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211-136
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. c j I - 1 3 (0. Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: olor Items: ❑ Maps: ayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: g aS- `y• /s/ Re Project Proofing (V/BY: C Maria Date: 0,� �9. /s/ p 1 Scanning Preparation I x 30 = 30 + (2_5- = TOTAL PAGES S (Count does not include cover sheet) BY: Date: g/c2. j(/ /s/ Production Scanning Stage 1 Page Count from Scanned File: O (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: (-Maria ) Date: gas `t-f /s/ olio 1 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 9 9 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 4 c a) o) 1 oI 1 0 N N J J I 4clil III �0 .-. E N z II(Y LL (YI I�I C I N o ce 0 co II c U R ail . c cc ce ct U.� . r � 'I �} i yU' U` + a LL 6 1 N E a x c (2 a (a E'Ia- 2 a 00 - g o2O2 Q: iUZ Z u) s> p Q 73o -a ,- ► c > ,-- 0 0 OIo 0 0 0 E. o 1-7 J y VIN N N N N N Q Q J cp cc V V V N N U 0 0 Z Ec Q 'o c2 — c c c c c c `1 m c 0 0 a CI) a a a a E R �/ a Y OU 0 0 0 0 0 0 o 0 Ce J c 1 ° U y o rn o rn rn rn rn y m Z j O J U 1 N N o :: : 0 0 0a CL a 6 2wzC t O NIX a� N N a) -o I W o J d U c o Qd' z o y 7 1 A OII a a = .r ill CL O 1 c 0 l z �y o 0 U o c ,a EiJ r (C o O NN 1 d O NC a N ! 01 73 V Lo in N U O J N 0 E 1 JV) J r a M ICCN 1— Z e- 0. 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J 0 F- _i'ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development a Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: October 24,2011 211-136/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 October 12,2011 50-103-20284-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 157'FNL,602'FEL,Sec.22,T1ON,R7E, UM October 13,2011 2L-307L2-01 Top of Productive Horizon: 8.KB(ft above MSL): 152'RKB 15.Field/Pool(s): 2223'FSL,448'FWL,Sec.24,T1ON,RO7E,UM GL(ft above MSL): 28'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1667'FSL,629'FWL,Sec.24,T1ON,RO7E,UM 10164'MD/5387'ND Tarn Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-461049 y- 5927689 Zone-4 10190'MD/5385'ND ADL 380051 TPI: x-467368 y- 5924759 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-467546 y- 5924202 Zone-4 nipple @ 511'MD/511'ND 4599 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1239'MD/1202'ND 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 9592'MD/5461'ND 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" 62.5# H-40 surf 115' surf 115' 24" 9 cu yds High Early 7.625" 29.7# L-80 surf 2905' surf 2307' 9.875" 387 sx ASAI,235 sx Class G 5.5"x 15.5# L-80 surf 8848' surf 5267' • 6.75" 253 sx Class G 3.5" 9.3# L-80 8848' 9709' 5267' 5755' 6.75" included above 2.375" 4.7# L-80 9138' 10164' 5433' 5387' 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" 9709' 6454'MD/4245'ND,8609'MD/5135'ND 8803'MD/5241'ND,9186'MD/5460'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9138'-10164'MD 5433'-5387'ND slotted liner ,-i ,,; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i1PATCH @ 6448'-8850'MD 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) November 5,2011 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/12/2011 12 hours Test Period--> 419 542 5 100% 1800 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 224 psi 689 24-Hour Rate-> 675 1216 10 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+ND 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 RECEIVED' RSDMS Nov 2 1 101f NOV 1 8 Cott Afr--- Form 10-407 Revised 12/2009 CONTINUED ON REV4R8E'' :ill t Gas Cons taSnubmit original only /L-/- -(f ,13-#)4 C 28. GEOLOGIC MARKERS(List all formations and m. ._rs encountered). 29. F. .ATION TESTS NAME MD TVD Well tested? ❑ 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 1239' 1202' needed,and submit detailed test information per 20 AAC 25.071. not attained N/A Formation at total depth: Bermuda 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,Final Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 4-0 01?Ill Printed Nam Vantt Title: CTD Engineering Supervisor Signature CUIV JIA to Phone 263-4021 Date 11//7/// Sharon Allsup-Drake 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 `. 4 ..UP -307L2-01 CorlocoPhillhps ,;,,,,1 Well Attributes `Matt Angle&MD TD -- Alaska. /' WeltboreAPIIUWI Field Name (Well Status Intl(') [PAD(ftKB) Act 6an(BK6) 50103202862 TARN PARTICIPATING AREA PROD J Last TaSS SV g-PPLE SLM 9 428 0 8/6/2011 Rev/Reason:ADD SIDETRACKS'End Date KB=cm(ft) Rig Balsas Dets ont 1IN2S(ppm) Date Mnotation •.• Wet contig -2L-307L2-01,J7/4/24t1 12 04,23PM j,.__ I I ` .4340. 4/3/1999 SchenrtiC, oat _ Annotation Depth(ftKB) [End Date [Annotation Last Mod [End Date g 11 I ninam 11/4/2011 RANGER,15 _ Casing Strings Casing Description String 0... [String ID...Top(ftKB) Se1 Depth(1...Set Depth(TVD) String WI. String..IString Top Thad LINER L2-0123/8 � 1.992 �_--9,1380 I 10,164.4 4.70 L 80 STL. ■ 111Liner Details / Top Depth (TVD) Top Incl Norrii--. Top OMB) (BKB) r) Item Description Comment ID(in) 9,138.0 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.992 1Perforations&Slots CONDUCTOR, Shot 35-115 Top(TVD) Bim(TVD) Dens _--- _I ;a� Top(ftKB) Btrn(MB) (1IKB) (NMI) Zone Date (oh•-. Type Comment NIPPLE,511— ?�-. 9,139 10,164 T-2,2L-307 10/14/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends n SURFACE, 1J ', 35.2,905 �� '' GAS LIFT, 4,979 i --R DEPLOY.6,448-- PACKER,6,455------ 4747 �y • p:3 SEAL ASSY8,601, DEPLOY.8.803 t, -- PACKER,8,609 • . 1- \ / SLEEVE-C, 8,680 GAS L8,730 IFT, A _-.. a 1 NIPPLE,8,782 -- LOCATE.,_..-._____.. -i 8,791 Centralizer, / 8,794 Centralizer,_--------_. N. 8,795�__.._-.. /'IN SEAL ASSY, ; h 8,795 I SEAL ASSY, =- I 8,792 DEPLOY,8,798 — I [Nr ,:>Ys _ PACKER,8,804-----. ).__ ,- 1 MILE SHOE. 8.849 Mandrel Details Top Depth Top 1I Port (TVD) Incl OD I Valve Latch Size TRO Run Stn T tpltusR (MAR) r) Make Model (in) . Sere , Term Type (in) a (Psi) Run Date Coin_ WHIPSTOCK. '^"+ 1 4,978.5 3,504.1 55.69 CAMCO KBG-2 9 11 GAS LIFT SOV INT 0.313 0.0 10/28/2011 10:30 9,185 �_ __ PACKER,9.194 ; 2 8,729.8 5,199.2 56.32 CAMC0 KBG-2-9 1IGAS LIFT OPEN I-0.000 0.0 7/1/2011 4:00 PERF. . 9,210-9,240 "" SLOTS, 9,139-10,164 PRODUCTION '. E. - 33-9.7D .. 2 9,727 -- -„ -.- LINER L2-01, 9,138-10,184 2L-307 Post CTD Schematic last updated 10/25/11 'Diesel=6.8 ppg,0-35 psi/ft K-Formate=11.8 ppg,0.6123 psi/ft I 16"62#11-40,Shoe 1_ 115'MD 7- i-- 115' 115'TVD 37'TVDSS _- �" 7-518"29.7#L-80 BTC,Open shoe Straddle#3: 2-3/8"Hydril 511 4.6#L-80,10=1.992" 2905'MD Top of Deployment Sleeve KB Packer Bottom of Seal Assembly 2307'TVD 6448'MD 6455'MD 8607'MD 2155'TVDSS 4242'ND 4245'ND 5135'ND 4090'NDSS 4093'TVDSS 4983'TVDSS Straddle#2: 2-3/8"STL 4.7#L-80,ID=1.992" Top of Deployment Sleeve KB Packer Bottom of Seal Assembly Q; 8603'MD 8609'MD 8801'MD 5133'ND 5136'ND 5239'TVD 4981'NDSS 4984'NDSS 5087'NDSS Straddle#1: 2-3/8"STL 4.7#L-80,ID=1.992" 5-1/2"15.5#L-80 MOD,Casing Seal Receptacle �' Top of Deployment Sleeve KB Packer Bottom of Mule Shoe 8848'MD 8798'MD 8804'MD 8850'MD 5267'ND 5238'ND 5241'ND 5268'ND 5115'NDSS 5086'NDSS 5089'NDSS 5116'TVDSS 3-1/2"9.3#L-80 EUE,Seal Assembly 8843'MD 5264'ND 5112'NDSS Upper Window(Whipstock removed) TOP BOTTOM ` 9127 MD 9134'MD `\. 5427'ND 5431'ND .� 5275'NDSS 5279'TVDSS �\`\ Lower Window-(Whipstock covered by liner) �- `�\\` i � `` �:� TOP BOTTOM ` l \\ i 9185'MD 9190'MD \\ i/ 2L-307L2-01 5460'ND 5463'ND \\. iii 5308'NDSS 5311'NDSS --�. _ \.„, �� , / -` '--- — Top T2 Peri ``` _� y- �\\\` 9210'MD % i i 5474'ND �=F \�\ ,i 2L- 307L1 5322'NDSS — a.h.y \\\ iii \. I i/ ''''\:. 3-1/2"9.3#L-80 EUE,Shoe '-' 2L-307L2 9709'MD 5755'ND 5603'NDSS Lateral Completion Details Lower Window-Whipstock still in place isolating parent perforations L2-01 Liner:2-3/8"STL 4.7#L-80 Top of Whipstock RA Tag Bottom of Packer Top of Deployment Sleeve Bottom of Liner 9185'MD 9190'MD 9198'MD 9138'MD 10164'MD 5460'TVD 5463'ND 5468'ND 5433'ND 5387'ND 5308'NDSS 5311'NDSS 5316'NDSS 5281'NDSS 5235'NDSS L1 Liner:2-3/8"STL 4.7#L-80 L2 Liner:2-3/8"STL 4.7#L-80 Top of Deployment Sleeve Bottom of Liner Top of Aluminum Billet Bottom of Liner 9179'MD 10624'MD 9593'MD 10218'MD 545T ND • 5469'ND 5461'ND 5538'ND 5305'NDSS 5317 NDSS 5309'NDSS 5386'NDSS liiA MAIO m V 0m.. t to O Q u) a w co w ce 0 1 < F-- >, . " 2_, u) z w o_ ....... 0..... •..... ...c 111•111. 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CI) 03 () 6) 6) 0 CD Cn 0) 0 0) 0 O 0 0 0 0 0 0 6 U0 OL .O. cU a) a) 'O Q 2L-307 Ore and Post Rig Summary 'DATE SUMMARY 8/3/11 Milled out Camco"D" nipple ID at 8782'with 2.80" OD step mill. Post job mill OD at surfau =2.79" gauge ring no-go. 8/4/11 FCO TO 9380' CTMD WHILE PUMPING .5BPM ON IA 8/6/11 BRUSH & FLUSH TBG, GAUGE TO 2.77", BAIL SAND BRIDGE f/9238' TO 9250' SLM, TAG @ 9428' SLM, IN PROGRESS. 8/7/11 DRIFT TO 9426' SLM W/ 3" GR, 2.73" BAITSUB, 2.635"X 10' DRIFT, 2' X 1.875"WB, 2.635" CENT (OAL= 17.2'), NO OBSTRUCTIONS. READY FOR CALIPER. 8/9/11 LOG 24 ARM CALIPER FROM 9250' TO SURFACE. NO PROBLEMS WHILE RIH/POOH. 8/15/11 SET WEATHERFORD ER PACKER AT 8744 MID ELEMENT. CCL TO PACKER MID ELEMENT OFFSET: 10'. CCL STOP AT 8734. 8/16/11 (PRE-CTD) MV- PASSED; SSV- PASSED; SV- PASSED; T PPPOT- PASSED; T POT- FAILED; IC PPPOT- PASSED; IC POT- FAILED; LDS- FUNCTIONAL 8/17/11 ATTEMPTED TO TEST LOWER WEATHERFORD ER PACKER TWICE, TEST FAILED. PULLED ER PACKER @ 8744' RKB. 8/19/11 SET WEATHERFORD ER PACKER AT 8742'. CCL TO MID-ELEMENT OFFSET AT 9.9'. CCL STOP DEPTH AT 8732.1'. TURN WELL OVER TO DSO. 8/20/11 SET ER TEST TOOL IN ER PKR @ 8742' RKB, UNABLE TO GET P/T. RAN HOLEFINDER TO TOP OF ER PKR @ SAME, UNABLE TO GET P/T. PULLED ER PKR @ 8742' RKB. RAN HOLEFINDER, SUSPECT TBG LEAK IS BETWEEN —8767' RKB & —8749' RKB. JOB COMPLETE 8/23/11 SET WEATHERFORD ER PACKER (2.74" OD) MID ELEMENT @ 8774' ELMD. CCL TO MID ELEMENT= 9.9'. CCL STOP DEPTH = 8764.1'. PACKER SETTING CORRELATED TO LEAK DETECT LOG DATED 22-JULY-2011. 8/25/11 LOWER ER PKR @ 8774' RKB MOVED APPROX 8' DOWNHOLE WHILE SETTING TESTTOOL.PULLED LOWER ER PKR.IN PROGRESS. 8/28/11 SET WEATHERFORD ER PACKER MID-ELEMENT (2.74" OD) AT 8773' RKB. CCL TO MID- ELEMENT OFFSET=9.9'. CCL STOP DEPTH=8763.1'. LOG CORRELATED TO HES LEAK DETECTION LOG DATED 22-JULY-2011 8/30/11 RAN ER PACKER TEST TOOL TO ER PKR @ 8788' SLM, PERFORM COMBO MIT TO 2500 PSI, GOOD, RAN D&D HOLE FINDER, UNABLE TO GET TEST LOWER THAN 8615' SLM, RDMO 9/2/11 PULL ER PACKER @ 8773' RKB, JOB COMPLETE. 9/16/11 DRIFTED TBG WITH 2.74" x 134" DUMMY WHIPSTOCK TO 9310' SLM. TBG CLEAR, READY FOR E-LINE. 9/16/11 SET WEATHERFORD LOWER PACKER FOR WHIPSTOCK. BOTTOM OF PACKER SET AT 9197.8' CCL TO BOTTOM OF PACKER 24.5' CCL STOP DEPTH 9173.3'. ORENTATION 25 DEGREES LEFT OF HIGH SIDE. HAD TO WORK WIRELINE AND STROKE DPU SETTING ROD AN ADDITIONAL 2"TO GET FREE FROM PACKER. 9/17/11 SET 3-1/2"WS-R-BB WHIPSTOCK(9.44' OAL) @ 9169' SLM. PRESSURE TESTED PKR TO 1700 PSI, PASSED. BLED TBG & IA TO 0 PSI. COMPLETE. 10/27/11 ATTEMPTED DRIFT; BEGAN ENCOUNTERING METAL SHAVINGS @ 1215' SLM. MAKE BAILER / MAGNET RUNS TO CLEAN UP TBG, WORK TO TOP OF PATCH. ATTEMPT TO DRIFT PATCH W/ 1.75 BAILER, UNABLE TO GET PAST 6453' RKB ( 7' INSIDE PATCH ) DUE TO SHAVINGS. IN PROGRESS. 10/28/11 MEASURED SBHPS @ 6446' RKB = 2650 psi WITH GRADIENT@ 6151' RKB . PASSING MITIA TO 2500 PSI. BRUSH AND FLUSH TBG WITH BLB AND 2.78" GAUGERING.REPLACED 1" DV WITH 5/16" ORFICE @ 4979' RKB.DRAWDOWN TBG.JOB COMPLETE ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2L-307 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/1/2011 5:00:00 PM Rig Release: 10/25/2011 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/30/2011 24 hr Summary Start Rig move to 2L Exception Move 09:00 00:00 15.00 0 MIRU MOVE MOB P Move rig from 1E-pad. 10/01/2011 Complete Rig move.Accept rig at 17:00. Nipple up&start test of BOP's. 00:00 10:00 10.00 MIRU MOVE MOB P Arrive on 2L-pad. 10:00 17:00 7.00 MIRU MOVE MOB P Spot rig on the well. MIRU equip. 17:00 20:00 3.00 MIRU WHDBO NUND P Accept rig. NU BOP's 20:00 23:00 3.00 MIRU WHDBO NUND P Change out riser/Install QTS 23:00 00:00 1.00 MIRU WHDBO NUND P Fill coil,(Not BOPE Test Time) 10/02/2011 Test BOP,test waived by Lou Gramaladi. Pulled BPV. RIH W/Window milling BHA,Swap well to 8.6 Biozan for milling window. 00:00 01:30 1.50 0 0 MIRU WHDBO NUND P Continue prep for BOP test. Fluid pack Coil. Note: BOP test waived by Lou Gramaldi 9/30 @ 15:30.Test Inner reel valve and packoff( Not BOPE Test Time) 01:30 06:00 4.50 0 0 MIRU WHDBO BOPE T Swab on tree leaking out of the stem. call valve crew. 06:00 12:00 6.00 0 0 MIRU WHDBO BOPE P Crew change, PJSM,Test BOPE 12:00 14:00 2.00 0 0 MIRU WHDBO OTHR T BOPE Test Complete Replace T-1 Valve leaking out of stem 14:00 17:00 3.00 0 0 MIRU WHDBO PRTS P Test new T-1 -Good, PT PDL's,TT Line. Hook up remote panel to DS Well SSV 17:00 17:30 0.50 0 0 MIRU WELLPFOTHR P R/U and pull BPV 17:30 18:45 1.25 0 0 PROD1 WHPST SFTY P Well is capped. Get both crews down in conference room.Conduct pre-spud meeting.Then conduct pre-tour meeting with incoming crew. Pre-job prior to picking up BHA 18:45 21:00 2.25 0 0 PROD1 WHPST PULD P PU window milling BHA. Double check fluid path to the tiger tank. 21:00 00:00 3.00 0 9,130 PROD1 WHPST CIRC P RIH W/Window milling BHA, line up returns to tiger tank, pump seawater @ 1 BPM 950 psi pump pressure, WHP 50 psi. pump 100 bbls of sewater then swap to 8.6 Biozan. 10/03/2011 Tag TOW @ 9185'. Circulate 12 bbls of 8.6 Biozan into IA.Time mill window. Have difficulties with numerous stalls. Exit @—9190.4'. Start drilling rathole @ 9195'. Page 1 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:45 2.75 9,130 9,167 PROD1 WHPST CIRC P Tag Whipstock @ 9180'uncorrected. PUH log a CCL log, +6'correction= 9186'. PUH to 9167'&park-continue With btms up to load well with 8.6 Biozan. Shut in choke. Open up hose on IA taking returns to Tiger, pump down coil pushing 12 bbls of 8.6 bio into the IA.Shut in IA returns. 02:45 06:00 3.25 9,167 9,186 PROD1 WHPST WPST P Pumps up 1.43 BPM,choke wide open,CTP 3060 PSI,WHP 26 psi, IA@ 1100 PSI Tag TOW @9185', stall motor several times. 06:00 08:00 2.00 9,186 9,185 PROD1 WHPST WPST P Crew change, Still stalling,try multiple pump rates 1.55 to 1.3. 08:00 08:30 0.50 9,185 9,185 PROD1 WHPST WPST P Orient TF from HS to 20 R, 1.35 BPM @ 2900 PSI FS,Still stalling, roll to 30-35 ROHS 08:30 13:00 4.50 9,186 9,186 PROD1 WHPST WPST P Still unable to get started, Orient to 30-35R, Start slicking up Bio water with 776,continue to time mill to get started,Able to get past stall spot @ 9185.74. Looks like we got pattern developed,Start normal window time milling. Roll TF back to high side. Call pinch point @ 9185.7 13:00 13:30 0.50 9,186 9,187 PROD1 WHPST WPST P Time milling, 1.35 BPM @ 2809 PSI FS,TF=HS,WOB=3K 13:30 15:30 2.00 9,187 9,188 PROD1 WHPST WPST P 9188,2.3'down from pinch point, good metal on shaker 15:30 21:00 5.50 9,188 9,190 PROD1 WHPST WPST P 9188.7,Starting to show some fluid losses on MicroMotion, Not showing loss in pits yet 21:00 22:00 1.00 9,190 9,192 PROD1 WHPST WPST P Getting weight fall off, getting cement in returns.Should have window mill out of the liner now& engaging the string reamer. continue time milling, 1.9 FPH. 22:00 23:15 1.25 9,192 9,195 PROD1 WHPST WPST P Good weight fall off,possiable string reamer exit.continue time milling, 1.9 FPH. 23:15' 00:00 0.75 9,195 9,201 PROD1 WHPST WPST P Start drilling the rathole,ease up from 2 FPM to 5 FPM,2.5 Wt on bit. 10/04/2011 Complete window milling operations,trip for drilling BHA,drill build to 9258'. Trip for AKO. 00:00 01:00 1.00 9,201 9,206 PROD1 WHPST WPST P Continue Drilling rathole past window 2.67 WOB, 7.5 ROP, 1.40 BPM, 2980 PSI. Drill down to 9206' ****Note, conduct kick while drilling drill*********** 01:00 02:00 1.00 9,206 9,206 PROD1 WHPST WPST P Pull several reaming passes. Dry drift window with no problems. 02:00 04:15 2.25 9,206 0 PROD1 WHPST TRIP P Open EDC,Trip out circulating @ 1.5 BPM 04:15 04:30 0.25 0 0 PROD1 WHPST SFTY P Tag up. Pre-Job prior to undeploy. 04:30 06:00 1.50 0 0 PROD1 WHPST PULD P Pressure undeploy BHA. Page 2 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 PROD1 WHPST PULD P Crew change,continue undeployment. Mill 2.80 No Go, String mill 2.79 NoGo,Test ESD- good test 08:00 09:54 1.90 0 72 PROD1 DRILL PULD P PJSM-PD BHA#2 Build section with 2.3 AKO Bend with re-run Hughs Bi Center Inspect checks in UQC, make up coil to coiltrack, Strip on well, Surface test tool 09:54 11:54 2.00 72 8,990 PROD1 DRILL TRIP P Trip in hole EDC Closed 11:54 12:42 0.80 8,990 9,140 PROD1 DRILL DLOG P Gamma log for tie in,+3'PUW=29K 12:42 13:00 0.30 9,140 9,206 PROD1 DRILL TRIP P Trip in through window,Clean pass throrough and tag up @ 9206,Clean pick up out of window, PUW=32 13:00 14:00 1.00 9,206 9,160 PROD1 DRILL CIRC P 9160, Open EDC and swap over to 8.6 PPG Flo Pro 14:00 14:06 0.10 9,160 9,206 PROD1 DRILL TRIP P Close EDC and trip in well 14:06 15:54 1.80 9,206 9,258 PROD1 DRILL DRLG P 9206'Drill Ahead, 1.35 BPM @ 2515 PSI FS, BHP=2986, RIW=14K, WOB=1.4K, ROP=30-20 FPH, estimated AVG DLS=45 degree 15:54 18:30 2.60 9,258 0 PROD1 DRILL TRIP P 9258 EOB, POOH for lateral BHA PUW=32K,Open EDC 18:30 22:00 3.50 0 0 PROD1 DRILL PULD P Undeploy BHA, adjust AKO and deploy BHA 22:00 00:00 2.00 0 PROD1 DRILL TRIP P RIH 10/05/2011 Drilled lateral 00:00 00:12 0.20 8,800 9,035 PROD1 DRILL TRIP P Coniine RIH 00:12 00:42 0.50 9,035 9,258 PROD1 DRILL DLOG P Tie in,+3.5', log RA at 9190' 00:42 02:48 2.10 9,258 9,408 PROD1 DRILL DRLG P RIH and drill, 1.4 BPM,2500 CTP,3040 BHP with WOC 02:48 03:00 0.20 9,408 9,408 PROD1 DRILL WPRT P Wiper to window,30 K PUW 03:00 05:12 2.20 9,408 9,575 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,2500 CTP,3050 BHP, 12 K RIW 05:12 05:57 0.75 9,575 9,150 PROD1 DRILL WPRT P Wiper to window, 05:57 06:21 0.40 9,150 9,150 PROD1 DRILL WPRT P In cased hole, discuss lack of clear surveys, BHI consulted their town folks.Tool is operating in specs. High solar activity reported on web. RBIH will attemp to get clear surveys RIH,Check surveys on way in 06:21 07:15 0.90 9,150 9,575 PROD1 DRILL WPRT P RBIH will attemp to get clear surveys RIH, Check surveys on way in 07:15 08:15 1.00 9,575 9,659 PROD1 DRILL DRLG P 9575', Drill Ahead 1.5 BPM @ 2620 PSI FS, BHP=3050, RIW=10.7, WOB=1.9K Obtained good surveys past 9400 08:15 09:21 1.10 9,659 9,659 PROD1 DRILL WPRT P P/U to take check surveys in know good zone. Surveys on bottom still failed due to mag field Page 3 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:21 10:03 0.70 9,659 9,725 PROD1 DRILL DRLG P 9659', Drill Ahead, 1.45 BPM @ 2620 PSI FS, BHP=3095 10:03 10:51 0.80 9,725 9,725 PROD1 DRILL WPRT P Wipe to window with tie in for+1.5, PUW=31K, BHP=3100 10:51 12:09 1.30 9,725 9,828 PROD1 DRILL DRLG P 9725', Drill Ahead, 1.4 BPM @ 2450 PSI FS, BHP=3080, RIW=11.2K, WOB=1.3K 12:09 12:33 0.40 9,828 9,848 PROD1 DRILL DRLG P 9828', Drilling, Reduce pump rate to 1.3 BPM @ 2350 PSI FS, BHP=3117 12:33 13:21 0.80 9,848 9,845 PROD1 DRILL WPRT P 9848', Pull Wiper early due to high annular pressure. ECD 11.35, BHP=3120, PUW=31K 13:21 15:33 2.20 9,845 9,960 PROD1 DRILL DRLG P 9845', Drill Ahead, 1.3 BPM @ 2460 PSI FS, BHP=3120,WHP=15PSI. Opened T1 and T2 to confirm WHP on MP line sensor showed 4 PSI. Running mud checks to determine source of additional pressure 15:33 17:00 1.45 9,960 9,680 PROD1 DRILL WPRT P 9960',Wiper to window, PUW=31K. Pulled early, reduce flow rate to take returns to tiger tank without increasing pressure on well. Prep for mud swap 17:00 18:30 1.50 9,680 9,900 PROD1 DRILL WPRT P Started new mud down coil 18:30 22:00 3.50 9,900 9,960 PROD1 DRILL WPRT P New mud, 1.2 BPM,3090 CTP, 11.2 ECD, pull wiper into tubing,pump sweeps. 22:00 00:00 2.00 9,960 10,110 PROD1 DRILL DRLG P Continue drilling, LSRV at 40K, add 20 Bbls low-vis to lower LSRV, 1.2 BPM,2400 CTP, 3070 BHP, 11 ECD 10/06/2011 Drilled lateral to 10624',encountered higher than expected formation pressures and TD lateral at this point. Wiper to surface. 00:00 01:12 1.20 10,110 10,110 PROD1 DRILL WPRT P Wiper to the window,29K PUW, 14K RIW 01:12 03:42 2.50 10,110 10,260 PROD1 DRILL DRLG P Continue drilling, 1.2 BPM,3040 BHP, 11.0 ECD 03:42 04:54 1.20 10,260 10,260 PROD1 DRILL DRLG P Wiper to window, 30K PUW 04:54 05:42 0.80 10,260 10,325 PROD1 DRILL DRLG P Continue drilling ahead, 1.2 BPM, 2370 CTP,3100 BHP, 05:42 06:27 0.75 10,325 10,325 PROD1 DRILL WPRT P Charge pump issues, PUH to sort out 06:27 07:42 1.25 10,325 10,410 PROD1 DRILL DRLG P 10325', Drill Ahead 1.15 BPM @ 2075 PSI FS, BHP=3040 07:42 09:24 1.70 10,410 10,410 PROD1 DRILL WPRT P Wiper to window with tie in, +2.5', PUW=32K 09:24 10:06 0.70 10,410 10,460 PROD1 DRILL DRLG P 10410 Drill Ahead, 1.3 BPM @ 2250 PSI FS, BHP=3042, RIW=10.2, WOB=2.2K 10:06 10:18 0.20 10,460 10,469 PROD1 DRILL DRLG P 10460,gas cut mud at surface, send returns to tiger tank. Bring BHP up 100 PSI over 3120 10:18 12:03 1.75 10,469 10,469 PROD1 DRILL WPRT P Bring returns back in,still gas cut, wiper trip while circulating bottoms up Wiped up to 9225, PUW=31 K Page 4 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:03 13:18 1.25 10,469 10,556 PROD1 DRILL DRLG P 10469, Drill Ahead, 1.54 BPM @ 2500 PSI FS, BHP=3154, RIW=7.8K,WOB=1.6K 13:18 13:33 0.25 10,556 10,590 PROD1 DRILL DRLG P 10556, Drilling ahead,Gas in returns send out to tiger tank, BHP=3190 1.53 BPM @ 2510 PSI FS 13:33 14:33 1.00 10,590 9,165 PROD1 DRILL WPRT P Still flowing to TT,Wiper to window and static, BHP=3350, PUW=31K Brought returns inside after reading density and rate @ 9600' 14:33 15:45 1.20 9,165 9,159 PROD1 DRILL PRTS P In cased hole Shut down,Shut in well for static pressures Time=2:30, BHP=3206, ECD=11.71, IA=1220 Initial shut in Time=2:35, BHP=3138, ECD=11.46, IA=1179 Time=2:40, BHP=3128, ECD=11.42, IA=1155 Time=2:45, BHP=3129, ECD=11.43, IA=1150 Time=2:50, BHP=3128, ECD=11.42, IA=1150 Time=2:55, BHP=3138, ECD=11.42, IA=1151 Time=3:00, BHP=3137, ECD=11.42, IA=1151 Time=3:05, BHP=3137, ECD=11.42, IA=1150 15:45 16:45 1.00 9,159 10,590 PROD1 DRILL WPRT P Wiper trip back to bottom. Hold 3250 PSI on BHI annular guage at all times in open hole 16:45 17:09 0.40 10,590 10,623 PROD1 DRILL DRLG P 10590', Drill ahead, 1.4 BPM @ 2565 PSi FS, BHP=3258 17:09 18:12 1.05 10,623 9,150 PROD1 DRILL WPRT P More gas, Divert to TT, ECD @ 12.1, PUH to circ out gas, PUW=32K, BHP=3407 18:12 19:12 1.00 9,150 9,155 PROD1 DRILL SIPB P Static BHP,9155 bit depth, 5291 TVD at BHP sub; 18:15, 12.15 ECD,3308 BHP, 1250 IA 18:20, 11.47 ECD,3145 BHP, 1178 IA 18:30, 11.46 ECD,3136 BHP, 1161 IA 18:40, 11.47 ECD,3138 BHP, 1162 IA 19:00, 11.47 ECD,3139 BHP, 1164 IA 19:12 20:18 1.10 9,155 10,624 PROD1 DRILL WPRT P Tie-in,+0.5'correction. RIH with new pressure schedule for 11.7 EMW at window. 13K RIW 20:18 00:00 3.70 10,624 1,600 PROD1 CASING WPRT P Wiper OOH, 30K PUW, at surface zero depth and RBIH 10/07/2011 Completed wiper to surface and back to TD, layed in completion fluid, PU liner string for L1. Lost 179 Bbls of completion fluid 00:00 02:00 2.00 1,600 9,050 PROD1 DRILL WPRT P Continue with long wiper trip. Page 5of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:12 0.20 9,050 9,075 PROD1 DRILL DLOG P tie-in 02:12 06:00 3.80 9,075 9,075 PROD1 DRILL WPRT T Vac truck of completion fluid broke down enroute 06:00 07:30 1.50 9,075 9,038 PROD1 DRILL WPRT T Crew change, KWF here 6:20, Bring on fluid, Mix liner running pill 07:30 08:30 1.00 9,038 10,608 PROD1 DRILL WPRT P Trip in hole to TD 08:30 11:54 3.40 10,608 72 PROD1 DRILL TRIP P Trip out of hole laying in 20 BBL beaded liner running pill/KWF 12.1 PPG Paint EOP Flags @ 9000', 7600 11:54 13:24 1.50 72 0 PROD1 DRILL PULD P At surface,flow check well, lay down tools, Lost 35 BBI KWF on way out, well taking—20BBI/Hr.61 BBL KWF on surface.Started taking fluid —1800'from surface.Order out 11.9 PPG completion 13:24 16:24 3.00 0 0 PROD1 DRILL CTOP T Vac trk going to get fluid has flat, Call out peak to P/U 11.9 fluid, Mix 50 BBIs here on rig,Stab back on and recover 12.1 out of coil. 16:24 20:24 4.00 0 0 PROD1 DRILL CTOP T Lost 5 BBIs from coil circ, 30 BBIs 12.1 in suction pit—15 pumpable, Still making 50 LBS 11.9,250 BBIs 11.9 on the way. Vac truck arrived on location at 19:30,circulated coil to 11.9 PPG fluid. 20:24 20:42 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations 20:42 23:30 2.80 0 1,490 COMPZ CASING PUTB P MU liner string 23:30 00:00 0.50 1,490 3,000 COMPZ CASING RUNL P RIH 10/08/2011 Ran liner to TD and released, Liner top at 9179',set KB packer/whipstock assembly at 9125'TOWS,start milling window 00:00 01:42 1.70 3,000 9,100 COMPZ CASING RUNL P Continue RIH, correct depth at flag, 30K PUW,-2.5K WOB 01:42 02:24 0.70 9,100 10,628 COMPZ CASING RUNL P Continue RIH,tag TD at 10628', 35K (-4K WOB) PUW,Stack weight and come on line with pump at 1.3 BPM, released from liner. 02:24 04:24 2.00 10,628 0 COMPZ CASING RUNL P POOH 04:24 04:48 0.40 0 0 COMPZ CASING SFTY P Check for no flow, PJSM 04:48 05:30 0.70 0 0 COMPZ CASING PUTB P Lay down liner running BHA 05:30 06:42 1.20 0 72 PROD2 RPEQP1 PULD P PU whipstock setting BHA, KB packer and WS.,Make up coil trak and surface test tool 06:42 09:54 3.20 72 9,060 PROD2 RPEQP1TRIP P RIH, EDC Open 09:54 10:00 0.10 9,060 9,083 PROD2 RPEQPI DLOG P Log tie in for+3'correction, PUW=30K, RIH to set Whipstock Page 6 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:30 0.50 9,083 9,137 PROD2 RPEQP1WPST P 9136.9 set bit depth, RIH to 9140 PUH to set depth,20LHS,Close EDC, Pump on.Tool shifted 1200PSI, Set down 1K DHWOB. Pull out setting rod TOL=9125,20 LOHS 10:30 12:45 2.25 9,137 85 PROD2 RPEQPI TRIP P Trip out with setting tools 12:45 13:15 0.50 85 0 PROD2 RPEQP1 PULD P PJSM,At surface, PJSM Lay down whipstock running tools 13:15 14:15 1.00 0 73 PROD2 WHPST PULD P P/U Window upper window milling BHA, .6 degree AKO, New 2.80 Dimond whipstock mill and string reamer 2.8 Go,2.79 No Go,Stab on Injector and surface test tool, Open EDC 14:15 16:30 2.25 73 9,060 PROD2 WHPST TRIP P Trip in to mill window 16:30 16:36 0.10 9,060 9,078 PROD2 WHPST DLOG P Gamma tie in for+4' 16:36 18:36 2.00 9,078 9,126 PROD2 WHPST CIRC P Pump 15 BBL hi vis spacer followed by 2 PPB Bio/Seawater 18:36 00:00 5.40 9,126 9,128 PROD2 WHPST MILL P Tag TOWS at 9126', PU and start time milling, pinch point is 9125.8. 1.5 BPM, 3400 CTP,3200 BHP, 10/09/2011 Completed window milling and drilled formation to 9146'. Pumped slack and cut 23'of CT. Started BOP testing, state witnessing waived by Jeff Jones 00:00 06:30 6.50 9,128 9,131 PROD2 WHPST MILL P Continue milling window 06:30 10:00 3.50 9,131 9,147 PROD2 WHPST MILL P 9131.2,Weight drop String mill out of window,see weight drop off Mill rathole 10:00 11:00 1.00 9,147 9,146 PROD2 WHPST REAM P 9146.7, Ream window, PUW=30K 11:00 13:42 2.70 9,146 73 PROD2 WHPST TRIP P Ream, Dry drift looks all good,Trip out of well with BHA#6, PUW=31 K 13:42 16:00 2.30 73 0 PROD2 WHPST PULD P At Surface, PUD BHA#6, Blow down and lay down tools Mill 2.80 Go, 2.79 No Go, reamer 2.79 Go 2.78 No Go 16:00 18:00 2.00 0 0 PROD2 DRILL BOPE P Prep for BOPE Test,Grease crew here to service swabs and T valves 18:00 22:00 4.00 0 0 PROD2 DRILL SLPC P Reverse circulate for slack management,cut pipe to find wire, cut 23'. Test wire... 22:00 00:00 2.00 0 0 PROD2 DRILL BOPE P RU and start testing BOP 10/10/2011 Tested BOP, Drilled L2 build from 9142'to 9243'. 00:00 07:00 7.00 0 0 PROD2 DRILL BOPE P Continue testing BOP, rehead coil, Chanege out Bleeder two valve 07:00 08:00 1.00 0 0 PROD2 DRILL CTOP P Test complete, Normal up rig and cellar 08:00 11:00 3.00 0 62 PROD2 DRILL PULD P M/U BHA#7 with 2 degree motor and RR Hughes bit, Load in PDL and PD, Make up to CTC and surface test. Strip on well,Tag up, reset counters Page 7 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:12 2.20 62 9,050 PROD2 DRILL TRIP P Trip in well, EDC open. Pumping 1 BPM from surface 13:12 13:18 0.10 9,050 9,068 PROD2 DRILL DLOG P Log Tie In for+3'correction 13:18 13:36 0.30 9,068 9,115 PROD2 DRILL TRIP P Close EDC and trip through window. Looks good, Pull back in to cased hole, open EDC to swap well to Flo Pro 13:36 14:36 1.00 9,115 9,115 PROD2 DRILL CIRC P Circulate well to Flo Pro from Biozan Water 14:36 14:42 0.10 9,115 9,147 PROD2 DRILL TRIP P Close EDC,trip back through window 14:42 15:54 1.20 9,147 9,240 PROD2 DRILL DRLG P 9147 Drill Ahead 1.44 BPM @ 2550 PSI FS, BHP=3000, RIW=12K, WHP=20 15:54 18:12 2.30 9,240 0 PROD2 DRILL TRIP P 9240,Call End Of Build, PUW=28K, BHP=3030, Near bit Inc=85.6,Avg DLS=33.5 18:12 18:24 0.20 0 0 PROD2 DRILL SFTY P PJSM 18:24 21:42 3.30 0 0 PROD2 DRILL PULD P Undeploy build BHA,deploy lateral drilling assembly 21:42 23:48 2.10 0 9,050 PROD2 DRILL TRIP P RIH,at 1800'while RIH gas cut and oil cut mud at surface,divert returns to tiger tank 23:48 00:00 0.20 9,050 9,080 PROD2 DRILL DLOG P Tie-in to formation, +4', Logged RA at 9134' 10/11/2011 Drilled L2 Lateral from 9050ft to TD @ 10218ft. 00:00 01:12 1.20 9,050 9,050 PROD2 DRILL CIRC P CBU above window, returns to tiger tank., holding 3100 BHP, 1.4 BPM, 01:12 01:54 0.70 9,240 9,303 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,2600 CTP, 3100 BHP(-100 WHP with returns going to the tiger tank),gas cut and oil in returns. 01:54 02:24 0.50 9,303 9,303 PROD2 DRILL WPRT P P/U High annular pressure, Returns to TT, PUW=27K, BHP=3355, PUH tp 9050 02:24 04:30 2.10 9,303 9,425 PROD2 DRILL DRLG P 9303', Drill Ahead, 1.45 BPM @ 2590PSI FS, BHP=3100, RIW=11.1 WOB=1.7 04:30 04:54 0.40 9,425 9,425 PROD2 DRILL WPRT P 9425 Wiper to window, PUW=28K, BHP=3131, ECD=11.1 Returns normal, Mad Pass 9245 to 9155 04:54 07:06 2.20 9,425 9,575 PROD2 DRILL DRLG P 9425' Drill Ahead, 1.44 BPM @ 2600 PSI FS, BHP=3160 ECD=11.4, 1 for 1 returns 07:06 07:36 0.50 9,575 9,575 PROD2 DRILL WPRT P 9575 Wiper trip to window, PUW=29K 07:36 10:48 3.20 9,575 9,725 PROD2 DRILL DRLG P 9575', Drill Ahead, 1.44 BPM @ 2636PS1 FS, BHP=3155 10:48 11:12 0.40 9,725 9,150 PROD2 DRILL WPRT P Wiper to the window, holding 11.5 ECD at the bit. 29K PUW 11:12 11:24 0.20 9,150 9,175 PROD2 DRILL DLOG P Tie-n, no correction 11:24 11:42 0.30 9,175 9,725 PROD2 DRILL WPRT P Wiper back in, 13K RIW 11:42 14:00 2.30 9,725 9,875 PROD2 DRILL DRLG P Continure drilling ahead, maintain 11.5 ECD, 1.54 BPM, 120 WHP. Page 8 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:54 0.90 9,875 9,875 PROD2 DRILL WPRT P Wiper to the window, 30K PUW, 13K RIW, 14:54 17:36 2.70 9,875 10,025 PROD2 DRILL DRLG P continue drilling, holding 11.55 ECD at the bit, 1.5 BPM,2700 CTP,95 WHP 17:36 18:36 1.00 10,025 10,025 PROD2 DRILL WPRT P Wiper trip, 29K PUW, 13 K RIW 18:36 21:18 2.70 10,025 10,172 PROD2 DRILL DRLG P Continue drilling, 11.55 ECD, 1.5 BPM, 2800 CTP, 94 WHP 21:18 21:48 0.50 10,172 9,150 PROD2 DRILL WPRT P @ 10172 ft, lost WOB, no motor work, PUH, PU wt is 34k,Wiper trip to window. 21:48 22:00 0.20 9,150 9,175 PROD2 DRILL DLOG P Tie-n, +2'correction 22:00 22:30 0.50 9,175 10,172 PROD2 DRILL WPRT P Wiper back in, 13k RIW 22:30 00:00 1.50 10,172 10,218 PROD2 DRILL DRLG P Continue Drilling ahead, 11.55 ECD, 1.5 BPM,WHP=90, CTP=2990, Reached TD at 10218ft. 10/12/2011 Completed wiper to surface and back to TD, layed in completion fluid, PU liner string for L2. Set liner @ 10218ft, Swapped well back to 8.6 ppg drilling fluid.Total of 63 bbls KWF lost while running liner. 00:00 03:30 3.50 10,218 0 PROD2 DRILL WPRT P Start Wiper run to swab, 1.5 bpm, 11.55 ECD, POOH following trip schedule 03:30 06:18 2.80 0 10,218 PROD2 DRILL WPRT P Mix liner running pill,Trip in to TD, tag bottom at 10218' 06:18 09:48 3.50 10,218 0 PROD2 DRILL DISP P Lay in liner running pill from 10218' followed by clean 11.9 brine, paint EOP flags at 8300'and 9400'. 09:48 10:30 0.70 0 0 PROD2 DRILL SFTY P PJSM,check well for flow 10:30 11:30 1.00 0 0 PROD2 DRILL PULD P Lay down drilling BHA 11:30 15:30 4.00 0 0 COMPZ CASING RUNL P Rig up for liner ops. run 18 jts liner, 15:30 18:30 3.00 0 10,218 COMPZ CASING RUNL P RIH with liner 18:30 23:00 4.50 10,218 9,127 COMPZ CASING DISP P Tag bottom at 10218ft, pump off liner, PUH to window.start to circ out KWF. 23:00 00:00 1.00 9,127 0 COMPZ CASING DISP P @ surface with hole swapped over to 8.6 ppg,Total of 63 bbls KWF lost while running liner,start to undeploy. 10/13/2011 Completed billet milling at 9592', Drilled L2-01 lateral to TD @ 10190' 00:00 02:00 2.00 0 0 PROD3 STK PULD P Deploy drilling BHA#10, Losing approx 10 bbls per hour with WHP @ 800, Decrease to 700 psi,well is stable. 02:00 04:30 2.50 0 9,592 PROD3 STK TRIP P RIH witj BHA#10,Tagged billet @ 9592ft, PU wt is 29k, online with pump, 1.5 bpm,ctp=2815, 04:30 07:00 2.50 9,592 9,600 PROD3 STK KOST P Start milling holding 11.55 ECD. Clean milling 1-3-fph,with ROP increase to 10-fph at 9596';then 20-fph once through billet after 9600'. 07:00 08:12 1.20 9,600 9,640 PROD3 DRILL DRLG P Drill ahead formation to 9640'20-fph holding 11.52 ECD. Page 9 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:12 08:30 0.30 9,640 9,640 PROD3 DRILL WPRT P Pull back up above billet to 9570'and drift KOP. Drifted smoothly; all clean. 08:30 10:06 1.60 9,640 9,740 PROD3 DRILL DRLG P Drill ahead L2-01 lateral; 1.5-BPM; 2925-psi CTP; 3704-psi BHP; 11.55 ECD. 10:06 11:00 0.90 9,740 9,740 PROD3 DRILL WPRT P Wiper trip#1 to 9165';31.5k#PUW. 11:00 13:36 2.60 9,740 9,890 PROD3 DRILL DRLG P Drill ahead; 1.52-BPM;2972-psi CTP; 3682-psi BHP; 11.54 ECD. 13:36 14:36 1.00 9,890 9,890 PROD3 DRILL WPRT P Wiper trip#2 to 9163';30.5k#PUW. 14:36 18:06 3.50 9,890 10,040 PROD3 DRILL DRLG P Drill ahead; 1.51-BPM; 3000-psi CTP;3735-psi BHP; 11.52 ECD. 18:06 19:06 1.00 10,040 10,040 PROD3 DRILL WPRT P Wiper Trip#3 to 9150', PU wt is 32k, Tie-in, +2.5 correction 19:06 22:06 3.00 10,040 10,170 PROD3 DRILL DRLG P Drill ahead, 1.5 bpm, ctp=3100, 11.55 ECD, 22:06 22:18 0.20 10,170 10,170 PROD3 DRILL WPRT P @ 10170ft, having trouble keeping WOB, PUh to 10090ft, RBIH, 22:18 23:18 1.00 10,170 10,190 PROD3 DRILL DRLG P Drill ahead,CTP=3028, ECD=11.55 23:18 00:00 0.70 10,190 10,190 PROD3 DRILL WPRT P Wiper trip#4, PU WT is 31k, decision from town to TD at this depth, Start wiper to surface. 10/14/2011 Finish laying in KWF, Ran liner top to 9138'and released, RIH with whipstock fishing BHA 00:00 03:00 3.00 10,190 0 PROD3 DRILL WPRT P Continue Wiper trip to surface, PU WT is 31k, 03:00 05:00 2.00 0 10,190 PROD3 DRILL WPRT P Mix liner running pill,Trip in to TD, tag bottom at 10190' 05:00 08:00 3.00 10,190 0 PROD3 DRILL DISP P Lay in liner running pill from 10190' followed by clean 11.8 brine, Flag pipe at 7900'and 9000'. 08:00 08:30 0.50 0 0 PROD3 DRILL SFTY P Check for no-flow, PJSM 08:30 09:30 1.00 0 0 PROD3 DRILL PULD P Lay down drilling BHA 09:30 10:00 0.50 0 0 COMPZ CASING SFTY P PJSM for liner operations 10:00 11:00 1.00 0 0 COMPZ CASING PUTB P PU liner,safety joint drill 11:00 11:30 0.50 0 0 COMPZ CASING SFTY P PJSM after crew changeout 11:30 12:54 1.40 0 1,071 COMPZ CASING PUTB P Continue with liner, safety joint drill 12:54 16:24 3.50 1,071 10,164 COMPZ CASING RUNL P RIH,At upper flag correct+2.75', 28K PUW, 15K RIW(-3K WOB), 1:1 returns during trip in. 16:24 17:48 1.40 10,164 8,500 COMPZ CASING DLOG P Released from liner, liner top at 9138' after logging GR, log gamma and CCL for straddle packer runs 17:48 19:54 2.10 8,500 0 COMPZ CASING RUNL P POOH 19:54 20:24 0.50 0 0 COMPZ CASING SFTY P @ surface,Check for no-flow, PJSM 20:24 20:54 0.50 0 0 COMPZ CASING PULD P Lay down liner running BHA 20:54 21:48 0.90 0 0 COMPZ RPEQP1PULD P Rig up whipstock Fishing BHA#12 21:48 00:00 2.20 0 8,950 COMPZ RPEQP1TRIP P RIH to whipstock, pumping min rate. Page 10 of 21 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/15/2011 24 hr Summary Attempt to Fish whipstock with J-hook assembly with no success, Drifted tubing with 2.80 crayola mill to top of liner at 9138'with no obstruction,Attempt to fish whipstock with baited overshot BHA with no success. 00:00 00:18 0.30 8,950 9,131 COMPZ RPEQP1TRIP P RIH to whipstock, pumping min rate, 00:18 03:18 3.00 9,131 9,135 COMPZ RPEQPI PULL P Start fishing whipstock, make several attempts to latch j-hook,Jetting on fish, Orient the hook from 40 left to 20 right and everything in between, not even trying to latch,Went as low as 9135 Losing 2.5 bbl KWF per hour. 03:18 03:30 0.20 9,135 8,841 COMPZ RPEQP1TRIP P POOH to rig up overshot BHA, 03:30 06:00 2.50 8,841 0 COMPZ RPEQP1TRIP P Over pull of 8k while POOH,continue to POOH 06:00 07:00 1.00 0 0 COMPZ RPEQP1PULD P Lay down fishing BHA, retrieval hook was bent,over almost 90 degrees. 07:00 09:00 2.00 0 0 COMPZ RPEQP1PULD T Evaluate options 09:00 09:48 0.80 0 0 COMPZ RPEQP1PULD T MU cleanout BHA with motor and 2.80"crayola mill/ 09:48 12:36 2.80 0 9,138 COMPZ RPEQPI TRIP T RIH,did not see anything at the nipple or the seal assembly. Continued down to the window and tagged the liner top at 9138'. 12:36 15:06 2.50 9,138 0 COMPZ RPEQPI TRIP T POOH at 1 FPM past billet, circulating at 1 BPM. Continue OOH and slow down to 1 FPM at seal assembly and at nipple. No motor work or weight changes. Continue POOH 15:06 16:42 1.60 0 0 COMPZ RPEQP1PULD T Lay down cleanout BHA,crayola is still 2.80"no-go. MU Fishing BHA with baited overshot 16:42 19:48 3.10 0 9,128 COMPZ RPEQPITRIP T RIH, EDC is open 19:48 20:42 0.90 9,128 9,128 COMPZ RPEQPI FISH T Attempt to latch whipstock several times at several different speeds from 1 fpm to 15 fpm. No indication on latching at all,overshot just drifts whipstock clean. 20:42 23:30 2.80 9,128 0 COMPZ RPEQP1TRIP T POOH 23:30 00:00 0.50 0 0 COMPZ RPEQPI PULD T @ surface, Lay down BHA#13, Lost total of 30 bbls KWF on this round trip. 10/16/2011 After several attempts to fish whipstock with overshot, POOH and observed 3 splits in the overshot sleeve with twist-deformation in the housing sections between where the splits occurred. (Pictures in Operational Data folder.) Had new thicker overshot made,attempt to fish whipstock with new overshot on 1.5 bent sub, Able to stack out on fish but unable to latch at all, no over pulls. Lost total of 94 bbls KWF in last 24hrs. 00:00 01:00 1.00 0 0 COMPZ•RPEQPI PULD T Make up BHA#14,overshot with no bait sub or G-Spear. 01:00 05:00 4.00 0 9,126 COMPZ RPEQP1TRIP T RIH at 50 fpm, pumping min rate, Lost 19 bbls KWF on trip in.Tie in _depth+3' 05:00 08:00 3.00 9,126 9,126 COMPZ RPEQPI FISH T Start fishing whipstock,set down -8k, puh fish not latched, orient shoe in multiple setting Page 11 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:18 2.30 9,126 0 COMPZ RPEQP1TRIP T POOH, 5K overpull entering seal assembly, run in hole-4K and popped free. PUH and saw no more overpulls. 10:18 10:36 0.30 0 0 COMPZ RPEQP1OWFF T At surface. Monitor well and confirm no-flow. 10:36 11:00 0.40 0 0 COMPZ RPEQP1SFTY T Conduct safety meeting for lay-down tools. 11:00 12:30 1.50 0 0 COMPZ RPEQP1 PULD T Stab-off well while monitoring no-flow at pits. Make down tools and observe 3 splits in the overshot sleeve with twist-deformation in the housing sections between where the splits occurred. (Pictures in Operational Data folder.) Discuss plan forward. 12:30 19:00 6.50 0 0 COMPZ RPEQP1PULD T Direct Baker machine shop to fabricate another sleeve, increasing wall thickness from previous 0.26"to 0.33",thereby decreasing gap between the sleeve and grapple inside by 0.125". Standby for tools monitoring well: pump in 3-bbl per hour to keep well loaded. 19:00 20:00 1.00 0 0 COMPZ RPEQP1 PULD T Make up BHA#16 with new overshot on 1.5 bent sub. 20:00 23:30 3.50 0 9,126 COMPZ RPEQP1TRIP T RIH at 50 fpm, pumping min rate, Lost 18 bbls KWF on trip in.Tie in depth+3' 23:30 00:00 0.50 9,126 9,126 COMPZ RPEQP1 FISH T Start fishing whipstock, able to tag up when overshot is oriented correctly, able to drift smoothly through when oriented 180 opposite. Made several attempts without any over pulls. 10/17/2011 Attempt to fish whipstock with Baker overshot with no success, During reel inspection,find weld failures in three of the four steel plate hub-to-spoke spacers that back up the bolt attachments from the axle clamp. Called out certified welder from GBR in Deadhorse to repair welds. Ran caliper on S/L. 00:00 01:36 1.60 9,126 9,126 COMPZ RPEQP1 FISH T Continue fishing whipstock,able to tag up when overshot is oriented correctly, able to drift smoothly through when oriented 180 opposite. Made several attempts without any .over pulls. 01:36 05:12 3.60 9,126 0 COMPZ RPEQP1TRIP T POOH. 05:12 06:12 1.00 0 0 COMPZ RPEQP1 PULD T Make down overshot and inspect _tool. 06:12 07:30 1.30 0 0 COMPZ RPEQP1 T No apparent damage to tool and no visible indications on to tool as to reason for not engaging fish. Discuss options with town. Page 12 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 12:30 5.00 0 0 COMPZ RPEQPI RGRP T During reel inspection,find weld failures in three of the four steel plate hub-to-spoke spacers that back up the bolt attachments from the axle clamp. Call out certified welder from GBR in Deadhorse to repair welds. [Call-out slickline at 11:30am.] 12:30 15:00 2.50 0 0 COMPZ RPEQPI T Wait on slickline. (Call out PDS calipers at 13:30.) 15:00 15:30 0.50 0 0 COMPZ RPEQP1SFTY T Slickline on location. Conduct safety meeting for slickline rig-up. 15:30 18:30 3.00 0 0 COMPZ RPEQP1SLKL T Rig up Slickline. PDS on location 16:00. Rig-up PDS. 18:30 21:00 2.50 0 0 COMPZ RPEQP1SLKL T RIH with PDS 24 arm caliper, POOH, Good data, rig up overshot run. 21:00 00:00 3.00 0 0 COMPZ RPEQP1 SLKL T RIH with Baker 2.70 overshot, set down at 9124',tap down, latched up, PU 1000#,jars hit,off fish,continue trying this several times, able to latch each time but not good enough to hit up on, POOH to rig up LIB run. 10/18/2011 RIH and latched into WS with J-hook fishing tool @ 120 LOHS. Jars fired once&WS came free. Let the elements relax and POOH,fish got stuck in D-nipple and pulled free with 50K surface weight.Whipstck recovered but two small slip elements pulled off the tool. Rig up SL with 2.62"magnet.Total losses 166 bbls of KWF/24 hours 00:00 02:30 2.50 0 0 COMPZ RPEQP1 SLKL T Attempt to run 2.78 LIB, hung up in nipple at 8819; POOH to run 2.72 LIB. 02:30 04:00 1.50 0 0 COMPZ RPEQP1SLKL T Run 2.72 LIB to fish at 9126', POOH, @ surface, LIB edge shave off, indicate top of fish is still 2"wide and close to tubing wall. 04:00 06:00 2.00 0 0 COMPZ RPCOM SLKL T RIH with Baker 2.70 overshot,set down at 9124', Hit down several times, latched up,4 up spangs, overshot pulled off, pooh. 06:00 09:30 3.50 0 0 COMPZ RPEQP1 PULD T Make up whipstock retrieval hook BHA#17 09:30 12:30 3.00 0 9,127 COMPZ RPEQP1TRIP T RIH with BHA#17 12:30 12:45 0.25 9,127 9,127 COMPZ RPEQPI FISH P Latch into WS 240TF. PU 45K CTW. Pull WS free with 10K overpull.40K CTW. PUH slowly, orient 180 deg. Open EDC, (concerns of stroking jar) circulate bottoms up. 12:45 14:00 1.25 9,127 8,809 COMPZ RPEQP1TRIP P POOH,Circulating keeping hole full 14:00 14:30 0.50 8,809 8,811 COMPZ RPEQP1TRIP P Over pull 8811'. 8K WOB. RBIH to neutral weight to close EDC. 14:30 14:45 0.25 8,811 8,811 COMPZ RPEQP1TRIP P Close EDC 14:45 15:30 0.75 8,811 8,806 COMPZ RPEQP1TRIP P PUH 50K, 19K WOB.Stuck 8806'. Pump down backside 1 BPM,800 WHP attempt to free elements past D-Nipple,work pipe up and down Page 13 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 20:00 4.50 8,806 85 COMPZ RPEQPITRIP P -16K WOB, 50K CTW. Pull free, cont. POOH slowly 40 FPM, 5-10 FPM through jewelry pumping down the CT.3 BPM 20:00 20:30 0.50 85 0 COMPZ RPEQP1SFTY P Stop 20 ft from surface. Flow check. Total loss of 40bbls of KWF while POOH. PJSM for Laying down BHA. P/U injector and slowly POOH until c-plate can be installed. 20:30 22:00 1.50 0 0 COMPZ RPEQPI PULD P WS fish at surface,two lower sections of the slip elements are missing. Rig down Coiltrack and fishing assembly. 22:00 23:00 1.00 0 0 COMPZ RPEQPI RURD P Rig up SL&stage reel for welding repairs on bolt eye repairs.(Same as previous failures). 23:00 00:00 1.00 0 2,500 COMPZ RPEQP1 FISH P RIH with a 2.62"magnet with SL to try and latch two slip elements. 10/19/2011 Completed retrieving second slip from WS with a 2.62"magnet. Ran 2.79"Drift to 8800'then 1.81"dummy gun drift to 9230'. Rigged down SL. ,Started to RIH with KB packer assembly and had injector failure. POOH, Unstab pipe and prep for injector (repairs. 184 bbls of KWF losses in 24hours. 00:00 02:30 2.50 9,182 0 COMPZ RPEQP1FISH T RIH with 2.62"magnet run down to 9182'SLMD. POOH slowly. Inspect BHA and found metal shavings, 1 slip element, &cuttings/mud packed around the tool. Losing 10 bbls hour KWF. 02:30 03:30 1.00 0 5,150 COMPZ RPEQP1 FISH T RIH for second slip,tagged up early @5150'-POOH 03:30 04:30 1.00 5,150 0 COMPZ RPEQP1 FISH T POOH to inspect BHA-second slip piece recovered. 04:30 05:30 1.00 0 0 COMPZ RPEQP1 SLKL P RU drift for straddle packer 05:30 07:30 2.00 0 8,800 COMPZ RPEQP1SLKL P RIH 2.79 drift for straddle packer run down to 8800'. POOH 07:30 08:30 1.00 0 0 COMPZ RPEQP1SLKL P At surface, changeout SL crews 08:30 09:30 1.00 0 0 COMPZ RPEQP1SLKL P Wait on tools 09:30 10:00 0.50 0 0 COMPZ RPEQP1SLKL P MU drift 1.5"tool string 10:00 11:00 1.00 0 9,230 COMPZ RPEQP1 SLKL P RIH 11:00 12:00 1.00 9,230 9,230 COMPZ RPEQP1SLKL P Drift down to 9230'SLMD. POOH 12:00 14:00 2.00 9,230 0 COMPZ RPEQP1SLKL P RD Slickline 14:00 14:15 0.25 0 0 COMPZ RPEQP1SFTY P PJSM-MU BHA 18 14:15 15:30 1.25 0 0 COMPZ RPEQP1PULD P PU/MU BHA 18, (Shorty deployment sleeve/KB packer/1 jnt solid liner/pup jnt/mule shoe) 15:30 16:30 1.00 0 3,705 COMPZ RPEQP1TRIP P RIH 16:30 20:30 4.00 3,705 0 COMPZ RPEQP1 TRIP T Injector head started making metal on metal grinding noise. Slowly POOH inspecting pipe. "**Nabors on Non-Billable Time"* Page 14 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:30 1.00 0 0 COMPZ RPEQPI PULD T Flow check-Lay down packer assembly and close swab valves. 21:30 00:00 2.50 0 0 COMPZ RPEQPI CTOP T Unstab injector and prep for injector maint.&skate change 10/20/2011 Complete Injector repairs. Bullhead KWF to kill well. P/U lower BTT KB packer assembly, RIH and tie in with +3ft correction. Set Lower KB packer assembly from 8850'-8797'and test IA&PBR to 2500 psi. POOH.24 hour losses=250 bbls. 00:00 10:00 10.00 0 0 COMPZ RPEQP1CTOP T Changing out skates on injector. One skate roller was completely cracked in half and two others partially cracked. 10:00 11:00 1.00 0 0 COMPZ RPEQPICTOP T PJSM-Stab CT into injector head 11:00 14:00 3.00 0 0 COMPZ RPEQPI CTOP T Test E-line, MU CTC and BHI drilling head. Pull test 30K, Pressure test 4000psi 14:00 15:45 1.75 0 0 COMPZ RPEQPI CIRC T ****Nabors on Billable time***** Bull Head 50 brls high vis pill, 120 brls KWF Starting WHP 563psi 15:45 16:00 0.25 0 0 COMPZ RPEQP1OWFF T Monitor well for flow-No Flow 16:00 16:30 0.50 0 0 COMPZ RPEQPISFTY T PJSM 16:30 17:30 1.00 0 0 COMPZ RPEQPI PULD T **Nabors NPT***PU/MU BHA 19 17:30 19:30 2.00 0 3,700 COMPZ RPEQPI TRIP T RIH-EDC open pumping .4bpm. 19:30 20:15 0.75 3,700 7,750 COMPZ RPEQP1TRIP P **Off Nabors NPT time**. RIH to new Gamma depth of 7750'-tie in. 20:15 21:00 0.75 7,750 8,840 COMPZ RPEQP1ELOG P Gamma tie in+3 ft correction. RIH to 8500' Bit depth and perform CCL log @ 17fpm. 21:00 22:00 1.00 8,840 8,850 COMPZ RPEQPI PACK P Weight check-P/U weight 28K. Rlh to setting depth pumping.3 bpm with returns.-confirm logging depth zero correction to CCL. RIH to setting depth of 8850'-KB packer depth of 8804'. Start IA= 1240/OA 260/WHP 0/ CT circ,60 psi Close EDC,WOB 0, CT weight 17K, Set PBR 1500psi. Set down 7K WOB. Close the choke-Chart&Pump down IA with diesel-All CT pressure &BHP dropped to zero with only 200 psi increase on IA. 22:00 22:30 0.50 8,850 8,850 COMPZ RPEQPI PRTS P Pump across the top with choke closed before moving pipe to see indication of what failed or sheared downhole. Pump-WHP 500. IA 1600 psi. Confirm& Increase IA to 2500 psi.to test packer. Differential on tool 1050 psi.WHP 1075 psi. Hold for 5 minutes****good test on PBR*** Page 15 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 8,850 8,500 COMPZ RPEQPI TRIP P Bleed down IA to 1400 psi, Open choke&pressure up to release tool, had immediate communication to surface.-POOH started losing returns once stung out of PBR pumping 1 bpm. Flag EOP @ 8500'. Slow pump rate to.5bpm 23:00 00:00 1.00 8,500 5,500 COMPZ RPEQP1TRNS P POOH to surface pumping KWF across the top&down the CT string. Losing 12-15 bbl/hour. 10/21/2011 RIH with BHA#20 6jnts of solid liner and upper KB packer.Once on bottom mechanical failure on BHA- Packer released and did not set. BHA#21 fishing run&retrieved KB packer&liner.Total losses 275 bbls/24 hour KWF. 00:00 01:30 1.50 5,500 44 COMPZ RPEQPI TRIP P POOH to surface-flow check. 01:30 03:30 2.00 44 0 COMPZ RPEQP1 PULD P Lay down BHA. Setting tool looks normal,testing CT connector to 4000 psi. Recovered ball and changing out coiltrack BHA. Service injector head. 03:30 04:30 1.00 0 242 COMPZ RPEQPI PUTB P P/U 6 joints of solid liner with KB seal assembly&new coiltrack BHA 04:30 07:30 3.00 242 8,741 COMPZ RPEQPI TRIP P RIH with EDC open pumping .3bpm. 07:30 09:00 1.50 8,741 8,800 COMPZ RPEQPI PACK P Correct depth+3'correction to EOP flag. Record up weight, 30K, RIH wt. 15K, RIH.Attempt to sting into lower packer tag 8800',set down 6K WOB. Attempt to pressure up on backside to assure seal assembly is stung into lower packer, unable to pressure up. Pump.5 BPM down backside attempt to sting into packer.Tag 8800'not stung into packer. Pump down IA 1 BPM attempt to sting into packer. Unable to sting into packer. PUH 200'attempt rotate mule shoe. RIH. Unable to sting in. Pump down backside 1 BPM attempt to sting in. Unable to sting in. Set down 6.75K WOB, LRS attempt psi up IA with MP choke closed. Unable to psi up. Attempt to slowly sting in 2 FPM-15 FPM. Unable to sting into lower packer 09:00 13:00 4.00 8,800 0 COMPZ RPEQPI TRIP T POOH 30-40 FPM to allow trapped psi to bleed from ball on seat.Trapped psi due to running FVS (Flapper Valve Sub)in BHA located below EDC. 13:00 13:15 0.25 0 0 COMPZ RPEQP1SFTY T At surface, Monitor well for flow. PJSM 13:15 14:15 1.00 0 0 COMPZ RPEQP1PULD T LD BHA, Packer not on BHA. 14:15 15:30 1.25 0 0 COMPZ RPEQPI PULD T MU Fishing BHA Page 16 of 21 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:30 19:00 3.50 49 8,500 COMPZ RPEQP1TRIP T RIH slowly, with fishing assembly. Stop and correct depths on flag @ 8500'+2ft correction.CT weight 16K, Upweight 29.5K.Zero WOB sensor 19:00 19:15 0.25 8,500 8,602 COMPZ RPEQP1FISH T RIH pumping.2 bpm-Tagged TOF @ 8602.5'Sit down 5K-P/U weight 31.6K-400 pounds WOB drag.Stop pumping-go down and tag again to ensure fish is latched. Positive WOB @ 8602' ,set down 2K-PU weight dry-32K,500 lb increase WOB drag. 19:15 21:45 2.50 8,602 320 COMPZ RPEQP1 FISH T POOH with EDC open pumping .4 bpm.. Bump up at surface. No-flow. 21:45 00:00 2.25 320 0 COMPZ RPEQP1 PULL T Fish at surface. Lay down BHA and lay down 6 jnts of liner to inspect seal assembly.Seals looked good, bottom on mule shoe had one small little nick. Service injector. 10/22/2011 Set upper KB packer and pumped 17 bbls diesel down IA. Started to test upper KB packer had communication from IA to tubing. Release from packer POOH and run slickine D&D tool. RIH to 8606'SLMD -initial test failed indicating casing leak above the packer. Continue with D& D testing every 100'intervals. Total 231 formation-158 bbls to tiger tank. 00:00 01:00 1.00 0 252 COMPZ RPEQPI PUTB T P/U BHA#22 with Seal Assembly, centrilizer,6 joints of solid liner, KB packer and Coiltrack assembly with HOT&no FVS. 01:00 04:00 3.00 252 8,500 COMPZ RPEQPITRIP T Rlh with EDC open pumping.3bpm. Correction+2.5 ft.Weight check 30K. RIH 10ft above seal assembly. 04:00 05:00 1.00 8,500 8,803 COMPZ RPEQP1PACK P Stop Close EDC&set up to pump down backside. Slowly sting into seal assembly while pumping down backside.3 bpm with closed choke. WHP increase from 30 psi to 90 psi when stinging in PBR.Stop pumping with-80 psi differntial on BHA @ 8801' No-go tag at 8804.5'. P/U 2ft over break over from 8802'to 8800'.WHP 90, BHP 3150, Circ 30,Annular 3240psi. IA 1340psi Increase backside to 500 psi to test PBR seals. Good test.WHP 480/ BHP 3591, circ 40, IA 1780psi. Rig up LRS to pump diesel down IA. 05:00 06:00 1.00 8,803 8,800 COMPZ RPEQP1CIRC P Bleed WHP slowly through choke- Start pumping 17 bbls of diesel down IA Start IA 1400 psi, BHP 3235 psi, WHP 10, pump 1/2 bpm. 06:00 06:30 0.50 8,800 8,800 COMPZ RPEQP1SFTY P Crew Change/PJSM Page 17 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 8,800 8,800 COMPZ RPEQPI PACK P Space out packer. RIH set down 2.5K WOB at 8803.8'. PUH to break over point on weight indicator 8801.84'. Pick up another 2',8799.8'. Set packer 1588 diff. psi. RIH to assure packer set.set down 2.5K at 8801.69',this indicating packer set. RIH set down 7K WOB.2731ann psi, 4336 bore psi. Pressure test packer IA/MIT to 2500psi.At 2000psi pressure dropped. Shut down test pump and monitor.After 5 min. IA 930,WHP increased 50psi.Attempt to pressure up on IA again testing packer.WHP increase to 130psi while trying to psi up on IA indicating packer leaking. 07:30 08:00 0.50 8,800 8,800 COMPZ RPEQP1 PACK P Attempt to set packer again compressing elements, PU 30K, RIH set down 10K WOB.Attempt to pressure test packer to 2500psi, at 1450psi on IA shut down.After 5 min WHP increase to 300psi. 08:00 08:30 0.50 8,800 8,800 COMPZ RPEQP1 PACK P Attempt to pressure up on 2"x 3.5" annulus.300psi, monitoring the IA 3.5"x 5.5"annulus. Starting pressures 300 WHP(2"x 3.5"), 1100 psi IA(3.5"x 5.5"). Pressure increased on IA immediatly. Possibly the Packer not holding or GLM. Packer elements set at 8608.22' 08:30 08:45 0.25 8,800 8,800 COMPZ RPEQP1TRIP P Release off packer 2100psi CTP. PU 29K. Released from packer 08:45 11:45 3.00 8,800 7,500 COMPZ RPEQP1TRIP T POOH, Diesel in returns immediatly. At 7500'gas in returns.WHP increasing. Diesel strung out in KWF.WHP increased 580psi shut in. RIH to 8550 to Kill well. Bull head 60brls KWF Diesel in returns indicating IA leak much higher in wellbore. 11:45 12:15 0.50 7,500 7,500 COMPZ RPEQPI SFTY T Attempt to Bleed WHP to Tiger tank. Choke plugged. Bleed to pits. high level LEL in pits.. Complete Rig muster.All accounted for.Contact Pad Operator, have pad operator sniff pits for residual LEL. Readings 0 ppm. Reset alarms. 12:15 15:30 3.25 7,500 0 COMPZ RPEQP1TRIP T Flow check well,well is dead, POOH,.Tough to keep returns. 15:30 16:30 1.00 0 0 COMPZ RPEQP1SFTY T At surface, Flow check. PJSM 16:30 17:30 1.00 0 0 COMPZ RPEQP1PULD T LD Tools 17:30 19:30 2.00 0 29 COMPZ RPEQP1SLKL T PJSM, PU Slickline. Keeping hole full with KWF. Pressure test SL PDL. Page 18 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 29 8,606 COMPZ RPEQP1SLKL T Make up D&D hole finder 29 ft BHA lenght to run down and test lower straddle packer. IA= 1055/OA 255 -RIH.Tag Top of Packer assembly @ 8606'WLMD. 21:00 22:00 1.00 8,606 0 COMPZ RPEQP1SLKL T Stop pumping-set D&D testing tool. Close choke.Start-IA 1107, WHP 0. Increase WHP&IA is building as well. Stop pumping 800 psi on WHP &IA 1480. End-WHP 545 psi/IA 1643 psi. P/U SL 100'below GLM @ 4979'& test again. Start-SLMD 5096'Close choke, IA 965psi. End WHP-900 psi-IA 935psi. GLM tested good. POOH to re-pin the tool. 22:00 00:00 2.00 0 5,000 COMPZ RPEQP1SLKL T Redress tool-RIH to Top of packer. 10/23/2011 Ran SL D&D tool found IA/tubing leak @ 6690'SLMD. Continue to test tubing to find good KB setting point. Ran CCL log&final D&D run to test area of 6450'. Rig down SL.total losses 295 bbls in 24 hours. 00:00 02:00 2.00 5,000 8,590 COMPZ RPEQP1SLKL T Start D&D testing from 8590'SLD and continue moving up hole in 100' test intervals to find casing leak. ***Continued to have IA communication up to 6690'. IA did not gain pressure but WHP leaked off. P/U 50ft and test again.*** 02:00 04:30 2.50 6,650 0 COMPZ RPEQP1SLKL T **Good solid test from 6650'-Pull a test every 10ft to 6600'.Tubing testing good 6650,6640,6630'.*** Failed test in tubing not IA @ 6620',6610' P/U 100'and test 6510'- passed with slight leak off. POOH to inspect tool&contact town. 04:30 08:45 4.25 0 6,600 COMPZ RPEQP1SLKL T RIH and test in 100'increments from 6600-5610'.All tests pass except 6310,6210, 5610.***Did not have IA communication***, indicating possibly set in collar, or the ID integrity in 3.5"is bad. Tubing leak below 6650' Good tests 6650-6600',testing in 10' increments 08:45 09:15 0.50 6,600 0 COMPZ RPEQP1SLKL T POOH with slickline 09:15 09:30 0.25 0 0 COMPZ RPEQP1SLKL T At surface with SL.Crew change SL crew. PJSM 09:30 10:30 1.00 0 0 COMPZ RPEQP1SLKL T RD Slickling 10:30 11:30 1.00 0 0 COMPZ RPEQP1PULD T PU/MU BHA 23. 11:30 13:30 2.00 43 7,800 COMPZ RPEQP1TRIP T RIH 13:30 13:45 0.25 7,800 7,800 COMPZ RPEQPI DLOG T Tie in depth with Gamma+1' correction Page 19 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 14:45 1.00 7,800 6,400 COMPZ RPEQPI DLOG T PUH to 7000' Log up for CCL 14:45 16:45 2.00 6,400 0 COMPZ RPEQP1TRIP T POOH, Paint EOP flag 6000' 16:45 17:00 0.25 0 0 COMPZ RPEQP1SFTY T Monitor well for flow, PJSM 17:00 18:00 1.00 0 0 COMPZ RPEQP1PULD T LD BHA 18:00 00:00 6.00 0 6,460 COMPZ RPEQPI SLKL T Rig up SL for final D&D test. RIH tag TD-P/U and start testing from 6460-6442'in 2ft increments.All passed with Max.WHP 1000 psi. POOH with SL. Rig down SL operations. 10/24/2011 RIH with KB packer to seeting depth of 8603'. Pump 11.8 of formate down the tubing prior to setting KB packer.Set packer and test to 2400 psi. Passed-tested tubing by IA up to 2450psi held for 30 minutes. Pass. Upper&lower straddle from 8850'-6448' POOH,Set BPV, Purge CT&BOP stack with corrossion inhibitor. 00:00 01:30 1.50 0 0 COMPZ RPEQP1SVRG T Set up rig floor for running liner. Service top drive. PJSM for P/U liner. 01:30 08:00 6.50 0 2,200 COMPZ RPEQP1PUTB T Start P/U seal assembly-68 jnts 2 3/8"Hydril 511 -Baker 35KB packer assembly Inspect stripper rubber 08:00 10:45 2.75 2,200 8,550 COMPZ RPEQPITRIP T RIH,tie into EOP flag+.69' 10:45 11:45 1.00 8,550 8,550 COMPZ RPEQPI PACK T Prepare Formate KWF.Water down from 13.1 ppg to 11.8ppg. 11:45 12:30 0.75 8,550 8,550 COMPZ RPEQPI PACK T Displace CT to Formate KWF. 35brls 12:30 13:00 0.50 8,550 8,550 COMPZ RPEQPI PACK T Bullhead 50brls 1.6 BPM, 1400 WHP. 13:00 13:30 0.50 8,550 8,603 COMPZ RPEQPI PACK T Shut down pump.WHP slowly bleed down to 0. Closed EDC. Record up and down weights. 30K up, 12K down. RIH to deployment sleeve, pumping .4 BPM, 180psi.WHP increase 300psi 8608'. Bleed WHP to 0. RIH no-go 5K down on WOB. 8613.92'5K down. PU 2'past break over point on wt indicator,8609.12'. Pressure test seals, 300psi, hold 5 min.Good Test. Bleed down. RIH, PU 2'Confirm spaceout.8609.21'. Set packer pumping down CT 1550 diff psi. RIH confirm packer is set. 8610'4K WOB.Confirms packer set. 13:30 16:00 2.50 0 8,610 COMPZ RPEQPI PRTS T Pressure test packer. IA-2300, IA-11 psi,After 5 minutes IA-1795, WHP-78psi. Bleed psi.Set down 10K WOB on elements.Attempt test again. Second Test good: IA-2450, WHP-33.After 30 minutes bleed down to 2340 in 5 minutes.WHP 33. 16:00 17:30 1.50 8,610 0 COMPZ RPEQPITRIP T Release from packer, POOH Page 20 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 17:45 0.25 0 0 COMPZ RPEQP1OWFF T At surface, Monitor well for flow. 17:45 19:00 1.25 0 0 COMPZ RPEQP1PULD T LD tools 19:00 20:00 1.00 0 0 DEMOB WHDBO CTOP P Flush BOP's 20:00 22:00 2.00 0 0 DEMOB WHDBO NUND P Set BPV 22:00 00:00 2.00 0 DEMOB WHDBO CIRC P Pump corrossion inhibitor through CT string and BOPE stack. Flush all iron at surface. 10/25/2011 Rig Release @ 06:00 HRS Total well losses to formation 73 bbls Bio, 140 bbls flo pro, 2189 bbls 11.8#Brine,25 bbls 11.8#Formate. 00:00 06:00 6.00 0 0 DEMOB MOVE RURD P Purge CT&stack with air,offloading fluid and rig down. 0 DEMOB *****RIG RELEASE***Excempt move to 2K-22 Page 21 of 21 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, October 24, 2011 6:49 PM To: Long, Jill W Cc: Nabors CDR2 Company Man Subject: Re: Nabors CDR2-BOP Test Clarification PTS U/—/ 3G Jill, Thanks for the update and you are correct that a BOP test is not required if you are OOH before midnight or are POOH and have no plans to reenter . If you encounter unexpected delays call back for further guidance. Regards, Guy Sent from my iPhone On Oct 24, 2011, at 5:17 PM, "Long, Jill W" <Jill.W.Long�cr�,conocophillips.com>wrote: Guy- As we just discussed on the phone, CTD operations on 2L-307 (being performed by Nabors CDR2) are complete. The rig is currently in the process of POOH. Once at surface the BHA will be laid down and the BPV set in preparation for rigging down and moving off the weU. The Rig Supervisor and I both called you to discuss our current operations because the next BOP test due on this well must be started by midnight tonight, Monday, October 24. By midnight this evening we expect to be out of the hole with no plans to re-enter the wellbore except to set a BPV in preparation for rigging down. However, the rig may not be officially released until morning, Tuesday, October 25. This is the first time that we remember this situation arising(i.e. POOH to rig down on the same day that a BOP test is due). For clarification and to ensure that we are in compliance with State regulations, we would like to confirm that a BOP test does not need to be started prior to midnight since operations are complete and there is no plan to enter the wellbore again. If you have questions please give the Rig Supervisor(907-659-3990) or myself a call to discuss. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 10/25/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Long, Jill W[Jill.W.Long@conocophillips.com] rip Z 1 (� I SSent: Friday, October 07, 2011 1:53 PM To: Schwartz, Guy L (DOA) Subject: RE: 2L-307 New Drilling PTD- Initial Discussion a - 30 7 L Z —o / Thank you for walking through the naming conventions with me Guy. As we discussed, since the revised plan for 2L-307L2 does not deviate from the permitted plan by more than 500', the first lateral drilled out of the upper window will remain as permitted (2L-307L2). We will submit the new PTD application for the 2L-307L2-01 lateral next week after operations for 2L-307L2 are underway. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 From: Long,Jill W Sent: Friday,October 07,2011 1:39 PM To: 'Schwartz,Guy L(DOA)' Subject: 2L-307 New Drilling PTD-Initial Discussion << File: 2L-307 Description Diagram 100711.pdf>> Guy- ConocoPhillips is currently drilling the 2L-307L1 lateral. We will need to submit a new PTD for an additional lateral, however, before I do so, I'd like to discuss with you the naming convention that should be used. I've attached a diagram to use in our discussions. After our discussion I will submit a formal request for verbal approval. Jill Long ConocoPhillips Alaska Drilling and Wells • Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 • 10/7/2011 • • " IJ r w w r 0 0 V V C) C) —I —1 p O y Vl a a co F...' m m el w to 'v O 'o m v o 0 co co o. •.T v CD CD 3 3 mA a. a. z o 3 3 3. 3 co Ca o 0 < < /Dig 7 7 O O o o CI N o a ✓ m 3 x v a CD m N 3 a r CD w V SO N9r gr Al S N o a. 1 i m N N r : .1 I V r N r N a 0 C.' SMIE OF ir\t\ ILASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-307L2-01 ConocoPhillips Alaska, Inc. Permit No: 211-136 Surface Location: 157' FNL, 602' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 1494' FSL, 729' FWL, SEC. 24, T1ON, R7E, 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 2L-307, Permit No 198- 256, API 50-103-20284-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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. Sincerely, 0 wr Daniel T. Seamount, Jr. 2 Chair DATED this 1 Jday of October, 2011. cc: Department of Fish 86 Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) 2 RECEIVE STATE OF ALASKA )CT 1 1 ���� ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil& Gay Cons. Con jssion 20 AAC 25.005 rYirtm*Age la.Type of Work: • lb.Proposed Well Class: Development-Oil ❑✓ • Service-Winj ❑ Single Zone ❑✓ • 1c.Specify if well is proposed for: Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2L-307L2-01 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10385' I TVDSS: 5220' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 157'FNL,602'FEL,Sec.22,T1ON, R7E, UM . ADL 380051 • Tarn Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1989'FSL,561'FWL,Sec.24,T1ON, RO7E,UM 4599 10/14/2011 Total Depth: 9.Acres in Property: 14.Distance to 1494'FSL,729'FWL,Sec.24,T1 ON, RO7E, UM 2560 Nearest Property: 4720 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 152 feet 15.Distance to Nearest Well Open ' 28 feet Surface:x- 461049 . y- 5927689 . Zone- 4 GL Elevation above MSL: to Same Pool: 2L-313,985 16.Deviated wells: Kickoff depth: 9850 •ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.03 ) _ _ )4.- Maximum 'Maximum Hole Angle: 101° deg Downhole: 378.c Pu Surface:3 25-°7 p•sg: /6.6" 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 ST-L 1255' 9130' 5277' 10385' 5220' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9727' 5765' 9581' 5684' • Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 9 cu yds High Early 115' 115' Surface 2870' 7.625" 387 sx AS III,235 sx Class G 2905' 2307' Intermediate Production 9674' 5.5"x 3.5" 253 sx Class G 8848',9709' 5755' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 9210'-9240' 5474'-5491' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: 6.1 w5G1+ +4ytt /o%zlie Date: " 11 22. I hereby certify that the foregoing is true and correct. Contact Jill Long 4093 '�' Printed Name L. G UTitle CTD Engineering Supervisor SignatureVI) , I ��C�� Phon 265-6306 Date /0 /)r ii' Commission Use Only Permit to Drill API Number: Permit ApprovI n See cover letter ,2 Number: / 1,.��j 50-45-2C21)}4-6Z-00 Date: tot 13 I I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: L� * 3500 r S1" Bo P -7;-:-S-1- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [/ Other: it 2SD� s i AwaJ /cr,f- H2S measures: Yes [ No • Directional svy req'd: Yes [r No ❑ / / �j / APPROVED BY THE COMMISSION ` ✓ /� DATE ice/ r E ,COMMISSIONER Form 10-401 (Revised 7/2009) This ermit is valid for 24 mo i►rs kol�rSteto a`ppl\oittI p C 25.005(9)) Submit in Duplicate OSS 1a ac3 i) /o.!z •!( .4 "--)/P/-2/// /13' ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED October 11, 2011 OCT 11 2011 Alaska Oil&Gas Cons. Comllussi Commissioner- State of Alaska 011 Alaska Oil &Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill (PTD) application for an additional coiled tubing drilling (CTD) lateral (2L-307L2-01) out of Kuparuk's Tarn well 2L-307 (PTD# 198-256). This permit will be in addition to the previously permitted laterals 2L-307L1 (PTD# 211-093) and 2L-307L2 (PTD# 211-094). CTD operations began at 2L-307 on 10/1/2011. To date, 2L-307L1 has been drilled and completed. Drilling of 2L- 307L2 should begin today. The objective of the additional lateral, 2L-307L2-01, will be to contact sections of the reservoir that will not be drilled with one of the other two laterals. While drilling 2L-307L1, higher reservoir pressures were encountered which resulted in calling TD of the lateral early. Because of this, not all of the reservoir objectives for that lateral were achieved. By adding an additional lateral, the objectives of the entire project should be achieved. The overall objective of the CTD project remains the same: to improve sweep efficiency and oil recovery by drilling lateral sidetracks in the Bermuda reservoir. There will be two, single string window exits out of the 3.5" liner in 2L-307. Attached to this application are the following documents: — Permit to Drill Application Form: 2L-307L2-01 — Updated Wellbore Schematic — Directional plans for 2L-307L2-01, including anti-collision review — Previously Submitted Summary of Planned Operations — Addendum to the Previously Submitted Summary of Planned Operations — BOP Schematic If you have any questions or require additional information please contact me at 907-263-4093 (office) or 907- 230-7550 (cell). Sinc _ Jill Lo g Coiled Tubing Drilling Engin r Permit to Drill Summary of Operations Tarn 2L-307L1 and 2L-307L2 Summary of Operations Tarn well 2L-307 was drilled and completed in 1999 as part of the original Tarn development program. The well has been on production since completion. From 2001 to 2007 it was on jet pump service but was then converted' to gas lift service where it has remains to date. Recent diagnostics confirm that there is TxIA communication near one of the gas lift mandrels. However, a combo MIT T&IA was performed on July 15, 2011, to 3000 psi and passed confirming integrity of the 5.5" production casing. The 5.5" casing head is rated to 5000 psi which will accommodate the maximum anticipated surface pressure of 2120 psi. Because of this, CTD operations will continue and a tubing patch will be installed afterwards. The CTD sidetracks at Tarn are intended to improve areal sweep efficiency and oil recovery from the 2L-323/2L- 317A line drive flood patterns. Also of significance, these laterals will be the first CTD laterals drilled in the Bermuda reservoir. The outcome of this project will provide significant information on the productivity of un- stimulated horizontal laterals in the Bermuda. The parent wellbore perforations will be isolated while drilling with use of a packer/tray system. The laterals are planned to be on production for at least several months prior to re-opening the parent perforations. Operational Outline Pre-Rig Work 1. Perform diagnostics to verify gas lift mandrel is leaking 2. Perform dummy whipstock drift. 3. Obtain updated SBHP. 4. Caliper the 3.5" tubing and liner from 9250'to surface. 5. Mill out 2.75" D nipple to 2.80". 6. Set BPV and prepare wellsite for rig arrival. CTD Procedure Overview 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set the lower whi s cke -at-9185' MD. Mill a 2.80", single string window exit with high-side orientation. 3. 2L-307L1 Lateral a. Drill 2.70" x 3" bi-center lateral in the Bermuda to a TD of 11315' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to-5' below the window(-9190' MD)to allow access to the tray 4. Set the upper whipstock at-9125' MD. Mill a 2.80", single-string window exit with high-side orientation off of the upper whipstock. 5. 2L-307L2 Lateral a. Drill 2.70" x 3" bi-center lateral in Bermuda to a TD of 11360' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to the-5' below the window (-9130' MD)to allow for retrieval of the whipstock equipment. 6. Retrieve upper whipstock. 7. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Post-Rig Work See 1. Install gas lift design. M n 2. Place patch across the leaking gas lift mandrel 3. Put on production. Z`-3o712-a Page 1 of 3 0R I G I N L 10/11/2011 PTD Applications: 2L-30i L1 and 2L-307L2 Operational Details Hazards - There have historically been loss circulation issues when drilling in the Bermuda T3 sands due to low- ✓ strength rock. Optimizing the directional plan will be done to help minimize this risk. - Drillsite 2L is an H2S pad. The maximum recorded H2S reading on the pad in 2010 was 20 ppm at wells 2L- 301 and 2L-325. The most recent H2S reading on well 2L-307 was 10 ppm on (1/14/10). All H2S monitoring equipment should be operational. - The wellbore does currently have T x IA communication. Special consideration will be given to monitoring the OA pressure while drilling. Fluids Program - Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. - Chloride-based Flo-Pro mud (8.6 ppg)for drilling operations. / - 2L-307 does not contain a subsurface safety valve(SSSV). In order to maintain managed pressure on open reservoir while running completions, completion kill weight fluid will be used. The weight of the,- completion kill weight fluid will match the ECD held at the window(planned to be 10.6 ppg). c t� Disposal - No annular injection on this well. J - 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. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD TVDSS TVDSS 2L-307L1 9185 11315 5308 5407 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 2L-307L2 9125 11360 5274 5314 23h 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Existing Casing/Liner/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PO MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 0 115 0 115 1640 630 Surface 7-5/8" 29.7 L-80 BTC 0 2905 0 2307 6890 4790 Casing 5-1/2" 15.5 L-80 MOD 0 8848 0 5267 7000 4990 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 8848 9709 5267 5755 10160 10540 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0 8845 0 5264 10160 10540 Page 2 of 3 10/11/2011 PTD Applications: 2L-30.I1 and 2L-307L2 Directional Planning — See attached directional plans for each of the three laterals. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — Distance to Nearest Property Line(measured to Tarn PA boundary at closest point) Lateral Name Distance 2L-307L1 4720' 2L-307L2 4720' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 2L-307L1 985 2L-313 2L-307L2 985 2L-313 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure The most recent bottomhole pressure at the lower kickoff point (9185' MD/5308' TVDSS) is estimated to be 2650 psi (9.6 ppg EMW). This pressure estimation is based on static bottomhole pressure data acquired in July 2011. Assuming a gas gradient to surface, the maximum surface pressure anticipated is 2120 psi. Well Control — Two well bore volumes(-200 bbl) of 10.6 ppg 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. — BOP diagram is attached for operations with 2" coil tubing. 35oa — Pipe rams, blind rams and the CTpack off will bepressure tested to 250 psi and to.2b60-psi. Maximum surface pressure anticipated while sidetracking out of 2L-307 is —2120 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the expected reservoir pressure of 2650 psi based on recent pressures within the area and assuming a gas gradient of 0.1 psi/ft. — The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 3 ! GI N r L 10/11/2011 Addendum to the S mars of rations at 2L-307 Tarn 2L-307L2-01 , All general information relating to the CTD drilling program at 2L-307 outlined in the previously submitted PTD Summary of Operations is relevant to 2L-307L2-01 as well. The updated information that is lateral specific is noted below. Summary of Operations Additional lateral, 2L-307L2-01, is being added to the 2L-307 coiled tubing drilling (CTD) program after the drilling ✓ of 2L-307L1 and 2L-307L2 have taken place. While drilling 2L-307L1, increased reservoir pressures were / encountered causing the TD to be called earlier than planned. Because of this, the CTD team reconsidered how the planned 2L-307L2 lateral should be drilled. In order to maximize reservoir exposure, an additional lateral (2L- 307L2-01)was added to ensure that all parts of the reservoir would be contacted in order to meet the objectives of the project. The 2L-307L2-01 lateral will kick off from an aluminum billet at 9850' MD from the 2L-307L2 lateral. The planned length of the lateral is 535'. The hole will be completed with a 2%" slotted liner to the TD of 10385' MD with a shorty deployment sleeve left outside of the window at 9130'. Drilling operations will then proceed to retrieving the upper whipstock.✓ Completed Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. 2. Set the lower whipstock/packer at-9185' MD. Mill a 2.80", single string window exit with high-side orientation. 3. 2L-307L1 Lateral a. Drilled 2.70"x 3" bi-center lateral in the Bermuda to a TD of 10624' MD b. Loaded well with completion fluid. Ran 2%" slotted liner from TD to just inside the window 4. Set the upper whipstock at-9125' MD. Milled a 2.80", single-string window exit with high-side orientation off of the upper whipstock. Remaining Work 1. 2L-307L2 Lateral- In progress ' a. Drill 2.70"x 3" bi-center lateral in Bermuda to a TD of 10370' MD.' b. Load well with completion fluid. Run 2%" slotted liner from TD to 9850'with an aluminum billet on top. 2. 2L-307L2-01 Lateral • a. Kickoff of the aluminum billet set in 2L-307L2 at 9850'. ' b. Drill 2.70" x 3" bi-center lateral in Bermuda to a TD of 10385' MD ittiy c. Load well with completion fluid. Run 2%" slotted liner from TD to just outside of the window 3. Retrieve upper whipstock. Run straddle packer assembly to isolate leak in tubing. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Casing Program 2L-307L2-01: 2%', 4.7#, L-80, ST-L slotted/solid liner from 9130' MD to 10385' MD '- Directional - See attached directional plan: 2L-307L2-01 - 2L-307L2-01: -4720' to property line, -985' to well 2L-313 Page 1 of 2 r'I P ! GIN AL 10/11/2011 4: PTD Application: 2L-307L2-01 Fluids Program — Chloride-based Biozan brine(8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (8.6 ppg)for drilling operations. — 2L-307 does not contain a subsurface safety valve(SSSV). In order to maintain managed pressure on open reservoir while running completions, completion fluid will be used. The weight of the completion kill weight fluid will match the ECD held at the window (planned to be 10.7 ppg) or the reservoir pressure encountered while drilling, whichever is greater. On 2L-307L1 the completion fluid ended up being a weight of 11.9 ppg. Reservoir Pressure The near wellbore pressure seen while drilling 2L-307L1 was consistent with the most recent bottomhole pressure taken in July 2011 which estimated the pressure at the lower kickoff point (9185' MD/5308' TVDSS) to be 2650 psi (9.6 ppg EMW). However, while drilling 2L-307L1, higher reservoir pressures were encountered up to an 11.8 ppg EMW. 2L- 307L2 and 2L-307L2-01 are not planned to exceed the 11.8 ppg pressure equivalent. Assuming a conservative if 12.0 ppg equivalent at the upper window (9125' MD/ 5274' TVDSS), the pressure at the window would be 3291 psi. The maximum surfacepressure anticipated based on this 12.0EMW usingagas gradient to surface is P ppg 2764 psi. The last recorded highest bottomhole pressure in surrounding wells was a 13."8 ppg equivalent. This pressure reading was taken in September 2009. If a 13.8 ppg equivalent pressure is seen in 2L-307L2-01, pressure at the window will be 3785 psi. The maximum surface pressure based on this pressure using a gas gradient to surface is 3257 psi. '---- Well --"Well Control — Two well bore volumes(-200 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. — BOP diagram is attached for operations with 2" coil tubing. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum surface pressure anticipated while sidetracking out of 2L-307 is —2764 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the expected reservoir pressure of 3291 psi based on recent drilling pressures and assuming a gas gradient of 0.1 psi/ft. — The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 2 IrD I A I 10/11/2011 O N o a a O c Y CY r` Y ry \ CC 0 O N N 03 \ co m N �`0 Lc) -p N V,RK2 co 0 00 E Cb O co TO 0 0) ) E CO E a) Cl) a) N CO 0 V C N Y 0) U _J O CO T Q Y - iz ca ca r— J p O ::-_-• CL m Q 0 V �N N CO O C = o 2 Y a) a) _J o_ N -2 (n a) c- N H 11 r-- J 0 cornci) rI co I 1 w T-0 N �N 0 ti U / / II J ❑ O w ti Q Q OO O I N m co m m u) (�) s� 1 1 11 /------ ---- O (V Y Y p v 0 0 1 1 1 1 J co o O V O O O 00 U �1 ��� N *k E E 3 E E c13 ?I\-1-. �\ ;` 4— CO Cts CB CU CII 00 U \\ / N,\\ O rn U 0 CO 0 0 Li) \'\ /f N•�. N N N N N N a) Q) a) \��` /1 `�N� }+ CO CO CO CO CO CO CO CO CO \�\ \\\ • as 11 /1 11 // I / / // (..,) i .„ i - EnOiiD r o y 1 1 m II us I co Zo N ib ❑ OVO a 1 n- O 00 tt Q ' a) p X co Y Li a) J co O N O _E � V J J N N � ❑ J til i F— O (A co a) O > N O) M _ 0 O (NI N 0 O _j c� � o CO O) N co En 7- Co o (j) O ti fo ORIGINAL ConocoPhilli ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2L Pad 2L-307 2L-307L2-01 Plan: 2 L-307 L2-01_wp01 Standard Planning Report 07 October, 2011 oPP— BAKER HUGHES URIGI \IAL r.' ConocoPhillips or its affiliates 1,47 ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2L-307 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level . Project: Kuparuk River Unit MD Reference: 2L-307:152.05 @ 152.05ft(2L-307:152.05) Site: Kuparuk 2L Pad North Reference: True Well: 2L-307 Survey Calculation Method: Minimum Curvature Wellbore: 2L-307L2-01 Design: 2 L-307 L2-01_wp 01 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 2L Pad Site Position: Northing: 5,927,695.13ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30° Well 2L-307 Well Position +N/-S 0.00 ft Northing: 5,927,688.53 ft . Latitude: 70° 12'48.206 N +E/-W 0.00 ft Easting: 461,048.89 ft , Longitude: 150°18'50.890 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 2L-307L2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 10/1/2011 16.27 79.74 57,336 Design 2L-307L2-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,850.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) i 0.00 0.00 0.00 170.00 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) (°) Target 9,850.00 89.92 161.55 5,310.01 -3,131.72 6,448.23 0.00 0.00 0.00 0.00 9,965.00 101.42 161.55 5,298.67 -3,240.09 6,484.38 10.00 10.00 0.00 0.00 10,091.00 101.14 148.70 5,273.92 -3,351.94 6,536.24 10.00 -0.22 -10.20 270.00 10,385.00 99.69 178.57 5,219.57 -3,626.08 6,616.54 10.00 -0.49 10.16 90.00 10/712011 3.37:59PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL VP, ConocoPhillips or its affiliates Es- ConocoPhillips Planning Report BAKER Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2L-307 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2L-307:152.05 @ 152.05ft(2L-307:152.05) Site: Kuparuk 2L Pad North Reference: True Well: 2L-307 Survey Calculation Method: Minimum Curvature Wellbore: 2L-307L2-01 Design: 2L-307L2-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,850.00 • 89.92 161.55 5,310.01 -3,131.72 6,448.23 4,203.86 0.00 0.00 5,924,523.90 467,480.24 TIP/KOP 9,900.00 94.92 161.55 5,307.90 -3,179.09 6,464.03 4,253.26 10.00 0.00 5,924,476.45 467,495.80 9,965.00 101.42 161.55 5,298.67 -3,240.09 6,484.38 4,316.87 10.00 0.00 5,924,415.35 467,515.83 2 10,000.00 101.40 157.98 5,291.74 -3,272.28 6,496.25 4,350.63 10.00 -90.00 5,924,383.11 467,527.53 10,091.00 101.14 148.70 5,273.92 -3,351.94 6,536.24 4,436.02 10.00 -90.71 5,924,303.24 467,567.11 3 10,100.00 101.14 149.62 5,272.18 -3,359.52 6,540.77 4,444.28 10.00 90.00 5,924,295.64 467,571.60 10,200.00 100.94 159.81 5,252.98 -3,448.15 6,582.63 4,538.82 10.00 90.18 5,924,206.81 467,613.00 10,300.00 100.40 169.97 5,234.42 -3,542.89 6,608.20 4,636.57 10.00 92.13 5,924,111.95 467,638.08 10,385.00 99.69 178.57 5,219.57 . -3,626.08 6,616.54 4,719.95 10.00 94.02 5,924,028.72 467,645.99 TD Targets Target Name ' -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2L-307L1,L2,L2-01 P 0.00 0.00 0.00 -2,475.65 6,290.88 5,925,180.71 467,326.30 70°12'23.832 N 150°15'48.322 W -plan misses target center by 5350.21ft at 10200.00ft MD(5252.98 TVD,-3448.15 N,6582.63 E) -Polygon Point 1 0.00 -2,475.65 6,290.88 5,925,180.71 467,326.30 Point 2 0.00 -2,878.86 6,643.02 5,924,775.73 467,676.32 Point 3 0.00 -3,757.53 6,917.63 5,923,895.74 467,946.37 Point 4 0.00 -3,844.93 6,458.03 5,923,810.72 467,486.37 Point 5 0.00 -3,080.75 6,284.03 5,924,575.71 467,316.33 Point 6 0.00 -2,757.16 6,007.31 5,924,900.69 467,041.31 2L-307L2-01 T2 0.00 0.00 5,220.00 -3,624.08 6,615.82 5,924,030.72 467,645.28 70°12'12.534 N 150°15'38.921 W -plan hits target center -Point 2L-307L2-01 T1 0.00 0.00 5,310.00 -3,132.90 6,447.28 5,924,522.72 467,479.29 70°12'17.366 N 150°15'43.799 W I -plan misses target center by 1.27ft at 9850.82ft MD(5310.01 TVD,-3132.50 N,6448.49 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 8,848.00 5,114.49 51/2" 5-1/2 6-3/4 2,905.00 2,155.07 7 5/8" 7-5/8 9-7/8 10,385.00 5,219.57 2-3/8" 2-3/8 3 10/7/2011 3:37:59PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL 4:- ConocoPhillips or its affiliates VP irti ConocoPhilkps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2L-307 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2L-307:152.05 @ 152.05ft(2L-307:152.05) Site: Kuparuk 2L Pad North Reference: True Well: 2L-307 Survey Calculation Method: Minimum Curvature Wellbore: 2L-307L2-01 Design: 2L-307L2-01_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,850.00 5,310.01 -3,131.72 6,448.23 TIP/KOP 9,965.00 5,298.67 -3,240.09 6,484.38 2 10,091.00 5,273.92 -3,351.94 6,536.24 3 10,385.00 5,219.57 -3,626.08 6,616.54 TD 1:c1-2011 3:37:59PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL lots_ '3;1n Malik, I i j,=.j.4 I__ s f i 0 2:11: , .,.._ no pp . I n osa N fJ p j ' m,�,;� b ,., > /' _'il _ n w r'3 ^l .o I a Lg N Fo 5 Sti e ..._:3 fy „8 m m g erIC-e / yy 3 ¢ E Wagai oWI M 0� / N / 1 / ...,. a / N I 4a J N y I K y ^c2 O a a �0�j Y O N� N__ I v W I d , e n— a o — N M =r h .o oo a I in 0 = fi CGF- NNN `7ermmer Menm `',IIc.' I ( /j OOT)(+ o (-)10nos I. O V-.N/ a R. 3 I 0 3 a ^� 2 I V y a 0 $ g. a €aai ani O B R a a. I N oo pMp eG*Of a O N M V M1 .. Oe ,a.O< I r� N v c o ` I �8$SM ma M 3 7 ,6 psi a ZJ � 0KNG L f In O.dMMJ 08$88 ✓ NN O Z OCCO i I Y YO ry ^ _ m ?..4- o ~crN moI .�., i smN '2,.._i : .- CO "6 , O. mr COJiieOo Q D , O N o 0 Ca U +M M M t�'� 0 a -. So,2 w e=co a2�2o� a 0,.: a zm,r5 gi M mood wo gggg o M r, N , ,a as g „ ., .n ,ana-,eag ueeyy © C Noo U N M Q (us OS) q;da4 IEo►paA awl ORIGINAL ili I Ui= "_ �N - 8 1 8 g J ' 8 0 f 2 i .. rl 1 g ET, � dv mddm — d / / , 0 o • 8 S 1 1 a;o i JE ,e-co I 8 w , l. / - O g i / 1 0 W q� ;�./' �/'^ g . li // U • . : I / 3 1 / 8 ,,,� / / e Y j / § �;, y % ; / ma 8 / / i, ff Y N r.- / / i 1�n it + . -Ow O oCT)3a 8 LI: 3 Fh, j i ///? • o I / • N v/�k — / 1 / r. / JJ I / V O 1 CNi 8 I / : § 1 / � D / N 0 ConocoPhillips or its affiliates irrr ConocoPhillips Travelling Cylinder Report BAILER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-307 Project: Kuparuk River Unit TVD Reference: 2L-307:152.05 @ 152.05ft(2L-307:152.05) Reference Site: Kuparuk 2L Pad MD Reference: 2L-307:152.05 @ 152.05ft(2L-307:152.05) Site Error: 0.00ft North Reference: True Reference Well: 2L-307 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2L-307L2-01 Database: EDM Alaska Prod v16 Reference Design: 2L-307L2-01_wp01 Offset TVD Reference: Offset Datum Reference 2L-307L2-01_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,850.00 to 10,385.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,223.30ft Error Surface: Elliptical Conic Survey Tool Program Date 10/7/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 204.27 9,115.40 2L-307(2L-307) MWD MWD-Standard i 9,115.40 9,850.00 2L-307L2 wp04(2L-307L2) MWD MWD-Standard 9,850.00 10,385.00 2L-307L2701 wp01 (2L-307L2-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 1 (ft) (ft) Name (") (") 8,848.00 5,266.54 5 1/2" 5-1/2 6-3/4 2,905.00 2,307.12 7 5/8" 7-5/8 9-7/8 10,385.00 5,371.62 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2L Pad 2L-301-2L-301-2L-301 Out of range 2L-304-2L-304-2L-304 Out of range 2L-307-2L-307L1 -2L-307L1 9,866.47 9,900.00 42.31 0.29 42.03 Pass-Minor 1/10 2L-307-2L-307L2-2L-307L2_wp04 9,850.00 9,850.00 0.00 0.38 -0.22 FAIL-Minor 1/10 2L-309-2L-309-2L-309 Out of range 2L-311-Plan 2L-311A-2L-311A(wp01) Out of range 2L-313-2L-313-2L-313 10,236.42 9,975.00 369.81 2.34 367.78 Pass-Minor 1/10 2L-317-2L-317-2L-317 Out of range 2L-317-2L-317A-2L-317A Out of range 2L-320-2L-320-2L-320 Out of range 2L-320-2L-320PB1-2L-320PB1 Out of range 2L-320-2L-320PB2-2L-320PB2 Out of range 2L-321-2L-321-2L-321 Out of range Prelim:2L-302(Langley)-2L-302-2L-302(wp01) Out of range Prelim:2L-302(Langley)-2L-302L1-2L-302L1 (H Out of range Prelim:2L-318(Sierra)-2L-318-2L-318(wp01) Out of range Prelim:2L-318(Sierra)-2L-318PB1 -2L-318PB1 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1077;2011 1 3:12:33PM Page 2 of 7 COMPASS 2003.16 Build 69 IIRIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator I. I Riser r 3J Annular Blind Blind/Shear 2" Pipe/Slip(CT) ip Pump into Lubricator >\/J L\ above BHA rams ► �/� X —I I 1 r Choke 1 2-3/8" Pipe/Slip (BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip (BHA) Kill ►>>><J L>< L 1 r Blind/Shear 2" Pipe/Slip (CT) 5 r Choke 2 1 Swab Valves _lIL Wing Valves ���r��� Tree Flow Cross > Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union OR ! GINL Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, October 12, 2011 10:10 AM To: 'Long, Jill W Subject: RE: Verbal Approval Request: 2L-307L2-01 t '71D al I - 13 c Jill, You have verbal approval to add Lateral 2L-307L2-01 as outlined in your PTD application. We are currently evaluating your application will contact you if any questions or concerns come up in the meantime. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com] Sent: Wednesday, October 12, 2011 9:55 AM To: Schwartz, Guy L (DOA) Subject: Verbal Approval Request: 2L-307L2-01 Guy, To follow up to our phone call this morning, ConocoPhillips' requests verbal approval to add an additional lateral to the current CTD program at 2L-307. Previously permitted laterals for the project were 2L-307L1 (PTD#211-093)and 2L-307L2 (PTD#211-094). The overall reservoir objectives and geologic targets for the program have not changed. The objective of the added lateral, 2L-307L2-01, will be to contact sections of the reservoir that will not be drilled with one of the other two laterals. While drilling 2L-307L1, higher reservoir pressures were encountered which resulted in calling TD of the lateral early. Because of this, not all of the reservoir objectives for that lateral were achieved. By drilling 2L-307L2-01, the objectives of the entire project should be achieved. A PTD application was submitted to the State yesterday, Tuesday, October 11. If you have any questions please give me a call. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 10/12/2011 M 0 N J J N CJ E M a � c E J a a N a o J r+ N eaa a a m E `a. a 0 0 0 a a c c O 0 c c > > c U C) c E E z z d d E E d d a a. T a is a o a o O a` w Y Y v v A ea a -a U) N D 0 F F U U A h 0 0 eh M J J N N 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 a 2 PTD# 2-1 / lfc� Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: 1` ���—`u � <\` C —� sC2( G� (J Circle 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 segment of existing well -00 (If last two digits in API number are Permit No. / ZS-6, API No. 50-43- 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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