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213-040
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. aL3 - 040 Well History File Identifier Organizing (done) ❑ Two-sided I 111111111 ❑ Rescan Needed ff111111111111111 RES AN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Age Date: 3 3 j /s/ ryte , Project Proofing I I BY: MD Date: 3/3/ /s/ P Scanning Preparation 1 x 30 = -30 + cq.. 1 = TOTAL PAGES 51 (Count does not include cover sheet) BY: Maria Date: / /s/ I Production Scanning I Stage 1 Page Count from Scanned File: �� (Count does include cover eet) Page Count Matches Number in Scanning , reparation: YES NO / BY: Date: 3/3 r I /s/ p 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II IllIllIlill liii ReScanned II IllIllIlIll 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 11111 III IIII Ill i o I a E E E m m ' /?/Z��._c p i N Z >. T N _ I.III / m Co m o m m m >, Q y L 'f0 0 co O < 1 c to D- Z Z o o m + on o 0 m m a m o a U r o o Q U C E. w o aJ a� m O ' Q c m a°i o 0 0 °� o o m a o, 2 a. ,a. Q U U J J N O O N O N O = a) 2 i� O Q c0 c aJ aJ a '1 CC Z o auto m E m m m 0 c Q Q N a E Ti �_ 2_ x a s m /Z Z N E o af4i ami tom a :° E 4; =°• o U •v a� a� to E 2 E >- >- } m IX a o o �� �� �c� aw v Q �N p ir m d O c .0 co M M M M o...... -0 ;6 to J U N N N N N N 7 Q Q ! co WN d co y N N N N N y Z co- 00)as IX U v Lo Lo Ix) in CZ E co 1 O W o c C C C c .a rn Co 1 N N CD N a) of a 0.U U O ' 0 0 0 0 0 0 0 j m E 3 m E f° i Z o / j a v v v v v o w Io ►m. N f a- ;4 '4 Tr v v J o_ C I I a) = ! R to rn rn rn rn rn -o E J o m Z o CM O o ZI ' c t0 0 0 0 0 v 0 0 / .� N 46 r O co co N- N- N- N. f� Oc-=.1 a a E ! o. Voo o I �? M / . H N m o. m N a)15 « E = U U y m c Z o U G N O CO m CO > N a)iii +°' c a) E 1; <Y V' J fn N 0 Lo c o F- E ' co/m//� • ) . C co N V/ Q Q co c c o 1 ct Q a c l �1 o io Y °' ZI 0 ` a �1 11 c 0. ! ° m O Q Z o ! /m I (1) w w w w Nit 0 E U I o I a m > > > > Q �� m Z •y N N y Z i 7 C.7 7 co N N N j a)- a a a d N c C C C c H 3 I ,o 0 0 o S c /Z mi�n Z'" > > > > �,�cp o Q Z �I O ` �'�,I 0 c c c c E p / co } �''� op Q d O W O J d! j' ate+ N CO O O CO O O C !0 o Q m c) 2 E co 0 0 co W E a ; a) N CC Z 0 O W a Z N N (N N Cl) W _O O CC 0 1 2 S € :_°. w R O aai Y o Ix p /• NI- p O v c O d a N Z Q p c c �j „ n 7 o E a a 1 c 3 o °w 3 Z c i a 0 10 0 r �T ➢I�, � ' ��im BAKER PRINT DISTRIBUTION LIST MAY 2 0 2013 HUGHES AOG CC COMPANY ConocoPhillips,A laska Inc. INTERMEDIATE FINAL Yes (mandatory) 12-X 0 'It a WELL NAME 2T-03A;03AL1;03AL2;03APB1 RUN NUMBER C� - (mandatory) ")._:2—C.:,c� FIELD Kuparuk BH SALESMAN Anyanwu,Okechukwu(OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF '° (mandatory) LOG DATE: TODAYS DATE: 5/16/2013 I (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital l / ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UI-F'HIN I S #OF COPIES #OF COPIES U ' U 4 4 1 ConocoPhillips Alaska,Inc. I 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 i • 2 AOGCC I 1 I 1 I I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP I 1 I 1 I I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd I�I Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I I 1 I I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,AlAska 99501-3510 J TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 • RECEIVED • STATE OF ALASKA MAY 10 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND ICC la.Well Status: Oil 0 • Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: • 20AAC 25.105 20AAC 25.110 Development ISI Exploratory ❑ GINJ ❑ WINJ ❑ WAG El WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' orAband.: April 23,2013• 213-040/ - 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 April 16,2013 50-103-20073-60 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 377'FSL,556'FWL,Sec. 1,T11N, R8E, UM • April 18,2013 2T-03AL1 • Top of Productive Horizon: 8. KB(ft above MSL): 117'RKB 15.Field/Pool(s): 887'FNL, 1590'FEL,Sec.2,T11N, R8E,UM GL(ft above MSL): 77'AMSL Kuparuk River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 574'FSL, 1318'FEL,Sec.35,T12N, R8E,UM 9444'MD/5793'TVD • Kuparuk Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498945 y- 5970357 • Zone-4 9444'MD/5793'TVD • ADL 25569,25548 • TPI: x-496797 y- 5974373 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-497068 y- 5975834 Zone-4 1714'MD/1697'TVD . 2667,2662 18.Directional Survey: Yes Q 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) 2360'MD/2224'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7676'MD/5854'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# 1440 32' 115' 32' 115' 24" 234 sx CS II 9.625" 36# J-55 32' 3174' 32' 2787' 12.25" 800 sx AS III,350 sx Class G 7" 26# J-55 30' 7893' 30' 6064' 8.5" 640 sx Class G,300 sx AS I 2.375" 4.7# L-80 8014' 9444' 5800' 5793' 3" slotted liner V- 24.Open to production or injection? Yes 0 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" 7458' 7306'MD/5625'ND,and 7413'MD/5702'NC 6PLE iON slots from 8035'-9443'MD 5798'-5793'TVD kA 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. it t z3T13 { Was hydraulic fracturing used during completion? Yes❑ No El I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED f -- 7359'cement plug 29 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting for facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes L__I No n Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 RBDMS MAY 101013 CONTINUED ON REVERSE t/L F Sub 't original only c.) %illl3 -./3 ► J /3 . 4 G F 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? E Yes is 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 2360' 2224' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A2 7777' 5840' • Kuparuk A3 7919' 5813' N/A Formation at total depth: Kuparuk A3 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Gary Eller @ 263-4172 Email: J.Gary.Eller @conocophillips.com Printed Name Lamar Gantt Title: CTU Engineering Supervisor Signature t j&INA tt,L Phone 263-4021 Date t 6/1/13 N. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP 2T-03AL1 ConocoPhiHips /g Well Attributes Max Angle&MD TD . Alaska.11 K; Wellbore API/UWI Field Name Well Status Ind a MD(ftKB) Act Btm(ftKB) ygF 501032007360 KUPARUK RIVER UNIT PROD 101.43 7,820.51 9,450.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:TRDP 25 1/17/2010 Last WO: 12/17/2011 40.00 9/14/1986 Well Canna:-2T-03ALi,5/3/2013 120833 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACK,ADD LATERALS osborl 5/3/2013 III Casing Strings HANGER,28 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER ALt 2 3/8 1.992 a013.8 9,444.0 4.70 L-80 ST-L 1191 g. P Liner Details Top Depth (TVD) Top Inc! Noml... Top(MB) (RKB) (°) Rem Description Comment ID(!n) Illa 8,013.8 5,800.4 96.55 BILLET OPEN HOLE ANCHORED BILLET 1.000 CONDUCTOR, 3z-„s Perforations&Slots Shot • Top(TVD) Btm(TVD) Dens SAFETY VLV, 1 0 Top(MB)Blot(MB) (MB) (MB) Zone Date (oh— Type Comment 1,714 1 8,035.0 9,443.0 5,798.0 5,793.2 4/18/2013 32.0 SLOTS Slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3” centers staggered 18 deg,3' non-slotted ends Notes:General&Safety ` ' End Date Annotation 4/29/2013 NOTE:SIDETRACK,LATERALS AL1,AL2(off main wellbore) PRODUCTION TIE BACK. 30-2.058 GAS LIFT, 2,735 I 1 ll il SURFACE. J L. 32-3,+74 . GAS LIFT. ) L- , 4.663 GAS LIFT. 7 5 854 1 GAS LIFT, __ sow•�I 6,707 GAS LIFT, 7.221 a . ........ . LOCATOR, 7.275 PER.7,284 — PACKER.7,307 -oaaTur4—'LS'i_ NIPPLE,7,358 PLUG,7,359 LOCATOR, 7.407 PACKER.7.413 SSE.7,416 ) NIPPLE,7,448 MEG.7,458 PILOT MOLE. WNDOW 7,458 A, 7,550-7,555 WHIPSTOCK, 7• Mandrel Details PRODPUCTIO Top Depth Top Port 2.038-7.570 S... (TVD) Incl OD Valve Latch Size TRO Run 8,0 5-9443 N...Top(ftKB) (RKB) (°) Make Model (!n) Sery Type Type (in) (psi) Run Date Corn... LINER AL,, 1 2,734.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/14/2013 TD 138-E.0>, 2 4,662.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/14/2013 LINER A. 3 5,854.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/14/2013 7,880.10,983 4 6,707.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/13/2013 LI 5 7,221.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/16/2013 11 Co r N 1 V i Dc d- '' 1 0 0) C 0 03 E,;) i f 0) a C1 'Co- 'Cr i 0 O CO - D co a 0 i ~ V d' c C N� N N� � cif g In E c E 0 =m • Joc) o • `t 0 co. C W J '� 11 '. 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IL (nUQ NNm _.-03 Pre Rig Well Work Summary DATE SUMMARY 3/12/2013 (PRE-CTD) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, TORQUED T LDS TO 450 LBS. 3/13/2013 PULLED ISO SLEEVE @ 1714' RKB; TAGGED w/SIMULATED GYRO DRIFT @ 7863' SLM ( EST. 261'OF RAT HOLE); MEASURED BHP(2746 psi) @ 7530' RKB; DRIFT W/DMY WHIPSTOCK TO 7500' SLM; SET 2.81"XX PLUG &AVA CATCHER @ 7359' RKB' PULLED GLV's @ 6707', 5854' RKB, SET DV @ 6707' RKB. IN PROGRESS. 3/14/2013 PULLED OV&GLV's @ 7221', 4662', 2734' RKB, SET DV's @ 5854', 4662', 2734' RKB, CIRC OUT W/ ' INHIBITED SEA WATER AND DIESEL FP ( PUMP 275 BBL CIRC OUT). LRS&DHD TO CMIT; IN PROGRESS. 3/14/2013 (PRE CTD) : CMIT TXIA PASSED TO 2550 PSI, MV, SSV, SV PASSED DDT. MV, SSV, SV PASSED PT, UNABLE TO PREFORM SSSV DDT DUE TO HYDRALIC PUMP ISSUES. 3/15/2013 (PRE-CTD): SSSV-DDT(PASSED)WITH A GAIN OF 0.5 PSI IN 30 MIN. 3/15/2013 ASSIST DHD PERFORM A PASSING SSSV CLOSURE TEST. IN PROGRESS. 3/16/2013 SET DV @ 7221' RKB; MITT( PASSED); PULLED CATCHER& 2.81"XX PLUG @ 7448' RKB. 3/22/2013 PERFORATE INTERVAL 7451'-7456' USING 2" HSC 6 SPF 60 DEGREE PHASING, CORRELATE TO TUBING DETAIL RECORD 17 DEC 2011, READY FOR COIL. 3/27/2013 Lay in 29 bbls 17 ppg, class"G"cement from 7,860-ft corrected depth. Squeeze—3 bbls to perfs. Clean out tubing to est. TOC at 7,440-ft MD. POOH jetting across all jewelry. Freeze protect. Trap 900 psi on tubing for over balance. Ready for Slickline in 72 hrs. 3/29/2013 BRUSHED& FLUSHED SSSV @ 1713'RKB; FUNCTION TESTED, GOOD. TESTED TBG 1500 PSI, GOOD. TAGGED TOC @ 7389' SLM/7417' RKB;WORKED BAILER TO 7394'SLM/7422' RKB. READY FOR E-LINE. 3/30/2013 LOG GYRODATA GYRO FROM SURFACE TO 7390'WITH GAMMA CCL, REPEAT LOG TO SURFACE. JOB COMPLETE ConocoPhillips Time Log & Summary We//view Web Reporting Report Well Name: 2T-03 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/3/2013 6:00:00 AM Rig Release: 4/23/2013 3:00:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/01/2013 24 hr Summary RDMO for 2T-03 12:00 00:00 12.00 MIRU MOVE 'MOB P Move rig to 2T-03 04/02/2013 Move to 2T-03.Well pad prep work had to be redone,grade pad and install tree valves.Spot rig modules. 00:00 03:00 3.00 MIRU MOVE MOB P Rig modules and shop on 2T location 03:00 21:00 18.00 MIRU MOVE MOB T Well pad grade had to be redone and tree not prepared for rig up(tree valves not installed). 21:00 00:00 3.00 MIRU MOVE MOB P Pad prepped sufficiently to spot rig. Spot rig modules for 21-03.. 04/03/2013 • Continue to troubleshoot BOPE test equipment failures,replaced R1 valve on MP line, BOPE test in progress. 00:00 10:00 10.00 MIRU MOVE MOB P RU Putz,berm up around cellar,RU interconnect,steam,landings,load pits.Spot tiger tank and RU hardline to rig from tiger tank. NU BOP stack. **Accept rig at 0600 hrs** 10:00 20:00 10.00 MIRU WHDBO BOPE P Perform initial BOPE test 250/4700 psi;annular 2500 psi.AOGCC John Crisp onsite to witness test. Troubleshoot tree valve issues.Valve crew and FMC called out several times to service tree valves,finally able to get shell test against master valve. Made crew change @ 18:00. Troubleshoot air in test pump system,also found R1 valve on MP line to be leaking,replaced valve and got good test. 20:00 00:00 4.00 MIRU WHDBO BOPE P Still leaking off slowly,shut surface safety valve while waiting on FMC crew to set 2-way check in BPV profile. BOP test in progress. 04/04/2013 Continue troubleshooting BOPE failures,pull BPV and run TWC,perform initial BOP test,witnessed by AOGCC John Crisp.Replace MP Lines, upper blinds,C-10, R-7 valves.Test both swabs, R-1,R-7,C-10,and BL2 valves,all tested good. 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE T Waiting on FMC crew from Prudhoe 02:00 05:30 3.50 0 0 MIRU WHDBO BOPE T PJSM. PU FMC lubricator,pull BPV, lay down BPV,PU two way check, set same,lay down FMC lubricator, test two way check 250/4700 psi. 05:30 13:00 7.50 0 0 MIRU WHDBO BOPE T End of initial BOPE Test. BOPE test witnessed by AOGCC(John Crisp) Page 1 of 18 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 13:00 13:30 0.50 0 0 MIRU WHDBO BOPE T Rig down test equipment, R/D test pump and freeze protect 13:30 20:45 7.25 0 0 MIRU WHDBO BOPE T PJSM to replace MP line, Upper blind shears,and C-10 valve and R-7 valve,blow down stack and surface lines,replace failures. 20:45 00:00 3.25 0 0 MIRU WHDBO BOPE T PJSM.Fluid pack BOP equipment, test swab valves,R-1, upper blind shear,C-10,R-2, R-7 and BL2 valves,all tested good.BOPE test complete. **Nabors charged for 24 hrs of downtime** 04/05/2013 PT inner reel lines,pull TWC, LD FMC lubricator.Load coil with SW.MU BHA#1 pilot hole assembly. RIH and tag TOC @ 7,426,swap hole over to milling fluid,mill WS pilot hole from 7,426'to 7,580'. 00:00 01:30 1.50 0 0 MIRU WHDBO CIRC P Reverse circulate with water, PT inner reel lines. 01:30 03:30 2.00 0 0 MIRU WHDBO MPSP P PU FMC lubricator,pull TWC, LD FMC equipment.Service and test PDL's. PJSM. 03:30 03:30 0.01 0 0 SLOT WELLPF SFTY P 03:30 04:29 0.99 0 0 PROD1 WHPST SFTY P Pre-spud 04:29 06:23 1.90 0 62 PROD1 WHPST PULD P PJSM. Load coil with seawater,MU checks.PU/MU BHA#1 Hook coil to tool and surface test. 06:23 08:47 2.40 62 7,430 PROD1 WHPST TRIP P RIH, EDC Closed,pumping seawater returns to TT 08:47 09:53 1.10 7,430 7,380 PROD1 WHPST CIRC P Tag TOC, PUH open EDC and circulate hole to Bio Water, PUW=37K Official TOC corrected from K1 is 7426 Post tie in 09:53 12:41 2.80 7,380 7,444 PROD1 WHPST MILL P Bio around,Close EDC, RIH to mill (Counter change 14'), ROP=30FPH, Stalled multiple times @ 7452.5 to 7452.9 call this the X nipple @ 7448 12:41 13:23 0.70 7,444 7,465 PROD1 WHPST MILL P Through X nipple and milling ahead @ 25 FPH,@ 7457.6 ROP dropped to 17.8 FPH 13:23 15:59 2.60 7,465 7,480 PROD1 WHPST MILL P 7465.2'Stall twice as working through,Stalled again 15:59 16:05 0.10 7,480 7,439 PROD1 WHPST WPRT P 7480',Wipe up hole to log K1 16:05 16:11 0.10 7,439 7,448 PROD1 WHPST DLOG P Log K1 for-18'correction 16:11 16:17 0.10 7,448 7,462 PROD1 WHPST WPRT P RBIH to mill, 1.46 BPM @ 2890PSI FS, ROP=20 FPH 16:17 18:17 2.00 7,480 7,500 PROD1 WHPST MILL P Continue milling 1.46 BPM @ 2,892 psi FS, ROP=20 FPH 18:17 18:32 0.25 7,500 7,500 PROD1 WHPST WPRT P 100 ft wiper trip,saw motor work @ 7,467'both up/dn 18:32 19:32 1.00 7,500 7,520 PROD1 WHPST MILL P Milling 1.43 bpm @ 2,892 psi FS, ROP=20 FPH 19:32 19:56 0.40 7,520 7,520 PROD1 WHPST WPRT P Wiper to 7,400',motor work @ same depth 7,467' Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:56 22:56 3.00 7,520 7,560 PROD1 WHPST MILL P Milling 1.44 bpm @ 2,804 psi,ROP= 20 FPH.Several stalls,pick-ups, slow going through perfs, PUW= 37K. 22:56 23:26 0.50 7,560 7,560 PROD1 WHPST WPRT P Wiper trip,PUW=37K 23:26 23:59 0.55 7,560 7,580 PROD1 WHPST MILL P Milling 1.44 bpm @ 2,804 psi FS, ROP=20 FPH 34/06/2013 Made several back reaming trips on low side @ 1 fpm from 7,400;to 7,580',till no improvement in dry drift. POOH. LD BHA#1,jet BOP stack.RU HES S/L,RIH w/memory caliper to tag up @ 7,558',log up hole @ 50 fpm to 6,870',OOH w/caliper,LD caliper,RIH w/WS dummy drift to 7,431',work drift to 7,455'. POOH. RDMO S/L. MU BHA#2,TIH w/Dummy WS to 7,580'with no problems,TOH. Flow check, LD BHA#2. 00:00 00:45 0.75 7,580 7,400 PROD1 WHPST WPRT P PUH to dry drift,dry drift 1K WOB @ 7,467'. 00:45 04:00 3.25 7,400 7,482 PROD1 WHPST REAM P Make several back reaming trips on low side @ 1 fpm.Till no improvement on dry drift run.WOB of 0.5K @ 7,467'. 04:00 04:45 0.75 7,100 7,580 PROD1 WHPST DLOG P PUH.Make CCL logging pass to 7,580' 04:45 06:51 2.10 7,580 62 PROD1 WHPST TRIP P POOH 06:51 07:51 1.00 62 0 PROD1 WHPST PULD P At surface, Flow check well,PJSM lay down BHA on dead well,Blow down and lay down BHA.Mill at 2.79 No Go 07:51 08:27 0.60 0 0 PROD1 RPEQPI CIRC P P/U Nozzle and jet BOP stack 08:27 11:27 3.00 0 0 PROD1 RPEQP1PULD P PJSM, Rig up slickline 11:27 13:15 1.80 0 7,558 PROD1 RPEQP1SLKL P RIH with memory MIT @ 150 FPM, Tag up @ 7558 SLM @ 12:24,Wait for fingers to open up Log uphole @ 50 FPM to 6870 SLM,Trip out of hole @ 100FPM 13:15 14:15 1.00 7,558 0 PROD1 RPEQP1SLKL P At surface,PJSM lay down Memory MIT,M/U Dummy whipstock 14:15 15:00 0.75 0 0 PROD1 RPEQP1SLKL P At surface with S/L, Lay down memory tool, P/U DW 15:00 16:15 1.25 0 7,457 PROD1 RPEQP1SLKL P Set down @ 7431,work to 7455, Work harder and get to 7457,Trip out 16:15 16:51 0.60 7,457 0 PROD1 RPEQP1SLKL P Trip out with Dummy Whipstock 16:51 18:45 1.90 0 0 PROD1 RPEQP1SLKL P At surface,R/D slickline 18:45 19:39 0.90 0 0 PROD1 RPEQP1PULD P PJSM. PU BHA#2,Test MWD, Stab on WH,check pack-offs,tag stripper,set depth,close EDC. 19:39 21:48 2.15 0 7,580 PROD1 RPEQP1TRIP P Trip in hole,dummy drift.Tie-in GR • -7 correction,Tag @ 7,580'.No problems encountered. 21:48 23:42 1.90 7,580 0 PROD1 RPEQP1TRIP P POOH w/BHA,open EDC,continue OOH. 23:42 00:00 0.30 0 0 PROD1 RPEQP1 PULD P Flow check, PJSM, LD BHA#2. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/07/2013 24 hr summary LD dummy whipstock, PU BHA#3, RIH w/Baker whipstock with openhole anchor,set TOW @ 7,550'10 deg LOHS,POOH and LD BHA#3.PU BHA#4,RIH w/BHA#4 milling window assembly,tag WS @ 7,550', start milling casing window,exit casing 7,556',drill rathole to 7,571',ream window,good drift, POOH and LD BHA#4. PU BHA#5,RIH w/build section assembly,in progress. 00:00 00:42 0.70 0 0 PROD1 RPEQP1PULD P LD Dummy WS,MU BHA#3 Baker Whipstock 00:42 03:36 2.90 0 7,560 PROD1 RPEQP1TRIP P TIH w/Baker Whipstock,tie-in GR- 8'correction,continue in hole, PUW=39K,close EDC,PU to 30K, pressure up to 2,850 psi to set anchor,release from WS,TOW @ 7,550'10 deg LOHS. 03:36 05:36 2.00 7,560 0 PROD1 RPEQP1TRIP P POOH with BHA#3 05:36 06:48 1.20 0 73 PROD1 RPEQP1PULD P At surface, Flo check well. Lay down BHA#3 Whipstock setting tools, M/U BHA#4 window milling BHA W .6°mtor,2.80 dimond window mill and 2.79 string reamer 06:48 08:24 1.60 73 7,425 PROD1 WHPST TRIP P RIH with BHA#4 08:24 08:36 0.20 7,425 7,452 PROD1 WHPST DLOG P Log K1 marker for-6'correction 08:36 08:42 0.10 7,452 7,531 PROD1 WHPST TRIP P trip in to 7531 08:42 09:24 0.70 7,531 7,531 PROD1 WHPST CIRC P Swap well to 9.5 PPG used flo pro, close EDC 09:24 09:42 0.30 7,531 7,550 PROD1 WHPST TRIP P Trip in hole to mill window,Tag up @ 7550, PUW=40K 09:42 14:42 5.00 7,550 7,555 PROD1 WHPST MILL P 7550 start milling window, 1.37 BPM @3816 PSI FS 14:42 17:12 2.50 7,555 7,560 PROD1 WHPST MILL • P 7555.2 DHWOB dropped from 1530 lbs to 500 lbs,Continue milling schedule,auto milling as per procedure,exit casing,see Baker milling report 17:12 19:42 2.50 7,560 7,571 PROD1 WHPST MILL P Start milling rathole, 1.37 bpm @ 3,908 psi FS, DHWOB=2.5K,drill to 7,571'.Ream window three times, dry drift window,good drift, PUW=37K,open EDC. 19:42 21:42 2.00 7,571 0 PROD1 WHPST TRIP P POOH BHA#4,close EDC @ 200', flow check, PJSM,on surface. 21:42 22:21 0.65 0 0 PROD1 WHPST PULD P LD BHA#4 22:21 23:00 0.65 0 0 PROD1 DRILL PULD P PU BHA#5 23:00 00:00 1.00 0 4,226 PROD1 DRILL TRIP P RIH w/build section assembly 04/08/2013 RIH w/BHA#5 to 7,571',drill build/turn section to 7,965',pumped to/hi 5 barrel sweeps,chase sweep OOH and LD BHA.PU BHA#6 with rib steer motor,RIH to 7,965',drill A lateral section from 7,965'to 8,204', drilling in progress. 00:00 01:00 1.00 4,226 7,571 PROD1 DRILL TRIP P Continue in hole with BHA#5,tie-in GR-7'correction, PUW=29K,RIH to 7,571'. Page 4 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:54 0.90 7,571 7,571 PROD1 DRILL DRLG P Start drilling 1.38 bpm @ 4,005 psi, DHWOB=2K,stall @ 7,575'. PU, choke plugging off, PU to 7,352'. Open EDC,circulate to clean up choke,lots of metal in returns,close EDC, RBIH. 01:54 04:48 2.90 7,571 7,720 PROD1 DRILL DRLG P Drill ahead 1.40 bpm @ 3,735 psi; WOB=14.8K, ROP=35. 04:48 05:06 0.30 7,720 7,430 PROD1 DRILL WPRT P Wiper to above window,tie-in RA 05:06 05:18 0.20 7,430 7,452 PROD1 DRILL DLOG P Log K1 for+1'correction 05:18 05:24 0.10 7,452 7,580 PROD1 DRILL TRIP P RBIH to log RA Marker 05:24 05:30 0.10 7,580 7,620 PROD1 DRILL DLOG P Log RA Marker @ 7556.5, TOWS=7550, BOWS=7560 05:30 05:36 0.10 7,620 7,720 PROD1 DRILL WPRT P RBIH to drill 05:36 08:30 2.90 7,720 7,870 PROD1 DRILL DRLG P 7720', Drill Ahead, 1.4 BPM @3780 PSI FS, BHP=3665 08:30 09:00 0.50 7,870 7,870 PROD1 DRILL WPRT P Wiper to window,PUW=31K, Overpull @ 7746', RBIH to neutral weight. Pull up through it.Appear to be dragging with slight overpull and negative WOB-100'.Slight stacking at 7740 to 7750 09:00 10:54 1.90 7,870 7,965 PROD1 DRILL DRLG P 7870', Drill Ahead 1.4 BPM @ 3890 PSI FS, BHP=3730 10:54 13:12 2.30 7,965 72 PROD1 DRILL TRIP P Call EOB, Pump 5X5 sweeps,Trip out, PUW=30K. Few additional cuttings at shaker with sweeps 13:12 15:48 2.60 72 68 PROD1 DRILL PULD P At surface, PJSM, PUD BHA#5, Build section for BHA#6 lateral section with Rib Steer motor,M/U to coil and surface test S/B 20 Min for injector service 15:48 18:21 2.55 68 7,965 PROD1 DRILL TRIP P RIH EDC Open,log GR tie-in-8' correction,close EDC,continue in hole,blow down choke. 18:21 21:45 3.40 7,965 8,120 PROD1 DRILL DRLG P 7,965', Drill Ahead 1.40 BPM @ 3980 PSI FS, BHP=4314 PSI. 21:45 22:30 0.75 8,120 8,120 PROD1 DRILL WPRT P Wiper to above window, PUW=33K, swap hole over to new mud.GEO=90.5 Inc 22:30 00:00 1.50 8,120 8,204 PROD1 DRILL DRLG P 8,120', Drill Ahead 1.40 BPM @ 3,894 PSI, BHP=3,682 PSI, DHWOB=1..86K, ROP=54. 04/09/2013 Drill A lateral to 9174',pumping 5 brl low/high vis.sweeps with shortened wiper trips,every third wiper trip pulling back to window for depth correlation.At 8975'stacking,50K pickup to get pipe free. Perform wiper trip back to EOB&Cont. drilling operations. 00:00 01:36 1.60 8,204 8,270 PROD1 DRILL DRLG P Continue drilling ahead 1.41 BPM @ 3,925 PSI, BHP=3,658 PSI, DHWOB=1.80K, ROP=45. 01:36 02:36 1.00 8,270 8,270 PROD1 DRILL WPRT P Wiper trip to above window, PUW=33K 02:36 04:36 2.00 8,270 8,420 PROD1 DRILL DRLG P Drilling ahead 1.41 BPM @ 3,912 PSI, BHP=3,703 PSI, DHWOB=1.72K, ROP=45. Page 5 of 18 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 04:36 05:21 0.75 8,420 8,420 PROD1 DRILL WPRT P Wiper trip to above window, PUW=34K 05:21 07:39 2.30 8,420 8,570 PROD1 DRILL DRLG P Drilling ahead 1.50 BPM @ 3,950 PSI, BHP=3,676PSI, DHWOB=1.65K, ROP=65. 07:39 08:45 1.10 8,570 8,570 PROD1 DRILL WPRT P Wiper trip 08:45 11:15 2.50 8,570 8,720 PROD1 DRILL DRLG P Drilling ahead 1.40 BPM @ 3,890 PSI, BHP=3,722PSI, DHWOB=1.13K, ROP=115. 11:15 12:15 1.00 8,720 8,720 PROD1 DRILL WPRT P 8720'Wiper, 31k off BTM. 12:15 14:00 1.75 8,720 8,870 PROD1 DRILL DRLG P 8720'Drill ahead 1.41 BPM @ 4000 psi 14:00 15:15 1.25 8,870 8,870 PROD1 DRILL WPRT P 8870'Wiper up,31k off BTM. Full wiper&tie in @ 7575'for 1.5' correction. RBIH 15:15 17:00 1.75 8,870 8,975 PROD1 DRILL DRLG P 8870'Drill ahead 1.40 BPM @ 3980 psi,88 ROP,WOB 1.72.Stack wt @ 8974'. Pull a BHP wiper,32k, RIH stacking wt again. PU,stuck,pull to 50k,work several times. 17:00 17:30 0.50 8,975 8,975 PROD1 DRILL WPRT T Neurtal wt,pump BTM's up. Come down on pumps,allow to relax. 2 pulls to 50k,came loose. 17:30 18:45 1.25 8,975 8,000 PROD1 DRILL WPRT P Pull short wiper to 8000' 18:45 21:45 3.00 8,975 9,120 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,4000 ctp,3750 bhp, 21:45 22:15 0.50 9,120 8,000 PROD1 DRILL WPRT P Wiper trip back to 8000'chasing 5 x 5 low/high sweeps up hole 22:15 22:45 0.50 8,000 9,120 PROD1 DRILL WPRT P RBIH 22:45 00:00 1.25 9,120 9,147 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm,3750 ctp, 10k ctw 04/10/2013 Drill ahead on A lateral.Swap out drilling mud system.Stop drilling at 9770', Unable to geo steer with Rib Steer Motor. POOH.At surface,test on SSSV unsuccessful. Undeploy BHA 6.Perform BOPE function test. Deploy BHA 7. RIH with.7 AKO motor. 00:00 02:00 2.00 9,147 9,270 PROD1 DRILL DRLG P Cont drilling 1.4 bpm,3860 ctp,8-9k ctw 02:00 02:45 0.75 9,270 7,550 PROD1 DRILL WPRT P Wiper trip back to window 32k puw 02:45 03:00 0.25 7,550 7,550 PROD1 DRILL DLOG P Log RA marker,+2'correction 03:00 03:45 0.75 7,550 9,270 PROD1 DRILL WPRT P RBIH 03:45 06:15 2.50 9,270 9,420 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm,3950 ctp,3842 bhp, 10k ctw 06:15 07:15 1.00 9,420 9,420 PROD1 DRILL WPRT P Pull 850'wiper,32k pu wt. 07:15 08:00 0.75 9,420 9,459 PROD1 DRILL DRLG P Drill ahead,stacking wt&have a stall @ 9459'pull BHA wiper,stack wt.again before reaching bottom, decide to line up for mud swap. 08:00 09:15 1.25 9,459 9,459 PROD1 DRILL CIRC P Line up for mud swap.Return trucks not here yet, line up returns to tiger tank. Pump new mud. Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:00 1.75 9,460 9,525 PROD1 DRILL DRLG P Drill ahead,have another stall.pick up, Drill ahead, 1.41 BPM @ 3900 psi,kick on rib steer. Having difficulty turning down but get it down to 88 deg. 11:00 12:45 1.75 9,525 9,610 PROD1 DRILL DRLG P Drilling ahead 12:45 13:15 0.50 9,610 8,760 PROD1 DRILL WPRT P 30k off btm. Wiper up,850'to 8760'. 13:15 13:30 0.25 8,760 9,610 PROD1 DRILL WPRT P RBIH 13:30 16:15 2.75 9,610 9,770 PROD1 DRILL DRLG P Drill ahead 1.43 BPM @ 3986 psi. Had stacking issues at 9730'...possible fault? continue drilling to 9770'. 16:15 17:15 1.00 9,770 7,550 PROD1 DRILL WPRT P 29k off BTM.Wiper up to window 17:15 20:00 2.75 7,550 0 PROD1 DRILL TRIP P Continue POOH to drop the rib steer for a conventional motor. 20:00 20:30 0.50 0 0 PROD1 DRILL OWFF P Close SSSV, bleed pressure above. Shut MP choke back in. Pressure building up.Circulate down CT thru SSSV with choke closed.Shut down and bleed pressure on CT and Well. Well flowing.23 bpm. 20:30 21:45 1.25 0 0 PROD1 DRILL PULD P Undeploy BHA 6 21:45 22:15 0.50 0 0 PROD1 DRILL BOPE P Perform BOPE function test 22:15 23:30 1.25 0 0 PROD1 DRILL PULD P Deploy BHA 7 23:30 00:00 0.50 72 5,000 PROD1 DRILL TRIP P RIH 04/11/2013 Drill A lateral performing 850'wiper trips.Pull back to window on third wiper trip chasing 5brl low/high vis sweeps, logging RA marker for depth correlation.Stop drilling at 10670', POOH for sidetrack.24hr total losses to formation 125 brls 00:00 01:00 1.00 5,000 7,409 PROD1 DRILL TRIP P Cont RIH 01:00 01:15 0.25 7,409 7,409 PROD1 DRILL DLOG P Tie in depth to K1,-9'correction 01:15 02:15 1.00 7,409 9,770 PROD1 DRILL TRIP P RIH 02:15 04:15 2.00 9,770 9,820 PROD1 DRILL DRLG P Drill Ahead 1.36 bpm,4029 ctp,3850 bhp, 12k ctw, 158 whp, 04:15 04:30 0.25 9,820 8,970 PROD1 DRILL WPRT P Wiper trip 850'.32k puw 04:30 04:45 0.25 8,970 9,820 PROD1 DRILL WPRT P RBIH 04:45 06:30 1.75 9,820 10,070 PROD1 DRILL DRLG P Drill ahead 1.3 06:30 07:00 0.50 10,070 9,220 PROD1 DRILL WPRT P Short wiper,850'. Pu 31k off BTM. Start seeing fluids losses @ 10,030'-Drill tp 10070'.losses to 1.38 in.88 out. 07:00 07:30 0.50 9,220 10,070 PROD1 DRILL WPRT P RBIH 07:30 09:30 2.00 10,070 10,220 PROD1 DRILL DRLG P Drill ahead, 1.37 BPM @ 4116 psi, 3877 BHP. Losses healing up 1.37 in, 1.16 out. r 09:30 10:45 1.25 10,220 7,580 PROD1 DRILL WPRT P Pumped 5 x 5 sweep,Wiper to window. Log for a-2.5 correction. 10:45 12:00 1.25 7,580 10,220 PROD1 DRILL WPRT P RBIH to drill ahead. Page 7 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 10,220 10,370 PROD1 DRILL DRLG P Drill ahead, 1.38 BPM @ 4081 PSI, 3880 BHP, 14:00 14:45 0.75 10,370 9,220 PROD1 DRILL WPRT P Wiper,32k off BTM, 14:45 15:15 0.50 9,220 10,370 PROD1 DRILL WPRT P RBIH 15:15 17:45 2.50 10,370 10,520 PROD1 DRILL DRLG P Drill ahead, 1.35 BPM@ 4080 PSI 17:45 18:30 0.75 10,520 9,670 PROD1 DRILL WPRT P Wiper trip 850',32k puw 18:30 19:00 0.50 9,670 10,520 PROD1 DRILL WPRT P RBIH 19:00 21:00 2.00 10,520 10,670 PROD1 DRILL DRLG P Drill ahead 1.37 bpm in, 1.20 out, 4113 ctp, 146 whp,3954 bhp. **Decision made to plugback. Drilled into lower A2 silt/shale while trying to find A3 pay. Not giving hole problems, but no pay here either. 21:00 00:00 3.00 10,670 2,500 PROD1 DRILL TRIP T POOH for OH anchored billet to sidetrack 04/12/2013 RIH with OH anchored billet.Set w/single slip 185 deg TF, 9525 TOB. POOH, undeploy BHA 8. Deploy BHA 9(.7 AKO)RIH,tie in depth to K1 marker-7'correction,dry tag billet 9525'. Kick Off Billet for A lateral sidetrack @ 155 TF.Difficulty sliding to get started. 00:00 00:30 0.50 2,500 0 PROD1 DRILL TRIP T Cont POOH 00:30 00:45 0.25 0 0 PROD1 DRILL SFTY T At surface, PJSM 00:45 02:00 1.25 0 0 PROD1 DRILL PULD T Undeploy BHA 7 02:00 03:30 1.50 0 0 PROD1 STK PULD T Deploy BHA 8. (OH anchored Billet) 03:30 05:00 1.50 72 9,410 PROD1 STK TRIP T RIH 05:00 05:15 0.25 9,410 9,410 PROD1 STK DLOG T Tie in depth to K1 of-5. 05:15 06:45 1.50 9,410 9,525 PROD1 STK TRIP T RIH to 9536.78' 06:45 07:00 0.25 9,525 9,525 PROD1 STK ANCR T Pull up to neural weight.Top @ 9525'.double check TF& measurements. Pump down coil. shear Rir @ 4000 psi. Have 2.5 WOB after set. 07:00 09:15 2.25 9,525 67 PROD1 STK TRIP T POOH to surface. 09:15 09:30 0.25 0 0 PROD1 STK SFTY T Bumped up.Conduct undeploy PJSM. 09:30 10:30 1.00 0 0 PROD1 STK PULD T Begin PUD BHA#8 10:30 12:15 1.75 0 72 PROD1 STK PULD T PD BHA#9 12:15 14:00 1.75 72 7,430 PROD1 STK TRIP T RIH W/BHA, 14:00 14:07 0.13 7,430 7,430 PROD1 STK DLOG T Log for-7 Correction. 14:07 15:14 1.13 7,430 7,430 PROD1 STK TRIP T RIH 15:14 15:59 0.75 9,525 9,525 PROD1 STK KOST T Off line on pump,dry tag TOB @ 9525. Pick off,on line with pumps, start kicking off biller, have 2 hard stalls.Appers to be slip sticking. 15:59 17:59 2.00 9,525 9,525 PROD1 STK CIRC T Begin swapping mud.Take returns to the tiger tank,trucks on the way. PUH slowly while circulating. Page 8 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:59 18:29 0.50 9,525 9,525 PROD1 STK KOST T New mud around, RIH to start milling billet.Stall x 2.Slip sticking.Clean PU's 30-31 K. 18:29 19:59 1.50 9,525 9,525 PROD1 STK KOST T Shut down pumps,trap pressure. RIH dry tag billet. PU to string weight w/o pumps 31K.Online with pumps 1.5 bpm,4100 ctp, 184 ctp,Start RIH from 9522.4'.Stall x 5 at 9524.6'. 19:59 20:44 0.75 9,523 9,523 PROD1 STK KOST T Cont to RIH dry tagging, PU and start pumps to KO billet. Lower pump rate to 1.3,3856 ctp,3798 bhp,24k ctw. Let sit for 10 min. 20:44 21:59 1.25 9,523 9,524 PROD1 STK KOST T Start to RIH 1'/hour. at 9523.5,stop increase pump rate to attempt contact with billet. No change. 21:59 22:29 0.50 9,524 9,524 PROD1 STK KOST T Drop pump rate back to 1.36bpm, Cont RIH 1'/hour 22:29 22:59 0.50 9,524 9,524 PROD1 STK KOST T Stop let sit for 5 minutes.Increase rate to 1.45 then 1.5, 1.55.No indication of making contact. 22:59 23:14 0.25 9,524 9,524 PROD1 STK KOST T Orient 90 ROHS, RIH 1'/hour 23:14 23:44 0.50 9,524 9,524 PROD1 STK KOST T Stall PU,Online with pumps RBIH to 9524'.set autodriller ,1'/hr,90 ROHS 23:44 23:59 0.25 9,524 9,524 PROD1 STK KOST T Stall 9524.3'PU 31k,Online with pumps, RBIH to 9524.25'.Mix 4% lube pill.90 ROHS TF 04/13/2013 Kickoff anchored billet.Slip sticking,sliding issues during kickoff. Pump 4%Lube pills to get successfully kicked off billet. Drill A lateral performing 850'wiper trips,every third wiper back to window for depth correlation. 103brIs total losses for 24 hrs. 00:00 00:30 0.50 9,524 9,524 PROD1 STK KOST T Online with pumps, RBIH to 9524.25'.Mix 4%lube pill.90 ROHS TF 00:30 01:00 0.50 9,524 9,524 PROD1 STK KOST T 9524.3'.Stop RIH.5'/hr,pump 10brls 4%Lube pill 01:00 02:00 1.00 9,524 9,524 PROD1 STK KOST T Pick up.3'to prevent stall if sudden jump forward in pipe when pill exits bit. Pill out of CT. no sudden jump. Slowly RBIH in attempt to make contact with TOB. 10br1 lube pill out, send another 5brl pill.Cont RIH slowly 1'/hr. 5 brl lube pill out.Send another 5brl pill.9524.6'deepest we have been all night without stalling. 02:00 02:15 0.25 9,524 9,524 PROD1 STK KOST T 3rd 4%pill exiting CT.9524.9'.Cont RIH 1'/hr 02:15 02:30 0.25 9,524 9,524 PROD1 STK KOST T Stall. PU 30'. RBIH dry tag TOB 9524.65'. PU string weight.Online with pump attempt to KO billet RIH 4'/hr to 9524'. RIH without autodriller. Send another 4%lube pill 02:30 03:00 0.50 9,524 9,525 PROD1 STK KOST T Start to get motorwork 90 ROHS TF. Let mill off.Orient TF 155 ROHS. Cont.milling down 1'/hr auto driller. trying to get started 15 total stalls. Page 9 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:00 03:15 0.25 9,526 9,526 PROD1 STK KOST T 9526.6'Cont milling increase 2'/hr 1.44 bpm,4198 ctp,3810 bhp, 12.5k ctw,cont.pumping 5brl 4%lube pills in enable slide. large amounts of aluminum across shakers 03:15 03:45 0.50 9,526 9,526 PROD1 STK KOST T Loose prime. PU. RIH 03:45 04:00 0.25 9,526 9,527 PROD1 STK KOST T Cont.milling 2'/hr for 1' 04:00 04:15 0.25 9,527 9,528 PROD1 STK KOST T Increase to 3'/hr for 1' 04:15 04:45 0.50 9,528 9,532 PROD1 STK KOST T Increase to 10fph for 5' 04:45 06:45 2.00 9,532 9,670 PROD1 DRILL DRLG T Increase to 20fph, Drill ahead,. 1.44 bpm,4039 ctp,227 whp, 14k ctp, 3783 bhp, 06:45 07:30 0.75 9,670 8,800 PROD1 DRILL WPRT T 31k off BTM.Wiper 07:30 08:00 0.50 8,800 9,670 PROD1 DRILL WPRT T RBIH 08:00 10:00 2.00 9,670 9,820 PROD1 DRILL DRLG T Drill ahead 1.39 BPM @ 4127 PSI, 3785 BHP, 10:00 10:45 0.75 9,820 8,670 PROD1 DRILL WPRT T 30k,wiper up 1150' 10:45 11:15 0.50 8,670 9,820 PROD1 DRILL WPRT T RBIH 11:15 13:15 2.00 9,820 9,970 PROD1 DRILL DRLG T Drill ahead, 1.34 BPM @ 4080 psi, 3818 BHP, 13:15 14:30 1.25 9,970 7,575 PROD1 DRILL WPRT T Pick-up wt 33k;Wiper to window with tie in.A correction of-.05 14:30 15:45 1.25 7,575 9,970 PROD1 DRILL WPRT T RBIH 15:45 17:30 1.75 9,970 10,120 PROD1 DRILL DRLG T Drill ahead 1.34 BPM @ 3800 psi, 3808 BHP, 17:30 18:00 0.50 10,120 9,217 PROD1 DRILL WPRT T Wiper trip 900',30k puw 18:00 18:45 0.75 9,217 10,120 PROD1 DRILL WPRT T RBIH 18:45 20:45 2.00 10,120 10,270 PROD1 DRILL DRLG T Drill Ahead 1.37 bpm, 1.25 out 4151 ctp,221 whp,3850 bhp, 11k ctw 20:45 21:30 0.75 10,270 9,420 PROD1 DRILL WPRT T Wiper trip 850'30k puw, Blow back Choke B. 21:30 22:15 0.75 9,420 10,270 PROD1 DRILL WPRT T RBIH 22:15 00:00 1.75 10,270 10,411 PROD1 DRILL DRLG T Drill Ahead 1.38 bpm, 1.23 out,4098 ctp,200 whp,3900 bhp, 10k ctw 04/14/2013 Drill A lateral to TD 10894'. POOH to swab valves. 00:00 00:15 0.25 10,411 10,420 PROD1 DRILL DRLG T Cont.drilling 1.38 bpm, 1.23 out, 4098 ctp,200 whp,3900 bhp, 10k ctw 00:15 01:45 1.50 10,420 7,556 PROD1 DRILL WPRT T Wiper trip back to window 30K puw. Reduce pump rate to minimum rate 7900-7980 area. Log RA marker for depth correlation.-4'correction 01:45 03:15 1.50 7,556 10,420 PROD1 DRILL WPRT T RBIH 03:15 05:30 2.25 10,420 10,570 PROD1 DRILL DRLG T Drill ahead 1.38 bpm in, 1.26 out, 4380 ctp, 194 whp,8k ctw,3860 bhp, Increase lubes in active system half percent low torq&776,total 3% lubes Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 10,570 9,699 PROD1 DRILL WPRT T Wiper,30.5 k off btm.850'wiper. 06:00 06:30 0.50 9,699 10,570 PROD1 DRILL WPRT T RBIH 06:30 07:45 1.25 10,570 10,670 PROD1 DRILL DRLG T Drill ahead 1.35 BPM @ 4250 psi, 3875 BHP, 07:45 08:15 0.50 10,670 10,720 PROD1 DRILL DRLG P Off of Trouble time, 10,670'reached again. Drill ahead. 08:15 08:52 0.63 10,720 9,867 PROD1 DRILL WPRT P wiper,31k off btm. 08:52 09:22 0.50 9,867 10,720 PROD1 DRILL WPRT P RBIH 09:22 11:59 2.62 10,720 10,870 PROD1 DRILL DRLG P Drill ahead 11:59 13:29 1.50 10,870 7,575 PROD1 DRILL WPRT P Wiper to window,32k off BTM. 13:29 13:44 0.25 7,575 7,596 PROD1 DRILL DLOG P Log GR, tie in for-8' 13:44 14:59 1.25 7,596 10,870 PROD1 DRILL WPRT P RBIH 14:59 17:14 2.25 10,870 10,984 PROD1 DRILL DRLG P Drill ahead 1.31 BPM,3947 BHP. Drill to 10984'.TD called.Get sweeps going down the coil. 17:14 17:44 0.50 10,984 10,500 PROD1 DRILL WPRT P Wipe up hole slowly to get sweep to bit.Wiper to the swabs. 17:44 21:29 3.75 10,500 0 PROD1 DRILL TRIP P POOH to swab valves. Large increase of cuttings&aluminum at 1500' 21:29 22:29 1.00 0 0 PROD1 DRILL SVRG P Clean counter and inspect. 22:29 23:59 1.50 0 7,410 PROD1 DRILL TRIP P RBIH 04/15/2013 Complete wiper trip to swab valves. Lay in 12ppg NaBr completion fluid with beads to TOC.Without beads to surface. PU/MU/RIH A liner in two segments. First segment release on bottom 10893,TOL 9473'.Second segment released on depth. BOL 9474,TOL 7680'. 00:00 00:15 0.25 7,410 7,410 PROD1 DRILL DLOG P Tie in depth to K1 marker-9' correction 00:15 02:15 2.00 7,410 10,983 PROD1 DRILL TRIP P RIH to TD.Tag at 10983'. 02:15 06:00 3.75 10,983 0 PROD1 DRILL TRIP P POOH laying in 12ppg NaBr completion fluid with beads to TOC. Displace well to 12ppg NaBr without beads to surface. 06:00 06:30 0.50 0 0 PROD1 DRILL SFTY P No flow check. PJSM on Lay down of drilling BHA. 06:30 07:15 0.75 0 0 PROD1 DRILL PULD P LD BHA#9 07:15 07:30 0.25 0 0 COMPZ CASING SFTY P PJSM for liner pick up. 07:30 10:00 2.50 0 1,553 COMPZ CASING PUTB P Pick-up/make up liner&BHA 10:00 12:30 2.50 1,553 10,983 COMPZ CASING RUNL P RIH W/A Lateral liner segment#1, note flag depths, looks good.Set on BTM @ 10983'.Get pick up wt of 40k.Set liner back on BTM,pump off.34k pick-up. Re-set counter, pump over the top to keep beads in place. 12:30 15:30 3.00 10,983 45 COMPZ CASING TRIP P TOOH,tie in for a-2.5'correction, Paint,plag @ 5643'continue POOH to surface. 15:30 15:45 0.25 45 45 COMPZ CASING SFTY P Conduct PJSM.Watch for no flow. Page 11 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:45 16:15 0.50 45 0 COMPZ CASING PULD P Lay down BHA#10. 16:15 17:45 1.50 0 0 COMPZ CASING PUTB P Pick-up A lateral segment#2 17:45 18:00 0.25 0 0 COMPZ CASING SFTY P PU safety joint with TIW.Crew change. PJSM 18:00 19:15 1.25 0 0 COMPZ CASING PUTB P Cont. PU/MU Liner 19:15 21:45 2.50 1,838 9,474 COMPZ CASING RUNL P RIH Liner segment#2.depth correction EOP flag-7'correction. Record up weight,33k puw ctw,-5k wob 21:45 00:00 2.25 9,474 0 COMPZ CASING RUNL P Tag TOL#1 at 9474', Release Liner #2, 1.2 bpm,4000psi ctp,34k puw, Ok wob. POOH,at window remove liner length from BHA 04/16/2013 Perform BOPE test, P/U 0.9°motor and RR Hughes bi-center bit. Ran in hole. 00:00 00:15 0.25 0 0 COMPZ CASING RUNL P At surface,Monitor well for flow. PJSM 00:15 01:00 0.75 0 0 COMPZ CASING PULD P LD BHA 01:00 02:00 1.00 0 0 PROD2 STK BOPE P Set two way check in tree for BOPE test 02:00 03:00 1.00 0 0 PROD2 STK CIRC P Displace reel with water and Flush stack 03:00 04:00 1.00 0 0 PROD2 STK BOPE P Grease stack,and rig valves 04:00 11:30 7.50 0 0 PROD2 STK BOPE P Start BOPE testing.Waived by State Inspector: Lou Grimaldi 11:30 14:00 2.50 0 0 PROD2 STK BOPE P BOPE test complete.RD test equip. swap CT back to 12.0 completion fluid. Rig up FMC W/lubicator to remove 2 way check. 14:00 15:30 1.50 0 0 PROD2 STK PULD P PU/MU BHA 12. (.9 AKO w/ Bi-Center RR) 15:30 17:00 1.50 72 7,410 PROD2 STK TRIP P RIH 17:00 17:15 0.25 7,410 7,410 PROD2 STK DLOG P Tie in depth to K1 marker-9' correction 17:15 18:15 1.00 7,410 7,410 PROD2 STK CIRC P Swap well back to drilling mud 18:15 18:45 0.50 7,410 7,676 PROD2 STK KOST P Dry Tag billet at 7677.2'. PUH, pump up at 4000psi, and work down to top of billet. BHP 3653,WHP 63, IA 0, OA 21. 18:45 19:15 0.50 7,676 7,677 PROD2 STK KOST P Time drilling billet at lfph 19:15 19:45 0.50 7,677 7,678 PROD2 STK KOST P Time drilling billet at 2 fph. 19:45 20:00 0.25 7,678 7,679 PROD2 STK KOST P Time drilling billet at 3fph 20:00 20:30 0.50 7,679 7,700 PROD2 DRILL DRLG P Start pushing on it now.drilling ahead. 20:30 20:45 0.25 7,700 7,680 PROD2 DRILL WPRT P PUH and dry drift billet area. 20:45 21:00 0.25 7,680 7,700 PROD2 DRILL WPRT P Run back in hole RIW 14k Page 12of18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 7,700 7,830 PROD2 DRILL DRLG P BOBD 1.4bpm at 4000psi. BHP 3670,WHP 63, IA 0,OA 21 23:00 00:00 1.00 7,830 7,355 PROD2 DRILL WPRT P Wiper up hole. PUW 32k. Pull up above cement top and circulate bottoms up. 04/17/2013 Kicked off of billet at 7676', Drilled Ahead in AL1 lateral as per plan. 00:00 01:00 1.00 7,355 7,830 PROD2 DRILL WPRT P Close EDC,Wiper back in hole. RIW 15k 01:00 02:45 1.75 7,830 7,980 PROD2 DRILL DRLG P BOBD-1.39bpm at 4000psi. BHP 3669,WHP 57, IA 0,OA 21. 02:45 03:15 0.50 7,980 7,700 PROD2 DRILL WPRT P Wiper up hole to 7700ft. PUW 32k 03:15 03:45 0.50 7,700 7,980 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k 03:45 04:45 1.00 7,980 8,130 PROD2 DRILL DRLG P BOBD-1.39bpm at 4000psi, BHP 3702,WHP 18, IA 2,OA 23 04:45 05:15 0.50 8,130 7,580 PROD2 DRILL WPRT P Wiper up hole. PUW 32k 05:15 05:30 0.25 7,580 7,598 PROD2 DRILL DLOG P Tie into RA marker correction of- 1.5k 05:30 06:00 0.50 7,598 8,130 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k 06:00 06:45 0.75 8,130 8,280 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm,4245 ctp, 14k ctw,3675 bhp 06:45 07:15 0.50 8,280 7,700 PROD2 DRILL WPRT P Wiper trip back to 7700',31k puw#1 07:15 07:45 0.50 7,700 8,280 PROD2 DRILL WPRT P RBIH 07:45 09:00 1.25 8,280 8,430 PROD2 DRILL DRLG P Drill ahead 1.4 bpm,4265 ctp, 13k ctw,3705 bhp Swap out mud system 09:00 09:30 0.50 8,430 7,695 PROD2 DRILL WPRT P Wiper trip back to 7695.32k puw#2 09:30 10:00 0.50 7,695 8,430 PROD2 DRILL WPRT P RBIH 10:00 11:00 1.00 8,430 8,580 PROD2 DRILL DRLG P Drill ahead 1.4 bpm.4150 ctp, 15k ctw,230 whp,3700 bhp 11:00 11:24 0.40 8,580 7,550 PROD2 DRILL WPRT P Wiper trip back to window,30k puw #3 11:24 11:36 0.20 7,550 7,550 PROD2 DRILL DLOG P Log RA marker for depth correlation. -4.5'correction 11:36 12:00 0.40 7,550 8,580 PROD2 DRILL WPRT P RBIH 12:00 13:00 1.00 8,580 8,730 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm,4030 ctp, 160 whp,3745 bhp, 13:00 13:21 0.35 8,730 7,880 PROD2 DRILL WPRT P Wiper trip 850',32k puw#1 13:21 13:42 0.35 7,880 8,730 PROD2 DRILL WPRT P RBIH 13:42 14:45 1.05 8,730 8,880 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm,4000 ctp, 3750 bhp, 160 whp 14:45 15:06 0.35 8,880 8,030 PROD2 DRILL WPRT P Wiper trip back 850',#2 15:06 15:28 0.38 8,030 8,880 PROD2 DRILL WPRT P RBIH 15:28 16:58 1.50 8,880 9,030 PROD2 DRILL DRLG P Drill Ahead 1.44 bpm,4220 ctp, 165 whp,3730 bhp, 12k ctw 16:58 17:28 0.50 9,030 7,550 PROD2 DRILL WPRT P Wiper trip to window 17:28 17:43 0.25 7,550 7,558 PROD2 DRILL DLOG P Tie into RA marker, -6' Page 13 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:43 18:13 0.50 7,558 9,030 PROD2 DRILL WPRT P Wiper back in hole RIW 14k 18:13 19:44 1.52 9,030 9,180 PROD2 DRILL DRLG P BOBD-1.41bpm at4000psi. BHP 3768,WHP 230, IA 97,OA 24 19:44 20:29 0.75 9,180 7,700 PROD2 DRILL WPRT P Wiper up hole. PUW 29k 20:29 20:59 0.50 7,700 9,180 PROD2 DRILL WPRT P Wiper back in hole.RIW 15k 20:59 22:59 2.00 9,180 9,330 PROD2 DRILL DRLG P BOBD-1.42bpm at 3846psi, BHP 3765,WHP 220, IA 107,OA 24, CTSW 13k 22:59 23:59 1.00 9,330 7,700 PROD2 DRILL WPRT P Wiper up hole. PUW 36k 04/18/2013 Drilled AU to TD.Performed wiper to the swab valves. RBIH and confirmed TD 9444'. POOH and M/U 45 jts of slotted liner. 00:00 00:45 0.75 7,700 9,330 PROD2 DRILL WPRT P Wiper in hole RIW 15k 00:45 02:45 2.00 9,330 9,450 PROD2 DRILL DRLG P BOBD-1.40bpm at 3841psi. BHP 3802,WHP 251, IA 141,OA 24, CTSW 14k 02:45 06:00 3.25 9,450 0 PROD2 DRILL WPRT P Pump 10x10 high/low sweep. Perform wiper to the swab valves. 06:00 06:15 0.25 0 0 PROD2 DRILL SVRG P At surface,Clean counter. 06:15 08:00 1.75 0 7,410 PROD2 DRILL WPRT P RBIH 08:00 08:15 0.25 7,410 7,410 PROD2 DRILL DLOG P Tie in depth to RA marker-905' correction 08:15 09:00 0.75 7,410 9,444 PROD2 DRILL WPRT P RIH to TD 09:00 12:00 3.00 9,444 0 PROD2 DRILL TRIP P Tag 9444'. POOH laying 12ppg NABr completion fluid with beads to TOC.Cont. POOH laying in completion fluid without beads to surface killing well. Paint EOP flag 6071.75' 12:00 12:15 0.25 0 0 PROD2 DRILL OWFF P At surface, monitor well for flow. PJSM 12:15 13:15 1.00 0 0 PROD2 DRILL PULD P LD BHA 13:15 13:45 0.50 0 0 COMPZ CASING SVRG P Prepare floor to PU liner,service tongs. 13:45 14:00 0.25 0 0 COMPZ CASING SFTY P PJSM 14:00 16:45 2.75 0 1,491 COMPZ CASING PUTB P PU/MU 45 jnts 2 3/8"Slotted Liner, OHanchored billet, Coil track 16:45 18:45 2.00 1,491 7,491 COMPZ CASING RUNL P RIH,with EDC open,circ.minimum rate 18:45 19:00 0.25 7,491 7,491 COMPZ CASING DLOG P Correct to EOP flag correction of-5'. 19:00 19:45 0.75 7,491 8,840 COMPZ CASING RUNL P Continue RIH w/AL1 completion. 19:45 20:00 0.25 8,840 8,869 COMPZ CASING DLOG P Tie into the K1 correction of-3' 20:00 20:15 0.25 8,869 9,444 COMPZ CASING RUNL P Continue RIH Page 14 of 18 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 20:15 20:30 0.25 9,444 9,444 COMPZ CASING RUNL P Tag bottom at 9444'. PUW 35k.Set back down on bottom. Pressure up to 3450psi. Lost weight,set down 1k,PUW32k TOL-8013.6' BOL-9444' 20:30 22:00 1.50 9,444 0 COMPZ CASING TRIP P POOH 22:00 22:30 0.50 0 0 COMPZ CASING SFTY P Conduct PJSM-UD liner running BHA,Check well for flow 22:30 23:30 1.00 0 0 COMPZ CASING TRIP P UD AL1 liner BHA 23:30 00:00 0.50 0 0 PROD3 STK SVRG P Service INJH,M/U AL2 kick off BHA. 04/19/2013 Set AL1 slotted liner completion on bottom 9444'.TOL 8013'. POOH,M/U, RIH with drilling bha. 1°ako motor and RR hycalog bi-center bit. KO anchored billet with 180 TF at 8013'. Drill AL2 lateral to 8320'. During wiper trip Coiled Tubing pinholed at 8010'. POOH. Rig down Coiled Tubing spool. 00:00 02:00 2.00 0 7,400 PROD3 STK TRIP P RIH w/AL2 kick off BHA.w/1°ako motor 02:00 03:30 1.50 7,400 7,430 PROD3 STK CIRC P Displace well to 9.5ppf Flo-pro. 03:30 03:45 0.25 7,430 7,461 PROD3 STK DLOG P Tie into the K1 correction of-9' 03:45 04:00 0.25 7,461 8,013 PROD3 STK TRIP P Continue in hole to billet. 04:00 04:15 0.25 8,013 8,013 PROD3 STK KOST P Dry tag billet at 8013.6', PUW 31, Pump up at 4000psi,work down to top of billet. 04:15 06:30 2.25 8,013 8,060 PROD3 STK KOST P Start time milling. 1.40bpm at 3970psi. BHP 3699,WHP 142, IA 0, OA 24 06:30 06:45 0.25 8,060 8,060 PROD3 STK WPRT P PU Drift Billet. Drift good RBIH 06:45 08:15 1.50 8,060 8,170 PROD3 DRILL DRLG P Drill ahead 1.5 bpm,4280 ctp,3700 bhp, 14k ctw 08:15 08:30 0.25 8,170 7,700 PROD3 DRILL WPRT P Wiper trip back to 7700'.29k 08:30 08:45 0.25 7,700 8,170 PROD3 DRILL TRIP P RBIH 08:45 10:45 2.00 8,170 8,320 PROD3 DRILL DRLG P Drill ahead 1.5 bpm,4280 ctp,3700 bhp, 14k ctw 10:45 11:00 0.25 8,320 7,400 PROD3 DRILL TRIP T Pinhole in Coiled Tubing.Offline with pumps.Circulate down backside, PUH to TOC.Assure DH checkvalves are holding 11:00 13:45 2.75 7,400 0 PROD3 DRILL TRIP T POOH 13:45 14:00 0.25 0 0 PROD3 DRILL SFTY T At surface PJSM 14:00 15:30 1.50 0 0 PROD3 DRILL PULD T Undeploy BHA 15:30 16:00 0.50 0 0 PROD3 DRILL PULD T LD Tools 16:00 16:45 0.75 0 0 PROD3 DRILL CIRC T MU Nozzle and stab back onto well. Flush CT with water. 16:45 18:00 1.25 0 0 PROD3 DRILL CTOP T RU N2 unit, PJSM 18:00 18:15 0.25 0 0 PROD3 DRILL SFTY T Crew Change-Conduct PSJM with SLB N2 and start cool down. 18:15 19:15 1.00 0 0 PROD3 DRILL CTOP T R/U, P/T,and pump N2 Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:45 1.50 0 0 PROD3 DRILL CTOP T Pump 1500scf for 20 mins, Shutdown N2. Rig up to bleed down coil and surface lines. 20:45 00:00 3.25 0 0 PROD3 DRILL CTOP T Conduct PSJM-Unstab coil and secure to reel spool. 04/20/2013 Swap out Coiled Tubing spools. PU/MU/RIH drilling BHA 1 deg AKO, RR Bi-Center. Drill AL2 lateral. 00:00 00:30 0.50 0 0 PROD3 DRILL CTOP T Remove inner reel iron and continue to secure coil to reel spool. 00:30 02:30 2.00 0 0 PROD3 DRILL CTOP T Conduct PJSM-Switch out reels, New reel in house 02:30 05:30 3.00 0 0 PROD3 DRILL CTOP T Conduct PJSM-Swap out brass in pac-off.SIMOPS with shimming up and tightening reel hubs. 05:30 06:00 0.50 0 0 PROD3 DRILL SFTY T Crew change, PJSM 06:00 08:30 2.50 0 0 PROD3 DRILL CTOP T RU and Stab CT into injector head, and RD stabbing equipment. 08:30 09:30 1.00 0 0 PROD3 DRILL CTOP T RU,prepare tools and position reel, to make up Inner reel Iron,pressure bulk head,CTC and BHI drilling head 09:30 11:30 2.00 0 0 PROD3 DRILL CTOP T MU Inner reel iron&CTC. 11:30 13:30 2.00 0 0 PROD3 DRILL CTOP T MU pressure bulk head 13:30 16:30 3.00 0 0 PROD3 DRILL CIRC T Change packoffs,Circulate 5brl methynol spear ahead of 150deg seawater,warming up CT,pressure test,inner reel iron,pressure bulk head,stripper and CTC. Displace reel to drilling mud 16:30 18:00 1.50 0 0 PROD3 DRILL PULD T Deploy BHA 18:00 18:30 0.50 0 0 PROD3 DRILL SFTY T Crew change, PJSM 18:30 20:00 1.50 0 0 PROD3 DRILL PULD T Cont deploying BHA 20:00 22:00 2.00 70 7,410 PROD3 DRILL TRIP T RIH 22:00 22:15 0.25 7,410 7,410 PROD3 DRILL DLOG T Tie in depth-5'correction 22:15 22:30 0.25 7,410 7,410 PROD3 DRILL SVRG T Check reel and saddle bolts 22:30 23:00 0.50 7,410 8,264 PROD3 DRILL TRIP T RIH tag 8264', PU 30k 23:00 00:00 1.00 8,264 8,313 PROD3 DRILL WPRT T Pumping 0.80bpm work pipe down to 8013'. PUW 42k, Plugging off annular.Wiper up hole. 04/21/2013 Problems getting to bottom, Perform wiper to swab.Work pipe to bottom Drill Ahead from 8320 to 9070' 00:00 00:15 0.25 8,313 8,000 PROD3 DRILL WPRT T Wiper up hole to 8000'.Annular showing packing off. Pull up into casing and circulate no sign of shale in returns. 00:15 02:00 1.75 8,000 72 PROD3 DRILL TRIP T Pull to surface to clean hole. Plugging off choke,perform jog close to surface to unload shale.Take pictures of shale. 02:00 04:30 2.50 72 72 PROD3 DRILL TRIP T At surface,flush choke and surface lines. 04:30 07:30 3.00 72 7,430 PROD3 DRILL TRIP T Reset counters and RBIH to bottom. Page 16 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:30 07:45 0.25 7,430 7,453 PROD3 DRILL DLOG T Tie into K1 correction of-6'. 07:45 08:30 0.75 7,453 8,250 PROD3 DRILL TRIP T Tagged high at 8250'work coil to bottom at min rate 0.80bpm.Bring pump up to full rate to wiper up hole. 08:30 09:00 0.50 8,250 8,320 PROD3 DRILL TRIP T Continue working pipe to bottom min rate. Bring pump to full rate to wiper up hole. 09:00 11:00 2.00 8,320 8,470 PROD3 DRILL DRLG P OBD-1.41bpm at 3850psi,BHP 3822,WHP 182, IA 0,OA 57,CSW 12k 11:00 11:45 0.75 8,470 7,700 PROD3 DRILL WPRT P Wiper up hole. PUW 30k 11:45 12:30 0.75 7,700 8,470 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 12:30 15:00 2.50 8,470 8,620 PROD3 DRILL DRLG P BOBD-1.41bpm at 3950psi, BHP 3726,WHP 133, IA 0,OA 61.CSW 11k 15:00 15:45 0.75 8,620 7,700 PROD3 DRILL WPRT P Wiper up hole. PUW 30k 15:45 16:30 0.75 7,700 8,620 PROD3 DRILL WPRT P Wiper back in hole. RIW 15k 16:30 17:54 1.40 8,620 8,770 PROD3 DRILL DRLG P BOBD-1.40bpm at 3950psi. BHP 3755,WHP 124, IA 9,OA 61, CSW 11k 17:54 19:24 1.50 8,770 8,770 PROD3 DRILL WPRT P Wiper trip to window with tie in for -6.5', PUW=34K 19:24 20:24 1.00 8,770 8,867 PROD3 DRILL DRLG P 8770', Drill ahead, 1.4 BPM @ 3780 PSI FS, BHP=3780 20:24 21:00 0.60 8,867 8,920 PROD3 DRILL DRLG P New mud at Bit,Old system 2050'@ .8%Drill solids 21:00 21:54 0.90 8,920 8,920 PROD3 DRILL WPRT P Wiper to 8025, PUW=33K,Clean trip in and out 21:54 23:03 1.15 8,920 9,070 PROD3 DRILL DRLG P 8920', Drill Ahead, 1.4 BPM @ 3770 PSI FS, BHP=3738 23:03 00:00 0.95 9,070 8,900 PROD3 DRILL WPRT P Wiper to 8035', PUW=31K 04/22/2013 TD AL2 Lateral @ 9446'corrected, Wiper to swab,condition hole,M/U liner,trip in hole 00:00 00:12 0.20 8,900 9,073 PROD3 DRILL WPRT P Continue wiper from 9070' 00:12 01:30 1.30 9,073 9,225 PROD3 DRILL DRLG P 9073', Drill ahead, 1.4 BPM @ 3575 PSI FS, RIW=15K, BHP=3715 01:30 03:24 1.90 9,225 9,225 PROD3 DRILL WPRT P Wiper to window with tie in, PUW=31 K,Correct-8' 03:24 05:00 1.60 9,225 9,375 PROD3 DRILL DRLG P 9223', Drill Ahead, 1.4 BPM @ 3525 PSI FS, BHP=3760 05:00 05:45 0.75 9,375 8,025 PROD3 DRILL WPRT P Wiper to 8025;, PUW=31K 05:45 06:30 0.75 8,025 9,375 PROD3 DRILL WPRT P Wiper back in hole. RIW 15k 06:30 07:30 1.00 9,375 9,450 PROD3 DRILL DRLG P BOBD-1.43bpm at 3642psi,BHP 4267,WHP 124, IA 40,OA 65 07:30 08:00 0.50 9,450 8,718 PROD3 DRILL WPRT P 9450'TD reached, Perform town wiper up to 8718ft 08:00 08:45 0.75 8,718 9,450 PROD3 DRILL WPRT P Wiper back in hole. RIW 15k 08:45 12:00 3.25 9,450 72 PROD3 DRILL TRIP P Pump 10x10 sweep and perform swab wiper. 12:00 12:30 0.50 72 72 PROD3 DRILL SVRG P Surface conduct PJSM,check inner reel iron, Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:30 2.00 72 7,430 PROD3 DRILL TRIP P RBIH 14:30 14:45 0.25 7,430 7,453 PROD3 DRILL DLOG P Tie into the K1 correction of-4.5ft. 14:45 16:00 1.25 7,453 9,446 PROD3 DRILL TRIP P Continue trip to bottom. 16:00 18:42 2.70 9,446 106 PROD3 DRILL TRIP P Tag bottom at 9446ft. PUW 32k, POOH laying in completion fluid with alpine beads up to TOC., Paint EOP flags @ 7300'and 5400' 18:42 19:42 1.00 106 0 PROD3 DRILL PULD P PJSM,Flow check well, Lay down BHA#15 19:42 20:30 0.80 0 0 COMPZ CASING PUTB P Prep floor to run liner/inspect tourque reel hub bolts and saddle clamp bolts, inspect top drive 20:30 23:06 2.60 0 2,011 COMPZ CASING PUTB P P/U BHA#16, Non ported bullnose, 59 Jts slotted liner,5 jts H-511 bank liner 23:06 23:42 0.60 2,011 2,059 COMPZ CASING PULD P All liner in well,M/U coiltrack to liner, M/U coiltrack to coil and surface test tool. 23:42 00:00 0.30 5,059 2,750 COMPZ CASING RUNL P Trip in hole with AL2 Liner 2,750 2,750 COMPZ CASING RUNL P Midnight depth 04/23/2013 Set AL2 Liner, Freeze Protect well,Set BPV, Release rig @ 15:00 00:00 01:06 1.10 2,750 7,458 COMPZ CASING RUNL P Trip in well 01:06 01:12 0.10 7,458 7,548 COMPZ CASING DLOG P Tie into 5400'EOP flag for+9' correction 01:12 01:54 0.70 7,548 9,410 COMPZ CASING RUNL P Continue in hole 01:54 02:06 0.20 9,410 9,448 COMPZ CASING DLOG P Went past lower flag looked like-6', Hole conditions will allow tie in,Log tie in for-12'correction 02:06 02:18 0.20 9,448 7,404 COMPZ CASING RUNL P Trip in and tag up @ 9446.0, PUW=39K,-9K DHWOB, set back down,pumps on and release from liner, PUW=31 K, DHWOB=-3K, Remove liner length from counters, TOL=7431, BOL=9446 02:18 03:30 1.20 7,404 7,404 COMPZ CASING DISP P Online with seawater recovering completion fluid 03:30 04:18 0.80 7,404 3,400 COMPZ CASING TRIP P Trip out of well 04:18 05:42 1.40 3,400 2,650 COMPZ CASING FRZP P Goto diesel freeze protect 05:42 05:57 0.25 2,650 0 COMPZ CASING PULD P At surface Conduct PJSM-Undeploy liner running BHA. 05:57 06:12 0.25 0 0 COMPZ CASING SFTY P Crew change-Conduct PJSM with day crew for undeploying 06:12 08:27 2.25 0 0 COMPZ CASING PULD P Undeploy BHA 08:27 09:27 1.00 0 0 DEMOB WHDBO NUND P Flush Stack and surface lines 09:27 11:15 1.80 0 0 DEMOB WHDBO NUND P Conduct PJSM w/FMC-prep to set BPV. 11:15 15:00 3.75 0 0 DEMOB WHDBO NUND P PJSM-RDMO XXX ----Rig Release 3 PM---------- XXX Page 18 of 18 ! 0 cr . / 1 J i ......._—___. 1 ) S '0 „we ______/ mil n‘ 1 en r( c, :ji.. 1 ci ca o cn , 4 C3 (1) IA ozi OA i cts W OC .— Q Z >+ C Z •- C ■ - - '— "E - U) U a = co = aD 0 0 > a' M I(2 .w 1c7i M O r O c L L a M -Y `= .Q U 0 aao ° V N Li Co G m 0 a N 4 , k.. w ►1 sex o m eil V o o r co M 07 O W O C M T r E c0i /0 O O 0 f� d Q N N 0 ,0 W ca O 6 co C W y c 7 Q v W C) LL 0. 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N. 1� m (O W O O 03 O A ti, O c T a ... co- m N co- CO a0 m CCi a0 ao m m m co- ao m CA Cn O) O) D) O) O) D) of co- D) O) D) o) W Eii s 0) 2 V .. _ I o a` in 3 3 0 co v Letter of Transmittal FARO v� � 3 RECEIVE BAKER Date: HUGHES April 26, 2013 o /_ APR 2 y 2013 �/ AOGCC To: • From: • Christine Mahnken Carl Ulrich/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2T-03A oZ 13 • © � ! 2T-03AL1 �t 3 ' Cr/ 0 2T-03AL2 a(3 . d 1-1' 2T-03APB1 1 ( 3 - 0� (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager / Carl.Ulrich @BakerHughes.com \ � THE STATE Alaska Oil and Gas ALASKA -� _ �,;_ Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Lamar Gantt CTU Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-03AL1 ConocoPhillips Alaska, Inc. Permit No: 213-040 Surface Location: 377' FSL, 556' FWL, SEC. 1, T11N, R8E, UM Bottomhole Location: 555' FSL, 1447' FEL, SEC. 35, T12N, R8E, 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 2T-03A, Permit No 213-039, API 50-103-20073-01-00. 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, Cathy P Foerster Chair DATED this/9r day of March, 2013. . .. REC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 `'✓ 2 i I D PERMIT TO DRILL O 20 AAC 25.005 ' '°`" 1a.Type of Work: lb.Proposed Well Class: Development-Oil IN► Service-Winj ❑ Single Zone 11, 1c.Specify if well is proposed for: Drill ❑ 'Lateral El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2T-03AL1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9450'- TVDSS: 5711'' Kuparuk River Field 1 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:377'FSL,556'FWL,Sec. 1,T11 N,R8E, UM• ADL 25569,25548 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1087'FNL, 1452'FEL,Sec.2,T11 N,R8E,UM 2667,2662 4/5/2013 Total Depth: 9.Acres in Property: 1116 14.Distance to 555'FSL, 1447'FEL,Sec.35,T12N, R8E,UM 2,60 .S1 Zo 31Iw1i3 Nearest Property: 8910 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: II 71 -62.feet 15.Distance to Nearest Well Open Surface:x- 498945 y- 5970357 Zone- 4• GL Elevation above MSL: i?134 feet P/ca 911511ci3 to Same Pool: 2T-27,720' 16.Deviated wells: Kickoff depth: . 7750 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 103° deg Downhole:4730 psig. Surface:4150 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS ' (including stage data) 3" 2.375" 4.7# L-80 ST-L 1780' 7670' 5740' 9450' 5711' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 7897' 6067' none 7809' 5999' none Casing Length Size Cement Volume MD TVD Conductor/Structural 83' 16" 234 sx CS II 115' 115' Surface 3142' 9.625" 800 sx AS III,350 sx CI G 3174' 2787' Intermediate Production 7863' 7" 640 sx Class G,300 sx AS I 7893' 6064' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7520'-7561', 7592'-7607' 5782'-5813', 5836'-5846' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Prograrr Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program II 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: "21,(8(�3 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 V.-- Email J.Garv.Eller @conocodhillip .com Printed Name Lamar Gantt Title CTU Engineering Supervisor r: Signature r"7iA,'11,uL\ 3f',j Phone:265-6120 Date */j j I Commission Use Only f Permit to Drill API Number: Permit Approval See cover letter Number: c2 13 0 tip 50-'o3-el00i3 -'(0,0 -0 O Date: �� / 0 Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: El Other: Samples req'd: Yes ❑ No Z Mud log req'd: Yes❑ No A 13 p j---Y.5 f f6 4. �e (r /.,S '- H2S measures: Yes No ❑ Directional svy req'd: Yes[ No❑ Spacing exception req'd: Yes ❑ No 2 Inclination-only svy req'd: Yes❑ No Z p�'�p'`, APPROVED BY THE Approved by. COM t Ri t I p,comMissioN Date:. — I — Form 10-401 (Re sed 10/2012) This permit is vaari2ikrt`ortth3 horn the date of approval(20 AAC 25.005(9)) J��j VL/ 3/Jyle3 \`� RECEIVED MAR 0 8 2013 Conoco Phillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 6, 2013 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD)applications to drill and complete 2T-03A, 2T-03AL1, and 2T-03AL2 from Kuparuk well 2T-03 (PTD# 186-142). CTD operations are scheduled to begin April 5, 2013 using the Nabors CDR2-AC rig. The objective of the CTD sidetrack is to improve Kuparuk A-Sand sweep efficiency and oil recovery within the target pattern. A 10-403 was submitted on March 4 to place a cement plug in the 7"casing of well 2T-03 to facilitate a casing exit for these laterals, which will likewise effectively plug the perfs in well 2T-03. That sundry application also requested that a variance from the plugging requirements of 20 AAC 25.112 (c) be granted to facilitate the casing exit of the 2T-03 horizontal laterals. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 2T-03A, 2T-03AL1, &2T-03AL2 — Directional plans for 2T-03A, 2T-03AL1, &2T-03AL2 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-263-4172. Sin•\`ly, J. a* Eller Co •c••hillips Alaska Coile. I bing Drilling Engineer Kuparuk CTD Sidetrack Drilling &Wells 2T-03A, AL1, & AL2 Drilling Program Summary 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 5 Pressure Deployment of BHA 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 Attachment 1: Directional Plans for 2T-03A,2T-03AL1,&2T-03AL2 6 Attachment 2: Current Well Schematic for 2T-03 6 Attachment 3: Proposed Well Schematic for 21-03 CTD Sidetrack 6 Page 1 of 6 ? y March 6,2013 i d a PTD Applicatior. .or. KRU 2T-03A, AL1, &AL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) KRU 2T-03A, 2T-03AL1, and 2T-03AL2 are proposed CTD horizontal laterals from the 2T-03 motherbore. They both will be classified as"Development- Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 2T-03 laterals will target the A3 and A2 sands in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2T-03A sidetrack and the 2T-03AL1 and 2T-03AL2 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4700 psi. Using a maximum potential formation pressure of 4730 psi, the maximum potential surface pressure is 4150 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure Well 2T-03 has a static BHP from April 2012 that measured 2913 psi at 7530' MD, 5789'TVD for an EMW of 9.7 ppg. Since we are drilling toward other producing wells, our expectation is that we will encounter similar formation pressure while drilling the 2T-03 CTD laterals. We plan to obtain an updated static BHP survey in 2T-03 as well as in offset injector 2T-29A within the next 2-4 weeks. Maximum potential formation pressure is based on offset injection wells. Several of these offsets have been plugged with cement or tubing tail plugs due to subsidence problems, so pressure measurements from those wells are from 2009 or older. Active injection wells 2T-26 and 2T-29A show formation pressure of 10.5 and 12.1 ppg respectively, although these pressure measurements are also somewhat dated. The historic maximum formation pressure in the vicinity is from 2T-05 in May of 2009,just prior to it being plugged with cement. It had a formation pressure of 4703 psi at 5770'TVD for a gradient of 15.7 ppg. In 2T-03 this equates to a maximum potential formation pressure of 4730 psi (7550' MD, 5804'TVD) and a maximum potential surface pressure of 4150 psi assuming a gas gradient to surface. Potential Gas Zones No miscible gas has been injected on the 2T pad since 2009, so it is unlikely that an influx will produce any significant amount of gas. Potential Causes of Hole Problems The major expected downhole risk in the 21-03A sidetrack is hole stability due to interbedded shales in the A-sand. Unstable shales were very problematic in the 2T-29 sidetrack in 2009. We will mitigate hole instability by maintaining a minimum ECD target of 12.0 ppg EMW at the window while drilling the CTD sidetrack, as well as using mud additives that minimize chemical instability. Subsidence problems on the 2T pad bring up issues of long-term productivity, but it should not affect CTD operations in 2T-03 in any way. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2T-03 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. a Page 2 of 6 (_ ;� + ; March 6,2013 PTD Application .or KRU 2T-03A, AL1, & AL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Sidetrack Liner Liner Liner Liner Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 2T-03A 7750' 11,100' 5735' 5737' 2%", 4.7#, L-80, ST-L slotted liner with aluminum billet 2T-03ALI 7670' 9450' 5740' 5711' 2W, 4.7#, L-80, ST-L slotted liner with aluminum billet 2T-03AL2 7448' 9375' 5611' 5742' 2'/g', 4.7#, L-80, ST-L slotted liner up inside 3'h"tubing tail Existing Casing/Liner Information Wt Top Btm Top Btm Burst Col. Category OD (PO Grade Cxn MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' n/a n/a Surface Csg 9%" 36 J-55 BTC 0' 3174' 0' 2787' 3520 2020 Prod Csg 7" 26 L-80 TC-II 0' 2058' 0' 1993' 7240 5410 J-55 BTC 2058' 7893' 1993' 6064' 4980 4320 Tubing 3%" 9.3 L-80 grd Mod 0' 7458' 0' 5736' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.5 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 2T-03 motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: Well 2T-03 is equipped with a subsurface safety valve (SSSV)which will be used to isolate the formation while picking up jointed completion liner. If the SSSV fails, the well will be loaded with over-balancing completion fluid while picking up jointed liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling(CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 2T-03 laterals we will target a constant BHP of 12.0 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain Page 3 of 6 March 6,2013 PTD Application .or KRU 2T-03A, AL1, & AL2 overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 2T-03A Window(7550' MD, 5804' TVD, 5687' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(9.7 ppg) 2930 psi 2930 psi Mud Hydrostatic(9.5 ppg) 2867 psi 2867 psi Annular friction (i.e. ECD, 0.095 psi/ft) 717 psi 0 psi Mud + ECD Combined 3584 psi 2867 psi (no choke pressure) (overbalanced (underbalanced -650 psi) -60 psi) Target BHP at Window(12.0 ppg) 3622 psi 3622 psi Choke Pressure Required to Maintain 40 psi 760 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Well 2T-03 is a Kuparuk A-sand/C-sand development(producer)well equipped with 3W tubing and 7" production casing. A rig workover was performed for subsidence in December 2011. They pulled and replaced the upper the-2000' of 7"casing and cemented it in place. They then ran a 3W straddle completion and re-perforated the Kuparuk A and C sand to reestablish production. Three proposed A-sand CTD laterals will increase reservoir exposure in the fault block. Prior to drilling, the existing A&C-sand perfs in 2T-03 will be plugged with cement to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A& C-sand perfs in this manner. The 3W tubing in the tubing tail will be perforated (7450'-7455' RKB) to allow cement to go above the tubing tail and reduce the risk of contaminated cement at the tubing tail. After plugging off the existing A and C sand perfs with cement, a pilot hole will be drilled through the cement to 7,580' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2T-03A sidetrack will exit the 7" casing at 7,550' MD and will target the A3 sand south of the existing well with a 3,350' lateral. The hole will be completed with a 2%' slotted liner to the TD of 11,100' MD with an aluminum billet at 7,750' MD. Page 4 of 6 March 6,2013 PTD Application .or KRU 2T-03A, AL1, & AL2 The 2T-03AL1 lateral will kick off from the aluminum billet at 7,750' MD and will target the A3 sand north of the existing well with a 1700' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9,450' MD with an aluminum billet at 7,670' MD. The 2T-03AL2 will kick off from the aluminum billet at 7,670' MD and will target the A2 sand north of the existing well with a 1705' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9,375' MD with the final liner top located inside the 3W tubing at 7,448' MD. Pre-CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T& IC. 3. RU Slickline. a. Pull ISO sleeve from the SSSV b. Drift and tag PBTD c. Drift w/Dummy whipstock d. Obtain static bottom hole pressure, (SBHP) e. CMIT&MITT 4. RU E-line. Perforate tubing tail at 7450'-7455' RKB (5' of perfs) 5. RU coil. Place cement in the 7"casing, squeeze off existing A and C sand perfs. 6. RU Slickline. Tag top of cement and pressure test. RD Slickline. 7. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. 2. 2T-03A Sidetrack(A3 sand, south) a. Drill 2.80" high-side pilot hole through cement to 7,580' MD b. Set whipstock at 7,550' MD with high-side orientation. c. Mill 2.80"window at 7,550' MD. d. Drill 2.70"x 3" bi-center lateral to TD of 11,100' MD e. Run 2%"slotted liner with an aluminum billet from TD up to 7,750' MD, using the SSSV to isolate formation pressure while picking up liner. 3. 2T-03AL1 Lateral (A3 sand, north)< p rD 113 a. Kick off of the aluminum billet at 7,750' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9,450 MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7,670' MD, using the SSSV to isolate formation pressure while picking up liner. 4. 2T-03AL2 Lateral (A2 sand, north) a. Kick off of the aluminum billet at 7,670' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9,375' MD c. Run 2%" slotted liner from TD up to 7,448' MD inside the 3W tubing tail, using the SSSV to isolate formation pressure while picking up liner. 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Liner Running — Well 2T-03 is equipped with a SSSV which will be closed to isolate the formation while picking up 2%" slotted liner. If the SSSV fails, fluid of sufficient density to over-balance the formation will be used to provide formation over-balance while picking up slotted liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. Page 5 of 6 'auJp ' Y 4 y i March 6,2013 r � '�✓ 3 PTD Applicatioi1 ,or KRU 2T-03A, AL1, & AL2 Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) - No annular injection on this well. - Class II liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - There are no other affected owners - Please see attached directional plans for each lateral. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to nearest property line and nearest well in the same pool. Distance Distance to Sidetrack Directional to Unit Nearest Name Plan Boundary Well Nearest Well 2T-03A 03 -8845' -220' 2T-07 2T-03AL1 03 -8910' -720' 2T-27 2T-03AL2 01 -8910' -720' 2T-27 Attachment 1: Directional Plans for 2T-03A, 2T-03AL1, & 2T-03AL2 Attachment 2: Current Well Schematic for 2T-03 Attachment 3: Proposed Well Schematic for 2T-03 CTD Sidetrack Page 6 of 6 March 6, 2013 m \ \ ¥ • / \ CO \ < a 1i < Ct _ 6c > --ge 2 6 / k� b k> 7 7 = : : \ % 4e ® 2 _/ t 5 $ ® g2 / \ 2 < � 2 / \ N. 6 00 - °a® 9aa a m _ /e / 2 =@ / \ /} § / \ $ \ § R6 /\% 7 / m E2 §/ §{/ - £5 ° eoe @ a \ \ mk /Q/ ® - \ ƒ ! \ § \\ /` 2 ?#/ / \\ E\ { } [\ x \ } [\ §\ [ /)9 / / . ® .` ��\ / CO G/ A/ 0 z)/ 3 a #y 2 \ « \ $) 2 ) ) 2 2 A m m° IA m 2 co m m 06 in # 1 I , , � , a. A // H ; Q \� / ■ a., , . ƒ K » \ ƒ _ 2©, ._ ) . . . . yx. U) „,, : « . «y� .,. ,_ .. , . ''' . ». w< : D ^ \2 - 2 » : 2« 2 > . , > . . :> ». . j\ dL 2 < ° ° U :< a . » .. ©rmx \i' i,/,';''''' - @ 0 0 1 ,, 0 ,, § Ti a) » \ co _ _§ 2 E _ . � & 2 > 3c < . �k :J.-) 5 / \ / # > < » ° � k r- -6-2- k\ / k � ^� \ a \ b ® 1--N" &% � \ \ % aq 0 - \ \ )/ U ° ® ~ / N- \ / / op 0 | i t t | viii }}% . ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2T Pad 2T-03 2T-03AL1 Plan: 2T-03AL1_wp03 Standard Planning Report 07 March, 2013 BAKER HUGHES 0 R fr:l.'114% v-' Baker Hughes INTEQ FS� ConocoPhillips Planning Report BAKER Alamo HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2T-03 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-03 @ 117.00ft(2T-03) Site: Kuparuk 2T Pad North Reference: True Well: 2T-03 Survey Calculation Method: Minimum Curvature Wellbore: 2T-03AL1 Design: 2T-03A L 1_wp03 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 2T Pad Site Position: Northing: 5,970,382.43ft Latitude: 70°19'49.129 N From: Map Easting: 498,944.93ft Longitude: 150°0'30.807 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2T-03 Well Position +N/-S 0.00 ft Northing: 5,970,357.42 ft Latitude: 70°19'48.883 N +E/-W 0.00 ft Easting: 498,944.91 ft Longitude: 150°0'30.808 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 2T-03AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2012 4/30/2013 15.50 79.89 57,350 Design 2T-03AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,750.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (1 -81.50 0.00 0.00 339.81 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (1100ft) (°I100ft) (°/100ft) (°) Target 7,750.00 94.46 297.55 5,734.76 3,871.14 -2,065.10 0.00 0.00 0.00 0.00 7,780.00 99.64 300.58 5,731.08 3,885.59 -2,091.11 20.00 17.29 10.13 30.00 7,815.00 103.08 306.81 5,724.18 3,904.61 -2,119.65 20.00 9.82 17.77 60.00 7,905.00 101.51 325.16 5,704.85 3,967.58 -2,180.44 20.00 -1.75 20.40 93.00 7,992.00 90.12 338.40 5,696.02 4,043.60 -2,221.11 20.00 -13.09 15.22 130.00 8,192.00 89.90 2.40 5,695.98 4,239.36 -2,254.21 12.00 -0.11 12.00 90.50 8,362.00 90.36 22.80 5,695.58 4,404.39 -2,217.31 12.00 0.27 12.00 88.70 8,612.00 90.31 352.80 5,694.07 4,649.25 -2,183.78 12.00 -0.02 -12.00 270.00 8,862.00 88.42 22.74 5,696.89 4,894.12 -2,150.38 12.00 -0.76 11.98 93.70 9,062.00 88.56 358.73 5,702.24 5,089.12 -2,113.40 12.00 0.07 -12.00 270.00 9,312.00 88.75 28.74 5,708.24 5,329.13 -2,054.73 12.00 0.08 12.00 90.00 9,450.00 88.80 12.18 5,711.20 5,457.95 -2,006.67 12.00 0.04 -12.00 270.00 3/7/2013 4:39:11PM Page 2 COMPASS 2003.16 Build 69 0 yFy E i t d y R 6` g * to i H v 't..._ -Ncv--' Baker Hughes INTEQ Fir- ConocoPhillips Planning Report BAKER Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 21-03 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-03 @ 117.00ft(2T-03) Site: Kuparuk 2T Pad North Reference: True Well: 2T-03 Survey Calculation Method: Minimum Curvature Wellbore: 2T-03AL1 Design: 2T-03AL 1_w p03 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) 7,750.00 94.46 297.55 5,734.76 3,871.14 -2,065.10 4,345.97 0.00 0.00 5,974,228.46 496,880.56 TIP/KOP 7,780.00 99.64 300.58 5,731.08 3,885.59 -2,091.11 4,368.51 20.00 30.00 5,974,242.92 496,854.55 Start 20 dls 7,800.00 101.63 304.12 5,727.39 3,896.11 -2,107.72 4,384.11 20.00 60.00 5,974,253.44 496,837.95 7,815.00 103.08 306.81 5,724.18 3,904.61 -2,119.65 4,396.21 20.00 60.65 5,974,261.94 496,826.02 3 7,900.00 101.63 324.15 5,705.85 3,963.58 -2,177.60 4,471.56 20.00 93.00 5,974,320.91 496,768.08 7,905.00 101.51 325.16 5,704.85 3,967.58 -2,180.44 4,476.29 20.00 96.74 5,974,324.91 496,765.25 4 7,992.00 90.12 338.40 5,696.02 4,043.60 -2,221.11 4,561.67 20.00 130.00 5,974,400.92 496,724.59 5 8,000.00 90.11 339.36 5,696.00 4,051.06 -2,223.99 4,569.67 12.00 90.50 5,974,408.39 496,721.71 8,100.00 90.00 351.36 5,695.90 4,147.64 -2,249.21 4,669.02 12.00 90.50 5,974,504.96 496,696.51 8,192.00 89.90 2.40 5,695.98 4,239.36 -2,254.21 4,756.83 12.00 90.51 5,974,596.67 496,691.53 Start 12 dls 8,200.00 89.93 3.36 5,695.99 4,247.35 -2,253.80 4,764.19 12.00 88.70 5,974,604.66 496,691.93 8,300.00 90.20 15.36 5,695.88 4,345.84 -2,237.57 4,851.02 12.00 88.70 5,974,703.14 496,708.18 8,362.00 90.36 22.80 5,695.58 4,404.39 -2,217.31 4,898.99 12.00 88.71 5,974,761.68 496,728.44 7 8,400.00 90.36 18.24 5,695.34 4,439.97 -2,204.00 4,927.79 12.00 -90.00 5,974,797.25 496,741.76 8,500.00 90.35 6.24 5,694.72 4,537.52 -2,182.84 5,012.04 12.00 -90.03 5,974,894.79 496,762.93 8,600.00 90.32 354.24 5,694.14 4,637.33 -2,182.42 5,105.58 12.00 -90.10 5,974,994.59 496,763.36 8,612.00 90.31 352.80 5,694.07 4,649.25 -2,183.78 5,117.24 12.00 -90.17 5,975,006.51 496,762.00 8 8,700.00 89.63 3.34 5,694.11 4,737.08 -2,186.74 5,200.69 12.00 93.70 5,975,094.33 496,759.05 8,800.00 88.87 15.31 5,695.43 4,835.57 -2,170.57 5,287.55 12.00 93.69 5,975,192.81 496,775.23 8,862.00 88.42 22.74 5,696.89 4,894.12 -2,150.38 5,335.55 12.00 93.54 5,975,251.36 496,795.43 9 8,900.00 88.43 18.18 5,697.94 4,929.70 -2,137.10 5,364.36 12.00 -90.00 5,975,286.93 496,808.71 9,000.00 88.49 6.18 5,700.64 5,027.24 -2,116.06 5,448.64 12.00 -89.87 5,975,384.45 496,829.77 9,062.00 88.56 358.73 5,702.24 5,089.12 -2,113.40 5,505.80 12.00 -89.55 5,975,446.33 496,832.43 10 9,100.00 88.56 3.29 5,703.19 5,127.09 -2,112.73 5,541.21 12.00 90.00 5,975,484.29 496,833.11 9,200.00 88.62 15.30 5,705.66 5,225.57 -2,096.61 5,628.07 12.00 89.89 5,975,582.76 496,849.24 9,300.00 88.73 27.30 5,707.97 5,318.54 -2,060.36 5,702.83 12.00 89.59 5,975,675.72 496,885.50 9,312.00 88.75 28.74 5,708.24 5,329.13 -2,054.73 5,710.82 12.00 89.31 5,975,686.31 496,891.14 11 9,400.00 88.77 18.18 5,710.14 5,409.72 -2,019.75 5,774.40 12.00 -90.00 5,975,766.89 496,926.12 9,450.00 88.80 12.18 5,711.20 5,457.95 -2,006.67 5,815.14 12.00 -89.77 5,975,815.10 496,939.21 TD at 9450.00 3/7/2013 4:39:11PM Page 3 COMPASS 2003,16 Build 69 11.-' . . Baker Hughes INTEQ �&� ConocoPhillliips Planning Report HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2T-03 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-03 @ 117.00ft(21-03) Site: Kuparuk 2T Pad North Reference: True Well: 21-03 Survey Calculation Method: Minimum Curvature Wellbore: 2T-03AL1 Design: 2T-03AL 1_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2T-03AL1_T1 0.00 0.00 5,694.00 4,686.96 -2,187.15 5,975,044.22 496,758.64 70°20'34.975 N 150°1'34.704 W -plan hits target center -Point 21-03 CTD Polygon_Noi 0.00 0.00 0.00 3,643.88 -2,108.01 5,974,001.24 496,837.62 70°20'24.717 N 150°1'32.383 W -plan misses target center by 5711.14ft at 7992.00ft MD(5696.02 TVD,4043.60 N,-2221.11 E) -Polygon Point 1 0.00 3,643.88 -2,108.01 5,974,001.24 496,837.62 Point 2 0.00 4,247.85 -2,574.17 5,974,605.21 496,371.60 Point 3 0.00 5,678.11 -1,963.39 5,976,035.24 496,982.52 Point4 0.00 5,498.17 -1,588.31 5,975,855.27 497,357.53 Point 5 0.00 4,073.93 -2,074.09 5,974,431.24 496,871.60 Point 6 0.00 3,872.94 -1,900.03 5,974,230.24 497,045.62 Point? 0.00 3,643.88 -2,108.01 5,974,001.24 496,837.62 2T-03AL1_T2 0.00 0.00 5,711.00 5,458.04 -2,006.23 5,975,815.20 496,939.65 70°20'42.559 N 150°1'29.424 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,450.00 5,711.20 2 3/8" 2-3/8 3 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology (°) (°) 7,562.08 5,696.00 Formation 2 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,750.00 5,734.76 3,871.14 -2,065.10 TIP/KOP 7,780.00 5,731.08 3,885.59 -2,091.11 Start 20 dls 7,815.00 5,724.18 3,904.61 -2,119.65 3 7,905.00 5,704.85 3,967.58 -2,180.44 4 7,992.00 5,696.02 4,043.60 -2,221.11 5 8,192.00 5,695.98 4,239.36 -2,254.21 Start 12 dls 8,362.00 5,695.58 4,404.39 -2,217.31 7 8,612.00 5,694.07 4,649.25 -2,183.78 8 8,862.00 5,696.89 4,894.12 -2,150.38 9 9,062.00 5,702.24 5,089.12 -2,113.40 10 9,312.00 5,708.24 5,329.13 -2,054.73 11 9,450.00 5,711.20 5,457.95 -2,006.67 TD at 9450.00 3/7/2013 4:39:11 PM Page 4 COMPASS 2003.16 Build 69 0 11) I i � � p i,x - t 6 'Yi c, '`,3 L, ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2T Pad 2T-03 2T-03AL1 2T-03AL1_wp03 Travelling Cylinder Report 07 March, 2013 mar BAKER HUGHES 1.-- Baker Hughes INTEQ Id" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-03 Project: Kuparuk River Unit TVD Reference: 2T-03 @ 117.00ft(2T-03) Reference Site: Kuparuk 2T Pad MD Reference: 2T-03 @ 117.00ft(2T-03) Site Error: 0.00ft North Reference: True Reference Well: 2T-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2T-03AL1 Database: EDM Alaska Prod v16 Reference Design: 2T-03AL1_wp03 Offset TVD Reference: Offset Datum Reference 2T-03AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,750.00 to 9,450.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,141.45ft Error Surface: Elliptical Conic Survey Tool Program Date 3/7/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 7,500.00 21-03(21-03) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,500.00 7,750.00 2T-03A_wp03(2T-03A) MWD MWD-Standard 7,750.00 9,450.00 2T-03AL1_wp03(2T-03AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,450.00 5,828.20 2 3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/7/2013 11:07:38AM Page 2 of 13 COMPASS 2003.16 Build 69 ir- 1 . Baker Hughes INTEQ Fri ConocoPhulhhps Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-03 Project: Kuparuk River Unit TVD Reference: 2T-03 @ 117.00ft(2T-03) Reference Site: Kuparuk 2T Pad MD Reference: 2T-03 @ 117.00ft(2T-03) Site Error: 0.00ft North Reference: True Reference Well: 2T-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2T-03AL1 Database: EDM Alaska Prod v16 Reference Design: 21-03AL1_wp03 Offset TVD Reference: Offset Datum 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 2T Pad 2T-203-21-203-2T-203 wp06 Out of range 2T-40-2T-40 Wp06-2T-40 Wp06 Planning Work Out of range Kuparuk 2T Pad 21-02-21-02-2T-02 Out of range 21-03-21-03-21-03 7,750.00 7,875.00 202.63 130.53 162.57 Pass-Major Risk 21-03-21-03A-21-03A_wp03 7,750.00 7,750.00 0.00 0.33 -0.22 FAIL-Major Risk 2T-03-2T-03AL2-2T-03AL2_wp01 9,434.14 9,375.00 30.81 0.67 30.59 Pass-Minor 1/10 2T-04-2T-04-21-04 Out of range 2T-20-21-20-21-20 Out of range 2T-203-2T-203-21-203 Out of range 2T-203-2T-203-2T-203wp06 Out of range 2T-22-2T-22-2T-22 Out of range 2T-23-2T-23-21-23 Out of range 2T-26-2T-26-2T-26 Out of range 21-27-2T-27-2T-27 9,450.00 8,000.00 864.51 262.94 663.12 Pass-Major Risk 2T-27-2T-27A-2T-27A 9,450.00 8,000.00 864.51 262.94 663.12 Pass-Major Risk 2T-27-2T-27AL1-2T-27AL1 9,450.00 8,000.00 864.51 262.94 663.12 Pass-Major Risk 2T-27-2T-27APB1-2T-27APB1 9,450.00 8,000.00 864.51 262.94 663.12 Pass-Major Risk 2T-27-2T-27APB2-2T-27APB2 9,450.00 8,000.00 864.51 262.94 663.12 Pass-Major Risk 2T-28-2T-28-2T-28 Out of range 2T-29-2T-29-2T-29 Out of range 2T-29-2T-29A-21-29A Out of range 2T-29-2T-29AL1-2T-29AL1 Out of range 2T-29-2T-29AL1-01-2T-29AL1-01 Out of range 2T-29-2T-29AL1-01 PB1-2T-29AL1-01 PB1 Out of range 2T-29-2T-29AL1-02-2T-29AL1-02 Out of range 21-30-21-30-21-30 Out of range 2T-31-21-31-2T-31 Out of range 2T-32-2T-32-2T-32 Out of range 2139-2139-2139 Out of range 21-40-21-40-2T-40 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/7/2013 11:07:38AM Page 3 of 13 COMPASS 2003.16 Build 69 • Baker Hughes INTEQ rj— ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-03 Project: Kuparuk River Unit TVD Reference: 2T-03 @ 117.00ft(2T-03) Reference Site: Kuparuk 2T Pad MD Reference: 2T-03 @ 117.00ft(2T-03) Site Error: 0.00ft North Reference: True Reference Well: 2T-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2T-03AL1 Database: EDM Alaska Prod v16 Reference Design: 2T-03AL1_wp03 Offset TVD Reference: Offset Datum Reference Depths are relative to 2T-03 @ 117.00ft(21-03) Coordinates are relative to:2T-03 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.01° Ladder Plot I I I I I 1200— J J c 900 O co J J J J 0_ a) U) a) a 600- U O _J J J J J cc a) 0 300- 1 I I I I I 1 I I I 1 I 1 I i I 1 I 1 I _ 0 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND 2T-27,2T-27APB2,2T-27APB2VO 21-27,2T-27,2T-27VO 21-03,2T-03AL2,2T-03AL2_wp01VO 2T-27,2T-27A,2T-27AV0 $ 2T-27,2T-27AL1,2T-27AL1 V0 —} 2T-03,2T-03A,2T-03A_wp03V0 $ 2T-27,2T-27APB1,2T-27APB1V0 2T-03,2T-03,2T-03 V3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/7/2013 11:07:38AM Page 13 of 13 COMPASS 2003.16 Build 69 ONft .2L 4 0° < s ,. F a 1 NC A • EN 0 2n N h I 8 I 8 0 r aI �_____ N . i\, , ,.7.-"' r , T b , I s I / h ` ▪ O▪ �I . o _E ° v I C i Q / r A0r.,5 �8, I . 2. o 8 0 c g r g g ¢°o o IL o o 8 I-. ? © J• .. - ° r a.• a°0 E ° o ° g ° ° F., a m n � 8 M o F ( OS )( /- ;noS ° m 3 CA ¢ �, 0 a° i IA z U .Y .1. d1 ¢ - -■ o _ __ n 8 1. 5 ,, o No.. , r c — a 8 .. - . 0 .v a 300 000S°°o8°0 ° ar IL - '° g°° -°°&N NSN 2.a"oq 088888 ° o C O 1,11111'.. d 2 a N N w -- - .. 0 c a % ^ z ..o o rn N_o4_m,° L F z, M m d U �i°i�.�`i uwm .mi�Nmom"'o m,, -," ° �gmmmISm� 6 I�m.°'omm r J9�Q -.E,.: N18M,MR -..- N s e P _ o 'd 30 0000000 m 7 �00�000oo88S °g °gm • 0 28—�'NmN��N.=53 r 9 ,., U ��ml.l,mmmmmmg, 0 o (uoj OS g2u e ! A {I lJ I _... TRANSMITTAL LETTER CHECKLIST WELL NAME KFUA. 2i-03A L.l. PTD# 2/3oyo Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: K cA4c 2`v6c POOL: J\ycvLmG< L/E, )L AIC g.YEAr O) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well )< U.. 21-O3A (If last: bt5a o digi in Permit No. 213 C7 3y ,API No. 50- API re I U 3 - 00?3'61 - bb. 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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