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213-004
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 b direct inspection of the file. j 3 - ©0 4 Well History File Identifier Organizing(done) ❑ Two-sided III III Iliii ❑ Rescan Needed III 1111111111 III III RES AN DIGITAL DATA OVERSIZED (Scannable) Color 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: daft Date: _ •. /s/ u Project Proofing I 1111111111 11111 ! 9► BY: Maria Date: aJLfJILt /s/ MP Scanning Preparation c2, x 30 = '(j() + I p`. = TOTAL PAGES c (Count does not include cover s et) BY: 411212ft Date: a Lil 1 L../. /s/ ' Production Scanning II IIIIIIIIIII 11111 Stage 1 Page Count from Scanned File: 73 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: 3_4 a 1-I- I j ty. /s/ M1 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. III 11111111111 11111 ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked Iii 111111 III 111111 c �� , 0 i cu CC m E < < , CC el c co a) N •� •` N ..-0 10 N >, I u) 7) .0 X o) < NO O c O 2 Q co 0 c O N y U d ° O O a t N N 2 1 as O 01 p N U U co � 11116• Z O N d d N Lc;a 0 S ° ° -6.-1 rn+ ° c a) -Z o o oo r I a) O a of d ' 1 a E c c a) a a) a a) E J a) m /Z /<? 1 co m ' 11 I 0 N as I I I o U � IX m p E >- >- >-/y d It O ' c _M M �M M CO C•r a m (a i Om Zi- J U N N N N N 7 Q ° IX o 2 v i ii ;v U Z j N 5 m rn n (� � l 3 0 ° 0 0 0 0 0 E 3 Z y v; 42 N co ICC R N 2 N N N N N !I J a c ' O p) a) O IE Cl) r �- �- r �- - E J a c _ 0 CA 0 V)• I o :: c 0 0 L M c I c t 0) (0 (0 (O (0 a) !I 0) G O ° a• go CO`f a`fo ado co Cl) . I • r E / Z iI U U II' E I II C c 9 IIICC 0) e- 1 / 2 2 1 0 a m , Z O J 2 U U U m N :° c f■ C • / N i to (a N o 76 03 rc .i.--3 J W N C O I— E 0. V/ • Iii I co ) a) c a ° 5 S Q o m m m Y m III of o c ° \� Q ° a , Z U L 0 , 0 Z Eo w > o v > I E —D Z w w w w Z 7 I''I 0 a0 aa)) aa)) aa)) I to i m c c c c c 1 ✓ c E'; o 0 0 0 o c ¢ I �1� I c koi O p) a c c c c E } C } Ld1 Lc (n (n LO W E CO m N Q Q Y W Q Z N N N N CO W -c w a) H as r d N 0 C Ln > OLL 0 � . E Z aai N a) m ' O o 0• O ? a' r 2 O) 'O N Z I— ca a1 O a o u c v a w Q o c ) c ✓ Z W o 2 0 o a 2 m m ce w J U a ° o E o. Zr) III ,II 0 1- 3 -1o � ._1 ° °W ?u. 0 Cl. 0 II 0 10 t r 7 _ RECEIVH rI`• PRINT DISTRIBUTION LIST BAKER D S T MAY 1 3 2013 HUGHES AOGCC COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 1H-19A 19AL1; 19AL1-01; 19AL1-01PB1 19AL2; 19APB1; 19AL1 PB1 X557 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: 5/9/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital il ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur F'HIN I S #OF COPIES #OF COPIES ConocoPhillips Alaska,Inc. 1 I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 1 I 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 1 1 1 I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT 1 1 1 I I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: • 0 4 4 0 0 0 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND `LOG. ' .. ' la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ El • WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service El ' Stratigraphic Test El 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 16,2013 213-004/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 7,2013 50-029-22312-61 r 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 582'FNL, 1160'FEL,Sec.33,T12N,R10E,UM' March 15,2013 1 H-19AL21 Top of Productive Horizon: 8.KB(ft above MSL): 96'RKB 15.Field/Pool(s): 2558'FNL,440'FWL,Sec.28,T12N, R10E, UM GL(ft above MSL): 54'AMSL Kuparuk River Field ' Total Depth: 9.Plug Back Depth(MD+TVD): 2871'FNL,350'FWL,Sec.28,T12N,R10E,UM ' 11200'MD/6641'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-549187 y- 5980119 Zone-4• " 11201'MD/6641'TVD ADL 25639 TPI: x-545478 y- 5983399 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-545391 - y- 5983086 Zone-4 nipple @ 1810'MD/1692'TVD 464 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) 1703'MD/1625'ND • 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD none 8496'MD/6556'ND 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# H-40 42' 121' 42' 121' 24" 200 sx PF C 9.625" 40# L-80 42' 5345' 42' 4270' 12.25" 1390 sx PF E,500 sx Class G,44 bbls PF C 7" 26# J-55 39' 8970' 39' 6913' 8.5" 270 sx Class G 2.375" 4.7# L-80 8484' 11200' 6551' 6641' 3" slotted liner 24.Open to production or injection? Yes 119 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"x 2.875" 8600' 8242'MD/6370'ND,and slotted liner from 8490'-11200'MD 6551'-6641'ND 8569'MD/6609'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 31* 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) March 28,2013 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE -GAS-OIL RATIO 4/7/2013 11 hours Test Period--> 25 10 13 176 Bean Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 197 psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No pi 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 REIDMS APR 16 21 c f rr Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Lj 9/2+/2O i3 Submit original only •tj 404;0, 44G 29. GEOLOGIC MARKERS(List all formations and r, s encountered): 30. _ FORMATION TESTS NAME MD TVD Well tested? 11 Yes 0 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 1703' 1625' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A3 10880' 6613' 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 t best knoowllejge. Contact: James Ohlinger @ 265-1102 /WI if Lamar.L.GanttCa conocophillips.com Printed Name Lamar Gantt Title: CT Drilling Supervisor Signature 'cknavulk. X ,:4-ekikitN Phone 263-4021 Date 1� 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 1H-19 �. ps •� Alaska, Well Attributes Max Angle K MD TD ��� ��,' Wellbore API/l1Wl Field Name Well Status Intl(') MD(RKB) Act Btm(MB) .. ......._..................._................... carc.:end , 500292231200 KUPARUK RIVER UNIT INJ 46.17 5,677.00 8,990.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ' SSSV:WRDP Last WO: 6/14/1993 12/18/1992 Well Confa:-1H-19,c8-AcS, 1040:56 AM schematic-AClual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,683.0 10/2/2012 Rev Reason:ADD PERFS,SET PLUG/SLIDING SLV osborl 1/7/2013 ,Casinq Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd HANGER.38 CONDUCTOR 16 15.060 41.9 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd SURFACE 95/8 8.835 41.9 5,344.6 4,269.9 40.00 L-80 BTC "-"r Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd_ PRODUCTION 7 6.276 38.5 8,973.5 6,915.7 26.00 J-55 AB-MOD Tubing Strings Tubing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 3.5x 2.875 31/2 2.992 37.6 8,599.8 6,632.4 9.30 J-55 ABM-EUE CONDUCTOR, _ Completion Details 42-121 Top Depth II (TVD) Top net Noml... Top(ftKB) MB) (") Item Description Comment ID(in) i W • 37.6 37.6 0.05 HANGER FMC GEN IV HANGER 3.500 NIPPLE,1,810 I 1,810.1 1,692.1 37.81 NIPPLE OTIS SELECTIVE LANDING NIPPLE 2.813 8,229.7 6,360.9 43.39 PBR OTIS PBR,LOCATOR 4.4"OD,SEALS 2.97"ID 2.970 8,241.9 6,369.8 43.66 PACKER OTIS HVT RETRIEVABLE PACKER 2.972 8,337.2 6,439.1 43.19 BLAST JT BLAST JOINT PUPS(OAL=139.08') 2.992 8,526.6 6,578.1 42.32 NIPPLE AVA BPL PORTED NIPPLE 2.320 8,560.7 6,603.4 42.08 XO Reducing CROSSOVER 3.5 x 2.875 2.875 8,565.5 6,607.0 42.05 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.406 ___� 8,568.6 6,609.3 42.03 PACKER BAKER D PERMANENT PACKER(2 SPACE OUT ABOVE PKR)4.25" 3.250 SEAL BORE SURFACE, 42-5,345 8,587.3 6,623.2 41.84 NIPPLE CAMCO D NIPPLE NO GO 2.250 IN 8,599.0 6,631.8 41.82 SOS OTIS SHEAR OUT SUB. ELMD TTL 8596'ON 5/29/06 2.441 GAS LIFT, = Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 8,180 Top Depth 1 (TVD) Top Intl Top(RKB) (RKB) (') Description Comment Run Date ID(in) 8,526.6 6,578.2 42.32 SLEEVE AVA BPC SET IN PORTED NIPPLE 1/3/2013 - 8,568.6 6,609.3 42.03 PLUG CA-2 PLUG SET IN PACKER 1/3/2013 0.000 PBR,8,230 Perforations&Slots PACKER,8,242 Ift■ift-- Shot Top(TVD) Btm(TVD) Dens Top OMB)Btm(RKB) (5081 (RKB) Zone Date loh... Type Comment 8,340.0 8,404.0 6,441.1 6,487.9 C-4,C-3,1H-19 6/14/1993 12.0 IPERF 60 deg Phasing 8,430.0 8,470.0 6,506.9 6,536.3 C-2,C-1,UNIT 6/14/1993 12.0 IPERF 60 deg Phasing B,1H-19 INJECTION. '- 8,490.0 8,500.0 6,551.1 6,558.5 UNIT B,1H-19 12/31/2012 6.0 APERF 2'HSC,Millenium HMX BH,60 deg 8 phase ,294 8,510.0 8,520.0 6,565.8 6,573.3 UNIT B,1H-19 12/31/2012 6.0 APERF 2"HSC,Millenium HMX BR,60 deg phase 8,673.0 8,693.0 6,687.0 6,702.0 A-4,1H-19 2/18/2007 6.0 RPERF 0deg Phasing IPERF,_ 8,706.0 8,726.0 6,711.7 6,726.8 A-3,1H-19 2/18/2007 6.0 RPERF OdegPhasing 8,340-8.404 Notes:General&Safety End Date Annotation IPERF,- E J ' ] 9/27/2010 NOTE:View Schematic w/AlaskaSchematic9.0 8,430-8,470 2/1/2011 NOTE:APPARENT C-SAND LEAK @ 8294'MANDREL APERF, r I La 8,490-8,500 1 APERF, 1 8,5104,520 I NIPPLE,8.527 SLEEVE,8,527 - I I;: lill SEAL ASSY. 8,566 III PACKER.8,569 r/4 ■ NIPPLE,0587 ht ■ SOS.8.599 ? Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run Stn Top(RKB) (fKS) ("I Make Model (in) Sery Type Type (in) (psi) Run Data Cont.. 1 8,179.8 6,324.6 43.40 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/14/2010 ® 2 8,294.0 6,407.6 43.36 CAMCO MMG 1 12 INJ OPEN 0.000 0.0 1/3/2013 RPERF, 8,6738,693 II RPERF, ill 111 8,708-8,728 PRODUCTION, 38-8,973 . TD,8,990 • KUP 1 H-19AL2 • ConocoPhi lips Max Angle&MD TD Alaska.IIK;. Wel!bore APWWI Field Name Well Status Ind(°) MD MB) Act Btm(ftKB) 500292231261 KUPARUK RIVER UNIT SVC 11201.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date "„ _SSSV:NIPPLE Last WO: 6/14/1993 12/18/1992 Well Cont9:-111-19AL2,31271201312:47'33 PM -- Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACK,ADD LATERALS osborl 3/21/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd LINER AL2 2 3/8 1.995 8,484.0 11,200.0 4.60 L-80 ST-L HANGER,38 (off main Wellbore) Liner Details Top Depth (TVD) Top Teel Nom)... Top(kKB) ("B) (°) Item Description Comment ID(In) 8,484.0 DEPLOY SEAL BORE DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot Top(TVD) B6n(TVD) Dens Top(RKB)Btnr(ftKB) (RKB) (MB) Zone Date (Oh... Type Comment 8,490.0 8,524.0 3/16/2013 32.0 SLOTS Altemating solid/slotted pipe- CONDUCTOR. 0.125'52.5"@ 4 circumferential 42,121 - adjacent rows,3"centers staggered 18 deg,3'non-slotted ends 9,338.0 11,200.0 3/16/2013 32.0 SLOTS Alternating solid/slotted pipe- : 0.125'5(2.5"@ 4 circumferential - - adjacent rows,3"centers staggered NIPPLE.1 010 18 deg,3'non-slotted ends General&Safety End Date Annotation 3/16/2013 NOTE:SIDETRACK A collapsed,no Liner;renamed AL1-01 3/16/2013 NOTE:WELL SIDETRACKED AL1,AL1-01,AL2('A'RENAMED AL1-01) SURFACE. 42.5,345 GAS LIFT 8.180 PBR.8230 PACKER.8.242 I — INJECTION, 8,294 F-1 I T NANDOWALZ 8,496-0,501 WHIPSTOCK. f �. 8.496 SLOTS, 8,490-0,524 i\ PRODUCTION. J.. 38-0,973 Mandrel Details Top Depth Top Port (ND) Ind OD Valve Latch Site TRO Run N...Top(RKB) (ftKB) (°) Make Model (in) Sere Type Type (in) (per) Run Date Corn... 1 8,179.8 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/14/2010 2 8,294.0 CAMCO MMG 1 1/2 INJ OPEN 0.000 0.0 1/3/2013 SLOTS, 9.338-11.200 LINER AL2 (o5(mein memos). 8,484-11,200 TD(1 K-19AL2). 11,201 O 0 2 J a O M r °o m M .— M Q� ± 11 Q a) =H a) m H II s—H H II N M S F -- ^ H m N c0 0 a) m 7 a m a)m U V > ni r a) y m CO CK rn V N _ N O N N v a) 1 a N a) co co 1 a7 01 - o V C NON N rn co • ,� N N a) 00_ • J O �O N ti N r---C co - N in 0�. a r a a) M N c .-- II co oo m c co N© E co N-- C 2 0 dU a E 0` c N n)m'n `° `-H' ✓ H _ �Y o « 3 m2°° E o_ a oo o c a a)rnUd `m O- O N a) O N CO Q c E C) N � .— 2 a ��� 0 m 1O a 0�'E U g a) 2 m -) -2 43 0n in co _ NY O O N U m co O. U co ca —.3 d N U N h E - 12 E w < = o.E I, 0) M ca N ca J > m- co 0 o ai 1) '7-> 0 w < 0P0 . 0 (V N (V CO N N cV N Y Y 3 2 v co co A 0 0 co co CO m m N . 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( 2 c { \ ( � � U E � � w u � ) & a ' '\ k ConocoPhillips Time Log & Summary Wel!view Web Repotting Report Well Name: 1H-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 2/9/2013 5:00:00 AM Rig Release: 3/16/2013 6:00:00 PM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02/05/2013 24 hr Summary Stand By on 3C pad for extreme cold,-38 12:00 00:00 12.00 MIRU MOVE MOB T Stand by on 3C-11 for extreme cold 02/06/2013 Stand by for cold weather 00:00 00:00 24.00 0 0 MIRU MOVE MOB T Cold weather shut down, Held Pre Spud with night crew(Maddy) 02/07/2013 00:00 12:00 12.00 0 0 MIRU MOVE MOB T Stand by for Cold Weather-36 12:00 16:00 4.00 0 0 MIRU MOVE MOB P Cold weather guidlines lifted,-33°, Move rig to KCC 16:00 19:30 3.50 0 0 MIRU MOVE MOB T Waiting to remove runway barricades on east end of airport/crew changeouts from KIC 19:30 21:00 1.50 0 0 MIRU MOVE MOB P Continue move to 1H pad 21:00 00:00 3.00 0 0 MIRU MOVE MOB T Kuparuk field back in cold weather operating guidelines 02/08/2013 Stand by for cold weather till lifted @ 16:00.MIRU rig modules on 1H-19.Start to NU BOP equipment. 00:00 15:00 15.00 0 0 MIRU MOVE MOB T Kuparuk in Cold Weather Operating Guidelines,cold weather restriction lifted. 15:00 20:00 5.00 0 0 MIRU MOVE MOB P Remove Jeeps,Tarp down and plywood around wellhead,Spot rig modules on 1H-19. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P PU Putz,berm up around cellar, RU interconnect,steam,landings,load pits. 02/09/2013 Continue to MIRU CDR2. NU BOPE. Performed initial BOPE test 250/4000 psi annular 2500 psi. Pulled BPV, pumped slack management, PT PD L's and TT line. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Spot tiger tank, Hardline crew here, Continue rig up 05:00 08:00 3.00 0 0 MIRU WHDBO BOPE P Rig Accept NU BOPE,shell test. 08:00 18:00 10.00 0 0 MIRU WHDBO BOPE P Perform initial BOPE test 250/4,000 psi,annular 2,500 psi.Test witnessed by AOGCC(Chuck Sheave). 18:00 21:00 3.00 0 0 MIRU WHDBO BOPE P RD/LD test joint,blow down test pump. PJSM. RU BPV lubricator, pull BPV, LD equipment.Change 0-ring on riser. 21:00 23:30 2.50 0 0 MIRU WHDBO CTOP P Pump slack management, little to no movement, PT inner reel and stripper. Page 1 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 MIRU WHDBO PRTS P PT PDL's and tiger tank line. 02/10/2013 Installed coil connector.MU BHA#1 cleanout cement from 8,515'to 8,524'above AVA nipple. POOH.MU BHA#2 Dummy WS assembly drift to AVA nipple 8,524'. POOH.MU BHA#3 set WS above AVA,TOWS @ 8,513'.Start OOH w/BHA#3. 00:00 01:30 1.50 0 0 MIRU WHDBO CTOP P Continue PT of PDL's and TT line, cut 10'coil and test E-Line. 01:30 05:00 3.50 0 0 MIRU WHDBO CTOP P Install coil connector,pull test 37K., Make up E-line,PT CTC 4K. Pump forward for a coil volume 05:00 06:00 1.00 0 62 SLOT WELLPF MILL P M/U BHA#1,Straight motor with D331 with Ridge set cutters,M/U to coil and surface test 06:00 08:24 2.40 62 8,100 SLOT WELLPF MILL P Trip in well 08:24 09:00 0.60 8,100 8,205 SLOT WELLPF MILL P Log K1 marker for+3 09:00 09:12 0.20 8,205 8,515 SLOT WELLPF MILL P Trip in for cleanout,tag up @ 8515, PUW=40K, 09:12 09:24 0.20 8,515 8,524 SLOT WELLPF MILL P 8515',Mill Cement, 1.5 BPM @ 2720 PSI FS, ROP=26 FPH constant motor work and WOB, 09:24 09:48 0.40 8,524 8,524 SLOT WELLPF MILL P Mill down to 8524,Set down with 3.3K DHWOB, Looks like top of AVA sleeve, PUW=40K, PUH then run in at min rate clean 09:48 10:00 0.20 8,524 8,265 SLOT WELLPF MILL P PUH to log CCL pass 10:00 10:18 0.30 8,265 8,420 SLOT WELLPF MILL P Log CCL,+4'correction on jewery 10:18 12:12 1.90 8,420 57 SLOT WELLPF MILL P Trip out of well 12:12 13:48 1.60 57 71 PROD1 RPEQP1PULD P At surface, Flow check well, Lay Down BHA#1,cement mill, P/U BHA#2 Dummy Whipstock,Mill out @ 2.79 No Go,Service injector 13:48 15:42 1.90 71 8,120 PROD1 RPEQP1TRIP P RIH with Dummy Whipstock,EDC closed 15:42 16:06 0.40 8,120 8,178 PROD1 RPEQPI DLOG P Log K1 tie in for,+4'correction 16:06 16:12 0.10 8,178 8,525 PROD1 RPEQP1TRIP P RIH with dummy,Tag @ 8525 with 2.8K DHWOB 16:12 18:00 1.80 8,525 70 PROD1 RPEQP1TRIP P POOH,PUW=39K,Circulate bio 18:00 20:00 2.00 70 70 PROD1 RPEQPI PULD P At surface,flow check, LD BHA#2. PU/MU BHA#3 Whipstock assembly. 20:00 22:45 2.75 70 8,524 PROD1 RPEQP1TRIP P RIH w/BHA#3 Whipstock,open EDC,Continue in hole,log GR tie-in, +3'correction.Continue in hole, PUW @ 8,450'42K.Continue in hole,tag top of AVA @ 8,524'. PUH 10', PUW 42K. 22:45 23:15 0.50 8,524 8,524 PROD1 RPEQP1WPST P RBIH to 8,524'whipstock tray oriented to high side,tag AVA, PU .5'of slack,close EDC,pump online @.5 bpm,set WS @ 3,700 psi,pull free,top of WS 8,513'. 23:15 00:00 0.75 8,524 5,000 PROD1 RPEQP1TRIP P POOH w/BHA#3 • Page 2 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/11/2013 24 hr Summary POOH W/BHA#3, LD WS setting tool assembly.PU/MU BHWA#4, RIH milling assembly to dry tag on WS @ 8,513',time mill tubing window,ream and dry drift window, looks good. POOH. LD milling assembly. PU BHA#5, RIH w/Camera assembly @ 5,000'swap from biozan to SW,biozan not clear enough. Pumped 120 bbls SW,continue in hole with camera to 8,517',downward shot still not clear,good side angle view. Video survey in progress. 00:00 01:30 1.50 5,000 78 PROD1 RPEQP1TRIP P Continue OOH with BHA#3,on surface,no flow check, PJSM. 01:30 02:33 1.05 78 78 PROD1 WHPST PULD P LD BHA#3. PU/MU BHA#4 mill assembly,surface test. 02:33 05:03 2.50 78 8,513 PROD1 WHPST TRIP P RIH w/BHA#4,Tie in+3,Dry tag @ 8513.3 05:03 12:09 7.10 8,513 8,519 PROD1 WHPST MILL P Pumps on,Start time milling from 8513.2, 1.6 BPM @ 2980 PSI FS Window milling report on S Drive 12:09 13:21 1.20 8,519 8,519 PROD1 WHPST REAM P Ream window,as milled+30,-30, Dry drift looks good 13:21 15:27 2.10 8,519 71 PROD1 WHPST TRIP P Trip out of well, PUW=39K 15:27 16:27 1.00 71 0 PROD1 WHPST PULD P On Surface,flow check well,Pull BHA#4,first window mill run,Mill out @ 2.79 No Go 16:27 19:27 3.00 0 0 PROD1 WHPST PULD T Locating equipment to make camera run 19:27 19:57 0.50 0 16 PROD1 WHPST PULD P PJSM.M/U BHA#5 Camera run, Good surface test on camera 19:57 23:21 3.40 16 8,452 PROD1 WHPST TRIP P Trip in hole with camera,swap to seawater @ 5000', Bio water to dark 23:21 23:33 0.20 8,452 8,452 PROD1 WHPST TRIP P Pumped 110 BBIs seawater,Stop coil and shut down pumps to see if image will clear 23:33 00:00 0.45 8,452 8,518 PROD1 WHPST TRIP P Image never really cleared up, Bring pumps back on line and ease in hole to 8,517'. 02/12/2013 Complete video/survey log POOH. PU/RIH 2nd step Mill Run BHA.(2.8"HCC dual string fat radius mill,2 3/8" Weatherford motor w/2 deg tapered fixed bend housing).Swap hole to used Flo-Pro system.Mill thru 7" casing as per program ex_iting @ 8523'.Mill additional rathole to 8538'. Dress window as per program. 00:00 01:30 1.50 8,518 8,518 PROD1 WHPST ELOG P Continue in hole with camera to 8,517',down hole shot still not clear, shut down pump,check for clarity, decide to switch to clean FW. Pump FW,starting to see clearer fluid at camera,continue pumping 2 bpm. 01:30 02:30 1.00 8,518 8,450 PROD1 WHPST ELOG T Lost singal to camera,troubleshoot problem, PUH. Found lose wire connection at putz junction, have singal again. 02:30 04:45 2.25 8,450 8,518 PROD1 WHPST ELOG P Continue video survey through whipstock,up and down passes, side/down angle,pumping clean FW @ 1-2 bpm,till FW gone. 04:45 06:45 2.00 8,518 8 PROD1 WHPST TRIP P POOH w/camera assembly,swap fluid to used flo-pro. 06:45 08:30 1.75 8 8 PROD1 WHPST PULD P On surface with camera, PJSM,flow check. LD BHA, RD EV camera equipment.MU BHA#6. Page 3 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 8 8 PROD1 WHPST PULD T Wait on Weatherford motor and rep, temp.stuck behind rig move. 09:15 10:15 1.00 8 8 PROD1 WHPST PULD P PJSM.MU Weatherford motor and mill assembly. 10:15 12:45 2.50 8 8,518 PROD1 WHPST TRIP P RIH w/BHA#6 casing mill assembly,tie-in to K1,plus 2' correction @ 8,120', continue in hole to 8,519'. 12:45 17:30 4.75 8,518 8,523 PROD1 WHPST MILL P Start time milling at 8519'as per schedule @ 1.45 bpm 4036 psi. 15 ROHS 17:30 21:45 4.25 8,523 8,538 PROD1 WHPST MILL P Exit 7"casing 8522.5'.Cont milling 1 fph, 15 deg ROHS 21:45 00:00 2.25 8,538 8,538 PROD1 WHPST MILL P TD rathole 8538'. Dress window reaming up and down from the WS face 2'below the window.All passes down at milled TF.2 up passes at 30 ROHS.Excessive motor work on 1st pass at 30 ROHS.Second pass looked good.Make one pass 60 _ ROHS. 02/13/2013 POOH/Undeploy BHA 6,2nd window mill run. Mill gauged 2.79 No-Go,2.80 Go. Deploy build BHA 7(1.2 ako,3.25"Bi-Center bit), RIH.+12.5'depth correction.Drill/Land build @ 8600'. POOH. Undeploy BHA 7, Deploy BHA 8(.8 ako,3.25"Bi-Center bit). RIH. +38'depth correction.Change out depth counter.Correlate depth-1'correction.Circulate well to new drilling mud 9.6ppg FloVis. Log RA marker.TOWS 8512, RA tag 8519,BOW 8523'. Drill"A"lateral. 00:00 00:15 0.25 8,538 8,538 PROD1 WHPST MILL P Drift window, looked good 00:15 02:15 2.00 8,538 0 PROD1 WHPST TRIP P POOH 02:15 02:30 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 02:30 04:15 1.75 0 0 PROD1 WHPST PULD P Undeploy BHA 6,Mill Gauged 2.79 No-Go,2.80-Go 04:15 04:30 0.25 0 0 PROD1 DRILL SFTY P PJSM 04:30 05:45 1.25 0 0 PROD1 DRILL PULD P Deploy BHA 7 05:45 08:36 2.85 0 8,538 PROD1 DRILL TRIP P RIH w/BHA#7,Tie-in to K1,+12 correction @ 8,120'. RIH, hanging up past the window, PUH to check tie-in, no correction, RBIH to 8,538'. 08:36 10:45 2.15 8,538 8,600 PROD1 DRILL DRLG P Drill build section, pump @ 1.55 bpm 4,125 psi, DHWOB=1.6K, ROP=30, PUW=36K. 10:45 13:30 2.75 8,600 0 PROD1 DRILL TRIP P POOH w/BHA#7,open EDC, continue OOH. 13:30 17:00 3.50 0 0 PROD1 DRILL PULD P At surface, PJSM, PUD BHA#7, function test BOPE and service rig, swap motor and bit. PD BHA#8. 17:00 19:00 2.00 72 8,106 PROD1 DRILL TRIP P RIH w/BHA#8 19:00 19:45 0.75 8,106 8,106 PROD1 DRILL DLOG P Tie in depth to K1 marker.Missed mark on first two attempts.+38' correction.Corrections getting increasingly more with previous tie in +12.5'correction. Inspection of counter shows to be extremely greased up with friction wheel wear. Page 4 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 19:45 20:30 0.75 8,106 8,400 PROD1 DRILL CIRC P RIH to 8400'. Park CT circulate well to new drilling mud system.Change out BHI counter. 20:30 21:00 0.50 8,400 8,106 PROD1 DRILL DLOG P PU to K1 marker log GR tie in. minus 1'correction.Overpull at 8294',#2 GLM. 21:00 21:45 0.75 8,106 8,600 PROD1 DRILL TRIP P Close EDC, RIH to TD.Small weight bobble at bottom of window.300lbs wob. Log RA marker. TOWS 8512' RA 8519' BOW 8523' 21:45 00:00 2.25 8,600 8,670 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm,3950 ctp,4090 bhp,open choke, 17k ctw, 02/14/2013 Drill A Lateral,pumping low/high Vis sweeps with wiper trips back to window after 150'drilled.3-4brl per hour losses starting at 9326' 00:00 03:00 3.00 8,670 8,740 PROD1 DRILL DRLG P Cont.drilling 1.42 bpm,3800 ctp, 4120 bhp,50 whp, 16k ctw 03:00 03:09 0.15 8,740 8,550 PROD1 DRILL WPRT P Wiper trip to window,37k CTW 03:09 03:18 0.15 8,550 8,740 PROD1 DRILL WPRT P RBIH 03:18 05:54 2.60 8,740 8,800 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm,3870 ctp,4144 bhp, 18k ctw.Geo wants to land deep. PUW=42K. RBIH 05:54 08:06 2.20 8,800 8,890 PROD1 DRILL DRLG P Continue drilling ahead 1.44 bpm, 3860 ctp, 16k ctw, ROP=42. 08:06 08:36 0.50 8,740 8,890 PROD1 DRILL WPRT P Wiper trip to window,39k CTW 08:36 09:21 0.75 8,890 8,920 PROD1 DRILL DRLG P Drill Ahead 1.43 bpm,3860 ctp,4156 bhp, 17.5k ctw, ROP=45.Geo> come up to 91 deg. 09:21 11:33 2.20 8,920 9,040 PROD1 DRILL DRLG P Drill ahead 1.45 bpm,3830 ctp,4170 bhp, 17k ctw, ROP=32. 11:33 12:33 1.00 9,040 9,040 PROD1 DRILL WPRT P Wiper trip to window,37k CTW 12:33 13:48 1.25 9,040 9,090 PROD1 DRILL DRLG P Drill ahead 1.45 bpm,3600 ctp,4176 bhp, 18.5k ctw. Started seeing high differental psi,free spin 580. 13:48 14:03 0.25 9,090 9,090 PROD1 DRILL WPRT P PUH to clear bit,decrease diff. pressure, RBIH.Will drill ahead to next wiper trip. 14:03 15:48 1.75 9,090 9,190 PROD1 DRILL DRLG P Drill ahead 1.44 bpm,3750 ctp,4140 bhp, 17k ctw, ROP=80. 15:48 16:20 0.54 9,190 9,190 PROD1 DRILL WPRT P Wiper trip to window,37k CTW, pump five barrel to/hi vis sweep. 16:20 19:20 3.00 9,190 9,326 PROD1 DRILL DRLG P Drill ahead 1.44 bpm,3860 ctp,4170 bhp, 18k ctw, ROP=60. 19:20 19:50 0.50 9,326 9,340 PROD1 DRILL DRLG P .10 bpm losses. Ratty drilling. Cont. Drilling ahead 19:50 20:20 0.50 9,340 8,560 PROD1 DRILL WPRT P Wiper trip to window 35k puw. Chasing low/high vis sweeps. Increase of cuttings when high vis sweep at surface 20:20 20:59 0.66 8,560 9,340 PROD1 DRILL WPRT P RBIH 20:59 23:59 3.00 9,340 9,457 PROD1 DRILL DRLG P Drill ahead 1.45 bpm,3600 ctp,4190 bhp, 17k ctw Page 5 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/15/2013 24 hr Summary Drill A lateral,pumping low/high Vis sweeps with wiper trips.Swap out drilling mud.24hr loses:84 brls to formation. 00:00 01:30 1.50 9,457 9,490 PROD1 DRILL DRLG P Drill Ahead 1.44 bpm in, 1.34 out, 3950 ctp,4185 bhp, 16k ctw,50 whp 01:30 02:00 0.50 9,490 8,519 PROD1 DRILL WPRT P Wiper trip to window 35k puw, chasing 5brl low/high sweeps. 02:00 02:15 0.25 8,519 8,519 PROD1 DRILL DLOG P Log RA marker,+1.5'correction. 02:15 02:45 0.50 8,519 9,490 PROD1 DRILL WPRT P RBIH 02:45 06:06 3.35 9,490 9,640 PROD1 DRILL DRLG P Drill ahead 1.45 bpm in, 1.35 out, 3950 ctp,4210 bhp, 18k ctw.Couple stalls in last hour of drilling,starting to loss 3-4 bph. 06:06 07:15 1.15 9,640 9,640 PROD1 DRILL WPRT P Wiper trip to window 36k puw 07:15 10:51 3.60 9,640 9,790 PROD1 DRILL DRLG P Drill ahead 1.44 bpm,3825 ctp,4245 bhp, 17k ctp, ROP=40.Still losing 3-4 bph.GEO>hold 89-90 degree. 10:51 12:03 1.20 9,790 9,790 PROD1 DRILL WPRT P Wiper trip to window 37k puw,log ra +2'correction 12:03 15:03 3.00 9,790 9,940 PROD1 DRILL DRLG P Drill ahead 1.45 bpm,4025 ctp,4250 bhp, 16k ctp, ROP=55.Still losing 3-4 bph.GEO>drop to 93 degree and hold.At 9,855 GEO>build to 97-98 degree 15:03 16:36 1.55 9,940 9,940 PROD1 DRILL WPRT P Wiper trip to window 37k puw, chasing 5brl low/high sweeps. 16:36 20:06 3.50 9,940 10,068 PROD1 DRILL DRLG P Drill ahead 1.44 bpm,3875 ctp,4248 bhp, 15k ctp, ROP=50,losing 4 bph. 20:06 21:36 1.50 10,068 8,550 PROD1 DRILL WPRT P Pull wiper trip early,stacking.Swap out drilling mud system. 21:36 22:21 0.75 8,550 10,068 PROD1 DRILL WPRT P RBIH,set down at 8790', PU.Clean pick up.Cont. RIH 22:21 00:00 1.65 10,068 10,130 PROD1 DRILL DRLG P Drill ahead 1.55 bpm,3865 ctp,4206 bhp, 136 whp, 02/16/2013 Drill A lateral,pumping low/high Vis sweeps with wiper trips.24hr loses: 54 brls to formation. 00:00 02:30 2.50 10,130 10,240 PROD1 DRILL DRLG P Cont drilling 20-60 fph, 1.5 bpm, 1.45 out,3964 ctp,4250 bhp. 02:30 03:45 1.25 10,240 8,550 PROD1 DRILL WPRT P Wiper trip 36k puw.chasing 5brl low/high sweeps 20-25 fpm. 03:45 04:15 0.50 8,550 10,240 PROD1 DRILL WPRT P RBIH,36 fpm 04:15 08:30 4.25 10,240 10,390 PROD1 DRILL DRLG P Drill ahead 1.58 bpm, 1.49 out,3990 ctp,4235 bhp, 127 whp. 08:30 10:30 2.00 10,390 10,390 PROD1 DRILL WPRT P Wiper trip 36k puw. 10:30 13:30 3.00 10,390 10,493 PROD1 DRILL DRLG P Drill ahead 1.57 bpm, 1.48 out,4130 ctp,4276 bhp, 118 whp.Stuck pipe on btm @ 10,493',work pipe,shut down pump and relax pipe for 30 min,got back some WOB,work pipe,pulled free at 48K, make BHA wiper trip. RBIH. 13:30 14:45 1.25 10,493 10,540 PROD1 DRILL DRLG P Drill ahead 1.57 bpm, 1.47 out,4087 ctp,4256 bhp, 110 whp. 14:45 16:45 2.00 10,540 10,540 PROD1 DRILL WPRT P Wiper trip to window,35k puw. Page 6 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:45 21:00 4.25 10,540 10,690 PROD1 DRILL DRLG P Drill ahead 1.57 bpm, 1.52 out,3892 ctp,4280 bhp,52 whp, 16.2k cw. 21:00 22:30 1.50 10,690 8,550 PROD1 DRILL WPRT P Wiper trip to window,35k puw. Chasing 5/5 low/high sweeps.Small overpull at 8765&pressure increase. 22:30 23:30 1.00 8,550 10,690 PROD1 DRILL WPRT P RBIH, Drop pump rate thru 8765-8790'.Have seen this area on wiper trips nearly everytime. 23:30 00:00 0.50 10,690 10,730 PROD1 DRILL DRLG P Drill Ahead 1.52 bpm in, 1.45 out, 4040 ctp,4298 bhp,80 whp, 16k ctw, 02/17/2013 Drill A lateral,pumping low/high Vis sweeps with wiper trips back to window.Swap out drilling mud.24hr loses: 56 brls to formation. 00:00 02:00 2.00 10,730 10,840 PROD1 DRILL DRLG P Cont. Drilling Ahead 1.50 bpm in, 1.45 out,4046 ctp,4300 bhp, 80 whp, 16k ctw, 02:00 03:30 1.50 10,840 8,550 PROD1 DRILL WPRT P Wiper trip to window 34k puw. Chasing 5x5 Low/high vis sweeps 8750'slight overpull,6501bs on WOB,with pressure spike.Cont. POOH for wiper 03:30 04:30 1.00 8,550 10,840 PROD1 DRILL WPRT P Log RA marker+2'correction, RBIH. Drop pump rate.6 bpm thru 8750 area. Small set down 700lbs WOB, _ cont. RIH 04:30 08:42 4.20 10,840 10,990 PROD1 DRILL DRLG P Drill ahead 1.47 bpm,4063 ctp,4256 bhp,40 whp, 15.5 ctw. 08:42 10:54 2.20 10,990 10,990 PROD1 DRILL WPRT P Wiper trip to window 35k puw. Chasing 5x5 Low/high vis sweeps 10:54 15:09 4.25 10,990 11,140 PROD1 DRILL DRLG P Drill ahead 1.43 bpm,3925 ctp,4339 bhp,48 whp, 15.0 ctw. Blew pop-off on pump#1,switch to pump#2, replace pop-off,continue drilling ahead.Stacked-out weight several times the last 100'or so,made several short wiper trips as well. 15:09 16:39 1.50 11,140 8,550 PROD1 DRILL WPRT P Wiper trip to window 35k puw. Chasing 5x5 Low/high vis sweeps 16:39 17:39 1.00 8,550 11,140 PROD1 DRILL WPRT P RBIH 17:39 18:39 1.00 11,140 11,182 PROD1 DRILL DRLG P Drill ahead 1.47 bpm,4063 ctp,4256 bhp,40 whp, 15.5 ctw. 18:39 19:45 1.10 11,182 11,182 PROD1 DRILL WPRT P Stacking PU 500'wiper trip.34k Prepare to swap out mud system. 19:45 23:00 3.25 11,182 11,320 PROD1 DRILL DRLG P Drill ahead tuff drilling.stacking 20-30 fph.send new mud downhole. New mud at bit 11190'. ROP improved 60-80 fph,Cont.drilling ahead 1.55 bpm in, 1.45 out,4003 ctp,4345 bhp,start applying choke psi on MP choke. 100 whp. 23:00 23:30 0.50 11,320 10,600 PROD1 DRILL WPRT P Wiper trip 35k puw. PU looked good. Chase 5x5 low/high sweeps OOH. Once sweeps at surface. RBIH to drill 50'for possible TD. Page 7 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 23:45 0.25 10,600 11,320 PROD1 DRILL WPRT P RBIH 23:45 00:00 0.25 11,320 11,328 PROD1 DRILL DRLG P Drill ahead 1.48 bpm in, 1.44 bpm out,4127 ctp, 156 whp,4350 bhp, 14k ctw, 1.6 wob. Looking for the A3 to call TD. 02/18/2013 TD A lateral 11377'. Pump 10x10 brls sweeps. POOH to swab valves. RBIH,Tag 8772-8784'.Work pipe up and down cleaning up troubled area.Cont.RIH to TD.POOH lay in high vis 12.2ppg NaBr completion fluid with 2ppb beads up into tubing,without beads to surface.Flow check, LD BHA. PU/MU/RIH 55jnts 2 3/8" Slotted liner with deployment sleeve. Unable to get liner past 8789'.Multiple attempts failed.POOH. 00:00 01:00 1.00 11,328 11,373 PROD1 DRILL DRLG P Drill ahead 1.48 bpm in, 1.44 bpm out,4127 ctp, 156 whp,4350 bhp, 14k ctw, 1.6 wob. Looking for the A3 to call TD. Pump 5x5 sweeps. Increase of cuttings at surface. Drilling ahead,with stalls,slip sticking,stacking,problems sliding. 01:00 01:30 0.50 11,373 11,300 PROD1 DRILL WPRT P A3 formation confirmed with Geo on Res&Gamma. Pump 10x10 sweeps.TD"A"Lateral.PU slow waiting for sweeps to exit bit.35k puw. 01:30 06:00 4.50 11,300 0 PROD1 DRILL WPRT P POOH to swap valves chasing sweeps OOH.Open EDC in casing, Cont.POOH 1.7 bpm in, 1.43 bpm out,following MP 06:00 11:00 5.00 0 11,377 PROD1 DRILL WPRT P RBIH. Log K1,did not come in.PUH. Re-log K1,+23 correction.Check counter looks OK. RIH,close EDC. RIH @ 8,830'started setting down, packing off,work pipe.Wiper up hole,RBIH,stacked-out twice more @ 8,772'and 8,784',work pipe, reduce pump rate, rotate BHA.RBIH, no problems,tag TD @ 11.377'. 11:00 13:30 2.50 11,377 0 PROD1 DRILL TRIP P POOH laying in completion fluid with beads to window,continue OOH laying in completion fluid. Paint flags @ 6,500'and 8,928',continue POOH. 13:30 17:00 3.50 0 0 PROD1 DRILL PULD P At surface,flow check, PJSM. Break off injector, LD BHA.Top drive moving slowly due cold weather, service injector and top drive. 17:00 21:00 4.00 0 1,881 COMPZ CASING PUTB P PJSM. PU/MU/lower liner assembly: Short deployment sleeve,55 jts slotted liner,bull nose(non-ported). Surface test, 21:00 23:30 2.50 1,881 8,381 COMPZ CASING RUNL P RIH w/BHA#9 23:30 23:45 0.25 8,381 8,789 COMPZ CASING RUNL P Correct depth to EOP flag.+16.5' correction.Close EDC.Weight check 41k puw, 19k rihw.Cont. RIH. Window looked, no weight bobbles. RIH thru window 20 fpm 23:45 00:00 0.25 8,789 8,789 COMPZ CASING RUNL T Increase 50-60 fpm.Tag 8789'. Page 8 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/19/2013 24 hr Summary LD liner,M/U and RIH with clean out BHA with a.8°motor bend and a D331 mill.Tag up at the transition area from the A6 to the A5.Work Coil through area with a 70°Left tool face-back reaming.Clean out A lateral down to 10700ft. 00:00 00:30 0.50 8,789 8,789 COMPZ CASING RUNL T Multiple attempts to push liner in hole. 10fpm to 70 fpm, Hard tag everytime.Clean pickups 40-45k, RIH to OK CT surface weight hitting tag 8789'at 60fpm. Hold in compression. Liner will go down. 00:30 01:30 1.00 8,789 8,789 COMPZ CASING RUNL T Pick up into casing clean pickup 45k.Consult with town. Pump down backside 250psi whp, RIH attempt to push liner past 8789'. No luck..3 bpm injectivity when pressure up backside. Decision to POOH 01:30 03:00 1.50 8,789 0 COMPZ CASING RUNL T POOH 03:00 03:15 0.25 0 0 COMPZ CASING SFTY T At surface. Flow check, PJSM 03:15 04:15 1.00 0 0 COMPZ CASING PUTB T LD BHA. 04:15 07:45 3.50 0 0 COMPZ CASING PUTB T Prep floor and pipe shed to lay down liner. 07:45 11:15 3.50 0 0 COMPZ CASING PUTB T LD 55 jnts liner 11:15 11:45 0.50 0 0 COMPZ CASING SVRG T Clean up rig floor 11:45 12:00 0.25 0 0 COMPZ CASING SFTY T PJSM,PU BHA 12:00 13:00 1.00 0 0 COMPZ CASING PULD T PU/MU BHA 10.(.8 ako, DSM 331 w/sidecutters) 13:00 14:45 1.75 62 8,090 COMPZ CASING TRIP T RIH w/open EDC 14:45 15:00 0.25 8,090 8,140 COMPZ CASING DLOG T 8090ft-Tie into K1 marker for a correction of plus 16ft 15:00 15:15 0.25 8,140 8,480 COMPZ CASING TRIP T 8140ft-ContinueRlH 15:15 16:15 1.00 8,480 8,480 COMPZ CASING CIRC T 8480ft-Displace KWF 16:15 17:00 0.75 8,480 8,768 COMPZ CASING TRIP T 8480ft-Close EDC and continue RIH 17:00 19:30 2.50 8,768 8,783 COMPZ CASING WPRT T 8768ft-Tag up and work pipe 19:30 19:45 0.25 8,783 8,815 COMPZ CASING WPRT T Change Tool face to 70°Left,made it through bad spot 19:45 20:30 0.75 8,815 10,700 COMPZ CASING WPRT T Continue RIH smoothly to 10700ft 20:30 21:15 0.75 10,700 8,815 COMPZ CASING WPRT T 10700ft-PUH to bad spot 21:15 22:15 1.00 8,815 8,750 COMPZ CASING REAM T Back ream bad area, looks clean on the up pass 22:15 23:15 1.00 8,750 8,776 COMPZ CASING REAM T RIH tag at 8776ft 23:15 00:00 0.75 8,776 8,815 COMPZ CASING REAM T Work pipe down and ream from 8815ft-8750.0 02/20/2013 POOH. Undeployed Clean out BHA. Deployed Anchored Billet setting BHA. RIH and set TOB at 8625ft. POOH and Undeploy billet setting BHA. Flush BOPE and rig lines for BOPE testing. 00:00 01:45 1.75 8,815 8,776 COMPZ CASING WPRT T Work bad area from 8750ft-8815ft 01:45 02:00 0.25 8,776 8,776 COMPZ CASING WPRT T Make call to town for plan forward. Page 9 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:00 04:00 2.00 8,776 8,776 COMPZ CASING WPRT T Try and work through tight spot with no sucess., Pull heavy thru window. RBIH thru window. PU clean thru window 04:00 07:00 3.00 8,776 0 COMPZ CASING WPRT T POOH 07:00 07:15 0.25 0 0 COMPZ CASING SFTY T PJSM 07:15 10:45 3.50 0 0 COMPZ CASING PULD T Undeploy BHA. Unable to bleed pressure down once deployment rams closed.Open rams,Flush stack. Large amounts of shale across shakers.Attempt to Undeploy.Still cannot bleed psi. Equilize and close EDC.Attempt to undeploy.All good. Problem: FVS not holding in BHA.Cont.to undeploy with EDC closed. Utilize double ball valves for double isolation from well. 10:45 12:15 1.50 0 0 PROD2 STK PULD P Deploy BHA 11.Anchored Billet 12:15 14:30 2.25 72 8,106 PROD2 STK TRIP P RIH,start pumping new mud down to bit. 14:30 14:45 0.25 8,106 8,106 PROD2 STK DLOG P Tie in depth to K1,+14'correction 14:45 15:00 0.25 8,106 8,636 PROD2 STK TRIP P Record up weight 34k,puw.RIH to set depth 15:00 15:15 0.25 8,636 8,636 PROD2 STK ANCR P Set billet 210 deg,single slip. 8626 TOB.Good set 4100psi,set down 2k. 15:15 18:00 2.75 8,636 0 PROD2 STK TRIP P POOH displacing well to new mud. 18:00 18:15 0.25 0 0 PROD2 STK SFTY P OOH, PJSM for undeploying BHA 18:15 21:00 2.75 0 0 PROD2 STK PULD P Undeploy Billet setting BHA and remove and inspect checks 21:00 21:30 0.50 0 0 PROD2 STK BOPE P Flush BOP stack, rig lines,and PJSM for BOPE testing 21:30 00:00 2.50 0 0 PROD2 STK BOPE P Prep for BOPE test 32/21/2013 Finish BOPE test with no failures. Deploy Kick off BHA with 1.0°AKO motor and bi-center bit. RIH,Tie in,and Kick off of billet at 8625ft. 00:00 09:00 9.00 0 0 PROD2 STK BOPE P Start Testing BOPE.Witness Waived:John Crisp 09:00 09:45 0.75 0 0 PROD2 STK SVRG P Complete testing.Clean up floor. service inj, reel. 09:45 10:00 0.25 0 0 PROD2 STK SFTY P PJSM 10:00 11:30 1.50 0 0 PROD2 STK PULD P Deploy BHA 12 11:30 13:30 2.00 72 8,180 PROD2 STK TRIP P RIH 13:30 14:00 0.50 8,180 8,180 PROD2 STK DLOG P Tie in depth to K1.+30'correction. Inspect counter. Looked fine 14:00 14:15 0.25 8,180 8,625 PROD2 STK TRIP P RIH, log RA marker 0 correction. Cont. RIH 14:15 14:30 0.25 8,625 8,625 PROD2 STK KOST P Dry tag TOB 8625'. PU 35k puw Page 10 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 17:00 2.50 8,625 8,636 PROD2 STK KOST P Start milling billet as per program. 1.56 bpm,3691 ctp,20k ctw,4068 bhp,.5k wob 17:00 18:00 1.00 8,636 8,660 PROD2 DRILL DRLG P 8636ft-Drill Ahead 1.54 bpm at 3820psi BHP 4784,WHP 96 2k WOB 16k coil surface weight 18:00 18:30 0.50 8,660 8,620 PROD2 DRILL WPRT P 8660ft-PUH and dry drift billet area PUW 35k 18:30 19:00 0.50 8,620 8,660 PROD2 DRILL WPRT P 8620ft-RBIH to drill ahead RIW 16k 19:00 21:30 2.50 8,660 8,775 PROD2 DRILL DRLG P 8660ft-Drill Ahead 21:30 22:00 0.50 8,775 8,640 PROD2 DRILL WPRT P 8775ft-Wiper to the bottom of billet 8640ft PUW 40k 22:00 22:30 0.50 8,640 8,775 PROD2 DRILL WPRT P 8640ft-Wiper back in hole RIW 15k 22:30 00:00 1.50 8,775 8,838 PROD2 DRILL DRLG P 8775ft-BOBD 1.43 bpm at 3430psi BHP 4684,WHP 91 WOB 3K, ROP 31fph 14k coil surface weight 02/22/2013 Drilled AU laterat with 3.2500 bi-center bit.Wipers every 150ft drilled to the bottom of the A5 shale transition and to the window on tie in wipers. Pumping sweeps every wiper to keep hole clean. 00:00 02:00 2.00 8,838 8,925 PROD2 DRILL DRLG P 8838ft-OBD 1.43bpm at 3450psi BHP 4152,WHP 120 WOB 1.7k, ROP 40 fph 14k coil surface weight 02:00 02:15 0.25 8,925 8,640 PROD2 DRILL WPRT P 8925ft-Wiper to the bottom of billet PUW 40k 02:15 02:30 0.25 8,640 8,925 PROD2 DRILL WPRT P 8640ft-Wiper back in hole RIW 15k 02:30 05:30 3.00 8,925 9,075 PROD2 DRILL DRLG P 8925ft-BOBD 1.41 bpm at 3450psi BHP 4180,WHP 101 WOB 1.4k, ROP 63fph 15k coil surface weight 05:30 06:00 0.50 9,075 8,500 PROD2 DRILL WPRT P Wiper trip back to window.Tie in depth.+.5'correction. 06:00 06:30 0.50 8,500 9,075 PROD2 DRILL WPRT P RBIH 06:30 09:15 2.75 9,075 9,225 PROD2 DRILL DRLG P Drill ahead 1.54 bpm,4049 ctp,23 whp,4170 bhp 09:15 09:42 0.45 9,225 8,750 PROD2 DRILL WPRT P Wiper trip back to 8750,staying below shales 09:42 10:03 0.35 8,750 9,225 PROD2 DRILL WPRT P RBIH 10:03 12:42 2.65 9,225 9,375 PROD2 DRILL DRLG P Drill ahead 1.54 bpm,4049 ctp,23 whp,4170 bhp 12:42 13:12 0.50 9,375 8,750 PROD2 DRILL WPRT P Wiper trip back to 8750'.36k puw 13:12 13:42 0.50 8,750 9,375 PROD2 DRILL WPRT P RBIH 13:42 16:12 2.50 9,375 9,525 PROD2 DRILL DRLG P Drill ahead 1.53 bpm,4050 ctp,4167 bhp,open choke. 16:12 16:57 0.75 9,525 8,520 PROD2 DRILL WPRT P Wiper trip to window,37k puw. 16:57 17:12 0.25 8,520 8,568 PROD2 DRILL WPRT P Log RA marker+2ft correction. Page 11 of 30 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 17:12 17:57 0.75 8,568 9,525 PROD2 DRILL WPRT P RBIH RIW 21k 17:57 21:00 3.06 9,525 9,675 PROD2 DRILL DRLG P BOBD 1.54bpm at 3830psi BHP 4227,WHP 0 WOB 2.2k, ROP 35fph 13k Coil surface weight 21:00 21:30 0.50 9,675 8,750 PROD2 DRILL WPRT P Wiper trip up to 8750ft 21:30 21:59 0.49 8,750 9,675 PROD2 DRILL WPRT P 8750ft-wiper back in hole RIW 14k 21:59 23:59 2.00 9,675 9,782 PROD2 DRILL DRLG P 9675ft-BOBD 1.51 bpm at 3853psi BHP 4212,WHP 0 WOB 2k, ROP 38fph 13k coil surface weight XXXXX Lost 17bbls last 24hrs 32/23/2013 Drilled AL1 lateral.pumping sweeps every wiper.Swapped mud at 10075ft. Previous system had 1149'with 0.65%drilled solids.Lost 18 bbls to formation in the last 24hrs. 00:00 01:15 1.25 9,782 9,825 PROD2 DRILL DRLG P 9782ft-Drilling Ahead 1.49bpm at 3830psi BHP 4233,WHP 0 WOB 1.5k, ROP 55fph 13k coil surface weight 01:15 02:00 0.75 9,825 8,750 PROD2 DRILL WPRT P 9825ft-Wiper up to 8750ft PUW 40k 02:00 02:30 0.50 8,750 9,825 PROD2 DRILL WPRT P 8750ft-Wiper back in hole RIW 02:30 06:00 3.50 9,825 9,975 PROD2 DRILL DRLG P 9825ft-BOBD 1.48bpm at 3835psi BHP 485,WHP 0 WOB 1.8k, ROP 52 fph 10k coil surface weight 06:00 07:00 1.00 9,975 8,500 PROD2 DRILL WPRT P Wiper trip to window.45k intial PU weight,breaking back to 36k for wiper trip. Large increase on density out when sweeps at surface 07:00 08:00 1.00 8,500 9,975 PROD2 DRILL DLOG P Log RA marker+6'correction. RBIH 08:00 11:00 3.00 9,975 10,060 PROD2 DRILL DRLG P Drill Ahead 1.43 bpm,4250 ctp,8k ctw,4240 bhp 11:00 12:00 1.00 10,060 10,080 PROD2 DRILL DRLG P Start sending new mud down.Cont. drilling ahead 12:00 12:45 0.75 10,080 10,125 PROD2 DRILL DRLG P Mud to surface.Weight check 37k puw.Cont.drilling ahead 1.4 bpm, 3930 ctp,4260 bhp, 15k ctw 12:45 13:45 1.00 10,125 8,750 PROD2 DRILL WPRT P Wiper trip 36k puw. PU weights much better. 13:45 14:45 1.00 8,750 10,125 PROD2 DRILL WPRT P RBIH 14:45 16:00 1.25 10,125 10,180 PROD2 DRILL WPRT P Drill Ahead 1.5 bpm,4313 ctp,4200 bhp, 15k ctw 16:00 18:00 2.00 10,180 10,275 PROD2 DRILL DRLG P Attempt to swap pumps. Unable to catch prime.Cont drilling 1.44 born, 4063 ctp,43 whp,4191 18:00 19:00 1.00 10,275 8,750 PROD2 DRILL WPRT P Wiper up to 8750ft PUW 36k 19:00 19:30 0.50 8,750 10,275 PROD2 DRILL WPRT P Wiper back in hole RIW 18k Page 12 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:30 22:00 2.50 10,275 10,394 PROD2 DRILL DRLG P 10275ft-BOBD 1.46bpm at 3800psi BHP 4239,WHP 96 IA 448,OA 0 WOB 2.7k, ROP 53fph 12k coil surface weight 22:00 22:15 0.25 10,394 10,294 PROD2 DRILL WPRT P BHA Wiper 22:15 22:30 0.25 10,294 10,394 PROD2 DRILL WPRT P Wiper back to bottom 22:30 23:30 1.00 10,394 10,425 PROD2 DRILL DRLG P 10294ft-BOBD 1.54bpm at 3805psi, BHP 4278,WHP 106,WOB 498, ROP 36 23:30 00:00 0.50 10,425 9,611 PROD2 DRILL WPRT P Wiper up to the window for a tie in chasing sweep. PUW X2/24/2013 Drilled AL1 lateral. Pumping sweeps every wiper. Lost 9 bbls to formation in the last 24hrs. 00:00 00:30 0.50 9,611 8,540 PROD2 DRILL WPRT P Continue wiper up to the window for a tie in 00:30 00:45 0.25 8,540 8,568 PROD2 DRILL DLOG P Tie into RA marker correction of+8ft. 00:45 01:30 0.75 8,568 10,425 PROD2 DRILL WPRT P Wiper back in hole RIW 16k 01:30 04:30 3.00 10,425 10,575 PROD2 DRILL DRLG P 10425ft-BOBD 1.49bpm at 3805psi BHP 4249 ,WHP 111 IA 437,OA 0 WOB 1.8 , ROP 54fph 10k Coil surface weight 04:30 05:30 1.00 10,575 8,750 PROD2 DRILL WPRT P Wiper up hole to 8750ft. PUW 38k 05:30 06:15 0.75 8,750 10,575 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 06:15 08:45 2.50 10,575 10,725 PROD2 DRILL DRLG P BOBD 1.46bpm at 3754,BHP 08:45 09:15 0.50 10,725 9,575 PROD2 DRILL WPRT P Wiper trip back 1150'.37k puw. Chasing sweeps 5x5 low/high sweeps. Increase on density on bottoms up after intial PU 09:15 09:45 0.50 9,575 10,725 PROD2 DRILL WPRT P RBIH 09:45 13:00 3.25 10,725 10,875 PROD2 DRILL DRLG P Drill Ahead 1.44 bpm,4303 ctp, 132 whp,4315 bhp. 13:00 14:00 1.00 10,875 8,500 PROD2 DRILL WPRT P Wiper trip to window.35K puw chasing sweeps OOH.Increase in mud density on out MM when sweeps to surface. 14:00 14:45 0.75 8,500 10,875 PROD2 DRILL WPRT P Log RA marker.+6.5'correction,. RBIH 14:45 15:30 0.75 10,875 10,909 PROD2 DRILL DRLG P Drill Ahead 1.5 bpm,4290 ctp, 100 whp,4300 bhp 15:30 15:45 0.25 10,909 10,946 PROD2 DRILL DRLG P Sticky pick up,-3.8k. Drilling Ahead 1.5 bpm at 3851psi.WHP 98, BHP 4339 15:45 16:30 0.75 10,946 10,946 PROD2 DRILL DRLG P Temporarily detained stuck below WOB sensor. Looks like differentually stuck.Stack down on bottom.Shut in choke,shut down pump and let relax. 16:30 17:15 0.75 10,946 10,846 PROD2 DRILL WPRT P Pulled free at 51k. BHA wiper. Page 13 of 30 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 17:15 17:30 0.25 10,846 10,946 PROD2 DRILL WPRT P RBIH to drill ahead. 17:30 19:15 1.75 10,946 11,025 PROD2 DRILL DRLG P BOBD 1.50bpm at 3856psi BHP 4335,WHP 100 WOB 1.8k, ROP 75fph IA 616,OAO 5k Coil surface weight 19:15 20:30 1.25 11,025 8,750 PROD2 DRILL WPRT P Wiper up hole to 8750ft. PUW 41k 20:30 21:15 0.75 8,750 11,025 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 21:15 23:45 2.50 11,025 11,190 PROD2 DRILL DRLG P 11025ft-BOBD 1.43bpm at 3760 BHP 4304 ,WHP 64 WOB 1.4k , ROP 80fph IA 617,OAO 14k coil surface weight 23:45 00:00 0.25 11,190 11,000 PROD2 DRILL WPRT P Wiper up to 8750ft PUW 37k 02/25/2013 Drilled AL1 lateral to TD 11500ft. Perform wiper to the swab valves.RBIH,Tied into the K1 correction of+15ft. POOH laying in 12.2 ppg completion fluid with alpine beads in open hole and without beads from window up to surface. 00:00 01:00 1.00 11,000 8,750 PROD2 DRILL WPRT P Continue Wiper up to 8750ft 01:00 02:00 1.00 8,750 11,190 PROD2 DRILL WPRT P 8750ft-Wiper back in hole.RIW 18k 02:00 05:00 3.00 11,190 11,340 PROD2 DRILL DRLG P 11190ft-BOBD BHP 4311 ,WHP 46 IA 594 ,OA O WOB 1.7k , ROP 100fph 12k coil surface weight xxxxx New Mud at 11270ft xxxxxx 05:00 07:00 2.00 11,340 8,550 PROD2 DRILL WPRT P 11340ft-Wiper up to the window for a tie in 07:00 08:00 1.00 8,550 11,340 PROD2 DRILL WPRT P Log RA marker,+5.5'correction. RBIH 08:00 12:30 4.50 11,340 11,500 PROD2 DRILL DRLG P Drill ahead 1.5 bpm,3956 ctp, 1.6k wob,4329 bhp,2k ctw,236 whp 12:30 16:00 3.50 11,500 0 PROD2 DRILL WPRT P TD Lateral 11500'.POOH to swab valves chasing 10 x 10 low/high sweeps OOH,Open EDC in cased hole. Follow MP schedule pumping 1.55bpm. Large increase of cuttings starting at 3000'. 16:00 18:30 2.50 0 8,150 PROD2 DRILL WPRT P At surface. RBIH 18:30 19:45 1.25 8,150 11,500 PROD2 DRILL DLOG P Tie in depth to RA marker Correct +15'.Close EDC RIH to TD 19:45 23:15 3.50 11,500 0 PROD2 DRILL TRIP P Tag TD 11500'. POOH laying in 12.2ppg completion fluid to window with alpine 2ppb beads,to surface without beads. Paint EOP flags 10200&7200' 23:15 23:30 0.25 0 0 PROD2 DRILL TRIP P At surface, PJSM,monitor well for flow 23:30 00:00 0.50 0 0 PROD2 DRILL PULD P LD BHA 02/26/2013 Lay down Drilling BHA#12, M/U AU Liner, 33 Jts slotted liner 2 pups and non ported bullnose with anchored billet,set BOL=11500,TOL=10371 Page 14 of 30 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 PROD2 DRILL PULD P Continue LD BHA#12 00:30 00:45 0.25 0 0 COMPZ CASING SFTY P Prep rig floor for running liner. PSJM for MU AL1 liner assy. 00:45 01:30 0.75 0 0 COMPZ CASING PUTB P Start Running AU liner assy. 01:30 01:45 0.25 0 0 COMPZ CASING SFTY P Kick while running liner drill 01:45 03:30 1.75 0 0 COMPZ CASING PUTS P Continue mu 33 jts of liner. 03:30 04:30 1.00 0 1,196 COMPZ CASING SVRG P Stab on INJH,Service coiled tubing reel. 04:30 05:00 0.50 1,196 4,587 COMPZ CASING RUNL P Open EDC, RIH with AL1 liner assy 33jts and anchored billet pumping min rate.Stop and fix shims on reel • hub. 05:00 07:00 2.00 4,587 8,369 COMPZ CASING RUNL P Continue RIH with AL1 liner assy. (AU PB1)Post Mortum 07:00 07:15 0.25 8,369 9,660 COMPZ CASING RUNL P Correct to 7200'EOP flag+21ft 07:15 07:30 0.25 9,660 9,675 COMPZ CASING DLOG P Tie into RA marker w/correction of- 4.5ft. 07:30 08:45 1.25 9,675 11,500 COMPZ CASING RUNL P Continue RIH, Pass flag 10200ft EOP flag 11388.10ft making it+ 2.5ft.Tag Bottom at 11500' 08:45 09:00 0.25 11,500 11,500 COMPZ CASING RUNL P Get up weights,set back down, bring pump up and release from liner. 09:00 12:00 3.00 11,500 0 COMPZ CASING RUNL P POOH 12:00 12:45 0.75 0 0 COMPZ CASING PULD P PJSM-Check well for flow, LD BHA 12:45 14:00 1.25 0 0 PROD3 STK CTOP P Install nozzle,Swap coil over to fresh water 14:00 15:00 1.00 0 0 PROD3 STK CTOP P Cut CTC and BHI head off. Boot eline. Pump slack. 15:00 15:30 0.50 0 0 PROD3 STK SFTY P PJSM, Prep rig floor for cutting coil 15:30 18:00 2.50 0 0 PROD3 STK CTOP P Start cutting 420ft of coil for pipe management. 18:00 18:30 0.50 0 0 PROD3 STK CTOP P Crew change out,CT trim complete 420'cut,Test E-Line all good. 18:30 21:15 2.75 0 0 PROD3 STK CTOP P Prep coil and install CTC, Pull test to 40K, Head up E-Line UQC, PT to 4400 PSI 21:15 22:00 0.75 0 0 PROD3 STK CTOP P Install Nozzle,stab on well and roll coil to 12.2PPG Completion fluid, Unstab C/O packoffs 22:00 22:30 0.50 0 0 PROD3 STK BOPE P Perform BOPE bi weekly function test 22:30 23:30 1.00 0 72 PROD3 STK PULD T PJSM,P/U BHA#14,lateral drilling, .8°AKO motor and Re Run Bi center,Stab on coil and surface test tool 23:30 00:00 0.50 72 1,845 PROD3 STK TRIP T RIH BHA#14, EDC Open 02/27/2013 Kick off liner top billet @ 10371, Drill Ahead to 10,933 00:00 01:18 1.30 1,845 8,100 PROD3 STK TRIP T Continue tripping in well BHA#14, EDC open Page 15 of 30 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01:18 01:36 0.30 8,100 8,143 PROD3 STK DLOG T Log K1 marker for+12'correction, PUW=33K,Trip in EDC open 01:36 01:48 0.20 8,143 8,460 PROD3 STK TRIP T Trip in to above window 01:48 02:36 0.80 8,460 8,460 PROD3 STK CIRC T Circulate 12.2 PPG fluid out of well, 9.6 in,Shut EDC 02:36 03:24 0.80 8,460 10,374 PROD3 STK TRIP T RIH to drill off billet, Clean pass through window,billet and shales, Dry tag @ 10374 03:24 04:06 0.70 10,374 10,375 PROD3 STK KOST T PUH and start time milling @ 10374.6, 1 FPH, 1.44 BPM @ 3450 PSI FS.Looks like BHA not moving 04:06 06:06 2.00 10,375 10,377 PROD3 STK KOST T Goto 2 FPH and slip in,4.5K DHWOB,stall, PUH, PUW=38K, RBIH to restart kick off of billet as per plan. 06:06 07:00 0.91 10,377 10,410 PROD3 DRILL DRLG T Start pushing on it 07:00 07:30 0.50 10,410 10,350 PROD3 DRILL WPRT T PUH to dry drift billet area 07:30 07:45 0.25 10,350 8,535 PROD3 DRILL WPRT T Wiper up hole and tie into RA marker 07:45 08:00 0.25 8,535 8,559 PROD3 DRILL DLOG T Tie in to RA marker correction of- 3.5ft 08:00 09:00 1.00 8,559 10,410 PROD3 DRILL WPRT T Wiper back in hole. 09:00 11:30 2.50 10,410 10,560 PROD3 DRILL DRLG T OBD 1.47bpm at 3693psi BHP 4272,WHP 53 WOB 1.3k,56fph IA 140,OA 0 14k coil surface weight 11:30 12:30 1.00 10,560 8,750 PROD3 DRILL WPRT T 10560ft-Wiper up to 8750ft PUW 38 12:30 13:30 1.00 8,750 10,560 PROD3 DRILL WPRT T 8750ft-Wiper back in hole. RIW 16k 13:30 16:00 2.50 10,560 10,710 PROD3 DRILL DRLG T 10560ft-BOBD 1.49bpm at 3730psi BHP 4282,WHP 37 WOB 1.82, ROP 80 fph IA 197,OA 0 11 k coil surface weight 16:00 17:00 1.00 10,710 10,710 PROD3 DRILL WPRT T Wiper up to 9650ft.PUW 37k 17:00 18:06 1.10 10,710 10,760 PROD3 DRILL DRLG T 10710',Drill ahead, 1.46 BPM @ 3520 PSI FS, RIW=15K, BHP=4295 18:06 18:18 0.20 10,760 10,760 PROD3 DRILL WPRT T Stacking out, Pull Mini wiper,Crew change 18:18 19:48 1.50 10,760 10,828 PROD3 DRILL DRLG T 10760',Drill Ahead, 1.4 BPM @ 3650 PSI FS, BHP=4310, RIW=11.5K, DHWOB=1.4K 19:48 21:59 2.19 10,828 10,828 PROD3 DRILL WPRT T Pull wiper early,Stacking, RIW=-3K, DHWOB=2.2K, PUW=38K,Saw billet on way up clean trip RIH,Tied in for-3' 21:59 23:59 2.00 10,828 10,933 PROD3 DRILL DRLG T 10828',Drill ahead, 1.5 BPM @ 3670 PSI FS, BHP=4325, RIW=15.2K, DHWOB=1.1K 32/28/2013 Drill 10933 to 11195,On wiper from 11195 tie in for-11'correction,Set down @9939',unable to pass,motor rubber on shaker,POOH to 0/0 Motor,Make repairs to gooseneck rollers on surface Page 16 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:18 0.30 10,933 10,961 PROD3 DRILL DRLG T Drill Ahead, 1.49 BPM @ 3670 PSI FS 00:18 02:42 2.40 10,961 10,961 PROD3 DRILL WPRT T Pulled wiper trip early,to 8750', Below upper billet,Stacking, Pumped 5 and 5 sweeps, PUW=45K,Little bump at 10371 billet on way up,Clean trip Running in 02:42 04:42 2.00 10,961 11,050 PROD3 DRILL DRLG T 10964', Drill ahead, 1.5 BPM @ 3750 PSI FS, RIW=15K, BHP=4310 04:42 05:12 0.50 11,050 10,390 PROD3 DRILL WPRT T Stacking, Pull wiper with sweeps, PUW=36K 05:12 06:00 0.80 10,390 11,050 PROD3 DRILL WPRT T Wiper back in hole RIW 15k 06:00 08:45 2.75 11,050 11,195 PROD3 DRILL DRLG T 11050ft-BOBD 1.44bpm at 3562psi BHP 4326,WHP 58 WOB 1.8k, ROP 53fph IA 517,OA 0 08:45 10:15 1.50 11,195 8,535 PROD3 DRILL WPRT T 11195ft-Wiper up to the window for a tie in.PUW 44k 10:15 10:30 0.25 8,535 8,568 PROD3 DRILL DLOG T Tie into the RA marker correction of- 11ft 10:30 11:30 1.00 8,568 9,930 PROD3 DRILL WPRT T Wiper back in hole RIW 17k 11:30 12:45 1.25 9,930 9,930 PROD3 DRILL WPRT T Tag at 9930ft Work pipe Looks like we may have chunked motor. 12:45 15:45 3.00 9,930 0 PROD3 DRILL TRIP T POOH, Start BHI Downtime 15:45 16:00 0.25 0 0 PROD3 DRILL SFTY T PJSM-Undeploying BHA 16:00 17:30 1.50 0 0 PROD3 DRILL PULD T Start Undeploy AL1-01 lateral BHA# 13 17:30 18:00 0.50 0 0 PROD3 DRILL RGRP T PJSM,Replace worn gooseneck rollers End BHI Downtime 4Hrs for trip to surface 18:00 00:00 6.00 0 PROD3 DRILL RGRP T Replace gooseneck roller Start NAD Rig reapir hours 03/01/2013 Complete Rig Repairs, RIH with Drilling BHA#15, Unable to get past 9930, POOH for HYC hole finder bit BHA #16, Unable to find hole oast 9930 00:00 02:30 2.50 0 0 PROD3 DRILL RGRP T Repairing gooseneck rollers 02:30 03:00 0.50 0 0 PROD3 DRILL SFTY T PJSM/Planning meeting, P/U BHA #15 03:00 04:00 1.00 0 72 PROD3 DRILL PULD T P/U BHA#15 with.8°Motor and re run 3.25"Bi center,M/U to coil track and surface test Start BHI Down time 04:00 06:00 2.00 72 8,100 PROD3 DRILL TRIP T Trip in hole 06:00 06:15 0.25 8,100 8,142 PROD3 DRILL DLOG T Tie in to the K1 marker correction +7', Page 17 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 06:45 0.50 8,142 9,930 PROD3 DRILL TRIP T Continue RIH END BHI DOWNTIME @ 06:00 for 3 HRS 06:45 07:30 0.75 9,930 9,930 PROD3 DRILL TRIP T Tag at 9930ft pumping 1.0bpm stall, Shut down pump.PU clean.Try different TF 95°,0°,50°L,45°R, 90°R,and 90°L with no success. 07:30 10:15 2.75 9,930 100 PROD3 DRILL TRIP T POOH Talk to town for plan forward. 10:15 10:30 0.25 100 100 PROD3 DRILL SFTY T PJSM-Updeploying BHA 10:30 11:30 1.00 100 100 PROD3 DRILL PULD T Start Undeploying 11:30 12:15 0.75 100 0 PROD3 DRILL PULD T Switch bits to the hycalog nipple bit with cutters on nipple.PJSM with crew coming on tour. 12:15 13:15 1.00 0 0 PROD3 DRILL PULD T Start Deploying cleanout BHA#16 13:15 15:45 2.50 0 8,100 PROD3 DRILL TRIP T RIH w/PDC 2.730 RR bit and 0.8° ako motor. 15:45 16:00 0.25 8,100 8,138 PROD3 DRILL TRIP T Tie into the K1 correction of+5.5ft 16:00 16:30 0.50 8,138 9,930 PROD3 DRILL TRIP T New mud all the way around. Bring pump to min rate and RIH to 9930'. 25fpm and 270°TF. 16:30 17:30 1.00 9,930 9,935 PROD3 DRILL TRIP T Drill 1/2 foot,goto minimum rate and try to work through,repeat down to 9934.7 17:30 18:36 1.10 9,935 9,936 PROD3 DRILL WPRT T Wiper trip to 9156, RBIH 18:36 19:36 1.00 9,936 9,938 PROD3 DRILL TRIP T Attempt to work through at as drilled TF 120L with pumps on @ 35 FPM, Goto min rate with trapped pressure. Work @ 22 to 45 FPM @ 120L, HS, 15R 30R,50R,70R, 120L, 100L, 80L,60L and 40L 19:36 19:54 0.30 9,938 9,938 PROD3 DRILL TRIP T Bring pumps on @ 1 BPM,Set down lightly 1K to 1.4K and roll TF left and right in attemp to work past obstruction 19:54 21:00 1.10 9,937 9,955 PROD3 DRILL TRIP T Goto full rate, 1.4 BPM @ 3462 PSI FS,Try to wash/drill past obstruction,at as drilled TF, 120L 21:00 22:18 1.30 9,955 9,958 PROD3 DRILL TRIP T Roll TF attempt to find hole 80 to 140L, weight fell off @ 9958 PUH and make minimum rate attempt 22:18 22:48 0.50 9,958 9,961 PROD3 DRILL TRIP T Attempt at full rate, 1.4 BPM, No luck 22:48 00:00 1.20 9,961 8,605 PROD3 DRILL WPRT T Wiper to window with Sweeps and tie in for-6, PUW=34K, RBIH X3/02/2013 Condition hole, Run AL1-01 Liner 9959 to TOL @8763, Drill off liner top billet, Drill ahead to 8865 00:00 00:36 0.60 8,605 9,956 PROD3 DRILL WPRT T RBIH after tie in 00:36 03:54 3.30 9,956 121 PROD3 DRILL TRIP T Trip out laying in 12.2 beaded liner running pill followed by 12.2 completion fluid, Paint EOP flags @ 8600 and 7200'EOP, PUW=40K 03:54 05:24 1.50 121 0 PROD3 DRILL PULD T At surface,flow check well, PJSM to lay down BHA#17 Page 18 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03/02/2013 24 hr Summary Condition hole, Run AL1-01 Liner 9959 to TOL @8763, Drill off liner top billet,Drill ahead to 8865 05:24 06:00 0.60 0 0 COMPZ CASING PUTB T Prep floor for M/U AL1,liner assy. 06:00 07:00 1.00 0 268 COMPZ CASING PUTB T Start picking up liner 07:00 07:15 0.25 268 268 COMPZ CASING SFTY T BOPE drill with crew. Drill time 1min and 38 sec.Great discussion with crew about placement of the safety joint with in the BOPE stack and placement on the rig floor. 07:15 08:45 1.50 268 1,238 COMPZ CASING PUTB T Continue M/U AL1-01 liner assy. 08:45 10:15 1.50 1,238 8,438 COMPZ CASING RUNL T RIH with AL1-01 liner assy. 35 jts of 2-3/8"Slotted Liner 2 pup jts 2-3/8"Solid Pup jts Non-ported bull nose 10:15 10:30 0.25 8,438 8,439 COMPZ CASING RUNL T Correct to 7200ft EOP flag+18.7ft. PUW 39k 10:30 10:45 0.25 8,439 9,295 COMPZ CASING RUNL T Continue in with AU liner.RIW 18k 10:45 11:00 0.25 9,295 9,316 COMPZ CASING RUNL T Tie into the K1 correction of-4ft. 11:00 11:15 0.25 9,316 9,959 COMPZ CASING RUNL T Continue tripping in hole. 11:15 11:30 0.25 9,959 9,959 COMPZ CASING RUNL T Tag bottom at 9959ft. PUW 41k,Set down 4k, Bring pump up to 1.2bpm at 3570psi. PU and lost 2.2k. 11:30 13:45 2.25 9,959 0 COMPZ CASING RUNL T POOH 13:45 14:30 0.75 0 0 COMPZ CASING PULD T Flow Check well, LD AL1-01 liner running assy. 14:30 15:00 0.50 0 0 PROD4 STK PULD T M/U AL1-02,with hycalog bi-center bit 15:00 17:00 2.00 0 8,100 PROD4 STK TRIP T RIH with AL1-02 lateral BHA 17:00 17:15 0.25 8,100 8,147 PROD4 STK DLOG T Tie in to K1 marker correction of+ 9.0ft 17:15 18:33 1.30 8,147 8,488 PROD4 STK TRIP T Continue to RIH,Swap well to 9.6 PPG Mud 18:33 18:51 0.30 8,488 8,763 PROD4 STK TRIP T Close EDC, RIH to mill off billet 18:51 20:03 1.20 8,763 8,765 PROD4 STK KOST T Dry tag Billet @ 8763,PUH, Bring pumps online 1.45 BPM @ 3430 PSI FS,Start time milling off billet @ 8763.5 20:03 20:33 0.50 8,765 8,766 PROD4 STK KOST T Go to 2 FPH 20:33 20:57 0.40 8,766 8,767 PROD4 STK KOST T Go to 3 FPH 20:57 22:03 1.10 8,767 8,790 PROD4 DRILL DRLG T Go to 10 FPH/Drill ahead, 1.45 BPM @ 3430 PSI FS,BHP=4125 22:03 22:15 0.20 8,790 8,790 PROD4 DRILL WPRT T Dry drift Billet area, PUW=35K, clean trip 22:15 23:45 1.50 8,790 8,865 PROD4 DRILL DRLG T 8790', Drill ahead, 1.45 BPM @ 3430 PSI FS, BHP=4150 23:45 00:00 0.25 8,865 8,865 PROD4 DRILL WPRT T Wiper trip, PUW=37K,Up to 8650 03/03/2013 P/U BHA#19, Drill 8865 to 9745 Page 19 of 30 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 01:36 1.60 8,865 8,940 PROD4 DRILL DRLG T 8865, Drill Ahead after clean wiper, 1.46 BPM @ 3430 PSI FS, BHP=4135 01:36 04:00 2.40 8,940 109 PROD4 DRILL TRIP T End of build/turn,Trip out to dial down AKO setting, PUW=38K Open EDC @ 8490' 04:00 07:30 3.50 109 72 PROD4 DRILL PULD T At surface,PJSM, PUD BHA#18 Build turn section with 1.9°motor. PD BHA#19 with.8°Motor and rebuild Hyc bi center 07:30 09:30 2.00 72 8,100 PROD4 DRILL TRIP T RIH 09:30 09:45 0.25 8,100 8,139 PROD4 DRILL DLOG T Tie into K1 marker correction of+8ft. 09:45 10:00 0.25 8,139 8,940 PROD4 DRILL TRIP T Continue tripping to bottom.Close EDC above window. 10:00 12:00 2.00 8,940 9,090 PROD4 DRILL DRLG T 8940ft-OBD 1.49bpm at 3500psi. BHP 4163,WHP 74, IA 32,OA 0. 15.5k coil surface weight. 12:00 12:15 0.25 9,090 8,800 PROD4 DRILL WPRT T 9090ft-Wiper up to 8750ft PUW 8800' 12:15 12:30 0.25 8,800 9,090 PROD4 DRILL WPRT T Wiper back in hole 12:30 14:00 1.50 9,090 9,240 PROD4 DRILL DRLG T BOBD 1.49bpm at 3500psi,BHP 4113,WHP 0, IA 52,OA 0, 15k coil surface weight 14:00 14:30 0.50 9,240 8,800 PROD4 DRILL WPRT T Wiper up hole to 8800ft, PUW 35k 14:30 15:00 0.50 8,800 9,240 PROD4 DRILL WPRT T 8800ft-Wiper back in hole RIW 16k 15:00 16:15 1.25 9,240 9,390 PROD4 DRILL DRLG T BOBD 1.49bpm at 3500psi. BHP 4167,WHP 34, IA 97,OA 0, 14k coil surface weight 16:15 17:00 0.75 9,390 8,535 PROD4 DRILL WPRT T Wiper up to 8535ft PUW 35k 17:00 17:15 0.25 8,535 8,558 PROD4 DRILL DLOG T Tie into the RA marker correction of- 2ft. 17:15 17:30 0.25 8,558 9,390 PROD4 DRILL WPRT T Wiper back in hole RIW 18 17:30 19:18 1.80 9,390 9,540 PROD4 DRILL DRLG T BOBD 1.49bpm at 3450, BHP=4185 19:18 20:12 0.90 9,540 9,540 PROD4 DRILL WPRT T Wiper trip to 8700', PUW=35K, Clean trip 20:12 22:12 2.00 9,540 9,690 PROD4 DRILL DRLG T 9540', Drill Ahead, 1.45 BPM @ 3450 PSi FS, BHP=4180 22:12 23:12 1.00 9,690 9,690 PROD4 DRILL WPRT T 9690',Wiper to 8800', PUW=34K, Clean trip 23:12 00:00 0.80 9,690 9,754 PROD4 DRILL DRLG T 9690', Drill Ahead, 1.45 BPM @ 3450 PSi FS, BHP=4170 03/04/2013 Drilled 9745'to 10880' 00:00 01:18 1.30 9,754 9,840 PROD4 DRILL DRLG T Drilling ahead 01:18 02:48 1.50 9,840 9,840 PROD4 DRILL WPRT T Wiper to window with tie in for a-2' correction, PUW=36K Clean trip out and in 02:48 04:54 2.10 9,840 9,990 PROD4 DRILL DRLG T 9840',Drill Ahead, 1.48 BPM @ 3600 PSI FS, BHP=4220, RIW=16K 04:54 05:30 0.61 9,990 8,800 PROD4 DRILL WPRT T Wiper trip to 8800', PUW=36K 05:30 06:00 0.50 8,800 9,990 PROD4 DRILL WPRT T Wiper back in hole. RIW 17k Page 20 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 9,990 10,140 PROD4 DRILL DRLG T Drill Ahead 1.54bpm at 3568psi, BHP 4256,WHP 0, IA 390,OA 0 08:00 08:30 0.50 10,140 8,800 PROD4 DRILL WPRT T Wiper trip to 8800ft PUW 35k 08:30 09:00 0.50 8,800 10,140 PROD4 DRILL WPRT T Wiper back in hole. RIW 17k 09:00 10:45 1.75 10,140 10,290 PROD4 DRILL DRLG T BOBD-1.48bpm at 3626psi, BHP 4261,WHP 0, IA 378,OA O. 15k coil surface weight.WOB 1.4, ROP 100fph 10:45 11:30 0.75 10,290 8,540 PROD4 DRILL WPRT T Wiper up to 8540ft for a tie in. PUW 35k 11:30 11:45 0.25 8,540 8,568 PROD4 DRILL DLOG T Tie into the RA marker correction of- 3ft. 11:45 12:30 0.75 8,568 10,290 PROD4 DRILL WPRT T Wiper back in hole RIW 18k 12:30 14:15 1.75 10,290 10,440 PROD4 DRILL DRLG T BOBD-1.48bpm at 3568psi, BHP 4263,WHP 0, IA 372,OA 0.WOB 1.8k , ROP 100 fph 14:15 15:00 0.75 10,440 8,800 PROD4 DRILL WPRT T Wiper up to 8800ft. PUW 35k 15:00 15:45 0.75 8,800 10,440 PROD4 DRILL WPRT T Wiper back in hole.RIW 16k 15:45 17:15 1.50 10,440 10,590 PROD4 DRILL DRLG T BOBD-1.42bpm at 3671psi, BHP 4346,WHP 0,WOB 1.7k, ROP 115 fph, IA 428,OA 0 17:15 18:00 0.75 10,590 9,051 PROD4 DRILL WPRT T Wiper up to 9051ft. PUW 36k 18:00 18:45 0.75 9,051 10,590 PROD4 DRILL WPRT T 9051ft-Wiper back in hole RIW 13k Start new mud down hole.- Old system 1827ft drilled,0.8%drill solids. 18:45 20:00 1.25 10,590 10,740 PROD4 DRILL DRLG T BOBD-New mud at bit 1.48bpm at 3540psi, BHP 4368,WHP 0,WOB 1.8, ROP 115fph, IA 386,OA 0 20:00 21:15 1.25 10,740 8,540 PROD4 DRILL WPRT T Wiper up to 8540ft for tie in PUW 37k 21:15 21:30 0.25 8,540 8,568 PROD4 DRILL DLOG T Tie into RA marker correction of- 8.5ft 21:30 22:44 1.24 8,568 10,740 PROD4 DRILL WPRT T Wiper back to bottom RIW 16k 22:44 23:59 1.25 10,740 10,880 PROD4 DRILL DRLG T BOBD-1.48bpm at 3563psi, BHP 4264,WHP 0, IA 262,OA 0 03/05/2013 Drill ahead with wiper trips to called TD @ 11,412',chase sweeps to swab valve. RBIH, log tie-in+2' correction,corrected tag depth 11,410',drill to 11,413.POOH laying in liner pill/completion fluid to surface. 00:00 00:12 0.20 10,880 10,890 PROD4 DRILL DRLG T Drilling Ahead 00:12 01:54 1.70 10,890 10,890 PROD4 DRILL WPRT T Wiper trip to 9000', PUW=36K, Clean trip out and in 01:54 03:18 1.40 10,890 11,040 PROD4 DRILL DRLG T 10890', Drill Ahead, 1.5 BP<@ 3670 PSI FS, BHP=4334, RIW=14.2K 03:18 04:48 1.50 11,040 11,040 PROD4 DRILL WPRT T Wiper trip to 9500', PUW=36K 04:48 06:30 1.70 11,040 11,190 PROD4 DRILL DRLG T 11040, Drill Ahead, 1.5 BPM @ 3590 PSi FS,BHP=4283 06:30 09:12 2.70 11,190 11,190 PROD4 DRILL WPRT T Wiper trip to window with tie in for -6.5', PUW=36K 09:12 11:18 2.10 11,190 11,340 PROD4 DRILL DRLG T 11190', Drill Ahead, 1.49 BPM @ 3555 PSI FS, BHP=4333, RIW=13.5 11:18 12:30 1.20 11,340 11,340 PROD4 DRILL WPRT T Wiper trip to 10K, PUW=36K Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:24 0.90 11,340 11,412 PROD4 DRILL DRLG T 11340', Drill Ahead, 1.52 BPM @ 3660 PSI FS, BHP=4343, RIW=13.5K 13:24 16:57 3.55 11,412 0 PROD4 DRILL TRIP T 11412 call TD,sweeps coming out chase to swab, PUW=36k,open EDC. 16:57 20:30 3.55 0 11,413 PROD4 DRILL TRIP T RBIH. Log GR tie-in+2 correction, RBIH,close EDC, RIH,start pumping beaded liner pill,tagged 11,410',drill to 11,413',wait on pill, PUW=40K. 20:30 00:00 3.50 11,413 132 PROD4 DRILL TRIP T POOH laying in liner pill. Paint EOP flags @ 9,300'&6,400',continue OOH. 03/06/2013 LID BHA#19. PU/MU BHA#20,60 jts lower liner assembly set @ 11,412'TOL @ 9,408'. POOH. LD BHA# 20.PU/MU BHA#21 27 jts upper liner assembly set @ 9,408'TOL 8,510'.POOH LID BHA#21.Start BOPE test. 00:00 00:30 0.50 132 0 PROD4 DRILL OWFF T On surface,flow check, hold PJSM. 00:30 01:36 1.10 0 0 PROD4 DRILL PULD T UD BHA#19,prep floor and finish maintenance. 01:36 05:06 3.50 0 2,005 COMPZ CASING PUTB T PJSM. PU 60 jts.lower liner section. 05:06 06:54 1.80 2,005 8,433 COMPZ CASING TRIP T RIH with BHA#20, EDC closed 06:54 07:00 0.10 8,433 8,449 COMPZ CASING TRIP T stop and correct to flag+15.75, PUW=39K 07:00 07:36 0.60 8,449 10,520 COMPZ CASING TRIP T Continue in hole 07:36 07:42 0.10 10,520 10,554 COMPZ CASING DLOG T Log RA Marker for-8'correction, 07:42 07:54 0.20 10,554 11,413 COMPZ CASING TRIP T Continue in hole 07:54 08:00 0.10 11,413 11,412 COMPZ CASING TRIP T Tag @ 11412.8, PUW=45K,Set back down @ 11412.2, Pumps on to release liner 1.27 BPM, PUW=36K, Liner release 08:00 10:30 2.50 11,412 55 COMPZ CASING TRIP T Trip out,paint EOP Flag 8400 and 7500 10:30 11:18 0.80 55 0 COMPZ CASING PULD T On Surface, PJSM, Lay down liner running BHA#20 11:18 13:12 1.90 0 941 COMPZ CASING PUTB T PJSM,M/U BHA#21, Ported Bullnose,27 Jts slotted liner,Shorty deployment sleeve. Perform Safety joint drill at#3,2:15 to install safety joint 13:12 14:42 1.50 941 8,439 COMPZ CASING TRIP T Trip in hole with BHA#21, EDC Closed 14:42 14:48 0.10 8,439 8,990 COMPZ CASING TRIP T Correct to flag,+1', PUW=35K, Continue in well 14:48 15:00 0.20 8,990 9,037 COMPZ CASING DLOG T Log K1 Marker for+2'correction 15:00 15:24 0.40 9,037 9,408 COMPZ CASING TRIP T Trip in well,start taking weight 9407, PUW=40K, Pumps on @ 1.2 BPM, PUW=37K TOL=8510, BOL=11412 15:24 17:18 1.90 9,408 0 COMPZ CASING TRIP T Stop and remove liner length from counters,897.04,trip out of well Page 22 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:18 20:03 2.75 0 0 COMPZ CASING PULD T On surface,flow check, PJSM. Unstab from wellhead, LD BHA#21. PJSM,pull checks and MU nozzle, stab lubricator,flush stack,valve crew serviced tree valves. PT inner reel. PJSM. 20:03 00:00 3.95 0 0 PROD5 RPEQPI BOPE P Start BOPE test 250/4000 psi annular 2500 psi.Witness waived by Lou Grimaldi AOGCC. 03/07/2013 Completed BOPE test. RIH w/BHA#22 whipstock set @ 8,504'TOWS 8,494'oriented to highside. POOH and LD BHA#22.RIH w/BHA#23 to mill tbg exit window,circulate well over to 9.6 ppg milling fluid,cut tbg window from 8,496'to 8,502'. POOH w/BHA#23. 00:00 04:00 4.00 0 0 PROD5 RPEQP1 BOPE P Complete BOPE test. 04:00 05:36 1.60 0 72 PROD5 RPEQPI PULD P Hold PJSM.MU BHA#22 Whipstock 05:36 07:36 2.00 72 8,110 PROD5 RPEQP1TRIP P RIH w/BHA#22 07:36 07:48 0.20 8,110 8,159 PROD5 RPEQP1DLOG P Log K1 marker for+1'correction„ PUW=35K 07:48 08:00 0.20 8,159 8,510 PROD5 RPEQP1TRIP P Continue in hole,Stop at 8340 and shut EDC 08:00 08:12 0.20 8,510 8,504 PROD5 RPEQP1TRIP P Lightly tag top of lower liner deployment sleeve @ 8510,Get to setting depth @ 8504,Oriented to High Side. Pumps on.3 BPM @ 3200 PSI see setting tool shift.Set down 1500LBS looks good,TOWS @ 8494 08:12 10:06 1.90 8,504 102 PRODS RPEQP1TRIP P POOH 10:06 10:24 0.30 102 0 PROD5 RPEQP1PULD P At surface, Flow check well, PJSM, Lay down BHA#22 whipstock set 10:24 11:12 0.80 0 73 PRODS WHPST PULD P M/U BHA#23 Window milling BHA with.6°motor,2.80 window mill, 2.79 string reamer,Make up to coil and surface test 11:12 13:06 1.90 73 8,110 PROD5 WHPST TRIP P RIH with EDC open 13:06 13:18 0.20 8,110 8,152 PROD5 WHPST DLOG P Log K1 Marker for+.5K, PUW=33K 13:18 13:30 0.20 8,152 8,470 PRODS WHPST TRIP P RIH to mill window 13:30 14:24 0.90 8,470 8,427 PRODS WHPST CIRC P Circulate well to 9.6 PPG milling fluid,shut down pump and shut EDC 14:24 14:30 0.10 8,427 8,496 PRODS WHPST TRIP P RIH to dry tag whipstock and mill window,Tag at 8496.2 14:30 21:15 6.75 8,496 8,502 PROD5 WHPST MILL P Pumps on 1.5 BPM @ 3840 PSI FS, call pinch point @ 8496.0,Mill window 3.5"exit per procedure. 21:15 22:03 0.80 8,502 8,502 PRODS WHPST MILL P Dress window,dry drift. PUW=35K 22:03 00:00 1.95 8,502 448 PRODS WHPST TRIP P POOH with BHA#23,open EDC @ 448' 03/08/2013 POOH w/BHA#23, PUD, LD Weatherford motor,MU treme motor.PD BHA#24, RIH w/7"casing exit assembly.Mill casing exit,bottom of exit 8,508'.Drill rathole to 8,519',ream/back ream casing exit window.POOH. PUD BHA#24, PD BHA#25, RIH w/build section assembly. 00:00 00:15 0.25 448 0 PROD5 WHPST TRIP P Continue OOH with BHA#23. Page 23 of 30 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 00:15 01:30 1.25 0 0 PROD5 WHPST PULD P PJSM. PUD BHA#23,LD X-motor, MU Weatherford motor. 01:30 03:30 2.00 0 74 PROD5 WHPST PULD P PD BHA#24 03:30 05:12 1.70 74 8,115 PROD5 WHPST TRIP P RIH w/7"casing exit mill assembly 05:12 05:24 0.20 8,115 8,150 PROD5 WHPST DLOG P Log K1 for no correction 05:24 05:54 0.50 8,150 8,502 PROD5 WHPST TRIP P Continue trip in,close EDC @ 8404, Dry tag @ 8502, PUW=34K, 05:54 10:30 4.60 8,502 8,508 PROD5 WHPST MILL P 8504.2 start time milling, 1.45 BPM @3670 PSI FS, RIW=17K, BHP=4025 10:30 14:30 4.00 8,508 8,519 PROD5 WHPST MILL P 8508 Bottom of window,continue milling rathole 14:30 16:30 2.00 8,519 8,519 PROD5 WHPST REAM P Start reaming/back reaming window, Dry drift up/down,looks good. PUW=33k 16:30 18:36 2.10 8,519 0 PROD5 WHPST TRIP P Trip out of hole, EDC open, PUW=34K 18:36 21:21 2.75 0 0 PROD5 DRILL PULD P On surface, PJSM. PUD BHA#24, LD Weatherford motor,MU Treme motor. PJSM, PD BHA#25. 21:21 00:00 2.65 0 8,133 PROD5 DRILL TRIP P RIH w/Build section assembly, performed tie-in log+4.5'correction, continue in hole. 03/09/2013 RIH w/build section BHA, Drill build section from 8,519'to 8,684', End of build 8,648'. POOH and PUD BHA# 25,PD BHA#26.7 bend motor. RIH to drill AL2 lateral,drill ahead from 8,684'to 9,136'with 150'wiper trips. 00:00 00:30 0.50 8,133 8,519 PRODS DRILL TRIP P Continue to RIH w/build section BHA 00:30 06:06 5.60 8,519 8,684 PRODS DRILL DRLG P Start drilling build section,pumping @ 1.49 bpm,3,645 psi,4,097 BHP, DHWOB 14.9 K. PU and log RA @ 8,502'.Continue drilling ahead with same parameters. 06:06 08:24 2.30 8,684 66 PRODS DRILL TRIP P Call End of Build @ 8648, POOH, PUW=43K.Open EDC @8884' 08:24 09:24 1.00 66 0 PRODS DRILL PULD P At surface, PJSM, PUD BHA#25 Build section 09:24 10:24 1.00 0 0 PRODS DRILL PULD P Configure tool string, Rebuild drilling choke install new seat and stem, 10:24 11:42 1.30 0 72 PROD5 DRILL PULD P PJSM, PD BHA#26, Lateral section with.7°motor and rebuild Hycalog with duraforce cutters.Make up to coil and surface test 11:42 13:30 1.80 72 8,110 PRODS DRILL TRIP P trip in with BHA#26, EDC Open 13:30 13:42 0.20 8,110 8,146 PRODS DRILL DLOG P Log K1 Marker for-7' 13:42 14:06 0.40 8,146 8,528 PRODS DRILL TRIP P Continue in well,Close EDC 14:06 14:12 0.10 8,528 8,536 PROD5 DRILL DLOG P Log/tie in RA marker @ 8502', TOWS @ 9496' 14:12 14:24 0.20 8,536 8,684 PROD5 DRILL TRIP P RIH to drill, 14:24 17:12 2.80 8,684 8,840 PROD5 DRILL DRLG P 8684', Drill ahead, 1.48 BPM @ 3740 PSI FS, BHP=4230, RIW=13.3K 17:12 17:51 0.65 8,840 8,840 PRODS DRILL WPRT P 8840',Wiper to window,Mad pass, PUW=41K Page 24 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:51 20:36 2.75 8,840 8,990 PROD5 DRILL DRLG P Drill ahead, 1.49 BPM @ 3,880 PSI FS, BHP=4,180, RIW=14.2K 20:36 21:36 1.00 8,990 8,990 PROD5 DRILL WPRT P Wiper to window, PUW=45K. RBIH 21:36 00:00 2.40 8,990 9,136 PROD5 DRILL DRLG P Drill ahead, 1.49 BPM @ 3,901 PSI FS,BHP=4,202, RIW=14.7K 03/10/2013 Continue drilling ahead from 9,136'to 9,598'with 150'wiper trips.Observed 300 psi lose in circulating psi. PUH and found pinhole @ 9,497'.Shut down drilling operations. POOH and PUD BHA#26,start loading coil with FW. 00:00 00:21 0.35 9,136 9,140 PROD5 DRILL DRLG P Continue drilling ahead, 1.48 BPM @ 3,901 PSI FS, BHP=4,202, RIW=14.7K 00:21 01:21 1.00 9,140 9,140 PROD5 DRILL WPRT P Wiper to window, Log tie-in,+1' correction. RBIH,GEO target 90 degree Inc. PUW=40K. 01:21 02:00 0.65 9,140 9,178 PROD5 DRILL DRLG P Drilling ahead, 1.48 BPM @ 3,988 PSI FS, BHP=4,244, RIW=15.3K 02:00 03:00 1.00 9,178 9,178 PROD5 DRILL DRLG P Spring forward! 03:00 04:49 1.82 9,178 9,290 PROD5 DRILL DRLG P Drilling ahead, 1.48 BPM @ 3,995 PSI FS, BHP=4,253, RIW=15.4K 04:49 06:07 1.30 9,290 9,290 PROD5 DRILL WPRT P Wiper to window 06:07 09:43 3.60 9,290 9,440 PROD5 DRILL DRLG P 9290', Drill Ahead, 1.43 BPM @3672 PSI FS, BHP=4250 Swap to new 9.6 Flo Pro drilling mud 09:43 10:49 1.10 9,440 9,440 PROD5 DRILL WPRT P Wiper trip, PUW=34K,Clean trip out and in 10:49 13:43 2.90 9,440 9,590 PROD5 DRILL DRLG P 9440'Drill Ahead, 1.4 BPM @ 3800 PSI FS, BHP=4221 13:43 15:01 1.30 9,590 9,590 PROD5 DRILL WPRT P Wiper to window with tie in PUW=37K,Correction at tie in-5', Clean trip out and in 15:01 15:13 0.20 9,590 9,598 PROD5 DRILL DRLG P 9586', Drill ahead, 1.42 BPM @ 3645 PSI FS, RIW=15.2K, BHP=4180, 15:13 15:19 0.10 9,598 9,590 PROD5 DRILL TRIP T Lost 300 PSI Circ pressure. Investigate pumps,Swap pumps, good charge pressure,Suspect pinhole 15:19 15:31 0.20 9,590 9,474 PROD5 DRILL TRIP T PUH while watching for pinhole, Pinhole @ 9497, Shut down pumps and bleed off pumps,Check valves holding,Make notifications on rig pull pinhole on reel 15:31 19:31 4.00 9,474 0 PROD5 DRILL TRIP T Trip out pumping across top to maintain BHP,on surface,space out. 19:31 21:07 1.60 0 0 PROD5 DRILL PULD T PJSM,PUD BHA#26, Unload PDL and blow down tools. 21:07 23:59 2.88 0 0 PROD5 DRILL CTOP T PJSM.Stab on to circulate coil with FW. Pumped 12 bbls away only getting 2-3 bbls back,pinhole larger than excepted. Unstab and remove UQC. Retry circulating FW less losses through leak. Page 25 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/11/2013 24 hr Summary Load coil with fresh water,blow down coil with nitrogen,bleed off coil.Start reel swap operations,change out injector skates a nd ripper blocks, install inner reel lines. 00:00 02:00 2.00 0 0 PROD5 DRILL CTOP T Continue loading coil with freshwater. Blow down initial 2,000'of coil with rig air. 02:00 03:00 1.00 0 0 PROD5 DRILL CTOP T MIRU SLB N2 unit. PJSM.Blow down remaining coil with nitrogen. 03:00 06:00 3.00 0 0 PROD5 DRILL CTOP T Break down inner reel lines. 06:00 11:00 5.00 0 0 PROD5 DRILL CTOP T Crew change, PJSM, Rig up spool for swap out.Clean reel sump. Load out reel on bed truck,Remove reel hub adapters.Clean and inspect reel saddles 11:00 14:00 3.00 0 0 PROD5 DRILL CTOP T Set new reel in saddles and secure. Refit spill containment in reel sump. Install king pin on drill sub 14:00 18:00 4.00 0 0 PROD5 DRILL RGRP P Continue work on injector skate change Start NAD Billable repair hours 18:00 00:00 6.00 0 0 PROD5 DRILL RGRP P Crew change,Continue on Injector, Remove stripper,break chains and remove gripper blocks,remove skates and old chain. Install new chains,skates,and grippers. End NAD Billable repair hours,for a total of 8 hrs. 03/12/2013 Complete reel swap&Injector maintenance.Perform BOPE Function test. RIH while inspecting reel,CT and injector head. 00:00 04:30 4.50 0 0 PROD5 DRILL RGRP P Complete injector head work. 04:30 05:00 0.50 0 0 PRODS DRILL SFTY T PJSM 05:00 09:15 4.25 0 0 PROD5 DRILL CTOP T Restab coil,skid injector,install boot &pump-in sub.Adjust gooseneck rollers,work on reel. 09:15 10:00 0.75 0 0 PROD5 DRILL CTOP T PJSM.Blow thru new reel with rig air to confirm no ice plug. 10:00 14:00 4.00 0 0 PROD5 DRILL CTOP T Cut coil to expose wire(1')Test cable,MU coil connector,pull test to 35K.MU UQC,MU nozzle, change-out pack-offs. 14:00 16:00 2.00 0 0 PROD5 DRILL CIRC T Load coil @.25 bpm with Flo-pro, install checks, PT UQC to 4,000 psi. 16:00 17:00 1.00 0 0 PROD5 DRILL RURD T PJSM,install depth counters. Function test BOPE 17:00 19:30 2.50 0 0 PROD5 DRILL PULD T PU/MU BHA#27. PD drilling assembly. 19:30 20:30 1.00 72 800 PROD5 DRILL TRIP T RIH,inspecting reel and injector head. PU to inspect pipe for markings assuring gooseneck alignment. Pipe looks good. 20:30 21:30 1.00 800 1,700 PROD5 DRILL TRIP T Cont. RIH, Found packoff hose on injector to be slightly rubbing on gripper blocks.Stop and adjust hose Page 26 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:00 1.50 1,700 8,100 PROD5 DRILL TRIP T Cont. RIH 23:00 23:15 0.25 8,100 8,100 PROD5 DRILL DLOG T Tie in depth to K1 marker,-1' correction 23:15 00:00 0.75 8,100 9,598 PROD5 DRILL TRIP T Cont RIH 03/13/2013 Drill AL2 lateral. Pipe differentially stuck at 10250'.Work pipe free,continue drilling ahead. Prepare to swap out mud system. 00:00 03:00 3.00 9,598 9,740 PROD5 DRILL DRLG P Drill Ahead 1.38 bpm, 3940 ctp,87 whp,4193 bhp, 14k ctw, 03:00 04:00 1.00 9,740 8,549 PROD5 DRILL WPRT P Wiper trip back to window,33k 04:00 04:51 0.85 8,549 9,743 PROD5 DRILL WPRT P RBIH 04:51 07:06 2.25 9,743 9,890 PROD5 DRILL DRLG P Drill Ahead 1.40 bpm, 3770 ctp,93 whp,4215 bhp, 13.5k ctw,made several Inc.changes from 91 to 86 degrees as per GEO. 07:06 08:21 1.25 9,890 8,466 PRODS DRILL WPRT P Wiper trip back to window,36K. Open EDC,lock out reel, re-shim reel,GEO 87.7 deg Inc.Close EDC. 08:21 09:03 0.70 8,466 9,890 PRODS DRILL WPRT P RBIH 09:03 11:39 2.60 9,890 10,040 PRODS DRILL DRLG P Drill Ahead 1.40 bpm, 3722 ctp, 120 whp,4220 bhp, 12k ctw. GEO 88.5 deg Inc.Stacked out once, PU, pulled heavy twice,43K @ 9,930'. 11:39 12:39 1.00 10,040 8,525 PRODS DRILL WPRT P Wiper trip back to window,36K, tie-in RA-10'correction. 12:39 13:24 0.75 8,525 10,040 PRODS DRILL WPRT P RBIH 13:24 15:36 2.20 10,040 10,190 PRODS DRILL DRLG P Drill Ahead 1.40 bpm, 3992 ctp, 131 whp,4,232 bhp, 11.5k ctw.GEO 88 deg Inc. 15:36 16:06 0.50 10,190 9,040 PROD5 DRILL WPRT P Short wiper trip,37K 16:06 16:36 0.50 9,040 10,190 PRODS DRILL WPRT P RBIH 16:36 18:06 1.50 10,190 10,249 PROD5 DRILL DRLG P Drill Ahead 1.40 bpm, 3992 ctp, 131 whp,4,232 bhp, 11.5k ctw.GEO 87.5 deg Inc. 18:06 18:36 0.50 10,249 10,249 PRODS DRILL DRLG T Start to stackout, Pickup 50k,stuck. Do not see anything on DHWOB sensor when trying to pull free.Able to orient without amping up. Work pipe up and down, unable to pull free. Trap MP matching schedule,offline with pumps,let set 5 minutes. Unable to pull free at 52k. Increase MP 100psi,trap pressure. Let set in neutral weight 5 minutes. Unable to pull free 55k.Go back to neutral weight bleed MP down to 3850 bhp. Let set 5 minutes, PU 50k,pull free, Differentially stuck. 18:36 20:21 1.75 10,249 8,525 PRODS DRILL WPRT P Pick up slowly pump 10 x 10 low/high sweeps. Pull wiper up to window.Order trucks for mud swap. 20:21 20:33 0.20 8,525 8,541 PROD5 DRILL DLOG P Log Ra marker.correct-1.5' correction Page 27 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:33 21:18 0.75 8,541 10,249 PROD5 DRILL WPRT P RBIH 21:18 00:00 2.70 10,249 10,390 PROD5 DRILL DRLG P Drill ahead 1.4 bpm,4037 ctp,4269 bhp,2200hrs overpull 48k. Pull BHA wiper.Cont drilling Increasing MP 50-80 psi. Drilling seeemed to get better last half hour 03/14/2013 Drill AL2 lateral. Perform shortened wiper trips schedule,as per program,pumping 5x5 low/high vis sweeps. Swap out drilling mud system 10390'. Pipe differentially stuck at 10642'. Pump mineral oil to pull free.Cont. drilling AL2 lateral. 00:00 01:30 1.50 10,390 8,550 PROD5 DRILL WPRT P Wiper trip back to window 34k puw 01:30 02:30 1.00 8,550 10,390 PROD5 DRILL WPRT P RBIH Start sending new mud DH 02:30 05:00 2.50 10,390 10,540 PROD5 DRILL DRLG P Drill ahead 1.4 bpm,4000,4292 bhp, 12k ctw, 146 whp, New mud at bit. GEO>88 deg Inc 05:00 07:30 2.50 10,540 10,540 PROD5 DRILL WPRT P Wiper trip back to window 37k puw. RBIH 07:30 09:30 2.00 10,540 10,690 PROD5 DRILL DRLG P Drill ahead 1.4 bpm,4012,4279 bhp, 11.2k ctw, 166 whp,GEO>90 deg inc,GEO>92 deg inc 09:30 11:57 2.45 10,690 10,690 PROD5 DRILL WPRT P Wiper trip back to window 37k puw. Tie-in RA-4'correction. RBIH. 11:57 12:45 0.80 10,690 10,742 PROD5 DRILL DRLG P Drill ahead 1.42 bpm,3975,4296 bhp, 10.2k ctw, 197 whp,poor motor work,stacking,GEO>92 deg inc 12:45 13:00 0.25 10,742 10,642 PROD5 DRILL WPRT P BHA wiper trip.GEO>91.5 deg Inc 13:00 14:00 1.00 10,642 10,642 PROD5 DRILL WPRT T RBIH,stacking,work pipe,diff stuck pipe,open choke,decrease WH, work pipe shut down pump, relax pipe,continue working pipe, load mineral oil. 14:00 14:51 0.85 10,642 10,642 PROD5 DRILL CIRC T Start pumping 7 bbls LVT chasing with mud, LVT at bit,pump additional 4 bbls,shut down pump,let soak 20 mins,work pipe,pull free 48K. 14:51 15:45 0.90 10,642 9,650 PROD5 DRILL WPRT P Make wiper trip,chase LVT to surface,recovered 7 bbls LVT. 15:45 16:15 0.50 9,650 10,742 PROD5 DRILL WPRT P RBIH 16:15 18:15 2.00 10,742 10,883 PROD5 DRILL DRLG P Drill ahead 1.44 bpm,3902,4249 bhp, 12.5k ctw, 119 whp 18:15 19:00 0.75 10,883 9,730 PROD5 DRILL WPRT P Stacking,indications of differential sticking. Pull wiper trip early. 1100' wiper.42k puw 19:00 19:30 0.50 9,730 10,883 PRODS DRILL WPRT P RBIH 19:30 22:00 2.50 10,883 11,026 PROD5 DRILL DRLG P Drill ahead 1.44 bpm,3902,4249 bhp, 12.5k ctw, 119 whp 22:00 22:30 0.50 11,026 9,929 PRODS DRILL WPRT P 1100'wiper.34k puw 22:30 23:00 0.50 9,929 11,026 PROD5 DRILL WPRT P RBIH 23:00 00:00 1.00 11,026 11,074 PRODS DRILL DRLG P Drill Ahead 1.44 bpm,4081 ctp,4326 bhp,9k ctw,2k wob 03/15/2013 TD AL2 lateral 11200'. POOH to swab valves chasing 10br1 low vis high vis sweeps. RBIH to 11200'. POOH laying 12.2 ppg completion fluid with beads,without beads to surface. PU/MU/RIH AL2 liner Page 28 of 30 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 02:30 2.50 11,074 11,200 PROD5 DRILL DRLG P Drill Ahead 1.44 bpm,4181 ctp,4356 bhp,9k ctw,2k wob 02:30 06:15 3.75 11,200 0 PROD5 DRILL WPRT P TD AL2 lateral. POOH to swab valves chasing 10x10 low/high sweeps.36k puw.22 fpm first 1000'.35 fpm up to window.POOH 80 fpm,pumping max rate following MP schedule. 06:15 10:00 3.75 0 11,201 PROD5 DRILL TRIP P RBIH.Open EDC, RIH,Log GR tie-in -7'correction, RIH,Close EDC,Tag TD @ 11,201'. 10:00 14:00 4.00 11,201 0 PROD5 DRILL TRIP P POOH,laying in beaded liner pill in open hole,continue OOH,laying completion fluid to surface,flow check. 14:00 15:00 1.00 0 0 PROD5 DRILL PULD P LD BHA#27, Prep floor for picking up liner. 15:00 18:00 3.00 0 0 COMPZ CASING PUTB P PJSM. PU Liner slotted jnts.MU safety joint with TIW. Load 511 solid joints and tally 18:00 19:00 1.00 0 0 COMPZ CASING SFTY P Crew change, PJSM. New crew up today.Stop discuss liner detail. Hold drill,and discuss everyones position. 19:00 21:30 2.50 0 0 COMPZ CASING PUTB P Continue picking up liner. 21:30 23:00 1.50 2,760 8,360 COMPZ CASING RUNL P RIH 23:00 23:12 0.20 8,360 8,360 COMPZ CASING DLOG P Tie in depth to EOP flag.+2.4' correction. Record up and down weight.38K up and 18 down,-7k wob 23:12 00:00 0.80 8,360 11,194 COMPZ CASING RUNL P RIH to bottom 18k RIHW, 03/16/2013 RIH with AL2 liner no issues.Tag 11194'.Swap well to diesel. POOH. Undeploy BHA 28.Set BPV, Flush& Blow down rig. RD Rig Release 1800 00:00 00:30 0.50 10,400 11,194 COMPZ CASING RUNL P RIH with AL2 liner.AT 10425'WOB indicating set down when solid liner exited open hole. Not seeing at surface CT weight indicator. 00:30 01:00 0.50 11,194 8,106 COMPZ CASING RUNL P Tag bottom 11194'.CTW 8k,4k WOB. Release liner 4300 CTP,33k PUW.-3k WOB. Liner released. Start circulating spacer for deisel displacement. PU tie in depth K1 tie in. 01:00 01:15 0.25 8,106 8,460 COMPZ CASING DLOG P -3'correction on K1 tie in.TOL- 8475'.RBIH 15'above TOL 01:15 03:15 2.00 8,460 8,460 COMPZ CASING DISP P Displace well to diesel 03:15 06:00 2.75 8,460 0 COMPZ CASING TRIP P POOH following MP schedule 06:00 06:15 0.25 0 0 COMPZ CASING SFTY P At surface, 1,750 psi whp. PJSM. 06:15 09:00 2.75 0 0 COMPZ CASING PULD P PUD BHA#28. PJSM. Line up BO PDL, LD BHA,organize floor. 09:00 12:30 3.50 0 0 DEMOB WHDBO NUND P Jet BOPE equipment. PU lubricator install BPV. Pump inhibitor,push and purge coil/rig. Page 29 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 16:00 3.50 0 0 DEMOB WHDBO DMOB P Blow down CT reel and rig lines to tiger tank. Rig down MP line and mis.lines in cellar. 16:00 18:00 2.00 0 0 DEMOB WHDBO DMOB P Continue to prep rig for move to 1G-Pad. ND BOPE, FP tree and secure. Lift and secure BOPE. Rig Release 1800 hrs Page 30 of 30 RECEIVED 2013 Letter of Transmittal WARM AOGCC BAKER Date: April 3, 2013 HUGHES 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): 1H-19A (3.13 ' OCR 1H-19AL1 a )3 OD ,3 1H-19AL1-01 a 13 ' C3 a 1H-19AL2 01.t 3 3 1H-19APB1 • D d�_ 1H-19AL1PB1 3 , 0©3 1H-19AL1-01PB1 a l3 0 a9 7 ?nts 130(7) Total pr 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 mai Michael Soper, Baker Hughes, Project Engineer (Yr/ Michael.Soper @BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich @BakerHughes.com Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Wednesday, March 06, 2013 10:28 AM To: 'Ohlinger, James J' Subject: RE: 1H-19 Naming You have already submitted a PTD for 1H-19AL1-02. Please modify this submission renaming it 1H-19AL1-01 and send me the modified PTD. I will change the pages out and keep the same PTD number(PTD 213-032). Close the remaining out with 407s(APB1,AL1PB1,AL1-01PB1). From: Ohlinger, James J jmailto:James.J.Ohlinger @conocophillips.coml Sent: Wednesday, March 06, 2013 9:17 AM To: Ferguson, Victoria L (DOA) Subject: RE: 11-1-19 Naming Correction... From: Ohlinger, James J Sent: Wednesday, March 06, 2013 9:16 AM To: 'Ferguson, Victoria L (DOA)' Subject: RE: 1H-19 Naming Do I need to submit something to adjust the Permit for the 1H-19AL1-01 lateral? Permit had kickoff point at 10370' MD,it was then lost so became 1H-19AL1-01PB1. We then kicked off at 8760' MD,was verbally approved for 1H-19AL1-02. However makes more sense to label it 1H- 19AL1-01. Please let me know what or if I need to submit anything, or just close them out with the 407's. From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Tuesday, March 05, 2013 9:58 AM To: Ohlinger, James 3 Subject: [EXTERNAL]RE: 1H-19 Naming We'd recommend naming the brown-colored segment 1H-19AL1-01 rather than 1H-19AL1-02. Otherwise it looks fine. From: Ohlinger, James 3 [mailto:James.J.Ohlinaer@conocophillips.com] Sent: Monday, March 04, 2013 8:32 AM To: Ferguson, Victoria L(DOA) Cc: Schwartz, Guy L(DOA) Subject: 1H-19 Naming I've attached two schematics. The first is the proposed naming,the second the completion. 1 Ferguson, Victoria L (DOA) From: Davies, Stephen F (DOA) Sent: Monday, March 04, 2013 11:40 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: 1H-19 Naming Victoria, I'd recommend calling the brown-colored weilbore segment 1H-19AL1-01 rather than 1H-19AL1-02, otherwise this looks file so long as the plug-backs are really plugged back with cement. I'd highly recommend placing color copies of the final version of this diagram in the history files for 1H-19, 1H-19A, 1H- 19AL1, 1H-19AL1-01, and 1H-19AL2. Thanks, Steve D. From: Ferguson, Victoria L (DOA) Sent: Monday, March 04, 2013 11:26 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: Fwd: 1H-19 Naming Steve, Could you please look at 1H-19 laterals and Plug backs attached and see if you agree with the naming convention proposed or if you would propose something different. Thanx, Victoria Sent from my iPhone Begin forwarded message: From: "Ohlinger,James J"<James.J.Ohlinger @conocophillips.com> Date: March 4,2013,8:32:14 AM AKST To: "'Ferguson,Victoria L(DOA)"<victoria.ferguson@alaska.gov> Cc: "'Schwartz,Guy L(DOA)"<guy.schwartz @alaska.gov> Subject: 1H-19 Naming I've attached two schematics. The first is the proposed naming, the second the completion. Please review and let me know if this is ok,or if I need to adjust the naming. Thanks. 1 I N o o N 0 N N I c-i WN N N N N N N N rl M 1 N m m m m m m m m 1 O a. W O N N N N N N N N I J N N N N N N N N Q,. 0 0 0 0 0 0 0 o I ■ 0 1 L Q ' M o 0 0 0 0 0 0 o m I -' J d a I Q I I b Q I _= I 1 • I Ln Ln m LO O CO v O I I .— CI al E 1_ 1 I I I ' CO 1 I a ; L�. YO o`^o CO t° 00 al ° op opo •— I C m I , 1 a I CO '-I a T T m r-I el e-I e-1 N 1!' a a a a a a a= _ _ _ _ _ _ = I •- r-+ Q m Q Z N Q a? gtt; CI C hi F... °c, , . r r c7 1 H i v °" ff t" z ,, i e ar rr r- f I- 1- 9 ; I- 02 r- h `e i r. c i k i � a i l c i a c f 4 4I f 0 P r I ( r 0 / r r 0 1� 1 0 f; 0 i f 9 R2 9: H 'F 9 4) , , , c a e' i I 1 / 1 .r. O i 1 v r e ' 0. 1 E 0 0 L. ' 4 i 0 0 Ml t I C•E a A o.o V � 2 I :I L ax o WE= 7 Go �/� ?f 11 MM fl "'._ 0m �E � M f�t"••= 0 � � l.Il t j1 1 i to 11. ________ _ _-___ _ .o., —.-----------_.. _. 11111 Il111 ♦ 1 t Yl Gig 0w\'\\�j/j7 s_x THE STATE Alaska Oil and Gas ,' =- ALAS Conservation Commission MTh. GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt i CT Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1H-19AL2 ConocoPhillips Alaska, Inc. Permit No: 213-004 Surface Location: 582' FNL, 1160' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 3337' FNL, 4742' FEL, SEC. 28, T12N, R10E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 11-1-19A, Permit No 213-002, API 50-029-22312-01-00. 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, 41 Cathy 7 Foerster Chair DATED this lie day of January, 2013. cc: Department of Fish& Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 9 2013 PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj 0 Single Zone ❑ lc.Specify if well is proposed for: Drill ❑ Lateral 0 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: [✓j Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 H-19AL2• 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11500' - TVD: 6510'• Kuparuk River Field, 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:582'FNL, 1160'FEL,Sec.33,T12N, R10E,UM• ADL 25639 Kuparuk River Oil Pool, Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1416'FNL,3569'FEL,Sec.28,T12N,R10E,UM 464 2/1/2013. Total Depth: 9.Acres in Property: ?I443 14.Distance to 3337'FNL,4742'FEL,Sec.28,T12N,R10E, UM 489-.25,0 093 Nearest Property: 9710 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 96 feet 15.Distance to Nearest Well Open Surface:x- 549187 y- 5980119 Zone- 4• GL Elevation above MSL: 54 feet to Same Pool: 1H-03,1100. 16.Deviated wells: Kickoff depth: . 8495 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: .100° deg Downhole:4200 psig. Surface:3550 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 3005' 8495' 6459' 11500' 6510' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 8990 6928 none 8887 6849 none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 200 sx PF C 121' 121' ! Surface 5303' 9.625" 1390 sx PF E,500 sx CI G, 5345 4270' Intermediate 44 bbls PF C Production 8935' 7" 270 sx Class G 8970' 6913' Liner • Perforation Depth MD(ft): Perforation Depth TVD(ft): 8340-8404, 8430-8470, 8673-8693, 8706-8726 6441-6488, 6507-6536, 6687-6702, 6712-6727 _ 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program 0 • Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 - 20 AAC 25.050 requirements El 21.Verbal Approval: Commission Representative: Date: d/OAS g° 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Email Printed Name Lamar Gantt Title CT Drilling Supervisor Signature 'Urn CIA, .` U _... Phon 2b:3-4U21 Date j v//3 i Commission Use Only Permit to Drill API Number: 1 Permit App oval See cover letter Number: ,2.13 0 0 1 50- 027- IA.3/2-G(-00 Date: \ I (\1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: L'J Other: -Af ii-.(7Q psi. fop 7e, Samples req'd: Yes ,❑ No Mud log req'd: Yes❑ No[,�" x U(f."),._C•- �yL .�.,.� c„�, H2S measures: Yes I!j No r❑�f Directional svy req'd: Yes[l No❑ Spacing exception req'd: Yes 10 No U Inclination-only svy req'd: Yes El No[y" / ay.Q Ale) 91S /ALT= (iet / 9 de- 2j . APPRQVEp THE Approved by P COI4 kSSIONJffRr COMMISSION Date: /-IC •-/ 3 Form 10-401(Re 10/2012) This permit is Valid for 24 months from the date.of approval(20 AAC 25.005(g)) \1�\l� Kuparuk CTD Laterals cN.BOAS.�9x, Miffing 1H-19A 1 H-19AL1, & 1 H-19AL2 C�J' Application for Permit to Drill Document L RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 MC 25.005(c)(12)) 5 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 MC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 8 (Requirements of 20 AAC 25.402) 8 17. Attachments 8 Attachment 1: Directional Plans for 1H-19A, 1 H-19AL1, & 1 H-19AL2 8 Attachment 2: Current Well Schematic for 1H-19 8 Attachment 3: Proposed Well Schematic for 1H-19A, 1H-19AL1, & 1 H-19AL2 8 Page 1 of 8 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1H-19A, 1H-19AL1, & 1 H-19AL2. All three of these laterals will be classified as"Service"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 582' FNL, 1160' FEL, Sec 33, T12N, R10E, UM NAD 1927 RKB Elevation 96 AMSL Northings: 5,980,119 Eastings: 549,187 Pad Elevation 54AMSL 1H-19A Location at Top of Productive Horizon 1183' FNL, 3695' FEL, Sec 28, T12N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8,800' Northings: 5,984,780 Eastings: 546,611 Total Vertical Depth, SS: 6,594' Location at Total Depth 4515' FNL, 171' FEL, Sec 20, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 11,500' Northings: 5,986,718 Eastings: 544,838 Total Vertical Depth, SS: 6,580' 1 H-19AL1 Location at Top of Productive Horizon 1404' FNL, 3575' FEL, Sec 28, T12N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8,515' Northings: 5,984,561 Eastings: 546,733 Total Vertical Depth, SS: 6,474' Location at Total Depth 4485' FNL, 160' FEL, Sec 20, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 11,500' Northings: 5,986,748 Eastings: 544,848 Total Vertical Depth, SS: 6,605' 1 H-19AL2 Location at Top of Productive Horizon 1416' FNL, 3569' FEL, Sec 28, T12N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8,495' Northings: 5,984,549 Eastings: 546,739 Total Vertical Depth, SS: 6,459' Location at Total Depth 3337' FNL, 4742' FEL, Sec 28, T12N, R10E, UM NAD 1927 Measured Depth, RKB: 11,500' Northings: 5,982,620 Eastings: 545,583 Total Vertical Depth, SS: 6,510' Page 2 of 8 �� 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. (Using the maximum pressure in the area of 4200 psi,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3550 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 1H-19 in October 2012 indicated a reservoir pressure of 4097 psi or 11.9 ppg equivalent mud weight. The maximum down hole pressure in the 1H-19 pattern is at injector 1R-26 with 4200 psi. It is not expected that reservoir pressure as high as 1R-26 well will be encountered while drilling the 1H-19 laterals because of offset distance and faulting. Using the 1R-26 pressure as the maximum possible in 1R- 29,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3550 psi. Potential Gas Zones(Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 1H Pad hasn't had any MI injection since early 2008.There was some MI injected into the C-sand(with some more than likely getting into the A)to the North in 1R-26. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1H-19 laterals will be crossing a fault into a lower pressurized reservoir block and experiencing losses. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 1H-19A 8800' 11500' 6594' 6580' 2'/",4.7#, L-80, ST-L slotted liner; aluminum billet on top. 11500' 6474' 6605 2%",4.7#, L-80, ST-L slotted liner; 1H-19AL1 8515 deployment sleeve on top. 1H-19AL2 8495' 11500' 6459' 6510' 2'/",4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Page 3 of 8 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 42' 121' 0' 121' 1640 630 Surface 9-5/8" 40 L-80 BTC 42' 5345' 0' 4270' 5750 3090 Casing 7" 26.0 J-55 AB-Mod 35' 8970' 0' 6913' 4980 4330 Tubing 3-1/2" 9.3 J-55 ABM-EUE 38' 8560' 0' 6603' 6990 7400 Tubing 2-7/8" 6.5 NA NA 8560' 8600' 6603' 6632' 7260 7680 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Flo-Pro FloVis mud (9.6 ppg) — Drilling operations: Chloride-based Flo-Pro FloVis mud (9.6 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1H-19 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes(-200 bbl)of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.0 ppg will be initially targeted at the window based on the recent static bottom hole pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 4 of 8 e 1/7/2013 PTD Application: 1 H-1 9A, 1 H-19AL1, & 1 H-1 9AL2 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 Background Well 1H-19 is a Kuparuk A-sand/C-sand injection well equipped with 3'/2"tubing and 7"production casing with the C-sand behind a straddled selective. Three proposed A-sand CTD laterals will increase reservoir exposure in two adjoining fault blocks. Prior to drilling,the existing C-sand perfs in 1H-19 will be plugged with cement to provide a means to kick out of the 3-1/2"and 7"casing. The existing A-sand perfs will be plugged off with a CA-2 plug in the tubing tail,then covered with cement when the C-sands are cemented. The well is currently an injector,however the injection point will be moved to—250' from the upper packer, once the C-sands are cemented and the windows are milled. The 3-1/2"tubing in the C-sand selective straddle will be perforated in two intervals to allow cement in the 3-1/2"by 7"annulus. The intervals will be at the whipstock setting locations with 10' of perforations. After plugging off the existing A&C-sand perfs with cement,mechanical whipstocks will be placed in the 3-1/2"tubing at the planned kickoff points. The 1H-19A sidetrack will exit through the 3-1/2"tubing and 7"casing at 8,515' MD and will target the A4 sand west of the existing well with a 2985' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 11,500' MD with an aluminum billet at 8,800' MD. The 1H-19AL1 lateral will kick off from the aluminum billet at 8,800' MD and will target the A3 sand west of the existing well with a 2700' lateral. The hole will be completed with a 2%" slotted liner to the TD of 7 11,500' MD with the liner top located inside the 3'h"tubing at 8,510' MD V The 1H1-9AL2 sidetrack will exit through the 3-1/2"tubing and 7"casing at 8,495' MD and will target the �4A ,sanusouth'of the existing well with a 2805' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,500' MD with the final liner top located inside the 3'/2"tubing at 8,490'MD. Page 5 of 8 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 Pre-Rig Work (As per submitted Sundry) 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC. 3. MIT-IA 4. RU slickline. Tag fill,drift dummy whipstock 5. RU Eline:GR/CCL/CBL Logs for jewelry correlation and bond log 6. RU Eline: Perforate tubing at 8,510' and 8,490' RKB 7. RU slickline. Set CA-2 plug in tubing tail nipple,set BPC sleeve in the AVA BPL nipple 8. RU coil:Place cement in the 3-1/2"tubing from the CA-2 up to 8,490' and in the annulus of the C-sand straddle 9. RU slickline. Tag top of cement and pressure test. RD slickline. 10. RU coil:Mill out cement in the 3-1/2"tubing down to the BPC sleeve in the AVA BPL nipple 11. 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. 1H-19A Sidetrack(A4 sand,west) a. Set whipstock at 8,515'MD b. Mill 2.80"window at 8,515'MD. c. Drill 2.70"x 3.25"bi-center lateral to TD of 11,500' MD d. Run 23/8"slotted liner with an aluminum billet from TD up to 8,800'MD 3. 1H-19AL1 Lateral(A3 sand,west) a. Kick off of the aluminum billet at 8,800' MD b. Drill 2.70"x 3.25"bi-center lateral to TD of 11,500'MD c. Run 23/8"slotted liner from TD up to 8,510' MD,up inside the 31/2"tubing tail 4. 1H-19AL2 Lateral(A4 sand,south) a. Set whipstock at 8,495' MD b. Mill 2.80"window at 8,495'MD. c. Drill 2.70"x 3.0"bi-center lateral to TD of 11,500'MD d. Run 23/8"slotted liner from TD up to 8,490'MD,up inside the 31/2"tubing tail 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 pre-production before injection 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 listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment,the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. Page 6 of 8 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment,the steps listed above are observed, only in reverse. Liner Running — The 1H-19 CTD laterals will be displaced to an overbalancing fluid (12 ppg Na-Br) prior to running liner. See the"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 1H-19A 9750 1 H-19AL1 9760 1 H-19AL2 9710 — Distance to Nearest Well within Pool(toe measured to offset well) Lateral Name Distance Well 1H-19A 1150 1R-02 1 H-19AL1 1100 1R-02 1 H-19AL2 1100 1H-03 Page7of8 nntri. N1 1/7/2013 PTD Application: 1H-19A, 1 H-19AL1, & 1 H-19AL2 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within %-mile of the proposed 1H-19 CTD laterals are the 1H-19 motherbore and 1 R-02. The casing and cementing of 1H-19 is described below. The A&C-sand perforations will be permanently plugged as part of this CTD sidetrack proposal. See the attached schematic for clarification. 1H-19 Mother Bore Well 1H-19 was drilled and completed in 1993. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,970' MD in the Miluveach. 1H-19 is a Service well with a"Normal Well"Ann-Comm status,was capable of injecting to both of the Kuparuk A&C sands with a straddle completion. The C-sand will be cemented off during the pre-rig procedures(Sundry#312-473). 1R-29 Well 1R-29 (PTD#191-094)was drilled and completed in 1991. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 11,331' MD in the Miluveach. 1 R-29 was a Production well with a"Normal Well"Ann-Comm status, capable of producing both of the Kuparuk A&C sands with a straddle completion. It has recently been sidetracked in the Kuparuk A sand with Coiled Tubing Drilling. The original C-sand is still accessible via the selective straddle completion. The original A-sand was cemented off, and is now accessed by the 4 laterals that were completed with 2-3/8"4.7ppf L-80 slotted liner. The 1H-19 to 1R-29 Center to Center distance is roughly 1270 feet; the 1H-19 laterals will be the injector offset to the 1R-29 production laterals. 1R-02 Well 1R-02 (PTD#185-176)was drilled and completed in 1985. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 9,291' MD in the Miluveach. 1R-02 is a Production well with a"Normal Well"Ann-Comm status, capable of producing both of the Kuparuk A&C sands with a straddle completion. The last SBHP for the A sand was 2261 psi in Sept. '11, and the C sand measured 2485 psi. 1H-03 Well 1 H-03 (PTD#182-115)was drilled and completed in 1982. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 8,141' MD in the Miluveach. 1 H-03 is a Service well with a"Normal Well"Ann-Comm status, and capable of injecting to both of the Kuparuk A&C sands with a straddle completion. The well will be shut-in prior(4 weeks)to CDR2-AC arrival to 1H-19. The last SBHP measured 3970 psi (12.1 ppg EMW)on Oct. '12. 17. Attachments Attachment 1: Directional Plans for 1H-19A, 1H-19AL1, & 1H-19AL2 Attachment 2: Current Well Schematic for 111-19 Attachment 3: Proposed Well Schematic for 1H-19A, 1H-19AL1, & 1H-19AL2 Page 8 of 8 1/10/2013 rsEcwl ��,►�Zo13 PTD Application: 1H-19A, 1 H-19AL1, & 1 '-19AL2 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within 14-mile of the proposed 1H-19 CTD laterals are the 1H-19 m 6 herbore and 1 R-02. The casing and cementing of 1H-19 is described below. The A&C-sand perforations , II be permanently plugged as part of this CTD sidetrack proposal. See the attached schematic for clarif ation. 1H-19 Mother Bore Well 1H-19 was drilled and completed in 1993. The 7", 26 ppf, J-55, BTC-Mod •roduction casing was set at 8,970' MD in the Miluveach. 1H-19 is a Service well with a"Normal Well"An -Comm status,was capable of injecting to both of the Kuparuk A&C sands with a straddle completion. T - C-sand will be cemented off during the pre-rig procedures(Sundry#312-473). 1R-02 Well 1R-02 (PTD#185-176)was drilled and completed in 1985. T - 7",26 ppf, J-55, BTC-Mod production casing was set at 9,291' MD in the Miluveach. 1R-02 is a Produ ion well with a"Normal Well"Ann-Comm status, capable of producing both of the Kuparuk A&C sands ,ith a straddle completion. The last SBHP for the A sand was 2261 psi in Sept. '11, and the C sand measu -d 2485 psi. 1H-03 Well 1H-03(PTD#182-115)was drilled and complete. n 1982. The 7",26 ppf, J-55, BTC-Mod production casing was set at 8,141' MD in the Miluveach. 1H-0 is a Service well with a"Normal Well"Ann-Comm status, and capable of injecting to both of the Kuparuk A : sands with a straddle completion. The well will be shut-in prior(4 weeks)to CDR2-AC arrival to 1H-19. Th- last SBHP measured 3970 psi (12.1 ppg EMW)on Oct. '12. 17. Attachments Attachment 1: Directional Plans fir 1H-19A, 1H-19AL1, & 1H-19AL2 Attachment 2: Current Well So,ematic for 1H-19 Attachment 3: Proposed We Schematic for 1H-19A, 1H-19AL1, & 1H-19AL2 Page 8 of 8 1/7/2013 KUP 1H-19 ConocoPhillips r. 4 Well Attributes Max Angle&MD TD Alaska, � Wellbore API/UWI Field Name Well Status Intl(') MD(ftKB) Act Btm(MB) carlorslFtallps 500292231200 KUPARUK RIVER UNIT INJ 46.17 5,677.00 8,990.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Canna:-1H-19,10/9/201 r!18:36:06 AM SSSV:WRDP Last WO: , 6/14/1993 12/18/1992 ■ Scnematk-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,683.0 10/2/2012 Rev Reason:GLV C/O,TAG,PULL SLEEVE ninam 10/9/2012 Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,38 CONDUCTOR 16 15.060 41.9 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 41.9 5,344.6 4,269.9 40.00 L-80 BTC P Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.2 8,970.2 6,913.2 26.00 J-55 AB-MOD Tubing Strings Tubing Description String 0... String ID...Top(01KB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 3.5x 2.875 31/2 2.992 37.6 8,599.8 6,632.4 9.30 J-55 ABM-EUE Completion Details CONDUCTOR,___ r Top Depth . 42-t21 (ND) Top Intl Nora.. Top(MB) (510B) (°) Item Description Comment ID(in) 37.6 37.6 0.05 HANGER FMC GEN IV HANGER 3.500 • I - - 1,810.1 1,692.1 37.81 NIPPLE OTIS SELECTIVE LANDING NIPPLE 2.813 NIPPLE.1,810 8,229.7 6,360.9 43.39 PBR OTIS PBR 2.970 I, 8,241.9 6,369.8 43.66 PACKER OTIS HVT RETRIEVABLE PACKER 2.972 8,337.2 6,439.1 43.19 BLASTJTS BLAST JOINTS 2.992 8,526.6 6,578.1 42.32 NIPPLE AVA BPL PORTED NIPPLE 2.320 li 8,560.7 6,603.4 42.08 XO Reducing CROSSOVER 3.5 x 2.875 2.875 8,565.5 6,607.0 42.05 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.406 8,568.6 6,609.3 42.03 PACKER BAKER D PERMANENT PACKER(2'SPACE OUT ABOVE PKR) 3.250 8,587.3 6,623.2 41.84 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,599.0 6,631.8 41.82 SOS OTIS SHEAR OUT SUB.ELMD TTL 8596'ON 5/29/06 2.441 SU 42-5,345 RFACE._. / Perforations&Slots Shot Top(TVD) Bern(ND) Dens Top(ftKB) Btm(RKB) (ftKB) (ftKB) Zone Date (3D- Type Comment I cnsel��_. 8,340 8,404 6,441.1 6,487.9 0-4,C-3,1H-19 6/14/1993 12.0 IPERF 60 deg Phasing 8,430 8,470 6,506.9 6,536.3 C-2,C-1,UNIT 6/14/1993 12.0 IPERF 60 deg Phasing B,1H-19 8,673 8,693 6,687.0 6,702.0 A-4,1H-19 2/18/2007 6.0 RPERF 0 deg Phasing 8,706 8,726 6,711.7 6,726.8 A-3,1H-19 2/18/2007 6.0 RPERF 0 deg Phasing P00.8,230 Motes:General&Safety PACKER,8,242- End Date Annotation 9/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 2/1/2011 NOTE:APPARENT C-SAND LEAK @ 8294'MANDREL INJECTION, 8.294 I IPERF, 8,34041,404 - IPERF. I e,430-e,470 NIPPLE,8,527 - { SEAL ASSY, 8,566 • PACKER,8,569 1 NIPPLE,8507 111 SOS.8.599-- Mandrel Details _ _ Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) I') Make Model (in) Sera Type Type ON (psi) Run Date Com... 1 8,179.8 6,324.6 43.40 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/14/2010 RPERF, 2 8,294.0. 6,407.6 43.36 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 10/6/2012 EM 8.673-8.693 pkg RPERF. 8,706-8.726 PRODUCTION, ( y� 35 8,970� • g q 4 I "' ,t, r 1 S� ad yy 1 9 6 8 �v u �r �s,..a o _ a N d in o°m v g m M 0 M 3 o U Q N p 1,I N Q N J N T 0) m d T r II a u E =o ac` O m @J O 'C S Q III CU co 7 Y N v N _N C co b. 1) v 9 m V v 0 a co b CV Q al m i-.0 V V •G] (D IIj R 'C ) O co Y co N O • O U C 10 . 0 N —N v f0 b O v I�N 45 co~ T C N C CD m tT p @ GV N E co @) F o 3 m a m E rig O U Ni n a — o m v @�v a O N M Q N O Q N o O C C E O) N O .c o. Q)m a 0 co co .• m L7 (' N C �1 o.cs O V C CU a m o 0 3 l0 m'� `p N Y a 0, It 00 Q. 'al 00 m 8- M OU a w 0) E d' E W < x o_Er, 0) N iv- N m 0 O rn v �S v W < cJo0rl N (V N M2 (V cV N N N oD 3 U N __ Y Y 0)• C') 0') 0 M M M co CO N I d V I rn a= m ii ii -!: „:,...::::::.--- ill 1 i A �� .. f�. . .NYC�a ,.,:,...,,,:v A-' 11,F \ , E 1 E, III ^_L;Cr�CKLti1'){.1 4L., 4 �,� Y %ef 1:111 .......% Ilr---1 #D D =0---, a w o w o � � Q QM o "� v V V '•) ° a m cB v 3 a vm CL L a ,a U Co v a O il ° m io o N Q. N m vI 2o o O) L CO V N co ° Cy M j V n@ CI co s � No rl Qa I o r �� .,..._ OR I 01 $ _ .__ ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1H Pad 1H-19 1 H-19AL2 Plan: 1 H-19AL2_wp06 Standard Planning Report 03 January, 2013 r 1111 BAKER HUGHES 0 C; ' [Lw Baker Hughes raI ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 11-1-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-19 @ 96.00ft(1H-19) Site: Kuparuk 1H Pad North Reference: True Well: 1H-19 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-19AL2 Design: 1 H-19AL2_wp06 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 1H Pad Site Position: Northing: 5,979,968.84ft Latitude: 70°21'21.831 N From: Map Easting: 549,197.16ft Longitude: 149°36'1.675 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1H-19 Well Position +N/-S 0.00 ft Northing: 5,980,118.88 ft Latitude: 70°21'23.308 N +E/-W 0.00 ft Easting: 549,186.59 ft Longitude: 149°36'1.955 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1H-19AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 12/31/2012 16.03 79.99 57,387 Design 1 H-19AL2_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,489.95 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) 0.00 0.00 0.00 210.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°1100ft) (°1100ft) (0) Target 8,489.95 42.38 331.51 6,455.03 4,443.37 -2,416.86 0.00 0.00 0.00 0.00 8,495.00 42.36 331.49 6,458.76 4,446.36 -2,418.49 0.48 -0.40 -0.40 -146.03 8,520.00 46.86 331.49 6,476.55 4,461.78 -2,426.86 18.00 18.00 0.00 0.00 8,613.20 88.80 331.49 6,510.94 4,535.94 -2,467.15 45.00 45.00 0.00 0.00 8,713.20 89.15 286.48 6,512.83 4,597.24 -2,542.88 45.00 0.35 -45.01 270.00 9,013.20 89.27 256.48 6,517.07 4,604.91 -2,839.34 10.00 0.04 -10.00 270.00 9,213.20 89.07 236.48 6,520.01 4,525.51 -3,021.77 10.00 -0.10 -10.00 269.30 9,363.20 96.53 249.52 6,512.65 4,457.64 -3,154.86 10.00 4.97 8.69 60.00 9,463.20 100.33 240.17 6,497.96 4,415.68 -3,244.29 10.00 3.81 -9.35 293.00 9,713.20 90.01 217.27 6,475.15 4,252.44 -3,429.62 10.00 -4.13 -9.16 247.00 10,263.20 88.78 162.28 6,481.49 3,731.04 -3,519.51 10.00 -0.22 -10.00 268.50 10,713.20 89.13 207.29 6,490.14 3,294.14 -3,556.10 10.00 0.08 10.00 90.00 11,163.20 88.33 162.28 6,500.65 2,857.27 -3,592.72 10.00 -0.18 -10.00 268.50 11,500.00 88.61 195.98 6,509.93 2,525.47 -3,587.69 10.00 0.08 10.00 90.00 1/3/2013 4:46:14PM Page 2 COMPASS 2003.16 Build 69 ' Baker Hughes Ilrer ConocoPhilluS p s Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1H-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-19 @ 96.00ft(1H-19) Site: Kuparuk 1H Pad North Reference: True Well: 1H-19 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-19AL2 Design: 1 H-19AL2_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-IN Section Rate Azimuth Northing Easting (ft) (0) (1 (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,489.95 42.38 331.51 6,455.03 4,443.37 -2,416.86 -2,639.64 0.00 0.00 5,984,545.85 546,740.84 TIP 8,495.00 42.36 331.49 6,458.76 4,446.36 -2,418.49 -2,641.42 0.48 -146.03 5,984,548.83 546,739.20 KOP 8,500.00 43.26 331.49 6,462.43 4,449.34 -2,420.11 -2,643.19 18.00 0.00 5,984,551.81 546,737.56 8,520.00 46.86 331.49 6,476.55 4,461.78 -2,426.86 -2,650.58 18.00 0.00 5,984,564.20 546,730.72 Start 45 dls 8,600.00 82.86 331.49 6,509.98 4,524.38 -2,460.87 -2,687.79 45.00 0.00 5,984,626.56 546,696.31 8,613.20 88.80 331.49 6,510.94 4,535.94 -2,467.15 -2,694.67 45.00 0.00 5,984,638.09 546,689.95 4 8,700.00 89.07 292.42 6,512.62 4,592.85 -2,530.44 -2,712.30 45.00 -90.00 5,984,694.57 546,626.29 8,713.20 89.15 286.48 6,512.83 4,597.24 -2,542.88 -2,709.89 45.00 -89.24 5,984,698.88 546,613.83 Start 10 dls 8,800.00 89.16 277.80 6,514.11 4,615.48 -2,627.65 -2,683.30 10.00 -90.00 5,984,716.56 546,528.95 8,900.00 89.20 267.80 6,515.55 4,620.36 -2,727.39 -2,637.65 10.00 -89.87 5,984,720.78 546,429.19 9,000.00 89.26 257.80 6,516.90 4,607.85 -2,826.47 -2,577.28 10.00 -89.73 5,984,707.62 546,330.20 9,013.20 89.27 256.48 6,517.07 4,604.91 -2,839.34 -2,568.30 10.00 -89.59 5,984,704.60 546,317.36 6 9,100.00 89.17 247.80 6,518.26 4,578.32 -2,921.87 -2,504.01 10.00 -90.70 5,984,677.47 546,235.01 9,200.00 89.08 237.80 6,519.79 4,532.67 -3,010.69 -2,420.07 10.00 -90.58 5,984,631.25 546,146.50 9,213.20 89.07 236.48 6,520.01 4,525.51 -3,021.77 -2,408.32 10.00 -90.43 5,984,624.01 546,135.46 7 9,300.00 93.41 244.00 6,518.13 4,482.48 -3,097.03 -2,333.42 10.00 60.00 5,984,580.49 546,060.49 9,363.20 96.53 249.52 6,512.65 4,457.64 -3,154.86 -2,283.00 10.00 60.16 5,984,555.28 546,002.84 8 9,400.00 97.96 246.10 6,508.01 4,443.85 -3,188.65 -2,254.16 10.00 -67.00 5,984,541.27 545,969.14 9,463.20 100.33 240.17 6,497.96 4,415.68 -3,244.29 -2,201.95 10.00 -67.43 5,984,512.73 545,913.70 9 9,500.00 98.88 236.74 6,491.82 4,396.70 -3,275.20 -2,170.05 10.00 -113.00 5,984,493.55 545,882.91 9,600.00 94,78 227.55 6,479.90 4,335.82 -3,353.47 -2,078.19 10.00 -113.57 5,984,432.17 545,805.05 9,700.00 90.57 218.47 6,475.22 4,262.86 -3,421.51 -1,980.99 10.00 -114.67 5,984,358.77 545,737.49 9,713.20 90.01 217.27 6,475.15 4,252.44 -3,429.62 -1,967.91 10.00 -115.09 5,984,348.30 545,729.46 10 9,800.00 89.78 208.60 6,475.31 4,179.66 -3,476.76 -1,881.31 10.00 -91.50 5,984,275.22 545,682.80 9,900.00 89.53 198.60 6,475.92 4,088.14 -3,516.75 -1,782.06 10.00 -91.48 5,984,183.44 545,643.42 10,000.00 89.29 188.60 6,476.96 3,991.07 -3,540.23 -1,686.26 10.00 -91.42 5,984,086.23 545,620.58 10,100.00 89.07 178.60 6,478.40 3,891.41 -3,546.51 -1,596.80 10.00 -91.32 5,983,986.54 545,614.96 10,200.00 88.88 168.60 6,480.19 3,792.17 -3,535.38 -1,516.43 10.00 -91.18 5,983,887.39 545,626.73 10,263.20 88.78 162.28 6,481.49 3,731.04 -3,519.51 -1,471.42 10.00 -91.00 5,983,826.37 545,643.00 11 10,300.00 88.78 165.96 6,482.27 3,695.66 -3,509.45 -1,445.81 10.00 90.00 5,983,791.06 545,653.30 10,400.00 88.81 175.97 6,484.38 3,597.05 -3,493.77 -1,368.25 10.00 89.92 5,983,692.56 545,669.62 10,500.00 88.88 185.97 6,486.40 3,497.21 -3,495.45 -1,280.95 10.00 89.71 5,983,592.73 545,668.59 10,600.00 88.98 195.97 6,488.27 3,399.18 -3,514.45 -1,186.55 10.00 89.51 5,983,494.58 545,650.24 10,700.00 89.11 205.97 6,489.94 3,305.93 -3,550.19 -1,087.93 10.00 89.32 5,983,401.11 545,615.12 10,713.20 89.13 207.29 6,490.14 3,294.14 -3,556.10 -1,074.75 10.00 89.15 5,983,389.28 545,609.28 12 10,800.00 88.92 198.61 6,491.62 3,214.30 -3,589.91 -988.71 10.00 -91.50 5,983,309.22 545,576.00 10,900.00 88.70 188.61 6,493.70 3,117.25 -3,613.41 -892.91 10.00 -91.35 5,983,212.03 545,553.14 11,000.00 88.52 178.61 6,496.13 3,017.60 -3,619.70 -803.47 10.00 -91.14 5,983,112.36 545,547.51 11,100.00 88.39 168.61 6,498.84 2,918.39 -3,608.59 -723.10 10.00 -90.90 5,983,013.23 545,559.27 11,163.20 88.33 162.28 6,500.65 2,857.27 -3,592.72 -678.11 10.00 -90.63 5,982,952.22 545,575.54 1/3/2013 4:46:14PM Page 3 COMPASS 2003.16 Build 69 Baker Hughes KE" Conocohillips e BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference;,,,,; Well 1H-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit M tit .^ 1H-19 @ 96.00ft(1H-19) Site: Kuparuk 1H Pad p NI�� ' '' True Well: 1H-19 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-19AL2 Design: 1H-19AL2_wp06 ., Planned Survey Measured ND 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) 13 11,200.00 88.33 165.97 6,501.73 2,821.90 -3,582.66 -652.50 10.00 90.00 5,982,916.92 545,585.83 11,300.00 88.37 175.97 6,504.61 2,723.30 -3,566.99 -574.95 10.00 89.89 5,982,818.44 545,602.14 11,400.00 88.47 185.97 6,507.37 2,623.48 -3,568.68 -487.66 10.00 89.60 5,982,718.62 545,601.11 11,500.00 88.61 195.98 6,509.93 2,525.47 -3,587.69 -393.27 10.00 89.33 5,982,620.49 545,582.74 TD at 11500.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape r) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1H-19 Fault 1 0.00 0.00 0.00 9,066.24 -4,104.07 5,989,157.09 545,023.48 70°22'52.462 N 149°38'2.077 W -plan misses target center by 7998.45ft at 9013.20ft MD(6517.07 TVD,4604.91 N,-2839.34 E) -Polygon Point 1 0.00 9,066.24 -4,104.07 5,989,157.09 545,023.48 Point 2 0.00 6,724.80 -4,232.34 5,986,815.09 544,910.60 Point3 0.00 9,066.24 -4,104.07 5,989,157.09 545,023.48 1H-19 CTD Polygon_No 0.00 0.00 0.00 6,714.82 -4,229.55 5,986,805.14 544,913.46 70°22'29.335 N 149°38'5.710 W -plan misses target center by 6958.18ft at 9600.00ft MD(6479.90 TVD,4335.82 N,-3353.47 E) -Polygon Point 1 0.00 6,714.82 -4,229.55 5,986,805.14 544,913.46 Point2 0.00 5,030.71 -2,247.29 5,985,134.24 546,906.54 Point 3 0.00 4,232.87 -2,440.51 5,984,335.23 546,718.58 Point4 0.00 6,042.39 -4,482.96 5,986,131.12 544,664.49 Point 5 0.00 6,714.82 -4,229.55 5,986,805.14 544,913.46 1 H-19AL2_T1 0.00 0.00 6,517.00 4,603.50 -2,843.25 5,984,703.16 546,313.45 70°22'8.577 N 149°37'25.124 W -plan hits target center -Point 1H-19 CTD Polygon_So 0.00 0.00 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 70°22'17.378 N 149°37'57.410 W -plan misses target center by 6610.10ft at 9600.00ft MD(6479.90 TVD,4335.82 N,-3353.47 E) -Polygon Point 1 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 Point 2 0.00 4,756.24 -3,100.24 5,984,854.20 546,055.49 Point 3 0.00 2,257.57 -3,503.56 5,982,353.18 545,668.62 Point 4 0.00 2,270.54 -3,958.53 5,982,363.16 545,213.62 Point 5 0.00 5,498.84 -3,946.50 5,985,591.16 545,204.45 1 H-19 Fault 2 0.00 0.00 0.00 7,380.77 -869.79 5,987,493.06 548,268.44 70°22'35.896 N 149°36'27.407 W -plan misses target center by 7258.73ft at 8489.95ft MD(6455.03 TVD,4443.37 N,-2416.86 E) -Polygon Point 1 0.00 7,380.77 -869.79 5,987,493.06 548,268.44 Point 2 0.00 4,934.65 -1,048.75 5,985,046.06 548,105.56 Point 3 0.00 7,380.77 -869.79 5,987,493.06 548,268.44 1 H-19AL2_T3 0.00 0.00 6,505.00 2,723.08 -3,566.70 5,982,818.22 545,602.44 70°21'50.080 N 149°37'46.260 W -plan hits target center -Point 1 H-19AL2_T2 0.00 0.00 6,477.00 4,308.01 -3,381.26 5,984,404.18 545,777.45 70°22'5.669 N 149°37'40.858 W -plan hits target center -Point 1/3/2013 4:46:14PM Page 4 COMPASS 2003.16 Build 69 p pp �k L zA 1 1 t„m 1 6 `S' f i .o:. Baker Hughes a/- ConocoPhillliips Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1H-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-19 @ 96.00ft(1 H-19) Site: Kuparuk 1H Pad North Reference: True Well: 1H-19 Survey Calculation Method: Minimum Curvature Wellbore: 1H-19AL2 Design: 1 H-19AL2_wp06 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 5,345.00 4,174.22 9 5/8" 9-5/8 12-1/4 11,500.00 6,509.93 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,489.95 6,455.03 4,443.37 -2,416.86 TIP 8,495.00 6,458.76 4,446.36 -2,418.49 KOP 8,520.00 6,476.55 4,461.78 -2,426.86 Start 45 dls 8,613.20 6,510.94 4,535.94 -2,467.15 4 8,713.20 6,512.83 4,597.24 -2,542.88 Start 10 dls 9,013.20 6,517.07 4,604.91 -2,839.34 6 9,213.20 6,520.01 4,525.51 -3,021.77 7 9,363.20 6,512.65 4,457.64 -3,154.86 8 9,463.20 6,497.96 4,415.68 -3,244.29 9 9,713.20 6,475.15 4,252.44 -3,429.62 10 10,263.20 6,481.49 3,731.04 -3,519.51 11 10,713.20 6,490.14 3,294.14 -3,556.10 12 11,163.20 6,500.65 2,857.27 -3,592.72 13 11,500.00 6,509.93 2,525.47 -3,587.69 TD at 11500.00 1/3/2013 4:46:14PM Page 5 COMPASS 2003.16 Build 69 3 1 i a '.. g 19 1 11 4 3 /• ' / 'g S \ I 8 9 • 1 ' 3 g1 a N 1' 8 8 std /-/' _ �1 • ,=, , 8 4 ifs 8 !ell' ▪ m M 1" ;8 _ v -. .. 8 8 F a al N "v N • _� M Y O I- `o s gg gg w O a. o (ui/8 00Z)(+)gJJoN/(-)43noS 8 rNi m • A._ O ati `d .4i 0 '. -2� �5 F II 2g°8 o 1 ° 0 8 3. z v R az t P. 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H■•os H■ •p.H•p■p•. 1111111:1111111 Bme:mBB:Biia:BBaaaaB B a u:B:BmmmuBB: a�aaaa�aaaa�mmmaasH:ma�a�me°aa mm 0 O 0 - - - 0 O 0 0 00 G O O o O U O O 0 O W O 0 b 0 '0 N O 0 O N 0`- 0 0 a a' co r r n O v, 0 0 0 rn rvf r. N N — ^_ ^ (ut OSE)(+)911oN/(-)111nos Bettis, Patricia K (DOA) From: Ohlinger, James J [James.J.Ohlinger @conocophillips.com] Sent: Thursday, January 10, 2013 4:06 PM To: Bettis, Patricia K(DOA) Cc: Allsup-Drake, Sharon K Subject: 1H-19 PTD update Attachments: 1H-19A CTD Spider 10-Jan-2013- NAD27.pdf; 1H-19 CTD PTD Application_Page 8.pdf Please find the attached updated PTD (Page 8) with the 1 R-29 1/4 mile review, and an updated spider plot. 1H-19 to 1R-29 Center to Center distance is roughly 1270 feet, we're still trying to determine why it was missed in the survey scan. Please let me know if you need any further information, Thank You. James°Binger Senior CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-854-2414 cell 1 TRANSMITTAL LETTER CHECKLIST WELL NAME MU,. 1I-E-19AC,2 PTD# a13ooy Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: 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 111- 19 4 (If last two digits in well KAu..Permit No. c2/J 3bd2_ ,API No. 50- - API number are 029 x312-01 - 60 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. Rev:9/09/2011 ra N m 0 a) 0- N N_ N 0 N _N 7 c N N c c0 Q U c>o CO CL a) E _ 0 c m 3 C7 M 3 c ° o ca O a E E m zm a n a) o c m c `p 0 0 0 co a) o CC -c .. d n E a 3 O - U • u) O c N co E Y a) 0 o c a) o 0) T •c O c (9 O 3 n c O E O Z O 0) (fl 2 o _ n o) a) 0) N c N O- CA a) O` 0 7 ) CO E a a` O 3 aa) a N o) T = a) ▪ L 3 n o a` c o 3 „- o aa) 0- O (0 a) 0 T _ - a)) _ 7 0. ` 'C U e 0 -0 a) a) U o_ N '00 = 5 0- a) n ✓ 0 n 0 a) o .-- a) _0 O - CA N n 3 a > W N a) ▪ N N N C (6 .-' CA ((6n O 0) '6 3 3 E Q = ° 3 • aa) a o 2 n 3@ o 2 co 0 a c 2 '7 c a) ? 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