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Home My WebLink About212-027 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. ,°z_ic,1 - 0 a7 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: deM Date: (00//9„, /s/ VII p Project Proofing BY: ACM Date: q !61/Lk /s/ re— M Scanning Preparation ta, x 30 = (00 + = TOTAL PAGES &‘.-5— (Count does not include cover sheet) AI BY: AZIM Date: AP / /s/ Production Scanning Stage 1 Page Count from Scanned File: 10 ll/ (Count does include cover sh ) Page Count Matches Number in Scanning Preparation: ES rN�OA BY: AV Date: i 'qi /s/ r 4/1Stag1 If NO in stage 1, page(s) discrepancies wound: 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 c 0 mi. 2 T 1 a� Z co Z 0 co j (a U N — O (/� O L Er_ TO O- O } y co U (� (� (, I.D. c m E 7300 CC E E c + to to <na Q a C O) 2 O J 2 2 O O U O Z D a 0 O. _ U cecea � _ OU 2 2 P 2 5 0 0 O O jN NNNN N ICI d NJ N Oo) o N NNNN N N 1 5 y co co 1 O i J V ,- ,- V V a M ,- ;35 SZ CCCC Q = x a a 0) 0) a a EoF"' Y OU OO O O O 0 IX Q EcaU d o O. v v CON a O) O d Z Z 0CL n N 1 w co CO co CO y e10:9 11 1 Na .5 c^o rn 0 CD aoo 0 N Z cc U V) CO-4- CO COC) Oo too o o v W °zlo > J N VO > u U O N O �' ° a cC ca. o s F- 1 Q OS r) = . zIIS N O I coa i M O =O ZI 1 J CD IO 2U U U N LL O a) 0 m Ti. i N E a p o N 121 Vn U CO N � N U cn JN Q N F- W a F- N w H N C Z N To Z CCI re r r CO � M C C v/ co N cc a o I YO Q o ZI u) w . .>. CI d U O N N N N Z E co -J O) N N 0 co (n Z 7 N y i O) O O O O p N co z co 1 ce Z c c c c O r 1 cn co 1 — E Z g O 1- , ...I s.. 0 .0 cc) a 1674) 1 i NI- O W 0 2 N O OQ - OS r a y LL c.. •` Z G N N O coEJ > LI LO O O c rnv Q w cn Z Q y ao Z W J ` ` U `p U d E y > E E Q w `p CI H fl Tyj= rn.� a p rn rn rn ad : 3 W J J J Q: W 0 Q R 0 a O v m I- to 00 Z N N C) 0 N 5 0 Lo 0 z a Q 0=114 J 0 Z_ 7 ai I .�/ is I Lf J co • co O Q O u a v O. J W = oc a 0 0 W Z U c0.) o Z Q . .. Ti O co a. L M o O N E%-1 o- 0 Uer N 0 J m Q a N E.. W ` r 1 N 2 z N M • r W r CON _I Ce Q ro CI ICC a Y a 5 o a Z p d 0 E II) Z m N LO N CO N > m O I— 'a N 3 N a) d a• in V 2 co a Ts. y 0 o a 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil O Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test El 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 13,2012 212-027/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 February 28,2012 50-029-20857-64 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 171'FSL,226'FEL,Sec. 16,T11N,R10E,UM March 1,2012 1E-24BL2-02 Top of Productive Horizon: 8.KB(ft above MSL): 94'RKB 15.Field/Pool(s): 1479'FNL, 15'FWL,Sec.22,T11N,R10E, UM GL(ft above MSL): 67'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1315'FNL, 1138'FEL,Sec.21,T11N,R10E,UM 8456'MD/6253'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-550301 y- 5959761 Zone-4 8486'MD/6252'TVD ADL 25651 TPI: x-550556 y- 5958113 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-549402 y- 5958269 Zone-4 1785'MD/1785'TVD 2657 18.Directional Survey: Yes ❑., No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1465'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 7850'MD/6263'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65# H-40 35' 112' 35' 112' 24" 326 sx AS II 10.75" 45.5# K-55 33' 2398' 33' 2398' 13.5" 1400 sx AS III,250 sx AS I 7" 26# K-55 32' 4913' 32' 4630' 8.75" 700 sx Class G,250 sx AS I 5.5" 15.5# L-80 4679' 6458' 4430' 6007' 7" 179 sx Class G 2.375" 4.7# L-80 7291' 8456' 6286' 6253' 3" slotted liner 24.Open to production or injection? Yes ❑ 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/ND) 3.5" 6274' 6263'MD/5844'TVD slotted-4iner.from 7302'-8456'MD 6286-6253'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. altia e ::1:'''''' z 1 RECEIVED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -C � na APR 1 12012 w. .-.� . AOGCC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) April 2,2012 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/3/2012 18 hours Test Period-> 348 1225 1126 100% 3925 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 199 psi 1174 24-Hour Rate-> 424 1664 1475 24 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No 2 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 Bi l iAPR 11 2171e, -1'l Form 10-407 Revised 12/2009 CONTI ED ON REVERSE Submit original only 28. GEOLOGIC MARKERS(List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? u Yes ❑., 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 1465' 1465' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A4 7850' 6263' Kuparuk A4 8486' 6252' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS YK�v Summary of Daily Operations,schematic,final directional survey 4 a ZOit'Z. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mik Winfree @ 265-6820 Printed Name L. ntt _. Title: CTD Engineering Supervisor Date ��410aSignature ♦ i.i& i l rd !A. ., Phone 263-4021 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 12/2009 KUP • 1 E-24BL2-02 ConocoPhillips ° Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ift(B) u�Alaska,Inc. 500292085764 KUPARUK RIVER UNIT 100.09 8,235.53 8,456.0 ConocoPhrlComment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -- SSSV:TRDP Last WO: 12/30/2011 32.30 12/13/1982 Well Conko -tE-24BL2-02, 016010122:39'.15 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,414.0 1/15/2012 Rev Reason: GLV C/O ninam 3/28/2012 HANGER,23 Casing Strings ill Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd LINER BL2-02 2 38 1.992 7,290.7 8,456.0 6,252.7 4.70 L-80 STL Liner Details gil Top DDpth (TVD) Top Incl Nomi... 17111 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 7,290.7 6,283.4 88.21 BILLET ALUMINUM BILLET 1.992 Perforations&Slots CONDUCTOR, Shot 35-112 Top(TVD) Bim(TVDDens ) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (ch..- Type Comment ice:. 7,302 8,456 6,285.6 6,252.7 3/1/2012 32.0 SLOTS SAFETY VLV, 1.785 I Notes:General&Safety End Date Annotation J 2/27/2012 NOTE:ADDED LATERALS BL1,BL2,BL2-01,BL2-02(BL1-01 COLLAPSED 8 ABANDONED) SURFACE. 34-2.398 I. GAS LIFT, _ 2,504 Mil GAS LIFT. .-- 3 709 _3,709 r I GAS LIFT.4.772 Whipstock'13., 4,91J13 WINDOW B, 4,9214,926 GAS LIFT, 5,449 MB GAS LIFT, 6.001 MB Mr MI NIPPLE.6,215 IN SEAL ASSY. la 6,258 —. i'''' I 5.5 LINER, 4.679-0.458 Whipstock. 6,890 N., WINDOW BL1, R. 6,890-8,895 Whipstock, 6.713 WINDOW BL2-01, 6,7168,721 Mandrel Details Top Depth Top I Port (TVD) Incl OD Valve Latch Size TRO Run Ste Top(ftKB) (ftKB) I°1 Make Model (In) Ser, Type Type (in) (psi) Run Date Com... 1 2,504.1 2,504.0 0.99 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,312.0 3/26/2012 3.5 LINER. 2 3,709.3 3,638.6 31.73 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,288.0 3/26/2012 6'TION,.93.N 3 4,772.1 4,512.1 32.71 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,269.03/26/2012 32-7.395 PRODUCT4 5,448.9 5,092.9 19.50 CAMCO KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,289.0 3/26/2012 5 6,001.0 5,615.3 25.40 CAMCO KBG-2-9 1 GAS LIFT OV BTM 0.250 0.0 3/262012 SLOTS, 7,302-8,456 SLOTS, 7,661-0,356 LINER BL2, 7,850-8,358 TD (1E-24BL2-02), 8,358 LINER BL2-02, 7,291-0,456 1 E-24BL1, 1 E-24BL2, 1 E-24BL2-01 and 1 E-24BL2-02 Well Work Summary DATE SUMMARY 1/11/12 GAUGE TBG TO 2.80"TO 641-. ,iLM, HAD TO WORK TOOLS f/6402'TO. . i4' SLM. COULD NOT GET DEEPER W/GAUGE RING. JOB SUSPENDED. 1/15/12 ENCOUNTER MUD @ 6414' SLM, READY FOR COIL. 1/16/12 DISPLACED MUD OUT OF TBG WITH DIESEL TO TAG AT 6627'CTMD WHILE MAINTAINING BACK PRESSURE ON IA.WELL FREEZE PROTECTED. JOB COMPLETE. 1/21/12 MILLED CEMENT FROM 6618'TO 6804' CTMD. 1:1 RETURNS WITH CEMENT THROUGH OUT JOB. F/P TUBING TO 3000'TURNED WELL OVER TO DSO, JOB IN PROGRESS, READY FOR E-LINE 1/29/12 LOGGED CEMENT BOND LOG AND GAMMA/CCL CORRELATION FROM A TAG DEPTH OF 6806'TO 5950'. TOP OF CEMENT FOUND IN 3.5" RETAINER AT A DEPTH OF 6460'. RIGGED DOWN AND TURNED WELL OVER TO DSO. 2/2/12 GAUGED TBG TO 2.78"TO 6800' SLM. DRIFTED TBG WITH 17' DUMMY WHIPSTOCK TO 6800' SLM. SET DV @ 6001' RKB. MITIA 2500 PSI, PASSED. COMPLETE. Conoco Phillips Time Log & Summary Wellview Web Reporting Report Well Name: 1E-24 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 2/5/2012 8:00:00 PM Rig Release: 3/14/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02/04/2012 74 hr Summary Move rig from 3H to 1 E 00:00 10:00 10.00 MIRU MOVE MOB P Order trucks from peak.Cont. preparing rig for move. 10:00 16:00 6.00 MIRU MOVE MOB P Move rig from 3H to 1E 16:00 18:00 2.00 MIRU MOVE MOB P On 1 E location, prepare to spot rig 18:00 20:00 2.00 MIRU MOVE MOB P Crew change Nabors and Peak, PJSM 20:00 00:00 4.00 MIRU MOVE MOB P Spot rig over 1E-24 02/05/2012 Rig up on 1 E-24.Attempt BOPE testing. State witness waived. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue rigging up 12:00 13:00 1.00 0 MIRU MOVE SFTY P Pre Spud meeting 13:00 18:00 5.00 0 MIRU MOVE MOB P Complete rig up,clean up rig 18:00 20:00 2.00 0 0 MIRU WHDBO BOPE P Prep for BOPE testing ***State witness waived by:Lou Grimaldi*** 20:00 00:00 4.00 0 0 MIRU WHDBO BOPE P Start BOPE testing,Swab valves believed to be leaking.Call out grease crew.Grease stack and tree. R1 appears to be leaking on rig ***Rig Accept*** 02/06/2012 Complete BOPE testing. Failed tests:R1 valve on Manage Pressure Line, Upper B/S rams. Pressure test PDL's and Tiger tank line. PU BHA#1.(whi.stock) 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE T Continue to attempt BOPE testing, R1 leaking. 03:00 06:00 3.00 0 0 MIRU WHDBO BOPE T Change out R1 valve on MP line. 06:00 14:00 8.00 0 0 MIRU WHDBO BOPE P Continue testing BOPE. Determine R1 now holding,but upper 2" blind/shear rams leaking. Continue test and plan to change-out rams at end of test. 14:00 14:15 0.25 0 0 MIRU WHDBO SFTY T Condust PJSM for replacing BOP rams. 14:15 16:00 1.75 0 0 MIRU WHDBO EQRP T Replace upper 2.0"blind/shear ram in BOPE and test. Complete BOP test. ***Nabors 8 hrs total used Billable Repair rate. BOP test failures**** Page 1 of 32 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 16:00 21:00 5.00 0 0 SURPRI WHDBO PRTS P Pressure test PDLs and line to tiger tank.(Unable to pumps.) 21:00 22:00 1.00 0 0 MIRU WHDBO BOPE P Pull BPV(rob with FMC) 22:00 00:00 2.00 0 0 SURPRI WHDBO CTOP P Inspect stripper, PT inner reel and stripper,displace CT to milling fluid 02/07/2012 Mill window from 6713'-6733'Backream and dry tag-clean. POOH and Undeploy BHA#2. 00:00 00:15 0.25 0 0 PROD1 DRILL SFTY P PJSM 00:15 01:30 1.25 0 0 PROD1 RPEQP1 PULD P PU BHA#1 (whipstock) 01:30 03:15 1.75 70 6,550 PROD1 RPEQP1TRIP P RIH,50FPM, Pumping minimum rate thru EDC. 03:15 03:30 0.25 6,550 6,500 PROD1 RPEQPI DLOG P Tie in depth logging up with gamma. -11'correction 03:30 03:48 0.30 6,550 6,748 PROD1 RPEQP1TRIP P RIH past setting depth 03:48 03:54 0.10 6,748 6,722 PROD1 RPEQP1WPST P PUH 32K PUW to set depth 6721.59'.TOWS 6713'. 03:54 04:00 0.10 6,722 6,711 PROD1 RPEQP1WPST P Close EDC set Whipstock 20LOHS CTW in tension.4100 psi CTP setting psi. DHWOB increased 1.1k to 3.5k.CTW 32K decreased to 22K during set. PUH 6711'.31K. 04:00 04:30 0.50 6,711 6,711 PROD1 WELLPF DISP P Open EDC. Displace well to milling fluid, Reboot Rig Link. 04:30 06:15 1.75 6,711 65 PROD1 RPEQP1TRIP P POOH 06:15 06:30 0.25 65 65 PROD1 RPEQP1SFTY P At surface. Conduct PJSM for laying down whipstock setting BHA (BHA#1)and making up window • milling BHA(BHA#2). 06:30 08:36 2.10 65 67 PROD1 WHPST PULD P Lay down BHA#1 and make up BHA#2. Service injector. 08:36 10:00 1.40 67 6,515 PROD1 WHPST TRIP P RIH BHA#2. 10:00 10:14 0.24 6,515 6,538 PROD1 WHPST DLOG P Tie in to GR: -14'correction. 10:14 10:20 0.10 6,538 6,679 PROD1 WHPST TRIP P RIH pumping 0.3-bpm; 1350-psi CTP. 10:20 10:35 0.25 6,679 6,713 PROD1 WHPST TRIP P Set down early[6707.0';2.5K WOB] but weight quickly fell off. Run in again and tag 6713'. Pick up[32.0k PUW]and proceed with milling. 10:35 15:05 4.50 6,713 6,717 PROD1 WHPST MILL P Time mill window: 1.41-bpm; 3950-psi CTP;4445-psi BH;3825-psi Annular. 1 FPH 15:05 16:50 1.75 6,717 6,719 PROD1 WHPST MILL P Mill exited casing.Contiinue milling rat hole. Not much cement or formation in returns 16:50 18:50 2.00 6,719 6,722 PROD1 WHPST MILL P Increase ROP 6 FPH,2K WOB, 3770 CTP, 1.4 BPM. Hold 12ppg at window on MP choke. 18:50 20:02 1.20 6,722 6,733 PROD1 WHPST MILL P Cement and formation in samples. Mill down to 6733'. 20:02 21:32 1.50 6,733 6,733 PROD1 WHPST REAM P Back ream-saw motor work on first pass with both string mill&mill at window. Ream up to 6700'.Other two passes clean-dry drift with a clean run. Page 2 of 32 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 21:32 00:00 2.47 6,733 72 PROD1 WHPST TRIP P POOH following MPD.Stop @ 5130' blow choke down.Cement chunks coming over shakers from choke. Continue to POOH,Zero gains or losses. 02/08/2012 Cut 1520'of Coil. Re-head and P/U 1.4 AKO with bi-center bit. RIH begin drilling build section from 6733'- 6857'. 00:00 02:30 2.50 0 0 PROD1 WHPST PULD P PJSM-undeploy BHA#2. Lay down BHA.Set up rig floor for cutting coil. Mill 2.80"no-go-String mill-2.79" no-go. 02:30 03:00 0.50 0 0 PROD1 DRILL SFTY P Pre-spud with Maddy's crew. 03:00 05:30 2.50 0 0 PROD1 DRILL SLPC P Start cutting 1500'of CT. 05:30 06:00 0.50 0 PROD1 DRILL SFTY P Crew Change, PJSM 06:00 07:00 1.00 0 0 PROD1 DRILL SLPC P RD cutter, RU to reverse circulate for slack management 07:00 08:30 1.50 0 0 PROD1 DRILL SLPC P Reverse circulate full coil volume fresh water 2BPM,displace CT back to mud,ramping up pump 4 times. Listening for cable movement. Verified cable moved. 08:30 09:45 1.25 0 0 PROD1 DRILL SLPC P Cut back CT to find E-line. 15'.Total amount cut 1520'. 09:45 12:15 2.50 0 0 PROD1 DRILL SLPC P MU CTC.pull test 35K. MU BHI drilling head. Pressure test 4K. Inspect stripper rubber. 12:15 12:30 0.25 0 0 PROD1 DRILL SFTY P PJSM. 12:30 14:00 1.50 0 0 PROD1 DRILL PULD P Deploy BHA 3. Build section(2.4 AKO, Bi-Center).Tough getting AK thru stack.Work 2.4 AKO thru tree. 14:00 16:00 2.00 62 6,515 PROD1 DRILL TRIP P RIH,set down weight at SSSV,GLM #2 3722',#4 5449',#5 6001',and the X-Nipple, 16:00 16:15 0.25 6,515 6,541 PROD1 DRILL DLOG P Tie in depth-12'correction 16:15 16:45 0.50 6,541 6,541 PROD1 DRILL DISP P Displace well to New mud. 16:45 17:15 0.50 6,541 6,733 PROD1 DRILL TRIP P Shut down close EDC. RIH to drill 17:15 22:15 5.00 6,733 6,815 PROD1 DRILL DRLG P Drill build section-1.50 bpm, 3680, BHP 3855, ECD 12,WOB 1.1,Ct weight 19K, ROP 15. 6780'-calculated doglegs look like 50-52.Call town.Control drill.WOB 1KROP15-20. 22:15 00:00 1.75 6,815 6,857 PROD1 DRILL DRLG P First clean Survey 54 dogleg. Update town.Continue drilling ahead-next survey was 50. 02/09/2012 Complete Build section to 6955'.Tie into RA marker @ 6718'. P/U BHA#4&start drilling lateral. TOW=6713' BOW=6718' 00:00 01:00 1.00 6,857 6,880 PROD1 DRILL DRLG P Drilling build section 01:00 01:15 0.25 6,880 6,880 PROD1 DRILL WPRT P Wiper trip 29K P/U weight Page 3 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01:15 03:45 2.50 6,880 6,955 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,3830, BHP 3883, ECD 12,WOB 1.2K,Ct weight 17K, ROP 30.Average dogleg 50- 52. 03:45 04:15 0.50 6,955 6,718 PROD1 DRILL DLOG P P/U weight 30K-tie into depth with gamma.+.5'correction. RA marker 6718.5'. 04:15 06:30 2.25 6,718 0 PROD1 DRILL TRIP P Open EDC POOH following MPD. 06:30 06:45 0.25 0 0 PROD1 DRILL SFTY P At surface. PJSM 06:45 08:15 1.50 0 0 PROD1 DRILL PULD P Undeploy BHA 3 08:15 09:45 1.50 0 0 PROD1 DRILL PULD P Deploy BHA 4.(.8 AKO 3"Bi-Center bit) 09:45 11:15 1.50 72 6,530 PROD1 DRILL TRIP P RIH 11:15 11:30 0.25 6,530 6,550 PROD1 DRILL DLOG P Tie in depth with gamma.-13' correction 11:30 11:45 0.25 6,550 6,955 PROD1 DRILL TRIP P Close EDC, RIH to drill 11:45 15:30 3.75 6,955 7,110 PROD1 DRILL DRLG P Drill Ahead 1.47 BPM,3797 CTP, 3864 BHP, 16 CTW 15:30 16:30 1.00 7,110 7,110 PROD1 DRILL WPRT P Wiper Trip to window,MAD pass for USR data 6965-6738'. 16:30 18:30 2.00 7,110 7,190 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM,3580 CTP, 3870 BHP, 16K CTW. 18:30 20:30 2.00 7,190 7,260 PROD1 DRILL DRLG P Drilling in shale-increase claygaurd to a total of 2.5%from 1.5%.Three stalls around 7215'area.Clean P/U weight 30K. Drilling ahead in better formation. 20:30 21:00 0.50 7,260 7,260 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K. 21:00 00:00 3.00 7,260 7,410 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,3680, BHP 3898, ECD 12.1, ROP 55,WOB 2.8K,Ct weight 15K. 02/10/2012 Drilling ahead on L1 lateral.Starting to see trouble spots from 7347-7250'during wiper trips.Mud swap with 1250'on system.total of 25 bbls losses in 24 hours. 00:00 01:00 1.00 7,410 7,410 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K.Minus 1.5 ft correction. 01:00 04:30 3.50 7,410 7,560 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,3840, BHP 3885, ECD 12.1, ROP 55 04:30 05:42 1.20 7,560 7,560 PROD1 DRILL WPRT P Wiper trip-P/U weight 31K 05:42 09:12 3.50 7,560 7,710 PROD1 DRILL DRLG P Drilling ahead-1.43 bpm,3939, BHP 4000, ECD 12.1.Stalls X 4 09:12 10:30 1.30 7,710 7,710 PROD1 DRILL WPRT P Wiper trip to window.30K PUW. RBIH 7360'set down weight. 10:30 11:15 0.75 7,710 7,745 PROD1 DRILL DRLG P Drilling ahead-1.43 bpm,4000, BHP 4180, ECD 12.1. 11:15 11:21 0.10 7,745 7,751 PROD1 DRILL DRLG P Pump 5 brls low/high sweeps. Annular pressure increasing. Hole possibly loading up. 11:21 11:33 0.20 7,751 7,751 PROD1 DRILL WPRT P PUH 30K PUW.annular psi increasing. Pump sweeps down to bit Page 4 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11:33 12:03 0.50 7,751 7,770 PROD1 DRILL DRLG P Sweeps at bit. Drill ahead 1.4 BPM, 3700 CTP, 16K CTW,3980 BHP. Hole loaded up.Sweeps helped BHP. 12:03 12:18 0.25 7,770 7,785 PROD1 DRILL DRLG P Unable to drop inclination.Slow down ROP 20 FPH to try to drop TF 12:18 14:42 2.40 7,785 7,860 PROD1 DRILL DRLG P Dropped inclination, Increase ROP drilling ahead. Ratty drilling,wanting to stall 14:42 15:42 1.00 7,860 7,860 PROD1 DRILL WPRT P Wiper trip to window.29K PUW,pull heavy stop at 37K,7290', unable to go down,stacking out. Drop pump rate to 1 BPM, RBIH get free, PUH to cont.wiper. Depth correlates to faulting area of lateral.Start lowering pump rate thru this area.6 BPM. 15:42 15:48 0.10 7,860 7,860 PROD1 DRILL WPRT P PU into casing. Park CT at 6644', chain reel. Inspect pressure bulk head.Online with pumps looks good. 15:48 16:30 0.70 7,860 7,860 PROD1 DRILL WPRT P RBIH,Tie in depth with RA marker-2' Correction.Cont RIH to TD 16:30 18:30 2.00 7,860 7,930 PROD1 DRILL DRLG P Drilling ahead-1.43 bpm,3720 CTP, BHP 4055, ECD 12.6. 16K CTW 18:30 20:00 1.50 7,930 7,970 PROD1 DRILL DRLG P Drilling ahead-getting small clay balls over shaker.Blow back choke and shale chunks came across. 1.40 bpm,3820, BHP 4050 psi, ECD 12.5,ROP 30,WOB 1.5K,Ct weight 16K. Call out vac trucks for mud swap.getting small shale chunks in returns. 20:00 21:00 1.00 7,970 7,973 PROD1 DRILL DRLG P Starting to lose returns, BHP dropping and stalls/stacking weight. Wiper 100'&drill ahead slowly. Make multiple attemps with Bore& circ pressure spiking on bottom, losing returns then when P/U gain in flow and pressure. Packing off around bit area,but no heavy P/U weights 30K. 21:00 22:30 1.50 7,973 6,700 PROD1 DRILL WPRT P Pull wiper trip early and prepare for mud swap-send returns to tiger tank. 7347'-Pulled heavy-Lower pump RIH-free-Lower pump rate through area past 7290, holding MPD. Losing roughly 6 bbls hour. 22:30 00:00 1.50 6,700 6,700 PROD1 DRILL WPRT P Open EDC&wipe up 1000'watching returns getting shale balls&light shale chunks. No major changes in cuttings. 1.55 bpm following MPD. RIH close EDC-Pump 5 bbl low/high sweep followed by new mud. 02/11/2012 Continue drilling ahead L1 lateral.Shale pebbles noticed across shakers during wiper trips. Lower pump rates while tripping past 7345-7115'.Total losses of 77 blls for 24 hours. 176 bbl losses for 24 hours. Page 5 of 32 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 00:30 0.50 6,700 7,973 PROD1 DRILL WPRT P Tripping in hole. New mud at bit for drilling. 00:30 01:30 1.00 7,973 7,974 PROD1 DRILL DRLG P Trying to Drill ahead-1.48 bpm, 3600, BHP 3940,WHP 80, ECD 12.2.having to work BHA through restricted area by taking runs hitting it 5 fpm. Losing returns and BHP when drilling into mystery fault. Bore pressure climbs like bit is packing off.P/U weight clean 30K. Fourth attempt started to get differentially stuck. P/U weight 38K. 01:30 03:30 2.00 7,974 7,976 PROD1 DRILL DRLG P Time drill-1.45 bpm,3350,BHP 3920,WHP 50, ECD 12.2,WOB .8K,CT weight 19K. Rate in 1.45/ Rate out 1.32 bpm.Good motor work &pressures,just not drilling off when WOB is over 1 -2K. Hard cemented sand&hard shales in samples.Very hard samples. (fault) 03:30 05:30 2.00 7,976 8,120 PROD1 DRILL DRLG P Hit it @ 5 fpm and broke through. Drilling ahead-1.48 bpm,3590, BHP 3930, ECD 12.2,WHP 30, ROP 15, WOB 1.8K,CT weight 17K.Rate out 1.40 bpm. ROP increased to 110 fph. 05:30 07:30 2.00 8,120 8,120 PROD1 DRILL WPRT P Wiper trip back to window, lowering pump rate thru 7290'area. Hardly seen anything.7114'small over pull PUH.On RBIH set down weight 7972'. 07:30 10:30 3.00 8,120 8,270 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM 3533 CTP,3935 BHP, 15K CTW, 10:30 12:15 1.75 8,270 8,270 PROD1 DRILL WPRT P Wiper trip do window,32K PUW lowering pump rates thru bad areas. Tie in depth to RA marker-3' correction 12:15 14:30 2.25 8,270 8,420 PROD1 DRILL DRLG P Drill Ahead 1.46 bpm,3576 CTP, 3984 BHP, 15K CTW 14:30 16:30 2.00 8,420 8,420 PROD1 DRILL WPRT P Wiper trip to window.32K PUW. Pull heavy 8041'.orient TF to drilled TF. Cont. PUH to window 16:30 19:30 3.00 8,420 8,550 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM,3653 CTP, 3994 BHP, 14 CTW. 8550'-Starting to stack CT weight with no WOB-P/U weight 37K break over. Poor shale formation. 100ft wiper clean P/U weight. 19:30 20:15 0.75 8,550 8,575 PROD1 DRILL DRLG P Drill ahead-1.48 bpm,3750, BHP 4020, ECD 12.4, ROP 15,WOB 1.6K,CT weight 12K.Starting to get large shale chunks plugging off the choke. P/U weights clean. Pump 5/5 sweep before wiper trip. Drilling improved last 15ft. 20:15 22:45 2.50 8,575 8,575 PROD1 DRILL WPRT P Wiper trip-P/U weight 34K.Minus 1.5 ft tie in.Slow rate thropugh troubled section,no weight issues. Page 6 of 32 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:45 00:00 1.25 8,575 8,643 PROD1 DRILL DRLG P Drilling ahead 02/12/2012 Continue drilling ahead on BL1 lateral.Continue to lower pump rates in troubled areas.8550 to TD is showing signs of poor shale sections. 00:00 01:30 1.50 8,643 8,725 PROD1 DRILL DRLG P Drilling ahead for information-1.45 bpm,3720, BHP 4010,ECD 12.4, ROP 55,WOB 1.5K,Ct weight 14K. 01:30 04:00 2.50 8,725 8,725 PROD1 DRILL WPRT P Wiper trip 33K off bottom. Had light sit down @ 8676'-Lower rate. 04:00 06:30 2.50 8,725 8,870 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3820, BHP 4060, ECD 12.6, ROP 60,WOB 2K, CT weight 12K. Bypass and blow down choke. 06:30 09:00 2.50 8,870 8,870 PROD1 DRILL WPRT P Wiper trip to window,33K PUW, reduce pump rate to.6 BPM thru possible trouble areas. Up to window looked good.On RBIH set down weight at 8500'.Gamma wraps around in this area. 09:00 11:06 2.10 8,870 8,976 PROD1 DRILL DRLG _ P Drill Ahead 1.44 BPM,3563 CTP, 4089 BHP, 11K CTW.Blow back MP choke. 1/4"cup shale rocks across shaker,Dime size. 11:06 11:12 0.10 8,976 8,976 PROD1 DRILL DRLG P Stall PU 40K.Online with pumps weight break back to 34K. RBIH to drill 11:12 12:27 1.25 8,976 9,020 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in, .9 BPM out. Losing 1/2 BPM.Continue drilling 3614 CTP,3943 BHP, 13K CTW.. 12:27 15:27 3.00 9,020 9,020 PROD1 DRILL WPRT P Wiper trip to window 30K PUW. Reducing pump rates thru trouble areas. 1.4 BPM in, 1.1 BPM out before PU. Losses healing up.Tie in depth to RA marker -1.5' correction. Up hole looked good. Over pull at Fault#1. Did not drop pump rate. RBIH ratty,set down weight at 8560'-9000'. 15:27 18:27 3.00 9,020 9,170 PROD1 DRILL DRLG P Drill Ahead 1.43 BPM in, 1.24 BPM out.3777 CTP,4142 BHP 13K CTW. Pump low/high sweeps 5brls each. 18:27 21:27 3.00 9,170 9,170 PROD1 DRILL WPRT P Pump 5/5 sweeps-Wiper trip-P/U weight 32K.Slow pump rate through troubled section. Had to work the string down from 8670'-then again from 9170'until TD. 21:27 00:00 2.55 9,170 9,272 PROD1 DRILL DRLG P Drilling ahead 1.43 bpm,3780, BHP 4150,@ 9272'started to stack weight.Try to P/U and temp.stuck max. P/U 48K.Good 1:1 returns. Pump sweeps wait for B/U. 02/13/2012 Mud swap with 1300'. Drilled to TD of 9431'Pump sweeps&wiper to swab valves with increased in shale cuttings from 2500'to surface.Tested SSSV-passed RIH&lay in Liner pill followed by KWF,lay down BHA at surface and perform weekly BOP function test. Page 7 of 32 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 00:45 0.75 9,272 9,272 PROD1 DRILL DRLG P Pump 5/5 sweeps followed by 20 bbls of new mud and cycle pipe when sweep is coming around.Max. P/U 50K.Max.set down-5K. Popped free on 7th attempt with new mud around the bit.Annular pressures dropped by 200 psi. 00:45 02:45 2.00 9,272 9,272 PROD1 DRILL WPRT P Wipe trip,seeing overpull in ratty sections 9100'area. Stacking weight when trying to go back down. B/U from sweep has more shale chunks coming back. Blow down choke. Continue with wiper trip. Call out vac trucks for mud swap. Tie in zero correction. 02:45 04:15 1.50 9,272 9,272 PROD1 DRILL WPRT P RIH-have to lower rate from 8560'- getting really ratty from 8840'to 9100'.Pump new mud on bottom- 1300 ft on old system. 04:15 05:00 0.75 9,272 9,300 PROD1 DRILL DRLG P Drilling ahead 1.45 bpm,3915,BHP 4210, ECD 13.1,WOB 1.7K, CT weight 10K. ROP 30. 05:00 08:00 3.00 9,300 9,400 PROD1 DRILL DRLG P New mud around-1.45 bpm,3580, BHP 4070,ECD 12.8.WOB 1.4K, CT weight 14K, ROP 50. 08:00 08:30 0.50 9,400 9,430 PROD1 DRILL DRLG P Pump 10brls low/10bris high sweeps. TD BL1 lateral 9430' 08:30 13:00 4.50 9,430 9,430 PROD1 DRILL WPRT P POOH to swab valves,open EDC in casing. Large amounts of cuttings across shakers starting at 2500'to surface. 1/2 dime size shale pebbles. 13:00 13:30 0.50 0 1,850 PROD1 DRILL WPRT P AT surface. RBIH to SSSV 13:30 13:45 0.25 1,850 1,850 PROD1 DRILL CIRC P Jet on SSSV pumping thru EDC 13:45 14:15 0.50 1,850 1,700 PROD1 DRILL PRTS P PU above SSSV,700psi WHP. Bleed off SSSV.Wait 3 minutes allowing SSSV to close, Bleed off well in 250psi increments.Once WHP at zero. Blow back and flush MP choke.Confirm SSSV is holding. 14:15 15:45 1.50 1,700 6,500 PROD1 DRILL WPRT P SSSV test good. Pressure up WHP to 700psi.Open SSSV 5500psi. Once SSSV open WHP 425 psi. Pressure bled down to formation. RBIH to TD 15:45 16:00 0.25 6,500 6,500 PROD1 DRILL DLOG P Tie in depth-1.5'correction.Close 16:00 19:00 3.00 6,500 9,431 PROD1 DRILL WPRT P Close EDC, RIH to TD. Had to work pumps to get past troubled area 8800-9100'.Tag TD. Pump Liner pill followed by KWF.get 3bbls out the bit&POOH laying in 1:1. 19:00 22:00 3.00 9,431 72 PROD1 DRILL TRIP P POOH laying in KWF liner pill(37 bbls)&KWF.Stop and paint EOP flags 7800'&5100'. Page 8 of 32 Time Logs Date From To Dur S.Depth E,Death Phase Code Subcode T Comment 22:00 23:30 1.50 72 0 PROD1 DRILL PULD P Flow check at surface for 15 minutes. PJSM for laying down BHA. Bit looked good no plugged nozzles with only 1 chipped tooth. 23:30 00:00 0.50 0 0 PROD1 DRILL BOPE P Weekly Funtion test of BOP's..Shut Swab valves and blow stack down. Service Injector. 02/14/2012 Ran BL1 Liner 9430 to 7275,RIH with Drill By BHA,Swap well to 9.8PPG Flow Pro 00:00 00:45 0.75 0 0 COMPZ CASING SFTY P Hold pre-spud meeting with Gary Crew. Let Top drive warm up 00:45 02:15 1.50 0 0 COMPZ CASING SVRG P Service Top drive and prep rig floor for liner run 02:15 04:15 2.00 0 1,517 COMPZ CASING PUTB P PJSM-Start P/U 46 joints of 2 3/8" slotted liner with shorty deployment sleeve. 04:15 05:30 1.25 1,517 1,561 COMPZ CASING PUTB P P/U coiltrack assembly. 05:30 06:00 0.50 1,561 1,561 COMPZ CASING SVRG P Check packoffs 06:00 07:30 1.50 1,561 6,500 COMPZ CASING RUNL P RIH with liner 07:30 07:45 0.25 6,500 6,500 COMPZ CASING RUNL P Tie in depth to EOP,-12'correction. Record up and down weights.32K PUW,20.5K RIHW 07:45 08:30 0.75 6,500 9,431 COMPZ CASING RUNL P RIH to TD 08:30 09:30 1.00 9,431 6,500 COMPZ CASING RUNL P Tag 9431'.3.6K WOB.Online with pumps 1.4 BPM,4000psi.31K PUW,OK DHWOB, Liner released. Remove liner depth,POOH to window pumping across top. 09:30 11:30 2.00 6,500 60 COMPZ CASING RUNL P POOH laying in KWF. 11:30 13:00 1.50 60 0 COMPZ CASING PULD P Ct at surface. Flow check-good.lay down BHA 13:00 13:30 0.50 0 0 COMPZ CASING RGRP P Service Top drive&injector-PJSM for P/U liner. 13:30 14:00 0.50 0 328 COMPZ CASING PUTB P P/U 10 joints of 2 3/8"Slotted liner& anchored billet. 14:00 14:30 0.50 328 400 COMPZ CASING PULD P P/U Anchored Billet,M/U to liner, M/U Coil track stab on and surface test tool 14:30 16:45 2.25 400 6,616 COMPZ CASING TRIP P RIH BHA#6 Upper liner section 16:45 17:21 0.60 6,616 7,911 COMPZ CASING TRIP P Stop and correct to flag,-15.5', Continue in to tag top of lower liner section,Close EDC, PUW=31K 17:21 19:45 2.40 7,911 61 COMPZ CASING TRIP P 7911',Tag up on top of lower liner, Orient to 20R,Set OH Anchor @ 3000 PSI,Set down 5K, Looks goog, trip Out 19:45 20:45 1.00 61 0 COMPZ CASING PULD P At Surface, Flo test well. PJSM Pull BHA from Dead Well, Lay down BHA #6 Liner running tools 20:45 22:00 1.25 0 72 PROD2 DRILL PULD P PJSM,M/U BHA#7,drill by bha with .8 degree AKO Motor and re run Bi Center,M/U to coil and surface test tool.Tag up depth and set de th 22:00 23:42 1.70 72 6,538 PROD2 DRILL TRIP P Trip in well, EDC Open Page 9 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 02/14/2012 24hr Summary Ran BL1 Liner 9430 to 7275, RIH with Drill By BHA,Swap well to 9.8PPG Flow Pro 23:42 23:54 0.20 6,538 6,560 PROD2 DRILL DLOG P Tie into formation for-16 23:54 00:00 0.10 6,560 6,700 PROD2 DRILL TRIP P Trip into 6700',Circulate well back to 9.8 PPG Flow Pro 02/15/2012 Drill off billet @ 7572, Drill ahead to 7754.Shales @ 7280 to 7320 acting up. Looks like hole collapse.Stuck with drilling BHA.Get free by pumping down back side. POOH and M/U EGO BHA.RIH and find hard bottom @ 7280 00:00 01:06 1.10 6,700 6,700 PROD2 STK CIRC P Circulate out 12.0 PPG completion fluid for 9.8 PPG Flo Pro with EDC open 01:06 01:36 0.50 6,700 7,572 PROD2 STK TRIP P Good Mud Around.Trap pressure, Shut down pumps.Close EDC, PUW=29K,clean pass through window,trip in to top of liner top billet 01:36 01:48 0.20 7,572 7,572 PROD2 STK TRIP P 7572, Dry tag TOB, PUH pumps on @ 1.46 BPM @ 3500 PSI FS, PUW=30K, 01:48 03:42 1.90 7,572 7,573 PROD2 STK MILL P Time mill @ 1 FPH as wob will allow 03:42 04:06 0.40 7,573 7,574 PROD2 STK MILL P Time mill @ 2 FPH, 1.45 BPM @ 3200 PSI FS, BHP=3890 04:06 05:18 1.20 7,574 7,600 PROD2 DRILL DRLG P 7573.9,2.2 feet down billet.Can't keep WOB looks like off billet,drill ahead 05:18 05:24 0.10 7,600 7,600 PROD2 DRILL WPRT P Drift past billet, PUW=33K 05:24 08:24 3.00 7,600 7,730 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM @ 3270 PSI FS, BHP=3870, RIW=17K 08:24 09:54 1.50 7,730 7,730 PROD2 DRILL WPRT P Wiper trip-P/U weight 31K. Light shale over shakers during wiper trip. Lower pump through shale section, light weight swings in area.(7350'- 7270') 09:54 10:24 0.50 7,730 7,754 PROD2 DRILL DRLG P Drilling ahead-Annluar pressure started to climb-blew down choke- no change. Pull wiper trip to clean up. Pulled heavy near the billet,work through. 10:24 12:24 2.00 7,754 7,255 PROD2 DRILL WPRT T Stuck pipe&lost returns @ 7540'. Could not move pipe. Had to pump down backside-Increase WHP 850 psi.able to move down. Bridged off @ 7255'.Popped free by cycling pipe and holding wellhead to 850 psi and no circulation through CT string. 12:24 15:24 3.00 7,255 72 PROD2 DRILL TRIP T Wiper to swab valves. Pump Low/high sweeps.Small pebble shale while POOH. Not a huge increase near surface,just consistant shale returns.Stop& blow choke down twice. 15:24 17:54 2.50 72 0 PROD2 DRILL PULD T PJSM-Undeploy BHA to change out bit&lay down the rez tool. 17:54 19:54 2.00 0 62 PROD2 DRILL PULD T Deply BHA with D331 bit with upcutters. Page 10 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:54 21:36 1.70 62 6,615 PROD2 DRILL TRIP T Trip in hole with BHA#8, .8 Degree motor and D-331 2.79 mill 21:36 21:48 0.20 6,515 6,545 PROD2 DRILL DLOG T Log Tie in for a-16.5'correction, PUW=29.6,Shut EDC 21:48 22:18 0.50 6,545 7,280 PROD2 DRILL TRIP T Trip in for FCO,Clean pass through window,Come to full rate at 7000', EOB,Sweeps going down coil, 1.3 BPM @ 2950 PSI FS, BHP=3880, RIW=19.6 22:18 23:03 0.75 7,280 7,283 PROD2 DRILL FCO T Clean trip to set down @ 7280,clean pick up @ 30K sweeps coming out, Pull up to 7200'.Clean trip.RBIH for another bite.Mill 7280 to 7280 at as drilled TF. High annular pressure. Pick up off bottom sticky pick up broke over @ 37K dragging heavy with motor work.Get clear,consult with town 23:03 23:27 0.40 7,283 7,276 PROD2 DRILL FCO T Trap pressure and reduce pump rate to.5 BPM.Attemp to RIH as was done on wiper trips while drilling 1st lateral.set down @ 7278 then 7276. loosing hole 23:27 00:00 0.55 7,276 7,280 PROD2 DRILL EGO T Wipe up hole 02/16/2012 Get coil free,Jet well. POOH,set anchored @ 6950. Prep for full BOPE Test 00:00 00:24 0.40 7,280 7,100 PROD2 DRILL EGO T Continue up hole, Pack off @ 7180. Keep coming up hole watching annular pressure fluctuations. cleared up 00:24 01:06 0.70 7,276 7,288 PROD2 DRILL EGO T RBIH,Tag up @ 7276.try drilling through area, motor stall,unable to pull up hole, no orienter, no circulation 01:06 03:06 2.00 7,288 7,288 PROD2 DRILL FCO T Try to establish circulation,work pipe -no movement,circulate across the top, hole is full. Pressure up well work pipe, Pressure up well and dump pressure while working pipe. Again attempt to establish circulation down coil @ min rate 03:06 04:36 1.50 7,288 7,288 PROD2 DRILL EGO T Unable to establish circulation, Confer with town,line up and pump MP 04:36 06:06 1.50 7,288 7,288 PROD2 DRILL EGO T Town ready to release tool string, work pipe,still stuck with no circulation. 06:06 06:36 0.50 7,288 6,500 PROD2 DRILL FCO T Crew change-Pump up WHP to 850. Pull Max.50K with-17K WOB. try to orient tool and started to pull free,keep pumping up WHP to 850. Pull free on second attempt.Wipe to window. 06:36 07:36 1.00 6,500 6,200 PROD2 DRILL CIRC T Pump Low/High sweep for B/U wipe up slowly and complete morning call. Shale over shakers but not a Page 11 of 32 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:36 10:36 3.00 6,200 72 PROD2 DRILL TRIP T POOH.Jet SSSV three passes. Function and flow test.Tried it twice slow dump&quick dump,bled down CT string/pumps as well with no luck. POOH set up for undeploying. 10:36 13:06 2.50 62 0 PROD2 DRILL PULD T PJSM for undeploying.Undeploy BHA&lay down for inspection. Service injector. 13:06 15:36 2.50 0 72 PROD2 STK PULD T P/U new BHA with Anchored billet. PJSM-Deploy BHA#9 15:36 17:36 2.00 72 6,961 PROD2 STK TRIP T RIh with EDC open-Tie in-16ft. Close EDC-P/U 29K. 17:36 18:06 0.50 6,961 6,950 PROD2 STK TRIP T Orient 20 degrees ROHS. Increase pumps set @ 3700 psi.Sit down 5K WOB.TOB©6950' 18:06 20:00 1.90 6,950 66 PROD2 STK TRIP T POOH pumping down ct string. 20:00 22:00 2.00 66 0 PROD2 STK PULD T At surface, PJSM, PUD BHA#9, Billet running tool 22:00 00:00 2.00 0 0 PROD2 DRILL SVRG P Service rig/tree for BOPE Test, swap coil to water and flush stack and surface lines 02/17/2012 Complete Full BOPE Test,Witness waived by Lou Grimaldi,AOGCC.Make up drill by BHA and Drill off billet @ 6949', Drill ahead to 7122' 00:00 00:30 0.50 0 0 PROD2 WHDBO CTOP P Continue prep for BOPE Test 00:30 09:30 9.00 0 0 PROD2 WHDBO BOPE P Start full BOPE Test.Witness waived by Lou Grimaldi,AOGCC. No failures during BOPE test.Cleared up rig floor. Pumped away roughly 8 bbls of mud during BOP test down MP line. 09:30 10:30 1.00 0 0 PROD2 DRILL SVRG P Service top drive loop,calibrate Micro motion&service injector cart. 10:30 11:30 1.00 0 0 PROD2 WHDBO CTOP P Circulate Mud back through CT sring and stack. 11:30 12:30 1.00 0 0 PROD2 STK SFTY P Crew change- valve checklist- PJSM for deploying 12:30 13:30 1.00 0 72 PROD2 STK PULD T Start deploying BHA#10 with.8 AKO and 3"Bi-center bit. 13:30 16:30 3.00 72 6,949 PROD2 STK TRIP T RIH EDC open.Tie in-9ft. P/U weight 29K.Close EDC and RIH min. rate. Dry Tag TOB 6949.5'-P/U weight 30K. 16:30 17:30 1.00 6,949 6,949 PROD2 STK KOST T Orient 5 degree LOHS.KOTB as per procedure. 1.44 bpm,3400.BHP 3867, ECD 12,WOB.5K,Ct weight 20K,time milling in auto pilot. 17:30 18:00 0.50 6,949 6,951 PROD2 STK KOST T Stall, PUH and restart time milling @ 1FPH 18:00 19:15 1.25 6,951 6,951 PROD2 STK KOST T Light DHWOB.2k,Goto 2 FPH, 1.44 BPM @ 3415 PSI FS, BHP=3863 19:15 19:30 0.25 6,951 6,953 PROD2 DRILL DRLG T Start pushing,WOB=.7K, ROP=4FPH 19:30 20:30 1.00 6,953 6,980 PROD2 DRILL DRLG T 6953', Drill Ahead, 1.44 BPM @ 3415 PSI FS, BHP=3865, RIW=16.7 20:30 20:42 0.20 6,980 6,980 PROD2 DRILL WPRT T Wiper trip past billet, PUW=27K, Clean trip up and down Page 12 of 32 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 20:42 22:48 2.10 6,980 7,110 PROD2 DRILL DRLG T 6980',drill ahead, 1.44 BPM @ 3275 PSI, BHP=3880,, RIW=18.5K 22:48 23:36 0.80 7,110 7,110 PROD2 DRILL WPRT T 7110',wiper to window, PUW=29K, Clean trip in and out 23:36 00:00 0.40 7,110 7,122 PROD2 DRILL DRLG T 7110', Drill Ahead, 1.42 BPM @ 3260 PSI, Blew down choke annular pressure rising. Pump LoHi Sweeps 02/18/2012 Drill Ahead from 7122 to 8025 00:00 01:48 1.80 7,122 7,260 PROD2 DRILL DRLG T Continue drilling ahead 01:48 02:36 0.80 7,260 7,260 PROD2 DRILL WPRT T Wiper to window, PUW=27.5K, Clean trip in and out 02:36 04:48 2.20 7,260 7,410 PROD2 DRILL DRLG T 7260', Drill Ahead, 1.4 BPM @ 3250 PSI FS,RIW=22K, ECD=12.2 Pump LoHi sweeps timed to come out just before wiper trip 04:48 06:18 1.50 7,410 7,410 PROD2 DRILL WPRT T Wiper to window with sweeps and tie in, PUW=28.5K 06:18 08:48 2.50 7,410 7,560 PROD2 DRILL DRLG T Drilling ahead-1.40 bpm,3500 psi, BHP 3910, ROP 60,WOB 2K,Ct weight 16K, ECD 12.2. Pump sweep prior to wiper. 08:48 10:06 1.30 7,560 7,560 PROD2 DRILL WPRT T Wiper trip-P/U weight 31K. No bad shale cutting detected over the shakers. 10:06 14:06 4.00 7,560 7,710 PROD2 DRILL DRLG T Drilling ahead-slow ROP 1.40 bpm, 3520, BHP 3920, ECD 12.2, ROP 9, WOB 2.6K,Ct weight 17K. Heavy packing clays over shakers, add drillzone to high sweeps.7577- Weight check clean 29K. ROP picked up @ 7610'. Pumped sweeps before wiper trip. 14:06 15:36 1.50 7,710 7,710 PROD2 DRILL WPRT T Wiper trip-P/U weight 31K 15:36 17:36 2.00 7,710 7,860 PROD2 DRILL DRLG T Drilling ahead-1.40 bpm,3630, BHP 3930, ECD 12.3, ROP 70,WOB 1.4K,Ct weight 17K.Vac trucks called out for 18:00 hrs 17:36 19:12 1.60 7,860 7,860 PROD2 DRILL WPRT T Wiper trip-P/U weight,30K,with tie if for-.5'correction,Clean trip in and out 19:12 20:54 1.70 7,860 8,010 PROD2 DRILL DRLG T 7860'drill ahead, 1.4 BPM @ 3300 PSI FS,BHP=3950 Start mud swap 20:54 22:36 1.70 8,010 8,010 PROD2 DRILL WPRT T Wiper trip to window, PUW=29K, New mud all around,Clean trip in and out 22:36 00:00 1.40 8,010 8,025 PROD2 DRILL DRLG T 8010', Drill Ahead, 1.42 BPM @ 3210 PSI FS, BHP=3880, RIW=18.3 02/19/2012 Drilled Ahead 8025 to 8610 00:00 02:30 2.50 8,025 8,060 PROD2 DRILL DRLG T Drill Ahead continued,Geo reported Ankorite in samples, ROP<15 FPH @-8005' Page 13 of 32 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 02:30 03:36 1.10 8,060 8,080 PROD2 DRILL DRLG T Low ROP,Geo sample show clay with harder material, Hot Gamma, Pump sweeps for balling, 1.42 BPM @ 3288 PSI FS, BHP=3915 03:36 04:24 0.80 8,080 8,160 PROD2 DRILL DRLG T 8080 Drilling Break, ROP 80-100 FPH, 04:24 06:24 2.00 8,160 8,160 PROD2 DRILL WPRT T Wiper trip to window BHP=3950, ECD=12.3, PUW=27K 06:24 09:24 3.00 8,160 8,310 PROD2 DRILL DRLG T Drilling ahead 1.45 bpm,3480, BHP 3897, ROP 70,WOB 1.6K,Ct weight 17K. Lost returns while drilling at 8168'- P/U weight clean 30K wiper 40 ft. Gained returns back. Drilling ahead-1.45 bpm,3470, BHP 3910, ROP 50,WOB 1.2K,Ct wweight 16K returns 1.35 bpm. 09:24 11:24 2.00 8,310 8,310 PROD2 DRILL WPRT T Wiper trip-P/U weight 31K. Had two overpulls off bottom.8237'&8200' with slight pack off.Tie in Zero correction. Continue with wiper.-stacked out @ 8237'@ 1.3 bpm,wipe up and lower rate to 1 bpm.Clean. 11:24 17:24 6.00 8,310 8,460 PROD2 DRILL DRLG T Drilling ahead-1.45 bpm,3480, BHP 3960, ECD 12.3,ROP 10,WOB, 2.5,Ct weight 15K. Ratty drilling.Try to P/U then drill-no change, pump sweep no-change. Drilling ahead. 17:24 19:54 2.50 8,460 8,460 PROD2 DRILL WPRT T Pump 5/5 Wiper-P/U weight 35K. Weight bobbles on way in with set down @ 8333 at drilled TF,reduce rate to.6 BPM and go through 19:54 22:12 2.30 8,460 8,610 PROD2 DRILL DRLG T 8460', Drill ahead, 1.44 BPM @ 3350 PSI FS, BHP=4000 22:12 00:00 1.80 8,610 8,610 PROD2 DRILL WPRT T 8610',Wiper to window, PUW=35K, slight overpulls with motor work @ 8320& 8230 coming up,set down @ 8333 RIH 02/20/2012 Drill from 8610 to 9210,Call TD 9210.51 bbls losses for 24 hours. 00:00 00:48 0.80 8,610 8,610 PROD2 DRILL WPRT T Continue with wiper trip 00:48 03:48 3.00 8,610 8,760 PROD2 DRILL DRLG T 8610',drill ahead, 1.42 BPM @ 3370 PSI FS, BHP=4060, RIW=17K 03:48 06:33 2.75 8,760 8,760 PROD2 DRILL WPRT T 8760',Wiper to window with tie in. PUW=31K, BHP=4066, ECD=12.6. Lowering pump rate through troubled section from 8290-8350'. 06:33 09:33 3.00 8,760 8,910 PROD2 DRILL DRLG T Drilling ahead-1.42 bpm,3710, BHP 4070, ECD 12.5, ROP 60,WOB 1.4, CT weight 14K.roughly 3-4 bbl/hour losses. Page 14 of 32 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:33 12:18 2.75 8,910 8,910 PROD2 DRILL WPRT T Wiper trip-P/U weight 32K. Lower pump rate from 8350'8290'-Pulled heavy 8225'-RIH lower pump rate and pulled through with a little drag. clean down to bottom. Lower rate 8200-8350' 12:18 17:03 4.75 8,910 9,060 PROD2 DRILL DRLG T Drilling ahead-1.43 bpm,3800, BHP 4090,ECD 12.7, ROP 44,WOB 1.7K,Ct weight 14K.SLow ROP.Hit sand last 50 ft. Pump Low/high sweep 17:03 20:33 3.50 9,060 9,060 PROD2 DRILL WPRT T Wiper to window-P/U weight 32K. 8250 area 45K pulls and minor packing off.Slow pull speed up to 8230,Set down at 8248 on way in @ 1 BPM had to reduce rate to.6 BPM and work through 20:33 00:00 3.45 9,060 9,210 PROD2 DRILL DRLG T 9060',Drill Ahead 1.4 BPM @ 3390 PSI FS, BHP=4130 02/21/2012 Wiper trip to surface, RBIH to TD,while laying in KWF liner pill packed off and stuck pipe with bit at 8785'. No indication at WOB,Orienter develops no torque and BHP tracks from bore to annulus. No circulation. 00:00 03:00 3.00 9,210 5,050 PROD2 DRILL WPRT T 9210-TD, PUH sweeps almost at bit, PUW=35K, BHP=4080,Wipe to swab,Started seeing bobbles with motor work @ 8358, Pull up and pack off @ 8250 to 8270.Hard work pipe to 8200.Pumped second set of sweeps entering case hole 03:00 05:00 2.00 5,050 72 PROD2 DRILL WPRT T 5050',unload good quantity of shales to shaker,Mico Motion plugging off with second sweeps coming to surface. Light traces of shale over shakers last 1800'. Bump up at surface and flush choke again.re-set depth. 05:00 08:00 3.00 72 8,271 PROD2 DRILL TRIP T RIH following MPD pumping 1.2 bpm. Tie correction minus 16ft.Slow pump rates to.6 bpm,from 8200'-8265' annular spike. Packing above BHA. 08:00 09:00 1.00 8,271 8,350 PROD2 DRILL WPRT T Wipe up 500'to start cleaning up area-P/U weight 36K. 1 bpm, sticky, loss of returns and higher annular up 8200',normal after poor section. RIH cleaner drift,holding around 4000psi BHP pumping .7 bpm.Clean down to 8350 09:00 10:00 1.00 8,350 7,700 PROD2 DRILL WPRT T Wipe up 500'to ensure hole is clean. Bring up pump rate from 8200',Stuck and packed off @ 8213.S/D pumps let coil relax, Dial in orienter torque. Pull free at 52K. Bring pumps on @ 1.4 BPM with full returns.Pump bottoms up while PUH @ 15 FPH Page 15 of 32 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 10:00 11:36 1.60 7,700 9,210 PROD2 DRILL WPRT T Pull up to 7700 while pumping bottoms up,RBIH,set down©8217' @.5 BPM. Pull up to 8180,RIH @ Min Rate,Slight set down @ 8330 then continue in 11:36 12:06 0.50 9,210 8,785 PROD2 DRILL WPRT T At bottom, POOH laying in 12LBS beaded liner pill 12:06 14:06 2.00 8,785 8,785 PROD2 DRILL WPRT T Packed off with over pull,attempt to RBIH.Can't RIH,S/D pump and let relax,Work pipe, Line up and pressure up well to 850 PSI,work pipe,Trap WHP line up to pump down coil 14:06 15:36 1.50 8,785 8,785 PROD2 DRILL WPRT T Work pipe,Stop working pipe and let hole relax,WHP down 250,work pipe then bleed off WHP to zero, work pipe. Pressure up back side to 850PSI and work pipe 15:36 17:06 1.50 8,785 8,785 PROD2 DRILL WPRT T Conference call with town,Initial plan forward hold 850PSI on well head,try to establish rate past BHA,Looks like 6 BBIs/Hr.Working pipe down, Pumping in compression 17:06 18:36 1.50 8,785 8,785 PROD2 DRILL WPRT T Trap WHP, Line up down coil with KWF.Start pumping and work pipe WHP=600 18:36 21:36 3.00 8,785 8,785 PROD2 DRILL WPRT T Check weights vs.depth,attempt to pump down coil,pressures right up to 4700 BHP,WHP dropped to 350 while working pipe. Pressure up WHP to 1200,surge WHP to TigerTank while pulling up at 58K. PUH to maximum of 65K@ 8781' and down to-25K@ 8798' -20K 8797' 0 K 8795' 30K 8789.2' 35K 8788.2' 40K 8787.4' 45K 8786.4' 60K 8781.6' 21:36 00:00 2.40 8,785 8,785 PROD2 DRILL WPRT T Start pumping down CT and into formation at 4900 BHP with.7 BPM. Displaced coil to 9.8 PPG flo-pro, pump in 8 bbls mineral oil and displace with flo-pro,spot 5 bbls through bit. 02/22/2012 Continued to work stuck pipe and managed to get free and POOH 00:00 02:00 2.00 8,785 8,785 PROD2 DRILL WPRT T Work pipe from-20K @ 8797'to 60K@ 8781'. 5.5 Bbls mineral oil out the bit, no movement. 02:00 03:00 1.00 8,785 8,785 PROD2 DRILL WPRT T Surge pressure alternating from coil to WH and working pipe from-20K to 60K 03:00 08:00 5.00 8,785 8,785 PROD2 DRILL WPRT T Maintain Coil in tension, let well relax Page 16 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 11:00 3.00 8,785 8,785 PROD2 DRILL WPRT T Put coil in compression, line up and pump down backside.Pumped tool free @ 1800PSI, Line up down coil while RIH.estabish circulation @.5 BPM. Pump pressure @ 4250, PUH and pack off @ 8790.Line up down back side and pump TS down hole @ 1200 PSI. Line up back down coil, unable to get rate down coil.Able to move 8785 to 8900 at normal weights 11:00 13:00 2.00 8,785 8,810 PROD2 DRILL WPRT T Line up and estalish circulation to formation.Work pipe while pumping. CT Press=2100,WHP=2030, .8 BPM down backside,unable to pump down coil. 13:00 14:30 1.50 8,810 8,790 PROD2 DRILL WPRT T Continue to work pipe while pumping down back side,8785 to 8892, Pulled heavy @ 8835,50K, Unable to RIH,S/D pumping down backside. let well relax 14:30 14:48 0.30 8,790 8,313 PROD2 DRILL WPRT T Pumping down back side. Dumped choke.Getting 3 BPM back.popped free and travel up hole. Lodged @ 8317. Pump down backside to charge up hole 14:48 16:48 2.00 8,313 6,650 PROD2 DRILL WPRT T Dump backside and pull free from 8317.Continue out of well 16:48 19:00 2.20 6,650 0 PROD2 DRILL WPRT T Up in case hole,stop and attempt to pump down coil, Pressured up on coil,no indication from downhole sensors.Open EDC,still unable to pump down coil,Trip out 19:00 19:30 0.50 0 0 PROD2 DRILL SFTY T Shut SSSV, PJSM while monitoring well for no-flow 19:30 21:42 2.20 0 0 PROD2 DRILL PULD T Lay down drilling BHA. One of the flappers had come loose and was sitting on flow sub, pulled checks from UQC and replaced with new. Confirmed clear flow path down CT 21:42 23:24 1.70 0 0 PROD2 DRILL PULD T MU clean out BHA, .8 deg motor and used HYC bit 23:24 00:00 0.60 0 PROD2 DRILL TRIP T RIH 02/23/2012 RIH with cleanout assembly to 7030', Ran Whipstock with KB packer and set at 6690'. Performed slack management and cut 900'of CT 00:00 01:00 1.00 1,500 6,500 PROD2 DRILL TRIP T Continue to RIH 01:00 01:18 0.30 6,500 6,550 PROD2 DRILL DLOG T Tie in,-11.5' 01:18 01:48 0.50 6,550 7,030 PROD2 DRILL FCO T Continue RIH through open hole. Tag at 7030',stall and PUH with 40K overpull,continue PUH 01:48 04:00 2.20 7,030 0 PROD2 DRILL TRIP T Continue POOH 04:00 06:00 2.00 0 0 PROD2 DRILL PULD T Undeploy BHA 06:00 10:00 4.00 0 0 PROD2 DRILL OTHR T Stand by for packer whipstock Page 17 of 32 Time Logs Date From To Dur S, Depth E.Death Phase Code Subcode T Comment 10:00 11:30 1.50 0 73 PROD3 WHPST PULD P PJSM, P/U Packer whipstock and pressure deploy,M/U coiltrack to coil and surface test,Tag up and set counters 11:30 13:15 1.75 73 6,520 PROD3 WHPST TRIP P Trip in with whipstock 13:15 13:30 0.25 6,520 6,544 PROD3 WHPST DLOG P Tie in for-14.5' 13:30 13:48 0.30 6,544 6,701 PROD3 WHPST TRIP P Trip in to set whipstock 13:48 13:54 0.10 6,701 6,701 PROD3 WHPST WPST P At set depth,Orient to 15 ROHS, shut EDC, Pressure up to 2700 and see tool shift.Orienter rolled to 150L. after set before picking up 13:54 15:48 1.90 6,700 64 PROD3 WHPST TRIP P Trip out after set 15:48 16:30 0.70 64 0 PROD3 WHPST PULD P PJSM, Flo check well,No flo, Pull BHA#12 Packer Whipstock running tools, Lay down coil track 16:30 17:00 0.50 0 0 PROD3 RIGMNT SFTY P PJSM, Rig up to trim-900'coil for fatigue mgmt 17:00 18:00 1.00 0 0 PROD3 RIGMNT SLPC P Reverse circulate 15 Bbls water, RU to cut coil 18:00 23:00 5.00 0 0 PROD3 RIGMNT SLPC P Cut 800'CT, Pump slack management,cut 10'to find wire and cut additional CT. total of 910'of CT cut, RD cutter. 23:00 00:00 1.00 0 PROD3 RIGMNT SLPC P Install CTC,pull test to 30K 02/24/2012 Function tested BOP, Rehead CT and PU window millling BHA,tag TOWS at 6990',mill window and rathole to 7011' 00:00 01:42 1.70 0 0 PROD3 RIGMNT SLPC P Install inteq UQC, PT to 4000 pis 01:42 02:42 1.00 0 0 PROD3 WHDBO BOPE P Function test BOP 02:42 03:00 0.30 0 0 PROD3 WHPST SFTY P PJSM for PU BHA 03:00 04:12 1.20 0 0 PROD3 WHPST PULD P MU window milling BHA, .6 deg. motor,used 2.80"go/2.79"no-go string reamer and 2.80"no-go window mill 04:12 06:24 2.20 0 6,520 PROD3 WHPST TRIP P Circulate water from CT and RIH 06:24 06:42 0.30 6,520 6,537 PROD3 WHPST DLOG P Log Gamma tie in for-13.5',close EDC, PUW=35K 06:42 06:54 0.20 6,537 6,690 PROD3 WHPST TRIP P Trip in to top of whipstock, Dry tag @ 6690.2. PUH Pumps on 1.53 BPM @ 3395 PSI,See motor work with WOB @ 6690.3 06:54 14:54 8.00 6,690 6,696 PROD3 WHPST MILL P Start time milling per procedure/ BOT window hand, 1.52 BPM @ 3390 PSi FS Preliminary window depths 6990.3 to 6995.5 14:54 18:12 3.30 6,696 6,711 PROD3 WHPST MILL P Call bottom of window/casing exit, Continue milling rathole 18:12 19:12 1.00 0 PROD3 WHPST MILL P Ream window,3 passes up and down. Dry drift window,clean. 19:12 20:36 1.40 6,711 0 PROD3 WHPST TRIP P POOH following MPD tripping schedule 20:36 20:54 0.30 0 PROD3 WHPST SFTY P PJSM Page 18 of 32 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 20:54 21:42 0.80 0 0 PROD3 WHPST PULD P Lay down milling BHA,Window mill is in guage at 2.80"no-go 21:42 22:18 0.60 0 0 PROD3 DRILL PULD P MU drilling BHA 22:18 00:00 1.70 0 6,000 PROD3 DRILL TRIP P RIH 02/25/2012 Drilled BL2 build to 7000',trip for lateral drilling assembly and drill lateral 00:00' 00:12 0.20 6,000 6,500 PROD3 DRILL TRIP P Continue RIH 00:12 00:30 0.30 6,500 6,711 PROD3 DRILL DLOG P Tie-in,-17' 00:30 09:15 8.75 6,711 6,860 PROD3 DRILL DRLG P Tag and start drilling, 1.5 BPM,3300 CTP,3780 BHP. Swap to new 9.8 flo-pro,Having problems getting surveys,Low ROP 09:15 09:33 0.30 6,860 6,860 PROD3 DRILL WPRT P Wiper trip to window, PUW=29K 09:33 12:03 2.50 6,860 7,000 PROD3 DRILL DRLG P 6860', Drill ahead, 1.5 BPM @ 3210 PSI FS, BHP=3850 12:03 15:03 3.00 7,000 50 PROD3 DRILL TRIP P End of Build,Trip out for lateral BHA, PUW=29K, BHP=3850 Stop at 6600'and open EDC,Avg DLS=38.6 Degrees,2.6 degree motor 15:03 19:30 4.45 50 72 PROD3 DRILL PULD P At surface, PJSM, PUD BHA#14, PD BHA#15 Lateral drilling BHA with.8 degree motor and 2.8 X 3.25 Bi Center 19:30 21:00 1.50 72 6,500 PROD3 DRILL TRIP P RIH 21:00 21:36 0.60 6,500 7,000 PROD3 DRILL DLOG P Tie-in,-17', RA at 6695', continue in hole and get surveys for confirmation 21:36 00:00 2.40 7,000 7,163 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3300 CTP,3900 BHP, 19K RIW 02/26/2012 Drilled BL2 lateral 00:00 00:18 0.30 7,163 7,175 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3300 CTP,3900 BHP 00:18 01:12 0.90 7,175 6,712 PROD3 DRILL DLOG P Mad pass,30K PUW 01:12 01:24 0.20 6,712 7,175 PROD3 DRILL WPRT P Wiper back in hole, 18K RIW 01:24 03:54 2.50 7,175 7,325 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3300 CTP,3900 BHP, 18K RIW 03:54 04:42 0.80 7,325 7,325 PROD3 DRILL WPRT P Wiper to the window,30K PUW 04:42 07:54 3.20 7,325 7,475 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3400 CTP,3900 BHP, 18K RIW. Plugged or balled up,pump low/high sweeps 07:54 09:06 1.20 7,475 7,475 PROD3 DRILL WPRT P 7475',Wiper to window with tie in, PUW=32.5K,Tie in correction+.5' 09:06 12:24 3.30 7,475 7,625 PROD3 DRILL DRLG P 7475', Drill Ahead, 1.4 BPM @ 3290 PSI FS, BHP=3960, RIW=18.2K 12:24 13:36 1.20 7,625 7,625 PROD3 DRILL WPRT P 7625,Wiper to window, PUW=33K, BHP=4000,Checked LSRV @32K 13:36 18:00 4.40 7,625 7,775 PROD3 DRILL DRLG P 7625',Drill Ahead, 1.4 BPM @ 3319 PSI FS, RIW=18.8, BHP=4000 18:00 19:18 1.30 7,775 7,775 PROD3 DRILL WPRT P Wiper to window,29K PUW Page 19 of 32 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 19:18 21:36 2.30 7,775 7,925 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3400 CTP,3980 BHP, 18K RIW 21:36 22:24 0.80 7,925 7,000 PROD3 DRILL WPRT P Wiper to window,29K PUW 22:24 22:36 0.20 7,000 7,030 PROD3 DRILL DLOG P Tie-in, +0.5' 22:36 23:12 0.60 7,030 7,925 PROD3 DRILL WPRT P Wiper back in hole, 19K RIW 23:12 00:00 0.80 7,925 7,960 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3275 CTP,3990 BHP, 18K RIW 02/27/2012 Drilled BL2 lateral to 8395' 00:00 03:42 3.70 7,960 8,085 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3275 CTP,3990 BHP, 18K RIW 03:42 05:24 1.70 8,085 8,085 PROD3 DRILL WPRT P Wiper to the window,29K PUW Stacking weight with motor work at -7950' 05:24 07:24 2.00 8,085 8,235 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3375 CTP,4040 BHP, 16K RIW 07:24 09:42 2.30 8,235 8,235 PROD3 DRILL WPRT P Wiper to window,Motor work with little overpull 7966 to7945 on way up. Set down @ 7970 after taking WOB @ 7960 with 1.3 BPM in rate, PUH trap 150 PSI WHP go to 1 BPM ratty hole from 7960 to 8050 then normal 09:42 13:12 3.50 8,235 8,395 PROD3 DRILL DRLG P 8235', Drill ahead, 1.46 BPM @ 3650 PSI FS, BHP=3920, BHP=3920 13:12 15:27 2.25 8,395 7,900 PROD3 DRILL WPRT P 8395',Call TD, LoHi sweeps coming out,Wiper to window, PUW=33K Over pulls to 42K. 1100 PSI Differential,8030 to 7935,Tie in for +2'correction, RBIH 15:27 18:24 2.95 7,900 0 PROD3 DRILL TRIP P 7900', POOH laying in beaded liner pill,followed by flo pro Paint EOP _ flag @ 6100'. Jet across SSSV. 18:24 18:54 0.50 0 0 PROD3 DRILL SFTY P PJSM,monitor well for flow 18:54 20:24 1.50 0 0 PROD3 DRILL PULD P Lay down drilling BHA,service injector 20:24 21:06 0.70 0 0 COMPZ CASING PUTB P RU for liner running 21:06 21:24 0.30 0 0 COMPZ CASING SFTY P PJSM for liner running 21:24 00:00 2.60 0 567 COMPZ CASING PUTB P Run 15 Jts. liner. Change out checkvalves in UQC. MU Inteq liner running tools. 02/28/2012 RIH,Set OH Anchored billet 7850'TOB. POOH, PU/MU/RIH BHA 17(1.0 AKO with 3.25"Bi-Center bit) Sidetrack BL2-02 lateral 150 ROHS toolface. Drill ahead BL2-01 lateral 7850'-7999'. 00:00 02:18 2.30 567 8,356 COMPZ CASING RUNL P RIH,correct at 6100'EOP flag-16', 30K PUW. Logged tie-in to formation for no correction. Orient anchor to 180 and set at 4400 PSI. Top of billet at 7850'. PUH at 28K. 02:18 04:18 2.00 8,356 48 COMPZ CASING RUNL P POOH 04:18 06:18 2.00 48 0 COMPZ CASING PULD P Tag up and space out,PJSM, Lay down liner running tools,Temp down to-44, change of plan,use SSSV to swap out tools so not to use mast hydraulics to move PDL's Page 20 of 32 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 06:18 08:42 2.40 0 72 PROD4 STK PULD P P/U lateral drilling BHA W/1 degree motor and 2.79 X 3.25 Bi Center, M/U coil track to CT,Surface test 08:42 10:36 1.90 72 6,530 PROD4 STK TRIP P Trip in hole, EDC open 10:36 11:00 0.40 6,530 6,560 PROD4 STK DLOG P Tie-in,-16'. Close EDC 11:00 11:42 0.70 6,560 7,850 PROD4 STK TRIP P Continue RIH 11:42 17:42 6.00 7,850 7,880 PROD4 STK KOST P Tag billet and start time milling, 1.4 BPM,3300 CTP,3900 BHP with WOC, 18K RIW. Drifted billet. 17:42 22:42 5.00 7,880 7,991 PROD4 DRILL DRLG P Continue drilling ahead 22:42 23:12 0.50 7,991 7,999 PROD4 DRILL DRLG P Pump low/Hi sweeps. Drilling ahead slow ROP's 23:12 00:00 0.80 7,999 7,999 PROD4 DRILL WPRT P Wiper trip to window.31K PUW 02/29/2012 Drill BL2-01 Lateral 7999'-8453'.Catch samples every 50',perform wiper trips every 150'.Tie in depth to RA marker every third wiper trip.Pump low/high sweeps as needed. 00:00 01:39 1.65 7,999 7,999 PROD4 DRILL WPRT P Continue wiper trip 01:39 08:00 6.35 7,999 8,138 PROD4 DRILL DRLG P Drill ahead 1.4 BPM,3500 CTP, 3950 BHP, 14K CTW 2:20am blow back MP choke 08:00 09:48 1.80 8,138 8,138 PROD4 DRILL WPRT P Wiper trip to window,PUW=31IK 09:48 14:30 4.70 8,138 8,290 PROD4 DRILL DRLG P Drill ahead 1.4 BPM,3400 CTP, 3945 BHP, 15.5K CTW 14:30 15:42 1.20 8,290 6,718 PROD4 DRILL WPRT P Wiper to the window,30K PUW 15:42 15:54 0.20 6,718 6,750 PROD4 DRILL DLOG P Tie-in, +2' 15:54 16:42 0.80 6,750 8,290 PROD4 DRILL WPRT P Wiper back in hole, 19K RIW 16:42 20:27 3.75 8,290 8,440 PROD4 DRILL DRLG P Drill ahead 1.4 BPM,3320 CTP, 3945 BHP 20:27 22:39 2.20 8,440 8,440 PROD4 DRILL WPRT P Wiper trip to window.31K PUW 22:39 00:00 1.35 8,440 8,453 PROD4 DRILL DRLG P Drill ahead 1.4 BPM,3385 CTP, 3960 BHP, 13.5K CTW 03/01/2012 TD BL2-01 Lateral to 8486'.Perform wiper trip to window,Tie in depth. RBIH,Spot liner pill in OH. POOH, LD drilling BHA 17. Utilizing SSSV, PU/MU/RIH BL2-01 liner(39jnts Slotted,w/OH anchored billet). Release liner setting single slip on OH anchor 20deg ROHS.BOL 8456'.TOB 7290'. 00:00 06:12 6.20 8,453 8,486 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM,3350 CTP, 3960 BHP, 13.5K CTW, ROP 5-10 FPH 06:12 08:48 2.60 8,486 6,500 PROD4 DRILL WPRT P Pump sweeps and wiper to above the window,29K PUW 08:48 09:06 0.30 6,500 6,550 PROD4 DRILL DLOG P Tie-in depth,+2.5'correction 09:06 10:18 1.20 6,550 8,446 PROD4 DRILL WPRT P Continue wiper back in hole 10:18 11:18 1.00 8,446 6,650 PROD4 DRILL DISP P Lay in liner pill with beads 11:18 14:48 3.50 6,650 0 PROD4 DRILL TRIP P POOH,paint EOP flag,after tag up at surface RBIH to 1700',open EDC and jet SSSV then POOH 14:48 15:18 0.50 0 0 PROD4 DRILL SFTY P Close SSSV and monitor well for flow. PJSM Page 21 of 32 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 15:18 16:18 1.00 0 0 PROD4 DRILL PULD P Lay down drilling BHA 16:18 16:42 0.40 0 0 COMPZ CASING PUTB P Rig up for liner operations 16:42 17:00 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations 17:00 18:00 1.00 0 0 COMPZ CASING PUTB P Run BL2-02 liner,35 Joints and an anchored billet 18:00 18:30 0.50 0 0 COMPZ CASING SFTY P Crew Change, PJSM 18:30 21:15 2.75 0 0 COMPZ CASING PUTB P Continue picking up BL2-02 liner 21:15 22:30 1.25 1,226 6,625 COMPZ CASING RUNL P RIH with BL2-02 liner,EDC open 22:30 22:45 0.25 6,525 6,525 COMPZ CASING RUNL P Tie in depth to EOP flag-16.5' correction, RIH to TOW 22:45 23:00 0.25 6,525 6,525 COMPZ CASING RUNL P Offline with pumps.Close EDC. 18K RIW,30K PUW 23:00 23:30 0.50 6,525 8,456 COMPZ CASING RUNL P RIH with liner 23:30 23:35 0.09 8,456 6,600 COMPZ CASING RUNL P Liner on depth 8456'. 16K CTW, 1.3K DHWOB.Orient TF 20 ROHS.Set OH anchor,4500 CTP.Slips set 5.9K DHWOB. PU off liner 28K CTW, DHWOB drop off to 500Ibs. 23:35 00:00 0.42 6,600 6,600 COMPZ CASING RUNL P POOH to window 03/02/2012 Perform BOPE testing.State Witness waived by Jeff Jones.0 failures. PU/MU/RIH BHA 19(1.1 AKO,3.25" Bi center bit).Mill off anchored billet 10 LOHS toolface 7290-7293', Drill BL2-01 lateral. 00:00 01:00 1.00 6,600 1,785 COMPZ CASING RUNL P Remove liner length from bit depth 1165.59',open EDC, POOH 01:00 01:15 0.25 1,785 1,785 COMPZ CASING RUNL P Jet SSSV clean of debris,pumping thru EDC 01:15 01:30 0.25 1,785 0 COMPZ CASING RUNL P POOH 01:30 01:45 0.25 0 0 COMPZ CASING SFTY P At surface,close SSSV,monitor well.Close EDC 01:45 02:00 0.25 0 COMPZ CASING SFTY P PJSM 02:00 03:30 1.50 0 0 COMPZ CASING RUNL P LD BHA 18,remove check valves. 03:30 05:00 1.50 0 0 PROD5 WHDBO SVRG P MU nozzle to CT,flush stack. Grease rig valves and wellhead, prepare for BOPE testing 05:00 15:30 10.50 0 0 PROD5 WHDBO BOPE P Start BOPE testing. . ***State Witness Waived by:Jeff Jones*** 15:30 15:54 0.40 0 0 PROD5 STK SFTY P PJSM for BHA 15:54 16:54 1.00 0 0 PROD5 STK PULD P MU BHA#19 16:54 18:54 2.00 0 6,540 PROD5 STK TRIP P RIH 18:54 19:09 0.25 6,540 6,540 PROD5 STK DLOG P Tie in depth,-18'correction 19:09 19:30 0.35 6,540 7,289 PROD5 STK TRIP P RIH to TOB on BL2-011iner, 17K RIW 19:30 20:30 1.00 7,289 7,291 PROD5 STK KOST P Dry tag TOB,7289.6. PUH 32K. Online with pumps est.milling rates. 1.46 BPM,3500 CTP,Slowly RIH, start milling 1 FPH at 7290.6'.Stall 7290.68'PU 33K PUW. Page 22 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 7,291 7,291 PROD5 STK KOST P Slowly RBIH,start to see motor work and WOB.75K.7290.09'.Start time milling 10 LOHS, 1 FPH, 1.45 BPM. 3552 CTP, 17K CTW,3956 BHP, open choke. 21:00 22:30 1.50 7,291 7,293 PROD5 STK KOST P Aluminum cuttings at shakers.Cont. milling on auto driller.10 LOHS, 1.46 BPM,3600 CTP,3956 BHP, 17K CTW,500lbs WOB, 1 FPH for 1',2 FPH for 1',3 FPH for 1'. 22:30 23:00 0.50 7,293 7,300 PROD5 STK KOST P Time Drilling 10 LOHS TF, 15 FPH, 1.4 BPM,3630 CTP,3953 BHP, .6K WOB 23:00 23:30 0.50 7,300 7,330 PROD5 STK KOST P Drill Ahead 1.4 BPM,3630 CTP, 16K CTW,3956 BHP 23:30 23:42 0.20 7,330 7,330 PROD5 STK KOST P PUH 30K PUW.dry drift sidetrack. Looks good. 23:42 00:00 0.30 7,330 7,346 PROD5 DRILL DRLG P Drill Ahead 1.4 BPM,3590 CTP, 3976 BHP, 16K CTW 03/03/2012 Drill BL2-01 Lateral,catching samples every 50',Wiper trips every 150'.Swap out mud system. 00:00 01:42 1.70 7,346 7,375 PROD5 DRILL DRLG P Drilling ahead 1.4 BPM,3660 CTP, 17K CTW,3967 BHP 01:42 01:48 0.10 7,375 7,375 PROD5 DRILL WPRT P PU for BHA wiper,Slow ROP's,29 CTW 01:48 03:24 1.60 7,375 7,438 PROD5 DRILL DRLG P Drill Ahead 1.4 BPM,3700 CTP, 3505 off bottom CTP, 16K CTW, 3964 BHP 03:24 03:36 0.20 7,438 7,438 PROD5 DRILL WPRT P CT surface weight stacking,PU weight check 42K. 03:36 06:36 3.00 7,438 7,479 PROD5 DRILL DRLG P Drill Ahead 1.4 BPM,3770 CTP, 3505 off bottom CTP, 15K CTW, 3984 BHP. Swap out mud(.55 DS, 1105'total footage drilled on mud system) 06:36 07:36 1.00 7,479 7,479 PROD5 DRILL WPRT P Wiper to the window,30K PUW 07:36 13:06 5.50 7,479 7,517 PROD5 DRILL DRLG P Continue drilling, 1.5 BPM,3300 CTP,3855 BHP. Very low ROP, pickup weights are normal. May have a plugged jet as freespin pressure has increased by-70 psi. Increased pump rate to 1.57 BPM, 3500 CTP,3850 BHP 13:06 15:06 2.00 7,517 7,517 PROD5 DRILL DRLG P Pump low/high sweeps,slow ROP's, weight check 31K PUW.Cont. Drilling 15:06 15:36 0.50 7,517 7,517 PRODS DRILL WPRT P PU BHA wiper,29K PUW 15:36 20:06 4.50 7,517 7,630 PROD5 DRILL DRLG P Cont Drilling 20:06 21:06 1.00 7,630 7,630 PROD5 DRILL WPRT P Wiper trip to window,31K PUW 21:06 23:51 2.75 7,630 7,758 PRODS DRILL DRLG P Drill Ahead 1.59 BPM,3670 off bottom,3875 on bottom CTP,3881 BHP, 15K CTW 23:51 00:00 0.15 7,758 7,760 PROD5 DRILL WPRT P PU BHA wiper 35K PUW. RBIH, Drill ahead Page 23 of 32 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 03/04/2012 24 hr Summary TD BL2-01 Lateral 8003'.Pump low/high sweeps,wiper trip to window. RBIH to TD. POOH,displacing liner running pill in OH.PU/MU/RIH BL2-01 liner(40 slotted jnts,shorty deployment sleeve).Release liner. BOL-8003',TOL-6690'. POOH 00:00 00:30 0.50 7,760 7,780 PROD5 DRILL DRLG P Drill ahead. 1.59 BPM,3930 CTP, 3920 BHP. 16K CTW 00:30 02:00 1.50 7,780 7,780 PROD5 DRILL WPRT P Wiper trip to window,31K PUW,tie in depth to RA marker-2'correction 02:00 04:30 2.50 7,780 7,930 PROD5 DRILL DRLG P Drill Ahead, 1.59 BPM,3900 CTP, 3905 BHP, 15.6K CTW 04:30 05:42 1.20 7,930 7,930 PRODS DRILL WPRT P Wiper trip to window. 30K PUW 05:42 09:24 3.70 7,930 8,003 PROD5 DRILL DRLG P Continue drilling, 1.5 BPM,3500 CTP,3910 BHP, 16K RIW Pump sweeps at 8003'TD 09:24 10:24 1.00 8,003 6,725 PRODS DRILL WPRT P Wiper to the window,30 K PUW 10:24 10:36 0.20 6,725 6,755 PROD5 DRILL DLOG P Tie-in,+1.5' 10:36 11:24 0.80 6,755 8,003 PRODS DRILL WPRT P Wiper back in hole 11:24 12:18 0.90 8,003 6,670 PROD5 DRILL DISP P Tag TD and lay in liner running pill with alpine beads 12:18 15:18 3.00 6,670 0 PRODS DRILL TRIP P POOH,paint EOP flags @ 6500'and 5200'. Pull to surface, RBIH to 1700',open EDC and jet accross SSSV, POOH 15:18 15:36 0.30 0 0 PROD5 DRILL SFTY P Close SSSV,PJSM,monitor well for flow 15:36 16:24 0.80 0 0 PROD5 DRILL PULD P Lay down drilling BHA 16:24 17:00 0.60 0 COMPZ CASING SFTY P MU and drill with new safety joint assembly 17:00 18:00 1.00 0 0 COMPZ CASING PUTB P Rig up for liner operations 18:00 18:45 0.75 0 0 COMPZ CASING SFTY P Crew change, PJSM 18:45 19:00 0.25 0 0 COMPZ CASING SFTY P Safety Drill, Practice making up shorter Safety Joint with Shear Release Disconnect 19:00 20:30 1.50 0 0 COMPZ CASING PUTB P PU/MU BL2-01 liner 20:30 20:45 0.25 0 0 COMPZ CASING SFTY P BOP drill PU safety joint.Spaceout across 2 3/8"deployment rams. Hold round table discussing drill. Last drill picking 30'safety joint was 4 min 20 sec.New time with shorter safety joint 57 seconds. 20:45 22:00 1.25 0 0 COMPZ CASING PUTB P Cont.PU/MU Liner 22:00 23:15 1.25 1,357 6,556 COMPZ CASING RUNL P RIH, EDC closed,circulating minimum rate 23:15 23:30 0.25 6,572 6,556 COMPZ CASING RUNL P Tie in depth to EOP flag-15.7', record up and down weights.20K _ RIHW,32K PUW 23:30 00:00 0.50 6,556 7,672 COMPZ CASING RUNL P RIH to TD 03/05/2012 Undeploy BHA 20(liner running tools).Deploy/RIH BHA 21 (3.5"Monobore WS).Set whipstock 6650'TOWS. POOH undeploy BHA 21. PU/MU/RIH BHA 22(.6 AKO,window mill with string mill)Mill window 6650'- 6654'.Mill 16'of rat hole Page 24 of 32 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 00:00 00:06 0.10 7,972 8,000 COMPZ CASING RUNL P Cont. RIH to TD 00:06 00:12 0.10 8,003 8,003 COMPZ CASING RUNL P Tag 8000'.6K DHWOB,online with pumps max rate at 4000psi CTP, PU 28K CTW. Liner released. BOL 8003, • TOL 6690'. Remove liner length from bit depth. 1312.60' 00:12 02:27 2.25 6,650 0 COMPZ CASING RUNL P POOH 02:27 02:48 0.35 0 0 COMPZ CASING SFTY P PJSM 02:48 04:18 1.50 0 0 COMPZ CASING PULD P Undeploy BHA 20 04:18 06:00 1.70 0 0 PROD6 RPEQPI PULD T Deploy BHA 21 (3.5"Monobore Whipstock) 06:00 08:18 2.30 0 6,661 PROD6 RPEQP1TRIP T RIH,Tie-in to formation marker at 6500',-15.5'correction,close EDC 08:18 08:42 0.40 6,661 6,650 PROD6 RPEQP1WPST T Set WS at 6660.5 bit depth,oriented highside,TOWS at 6650'. Set at 4000 CTP,set down 2K. 29K PUW, Open EDC. 08:42 10:24 1.70 6,650 0 PROD6 RPEQP1TRIP T Tha 10:24 10:54 0.50 0 0 PROD6 RPEQP1SFTY T PJSM 10:54 11:36 0.70 0 0 PROD6 RPEQP1PULD T Lay down WS setting BHA 11:36 12:30 0.90 0 0 PROD6 WHPST PULD T PU window milling BHA,Window mill is 2.80"no-go,string reamer is 2.79" no-go. 12:30 14:30 2.00 0 6,650 PROD6 WHPST TRIP T RIH,tie-in for-11'.Wt.check 29K PUW 14:30 20:30 6.00 6,650 6,654 PROD6 WHPST MILL T Tag billet at 6650 and start milling @ 1 FPH. 1.5 BPM,3600 CTP,3815 BHP, 19K RIW 20:30 22:30 2.00 6,654 6,660 PROD6 WHPST MILL T Mill exited casing.Cont milling 22:30 00:00 1.50 6,660 6,670 PROD6 WHPST MILL T Pump low/high,sweeps 10brls each. Cont.milling, Formation confirmed in returns 03/06/2012 TOWS=6650'-BOW=6654'. P/U 2.1 AKO with 3.00"Bicenter&Drill Build section to 6975'.AVG doglegs 39.7 00:00 01:15 1.25 6,670 6,670 PROD6 WHPST MILL T Back ream window up/down/up. Dry drift window. Looks good 01:15 03:36 2.35 6,670 0 PROD6 WHPST TRIP T POOH, EDC open pumping 1.6 BPM 03:36 04:06 0.50 0 0 PROD6 WHPST SFTY T PJSM while watching well for no-flow 04:06 04:48 0.70 0 0 PROD6 WHPST PULD T Lay down milling BHA • Mill 2.80"No-Go,String mill 2.79" No-Go 04:48 06:06 1.30 0 0 PROD6 DRILL PULD T MU driling BHA for build section, 2.1 Deg motor and HCC used bi-center. 06:06 08:06 2.00 0 6,500 PROD6 DRILL TRIP T RIH 08:06 09:06 1.00 6,500 6,500 PROD6 DRILL SVRG T Change out counter wheel assembly 09:06 09:21 0.25 6,500 6,670 PROD6 DRILL DLOG T Tie-in.-15'correction, PUW 29K, RIH to drill Page 25 of 32 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 09:21 13:06 3.75 6,670 6,757 PROD6 DRILL DRLG T Drill Ahead 1.5 BPM 3455 CTP, 18K CTW 13:06 14:51 1.75 6,757 6,800 PROD6 DRILL DRLG T Control drill limiting ROP's due to higher DLS than planned.Concern of drilling into existing lateral. 14:51 14:57 0.10 6,800 6,800 PROD6 DRILL WPRT T Wt.chk. PU weight check 33K PUW. RBIH 14:57 16:27 1.50 6,800 6,820 PROD6 DRILL DRLG T Drill ahead control drilling. 1.5 BPM, 3561 CTP, 18K CTW. Limit 1K WOB.lower DLS coming on surveys. 16:27 16:57 0.50 6,820 6,820 PROD6 DRILL WPRT T Wiper trip to window 32K PUW.Tie into RA marker.TOWS 6650,BOWS 6654, RA marker 6657 16:57 23:00 6.05 6,820 6,975 PROD6 DRILL DRLG T Time drilling Build section. 23:00 00:00 1.00 6,975 2,500 PROD6 DRILL TRIP T Open EDC above window POOH following MPD. 03/07/2012 P/U BHA#24 with 1.0 AKO and new 3"Bi-center. Poor ROP with multiple stalls,lighter doglegs while drilling.Group discussion of 5 to 7 ft seperation between 7"wellbore&current lateral @ 7450'.Doglegs increased with more WOB&less pump rate.Continue drilling ahead. Shale chunks found in choke during blow back.Overpull seen twice during wiper at 6776'.full rate. 00:00 01:30 1.50 2,500 62 PROD6 DRILL TRIP T Jet SSSV&POOH to surface. 01:30 02:00 0.50 62 62 PROD6 DRILL PULD T Shut SSSV&flow check-Good test. PJSM for laying down BHA. 02:00 03:30 1.50 0 72 PROD6 DRILL PULD T Lay down BHA#23&P/U BHA#24 with 1.0 AKO-new 3.00"Bi-center bit. 03:30 05:30 2.00 72 6,510 PROD6 DRILL TRIP T Open EDC-pressure up above SSSV to 700 psi. Pump SSSV open -equalize 670 psi. RIH. 05:30 05:45 0.25 6,510 6,565 PROD6 DRILL DLOG T Tie in depth+23 correction. Corrections have been consistent to -15-18'.The change in depth corrections is due to changing out BHI counter with new friction wheel on trip 23 build BHA on 3/6/12 05:45 06:30 0.75 6,565 6,975 PROD6 DRILL TRIP T Close EDC, RIH to drill. 06:30 09:30 3.00 6,975 7,090 PROD6 DRILL DRLG T Drill Ahead 1.47 BPM,3785 CTP, 15K CTW,3955 BHP 09:30 09:36 0.10 7,090 7,090 PROD6 DRILL WPRT T Stall 7090'. PU 32K PUW, RBIH. 09:36 10:36 1.00 7,090 7,125 PROD6 DRILL DRLG T Drill Ahead 1.45 BPM,3733 CTP, 3920 BHP, 17K CTW 10:36 10:48 0.20 7,125 7,125 PROD6 DRILL WPRT T Stall,Wiper trip back to window,35K 10:48 11:33 0.75 7,125 7,125 PROD6 DRILL DLOG T MADD pass build section. 6975'-6677' 10:50am-Out MW increased at bottoms up time indication increase of cuttings at surface. 11:33 11:45 0.20 7,125 7,125 PROD6 DRILL WPRT T RBIH 11:45 16:30 4.75 7,125 7,275 PROD6 DRILL DRLG T Drill Ahead 1.4 BPM,3566 CTP, 3927 BHP, ratty drilling/7 stalls. MW out increases when tagging bottom starting to drill from wiper trip Page 26 of 32 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 16:30 19:00 2.50 7,275 7,275 PROD6 DRILL WPRT T Wiper trip to window,31K PUW. Conference call to town @ 18:10 decision made to drill with more WOB to increase doglegs,max. depth to drill 40'(7315')for survey results. Blow choke back during wiper (surging)-shale chunks during blow back. 19:00 20:00 1.00 7,275 7,315 PROD6 DRILL DRLG T Drilling ahead-1.35 bpm,3320, BHP 3865,WOB 2.5 K, ROP 35,CT weight 14K. Stall 7278'3K WOB. Drill ahead 1.35 bpm,WOB 2.9K. ROP 38. Stall 7299'. Drill Ahead to 7315'Avg doglegs 14.3. 20:00 21:00 1.00 7,315 7,315 PROD6 DRILL WPRT T Wiper to window-wait on town projection&discussion.Over pull or weight spike @ 6776'pumping 1.5 bpm. Decision to drill ahead. 21:00 00:00 3.00 7,315 7,440 PROD6 DRILL DRLG T Drilling ahead-1.40 bpm,3400, BHP 3880, ROP 70,WOB 1.7K,Ct weight 17K.Multiple stalls(5)but good doglegs of 14. Projected to miss 7" wellbore by 7-8ft. 03/08/2012 Drilled ahead in BL1 lateral.45 bbl losses for 24 hours. 00:00 00:30 0.50 7,440 7,465 PROD6 DRILL DRLG T Drilling ahead 00:30 01:30 1.00 7,465 7,465 PROD6 DRILL WPRT T Wiper trip-gain in Density out rate. No overpulls @ 6776'full pump rate. Tie in correction-2ft. 01:30 05:30 4.00 7,465 7,615 PROD6 DRILL DRLG T Drilling ahead-1.45 bpm,3580, BHP 3930, ROP 65,WOB 1.7K,Ct weight 15K. No stalls. Pump 5/5 sweep before wiper trip. 05:30 06:45 1.25 7,615 7,615 PROD6 DRILL WPRT T Wiper trip to window.31K PUW, 06:45 09:15 2.50 7,615 7,765 PROD6 DRILL DRLG T Drill Ahead 1.43 BPM,3670 CTP, 3930 BHP, 15K CTW 09:15 10:45 1.50 7,765 7,765 PROD6 DRILL WPRT T Wiper trip to window 31K PUW, Increase on MW out at bottoms up time once pickup off bottom.940am. Take surveys from 7625-7630, 7655-7660 10:45 13:15 2.50 7,765 7,915 PROD6 DRILL DRLG T Drill Ahead 1.43 BPM,3670 CTP, 3930 BHP, 15K CTW 13:15 15:00 1.75 7,915 7,915 PROD6 DRILL WPRT T Wiper Trip to window 31K PUW, Increase in out MW on bottoms up time @ 1330.-3ft correction on tie in. 15:00 17:00 2.00 7,915 8,057 PROD6 DRILL DRLG T Drill Ahead 1.43 BPM,3670 CTP, 3930 BHP, 15K CTW 17:00 19:00 2.00 8,057 8,057 PROD6 DRILL WPRT T Wiper trip Page 27 of 32 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 19:00 22:30 3.50 8,057 8,215 PROD6 DRILL DRLG T Drilling-1.40 bpm, 3680,BHP 4010, WOB 1.5K,CT weight 13.5K. Stacking weight @ 8090-8110'P/U 36K.a couple of times due to weight transfer&slow ROP 15.8115'- better WOB&CT weight transfer ROP 55. 22:30 00:00 1.50 8,215 8,215 PROD6 DRILL WPRT T Pump 5/5 sweep-Wiper trip-P/U 33K Increase in Density out during wiper trip. 03/09/2012 While drilling noticed a loss in circ pressure. Discovered a pinhole in CT string @ 6981'. POOH for reel swap. Purge CT string and begin to swap CT reel. 00:00 00:30 0.50 8,215 8,215 PROD6 DRILL WPRT T Wiper trip 00:30 02:00 1.50 8,215 8,235 PROD6 DRILL DRLG T Drilling ahead-1.40 bpm,3780, BHP 4030, ROP 12,WOB 1.8K,CT weight 11K.Numerous stalls.(4) 02:00 06:00 4.00 8,235 8,365 PROD6 DRILL DRLG T Mud swap 1755ft on system-Drilling 1.43 bpm,3730, BHP 3945, ROP 21, WOB 2.6K,Ct weight 14K. Started to lose returns @ 8260'. P/U clean 31K.Continue drilling 1.41 bpm,rate out 1.25 bpm.Multiple stalls.(7).20 bbls losses since midnight. 06:00 08:30 2.50 8,365 8,365 PROD6 DRILL WPRT T Wiper trip to window.Tie in depth-7' correction 08:30 10:00 1.50 8,365 8,460 PROD6 DRILL DRLG T Drill Ahead 1.4 BPM 3623 CTP,4670 BHP, 13K CTW 10:00 10:15 0.25 8,460 8,463 PROD6 DRILL WPRT T PU weight check.33K. Drill Ahead 10:15 11:15 1.00 8,463 8,463 PROD6 DRILL WPRT T Pull wiper trip early. Losing Pump pressure&bore pressure.500-600 psi pressure drop.Keep rig floor clear. POOH slowly on wiper trip monitoring for possible pin hole in coil.8:30 on bottom CTP 3623 psi, 10:00 on bottom CTP 3000 psi. High fatigue areas 7926',6975'free end. 8000',7046'bit depth. 11:15 11:45 0.50 6,981 6,981 PROD6 DRILL WPRT T Pinhole in Coil.Shut down pumps. Place pinhole in chains. Bleed CT pressure.Verify check valves are holding. Line up to pump down MP line 11:45 14:45 3.00 6,981 0 PROD6 DRILL TRIP T POOH flag pinhole on CT 14:45 15:15 0.50 0 0 PROD6 DRILL SFTY T At surface. PJSM.close SSSV.flow check 15:15 16:30 1.25 0 0 PROD6 DRILL PULD T LD BHA 16:30 18:00 1.50 0 0 PROD6 DRILL CIRC T Stab back onto well flush and blow down CT with N2. 18:00 19:00 1.00 0 0 PROD6 DRILL SFTY T Crew change PJSM for unstabbing pipe&review lessons learned for reel swap. Holding MPD on well- injecting 2-3 bbl/hour. Page 28 of 32 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:00 22:00 3.00 0 0 PROD6 DRILL CTOP T Set up rig floor, remove reel counter, HP iron inside the reel&install CT cable grapple.Unstab pipe. 22:00 00:00 2.00 0 0 PROD6 DRILL CTOP T Secure reel and remove spacer flanges. Remove outside equipment from under the reel pan. 03/10/2012 Weekly BOPE function test,Swap reels, install new skates,pump slack and trim 12ft of pipe. Install connector,pull test 35K, pressure test 4000psi.Clean up&ready to P/U BHA#25. 00:00 06:00 6.00 0 0 PROD6 DRILL CTOP T Swap reels&install spacer flanges. Begin working on skates.25 bbls injected down MPD since 18:00 hrs. 06:00 06:30 0.50 0 0 PROD6 DRILL CTOP T Crew change. PJSM 06:30 13:30 7.00 0 0 PROD6 DRILL CTOP T Install skates and stripper,MU inner iron and pressure bulk head inside reel. 13:30 14:30 1.00 0 0 PROD6 DRILL CTOP T Prepare to stab CT 14:30 15:00 0.50 0 0 PROD6 DRILL CTOP T PJSM for stabbing CT 15:00 15:15 0.25 0 0 PROD6 DRILL CTOP T Stab CT 15:15 16:00 0.75 0 0 PROD6 DRILL CTOP T Prepare to reverse circulate 16:00 17:00 1.00 0 0 PROD6 DRILL CTOP T Circulate heated SW thru CT 17:00 17:15 0.25 0 0 PROD6 DRILL CTOP T Pressure test inner reel iron and bulk head 17:15 17:45 0.50 0 0 PROD6 DRILL CTOP T Lift off well prepare to cut CT back. 12ft trimmed. 17:45 21:45 4.00 0 0 PROD6 DRILL CTOP T Crew change PJSM-re-head CT connector tidy up rig floor.Pull test 35K. pressure test to 4K.Mig cable. _ Good 21:45 23:15 1.50 0 0 PROD6 DRILL CIRC T Circ flo-pro into reel and clean up rig floor and reel area. 23:15 00:00 0.75 0 0 PROD6 DRILL SFTY T Set up rig floor and PJSM for deploying BHA#25. 03/11/2012 Rlh with Drilling BHA and started to drill ahead. Noticed shale chunks crossing the shaker-wiper early. Trouble spot from 7033'-7050'.Clean and condition hole,continue drilling ahead..61 bbls lost to formation in 24 hours. 00:00 01:30 1.50 0 72 PROD6 DRILL PULD T Deploy BHA#25 with 1 AKo&3" Bi-center. 01:30 05:30 4.00 72 6,530 PROD6 DRILL TRIP T RIh pumping 1 bpm through EDC. Weight&pipe inspection at 1000' everything looked good.+4ft correction.Close EDC. P/U 200ft to inspect CT during weight check. P/U weight 30K 05:30 06:45 1.25 6,530 8,469 PROD6 DRILL TRIP T Crew change-RIh through window and Open hole, hole looks good. ***45hrs total turn around on reel swap/skate change. Starting time from PU for pinhole to on bottom drilling*** 60bbrls total pumped on MP Page 29 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:45 08:30 1.75 8,469 8,535 PROD6 DRILL DRLG T Drill ahead 1.42 BPM in, 1.33 out. 3621 CTP, 16K CTW 08:30 08:39 0.15 8,535 8,535 PROD6 DRILL WPRT T Stacking weight, PU for BHA wiper, 36K 08:39 10:39 2.00 8,535 8,610 PROD6 DRILL DRLG T Drill ahead 1.42 BPM in, 1.33 out. 3795 CTP,5K CTW 10:39 12:15 1.60 8,610 8,610 PROD6 DRILL WPRT T Wiper trip to window 12:15 13:21 1.10 8,610 8,610 PROD6 DRILL WPRT T Tag up 7037'-7057'. PU 40K PUW. Work pipe free. RBIH.bottoms up small shale over shaker 1/2 dime size.cont.RIH 13:21 14:21 1.00 8,610 8,650 PROD6 DRILL DRLG T Drill ahead 1.42 BPM in, 1.33 out. 3850 CTP,9K CTW 14:21 15:51 1.50 8,650 8,650 PROD6 DRILL WPRT T Annular pressure, Bore pressure increasing. Hole loading up. Pump low/high sweeps. PUH to 7900'for short wiper trip.At 15:00 large increase in MW out. Bottoms up time. Hole cleaned up of cuttings. 15:51 19:00 3.15 8,650 8,760 PROD6 DRILL DRLG T Drill ahead 1.45 BPM in, 1.35 out. 3972 CTP, 13K CTW.Wiper up 40 ft at crew change. P/U weight 32K. Fix electronic counter problems. Continue drilling ahead. 19:00 22:00 3.00 8,760 8,760 PROD6 DRILL WPRT T Pump 5/5 sweeps-Wiper trip-32K P/U weight. Kept full pump rate while wipng and saw small weight bobble @ 7033'while POOH.Tie in-3ft correction. RIH small weight bobble @ 6776' .3bpm.Set down @ 7044' 1 bpm, P/U clean 31K, RIH .6 bpm,small bobbles at 7033'&7045'. Increase rate to 1.2 bpm @ 7070'-RIH. 22:00 00:00 2.00 8,760 8,822 PROD6 DRILL DRLG T Drilling ahead-1.40 bpm,3880, BHP 4040, ROP 25,WOB 1.8K. 03/12/2012 TD BL1 lateral @ 8962'-Wiper to swab valves, RIH&Lay in liner pill followed by 12#KWF. EOP flags 7700' &5400'. Flow-check and lay down BHA. 24 losses=52 bbls of flo-pro&12 bbls of KWF 00:00 03:00 3.00 8,822 8,905 PROD6 DRILL DRLG T Drilling ahead-1.40 bpm,3910, BHP 4050,ROP 47,WOB 1K,Ct weight 11K.Stall @ 8890'-hard time transfering WOB after stall,pull wiper 5ft early. 03:00 06:00 3.00 8,905 8,910 PROD6 DRILL WPRT T Pump 5/5 sweeps Wiper trip 32K P/U weight.Clean through 7033' section during wiper up. 06:00 09:30 3.50 8,910 8,962 PROD6 DRILL DRLG T Ratty drilling,slow ROP's,multiple stalls,cont.drilling.small pebble shales coming across shakers.Call TD 09:30 09:45 0.25 8,962 8,962 PROD6 DRILL WPRT T Pump low/high sweeps PUH slowly pumping sweeps to bit. RBIH to TD 09:45 11:30 1.75 8,962 2,600 PROD6 DRILL WPRT T Sweeps at bit POOH to swab valves 11:30 11:36 0.10 2,600 2,000 PROD6 DRILL WPRT T Large increase in cuttings to surface. Cont POOH Page 30 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:36 12:51 1.25 2,000 2,400 PROD6 DRILL WPRT T RBIH performing JOG to 2400' 12:51 13:36 0.75 2,400 0 PROD6 DRILL WPRT T POOH to swabs 13:36 13:51 0.25 0 0 PROD6 DRILL WPRT T Flush and blow back MP choke. 13:51 15:21 1.50 0 6,500 PROD6 DRILL WPRT T RBIH 15:21 15:36 0.25 6,500 6,500 PROD6 DRILL DLOG T Tie in depth,-19'correction,close EDC. 15:36 16:54 1.30 6,500 8,962 PROD6 DRILL WPRT T RIH to TD,7030-7060'Looks good. 16:54 18:54 2.00 8,962 8,962 PROD6 DRILL TRIP T Tag TD. EOP 7700'flag. POOH laying in liner pill.8 bpm,50 fpm.Tie into formation-5ft correction. Checked counter&it was loose. Tighten. 18:54 20:54 2.00 6,500 6,500 PROD6 DRILL TRIP T POOH lay in KWF-Flag EOP 5400' POOH, KWf to surface at 1200ft. • 20:54 22:24 1.50 72 0 PROD6 DRILL PULD T Flow check for 15 minutes-PJSM for laying down BHA.lay down BHA. BIt&motor looked good.Top up well with 1 bbl. 22:24 00:00 1.60 0 COMPZ CASING RGRP T Set up'rig floor for liner run.PJSM Service top drive and do a Safety jiont drill. 03/13/2012 Ran liner in two sections from 8957'-6640'. Recover KWF&pumped,SW followed by SD for freeze protecting. Undeploy BHA, Flushed CT&stack with water&corrosion inhibitor. 00:00 02:00 2.00. 0 1,149 COMPZ CASING PUTB P P/U 35 joints of 2 3/8"Slotted liner. 02:00 02:30 0.50 1,149 1,194 COMPZ CASING PULD P P/U coil track assembly. 02:30 04:30 2.00 1,194 7,980 COMPZ CASING RUNL P RIH with EDC closed pumping . 3bpm. Flag correction+21ft. P/U weight @ 6614'32K. RIH weight 22K -4K WOB.Stop pumping down the coil. 04:30 05:00 0.50 7,980 8,957 COMPZ CASING RUNL P Stacked out WOB+8K, P/U weight 43K, P/U 100ft-BHP 3910 psi. RIH Pumping .3 down backside.30 psi on WHP&4060 BHP. Drifted through clean. Tag TD @ 8957'P/U weight 39K. -3WOB.Tag bottom and pump down CT. BOL=8957' /TOL=7809' 05:00 05:30 0.50 8,957 7,802 COMPZ CASING TRIP P Pump 1.2 bpm, P/U weight 32K. P/U 30ft and set up pumping down the backside with POOH. Reset counters to actual bit depth 05:30 05:48 0.30 7,802 6,475 COMPZ CASING DLOG P Tie in for-7'correction 05:48 07:54 2.10 6,475 41 COMPZ CASING TRIP P POOH for upper liner section, Paint 5300'EOP flag 07:54 08:54 1.00 41 0 COMPZ CASING PULD P PJSM, Lay down liner running tools 08:54 10:48 1.90 0 1,165 COMPZ CASING PUTB P PJSM, P/U 35 Jts slotted liner and 1 5.81'pup 10:48 11:30 0.70 1,165 1,210 COMPZ CASING PULD P P/U liner running tools/Coil track, M/U to coil and surface test Page 31 of 32 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:30 13:15 1.75 1,210 6,509 COMPZ CASING TRIP P Trip in well 13:15 13:33 0.30 6,509 7,645 COMPZ CASING TRIP P Correct to flag-15',continue in well 13:33 13:45 0.20 7,645 7,702 COMPZ CASING DLOG P Log K1 marker,correct-7', 13:45 13:57 0.20 7,702 7,806 COMPZ CASING TRIP P 7806 Tag up. PUW=39K,set back down and pump off liner, PUW=32K BOL=8957,TOL=6640 13:57 14:45 0.80 7,806 6,627 COMPZ CASING CIRC P PUH,Subtract liner left in hole, -1165.75,displace 12.0PPG completion fluid to seawater 14:45 17:00 2.25 6,627 69 COMPZ CASING TRIP P Trip out of well,start pumping diesel freeze protect from 4597, Pump 21 BBIs 17:00 18:00 1.00 69 69 COMPZ CASING PULD P PJSm to undeploy BHA#27 P Y 18:00 19:00 1.00 69 0 COMPZ CASING PULD P Crew change Undeploy BHA 19:00 21:30 2.50 0 0 DEMOB WELLPF CTOP P Set up rig floor and pits for corrossion pump,flush&purge. PJSM with LRS for pumping inhibitor. Pump through CT,Stack to Tiger tank. 21:30 23:30 2.00 0 0 PROD6 WELLPF CTOP P Blow down CT string to pits. 23:30 00:00 0.50 0 0 PROD6 WELLPF MPSP P PJSM for setting BPV.Set BPV with 520 psi below. 03/14/2012 Continue RDMO, Release Rig 0600 00:00 02:00 2.00 0 0 DEMOB WELLPF MPSP P Set BPV with 530 psi below. 02:00 06:00 4.00 0 0 DEMOB RIGMNISEQP P Rig down hard lines, BOP's and clean all pits. 0 DEMOB ****Rig Release**** Page 32 of 32 Post Rig Well Work Summary DATE SUMMARY 3/25/12 GAUGED TBG TO 2.73"TO L._.R TOP @ 6640' RKB. MEASURED BHP lw 6260' RKB: 3073 PSI. SET CATCHER @ 6626' SLM. PULLED DVs @ 6001', 5448', 4772', &3709' RKB. IN PROGRESS. 3/26/12 PULLED DV @ 2504' RKB. SET GLVs @ 2504', 3709',4772', &5449' RKB. SET OV @ 6001' RKB. PULLED CATCHER @ 6623' SLM. COMPLETE. • • • Letter of Transmittal rails BAKER Date: March 14 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/Sachin Gandra 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 fol. ging well(s): 1E-24BL1 212-7c 1E-24BL1PB1 1E-24BL1PB2 RECEIVED 1E-24BL1PB3 MAR 16 2012 1E-24BL2 Z\ t 1 1E-24BL2-01 212 \ AOG CC 1E-24BL2-02 (7) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files SCANNED MAR 1 3 2018 Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich • BakerHughes.com • • Q OJ oma c ri E CD CD o n,, -0 -0 Q Pi '11 �.l —■ c 0, . -. , poi( CC CD Zrt 00.. cow 9" M > CD 0 N VI o M 27 o 0 G) ~ m n 0 N a ( �• w ( N a 3. 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O) d p . — a co co CO 05 ao U U Od N 0 = Q it xit G � f�-'= f I '; [ ' `V� r �I� -$� I I r kI 4 �t' 'j 'p { ti ¢y p SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS / 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONANCHORAGE,ALASKA 99501-3539 7i PHONE (907)279-1433 6 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-24BL2-02 ConocoPhillips Alaska, Inc. Permit No: 212-027 Surface Location: 171' FSL, 226' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 1403' FNL, 1196' FEL, SEC. 21, T11N, R10E, UM Dear Mr. Gantt: 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 KRU 1E-24B, Permit No 211- 151, API 50-029-20857-02. 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 Commission 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 Commission 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 a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. -rel , diffaV o-n orm. Corn 's 'oner 4 DATEDhi March, t s _ dayof2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) Fisher, Samantha J (DOA) From: Foerster, Catherine P (DOA) Sent: Thursday, March 08, 2012 10:07 AM To: Fisher, Samantha J (DOA) Subject: Re: 1 E-24BL2-02 Approve Sent from my iPhone On Mar 8,2012,at 12:54 PM, "Fisher,Samantha J(DOA)" <samantha.fisher@alaska.gov>wrote: > Please approve. >Thank you, >Samantha Fisher,Executive Secretary II > Alaska Oil and Gas Conservation Commission > (907)793-1223 > <S45C-212030809420.pdf> 1 ConocoPhillips pp s Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 27th, 2011 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 a Permit to Drill application for an additional lateral designated 1 E- 24BL2-02 to the 1E-24B CTD project. The laterals already permitted for the 1E-24 CTD project are 1 E-24BL1 (PTD 212-009), 1 E-24BL1-01 (PTD 212-010), 1 E-24BL2 (PTD 212-011), and 1 E-24BL2-01 (PTD 212-012). The 1E-24B CTD project was originally permitted as a quad lateral targeting the Kuparuk A sand. The proposed 1 E-24BL2-02 lateral is based on our new fault interpretation after drilling the 1 E-24BL2 lateral. Adding the 1 E- 24BL2-02 lateral will be more effective at reaching targets west of those faults crossed while drilling the L2 lateral. Verbal approval was granted 2/27/2012 via e-mail. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Form for 1 E-24BL2-02 — Proposed Completion Schematic — Summary of Operations — Directional Plan If you have any questions or require additional information regarding the 1 E-24BL2-02 Application for Permit to Drill, please call 907-265-6820. Sincerely, ,,....iA 4.) Mike A. Wi ee ConocoPhillips Alaska CTD Drilling Engineer STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL FEB 2 9 2012 20 MC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑- Service-Winj ❑ Single Zone [11 k8F(atify'ifG(g°03ryss�• mlS • 8►1 Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zon ❑ Coalbed GasgtoraTtas Hydrates LJ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ sh le c f1 2.Operator Name: 5. Bond: U Blanket H Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 - 1E-24BL2-02 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:8560' • TVDSS: 6175' - Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 171'FSL,226'FEL,Sec. 16,T11N,R10E,UM ' ADL 25651 • Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1335'FNL,511'FEL,Sec.21,T11N,R10E,UM - 2657 2/27/2012 Total Depth: 9.Acres in Property: 14.Distance to 1403'FNL, 1196'FEL,Sec.21,T11N,R10E,UM . 2560 Nearest Property: 20750;to KPA Mr,nri,ry 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: `95 feet 15.Distance to Nearest Well Open Surface:x- 550301, y- 5959761 • Zone- 4 GL Elevation above MSL: • 67 feet to Same Pool: 1 E-29 @ 300', 16.Deviated wells: Kickoff depth: . 7850 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 100° deg Downhole:4060 psig • Surface:3443 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight , Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 STL 1210' 7350' 6188'- 8560' 6175' 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 ND(ft): Junk(measured) 6940 6411 6837 6195 Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" 326 sx AS II 112' 112' Surface 2398' 10.75" 1400 sx ASIII,250 sx AS I 2398' 2398' Intermediate 4914' 7" 700 sx Class G 4914' 4536' Production 1775' 5.5" 179 sx Class G 6458' 6007' Liner 649' 3.5" 72 sx Class G 6937' 6196' Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Property Plat H BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report H Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Guy Schwartz Date: 2/27/2012 Alio 22. I hereby certify that the foregoing is true and correct. Contact Mike Winfree @ 265-6820 Printed Name L. Gantt Title CTD Engineering Supervisor Signature L.i2Z�`t�•�.�TO!^ Phon 263-4021 Date 2 —Z•g_/ Z Commission Use Only Permit to Drill. API Number: Permit Appr val See cover letter Number: •-. ._/ G-, C,-)-z7 50-O4•__Za957-'6 47-60 Date: ``Z for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydr-tes,or gas contained in shales: d •� c�/ i tlsL aeo . Samples req'd: Yes El;No M d log req'd: Yes ❑ No [V Other: r Y H2S measures: Yes [�No ❑ •ir-cti• al svy req'd: Yes [' No ❑ r Alre APPROV • BY THE COMMISSION DATE: _ _ / R /4°I IF/ ,COMMISSIONER Form 10-401 (Revised 7/2009) Thispermit is valid for,. s -f tke e`of' ) ,V @ td ; •• •AAC 25.005(g)) Smit in"plicate P-e- 3. 7i� G� �'�L 3) Kuparuk CTD Laterals NAHORr1 ALASKA 1 E-24BL2-02 12 Application for Permit to Drill Document 2nc 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program for 1 E-24BL2-02 Operations 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 5 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1 E-24BL2-02 7 Attachment 2: Proposed Well Schematic for 1 E-24BL2-02 7 Page 1of7t � � �� 2/29/2012 1D Application: 1 E-24BL2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed lateral described in this document is 1E-24BL2-02. This lateral will be classified as "Development- Oif'. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 171' FSL, 226' FEL, Sec 16, T11N, R10E, UM NAD 1927 RKB Elevation 95 AMSL Northings: 5959760 Eastings: 550300 Pad Elevation 67 AMSL 1 E-24BL2-02 Location at Top of Productive Horizon 1335' FNL, 511' FEL, Sec 21, T11N, R10E, UM • (Kuparuk A5) NAD 1927 Measured Depth, RKB: 7850' Northings: 5958262 Eastings: 550029 Total Vertical Depth, SS: 6168' Location at Total Depth 1403' FNL, 1196' FEL, Sec 21, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8560' Northings: 5958180 Eastings: 549344 Total Vertical Depth, SS: 6175' Page 2 of 7 CRIG1NJL 2/29/2012 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 pressure in the area of 4060 psi. the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3443 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 114A sp « 3 44 �Lv 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)) While drilling 1E-24B with Doyon 141 (December 2011), the fluid weight at TD (6940'MD/6411'TVD) at which the reservoir (both A and C sands combined) remained static was 11.8 ppg. Based up on this static data, the anticipated bottomhole pressure at the kickoff point (KOP) is 3,819 psi, an 11.8 ppg equivalent mud weight (EMW). The maximum downhole pressure in the 1E-24B pattern is near injector 1E-23. 1E-23 has been shut-in since September 2011. An updated static bottomhole pressure (BHP) reading was obtained on 11/9/2011, indicating a pressure of 4060 psi at 7676' MD/6073' TVDSS. This would be the equivalent of 12.9ppg fluid. Using this pressure as the maximum possible in 1E-24B, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3,443 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 1E pad did have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 1E-24B laterals will be at fault crossings. 3 of the 4 laterals will encounter faults with throws in the 30'-40' range. After seeing the first fault, the subsequent geologic interpretation of the folloing lateral can be adjusted to minimize the risk of drilling out of zone. 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. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 1 E-24BL2-02 7300 8560 6188 . 6175 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Page 3 of 7 ORIGIf'\ 1L 2/29/2012 Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (PO MD Connection MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 0' 112' 0' 112' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 0' 2,399' 0' 2,399' 3580 2090 Casing 7" 26 K-55 BTC 0 4,914 0' 4,630' 4980 4330 Liner 5-1/2" 15.5 L-80 Hydril 563 4,682' 6,459' 4,435' 6,007' 7000 4990 Liner 3-1/2 " 9.3 L-80 Hydril 511 6,288' 6,937' 5,843' 6,408' 10160 10,540 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0' 6,274' 0' 5,853' 10160 10,540 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 Biozan brine (8.6 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5-10.5 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 E-24B contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this ' case, however, a constant BHP target of 11.8 ppg (target may change based on base fluid weight and acceptable choke pressure for MPD operations), targeted at the window, is available based on data from the recently drilled 1E-24B parent wellbore. 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. Page 4 of 7 ORIGINAL 2/29/2012 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program for 1 E-24BL2-02 Operations (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Kuparuk well 1 E-24A was sidetracked and completed as 1 E-24B in December 2011 as a set-up for four CTD laterals. The 3-1/2" liner across the reservoir was cemented in place and has not been perforated. The plan for the parent wellbore is to leave it as "suspended"; i.e. not open the parent up to production. At this time, the only __ production from 1E-24B will come from the CTD laterals. Drilling CTD laterals and redeveloping the 1 E-24B producer-centered pattern will improve productivity and increase oil recovery in this historically underperforming A-sand pattern 3 laterals, 1 E-24BL1 PB1, 1 E-24BL1 PB2, and 1 E-24BL1 PB3 were drilled to the east off of a whipstock set at 6,713' MD. The laterals were lost due to hole stability issues. The rig set another whipstock at 6,690' MD and kicked off to drill the already permitted western laterals 1 E-24BL2, and 1 E-24BL2-01. After drilling the BL2 lateral, the new geologic interpretation shows a fault that potentially isolates some A4 pay. The purpose of the BL2-02 lateral is to acquire the A4 pay west of that fault. The 1 E-24BL2-02 lateral will kick off from the aluminum billet at 7,850' MD and will target the A4 sand west of a fault mapped after drilling the 1 E-24BL2 lateral. The planned lateral length is 700' MD and TD is expected at 8,550' MD. The hole will be completed with a 2%" slotted liner from TD of 8,550' MD with the anchored billet liner top located at—7,300' MD Rig Work 1. Run 2-3/8" slotted liner in 1 E-24BL2 lateral spacing the liner top (Al anchored billet) at 7,850' MD 2. Kick off aluminum anchored billet set at 7,850' MD with KO Tool Face of 150°ROHS 3. Drill 1E-24BL2-02 Lateral a. Drill 2.80" x 3.25" bi-center lateral in the A4 sand to a TD of 8,560' MD b. Run 2%" slotted liner from TD to —7,300', utilizing the SSSV for deploying the liner 4. Drill 1E-24BL2-01 Lateral as Permitted 5. Continue with previously permitted operations. Pressure Deployment of BHA The double swab valves, double deployment rams, double ball valves and one set of double check valves in the BHA, and a slick line lubricator are used to deploy/undeploy the BHA under pressure. The Managed ' Pressure Drilling technique is used to maintain an overbalance on the formation, pumping below the swab Page 5 of 7 ORIGU\LAL 2/29/2012 valve, during the deployment procedure. The pressure control equipment listed ensures there are always two barriers to reservoir pressure during the BHA deploy/undeploy process. When the lubricator is installed and the BHA is spaced out above the tree, the double swab valves are closed and provide isolation to reservoir pressure. When the BHA is spaced out for access to the double ball valves, the set of double check valves and the double ball valves in the bottom hole assembly are preventing wellbore pressure communication up the BHA. The double deployment rams and lubricator are annular barriers to reservoir pressure with the BHA in this position. The lubricator can be removed once pressure is bled off above the deployment rams. Two barriers are still maintained with the double deployment rams on the annulus and the double check valves and double ball valves in the BHA. With the coil made up to the BHA, the double ball valves open in the BHA, and the riser installed, the BHA can continue to be safely run in the hole. Page 6 of 7 ORIGIN A [ 2/29/2012 Liner Running — Since 1E-24B is equipped with a SSSV, the 1E-24B CTD laterals will not need to be displaced to an overbalancing fluid prior to running liner unless the SSSV fails to operate properly. See the "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 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 1 E-24BL2-02 20,750' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 1 E-24BL2 300' 1 E-29 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 1E-24BL2-02 Attachment 2: Proposed Well Schematic for 1E-24BL2-02 Page 7 of 7 JI ! G / 1\!i 2/29/2012 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-24 1 E-24BL2-02 Plan: 1 E-24BL2-02wp02 Standard Planning Report 28 February, 2012 ORIGINAL �•' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-24BL2-02 Design: 1 E-24BL2-02_wp02 Project Kuparuk River Unit 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 1E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Fasting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1 E-24 Well Position +N/-S 0.00 ft Northing: 5,959,760.73 ft Latitude: 70°18'2.999 N +E/-W 0.00 ft Easting: 550,300.55 ft Longitude: 149°35'33.373 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 67.00ft Wellbore 1 E-24BL2-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 2/27/2012 16.44 79.91 57,376 Design 1 E 24BL2-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,835.49 , Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -67.00 0.00 0.00 275.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 7,835.49 94.76 265.38 6,169.89 -1,505.06 -267.26 0.00 0.00 0.00 0.00 7,850.00 94.02 264.06 6,168.78 -1,506.39 -281.67 10.41 -5.10 -9.10 -119.30 7,910.00 86.74 268.26 6,168.38 -1,510.41 -341.48 14.00 -12.13 6.99 150.00 7,940.00 84.65 271.91 6,170.63 -1,510.37 -371.39 14.00 -6.97 12.17 120.00 7,970.00 84.66 276.13 6,173.43 -1,508.28 -401.18 14.00 0.05 14.06 90.00 8,000.00 86.77 279.77 6,175.67 -1,504.14 -430.80 14.00 7.03 12.14 60.00 8,030.00 90.41 281.87 6,176.41 -1,498.51 -460.25 14.00 12.13 7.00 30.00 8,100.00 100.21 281.87 6,169.94 -1,484.20 -528.38 14.00 14.00 0.00 0.00 8,200.00 89.88 272.37 6,161.13 -1,471.95 -626.98 14.00 -10.33 -9.50 223.00 8,300.00 84.24 259.54 6,166.29 -1,478.95 -726.35 14.00 -5.64 -12.83 246.00 8,450.00 89.67 239.22 6,174.34 -1,531.48 -865.73 14.00 3.63 -13.55 284.30 8,560.00 89.68 254.62 6,174.96 -1,574.47 -966.61 14.00 0.01 14.00 90.00 2/28/2012 2:51:51PM Page 2 COMPASS 2003.16 Build 69 OR1GNAL o-' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-24BL2-02 Design: 1 E-24BL2-02_wp02 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,835.49 94.76 265.38 6,169.89 -1,505.06 -267.26 135.07 0.00 0.00 5,958,254.06 550,043.39 TIP 7,850.00 94.02 264.06 6,168.78 -1,506.39 -281.67 149.31 10.41 -119.30 5,958,252.63 550,029.001 KOP 7,900.00 87.95 267.56 6,167.92 -1,510.05 -331.50 198.63 14.00 150.00 5,958,248.65 549,979.20' 7,910.00 86.74 268.26 6,168.38 -1,510.41 -341.48 208.54 14.00 150.06 5,958,248.21 549,969.22 3 7,940.00 84.65 271.91 6,170.63 -1,510.37 -371.39 238.34 14.00 120.00 5,958,248.06 549,939.32 4 7,970.00 84.66 276.13 6,173.43 -1,508.28 -401.18 268.20 14.00 90.00 5,958,249.95 549,909.52 5 8,000.00 86.77 279.77 6,175.67 -1,504.14 -430.80 298.07 14.00 60.00 5,958,253.89 549,879.87' 6 8,030.00 90.41 281.87 6,176.41 -1,498.51 -460.25 327.90 14.00 30.00 5,958,259.32 549,850.38 7 8,100.00 100.21 281.87 6,169.94 -1,484.20 -528.38 397.01 14.00 0.00 5,958,273.17 549,782.171 8 1 8,200.00 89.88 272.37 6,161.13 -1,471.95 -626.98 496.31 14.00 -137.00 5,958,284.76 549,683.50 9 8,300.00 84.24 259.54 6,166.29 -1,478.95 -726.35 594.69 14.00 -114.00 5,958,277.10 549,584.18. 10 8,400.00 87.82 245.97 6,173.24 -1,508.48 -821.38 686.78 14.00 -75.70 5,958,246.93 549,489.371 8,450.00 89.67 239.22 6,174.34 -1,531.48 -865.73 728.96 14.00 -74.76 5,958,223.64 549,445.18' 11 8,500.00 89.68 246.22 6,174.62 -1,554.38 -910.14 771.20 14.00 90.00 5,958,200.44 549,400.931 8,560.00 89.68 254.62 6,174.96 . -1,574.47 -966.61 825.71 14.00 89.96 5,958,179.97 549,344.59 TD 2/28/2012 2:51:51PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL • .1•' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-24BL2-02 Design: 1 E-24BL2-02_wp02 [Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (1 (') (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-24BL2_Fault1 (col 0.00 0.00 6,181.00 -1,720.50 339.18 5,958,042.71 550,651.20 70°17'46.078 N 149°35'23.487 W -plan misses target center by 643.67ft at 7835.49ft MD(6169.89 TVD,-1505.06 N,-267.26 E) -Polygon Point 1 6,181.00 -1,930.03 264.78 5,957,832.70 550,578.22 Point 2 6,181.00 -1,720.48 336.18 5,958,042.71 550,648.20 Point 3 6,181.00 -1,511.00 417.58 5,958,252.71 550,728.19 1 E-24BL2-02_T2 0.00 0.00 6,161.00 -1,504.98 -629.48 5,958,251.72 549,681.22 70°17'48.198 N 149°35'51.721 W -plan misses target center by 33.28ft at 8204.81ft MD(6161.15 TVD,-1471.78 N,-631.79 E) -Point 1E-24BL2-02_T1 0.00 0.00 6,173.00 -1,512.61 -386.50 5,958,245.72 549,924.22 70°17'48.123 N 149°35 44.639 W -plan misses target center by 3.17ft at 7955.08ft MD(6172.04 TVD,-1509.59 N,-386.38 E) -Point 1E-24BL2,6L2-01 Po 0.00 0.00 0.00 -1,447.98 862.06 5,958,318.69 551,172.20 70°17'48.758 N 149°35'8.245 W' -plan misses target center by 6272.65ft at 7835.49ft MD(6169.89 TVD,-1505.06 N,-267.26 E) -Polygon Point 1 0.00 -1,447.98 862.06 5,958,318.69 551,172.20 Point 2 0.00 -1,943.07 716.75 5,957,822.69 551,030.22 Point 3 0.00 -1,909.03 409.94 5,957,854.67 550,723.22 Point4 0.00 -1,732.88 -60.94 5,958,027.65 550,251.21 Point 5 0.00 -1,722.27 -604.94 5,958,034.61 549,707.21 Point6 0.00 -1,821.56 -1,014.65 5,957,932.59 549,298.21 Point 7 0.00 -1,459.32 -1,044.24 5,958,294.59 549,266.20 Point8 0.00 -1,335.77 -673.38 5,958,420.61 549,636.19 Point9 0.00 -1,443.38 169.01 5,958,318.65 550,479.20 Point 10 0.00 -1,641.64 506.73 5,958,122.68 550,818.21 Point 11 0.00 -1,438.52 642.10 5,958,326.68 550,952.20 Point 12 0.00 -1,447.98 862.06 5,958,318.69 551,172.20 1E-24BL2-02_T4 0.00 0.00 6,175.00 -1,557.74 -963.86 5,958,196.73 549,347.23 70°17'47.679 N 149°36'1.468 W -plan misses target center by 15.37ft at 8551.79ft MD(6174.91 TVD,-1572.22 N,-958.72 E) -Point 1 E-24BL1 PB_Polygor 0.00 0.00 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 70°17'48.933 N 149°35'15.821 W -plan misses target center by 6231.29ft at 7835.49ft MD(6169.89 TVD,-1505.06 N,-267.26 E) -Polygon Point 1 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 Point2 0.00 -1,447.86 846.06 5,958,318.71 551,156.20 Point3 0.00 -1,558.19 893.33 5,958,208.71 551,204.20 • Point 4 0.00 -1,310.52 1,549.06 5,958,460.74 551,858.20 Point5 0.00 -1,172.79 2,195.05 5,958,602.78 552,503.19 Point6 0.00 -1,092.44 3,046.69 5,958,688.82 553,354.19 Point7 0.00 -1,077.80 3,251.81 5,958,704.83 553,559.19 Point 8 0.00 -1,439.98 3,272.40 5,958,342.83 553,582.20 Point 9 0.00 -1,429.68 2,926.43 5,958,350.81 553,236.20 Point 10 0.00 -1,481.50 2,296.01 5,958,294.78 552,606.20 Point 11 0.00 -1,555.84 1,743.45 5,958,216.75 552,054.21 Point 12 0.00 -1,710.71 1,270.37 5,958,058.73 551,582.22 Point 13 0.00 -1,874.10 1,025.25 5,957,893.72 551,338.22 Point 14 0.00 -1,975.44 772.55 5,957,790.70 551,086.23 Point 15 0.00 -1,848.17 584.37 5,957,916.70 550,897.22 Point 16 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 1 E-24BL2-02 T3 0.00 0.00 6,170.00 -1,491.04 -769.40 5,958,264.72 549,541.23 70°17'48.335 N 149°35'55.800 W -plan misses target center by 1.70ft at 8344.95ft MD(6170.19 TVD,-1489.42 N,-769.87 E) -Point 1E-24BL2-02_Fault2 0.00 0.00 6,173.00 -1,512.61 -386.50 5,958,245.72 549,924.22 70°17'48.123 N 149°35'44.639 W -plan misses target center by 3.17ft at 7955.08ft MD(6172.04 TVD,-1509.59A-386.38 E) 2/28/2012 2:51:51 PM Page 4 COMPASS 2003.16 Build 69 ? RG1NAL • Iv- ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-24BL2-02 Design: 1 E-24BL2-02_wp02 . ,it 9 y -Polygon I Point 1 6,173.00 -1,711.30 -587.84 5,958,045.70 549,724.23 Point 2 6,173.00 -1,512.61 -386.50 5,958,245.72 549,924.22 Point 3 6,173.00 -1,313.92 -185.16 5,958,445.73 550,124.20 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") ('7 2,385.80 2,291.94 10 3/4" 10-3/4 13-1/2 I 6,458.00 5,912.68 5 1/2" 5-1/2 7 8,560.00 6,174.96 2-3/8" 3 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,835.49 6,169.89 -1,505.06 -267.26 TIP 7,850.00 6,168.78 -1,506.39 -281.67 KOP 7,910.00 6,168.38 -1,510.41 -341.48 3 7,940.00 6,170.63 -1,510.37 -371.39 4 7,970.00 6,173.43 -1,508.28 -401.18 5 8,000.00 6,175.67 -1,504.14 -430.80 6 8,030.00 6,176.41 -1,498.51 -460.25 7 8,100.00 6,169.94 -1,484.20 -528.38 8 8,200.00 6,161.13 -1,471.95 -626.98 9 8,300.00 6,166.29 -1,478.95 -726.35 10 8,450.00 6,174.34 -1,531.48 -865.73 11 8,560.00 6,174.96 -1,574.47 -966.61 TD 2/28/2012 2.51:51PM Page 5 COMPASS 2003.16 Build 69 1 ORIGINAL ..... •. • l•• am. 40 0 .4 il Z1 ,.... ... 4 4A rto w _ . A A,0 z . ,,,j,..........e ...,, t ..., e- , —i .— . I .. t'.. ; ., - S st 'i ,n ......... ., — , I .r „,.. I . .4•1.— L --1 1 1 —1i 1 )•.....••••=••••• Wq 40 ...... r..1 ,r. I ... . 5 .. _ t ... 4 ,.- ..* ...-•-• '' :: ) t// 7".....'''': 1' .2g, NI + C*4 i I f S ; f r, \,,,....„...„,..„ k '2 it- L, rs, , s .4„ ; \ss...../ 1 , Lu. r1/4,1 v., '4e 'Za 73. ORIGINAL Page 1 of 2 Schwartz,Guy L(DOA) From: Winfree,Michael Alex(Jr.)[Michael.A.Winfree©conocophillips.com] Sent: Monday, February 27,2012 4:54 PM To: Schwartz,Guy L(DOA) Subject: RE: 1 E-24B CTD Operations(BL2 Permit to Drill#212-011) Thanks. We will submit a 401 as soon as possible. Mike A. W1nfree 907 265 6820 From:Schwartz,Guy L(DOA)[mailto:guy.schwartz@alaska.gov] Sent: Monday, February 27,2012 4:50 PM To:Winfree,Michael Alex(Jr.) Subject: [EXTERNAL]RE: 1E-24B CTD Operations(BL2 Permit to Drill #212-011) Mike, You have verbal approval to start the sidetrack 1 E-24BL2-02 to capture additional A4 pay. Please submit a 401 as soon as possible. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From:Winfree, Michael Alex(Jr.)[mailto:Michael.A.Winfree@conocophillips.com] Sent: Monday, February 27,2012 4:38 PM To:Schwartz,Guy L(DOA) Subject: 1E-24B CTD Operations(BL2 Permit to Drill # 212-011) Guy, As we discussed over the phone,we would like to add a lateral to 1 E-24BL2. 1 E-24BL2-01 has already been permitted and we plan to drill it within the permit details. The proposed lateral will be named 1 E- 24BL2-02 kicking off an aluminum billet from the 1 E-24BL2 lateral at 7,880'MD and targeting the upper A4 pay west of a fault. Please see drawing below for details. Currently the rig is pulling out of the hole to run liner/anchored billet in the 1 E-24BL2 lateral. Pending approval from the state to proceed with operations,the rig would be kicking off the anchored billet tomorrow morning. CPAI requests verbal permission to proceed with the proposed 1 E-24BL2-02 operations as the 10-401 is prepared for submission. Please advise, Thanks, -Mike 2/27/2012 Page 1 of 2 1 Schwartz, Guy L(DOA) From: Winfree,Michael Alex(Jr.)[Michael.A.Winfree@conocophillips.com] Sent: Monday, February 27,2012 4:38 PM To: Schwartz,Guy L(DOA) Subject: 1 E-24B CTD Operations(BL2 Permit to Drill#212-011) Guy, As we discussed over the phone,we would like to ad. - lateral to 1 E-24BL2. 1 E-24BL2-01 has already been permitted and we plan to drill it within the p-• it details. The proposed lateral will be named 1E- 24BL2-02 kicking off an aluminum billet from - 1 E-24BL2 lateral at 7,880'MD and targeting the upper A4 pay west of a fault. Please see drawing below for detai Currently the rig is pulling out - the hole to run liner/anchored billet in the 1 E-24BL2 lateral. Pending approval from the state to .ceed with operations,the rig would be kicking off the anchored billet tomorrow morning. CPAI requests verb. permission to proceed with the proposed 1E-24BL2-02 operations as the 10-401 is prepared for sub .ssion. Please advise Thanks, -Mike ‘,.;1 "1 Vis: 1E-A8 I MJF � IE.2161t-2'-nl (N.ero, 212 0.7) 1 - llllllllllll,, l �'I I�t •1\V iE Llat:j xdr G.,lett,\J / / • l 1E zAtt-2-0-1. ('ro P,ti p[cr�x�'rtb l,id M1• jA4[ K..1• —.roll ilium.- 2/27/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME �/ / C'( l t - .2--- 5L l-0 7 PTD# 2/ 2-- 0 Z- 7 /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ,ec�l C�—v z �/c, � � 1-6—c. POOL: ,, /eU-e_i� C/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore/se ent of existing well / J /6 -�`/ , (If last two digits in/ Permit No. 2// /5/ ,API No. 50-021- z -' ,s 7- G7! API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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