILL DRLG P 9,825', BOBD 1.50 bpm @ 3,947 psi BHP=4,135 psi WHP=Opsi CTW=7.3k IA=229 psi OA=0 psi 09:18 10:33 1.25 10,055 10,055 PROD1 DRILL WPRT P Wiper up hole, PUW=30k, RBIH @ 8,954' 10:33 14:18 3.75 10,055 10,255 PROD1 DRILL DRLG P 10,055', BOBD 1.50 bpm @ 3,903 psi BHP=4,117 psi WHP=0 psi CTW=7.9K WOB= 1.49K IA= 242 psi OA=0 psi 14:18 14:48 0.50 10,255 9,250 PROD1 DRILL WPRT P 10255ft,wiper up hole to 9250ft, PUW 30k 14:48 15:18 0.50 9,250 10,255 PROD1 DRILL WPRT P 9250ft,wiper back in hole RIW 12k 15:18 16:48 1.50 10,255 10,348 PROD1 DRILL DRLG P 10255ft, BOBD 1.5bpm at 3850psi, BHP 4170,WHP 0, IA 287,OA 0 16:48 18:42 1.90 10,348 7,550 PROD1 DRILL WPRT P 10348ft, TD L1 lateral,Wiper up hole to window,jet and jog BTP, RBIH to 7,550-ft. 18:42 19:18 0.60 7,550 7,610 PROD1 DRILL DLOG P 7,550-ft, Park coil,shut in for survey, initial Annular 3,858 psi, ECD 11.47, Monitor 15 min,Annular 3697, ECD 10.99, looks like trying to hold, confer with town, use DHLV, PUW 25k,tie-in at RA marker for plus 2-ft correction. 19:18 20:30 1.20 7,610 10,348 PROD1 DRILL WPRT P 7,610-ft, Wiper back in hole, 12k RIW. f_ Page 5 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 10,348 72 PROD1 DRILL DISP P 10,348-ft, Corrected TD, Lay in 9.4 ppg, 100k LSRV beaded liner pill in open hole, BTP and up into the 3 1/2"tubing,9.4 ppg to surface,paint flags at 9,300-ft(yellow)and 6,600-ft (white) 02/18/2015 Close DHLV. LD BHA#3, MU/TIH with BHA#4, L1 liner assembly.Open DHLV. Set L1 liner top at 9,500-ft, TOOH. Close DHLV. LD BHA#4. MU/TIH with BHA#5. Kick off OH anchored billet at 9,502-ft. Drill ahead L1-01 lateral to 9,682-ft. Drilling in progress. 00:00 00:30 0.50 72 72 PROD1 DRILL OWFF P PJSM-Close DHLV, SITP 581 psi, monitor for no flow. PJSM-LD BHA 00:30 01:45 1.25 72 0 PROD1 DRILL PULD P LD BHA#3, bit condition 1-1-PN-N-X-I-NO-TD. 01:45 02:15 0.50 0 0 COMPZ CASING PUTB P PJSM-Prep floors for running liner. 02:15 04:24 2.15 0 833 COMPZ CASING PUTB P PJSM-MU 2 3/8"non-ported bull nose,26 jts slotted, aluminum OH anchored billet. 04:24 06:00 1.60 833 894 COMPZ CASING PULD P PJSM-MU L1 liner assembly to BHA #4, MU to CoilTrak,surface test. 06:00 07:42 1.70 894 7,493 COMPZ CASING RUNL P Open DHLV, SITP 360 psi,TIH with _ L1 liner assembly on BHA#4. 07:42 07:57 0.25 7,493 7,493 COMPZ CASING RUNL P Correct to the EOP flag,correction of plus 0.62ft. Close EDC, PUW 26k 07:57 08:12 0.25 7,493 8,070 COMPZ CASING RUNL P Continue RIH for tie in at K1 marker. 08:12 08:27 0.25 8,070 8,070 COMPZ CASING DLOG P 8070ft,Tie into the K1 marker _ correction of plus 2.0ft 08:27 09:12 0.75 8,070 10,332 COMPZ CASING RUNL P 8070ft, Continue RIH, RIW 13k, Run in open hole at 40fpm, no pump 09:12 09:27 0.25 10,332 10,332 COMPZ CASING RUNL P 10332.5ft, PUW 26k, set TOB at 9500ft, pressure shear at 4400psi, set down 1k, PUW 26k, remove BHA from counters. 09:27 11:57 2.50 10,332 70 COMPZ CASING TRIP P 10332ft, POOH 11:57 12:27 0.50 70 70 COMPZ CASING SFTY P At surface PJSM for L/D setting tools, Perform flowcheck ****Note: Closed lubricator valve, 700psi WHP 12:27 13:27 1.00 70 0 COMPZ CASING PULD P L/D BOT setting tools,and BHA 13:27 13:57 0.50 0 0 PROD2 DRILL CTOP P PJSM, perform bi-weekly BOPE function test. 13:57 15:27 1.50 0 72 PROD2 STK PULD P PJSM, M/U, kick off/drilling BHA#5, bring pump up to MP,WHP 700psi ****Note: Open lubricator valve, WHP dropped to 460psi. 15:27 16:57 1.50 72 7,240 PROD2 STK TRIP P RIH,with rebuild Haycolog bi-center bit/0.8°ako motor,standard BHA with RES, EDC closed. 16:57 17:12 0.25 7,240 7,240 PROD2 STK DLOG P 7240ft,Tie into the K1 marker correction of plus 3.0ft, PUW 25k 17:12 18:18 1.10 7,240 9,502 PROD2 STK TRIP P 7240ft, Continue RIH to TOB, Dry tag TOB at 9,502.6-ft, PUW 26k, Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:18 21:21 3.05 9,502 9,513 PROD2 STK KOST P 9,502-ft. begin time milling off billet per schedule 1.43 bpm at 3765 psi, BHP 4058, IA 0, OA 0,two stalls, aluminum across shaker. 21:21 21:51 0.50 9,513 9,540 PROD2 DRILL DRLG P 9,513-ft, Drill ahead L1-01 lateral to 9,540-ft 1.44 bpm at 3882 psi, BHP 4072,WHP 21, IA 123, OA 0 21:51 22:00 0.15 9,540 9,400 PROD2 DRILL WPRT P 9,540-ft, Wiper trip to 9,400-ft to clean up hole, PUW 27.5k. 22:00 22:12 0.20 9,400 9,540 PROD2 DRILL WPRT P 9,400-ft, Wiper back in hole, pumps off,drift billet area clean. 22:12 00:00 1.80 9,540 9,682 PROD2 DRILL DRLG P 9,540-ft, OBD 1.50 bpm at 4063 psi, BHP 4099 psi,WHP 22, CWT 8.4k, WOB 1.85k, ROP 75, IA 130, OA 0. 02/19/2015 Drill L1-01 lateral 9,682-ft to TD at 10,201-ft.Wiper up into BTP. RBIH. Confirm TD 10,201-ft, Lay in 100k LSRV 9.4 ppg beaded liner pill, 9.4 ppg FloPro to surface. Paint flags.Close DHLV. LD BHA#5. MU/TIH with L1-01 liner assembly on BHA#6. 00:00 00:21 0.35 9,682 9,710 PROD2 DRILL DRLG P 9,682-ft, OBD 1.50 bpm at 4063 psi, BHP 4099 psi,WHP 22, CWT 8.4k, WOB 1.85k, ROP 75, IA 130, OA 0. 00:21 00:57 0.60 9,710 8,500 PROD2 DRILL WPRT P Wiper up hole, PUW 28k,5X5 sweep pumped. 00:57 01:33 0.60 8,500 9,710 PROD2 DRILL WPRT P Wiper back in hole, RIW 12k 01:33 03:36 2.05 9,710 9,910 PROD2 DRILL DRLG P 9,710-ft, OBD 1.49 bpm at 4123 psi, BHP 4132 psi,WHP 22, CWT 7.4k, WOB 2.25k, ROP 100, IA 190, OA 0. 03:36 04:09 0.55 9,910 8,900 PROD2 DRILL WPRT P Wiper up hole, PUW 27k. 04:09 04:42 0.55 8,900 9,910 PROD2 DRILL WPRT P Wiper back in hole, RIW 11k. 04:42 07:42 3.00 9,910 10,110 PROD2 DRILL DRLG P 9,910-ft, OBD 1.48 bpm at 4094 psi, BHP 4161 psi,WHP 20,CWT 5.9k, WOB 2.0k, ROP 65, IA 188, OA 0. 07:42 08:18 0.60 10,110 9,100 PROD2 DRILL WPRT P 10110ft,Wiper up hole to 9100ft, PUW 27k 08:18 08:48 0.50 9,100 10,110 PROD2 DRILL WPRT P 9100ft,Wiper back in hole to bottom, RIW 11k 08:48 10:48 2.00 10,110 10,200 PROD2 DRILL DRLG P 10110ft, BOBD 1.5 bpm at 3930psi, BHP 4211,WHP 20, IA 280, OA 0 10:48 12:18 1.50 10,200 7,564 PROD2 DRILL WPRT P 10200ft,TD L1-01 lateral,pump 10x10 sweep,wiper up hole to the window. 12:18 12:33 0.25 7,564 7,515 PROD2 DRILL WPRT P 7564ft, PUH into the casing jet up to the tubing tail, perform a jog in the 5-1/2", pumping 1.5 bpm at 3850psi. 7558ft-7515ft. 12:33 12:48 0.25 7,515 7,595 PROD2 DRILL WPRT P Wiper back in hole, pumping 1.5 bpm at 3850psi. 12:48 12:54 0.10 7,595 7,638 PROD2 DRILL DLOG P 7595ft,Tie into the RA marker correction of plus 2.0ft. 12:54 13:54 1.00 7,638 10,201 PROD2 DRILL WPRT P Continue wiper in hole RIW 12k 13:54 17:15 3.35 10,201 72 PROD2 DRILL DISP P POOH, laying in 9.4ppg(100k LSRV) Liner running pill with Alpine beads, paint flags at 8,800-ft and 6,600-ft, 9.4 ppg FloPro to surface. �� � Page 7 of 18 _Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment • 17:15 17:45 0.50 72 72 PROD2 DRILL OWFF P PJSM-Close DHLV, SITP 710 psi, monitor for no flow. PJSM-LD BHA 17:45 19:00 1.25 72 0 PROD2 DRILL PULD P LD BHA#5, bit condition 2-2-BT-N-X-I-CT-TD. 19:00 19:30 0.50 0 0 COMPZ CASING PUTB P PJSM-Prep floors for running liner. 19:30 21:45 2.25 0 1,238 COMPZ CASING PUTB P PJSM-MU 2 3/8"non-ported bull nose, 39 jts slotted,aluminum liner top billet. 21:45 23:00 1.25 1,238 1,282 COMPZ CASING PULD P PJSM-MU L1-01 liner assembly to BHA#6, MU to CoilTrak,surface test. 23:00 00:00 1.00 1,282 5,200 COMPZ CASING RUNL P Open DHLV, SITP 388 psi,TIH with L1 liner assembly on BHA#6. 32/20/2015 TIH with L1-01 liner assembly on BHA#6, release off liner at 10,201-ft,top of billt at 8,963-ft.TOOH. LD BHA #6. MU/TIH with BHA#7 L1-02 drilling assembly. Kick off billet at 8,963-ft, BHI"HOT"tool failed at 8,965-ft. TOOH. LD BHA#7. MU/TIH with BHA#8 L1-02 drilling assembly#2. Drill ahead L1-012 lateral to 8,989-ft, billet drift clean. BHI motor chunked. TOOH. 00:00 00:27 0.45 5,200 6,600 COMPZ CASING RUNL P Continue TIH with L1 liner assembly on BHA#6. 00:27 00:39 0.20 7,482 7,482 COMPZ CASING RUNL P Correct to the EOP flag,correction of plus 0.15-ft., PUW 28.5k. 00:39 01:51 1.20 7,482 10,201 COMPZ CASING RUNL P 7,482-ft, Continue RIH, RIW 12k, Run in open hole at 40-fpm, no pump 01:51 02:03 0.20 10,201 10,201 COMPZ CASING RUNL P 10,201-ft, PUW 29k, release off liner, PUW 23k,TOB at 8,963-ft, remove liner assembly from counters. 02:03 04:06 2.05 10,201 44 COMPZ CASING TRIP P TOOH with BHA#6. 04:06 04:36 0.50 44 44 COMPZ CASING OWFF P PJSM-Close DHLV, SITP 730 psi, monitor for no flow. PJSM-LD BHA 04:36 05:18 0.70 44 0 COMPZ CASING PULD P LD BHA#6.check coil above CTC. 05:18 06:48 1.50 0 72 PROD3 STK PULD P PJSM-MU BHA#7,/ ****Note: Simops inspect choke B 06:48 08:54 2.10 72 7,255 PROD3 STK TRIP P RIH with L1-02 drilling assembly with 0.8°bend motor and rebuilt Hycalog bit. ****Note: Bring WHP up to 700psi, pressure below DHLV 480psi. 08:54 09:09 0.25 7,255 7,277 PROD3 STK DLOG P 7255ft,Tie into the K1 marker correction of plus 3.5ft. 09:09 10:39 1.50 7,277 8,963 PROD3 STK TRIP P 7277ft, continue RIH through window. 10:39 10:54 0.25 8,963 8,963 PROD3 STK KOST P Dry tag TOB at 8963ft, PUH,bring on pump to drilling rate. 10:54 13:24 2.50 8,963 8,965 PROD3 STK KOST P 8963ft,Start kicking off of billet at 8963ft, 1.5 bpm at 3900psi, BHP 4085,WHP 25, IA 0, OA 0 13:24 16:24 3.00 8,965 72 PROD3 STK TRIP T Mill billet to 8965ft,Troubleshoot BHI "HOT"has failed, POOH ****Note: BHI HOT failed Page 8 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:24 16:39 0.25 72 0 PROD3 STK SFTY T At surface, PJSM for UD BHA ****Note: Close DHLV with 660psi, bled down WHP to 0, close choke back in with no pressure. 16:39 18:36 1.95 0 72 PROD3 STK PULD T L/D and changeout failed tools 18:36 20:06 1.50 72 7,250 PROD3 STK TRIP T Open DHLV, SITP 380 psi,TIH with L1-02 drilling assembly, 0.8°AKO motor and rebuilt Hycalog bit(Helios Edge) 20:06 20:18 0.20 7,250 7,275 PROD3 STK DLOG T Tie into the K1 marker with a correction of plus 3-ft, close EDC, PUW 26.5k. 20:18 21:15 0.95 7,275 8,965 PROD3 STK TRIP T 7,275-ft, Continue TIH through window. 21:15 22:18 1.05 8,965 8,988 PROD3 STK KOST P 8,965-ft. continue time milling off billet per schedule 1.43 bpm at 3962 psi, BHP 4098, IA 0, OA 0. ****Note: BHI downtime end 22:18 23:03 0.75 8,988 8,988 PROD3 DRILL WPRT T 8,988-ft, Hard stall, PUW 26k, high differntial,work pump to attempt to clear bit. RBIH pumps off,drift billet area clean. ****Note: Start BHI downtime 23:03 23:27 0.40 8,988 8,989 PROD3 DRILL DRLG T 8,988-ft, OB attempt to drill ahead 1.43 bpm at 4211 psi, BHP 4092, high diff when try to drill, up to 1k, bit plugged, handful of rubber across shaker, motor chuncked. 23:27 00:00 0.55 8,989 7,800 PROD3 DRILL TRIP T 8,989-ft,TOOH with BHA#8 02/21/2015 TOOH. LD BHA#8. MU/TIH with BHA#9 L1-02 drilling assembly#3. Drill ahead L1-02 lateral to 8,989-ft to 9,710-ft. Mud swap with new mud at bit at 9,030-ft. Drilling in progress 00:00 01:00 1.00 7,800 72 PROD3 DRILL TRIP T Continue out of hole with BHA#8, open EDC in BTP. 01:00 01:15 0.25 72 0 PROD3 DRILL SFTY T PJSM-Close DHLV, SITP 650 psi, and LD BHA. 01:15 03:45 2.50 0 72 PROD3 DRILL PULD T LD and change out failed tools. checked coil above connector. 03:45 05:21 1.60 72 7,250 PROD3 DRILL PULD T Open DHLV, SITP 320 psi,TIH with BHA#9, L1-02 drilling assembly, 0.8°AKO motor and re-run rebuilt Hycalog bit(Helios Edge) 05:21 05:36 0.25 7,250 7,275 PROD3 DRILL DLOG T Tie into the K1 marker with a correction of plus 2.5-ft, close EDC, PUW 27k. 05:36 06:36 1.00 7,275 8,990 PROD3 DRILL TRIP T 7,275-ft, Continue TIH through window. ****Note: End of BHI downtime (motor) Page 9of18 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:36 07:06 0.50 8,990 9,125 PROD3 DRILL DRLG T 8990ft, BOBD 1.43 bpm at 3800psi, BHP 4112,WHP 25, IA 130, OA 0 """"Note: New mud at the bit 9030ft. Previous system stats 1556ft drilled footage, 0.8%drill solids 07:06 10:36 3.50 9,125 9,190 PROD3 DRILL DRLG T 9125ft,Trouble with surveys perform CS to verify, CS good, RBIH, drill ahead to troubleshoot problems, Perform more CS, looks good, Call town, Pull above billet, perform CS, looks good, RBIH,seems to be interference between AL1-01, Decision was to get more separation 10:36 11:36 1.00 9,190 8,200 PROD3 DRILL WPRT P 9190ft,Wiper up hole PUW 26k 11:36 12:36 1.00 8,200 9,190 PROD3 DRILL WPRT P 8200ft,wiper back in hole. RIW 12k, perform CS on the way in to verify surveys. 12:36 15:36 3.00 9,190 9,390 PROD3 DRILL DRLG P 9190ft, BOBD 1.46 bpm at 3500 psi, BHP 4115,WHP 133, IA 208, OA 0 15:36 16:06 0.50 9,390 8,390 PROD3 DRILL WPRT P 9390ft,wiper up hole PUW 27.5k 16:06 16:36 0.50 8,390 9,390 PROD3 DRILL WPRT P 8390ft,wiper back in hole, RIW 12k 16:36 19:45 3.15 9,390 9,590 PROD3 DRILL DRLG P 9390ft, BOBD 1.5 bpm at 3600 psi, BHP 4120,WHP 132, IA 220, OA 0 19:45 21:03 1.30 9,590 7,510 PROD3 DRILL WPRT P 9590-ft,Wiper for tie-in, PUW 28k, jet and jog BTP 21:03 22:15 1.20 7,510 9,590 PROD3 DRILL WPRT P 7,510-ft, RBIH and tie-in to RA for plus 2-ft correction,wiper back in hole, RIW 12.4k 22:15 00:00 1.75 9,590 9,710 PROD3 DRILL DRLG P 9,590-ft, OBD 1.50 bpm at 3800 psi, BHP 4102 psi,WHP 18, CWT 9.9k, WOB 1.43k, ROP 60, IA 183, OA 0. 02/22/2015 Drill ahead L1-02 lateral to 9,710-ft toTD at 10,308-ft,Wiper to swab.Wiper back in hole.Tag corrected TD at 10,307-ft. Lay in 11.4 ppg beaded liner pill, completion fluid to surface. 00:00 00:54 0.90 9,710 9,790 PROD3 DRILL DRLG P 9,710-ft, OBD 1.50 bpm at 3855 psi, BHP 4102 psi,WHP 18, CWT 9.9k, WOB 1.43k, ROP 80, IA 330, OA 0. 00:54 01:21 0.45 9,790 9,000 PROD3 DRILL WPRT P 9,790-ft,wiper up hole PUW 26k 01:21 01:48 0.45 9,000 9,790 PROD3 DRILL WPRT P 9,000-ft,wiper back in hole, RIW 12k 01:48 04:36 2.80 9,790 9,990 PROD3 DRILL DRLG P 9,790-ft, OBD 1.50 bpm at 3974 psi, BHP 4127 psi,WHP 66, CWT 8.8k, WOB 1.28k, ROP 60, IA 380, OA O. 04:36 05:06 0.50 9,990 9,000 PROD3 DRILL WPRT P 9,990-ft,wiper up hole PUW 27k 05:06 05:36 0.50 9,000 9,990 PROD3 DRILL WPRT P 9,000-ft,wiper back in hole, RIW 11.5k 05:36 09:36 4.00 9,990 10,190 PROD3 DRILL DRLG P 9,990-ft, OBD 1.50 bpm at 3700 psi, BHP 4100 psi,WHP 10, IA 407, OA 0. 09:36 10:36 1.00 10,190 7,510 PROD3 DRILL WPRT P 10190ft,Wiper up hole to the tubing tail at 7510ft, PUW 24 10:36 10:51 0.25 7,510 7,590 PROD3 DRILL WPRT P 7510ft,Wiper back in hole RIW 15k Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:51 11:06 0.25 7,590 7,612 PROD3 DRILL DLOG P 7590ft,Tie into the RA marker correction of plus 2.0ft. 11:06 11:51 0.75 7,612 10,190 PROD3 DRILL WPRT P 7612ft,Continue wiper in hole, RIW 13k 11:51 14:51 3.00 10,190 10,308 PROD3 DRILL DRLG P 10190ft, BOBD 1.5 bpm at 3700 psi, BHP 4156,WHP 9, IA 429, OA 0 14:51 17:45 2.90 10,308 72 PROD3 DRILL WPRT P 10308ft, TD was called short due to crossing the A5-A6 interface. Pump 10x10 sweep and wiper to surface. 17:45 19:18 1.55 72 7,255 PROD3 DRILL WPRT P On surface, adjust counters,wiper back in hole. 19:18 19:27 0.15 7,255 7,312 PROD3 DRILL DLOG P Log K1 marker, plus 2.5-ft correction, PUW 26k. 19:27 20:48 1.35 7,312 10,276 PROD3 DRILL WPRT P Continue wiper back in hole, RIW 11k 20:48 21:00 0.20 10,276 10,307 PROD3 DRILL WPRT P 10,276-ft, stack out, PUW 27.5k, work down easy. 21:00 00:00 3.00 10,307 2,175 PROD3 DRILL DISP P 10,307-ft, Tag for corrected TD, PUW 29k, lay in 11.4 ppg beaded liner running pill, completion fluid to surface, paint flags at 8,400-ft and 5,700-ft. 02/23/2015 Finish TOOH.Well dead. LD BHA#9. MU/TIH with L1-02 lower liner assembly on BHA#10. Set lower liner at 10,307-ft,TOOH. LD BHA#10. MU/TIH with L1-02 upper liner assembly on BHA#11. Set upper liner at 8,595-ft,top at 8,199-ft. TOOH. LD BHA#11. Prep for bi-weekly BOPE test. 00:00 00:39 0.65 2,175 72 PROD3 DRILL DISP P Continue TOOH laying in 11.4 ppg completion fluid to surface. 00:39 01:09 0.50 72 72 PROD3 DRILL OWFF P On surface, monitor well for flow. PJSM-LD BHA 01:09 02:18 1.15 72 0 PROD3 DRILL PULD P LD BHA#9, flat spot found in coil 9-ft above CTC measured.126. bit condition 1-1-BU-G-X-I-NO-TD 02:18 06:00 3.70 0 1,712 COMPZ CASING PUTB P PJSM-Prep floors for liner run, MU bull nose,54 jts 2 3/8"511 hyd slotted liner,shorty deployment sleeve. 06:00 07:30 1.50 1,712 1,757 COMPZ CASING PULD P PJSM-MU L1-02 lower liner assembly to BHA#10, MU to CoilTrak,surface test. 07:30 08:57 1.45 1,757 7,455 COMPZ CASING RUNL P TIH with L1-02 lower liner assembly on BHA#10. 08:57 09:12 0.25 7,455 7,455 COMPZ CASING RUNL P Correct to the EOP flag at 5700ft, correction of minus 1.4ft, PUW 28k 09:12 10:12 1.00 7,455 10,307 COMPZ CASING RUNL P 7455ft, Continue RIH through window "***Note:Steadly stacking weight until BHA was past 9360ft, 10:12 10:27 0.25 10,307 10,307 COMPZ CASING RUNL P 10307ft,set down 3k, PUW 31k,set back down, release liner on bottom, PUW 27k 10:27 12:12 1.75 10,307 44 COMPZ CASING TRIP P Remove BHA from counters, POOH, pumping across the top, in attemp to leave beads in open hole. 12:12 12:42 0.50 44 44 COMPZ CASING SFTY P At surface, PJSM for LD setting tools,flow check well 12:42 13:30 0.80 44 0 COMPZ CASING PULD P LD BHA#10 Page 11 of 18 Time Logs J Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 13:48 0.30 0 0 COMPZ CASING PUTB P Prep rig floor for running upper segment of liner 13:48 14:48 1.00 0 457 COMPZ CASING PUTB P MU L1-02 upper liner segment.with 12 jts of slotted liner 14:48 16:12 1.40 457 457 COMPZ CASING PULD P PJSM, MU BHI tools and BOT setting tool with Open Hole Anchored Billet. 16:12 19:12 3.00 457 8,595 COMPZ CASING RUNL P RIH,with L1-02 liner w/12 jts of slotted ST-L liner with an Open Hole Anchored Billet. Close EDC at 6,658-ft,correction of plus 1.1-ft.at 7,000-ft EOP flag, PUW 28k, RBIH. 19:12 19:24 0.20 8,595 8,199 COMPZ CASING RUNL P 8,595-ft, Set down 3k,single slip set at 180°TF, release off OH anchored billet at 3,500 psi, re-set counters to BHA depth. 19:24 21:30 2.10 8,199 44 COMPZ CASING TRIP P 8,199-ft, TOOH with BHA#11, PUW 27k 21:30 22:00 0.50 44 44 COMPZ CASING OWFF P On surface, monitor well for flow. PJSM-LD BHA 22:00 23:00 1.00 44 0 COMPZ CASING PULD P LD BHA#11,flat spots on coil measured 4-ft above CTC at.123 and 9-ft above CTC at.125,pull checks, one good&one plugged. 23:00 00:00 1.00 0 0 PROD4 WHDBO RURD P PJSM-Prep for bi-wekkly BOP test, jet and fill stack,grease choke,tree. 32/24/2015 Perform bi-weekly BOPE test. Drill off liner top billet @ 8199', Drill to 8280 L1-03 00:00 12:00 12.00 0 0 PROD4 WHDBO BOPE P Perform bi-weekly BOP test 250/4000 psi,annular 2500 psi. Test waived by Bob Noble @ 20:13 on 02/22/15. 12:00 14:30 2.50 0 0 PROD4 STK RURD P RD, bope testing equipment, displace coil from fresh water to 9.4 ppg drilling fluid 14:30 15:18 0.80 0 0 PROD4 STK PULD P Line up to fill the hole after BOPE test, hole took 2 bbls, perform 30 min no flow test 15:18 17:18 2.00 0 72 PROD4 STK PULD P PJSM, MU BHA#12, Make up to coil and surface test 17:18 18:42 1.40 72 7,255 PROD4 STK TRIP P RIH, Kickoff/drilling BHA with 0.5+° motor and rerun bit. 18:42 18:54 0.20 7,255 7,280 PROD4 STK DLOG P Log K1 tie in for+2'correction, PUW=29K 18:54 20:24 1.50 7,280 8,199 PROD4 STK TRIP P Continue in well, Displace out KWF to 9.4PPG FloPro 20:24 22:06 1.70 8,199 8,201 PROD4 STK KOST P Dry tag billet @ 8199, PUH, Start time milling @ 8198, 1.47 BPM @ 3815 PSI FS, BHP=4030 22:06 23:06 1.00 8,201 8,225 PROD4 DRILL DRLG P Start drilling 10-20FPH to 8208 then drill normaly, 1.48 BPM @ 3815 PSI FS, BHP=4020 23:06 23:12 0.10 8,225 8,225 PROD4 DRILL WPRT P 8225 pull wiper up past billet-clean. PUW=27K 23:12 00:00 0.80 8,225 8,280 PROD4 DRILL DRLG P 8225', Drill, 1.49 BPM @ 3790 PSI FS, BHP=4030 Midnight depth 8280 32/25/2015 Drill 8280 to 9142. Swap mud. Encountered HRZ 9010 to 9040 Page 12 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:54 4.90 8,280 8,410 PROD4 DRILL DRLG P 8280', Drill, 1.47 BPM @ 3790 PSI FS, BHP=4038 04:54 05:39 0.75 8,410 8,410 PROD4 DRILL WPRT P Wiper to 7900, PUW=27K, RIW 13k 05:39 08:57 3.30 8,410 8,610 PROD4 DRILL DRLG P 8410ft, BOBD 1.53 bpm at 3600psi, BHP 4007,WHP 127, IA 92, OA 0 08:57 09:45 0.80 8,610 8,610 PROD4 DRILL WPRT P 8610ft,wiper up to 7860ft, PUW 27, RIW 13k 09:45 13:15 3.50 8,610 8,810 PROD4 DRILL DRLG P 8610', Drill, 1.44 BPM @ 3665 PSI FS, BHP=4088 13:15 13:51 0.60 8,810 7,510 PROD4 DRILL WPRT P 8810ft.wiper up fora tie in, PUW 28k "***Note: New mud at the bit 8785ft, Previous mud stats: Drilled footage 1863ft,with 0.9%drill solids 13:51 14:03 0.20 7,510 7,590 PROD4 DRILL WPRT P 7510ft,jet up to tubing tail pumping full rate 3650psi. RBIH to tie in to RA 14:03 14:09 0.10 7,590 7,611 PROD4 DRILL DLOG P 7590ft,Tie into the RA marker correction of plus 2.0ft. 14:09 14:45 0.60 7,608 8,810 PROD4 DRILL WPRT P 7608ft, Continue wiper in hole, RIW 13k 14:45 19:03 4.30 8,810 9,010 PROD4 DRILL DRLG P 8810ft, BOBD 1.53 bpm at 3650psi, BHP 4051,WHP 128, IA 4, OA 0 19:03 20:03 1.00 9,010 9,010 PROD4 DRILL WPRT P 9010 Wiper to 8210, PUW=27K 20:03 23:15 3.20 9,010 9,140 PROD4 DRILL DRLG P 9010', Drill, 1.49 BPM @ 3520PSI FS, BHP=4065, Opened hot zone 9010 to 9040 23:15 23:33 0.30 9,140 9,140 PROD4 DRILL WPRT P Low ROP,weight transfer down, pull BHA wiper, PUW=28K. Pulled heavy at 9060 with motor stall moving up. S/D pump continued up, pulled 32K to come through.brought pumps back up pulled up to 9000'. RBIH stacked out @ 9075 work through at reduced pump rate. 23:33 00:00 0.45 9,140 9,142 PROD4 DRILL DRLG P 9140', Drill 1.48 BPM @ 3520 PSI FS, BHP=4050, 32/26/2015 TD well @ 9400', Pump sweeps and circulate to surface. Tie in. RBIH and pump 9.4 PPG beaded liner from 9000'. Trip out. M/U L1-03 Liner Trip in and set @ 9400'.Trip out for drill by BHA 00:00 00:48 0.80 9,142 9,145 PROD4 DRILL DRLG P Drill ahead 1.48 BPM @ 3520 PSI FS, BHP=4050 00:48 00:54 0.10 9,145 9,145 PROD4 DRILL WPRT P Short wiper, stacking, PUW=28K 00:54 02:24 1.50 9,145 9,210 PROD4 DRILL DRLG P Drill, 1.48 BPM @ 3550 PSI FS, BHP=4055 02:24 03:24 1.00 9,210 9,210 PROD4 DRILL WPRT P 9210,Wiper to 8300', PUW=28. Minimal bobbles at 9075 to 9010, Stacked out on way back in @ 9025. Reduce pump and worked right through 03:24 07:24 4.00 9,210 9,400 PROD4 DRILL DRLG P 9210', Drill, 1.49 BPM @ 3560 PSI FS, BHP=4075 Page 13 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:24 09:24 2.00 9,400 7,590 PROD4 DRILL WPRT P 9400ft,TD AL1-03 lateral at 9400ft, pump 10x10 sweep,Wiper up to the window,pull up to the tubing tail and perform a jog, RIH to lay in liner pill. 09:24 09:36 0.20 7,590 7,610 PROD4 DRILL DLOG P Log Ra for+2'correction 09:36 10:42 1.10 7,610 9,000 PROD4 DRILL WPRT P RIH to lay in liner running pill from 9000' 10:42 12:54 2.20 9,000 97 PROD4 DRILL TRIP P Trip out laying in 9.4 PPG beaded liner running pill, Paint EOP flags @ 7800'and 5900'. Get to surface, 12:54 14:24 1.50 97 0 PROD4 DRILL PULD P At surface, PJSM, Close downhole HAL valve. Monitor No Flow. Lay down BHA#12 ****Note: Close DHLV WHP 670psi, 14:24 18:00 3.60 0 1,543 COMPZ CASING PUTB P PJSM, R/U floor for liner running, M/U BHA#13 with Non ported bullnose,47 jts CS511 slotted liner and aluiminum liner top billet. 18:00 19:06 1.10 1,543 1,543 COMPZ CASING PULD P Crew change, PJSM, M/U Injector to liner and surface test,tag up and set counters, Open downhole HAL valve ****Note: Pressure up to 550psi, Open DHLV,WHP 425psi. 19:06 20:54 1.80 1,543 7,443 COMPZ CASING RUNL P RIH BHA#13, EDC closed,pump min rate 20:54 21:00 0.10 7,443 7,443 COMPZ CASING DLOG P At 5900' EOP flag for no correction. PUW=28.5K 21:00 21:30 0.50 7,443 8,725 COMPZ CASING RUNL P Continue in with liner 21:30 21:36 0.10 8,725 8,745 COMPZ CASING DLOG P Log K1 for+2'correction 21:36 22:06 0.50 8,745 9,400 COMPZ CASING RUNL P Continue in with liner,Tag bottom, Weight check 26.5, set back down. Pump off liner, PUW=23.3K, PUH and reset counters to remove liner left in hole 22:06 23:48 1.70 7,870 68 COMPZ CASING TRIP P Trip out after setting liner 23:48 00:00 0.20 68 68 COMPZ CASING PULD P At surface, PJSM,Shut HAL valve. Observe for flow 32/27/2015 At surface with BHA 13 still have liner. M/U BHA 14 with new GS Spear and liner top billet.Trip in unable to release liner. Trip out and run BHA#15 OH anchor billet with same 47 jts liner. Set @ 9400,TOL=7899,Trip in with drilling BHA#16 00:00 00:42 0.70 68 0 COMPZ CASING PULD P Good no flow. Lift injector. Measure wIl thickness. .119, 3'up from CTC, .123, 8'above CTC. Lay down BHA #13 Liner running tools 00:42 04:30 3.80 0 0 COMPZ CASING PULD T Liner still on BHA, Billet damaged pulling out GS spear. New billet coming from Deadhorse Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:18 0.80 0 1,543 COMPZ CASING PULD T Billet on location, PJSM, remove safey joint, M/U new GS to coil track stab into billet. M/U to top of liner. M/U to coil trak and surface test. Strip on injector. Pressure up and open HAL valve. 05:18 07:18 2.00 1,543 7,444 COMPZ CASING RUNL T RIH, EDC shut, Min rate 07:18 07:33 0.25 7,444 7,444 COMPZ CASING RUNL T Correct to the EOP flag minus 1.16ft, _ _ PUW 27.5k 07:33 08:33 1.00 7,444 9,400 COMPZ CASING RUNL T Continue RIH,tagged bottom at 9400ft, PUW 27.5k, DHWOB 7.6k, SOW 4.0k, bring pump online at 1.65 bpm with 1.55 bpm returns, PUW 28k, looks like we lost 3.6k,after pulling up hole further DHWOB indicated liner still attached at minus 6k. Discussed with town on plan forward. 08:33 10:33 2.00 9,400 44 COMPZ CASING TRIP T 7435ft bit depth, POOH to EOP flag at 5900ft, perform weight check, PUW 26k,talked with town,decision POOH to see if liner is still there. 10:33 11:03 0.50 44 44 COMPZ CASING SFTY T At surface,WHP 600, close DHLV, perform flow check, PJSM for possibly having liner on BHA. 11:03 12:33 1.50 44 0 COMPZ CASING PULD T Visually Inspect BHI tools, LD BHA# _ 14, Liner at surface 12:33 15:03 2.50 0 0 COMPZ CASING PULD T PJSM, PT coil connector 4000 psi, BHI tools 2100 psi,good test, confir with town team 15:03 16:48 1.75 0 1,562 COMPZ CASING PULD T MU BHA 15,Anchored billet,47jts slotted liner, and solid bullnose. Make up BHI tools with HOT. Stab on to liner and attach coil.Surface test tool 16:48 19:18 2.50 1,562 8,740 COMPZ CASING RUNL T RIH, Stop and close EDC @7463 19:18 19:24 0.10 8,740 9,400 COMPZ CASING DLOG T Log K1 for+2' 19:24 19:42 0.30 9,400 9,400 COMPZ CASING RUNL T Continue trip in hole,Tag bottom @ 9400', Oriented to HS, bring pumps online and see tool shift @ 4400psi. 1K increase on DHWOB. Set down 3K. Looks good 19:42 21:18 1.60 9,400 55 COMPZ CASING TRIP T Trip ouit 21:18 21:48 0.50 55 55 COMPZ CASING PULD T At surface, PJSM, Close HAL Valve, bleed off and check for flow 21:48 22:12 0.40 55 0 COMPZ CASING PULD T Break off injector lay down BHA#15 Liner running tools. 22:12 23:24 1.20 0 72 PROD5 STK PULD P Reconfig BHA,M/U BHA#16 with .7°Motor and rerun bi center, M/U to coil and surface test tool. Equilize across HAL valve and open 23:24 00:00 0.60 72 553 PROD5 STK TRIP P RIH, EDC closed, pump min rate )2/28/2015 Kicked off of billet at 7898ft,drilled from 7898ft to 8510ft, POOH to the casing to wait on weather(Phase 3) 90 mph wind Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:12 1.20 553 7,255 PROD5 STK TRIP P Continue trip in to drill 01:12 01:18 0.10 7,255 7,274 PROD5 STK DLOG P Log K1 for+2.5'correction 01:18 01:36 0.30 7,274 7,899 PROD5 STK TRIP P Continue in, clean pass through window, Dry tag billet @ 7899 01:36 03:54 2.30 7,899 7,908 PRODS STK KOST P Dry tag billet @ 7899, PUH, PUW=25K. Pumps on 1.5 BPM @ 3675 PSI FS, BHP=3960. Start time milling @ 7898 03:54 04:18 0.40 7,908 7,930 PRODS DRILL DRLG P 7908', Drill ahead, 1.5BPM @ 3675PSI FS, BHP=3941 04:18 04:30 0.20 7,930 7,930 PRODS DRILL WPRT P Wiper trip past billet, PUW=25K, Clean up and down 04:30 06:45 2.25 7,930 8,110 PROD5 DRILL DRLG P 7930', Drill, 1.5BPM @ 3675 PSi FS, BHP=3935, RIW=11.9K with.8K DHWOB, 06:45 07:15 0.50 8,110 8,110 PRODS DRILL WPRT P 8110ft,wiper up hole to 7650ft PUW 25k 07:15 09:30 2.25 8,110 8,310 PRODS DRILL DRLG P 8110ft, BOBD 1.5 bpm at 3676psi, BHP 4012,WHP 0, IA 22, OA 0 **"*Note:We were behind on turn pushed on it to achieve turn that we needed,exceeding 150 fph DHWOB 600 lbs to 223 fph DHWOB 1.1k, alert town. 09:30 10:30 1.00 8,310 8,310 PRODS DRILL WPRT P 8310ft,wiper up hole 7660ft, PUW 26k, RIW 14k 10:30 10:54 0.40 8,310 8,360 PROD5 DRILL DRLG P 8310ft, BOBD 1.5 bpm at 3600 psi, BHP 4020,WHP 0, IA 16,OA 0 ****Note: Drilling ROP 200+fph, WOB 1.3k 10:54 11:21 0.45 8,360 8,360 PRODS DRILL WPRT P 8360ft,wiper up hole 7660ft. PUW 26k, RIW 13.5k 11:21 11:51 0.50 8,360 8,410 PRODS DRILL DRLG P 8360ft, BOBD 1.5 bpm at 3600 psi, BHP 3977,WHP 0, IA 37, OA 0 11:51 12:15 0.40 8,410 8,410 PRODS DRILL WPRT P 8410ft,wiper up hole to 7970ft, PUW 26k, 12:15 15:15 3.00 8,410 8,510 PRODS DRILL DRLG P 8410ft, BOBD 1.5 bpm at 3500 psi, BHP 3952,WHP 0, IA 81, OA 0, 15:15 16:00 0.75 8,510 7,507 PRODS DRILL WPRT P 8510ft,wiper up hole into casing for tie in, PUW 26k 16:00 16:18 0.30 7,507 7,590 PROD5 DRILL WPRT P 7507ft, Perform jog up to the tubing tail, RBIH 16:18 16:33 0.25 7,590 7,616 PRODS DRILL DLOG P 7590ft,tie into the RA marker correction of plus 2.0ft 16:33 17:03 0.50 7,616 8,425 PRODS DRILL WPRT P 7616ft, continue wiper in hole, RIW 13k 17:03 17:33 0.50 8,425 7,530 PRODS DRILL TRIP T 8425ft, POOH to the casing due to PHASE 3 weather conditions. pump 5x56 sweep. 17:33 18:33 1.00 7,530 7,507 PRODS DRILL TRIP T 7530ft, Pull up to the tubing tail and perform jog,to clean the 5-1/2" section before pulling through tubing tail. 18:33 00:00 5.45 7,507 6,830 PRODS DRILL CIRC T Circulating at min rate,slowly moving coil up hole at 2fph. 33/01/2015 Wait on Phase 3 _^_ Page 16 of 18 J Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment • 00:00 00:00 24.00 6,830 6,000 PROD5 DRILL CIRC T Circulating in the tubing waiting on weather. 03/02/2015 Wait on Phase 3, Off phase three drill and wipe to early TD @ 8912, Condition hole, Pump beaded liner running pill.Trip out and make up BHA#17 L1-04 completion 00:00 06:39 6.66 6,000 6,270 PROD5 DRILL CIRC T In cased hole circulating, Still Phase 3 06:39 06:59 0.34 6,270 7,250 PROD5 DRILL TRIP P 6270ft, RIH 06:59 07:14 0.25 7,250 7,250 PROD5 DRILL DLOG P 7250ft,tie into the K1 marker corrction of plus 3.5ft. PUW 25k 07:14 07:53 0.65 7,250 8,510 PROD5 DRILL TRIP P 7250ft,Continue RIH to bottom 07:53 10:53 3.00 8,510 8,710 PROD5 DRILL TRIP P 8510ft, BOBD 1.5 bpm at 3760psi, BHP 4019,WHP 0, IA 0, OA 0 10:53 11:53 1.00 8,710 8,710 PROD5 DRILL WPRT P 8710ft,wiper up hole to 7950ft, PUW 25k 11:53 13:44 1.85 8,710 8,910 PROD5 DRILL DRLG P 8710ft, BOBD 1.5 bpm at 3600psi, BHP 4050,WHP 0, IA 0, OA 0 13:44 15:14 1.50 8,910 7,516 PROD5 DRILL WPRT P 8910ft,wiper up hole, PUW 26k 15:14 15:44 0.50 7,516 7,590 PROD5 DRILL WPRT P 7516ft, Jog from tubing tail and TOWS 15:44 15:59 0.25 7,590 7,590 PROD5 DRILL DLOG P 7590ft,tie into the RA correction of plus 2.5ft. 15:59 16:32 0.55 7,590 8,912 PROD5 DRILL WPRT P 7590ft,Wiper back in hole, RIW 11k 16:32 17:23 0.85 8,912 7,372 PROD5 DRILL WPRT P 8912ft, Confirm TD, POOH laying in 9,4ppg beaded pill with beads 17:23 18:53 1.50 7,372 72 PROD5 DRILL TRIP P POOH, painting EOP flags at 7300ft _ and 6000ft. 18:53 19:08 0.25 72 72 PROD5 DRILL TRIP P At surface close DHLV, PJSM for LD BHA. --- _ WHP 670, 19:08 20:23 1.25 72 0 PROD5 DRILL PULD P PJSM, LD drilling BHA#16 20:23 21:23 1.00 0 0 COMPZ CASING PUTB P PJSM, prep rig floor 21:23 23:59 2.60 0 1,390 COMPZ CASING PUTB P Start MU L1-04 liner of 44jts of 2-3/8", Hyd 511,slotted 03/03/2015 Ran L1-04 lateral assembly to 8,912', relaese from liner, TOL @ 7,500'. PUH to 7,487'swap well to seawater. TOOH. Freeze protect with diesel from 2,500'. Install BPV, load and secure wellhead with methanol. RDMO CDR2. 00:00 00:45 0.75 1,390 1,457 COMPZ CASING PUTB P M/U liner to coil track, M/U to coil and surface test tool. Strip on injector, Bump up and set counters. Equalize well and open HAL valve 00:45 02:24 1.65 1,457 7,455 COMPZ CASING RUNL P Trip in hole with BHA#17 02:24 02:30 0.10 7,455 7,457 COMPZ CASING DLOG P At 6000' EOP flag correct-1.5, PUW=28K, Continue trip in 02:30 03:06 0.60 7,457 8,912 COMPZ CASING RUNL P Continue in with liner 03:06 03:18 0.20 8,912 7,488 COMPZ CASING TRIP P Tag up on bottom, PUW=28K, Set back down, pump on at 1.5 BPM, PUW=24K, PUH, remove counter lengths from counter, 03:18 04:00 0.70 7,488 7,487 DEMOB WHDBO DISP P Open EDC, roll hole to seawater __.- ______ Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment • 04:00 04:54 0.90 7,487 2,500 DEMOB WHDBO DISP P Tripping out,stop and do weight check @ 7456, PUW=23K, Continue out 04:54 06:24 1.50 2,500 51 DEMOB WHDBO DISP P LRS on location, PJSM, Pump 30 BBIs diesel in coil 06:24 07:24 1.00 51 51 DEMOB WHDBO DISP P At surface, PJSM Close DHLV 07:24 08:42 1.30 51 0 DEMOB WHDBO RURD P Break off injector, Blow down/Lay down tool 08:42 11:00 2.30 0 0 DEMOB WHDBO MPSP P PSJM Get BPV lubricator to floor, R/U and set BPV 11:00 13:00 2.00 0 0 DEMOB WHDBO RURD P Pump 30 flush folled by 30 BBI inhibitor, pump 30 flush. Circ through BOPE and rig lines 13:00 15:00 2.00 0 0 DEMOB WHDBO RURD P PJSM, Blow down coil and surface lines, bleed off pressure 15:00 16:30 1.50 0 0 DEMOB WHDBO RURD P Blow down steam,secure reel and injector 16:30 17:30 1.00 0 0 DEMOB WHDBO RURD P PJSM, MOB pit sub out for access to 30-12 17:30 22:30 5.00 0 0 DEMOB WHDBO NUND P Crew change. ND BOP stack, secure stack. Secure wellhead, check all tree flange bolts,found three total bolts not tight,took 45 minutes, load tree with methanol. While ASRC installs tree valves on 30-12. 22:30 00:00 1.50 0 0 DEMOB WHDBO NUND P PJSM with Peak crew. Pull rig sub from 30-13. Phase II weather conditions. Rig released at 24:00 on 03/03/15 Page 18 of 18 /ZN O. I O CO O 0- w OC I— >, co z > ._. O. cn L • MEM O aa > L T O °' i 0 V O G L. 4.1 • N O ■Y .Y N L s O C E ■_ L L M C7 LI V O a a o c3 w V Y Y Pi) F co 0 0 r IIIIII UI z ::—N a_ N Lo W� ry Ln o CO Li; w M N O a, N C m w u) u) 1 O g� N V F y a1 O O O c fo p N S--`' u) N CON _ N 7 o W W N Q II u o ? 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V .0c >, 2 V O 0) OOm OOm OOOOOOOOOdO O O O O OCONV E d NU) 0 0. m 0 0 RECEIVED Mai 05 2015Letter of Transmittal AoGcc, BAKER Date: March 4, 2015 HUGHES To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3 -13 •_ _ ..• 30-13L1-01 30-13L1-01 215-010 254.9 30-13L1-02 30-13L1702 215-011 254 0 30-13L1-03 30-13L1-03 215-013 25471 30-13L1-04 30-13L1-04 215-014 25472 (5) Totalprints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com _ __ h Q) ® to Ln v-7 in Ill N Nill ,. y tW, `gm a= m N > ,-', 8 . ...... _ . W g 0 v W � Q a CC co 0 a wW a i— ,, Q. C Z ._ a . ._ _ - co o CL -g V O L ' � d M > To t+ in (, O i c N C OYYTN N = O i V � LMc) � � L O as - C co /1 2 V Y Yci) inm 0 0 i 1 w Z o) i S -o , cf., O all N o m io �b V CO N O w O �� + N C m ; $ $3 CO in O }} N d F y O O o I ,,ca N N O I v a N_ "y N W N N Q :i1 . LL.1CL i8 O 3 I s s i , O o V c r CO CO i V o N d p N N 1 N Z N N N 7 COW V CO N1 i d iN CO r N N is J C r m 7 , E 333 , 1 C U 1 0 , U N Gr. 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N I- h 10 V 10 pN N 10 V M M co O idN O O N O cD o0) N 100 CD O 7 Or O D CD 8 N 10 CD O O O M (NO O C C m O M cti C ` ❑ 0 V 10 N 10 N N N N 1� CD n CO N CO CO m m m O O O N (p U 0 C T 2 V m Oi O) Oi o) Di of Oi Di W of m W Di of m Oi Di O O O O O C r U E .a _ a rn cu 0 o ,d d m 7 U d U) ❑ Cl) OF y 77-4, w\����VP/ THE sA THE STATE Alaska Oil and Gas '� Conservation Commission M ofALAS� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 P Main: 907,279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-13L1-01 ConocoPhillips Alaska, Inc. Permit No: 215-010 Surface Location: 1041' FNL, 2024' FWL, SEC. 22, T13N, R9E, UM Bottomhole Location: 1173' FSL, 309' FEL, SEC. 21, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 188-040, API No. 50-029- 21803-00-00. 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, (00#L Cathy . Foerster Chair DATED this GT day of January, 2015. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION „D JM 14 2015 PERMIT TO DRILL ���� 20 AAC 25.005 la Type of Work lb Proposed Well Class Development-Oil Q Service-Winj ❑ .Single Zone Q lc Specify if well is proposed for: Drill ❑ . Lateral 111 Stratigraphic Test❑ Development-Gas El Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name. 5 Bond1_I Blanket ❑Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. . Bond No. 59-52-180' KRU 30-13L1-01 3 Address: 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10270' . TVD: 6552'- Kuparuk River Field 4a. Location of Well(Governmental Section) 7 Property Designation(Lease Number) Surface. 1041'FNL,2024'FWL,Sec 22,T13N, R9E, UM • ADL 25513 - Kuparuk Oil Pool Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date: 733'FSL,754'FWL,Sec.22,T13N, R9E, UM 2554 2/2/2015 Total Depth 9.Acres in Property 14.Distance to 1173'FSL, 309'FEL,Sec.21,T13N, R9E, UM 2560 ' Nearest Property. 3500' 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL' 59 feet 15 Distance to Nearest Well Open Surface:x- 525661 y- 6021779 Zone- 4 • GL Elevation above MSL 24 feet to Same Pool 30-16,380' 16 Deviated wells Kickoff depth' V 9500 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle , 95° deg Downhole:4245 psig + Surface:3592 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 1150' 9120' 6561' 10270' 6501' 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) 7950' 6901' none 7832 6803 none Casing Length Size Cement Volume MD TVD Conductor/Structural 74' 16" 175 sx AS I 110' 110' Surface 4305' 9.625" 1500 sx AS III,300 sx CI G 4340' 4046' 85 sx AS I Liner Production 7882' 7" 395 sx Class G, 175 sx AS I 7915' 6872' Perforation Depth MD(ft). Perforation Depth TVD(ft): 7612'-7668', 7680'-7700' 6620'-6667', 6677-6693' 20 Attachments: Property Plat❑ BOP Sketch❑ Drilling Prograrr ❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑.r 21 Verbal Approval Commission Representative Date 1/(l4 f 67.0/5- 22 I hereby certify that the foregoing is true and correct Contact Cody Pohler @ 265-6435 C)9 Email Cody.J.Pohler@cop corn Printed Name VII. hau Title CTD Engineering Supervisor Signature Phone:263-4372 Date ///17--// S Commission Use Only Permit to Drill API Number: Permit Approv I / See cover letter Number. a/' 0)0 50-oaq- DI go3-62/-ov Date t 30 I t for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbem thane,gas hydrates,or gas contained in shales. d Other: BO 7`-‘15t 7`aO DCJ r�S r Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No Er f}-{-}vr tr.'a v ytr-z'vic err frs 71- H2S measures: Yes No r❑ LJ Directional svy req'd: Yes No❑ 25-60 /95 , Spacing exception req'd: Yes ❑ No Ir I Inclination-only svy req'd: Yes❑ No 0 / APPROVED BY THE ^ Approved by M Y-�COMMISSIONER COMMISSION Date 7 l Form 10-401 (Re sed 10/2012) This permit is valid for 24 months from the date o I 5 ) 7i 2 1121 r l VIL !/Z7-/« m4, / /-6 ���(i- `/ • ConocoPhillips • - • • • • RECEIVED • Alaska JAN 14 2015 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC January 14, 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 permits to drill a penta-lateral out of the Kuparuk Well 30-13 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin February 2015. The CTD objective will be to drill five laterals(30-13L1, 30- 13L1-01, 30-13L1-02, 30-13L1-03, 30-13L1-04), targeting the A sand intervals. Note the current A sand perforations are still open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 30-13L1, 30-13L1-01, 30-13L1-02, 30-13L1-03, 30-13L1- 04 — Detailed Summary of Operations — Directional Plans — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6435. Sincerely, a ���r i/ Cody Pohler Coiled Tubing Drilling Engineer r c- 1` O D C 0 N N 0 CO - — CO 1..0 C NE D D 0 ,:t. _ �F c-I 0In U s- rn co v 1` 0 Ln co M C ,: N co t` 0 2 _ co N m m u) m 2 a 71- rn N �n o -a D 0 Y rn Q. tol"I I` O O 2 2 U d- `' ti co Q. .Ni _ CO O.. 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C a m a m a _ CO d r o g o ❑ 3 0 u) N -O -O c H = > =M `-_ co 0 a o rn a m o 4 CO CO` N > N~ N O_ U C CO O V N co } rn m of6 m o• Z -0 O No' Q� 2 W 2 .O 2f`-) N m= C d rAl a.0 O0w ( JH .Q J U J 0 0 N d N 7 J 1—J f i.-. c0 c'7 N O c0❑ CO p m N0)0) - -_ i ❑ ai U t U� (� co v _ m a Q N N N • N� O N N N NN N �'• .- '@ TY w ch M M = c`�(O W co m M o',-) y rn v . N C C Y a 81:2,6 (0 - b. C.i ,1m UN (0 C M Y f6 CC N- M CO N m 6 IX U ff0 p N O NC O ` 0 FO y N > V_0 o°'0 (Vaa U o'C C U co ipti • m MO CN U3. 0 pN O m llD c{yN .XL a h'- - N NQ •' CI) .Oa, -o ?em , i f' rs+ / 00o, jcDmQ i A Y'1 f -N x i 0 tiU. O /6-� 11 r1 s 1 a -. L____._,.___{,Ii....--(1 —nr—l' 1 ' 1 - AAId CL L 71 ®_0-78 1 *a)2 occ)oci a �❑ * o g `_°=v �wwww N °ci) a iv)2 Lo N O Co O (Jo 0(V IV LY'N. O> -0 h N ��.— iO tO� r-r- OO N ,_,_ NN Nr �_� ORIGINAL .CD Kuparuk CTD Laterals NABORS ALASKA ¢=' & 30-13L1, 30-13L1-01, 30-13L1-02, 30-13L1-03 DR & 30-13L1-04 2nc Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)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 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 30-13L1, L1-01, L1-02, L1-03, L1-04 7 Attachment 2: Current Well Schematic for 30-13 7 Attachment 3: Proposed Well Schematic for 30-13L1, L1-01, L1-02, L1-03, L1-04 7 z + GINAL Page 1 of 7 1/14/2015 PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed laterals described in this document are 30-13L1, 30-13L1-01, 30-13L1-02, 30-13L1-03 & 30- 13L1-04. All laterals will be classified as "Development— Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 30-13L1, 30-13L1-01, 30-13L1-02, 30-13L1-03 & 30-13L1-04. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Using the maximum formation pressure in the area of 4245 psi in the 30-17, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3592 psi.I See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The final mud weight used during the 30-13 rig work over in December 2014 was 9.6 ppg to kill the well. An updated pressure survey will be obtained on the Kuparuk A-sand only before Coiled Tubing Drilling operations begin. The maximum downhole pressure in the 30-13 pattern is to the south with the 30-17 injector at 4245 psi (12.4 ppg EMW) dating August, 2008. As the laterals are drilled we approach 30-16A which is the next higher pressure in the 30 area. Well 30-16A has a pressure of 4095 (12.1 ppg EMW) and is planned for CTD sidetrack additionally. Along with 30-16A being separated by a sealing fault, it is likely that the A-sand pressure in 30-17 will be not be seen in respect to the distance between 30-13 and 30-17, and 30-13 will not be drilling towards 30-17 Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Well 30-14 to the west injected MI (2012) however all planned laterals are to the east; no specific gas zones will be drilled. No gas injection has been performed near 30-16, so low probability of encountering gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 30-13 laterals will be shale instability across the faults, managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossing. 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 .j R I G I N A L 1/14/2015 PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 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 30-13L1 9,500' 10,270' 6,558' 6,524' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 30-13L1-01 9,120' 10,270' 6,561' 6,501' 2%" 4.7#, L-80, ST-L slotted liner; deployment sleeve on top 30-13L1-02 8,425' 10,270' 6,591' 6,501' 2%", 4.7#, L 80, ST-L slotted liner; deployment sleeve on top 30-13L1-03 7,850' 9,215' 6,592' 6,588' 2%", 4.7#, L 80, ST-L slotted liner; deployment sleeve on top 30-13L1-04 7,498' 9,200 6,469' 6,539' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 110' 31' 110' 1,640 630 Surface 9-5/8" 36 J-55 BTC 35' 4,340' 35' 4,047' 3,520 2,020 Production 7" 26.0 J-55 BTC 33' 7,915' 33' 6,872' 4,980 4330 Tubing 3-1/2" 9.3 L-80 EUE 33' 7,494' 33' 6,524' 10,160 10,530 Tubing Tail 5-1/2" 14 H-40 STC 7504' 7,550' 6,532' 6,569' 3,110 2,610 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based FloVis mud (9.8 ppg) - Drilling operations: Chloride-based FloVis mud (9.8 ppg).' While this mud weight may hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: Well 30-13 contains a new style deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes(-180 bbl)of 12.0 ppg NaBr emergency kill I weight fluid will be within a short drive to the rig during drilling operations. IGINAL Page 3 of 7 1/14/2015 4. PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 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 kicking out into the B shales turning southwest in A2 through a fault into upthrown Al, we plan to hold 11.8 ppg at the window for stability. 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 30-13 Window(7,564' MD,6,581'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.6 ppg) 3285 psi 3285 psi Mud Hydrostatic (9.8 ppg) 3354 psi 3354 psi Annular friction (i.e. ECD, 0.090 psi/ft) 681 psi 0 psi Mud + ECD Combined 4034 psi 3354 psi (no choke pressure) (overbalanced (overbalanced —749 psi) —69 psi) Target BHP at Window(11.8 ppg) 4039 psi 4039 psi Choke Pressure Required to Maintain Target BHP 5 psi 686 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. ORIGINAL Page4of7 1/14/2015 PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 30-13 is a Kuparuk A-sand injection well equipped with 3'/2"tubing and 7"production casing. A rig work-over was recently performed,replacing the existing tubing and packers with new 3-1/2"tubing with a 5-1/2""Big Tail Pipe"completion. Five laterals will be drilled to the south west of the parent well with the laterals targeting the different A sand lobes.These laterals will access reserves in the adjacent fault blocks targeting the A3,A2, and Al sands. A Baker Hughes Thru-Tubing whip-stock will be set inside the 5 '/2"big tail pipe at the planned kick off point of 7,564' MD. The 30-13L1 lateral will exit through the big tail pipe at 7564'MD and TD at 10,275' MD. L1 lateral will be completed with 2 3/8"slotted liner from TD up to 9500' MD with an aluminum billet for kicking off the 30-13L1-01 lateral. The 30-13L1-01 will drill to a TD of 10,270' MD,with the liner top at 9,120' MD. The 30-13L1-02 will drill to a TD of 10,270' MD,with the liner top at 8,425' MD. The 30-13L1-03 will drill to a TD of 9,200' MD,with the liner top at 7,498 MD.The 30-13L1-04 will drill to a TD of 9,200' MD,with the liner top at 7,498 MD; located inside the 3 '/2"tubing. Pre-CTD Work 1. RU Slickline: Dummy all gas lift valves and obtain a KRU A-sand SBHP. 2. RU E-line: Set Baker Hughes 3-1/2"x 5-1/2"Thru-Tubing Whipstock. 3. Prep site for Nabors CDR2-AC,including setting BPV. Ric,Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE, test. 2. 30-13L1 Lateral(A2 sand to south west) a. Mill 2.80"window at 7,564' MD. b. Drill 3"bi-center lateral to TD of 10,275' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9,500' MD. 3. 30-13L1-01 Lateral(Al sand) a. Kick off of the aluminum billet at 9,500' MD. b. Drill 3"bi-center lateral to TD of 10,270' MD. c. Run 2%" slotted liner from TD up to 9,120'MD 4. 30-13L1-02 Lateral(A4 sand) a. Kick off of the aluminum billet at 9,120' MD. b. Drill 3"bi-center lateral to TD of 10,270'MD. c. Run 2%"slotted liner from TD up to 8,425'MD 5. 30-13L1-03 Lateral(A3 sand) a. Kick off of the aluminum billet at 8,425' MD. b. Drill 3"bi-center lateral to TD of 9,200' MD. c. Run 2%"slotted liner from TD up to 7,850'MD 6. 30-13L1-04 Lateral(A4 sand) a. Kick off of the aluminum billet at 7,850' MD. b. Drill 3"bi-center lateral to TD of 9,200' MD. c. Run 2%"slotted liner from TD up to 7,498'MD, inside the tubing tail. RIGI \JAL Page5of7 1/14/2015 PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 7. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's(if needed). Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using 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 — The 30-13 well has a new down hole deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalancing fluid (12 ppg NaBr) prior to running liner. See"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). ORIGINAL Page 6 of 7 1/14/2015 PTD Application: 30-13L1, L1-01, L1-02, L1-03, L1-04 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 Distance 30-13L1 3500' 30-13L1-01 3500' 30-13L1-02 3500' 30-13L1-03 3500' 30-13L1-04 3500' — Distance to Nearest Well within Pool Lateral Name Distance Well 30-13L1 380' 30-16 30-13L1-01 380' 30-16 30-13L1-02 380' 30-16 30-13L1-03 1400' 30-16 30-13L1-04 1400' 30-16 16. Attachments Attachment 1: Directional Plans for 30-13L1, L1-01, L1-02, L1-03, L1-04 Attachment 2: Current Well Schematic for 30-13 Attachment 3: Proposed Well Schematic for 30-13L1, L1-01, L1-02, L1-03, L1-04 ` RILII\ AL Page7of7 1/14/2015 , 4 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-13 30-13L1-01 Plan: 30-13L1-01_wp02 Standard Planning Report 12 January, 2015 BAKER HUGHES ORIGINAL ri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-13 @ 59.00usft(30-13) Site: Kuparuk 30 Pad North Reference: True Well: 30-13 Survey Calculation Method: Minimum Curvature Wellbore: 30-13L1-01 Design: 30-13L1-01_wp02 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 70°28'17.333 N From: Map Easting: 525,478.25 usft Longitude: 149°47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.20° Well 30-13 Well Position +N/-S 0.00 usft Northing: 6,021,779.16 usft Latitude: 70°28'14.223 N +E/-W 0.00 usft Easting: 525,661.20 usft Longitude: 149°47'25.550 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-13L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 2/1/2015 19.01 81.01 57,582 Design 30-13L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,500.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 217.19 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (0) Target 9,500.00 95.14 297.30 6,557.86 -3,352.17 -1,618.29 0.00 0.00 0.00 0.00 9,570.00 92.68 293.06 6,553.08 -3,322.47 -1,681.47 7.00 -3.52 -6.07 240.00 9,690.00 90.20 285.03 6,550.06 -3,283.37 -1,794.77 7.00 -2.06 -6.69 253.00 9,750.00 90.13 280.83 6,549.89 -3,269.95 -1,853.23 7.00 -0.12 -7.00 269.00 9,880.00 89.81 289.92 6,549.96 -3,235.52 -1,978.45 7.00 -0.24 7.00 92.00 9,940.00 89.66 285.72 6,550.24 -3,217.16 -2,035.56 7.00 -0.24 -7.00 268.00 10,070.00 89.67 294.82 6,550.99 -3,172.16 -2,157.37 7.00 0.00 7.00 90.00 10,270.00 89.68 308.82 6,552.14 -3,066.96 -2,326.88 7.00 0.00 7.00 90.00 1/12/2015 7:31:56AM Page 2 COMPASS 5000 1 Build 61 ORIGINAL a L ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-13 @ 59.00usft(30-13) Site: Kuparuk 30 Pad North Reference: True Well: 30-13 Survey Calculation Method: Minimum Curvature Wellbore: 30-13L1-01 Design: 30-13L1-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 9,500.00 95.14 297.30 6,557.86 -3,352.17 -1,618.29 3,648.68 0.00 0.00 6,018,421.76 524,054.64 TIP/KOP 9,570.00 92.68 293.06 6,553.08 -3,322.47 -1,681.47 3,663.21 7.00 -120.00 6,018,451.24 523,991.36 Start 7 dls 9,600.00 92.06 291.05 6,551.84 -3,311.22 -1,709.25 3,671.04 7.00 -107.00 6,018,462.40 523,963.54 9,690.00 90.20 285.03 6,550.06 -3,283.37 -1,794.77 3,700.54 7.00 -107.08 6,018,489.95 523,877.94 3 9,700.00 90.19 284.33 6,550.03 -3,280.84 -1,804.44 3,704.37 7.00 -91.00 6,018,492.45 523,868.26 9,750.00 90.13 280.83 6,549.89 -3,269.95 -1,853.23 3,725.19 7.00 -91.00 6,018,503.16 523,819.43 4 9,800.00 90.01 284.33 6,549.83 -3,259.07 -1,902.03 3,746.01 7.00 92.00 6,018,513.88 523,770.61 9,880.00 89.81 289.92 6,549.96 -3,235.52 -1,978.45 3,773.44 7.00 92.00 6,018,537.16 523,694.11 6 9,900.00 89.76 288.52 6,550.04 -3,228.94 -1,997.33 3,779.61 7.00 -92.00 6,018,543.68 523,675.20 9,940.00 89.66 285.72 6,550.24 -3,217.16 -2,035.56 3,793.33 7.00 -91.99 6,018,555.32 523,636.95 6 10,000.00 89.67 289.92 6,550.59 -3,198.80 -2,092.66 3,813.22 7.00 90.00 6,018,573.48 523,579.78 10,070.00 89.67 294.82 6,550.99 -3,172.16 -2,157.37 3,831.11 7.00 89.98 6,018,599.89 523,514.99 7 10,100.00 89.67 296.92 6,551.17 -3,159.07 -2,184.36 3,837.00 7.00 90.00 6,018,612.89 523,487.95 10,200.00 89.67 303.92 6,551.74 -3,108.46 -2,270.54 3,848.77 7.00 89.99 6,018,663.20 523,401.61 10,270.00 89.68 308.82 6,552.14 -3,066.96 -2,326.88 3,849.76 7.00 89.95 6,018,704.50 523,345.13 Planned TD at 10270.00 1/12/2015 7:31:56AM Page 3 COMPASS 5000.1 Build 61 ORIGINAL 'iv r�r ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-13 @ 59.00usft(30-13) Site: Kuparuk 30 Pad North Reference: True Well: 30-13 Survey Calculation Method: Minimum Curvature Wellbore: 30-13L1-01 Design: 30-13 L 1-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (1 (1 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 30-13L1-01_T03 0.00 0.00 6,550.00 -7,413.111,138,150.97 6,018,290.00 1,663,718.00 70°12'52.633 N 140°34'53.332 W -plan misses target center by 1139776.50usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Point 30-13L1_Faultl 0.00 0.00 0.00 -7,641.271,139,641.34 6,018,067.00 1,665,209.00 70°12'48.209 N 140°34'11.624 W -plan misses target center by 1141286.53usft at 9500.00usft MD(6557.86 ND,-3352.17 N,-1618.29 E) -Rectangle(sides W395.00 H1.00 D0.00) 30-13L1-01_T01 0.00 0.00 6,558.00 -7,529.391,138,518.61 6,018,175.00 1,664,086.00 70°12'50.959 N 140°34'43.306 W -plan misses target center by 1140144.55usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Point 30-13 CTD Polygon 0.00 0.00 0.00 -7,109.881,139,834.20 6,018,599.00 1,665,400.00 70°12'53.082 N 140°34'3.772 W -plan misses target center by 1141477.51 usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Polygon Point 1 0.00 0.00 0.00 6,018,599.00 1,665,400.00 Point 2 0.00 -214.73 -84.74 6,018,384.00 1,665,316.01 Point 3 0.00 -353.09 -279.23 6,018,244.98 1,665,122.02 Point4 0.00 -418.07 -581.48 6,018,178.97 1,664,820.02 Point5 0.00 -365.35 -790.32 6,018,230.96 1,664,611.02 Point6 0.00 -248.72 -1,268.98 6,018,345.93 1,664,132.01 Point? 0.00 -115.50 -1,622.56 6,018,477.92 1,663,778.01 Point8 0.00 -6.72 -1,851.22 6,018,585.90 1,663,549.00 Point9 0.00 97.75 -1,985.88 6,018,689.89 1,663,413.99 Point 10 0.00 -144.48 -2,219.72 6,018,446.88 1,663,181.01 Point 11 0.00 -298.12 -2,036.23 6,018,293.89 1,663,365.01 Point 12 0.00 -435.13 -1,741.66 6,018,157.91 1,663,660.02 Point 13 0.00 -571.50 -1,343.08 6,018,022.93 1,664,059.03 Point 14 0.00 -722.12 -870.54 6,017,873.96 1,664,532.04 Point 15 0.00 -755.22 -547.62 6,017,841.97 1,664,855.04 Point 16 0.00 -697.96 -34.37 6,017,900.99 1,665,368.04 Point 17 0.00 -358.21 345.82 6,018,242.02 1,665,747.02 Point 18 0.00 16.66 396.10 6,018,617.02 1,665,796.00 Point 19 0.00 0.00 0.00 6,018,599.00 1,665,400.00 30-13L1-01_T04 0.00 0.00 6,551.00 -7,344.451,137,963.19 6,018,358.00 1,663,530.00 70°12'53.577 N 140°34'58.413 W -plan misses target center by 1139588.47usft at 9500.00usft MD(6557.86 ND,-3352.17 N,-1618.29 E) -Point 30-13L1_Fault3 0.00 0.00 0.00 -7,128.291,137,631.90 6,018,573.00 1,663,198.00 70°12'56.166 N 140°35'6.962 W -plan misses target center by 1139275.32usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Rectangle(sides W500.00 H1.00 D0.00) 30-13L1-01_T05 0.00 0.00 6,552.00 -7,243.91 1,137,809.52 6,018,458.00 1,663,376.00 70°12'54.781 N 140°35'2.378 W -plan misses target center by 1139434.45usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Point 30-13L1_Fault2 0.00 0.00 0.00 -7,616.021,138,699.33 6,018,089.00 1,664,267.00 70°12'49.851 N 140°34'38.506 W -plan misses target center by 1140344.45usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Rectangle(sides W345.00 H1.00 D0.00) 30-13L1-01_T02 0.00 0.00 6,550.00 -7,456.791,138,346.84 6,018,247.00 1,663,914.00 70°12'51.919 N 140°34'47.910 W -plan misses target center by 1139972.52usft at 9500.00usft MD(6557.86 TVD,-3352.17 N,-1618.29 E) -Point 1/12/2015 7:31 56AM Page 4 COMPASS 5000.1 Build 61 DRG1NALR 4. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-13 @ 59.00usft(30-13) Site: Kuparuk 30 Pad North Reference: True Well: 30-13 Survey Calculation Method: Minimum Curvature Wellbore: 30-13L1-01 Design: 30-13L1-01_wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,270.00 6,552.14 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,500.00 6,557.86 -3,352.17 -1,618.29 TIP/KOP 9,570.00 6,553.08 -3,322.47 -1,681.47 Start 7 dls 9,690.00 6,550.06 -3,283.37 -1,794.77 3 9,750.00 6,549.89 -3,269.95 -1,853.23 4 9,880.00 6,549.96 -3,235.52 -1,978.45 5 9,940.00 6,550.24 -3,217.16 -2,035.56 6 10,070.00 6,550.99 -3,172.16 -2,157.37 7 10,270.00 6,552.14 -3,066.96 -2,326.88 Planned TD at 10270.00 1/12/2015 7:31:56AM Page 5 COMPASS 5000.1 Build 61 DR ( GINAL 0S a 0 o, i- 48 o \- a 1 1 i ., , �' M b a ' dd 8 8 .0 0., -- 41 8 ov -� d 8 0 30-1 Ll II T01--j a In. n 'O� _ o T.T. e C R a A e/. 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M 6 J co CO co 0 000 CO N o 7- 1Eco toCO CCOCO COCOto 4 O l- v zN ¢co co IOlAA COCpD-coNNlA,CV CO CV pp �(z/]� CD c0 N pP.,CNI Cs!ggj NNO p§ 8 �� C.�--CON W CO CO-c0 0l )k-ioim- 0 p6psps p�pg8.8 mm p iI M +0 °0 0 0 0 0 0 0 0 O O O O 0O O O8 p .... - N , m 8rC JM i y i , , , , 31� ,0 U,-CV M,t 41 CO D-CO M f 0 wN (uI/{usn OZ)q;dad F0P-10A ani', V ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-13 30-13L1-01 30-13L1-01_wp02 Travelling Cylinder Report 09 January, 2015 BAKER HUGHES ORIGINAL t" .- Baker Hughes INTEQ Inr"-- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-13 Project: Kuparuk River Unit TVD Reference: 30-13 @ 59.00usft(30-13) Reference Site: Kuparuk 30 Pad MD Reference: 30-13 @ 59.00usft(30-13) Site Error: 0.00usft North Reference: True Reference Well: 30-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-13L1-01 Database: OAKEDMP2 Reference Design: 30-13L1-01_wp02 Offset TVD Reference: Offset Datum Reference 30-13L1-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,500.00 to 10,270.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,221.10usft Error Surface: Elliptical Conic Survey Tool Program Date 1/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,500.00 30-13(30-13) GCT-MS Schlumberger GCT multishot 7,500.00 9,500.00 30-13L1_wp07(30-13L1) MWD MWD-Standard 9,500.00 10,270.00 30-13L1-01_wp02(30-13L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,270.00 6,611.14 2 3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/9/2015 9:20:12AM Page 2 of 6 COMPASS 5000.1 Build 65 .D R 1 INA L • �` ✓ Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-13 Project: Kuparuk River Unit TVD Reference: 30-13 @ 59.00usft(30-13) Reference Site: Kuparuk 30 Pad MD Reference: 30-13 @ 59.00usft(30-13) Site Error: 0.00usft North Reference: True Reference Well: 30-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-13L1-01 Database: OAKEDMP2 Reference Design: 30-13L1-01_wp02 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 30 Pad 30-01-30-01-30-01 Out of range 30-02-30-02-30-02 Out of range 30-02-30-02A-30-02A Out of range 30-02-30-02AL1-30-02AL1 Out of range 30-02-30-02AL1 PB1-30-02AL1 PB1 Out of range 30-02-30-02AL2-30-02AL2 Out of range 30-02-30-02AL2-01-30-02AL2-01 Out of range 30-03-30-03-30-03 Out of range 30-04-30-04-30-04 Out of range 30-05-30-05-30-05 Out of range 30-06-30-06-30-06 Out of range 30-07-30-07-30-07 Out of range 30-08-30-08-30-08 Out of range 30-09-30-09-30-09 Out of range 30-10-30-10-30-10 Out of range 30-11-30-11-30-11 Out of range 30-12-30-12-30-12 Out of range 30-12-30-12L1-30-12L1_wp07 Out of range 30-13-30-13-30-13 Out of range 30-13-30-13L1-30-13L1_wp07 9,500.00 9,500.00 0.00 0.28 -0.22 FAIL-Minor 1/10 30-13-30-13L1-02-30-13L1-02_wp02 10,146.18 10,150.00 50.85 0.32 50.63 Pass-Minor 1/10 30-13-30-13L1-03-30-13L1-03_wp02 Out of range 30-13-30-13L1-04-30-13L1-04_wp03 Out of range 30-14-30-14-30-14 Out of range 30-15-30-15-30-15 Out of range 30-16-30-16-30-16 Out of range 30-16-30-16A-30-16A Out of range 30-17-30-17-30-17 Out of range 30-18-30-18-30-18 Out of range 30-19-30-19-30-19 Out of range 30-20-30-20-30-20 Out of range Plan:DHH-01-Plan:DHH-01-DHH-01wp01 Out of range Plan:DHH-02-Plan:DHH-02-DHH-02wp01 Out of range Kuparuk UGNU Plan:UGNU SAGD-UGNU SAGD-UGNU SAGD Out of range UGNU DS2-061-UGNU DS2-0B1-UGNU DS2- Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/9/2015 9:20.12AM Page 3 of 6 COMPASS 5000.1 Build 65 ORIGINAL • 1 Eli Z 4 _..- 4 - q N r. 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TRANSMITTAL LETTER CHECKLIST WELL NAME: Kik U` 3 0 - I N,( - d l PTD: /Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: �� kvLf- POOL: K / 4( Ku1/4/J2,N 0' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER /MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. )88— 0'10 , API No. 50- O.Zq - 2.1$03 -00 - Ob . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation 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 Well Logging also required for this well: gg g 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 4/2014 J 'r] N 0) a N N c: N C (0 3 c . m a m > c, H W c '� � •as � E. : : ❑ 0 O .a C E O Z _' N 0 E m 1 f6' a : :', 3 co E O -c 3 c, a ay ° j 6 -a - ' > U cD N = a) 3 : • a o. c 3 m. `o , a LL: a • 75 J L...., C E, 0 aN: 00. '� �� 0. O �, • v,' umi O co a .y .0 O Ocd Wpca a o; ; . W> Ea � a H OU , la oa Ea o ° > d Q Ca C , a): , 2 N, N, V ,< E 0 a Yto E N �: cOd v' Eorn aoM o N G N �, Q. 0. ar ca p �: m. 3 E �: v) N: w G. 3, w : a. v) r M v �. N a: v: a vJ: �, dY' ca: 0 .- c 3, m ca, N m, a. 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