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212-127
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cJ ca - j tl 7 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES OVERSIZED: NOTES: Color Items: ❑ Maps. rayscale Items: ogs: 17/ ❑ Poor Quality Originals: ❑ Other: ❑ Other: C BY: Maria Date: 'a• 57 pq- /s/ Pe Project Proofing 1/14P BY: _ . Date: I 915 /if /s/ Scanning Preparation cL x 30 = / w + I = TOTAL PAGES ( / ^ (Count does not include cover sheet) BY: d Date: .IS /s/ IYI Production Scanning Stage 1 Page Count from Scanned File: b a. (Count does include cove heet) Page Count Matches Number in Scanning Preparation: YES MP BY: Date: 169131/Lf. /s/Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc co o c c o 8 1 co o > o > m m Q Q �¢ ' a) mX To CL a)CL ,Wo. � Z/ Z /Z t"1 O m a3 co a) O - Z 0Lr) a E o.E co O E N E O„_ >- >- >- N = E E a coE E E co c E + NU I 0 a a O ° NN ClaO WO O O 0O Ow N I o a3 E;.-- a) ..-. a) a) a) a 0 m f° to N E: z•>- E =.> E 3 E mE coN c 1 c ;II mca o 2.y= 2.N- u)..«.. o......?•)= to rn Q Z Z V Oaia1°i OaNim paNiafOi � maf) 0 a ° o I II cn c 2xce 2ww r-wa 2rta 0 a U a m Q o v a) `) `o C C a) N N N N N 0 0 N 0 0 O O J J .0 1 N o N N N N N WN r r rLn 0 O N U a— -J O O O O O N Z Q 0 E c c c C c E Z Z a) 0 a) a) a) N Q c O V O O O O O U / `°� } IX Q N co a co co a co u7 . p ii O cn o. COU j ... co oo co coCCOoo a a) E .� C CL J a N c 0 0 W .. oe a 4a) U) LU LU Z c o 0 0 N W — Z a) co a) a U o /o E _J E `°Z CCZ O oQ aN I O o ) J a C ) Iv oa I w 0 0 rn00 0 0 0 a cI, ZI IIV0O CCM o ' J - C o 1- ...:...) 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J Y -c.-5 U Z_ 1 m v r J p Ce a 132 a 5 CL J U J_ NW = j1 LL d ,I U W z J C) v q Z 0 Q « I CO y I a) > I J a U CL c MIIG o r O a) O `" E 1 I V ti o 000 I J Q A 0 Z M 1 M > a Ce al 1 m N 1 1 Ci) a o qk„..► Q c c Y g IC( ci Z E E 03 Z1 ii ‘1► co N �j m F- 'C N 13 CI; N .� d Ce pLip cou c 2 co is •E n ` 0 0 a U 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 a Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions Service ❑ Stratigraphic Test El 2.Operator Name12.Permit to Drill Number: 5.Date Comp.,Susp., ConocoPhillips Alaska, Inc. orAband.: September 15,2012 212-127/ 3 Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 August 30,2012 50-029-21539-66 ' 4a Location of Well(Governmental Section) 7.Date TD Reached 14.Well Name and Number: Surface: 1561'FSL,304'FEL,Sec.29,T13N, R9E, UM August 30,2012 3N-07AL1-03 , Top of Productive Horizon 8.KB(ft above MSL): 61'RKB 15.Field/Pool(s): 1231'FNL,571'FEL,Sec.29,T13N, R9E, UM GL(ft above MSL): 33.9'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 1152'FNL, 1510'FEL,Sec.29,T13N,R9E,UM 8655'MD/6419'ND Kuparuk River Oil Pool 4b Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+ND): 16.Property Designation' Surface: x-518096 y- 6013799 Zone-4 8656'MD/6419'TVD ADL 25521 TPI: x-517816 y- 6016286 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit Total Depth: x-516878 y- 6016362 Zone-4 SSSV @ 1818'MD/1818'ND 471 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) 2612'MD/2611'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7955'MD/6439'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 35' 115' 35' 115' 24" 235 sx CS II 9.625" 36# J-55 37' 3691' 37' 3634' 12.25" 1070 sx PF"E",280 sx Class G 7" 26# L-80 37' 7040' 37' 6306' 8.5" 310 sx Class G,175 sx AS I 4.5" 12.6# L-80 6822' 7448' 6150' 6588' 6.125" 94 sx Class G 2.375" 4.6# L-80 7230' 8655' 6435' 6419' - 3" slotted liner 24.Open to production or injection? Yes a No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+ND of Top&Bottom,Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6874' 6822'MD/2598'ND slotted liner 7230'-8655'MD 6435'-6419'ND RECEIVED 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 ! 0 C T 12 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED na AOGCC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 5,2012 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/8/2012 18.5 hours Test Period--> 1213 446 1611 124% 450 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL •OIL GRAVITY-API(con.) Press. 411 504 24-Hour Rate-> 1417 638 2015 20 1 API 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descnptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071 NONE FiRr-IMS OCT 15 2011 /,T, Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only ht/�„`? , ia//6 I lo• 4-t 4Z 6 29 GEOLOGIC MARKERS(List all formations and n s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface bnefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2612' 2611' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk Al 7955' 6439' Kuparuk Al 7995' 6432' N/A Formation at total depth: Kuparuk Al 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Gary Eller @ 263-4172 Email. J.Garv.Ellert conocophillips.com Pnnted Name L.Gantt Title CTD Supervisor i Signature ( f1JnI\I1A l r ,kIz:1Phone 263-4021 Date i0//(/f 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 ND 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 3N-07AL1-03 • ConocoPhillips /= Well Attributes Max Angle&MD TD Alaska,Inc V mWellbore API/UWI Field Nae Well Status Incl(°) MD(ftKB) Act Btm(ftKB) tihps 500292153966 KUPARUK RIVER UNIT PROD 8,655.0 Comment H25(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' _SSSV:TRDP 100 12/21/2008 38.49 3/7/1986 Wall Confi9'-3N-07AL tlo-9177120123'.10'.29 PM a., = Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:LATERALS ninam 9/17/2012 HANGER,23 111 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)... String WL..String...String Top Thrd LINER AL1-03 23/8 1.995 7,229.4 8,655.0 4.70 L-80 STL Liner Details • Top Depth •• P (SOB) Top Incl Nami. Top(ftKB) (SOB) (°) Item Description Comment ID(In) 7,229.4 DEPLOY GS SHORT DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot CONDUCTOR, 11911 Top(TVD) Btm(TVD) Dens 35-115 Top(ftKB) Btm(ftKB) (ftKB) ((KB) Zone Date ON— Type Comment • 7,230 8,069 8/31/2012 32.0 SLOTS SAFETY VLV, r �__� ( 8,084 8,655 8/31/2012 32.0 SLOTS 1,818 I Notes:General&Safety End Date Annotation 9/15/2012 NOTE:ADDED LATERALS AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01,AL2-02,AL2-03 9/15/2012 NOTE:LATERAL 3N-07AL1-03 OFF MAIN WELLBORE(See Multi-lat Drawing) WINDOWA 1 (9-5/8.009 rise), 2,599-2,616 GAS LIFT, 2,640 SURFACE, A I • 37-3,691 • GAS LIFT, 4 3,895 - GAS LIFT. 4.810 — GAS LIFT, 5,545 GAS LIFT. 6.186 MI GAS LIFT. 6.736 — NIPPLE.6.791 .'... Illt . 11 . t LOCATOR. ( ` I 1 6.836 I SEAL ASSY, °. r 1-' 6,837 2.2 ' I SHOE.8.873 Mandrel Details Top Depth Top Port PRODUCTION. _ (TVD) Incl OD Valve Latch Size TRO Run 37-7,047 * Stn Top(81(81 (ftKB) (°) Make Model (In) Sery Type Type PN (psi) Run Date Corn... 1 2,639.6 2,638.8 8.90 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 WHIPSTOCK - 7,204� 2 3,894.7 3,780.8 33.62 CAMCO MMG 1 12 GAS LIFT DMY DK 0.000 0.0 7/20/2012 Wind709-7 re 3 4,809.6 4,546.2 31.66 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 WHIPSTOCK, 4 5,545.0 5,165.8 32.62 CAMCO MMG 1 12 GAS LIFT DMY DK 0.000 0.0 7/20/2012 7,238 LINER, 5 6,186.0 5,693.1 40.42 CAMCO MMG 1 12 GAS LIFT DMY DK 0.000 0.0 7/20/2012 6,822-7,448 SLOTS, 7, ri ' 6 6,735.6 6,088.8 44.59 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 7/29/2012 WHIPSTOCK s PSTOCK. 7,230 SLOTS. 8.084-0.655 LINER AL1-03. 7,229-0 \,655 \ To (3N-07AL1-03), 8,655 (N Q a) W r, 0 N 0 0 2 o m o o c6 -m r o • o_ Co • dUm_ o c-6 co ca S2 c, m J . _ -2 m o v ^7, ao t o_ V p m 2 0 Z C C_ N Q,— H r N.0 M N Q X E 9 4 - 'Cu- m '6 •- MU Ot ZC ❑ _ M N J M N0 t � N n ON N M N Z N ❑ O N ❑ ❑ CO Cora Ce li cc, M 0 ❑ ��� �� .� 0 //���� U C (�, V 2 N i7 Or 7 'O a �� Q / �p 2 E N @) -'-- Cl) co N 'C O):ccrt- V dU • r F- O] m N O C— N I--- • N C N(D a co• Ll c m N C vU o NL C0 M 2 E Cl to m a m - O N Q_ OON O iDCO x T • Q O O mU Wa• M co0O J c r U coOD ,-'r. 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" 0 •- •- m O O) N Q N O 0D n N U) m NG N O 1e 10 N O) al 1- m p M fV C1 Cl 04 0 U) CO CO co n co co CO 0 r m m 2 0 0 0 U) 1O 0 1O 1I) 1O Q 1n 1O CO 0 CO CO 04 M co co CO M M M CO CO M M M CO CO M CO CO. CO CO M CO CO — m m 0 m m m m (0 16 m 0 0 m m m (o (o m m m 0 0 m 0 10 i 0) 0 m 0 N CI N- 1s- 0 CO CO CO M m 0 N 0 N 0 CO CO O 3 n 0 O co. (0 co. n N- 5- 0) O co m ' O O CO CO Q N 0 r CO 1 0 O) m N CV CO 0) CV CO m 0) 0 O) O) r U) V of N .- 0 N O 0 V V O O M M M t0 N N N N 0 $ Q Q Q Q Q cc Q Q v Q v Q Q Q Q Q Q Q Q p. m m m m m m co m (Lida 5 co m 10 m m 2 tri cd to 10 m 10 m co 0 C t Y N (0 C S N0 O0 N Q m Q m m 0) N M Q N M m m m m 0M O N 0 p 0r0 Q = -Q N ° 0 0 O) 2 0 Qi Q M) kyf0 O NNCNNO (0 N V N N O 8 O 0W 0 m) 14 Y "A._ j d Q —... NNNNN NNNNN N NNN N N N N N n - _, L LL 0) limm ,- 0- Y Y •- o29 h ti 0 S O m 8 IT, 0 0 m S. W0 m IT, N Om O 0 -i 0 0O a Q a o .. O 10 C O O O 0 .Q Uo o rn m m m 0 rn rn rn m rn rn m rn rn rn rn rn m '8 m m m LL ZZZ U i O o NV ` O 2 O N . N C m 0) U) p o 4 P 0 mn 11a n 14_ v, O ) O O UI O8O O 0 0 0 O O 0 0 0 O O 000 G mit.: m NCO C 0) 0 ^ 0 0 8 m " N Q N O M Mm O) N Q m 1q 0O00 Cl O .. a d c O 81 d 2 — r. r m au mao a6 ao aoamm 6 ao a6 co 06 m ad d 6 d 0 ad 06 0 Uvd N a u, o m o ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 3N-07 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/15/2012 6:00:00 PM Rig Release: 9/15/2012 9:00:00 PM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08/15/2012 24 hr Summary Move rig from 3N-11 to 3N-07.Change skates on injector head.Cont.CT reel rig up 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Move rig from 3N-11 to 3N-07.Spot subs onto well.Clean up from rig move and mop complete rig. ConocoPhillips HSE corporate manager rig visit. 12:00 15:00 3.00 0 0 MIRU MOVE NUND P NU BOP's 15:00 18:00 3.00 0 0 MIRU MOVE RGRP P Start working on Skates 18:00 18:30 0.50 0 0 MIRU WHDBO SFTY P Crew change, PJSM Rig Accept at 1800 hours*** 18:30 00:00 5.50 0 0 MIRU WHDBO CTOP P Cont.working on skates.MU inner reel iron and 5K bakke psi bulk head. 08/16/2012 Complete skate change,and reel swap. Peform slack management.Cut 20'to find E-line. Peform BOPE testing.Testing state witnessed:John Crisp 00:00 06:00 6.00 0 0 MIRU WHDBO CTOP P Complete reel RU,and Injector skate change.Change brass in packoff, stab CT into injector head. 06:00 11:00 5.00 0 0 MIRU WHDBO CTOP P Install boot,fill coil and reverse circulate 1/2 coil volume to pump slack back.Cut 20'of CT to find E-line.MU CTC 11:00 18:00 7.00 0 0 MIRU WHDBO BOPE P Start BOPE test,C4 valve did not pass. Swap out at end of testing and retest.Cont.on testing 18:00 19:30 1.50 0 0 MIRU WHDBO BOPE T Shut down,Transport rig crew to Nordic 3 for changeout and walk around rig to crew change 19:30 20:00 0.50 0 0 MIRU WHDBO BOPE P Pre-Tower meeting 20:00 23:00 3.00 0 0 MIRU WHDBO BOPE P PJSM,Cont.testing BOPs 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P Swap out C4 and retest. Repair hyd. leak on upper B/S rams. BOP test went longer than contract allowed time. Long crew change due to Nordic 3 rig in road. 1800-1930 hours.This time given back to Nabors to repair leaks. 08/17/2012 Pull BPV.MU BHI drilling head. Pump slack forward. PU/MU/RIH whipstock.Set TOWS 7238'. 10deg LOHS. PU/MU/RIH milling assembly.Mill a 4 1/2"single string window exit. 00:00 02:00 2.00 0 0 MIRU WHDBO CTOP P Pull test CTC 35K.MU BHI drilling head. 02:00 03:00 1.00 0 0 MIRU WHDBO BOPE P Pull BPV Page 1 of 26 Time Logs Date From To Our S. Depth E. Dgpth Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 MIRU WHDBO CTOP P Pressure test CTC 4000psi.Pump slack forward. PT tiger tank line 500psi. Install Orion depth counter 04:00 04:00 0.01 7,246 SLOT WELLPF CTOP P 04:00 05:29 1.49 0 0 PROD1 RPEQP1 PULD P PU/MU whipstock BHA 05:29 10:29 5.00 0 6,878 PROD1 RPEQP1TRIP P RIH with WS 10:29 10:59 0.50 6,878 6,938 PROD1 RPEQP1 DLOG P Tie in to the K1,Correction of+16' 10:59 11:29 0.50 6,938 7,251 PROD1 RPEQP1TRIP P Continue in hole RIW 21k 11:29 14:29 3.00 7,251 7,220 PROD1 RPEQP1TRIP P Set top of WS at 7238',Swap hole over to 9.5 mud for milling window. POOH 14:29 15:41 1.20 7,220 81 PROD1 RPEQP1 PULD P PJSM, Laydown WS setting BHA. 15:41 17:41 2.00 0 0 PROD1 WHPST PULD P MU Window milling BHA#2,Surface test BHI tools, RIH with.6 degree motor. 17:41 17:56 0.25 6,880 6,880 PROD1 WHPST DLOG P Tie in depth to K1, 17:56 18:26 0.50 6,953 6,953 PROD1 WHPST SFTY P Crew Change,Shut down.Hold Pre Spud Meeting and PTM 18:26 18:41 0.25 6,880 7,241 PROD1 WHPST TRIP P Dry tag pinch point on WS 7241'.PU 34K PUW,Online with pumps 1.48 bpm,3698 ctp,20k riw 18:41 23:59 5.30 7,241 7,246 PROD1 WHPST MILL P Start milling as per program 1 FPH, 10 LOHS 3887 ctp, 17k ctw,500 wob.Start to see motorwork 7241.2'. 08/18/2012 Mill 4 1/2"single string window,TOWS 7238',TOW 7240', RA marker 7246', BOW 7247'. POOH, PU/MU/RIH drilling BHA(2.2 AKO Bi-Center bit)to drill build. Land build section 7349'.Swap out mud system to 9.9ppg Flo-Pro. POOH.PU lateral section drilling BHA. 00:00 02:45 2.75 7,246 7,249 PROD1 WHPST MILL P Cont milling as per program 1.5 bpm, 3862 ctp, 02:45 05:45 3.00 7,249 7,264 PROD1 WHPST MILL P Milling rathole 5-8 fph,2k wob. 11k ctw. 05:45 06:57 1.20 7,264 7,237 PROD1 WHPST REAM P Ream Window area as per plan. Maintaining 10 LOHS TF. Dry run @ 10fpm clean. PUW 29k 06:57 08:27 1.50 7,237 500 PROD1 WHPST TRIP P POOH,PUW 29k, BHP 3987, Holding MPD. 08:27 08:51 0.40 500 0 PROD1 WHPST SFTY P PJSM for LD Window Milling BHA#2 08:51 09:33 0.70 0 0 PROD1 WHPST PULD P At surface-850psi WHP,Close SSSV, PT by bleeding above SSSV down to 100psi and monitor for 15 mins-holding, LD Milling BHA#2 Mills 2.80 Go,2.79 No-Go. 09:33 10:33 1.00 0 0 PROD1 DRILL PULD P PU BHA 3-2.2 deg Bi-Center Bit 10:33 12:33 2.00 0 6,875 PROD1 DRILL TRIP P RIH EDC Open 12:33 13:15 0.70 6,875 7,264 PROD1 DRILL DLOG P Tie in correction of minus 14.5', Close EDC, RIH to bottom 13:15 13:45 0.50 7,264 7,220 PROD1 DRILL TRIP P Choke is plugging off. Come off of pump. PUH to Flush Choke. RBIHTB 13:45 13:57 0.20 7,220 7,264 PROD1 DRILL TRIP P Run back to bottom Page 2 of 26 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 13:57 15:09 1.20 7,264 7,311 PROD1 DRILL DRLG P OBD, 1.45bpm @ 3610psi RIW 18.8k.WHP 150, BHP 4012 15:09 16:51 1.70 7,311 7,220 PROD1 DRILL RGRP T Leak on Inner Reel Iron.Shutdown pump and PUH into casing,Pumping down the back side.Repair blown iron seal on chicksan. PT. RBIH 16:51 17:09 0.30 7,220 7,311 PROD1 DRILL RGRP T Run back in hole. ***2 hours Billable Rig Repair*** 17:09 17:39 0.50 7,311 7,349 PROD1 DRILL DRLG P BOBD, 1.45bpm @ 3608psi,RIW 18.5,WHP 140, BHP 4025 17:39 18:39 1.00 7,349 7,349 PROD1 DRILL DRLG P Crew change/PJSM.Cont drilling landing build section. 18:39 19:09 0.50 7,349 7,349 PROD1 DRILL CIRC P Swap out milling fluid 9.5ppg Flo-Pro to 9.9 ppg Flo-Pro. 19:09 21:09 2.00 7,349 0 PROD1 DRILL TRIP P POOH 21:09 21:24 0.25 0 0 PROD1 DRILL SFTY P At surface, PJSM. 21:24 21:54 0.50 0 0 PROD1 DRILL PULD P Laydown BHA 3. 21:54 22:54 1.00 0 0 PROD1 DRILL SVRG P Service Reel, Injector head,check packoffs,flush and blowdown MP choke. 22:54 23:24 0.50 0 0 PROD1 DRILL PULD P PU/MU BHA 4 23:24 00:00 0.60 72 3,300 PROD1 DRILL TRIP P RIH 08/19/2012 Drill AL1 lateral.Increase MP schedule 12.3ppg.mitigating traces of crude in returns. 00:00 01:00 1.00 3,300 6,875 PROD1 DRILL TRIP P Cont. RIH 01:00 01:30 0.50 6,875 6,875 PROD1 DRILL DLOG P Tie in depth 01:30 01:45 0.25 7,245 7,245 PROD1 DRILL TRIP P Log RA marker.TOWS-7238, TOW-7240', RA marker 7246', BOW- 7247' OW7247' 01:45 02:15 0.50 7,340 7,340 PROD1 DRILL CIRC P Oil tracers in returns, increase MP schedule 12.3ppg at the window. PU circulate.28k PUW.Returns look good on bottoms up. RBIH 02:15 04:51 2.60 7,349 7,505 PROD1 DRILL DRLG P Drill ahead 1.4bpm,3806 ctp,4100 bhp,2k wob, 100 fph. 120 whp 04:51 04:57 0.10 7,505 7,355 PROD1 DRILL WPRT P Wiper trip to window 26K PUW 04:57 05:15 0.30 7,355 7,265 PROD1 DRILL DLOG P Madd Pass 05:15 05:33 0.30 7,265 7,505 PROD1 DRILL WPRT P RBIH 05:33 07:57 2.40 7,505 7,660 PROD1 DRILL DRLG P BOBD-1.40bpm at 3598psi,BHP 4559 07:57 08:15 0.30 7,660 7,270 PROD1 DRILL WPRT P Wiper to the window 08:15 08:33 0.30 7,270 7,660 PROD1 DRILL WPRT P RIBIH 08:33 11:33 3.00 7,660 7,810 PROD1 DRILL DRLG P BOBD-1.41bpm at 3602psi, BHP 4593 11:33 11:57 0.40 7,810 7,265 PROD1 DRILL WPRT P Wiper to the window 11:57 12:09 0.20 7,265 7,287 PROD1 DRILL DLOG P Tie in to RA 7246'correction of+1ft 12:09 12:27 0.30 7,287 7,810 PROD1 DRILL WPRT P RBIH-RIW 17.5k Page 3 of 26 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 12:27 15:15 2.80 7,810 7,960 PROD1 DRILL DRLG P BOBD-1.42bpm at 3625psi,WHP 107, BHP 4159 15:15 15:45 0.50 7,960 7,265 PROD1 DRILL WPRT P Wiper to the window 15:45 16:00 0.25 7,265 7,960 PROD1 DRILL WPRT P RBIH RIW 17.5k 16:00 17:30 1.50 7,960 8,057 PROD1 DRILL DRLG P BOBD-1.40 bpm at 3650,WHP 116, BHP 4170 17:30 19:30 2.00 8,057 8,057 PROD1 DRILL WPRT P PUH 7300'.for geo wiper.27k PUW 19:30 19:45 0.25 8,057 8,058 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM,3800 CTP, 16K CTW.4168 BHP 19:45 22:00 2.25 8,058 8,058 PROD1 DRILL RGRP T PUH short in BHA. Diagnose short to be inside J box inside reel due to inner reel iron leak. PU into cased hole. Safe out reel. Repair short. ***2 hours Billable Rig Repair rate*** 22:00 00:00 2.00 7,200 8,058 PROD1 DRILL WPRT P Comm's back up and running.RBIH to drill 08/20/2012 Drill AL1 lateral. DLS(Dog Leg Severity)to low. Pull BHA to increase AKO. Undeploy/Deploy BHA. RIH, Cont.drilling AL1 lateral. 00:00 01:00 1.00 8,210 8,210 PROD1 DRILL WPRT P Cont wiper trip 01:00 01:30 0.50 8,210 8,254 PROD1 DRILL DRLG P Drill Ahead 1.4bpm,3982ctp, 130whp, 15k ctw, 1.3k wob, 100 fph. 01:30 02:00 0.50 8,254 8,254 PROD1 DRILL WPRT P PUH.Geo changeout.28k PUW 02:00 04:00 2.00 8,254 8,360 PROD1 DRILL DRLG P Drill ahead 1.4bpm,3892 ctp, 133 whp, 14k ctw,2.3k wob,90fph 04:00 05:18 1.30 8,360 7,265 PROD1 DRILL WPRT P Wiper trip to window.28K. Directional projection is telling us we will drill out of the polygon.Call town. 05:18 05:30 0.20 7,265 7,289 PROD1 DRILL DLOG P Log RA for a tie in correction of+ 1.5ft 05:30 06:00 0.50 7,289 7,920 PROD1 DRILL WPRT P RBIH RIW 19k 06:00 08:30 2.50 7,920 72 PROD1 DRILL TRIP P Town decided to POOH for AKO change 08:30 08:42 0.20 72 0 PROD1 DRILL SFTY P PJSM for Undeploying Lateral BHA# 4 08:42 09:54 1.20 0 0 PROD1 DRILL PULD P Undeploy BHA#4 09:54 10:24 0.50 0 0 PROD1 DRILL PULD P MU BHA#5 with a 1 degree heavy AKO motor 10:24 10:54 0.50 0 0 PROD1 DRILL PULD P Pressure Deploy BHA#5,Surface test BHI tools 10:54 12:54 2.00 0 7,265 PROD1 DRILL TRIP P RIH 12:54 13:06 0.20 7,265 6,952 PROD1 DRILL DLOG P Log RA for a correction of-15ft 13:06 14:06 1.00 6,952 8,360 PROD1 DRILL TRIP P RIH RIW 18.5k 14:06 16:06 2.00 8,360 8,510 PROD1 DRILL DRLG P BOBD, 1.40bpm at 3700psi,WHP 109, BHP 4212 16:06 17:36 1.50 8,510 7,270 PROD1 DRILL WPRT P Wiper to the window#1 PUW 28k 17:36 18:36 1.00 7,270 8,510 PROD1 DRILL WPRT P Wiper back in hole 18:36 20:00 1.40 8,510 8,660 PROD1 DRILL DRLG P BOBD 1.4bpm at 3780psi WHP 120, BHP 4202 Page 4 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:00 20:42 0.70 8,660 7,270 PROD1 DRILL WPRT P Wiper to the window#2 PUW 28k 20:42 21:30 0.80 7,270 8,660 PROD1 DRILL WPRT P Wiper back in hole RIW 17K 21:30 23:18 1.80 8,660 8,810 PROD1 DRILL DRLG P BOBD-1.4 bpm at 3785psi WHP 109, BHP 4226 23:18 00:00 0.70 8,810 8,810 PROD1 DRILL WPRT P Wiper to the window PUW 29k.Tie in depth+1 correction 08/21/2012 Continue drilling ahead on AU lateral.Mud swap with 1760'on system.Small weight bobble @ 8440'during wiper trips. 00:00 01:15 1.25 8,810 8,810 PROD1 DRILL WPRT P Cont wiper trip 01:15 03:00 1.75 8,810 8,960 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,4120,80 whp, 11k ctw, 03:00 05:00 2.00 8,960 8,960 PROD1 DRILL WPRT P Wiper trip to window 27k puw. 05:00 07:30 2.50 8,960 9,110 PROD1 DRILL DRLG P Drill Ahead, 1.35bpm,3972 ctp, 113 whp, 1.5 wob,80-90 fph, 11 k ctw. 07:30 10:00 2.50 9,110 9,110 PROD1 DRILL WPRT P Wiper trip to window,28k puw.Swap out mud system 10:00 11:30 1.50 9,110 9,260 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,3990 ctp, 117 whp,4280 bhp,2.5 wob, 11:30 14:30 3.00 9,260 6,873 PROD1 DRILL WPRT P Wiper trip to window 27k puw.Tie in depth+1.5'correction. PU into casing..jet 4 1/2"tubing up to TT. RBIH 14:30 16:30 2.00 9,260 9,410 PROD1 DRILL DRLG P Drill ahead, 1.4 bpm,4072 ctp, 170 whp, 10k ctw,4253 bhp. 16:30 19:00 2.50 9,410 9,410 PROD1 DRILL WPRT P Wiper trip to the window 27k puw. 19:00 22:00 3.00 9,410 9,560 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3890, BHP 4305, ROP 100,WOB 2K,Ct weight 8K. Distinctive fault mark @ 9450' Slow ROP&gamma change. 22:00 00:00 2.00 9,560 9,560 PROD1 DRILL WPRT P Wiper trip to window-P/U 30K. Had to work back to bottom last 40ft. 08/22/2012 Drilled AL1 lateral to TD of 9753',Wiper to window, RIH Pump liner pill&POOH. P/U Liner top billet,44 joints &2 Solid Tracer pups. RIH set on bottom. 00:00 03:00 3.00 9,560 9,710 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4346, ROP 55,WOB 1.5K,CT weight 10K, ECD 13.2. Pump low/high sweep prior to wiper. 03:00 06:00 3.00 9,710 9,710 PROD1 DRILL WPRT P Wiper trip to 3.5"-P/U weight 29K. Decent cuttings up from 3.5"+17 ft correction at window. RIH. 06:00 07:30 1.50 9,719 9,746 PROD1 DRILL DRLG P Tag 9719'drill ahead. 1.4 bpm,3970 ctp,4330 bhp,7k ctw. 10-11k rihw 07:30 11:45 4.25 9,746 9,746 PROD1 DRILL WPRT P Call TD.go up inspect BHI counter and clean.. POOH to TT. RBIH depth tie in with RA marker.Chase 10 brls low/hi sweeps.+8'correction. Cont. RBIH to TD 11:45 13:15 1.50 9,753 6,950 PROD1 DRILL TRIP P Tag TD 9753'. POOH lay in liner running pill in OH. POOH to window 13:15 15:00 1.75 6,950 0 PROD1 DRILL TRIP P Open EDC, POOH 15:00 15:30 0.50 0 0 PROD1 DRILL SFTY P At surface,Close SSSV. Monitor well for flow. PJSM Page 5 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 16:00 0.50 0 0 PROD1 DRILL PULD P LD BHA 16:00 16:30 0.50 0 0 COMPZ CASING PUTB P Prep floor to run liner 16:30 19:30 3.00 0 1,556 COMPZ CASING PUTB P P/U 44 joints of slotted liner with two Tracer pups&Liner top billet. Tracer pups 1716(oil)and T919(water) placed at 8684'MD. 19:30 21:45 2.25 1,556 9,750 COMPZ CASING RUNL P RIH with EDC open pumping .3 bpm, P/U @ flag 30K,correction-17ft. RIH clean through window.Tag bottom @ 9750'P/U weight 33K,WOB-6K. 21:45 22:00 0.25 9,750 8,238 COMPZ CASING RUNL P RIH to bottom with 2K WOB. Bring pump rate up to 1.2bpm,3800 psi, P/U weight 28K, -2.9 WOB.Current liner string. BOL=9750' TOL=8238' 22:00 00:00 2.00 8,238 0 COMPZ CASING TRIP P POOH pumping following MPD. Bump up at surface. 08/23/2012 P/U BHA#7 with 1.1 ako and 3"bi-center. KOTB from 8238'clean drift.Continue drilling ahead on AL1-01 lateral. 00:00 02:00 2.00 0 0 COMPZ CASING PULD P Undeploy Liner BHA 02:00 04:00 2.00 0 72 PROD2 STK PULD P PJSM-Deploy BHA#7 with 1.1 AKO&3"Bi-center.Service injector, found excess gear oil puddled up on frame.Wiped it up could not find any leaks or low oil levels. 04:00 05:30 1.50 72 6,933 PROD2 STK TRIP P RIH pumping.5 bpm. 05:30 05:45 0.25 6,933 8,238 PROD2 STK DLOG P Tie in depth-14'correction. 05:45 06:30 0.75 PROD2 STK TRIP P Close EDC RIH 06:30 06:57 0.45 8,238 8,238 PROD2 STK TRIP P Dry Tag TOB 8238'PU 28K PUW online with pumps 1.4 bpm,3765 ctp,4174 bhp. RIH slowly to mill off billet 06:57 07:09 0.20 8,238 8,238 PROD2 STK KOST P Start milling 1 fph. 1.43 bpm, 18.5k ctw,3804 ctp. 07:09 07:15 0.10 8,238 8,238 PROD2 STK KOST P Stall PU 28K. RBIH 07:15 08:30 1.25 8,237 8,238 PROD2 STK KOST P Start to see WOB 8237'.Cont time milling 1 fph, 1.4 bpm,3875 ctp, 17k ctw,4186 bhp. 08:30 09:06 0.60 8,238 8,239 PROD2 STK KOST P Increase time milling to 2 fph 09:06 09:36 0.50 8,239 8,240 PROD2 STK KOST P Increase time milling to 3 fph 09:36 10:21 0.75 8,240 8,270 PROD2 STK KOST P Increase time milling to 10 fph for 5'. Increase ROP drilling formation 10:21 10:33 0.20 8,270 8,270 PROD2 STK TRIP P PU,offline with pumps,drift billet, looks good. RBIH 10:33 11:48 1.25 8,270 8,390 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm, 16.8 ctw,3927 ctp,4196 bhp 11:48 13:48 2.00 8,390 8,390 PROD2 DRILL WPRT P Wiper trip 28k puw. PU into casing. Trap pressure on choke A. Flush MP choke B off alluminum cuttings.tie into RA marker. No correction. RBIH Page 6 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Siibcode T Comment 13:48 15:18 1.50 8,390 8,540 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm,3839 ctp, 15k ctw,4189 bhp 15:18 16:33 1.25 8,540 8,540 PROD2 DRILL WPRT P Wiper trip to window,27k puw. 16:33 18:33 2.00 8,540 8,690 PROD2 DRILL DRLG P Drill Ahead 1.4 bpm,4064 ctp, 15k ctw,4202 bhp 18:33 20:03 1.50 8,690 8,690 PROD2 DRILL WPRT P Wiper trip-P/U weight 28K. 20:03 22:03 2.00 8,690 8,840 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,4200, BHP 4250, ROP 80,WOB 2.2K,Ct weight 14K. 22:03 00:00 1.95 8,840 8,840 PROD2 DRILL WPRT P Wiper trip to 3.5"P/U weight 29K. Plus 2.5ft tie in correction. 08/24/2012 Continue drilling ahead on AL1-01 lateral.Mud swap with 1400ft on the system. 00:00 02:00 2.00 8,840 8,990 PROD2 DRILL DRLG P Drilling ahead 1.40 bpm,4215, BHP 4250, ROP 85,WOB 2.2 K,Ct weight 13K. Call out vac trucks for mud swap. 02:00 04:30 2.50 8,990 8,990 PROD2 DRILL WPRT P Wiper trip-P/U weight 29K 04:30 06:00 1.50 8,990 9,140 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,4220, BHP 4260, ROP 88,WOB 1.9K,Ct weight 13K.Start pumping new mud on bottom. 06:00 08:00 2.00 9,140 9,140 PROD2 DRILL WPRT P Wiper trip to window,27k puw. 08:00 09:45 1.75 9,140 9,290 PROD2 DRILL DRLG P Drill Ahead 1.4bpm,3800 ctp,4224 bhp, 11k ctw 09:45 12:15 2.50 9,290 9,290 PROD2 DRILL WPRT P Wiper trip to 3.5"TT.28k puw.Tie in depth to RA marker+5'correction 12:15 13:45 1.50 9,290 9,440 PROD2 DRILL DRLG P Drill Ahead 1.4bpm,4010 ctp,4300 bhp, 11k ctw 13:45 16:00 2.25 9,440 9,440 PROD2 DRILL WPRT P Wiper trip to window 27.5k puw 16:00 18:30 2.50 9,440 9,625 PROD2 DRILL DRLG P Drill Ahead 1.4bpm,4061 ctp,4326 bhp,9k ctw 18:30 21:00 2.50 9,625 9,625 PROD2 DRILL WPRT P Wiper trip P/u weight 29K.Tie in zero correction. 21:00 22:00 1.00 9,625 9,682 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4300, ROP 70,WOB,2K,Ct weight 5K. 22:00 22:30 0.50 9,682 9,682 PROD2 DRILL WPRT P Geo Wiper-P/U weight 28K 22:30 23:45 1.25 9,682 9,775 PROD2 DRILL DRLG P Drilling ahead-steering down. 23:45 00:00 0.25 9,775 9,775 PROD2 DRILL WPRT P 800ft wiper trip-Geo's would like to drill a little further than planned. P/U weight 29K 08/25/2012 TD AL1-01 lateral @ 9835'. Lay in liner pill, P/U 50 joints liner&two tracer pups with liner top billet.Set from TD to 8128'. P/U BHA#9 with 1.0 AKO&Bi-center.bit. 00:00 00:30 0.50 9,775 9,775 PROD2 DRILL WPRT P 800'wiper 00:30 02:00 1.50 9,775 9,835 PROD2 DRILL DRLG P Drill final 60ft. 1.40 bpm,4080, BHP 4350, ROP 80,WOB 1.8K,Ct weight 9K. Pump 10/10 sweeps prior to TD wiper. 02:00 06:00 4.00 9,835 6,800 PROD2 DRILL WPRT P Wiper trip to 3.5"P/U weight 30K.+1 ft correction on tie in. RIH to TD Page 7 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:30 3.50 9,835 9,835 PROD2 DRILL TRIP P Tag TD 9836'. POOH laying in liner running pill. New 9.9 FP w/beads to window. POOH followinf MP schedule 09:30 09:45 0.25 0 0 PROD2 DRILL SFTY P At surface,Close SSSV with 800psi on well. Bleed off above SSSV. Monitor well for flow. PJSM 09:45 10:45 1.00 0 0 PROD2 DRILL PULD P LD BHA 10:45 11:45 1.00 0 0 COMPZ CASING PUTB P Prep floor for running liner 11:45 15:00 3.25 0 0 COMPZ CASING PUTB P PU/MU AL1-01 liner.Oil/Water tracer pups placed in liner T-912-water, T-731-oil at 8380'. 15:00 15:15 0.25 1,749 1,749,3,COMPZ CASING RUNL P Equalize Above SSSV and open. 800psi.0 leakoff. 15:15 16:30 1.25 1,749 6,900 COMPZ CASING RUNL P RIH, 16:30 18:00 1.50 6,900 9,835 COMPZ CASING RUNL P Correct depth to EOP flag-16'. record up and down weights.30k up, 21k RIHW. RIH to bottom.Tag bottom Release liner on bottom. BOL 9835' TOL 8130' 18:00 20:00 2.00 8,130 50 COMPZ CASING TRIP P POOH following MPD,started to get oil returns at 5500'.Stop take returns to TT.Cleaned up,continue to POOH. 20:00 22:00 2.00 50 0 COMPZ CASING PULD P PJSM-Undeploy BHA#8.Service injector and make up new BHA. 22:00 22:30 0.50 0 0 PROD3 STK SFTY P Pre-spud with Gary's Crew. 22:30 23:30 1.00 0 72 PROD3 STK PULD P PJSM-deploying BHA#9 with 1.0 AKO and re-run Bicenter bit. 23:30 00:00 0.50 72 300 PROD3 STK TRIP P RIH pumping.3 bpm EDC open. 08/26/2012 KOTB from 8127'45 LOHS.Clean exit,continue drilling ahead on AL1-02 lat. Mud swap with 1450'on system. 00:00 02:15 2.25 300 8,128 PROD3 STK TRIP P RIH tie in correction,minus 12ft. RIH dry tag TOB @ 8128' 02:15 05:00 2.75 8,128 8,135 PROD3 STK KOST P KOTB as per procedure from 8127'. 315 ROHS. Good alum.returns over shakers 1ft in. Increase speeds as per procedure. 05:00 05:30 0.50 8,135 8,160 PROD3 DRILL DRLG P Drilling ahead additional 30ft-1.40 bpm,3800, BHP 4220,WOB 1.2K, Ct weight 18K, ROP 30 05:30 06:00 0.50 8,160 8,100 PROD3 DRILL WPRT P Wipe up and drift Billet 06:00 07:45 1.75 8,160 8,280 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4059 ctp, 4233 bhp, 16k ctw 07:45 09:00 1.25 8,280 7,296 PROD3 DRILL WPRT P Wiper trip to window 28K puw 09:00 11:45 2.75 8,280 8,430 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4018 ctp, 4228 bhp, 16k ctw 11:45 13:00 1.25 8,430 7,290 PROD3 DRILL WPRT P Wiper trip to window28k puw 13:00 16:00 3.00 8,430 8,580 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4150 ctp, 4222 bhp, 15k ctw Page 8 of 26 Time Logs _Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 8,580 6,900 PROD3 DRILL WPRT P Wiper trip back to 3.5"Tubing tale. 28K puw, Log RA marker for depth correction-2'correction 17:30 19:30 2.00 8,580 8,730 PROD3 DRILL DRLG P Drilling ahead. ROP slowed down @ 8710'-possible ankerite. Ratty drilling last 20ft.Hard time getting doglegs in BHA.Call out vac trucks for mud swap. 19:30 20:30 1.00 8,730 7,247 PROD3 DRILL WPRT P Wiper trip-P/U weight 29K. Forcast getting a little close to the West side of the polygon. 20:30 22:00 1.50 8,730 8,880 PROD3 DRILL DRLG P Drilling ahead-start pumping new mud-1.40 bpm,3900, BHP 4230, WOB 2K, ROP 120,Ct weight 13K. 22:00 23:45 1.75 8,880 7,250 PROD3 DRILL WPRT P Wiper trip to window. P/U weight 27K 23:45 00:00 0.25 8,880 8,908 PROD3 DRILL DRLG P Drilling ahead 08/27/2012 Continue drilling ahead on AL1-02 lateral. Losses=30 bbls/24 hours. 24 hour notification given to AOGCC for BOP testing. 00:00 01:45 1.75 8,908 9,030 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,3950, BHP 4270, ROP 105,WOB 1.5K,Ct weight 13.5K. 01:45 04:45 3.00 9,030 6,900 PROD3 DRILL WPRT P Wiper trip up to 3.5" P/U weight 27K -Tie in+2 ft correction. 04:45 06:30 1.75 9,030 9,180 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4006, BHP 4274,WOB 1.5K,Ct weight 13.9K. 06:30 08:30 2.00 9,180 7,300 PROD3 DRILL WPRT P Wiper trip to window 28K PUW 08:30 10:00 1.50 9,180 9,330 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4042, BHP 4285,WOB 1.5K,Ct weight 13.9K. 10:00 12:00 2.00 9,330 7,285 PROD3 DRILL WPRT P Wiper trip to window 27K PUW 12:00 14:15 2.25 9,330 9,480 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4038, BHP 4299,Ct weight 11.9K. 14:15 16:45 2.50 9,480 6,900 PROD3 DRILL WPRT P Wiper trip back to 3.5"TT. 27k PUW. Log RA marker to correlate depth. +2'correction 16:45 20:30 3.75 9,480 9,630 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4038, BHP 4299,Ct weight 11.9K. 20:30 22:30 2.00 9,630 7,290 PROD3 DRILL WPRT P Wiper trip to window 28K PUW 22:30 00:00 1.50 9,630 9,709 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4038, BHP 4299,Ct weight 11.9K. 08/28/2012 Run AL1-02 Liner, BOL=9833',TOL=7965' 00:00 01:00 1.00 9,709 9,775 PROD3 DRILL DRLG P Drilling ahead. Hard drilling last 10ft- wiper early due to weight transfer and slow ROP. 01:00 02:30 1.50 9,775 8,600 PROD3 DRILL WPRT P Wiper trip-P/U weight 29K.Wipe up 1000ft to drill additional 50ft to TD. 02:30 03:45 1.25 9,775 9,833 PROD3 DRILL DRLG P Drilling ahead-slow ROP but good weight transfer-1.40 bpm,4050, BHP 4350, ROP 8,WOB 2.7K,Ct weight 3K, ECD 13.3. Pump 10/10 sweeps at TD 03:45 07:45 4.00 9,833 9,835 PROD3 DRILL WPRT P Wiper to 3.5"P/U weight 29K. +1 ft tie in correction. RIH tag bottom @ 9835'. Liner pill at bit. Page 9 of 26 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:45 11:00 3.25 9,835 72 PROD3 DRILL TRIP P POOH laying in liner pill. Bump up at surface. 11:00 11:30 0.50 72 72 PROD3 DRILL SFTY P Close SSSV-no flow. PJSM for laying down BHA. 11:30 12:30 1.00 72 72 PROD3 DRILL PULD T Broke off the injector connection and while blowing down the tool the H2S alarm sounded.Well/BHA Secure Muster in the shop. Head count taken,called DSO to verify area is clear at shakers.All clear. Mist over the shaker due to blow down from tool at the rig floor. Electrician inspected sensor. Passed.Max.reading 37 ppm.for 30 seconds. 12:30 13:00 0.50 72 0 PROD3 DRILL PULD P Continue with laying down the BHA. 13:00 16:00 3.00 0 1,583 COMPZ CASING PUTB P PJSM-start picking up 46 joints of slotted liner&coiltrak BHA 16:00 17:30 1.50 1,583 7,200 COMPZ CASING RUNL P RIH pumping.3bpm. 17:30 17:36 0.10 7,200 7,183 COMPZ CASING RUNL P Correct to 5600'EOP flag for-17' correction, PUW=30K 17:36 18:24 0.80 7,183 9,682 COMPZ CASING RUNL P Run past 8100'flag within 1 foot, continue in to bottom,made no correction 18:24 19:06 0.70 9,682 9,833 COMPZ CASING TRIP P Set down @ 9833,3.2K WOB, PUW=32.5K,-5K DHWOB Set back down @ 9833 3.37 DHWOB, Pumps on 1.1 BPM @ 3700, PUW=26K. DHWOB=-1.9.Shut down pumps and line up on back side.Trip out to tie in depth 19:06 19:24 0.30 7,240 7,273 COMPZ CASING DLOG P Log tie in to RA Marker for a+.5' correction, BOL=9833.5, TO L=8294.2 19:24 21:24 2.00 7,273 48 COMPZ CASING TRIP P Trip out of well 21:24 22:00 0.60 48 0 COMPZ CASING PULD P At surface, PJSM,Trap 800 PSI, Close SSSV and flo check well.All good. Pull liner run#1 setting tools 22:00 00:00 2.00 0 390 COMPZ CASING PUTB P Rig up floor to run tubing, PJSM, P/U Ported bullnose, 1 Jt slotted liner,2 tracer pups,8 jts slotted liner, Anchored aluminum billet. Tracers spaced out for—8250'MD. Oil=T718,water=T913. 08/29/2012 Complete AL1-02 Liner TOL=7965, BOL=9833,Complete Full BOPE Test,Witness waived by Lou Grimaldi, AOGCC 00:00 02:18 2.30 390 7,585 COMPZ CASING RUNL P RIH with Liner 02:18 02:30 0.20 7,585 7,604 COMPZ CASING DLOG P Tie into RA marker for-17.5'. PUW=30K,continue in 02:30 02:54 0.40 7,604 8,292 COMPZ CASING RUNL P Set down @ 8291.5', PUW=30K,Set back down oriented anchor to 170 ROHS, Pumps on see tool shift @ 4400 PSI.Gained 1.2K DHWOB. TOL=7964', BOL=9833' Page 10 of 26 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 02:54 05:54 3.00 8,292 45 COMPZ CASING TRIP P Trip Out of well. 05:54 07:24 1.50 45 0 COMPZ CASING SFTY P Crew change-PJSM undeploy BHA 07:24 09:54 2.50 0 0 COMPZ CASING PULD P Lay down BHA-remove upper quick, pump fresh water through CT reel and jet stack.Grease stack&choke manifold. 09:54 10:24 0.50 0 0 PROD4 STK SFTY P Set up rig floor for BOP testing, barriers. PJSM for BOP testing. 10:24 17:24 7.00 0 0 PROD4 STK BOPE P Start BOPE testing. Low 250 High 4600 psi.**Witness waived by Lou Grimaldi** Replace seal on Charlie 4-fail- Pass. 17:24 19:54 2.50 0 0 PROD4 STK BOPE P R/D BOPE Test equip, Run post BOPE Valve alignment checklist, Change pack offs,stab on roll coil back to Flo Pro,Change out QTS 19:54 21:54 2.00 0 72 PROD4 STK PULD P PJSM.Load PDL with BHA#12, Drill by BHA with 1.5 AKO motor and RR Bi Center, PD BHA,surface test tool 21:54 23:42 1.80 72 6,885 PROD4 STK TRIP P RIH 23:42 00:00 0.30 6,885 6,944 PROD4 STK DLOG P Tie into K-1 for-21 08/30/2012 Drilled AL1-03 to TD @ 8655,Wipe to TT, Lay in liner running pill 00:00 00:30 0.50 6,944 7,270 PROD4 STK TRIP P Tie into K1 for-21'.Close EDC,trip in hole 00:30 00:36 0.10 7,270 7,300 PROD4 STK DLOG P Tie into RA since K1 correction seemed a little high for-1.5 00:36 01:00 0.40 7,300 7,963 PROD4 STK TRIP P Trip into hole,Clean pass through window 01:00 01:12 0.20 7,963 7,963 PROD4 STK KOST P Dry tag @ 7963, PUW=30K, Bring pumps on line, RBIH to mill off Billet 01:12 02:12 1.00 7,962 7,963 PROD4 STK KOST P Pumps @ 1.4 BPM @ 3830 PSI FS, BHP=4218, RIW=17.3K,See motor and WOB @ 7962.TF=200,Start time milling per procedure, 1 FPH 02:12 02:42 0.50 7,963 7,964 PROD4 STK KOST P Go to 2 FPH, 1.4 BPM @ 3860 PSI FS, BHP=4200 02:42 03:12 0.50 7,964 7,987 PROD4 DRILL DRLG P Drilled off at 7964,drill ahead 1.4 BPM @ 3870 PSI FS, BHP=4220 03:12 03:24 0.20 7,987 7,987 PROD4 DRILL WPRT P Dry drift billet area clean, PUW=29K, RIW=18 03:24 03:54 0.50 7,987 7,300 PROD4 DRILL WPRT T Derrick hand injury in pits, PUH circulating aluminum out 03:54 04:24 0.50 7,300 7,987 PROD4 DRILL WPRT T Discuss options with crew and tool pusher, RBIH to drill 04:24 05:54 1.50 7,987 8,113 PROD4 DRILL DRLG P Drill Ahead, 1.4 BPM @ 4000 PSI FS, BHP=4230 Page 11 of 26 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 05:54 07:54 2.00 8,113 6,800 PROD4 DRILL SFTY T PJSM-crew change-P/U into cased hole&circulate."Safety discussion with the crew" Review immediate findings, report on IP,discuss personal safety&hand awareness. The crew responded on staying focused&looking out for each other. 07:54 09:24 1.50 6,800 8,113 PROD4 DRILL WPRT P Continue with operations-RIH prepare for mud swap. 09:24 12:09 2.75 8,113 8,265 PROD4 DRILL DRLG P Drill ahead-start pumping new mud -Mud pump problems with airing up. Continue drilling ahead. 12:09 13:09 1.00 8,265 7,260 PROD4 DRILL WPRT P Wiper trip-P/U weight 27K 13:09 15:39 2.50 8,265 8,415 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3900, BHP 4190, ECD 12.7, ROP 10,WOB 2.5K,Ct weight 15K. 15:39 16:57 1.30 8,415 8,415 PROD4 DRILL WPRT P Wiper trip-P/U weight 27K 16:57 18:39 1.70 8,415 8,565 PROD4 DRILL DRLG P Drill Ahead, 1.4 BPM @ 3800 PSi FS, BHP=4215, RIW=13.8K, PUW=28K 18:39 20:03 1.40 8,565 8,565 PROD4 DRILL WPRT P Wiper to window(7265)with tie in for +1.5' 20:03 21:39 1.60 8,565 8,655 PROD4 DRILL DRLG P Drill Ahead, 1.38 BPM @ 3850 PSI FS, BHP=4215,RIW=13.2 21:39 00:00 2.35 8,655 7,618 PROD4 DRILL WPRT P 8655 call TD on AL1-03,Wiper trip to 6900,TT, with sweeps coming off bottom, PUW=28K with tie in for+1' correction 08/31/2012 Run AL1-03 Liner,TOL=7230, BOL=8655 00:00 00:42 0.70 7,618 8,656 PROD4 DRILL WPRT P Continue wiper to bottom 00:42 03:18 2.60 8,656 70 PROD4 DRILL TRIP P Tag TD @ 8656, POOH laying in beaded liner running pill. PUW=28K, , Paint EOP flags @ 7100 and 5700, Jet SSSV 03:18 04:24 1.10 70 0 PROD4 DRILL PULD P At surface,Shut SSSV, Flow check well, PJSM pull BHA#12 from well 04:24 05:06 0.70 0 0 COMPZ CASING PULD P R/U floor to run liner,service top drive,adjust bails 05:06 06:06 1.00 0 0 COMPZ CASING SFTY T Crew change, PJSM. H2S alarm, Shaker again.Well Secure with Swab valves.8-10 ppm over shaker. Muster. Pack up Sniff area.clear. 06:06 08:06 2.00 0 0 COMPZ CASING RGRP T Change out sensor&test over shaker before proceeding with operations.Water/moisture in sensor locator box. 08:06 11:06 3.00 0 1,470 COMPZ CASING PULD P PJSM for P/U liner-17 joints-2 tracer-25 joints-shorty GS. P/U Coiltrack assembly Tracers:water T-809,oil-T167D, spaced out for 8070'MD.. 11:06 13:36 2.50 1,470 8,655 COMPZ CASING RUNL P PJSM-crew change-RIH pumping .3 EDC closed.Tie in at flag-22ft, P/U weight 30K. RIH to bottom Page 12 of 26 Time Logs _ Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:36 14:06 0.50 8,655 7,230 COMPZ CASING RUNL P Set down on bottom-P/U weight 32K,-6K WOB, RIH set down 4K.Bring pumps up and P/U 26K, -1.5K WOB. POOH to tie in depth. +1ft correction. BOL=8655' TOL=7230' 14:06 16:36 2.50 7,230 72 COMPZ CASING TRIP P POOH 16:36 17:36 1.00 72 0 COMPZ CASING PULD P PJSM-undeploy BHA. 17:36 18:06 0.50 0 0 COMPZ CASING PULD P Lay down BHA-Blow down tool in mousehole. Prep for hand-over with new crew. 18:06 20:06 2.00 0 0 PROD5 RPEQP1CTOP P Crew change, PJSM, Install nozzle on CT,stab on and displace coil to water, Remove BHI Upper quick connect and CTC. 20:06 22:54 2.80 0 0 PROD5 RPEQP1CTOP P PJSM, R/U hydraulic coil cutter,Cut coil for fatigue mgmt,cut 970'of coil 22:54 00:00 1.10 0 0 PRODS RPEQP1CTOP P PJSM, R/D cutter,seal end of wire and rig up to perform slack mgmt, Cut 15 to find wire, cut additional 15 feet to complete 1000'trim 09/01/2012 Set whipstock @ 7204', POOH M/U window milling BHA Trip in,start time milling 00:00 00:30 0.50 0 0 PROD5 RPEQP1 CTOP P Complete slack mgmt,Cut total of 1000'pipe, 15'to find wire 00:30 01:54 1.40 0 0 PROD5 RPEQP1CTOP P Test E-Line,all good,install CTC, Pull test to 30K 01:54 04:12 2.30 0 0 PRODS RPEQP1CTOP P Head up E-Line and test, PT CTC to 4K,Swap coil back to Flo Pro 04:12 05:57 1.75 0 0 PROD5 RPEQP1PULD P PJSM,M/U BHA#13 Baker Gen two Whipstock.Stab PDL on Well. 05:57 07:27 1.50 0 75 PRODS RPEQP1PULD P Crew change, PJSM-Deploy WS BHA 07:27 09:57 2.50 75 7,217 PROD5 RPEQP1TRIP P RIH-EDC open pumping.3 bpm,tie in-20ft correction. Compared across the board.Weight check-28K. RIH to 7217' 09:57 10:27 0.50 7,217 7,204 PRODS RPEQP1WPST P TOWS 7204', 15 deg ROHS. Neutral weight.Close EDC-Set WS @ 3300 psi.WOB 4K. 10:27 11:57 1.50 7,204 65 PROD5 RPEQP1TRIP P POOH following MPD. P/U weight 28K. 11:57 13:27 1.50 65 0 PRODS RPEQP1PULD P PJSM-undeploy BHA 13:27 15:27 2.00 0 73 PROD5 WHPST PULD P PJSM-deploy milling BHA with .6 ako.. 15:27 17:51 2.40 73 7,209 PROD5 WHPST TRIP P RIH-Tie+8 ft correction. RIH dry tag TOWS-P/U and re-tie in. 17:51 18:51 1.00 7,209 6,940 PROD5 WHPST DLOG P PUH to confirm tie in log 6885 to 6940. K-1 came in on depth at 6880 for no correction 18:51 19:09 0.30 6,940 7,209 PROD5 WHPST TRIP P Trip in well,dry tag whipstock @ 7209 PUH, Bring pumps online Page 13 of 26 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 19:09 00:00 4.85 7,209 7,213 PROD5 WHPST MILL P Pumps online, 1.4 BPM @ 3660 PSI FS, RIW 20 K,see WOB with motor work @ 7208.4,start time milling per procedure, BHP=4060 09/02/2012 Complete upper window,TOWS=7205, BOW=7214,TD Build @ 7460' 00:00 00:33 0.55 7,213 7,214 PROD5 WHPST MILL P 7213.0 Close to calculated mid-point of 4-1/2"liner exit 00:33 02:21 1.80 7,214 7,216 PROD5 WHPST MILL P BOT calling window exit based on loss of motor work and WOB, 1.42 bpm @ 3660 PSI FS, BHP=4100, continue time milling per program 02:21 04:57 2.60 7,216 7,230 PROD5 WHPST MILL P Drilling Rathole, 1.42 BPM @ 3660, BHP=4180,Geo confirms in formation 04:57 07:27 2.50 7,230 7,230 PROD5 WHPST REAM P 7230',Start back reaming window. Three passed 30-40 pounds of motor work-smoothed out. 15,HS,30. Dry tag-good,small weight bobble. P/U pass through one more time 15 ROHS. Dry drift clean no weight bobble. 07:27 09:27 2.00 7,230 73 PROD5 WHPST TRIP P POOH following MPD. 09:27 11:27 2.00 73 0 PROD5 WHPST PULD P PJSM-undeploy BHA#15. 11:27 14:27 3.00 0 0 PROD5 DRILL SFTY T Safety inspection stand down with documented findings. Discuss with crew prior to going back to work& emphasise COP safety culture. Open discussion to"I believe"survey &how it effected CDR2. 1)Sometimes my c-workers take shorcuts 2)there times I need help but try to do it by myself 3)I feel self imposed pressure to get the job done 14:27 15:57 1.50 0 72 PRODS DRILL PULD P PJSM-Deploy Build BHA with 1.7 AKO. 15:57 17:09 1.20 72 6,880 PROD5 DRILL TRIP P RIH with EDC open 17:09 17:21 0.20 6,880 6,930 PROD5 DRILL DLOG P Tie into K1 for-20,close EDC, PUW=27K 17:21 17:33 0.20 6,930 7,230 PROD5 DRILL TRIP P Trip in hole to drill,Clean pass through window 17:33 20:48 3.25 7,230 7,380 PROD5 DRILL DRLG P Tag up @ 7230', Drill ahead, 1.44 BPM @ 3570 PSI FS, BHP=4137, RIW=19K 20:48 21:24 0.60 7,380 7,380 PROD5 DRILL WPRT P Wiper trip, PUW=28K, Pull up through window and log K1 for+1' correction, Log RA @ 7212.5 21:24 22:18 0.90 7,380 7,460 PROD5 DRILL DRLG P 7380', Drill Ahead 1.43 BPM @ 3770 PSI FS, BHP=4210 22:18 00:00 1.70 7,460 3,436 PROD5 DRILL TRIP P Call EOB, PUW=28K, BHP=4144 09/03/2012 Complete trip OOH after TD of build @ 7460.M/U Lateral and RIH Drill to 8493 Page 14 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:54 0.90 3,436 43 PROD5 DRILL TRIP P Continue trip out of well after TD build section 00:54 03:42 2.80 43 0 PROD5 DRILL PULD P On surface, PJSM PUD BHA#16, reconfigure coil track,service injector, load into PDL. 03:42 05:00 1.30 0 72 PROD5 DRILL PULD P PJSM, PD BHA#17,AL2 Lateral section, .8°Motor and Rebuilt Hugh Bi Center,M/U to coil track and surface test. 05:00 07:30 2.50 72 7,460 PROD5 DRILL TRIP P RIH, EDC open,Tie in-21ft.Close EDC-clean through the window. 07:30 09:00 1.50 7,460 7,610 PROD5 DRILL DRLG P Drilling ahead-1.44 bpm,3900, BHP 4260, ECD 12.7, ROP 88,WOB 1K. 09:00 10:00 1.00 7,610 7,230 PROD5 DRILL DLOG P Wiper trip-P/U 28K-Mad pass from 7470' 10:00 11:30 1.50 7,610 7,760 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4270, ROP 120,WOB 1.7K,Ct weight 15K. 11:30 12:00 0.50 7,760 7,240 PRODS DRILL WPRT P Wiper trip-P/U weight 28K. 12:00 14:15 2.25 7,760 7,910 PRODS DRILL DRLG P Drilling ahead 14:15 16:00 1.75 7,910 6,900 PRODS DRILL WPRT P Wiper trip P/U weight 28K Tie in+2ft. Unloaded plenty of cuttings during TT wiper. 16:00 17:00 1.00 7,910 8,060 PRODS DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4255, ECD 12.8, ROP 150,CT weight 17. 17:00 18:00 1.00 8,060 7,240 PRODS DRILL WPRT P Wiper trip-P/U weight 28K 18:00 19:00 1.00 8,060 8,210 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,3890, BHP 4240, ROP 155,WOB.9,Ct weight 15K. 19:00 20:00 1.00 8,210 7,250 PRODS DRILL WPRT P Wiper trip-P/U 28K 20:00 21:15 1.25 8,210 8,360 PRODS DRILL DRLG P Drilling ahead-1.40 bpm,3900, BHP 4250,WOB 1.4, ROP 155,Ct weight 15K.Start sending mud to Tiger tank for mud swap. 21:15 23:15 2.00 8,360 6,880 PRODS DRILL WPRT P Wiper trip-P/U weight Tie in correction 23:15 00:00 0.75 8,360 8,439 PRODS DRILL DRLG P Drilling ahead-1.40 bpm,3890, BHP 4255, ROP 70,WOB 1.2K,Ct weight 17K.Start pumping new mud. 09/04/2012 Drilled AL2 lateral from 8493ft-9427ft 00:00 00:30 0.50 8,439 8,510 PROD5 DRILL DRLG P Drilling Ahead, 1.4 BPM @ 3890 PSI FS, BHP=4165 New mud around @ 12:15 00:30 02:06 1.60 8,510 8,510 PROD5 DRILL WPRT P Wiper trip to window,7230', PUW=28K, 02:06 03:24 1.30 8,510 8,660 PROD5 DRILL DRLG P 8510', Drill Ahead, 1.39 BPM @ 3570 PSI FS, BHP=4205, WHP=180, RIW=18K 03:24 04:48 1.40 8,660 8,660 PROD5 DRILL WPRT P 8660 Wiper to window,7260', PUW=28.5K 04:48 05:54 1.10 8,660 8,810 PROD5 DRILL DRLG P 8660', Drill Ahead, 1.48 BPM @ 3780 PSI FS, BHP=4240,WHP=170 Page 15 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:54 07:24 1.50 8,810 7,235 PROD5 DRILL WPRT P 8810,wiper trip to 7190, PUW=28K., RBIH to 7235 07:24 07:36 0.20 7,235 7,250 PROD5 DRILL WPRT P Log RA marker for-10.5'., 07:36 08:06 0.50 7,250 7,180 PROD5 DRILL WPRT P Wipe up to 7180.open EDC. Bypass choke B 08:06 09:00 0.90 7,180 7,180 PROD5 DRILL RGRP T Change out gooseneck counter(BHI counter)due to slippage from loose chain drive. Disassemble choke B and replace damaged seat 09:00 09:48 0.80 7,180 8,802 PRODS DRILL WPRT P Close EDC,RIH log past RA for no correction 09:48 11:12 1.40 8,810 8,960 PROD5 DRILL DRLG P Tagged early at 8802'due to counter slippage. Drill Ahead, 1.47 BPM @ 3800 PSI FS, BHP=4260, 11:12 13:06 1.90 8,960 8,960 PRODS DRILL WPRT P Wiper trip to window, 7235,with tie in to confirm counters, PUW=32K, BHP=4260, No correction at tie in. 13:06 14:12 1.10 8,960 9,110 PROD5 DRILL DRLG P 8960, Drill Ahead, 1.46 BPM @ 3775 PSI FS, BHP=4280,RIW=15K. Found bottom where it is supposed to be-no counter slippage. 14:12 15:27 1.25 9,110 9,110 PRODS DRILL WPRT P 9110',Abbreviated wiper trip to 7900', PUW=30K, No indication of unloading on out density 15:27 16:57 1.50 9,110 9,233 PRODS DRILL DRLG P 9110', Drill Ahead, 1.48 BPM @ 3750 PSI FS, BHP=4290 16:57 17:27 0.50 9,233 9,233 PROD5 DRILL WPRT P 9233,Geo Wiper,PUW=30K 17:27 17:45 0.30 9,233 9,260 PRODS DRILL DRLG P 9233, Drill Ahead, 1.48 BPM @ 3750 PSI FS 17:45 19:03 1.30 9,260 6,890 PRODS DRILL WPRT P 9260',Wiper to TT 6890, PUw=29K 19:03 19:15 0.20 6,890 7,191 PRODS DRILL WPRT P 6890ft, RBIH, RIW 15K 19:15 19:27 0.20 7,191 7,228 PRODS DRILL DLOG P Tie in to RA marker+1ft correction 19:27 20:27 1.00 7,228 9,260 PRODS DRILL WPRT P 7228ft Continue in hole, RIW 15K 20:27 22:27 2.00 9,260 9,410 PRODS DRILL DRLG P 9260ft, BOBD 1.42bpm,3780psi. BHP 4280,WHP 157 22:27 23:09 0.70 9,410 8,175 PRODS DRILL WPRT P 9410ft,wiper PUW 29K 23:09 23:51 0.70 8,175 9,410 PRODS DRILL WPRT P RBIH,TIW 17K 23:51 00:00 0.15 9,410 9,427 PRODS DRILL DRLG P 9410ft, BOBD, 1.43bpm at 3750psi, BHP 4314,WHP 156 09/05/2012 Drill AL2 from 9427ft to TD 9753ft. MU AL2 Liner 00:00 02:00 2.00 9,427 9,560 PRODS DRILL DRLG P Drilling Ahead 9427ft, 1.43bpm at 3750psi, BHP 4337ft,WHP 156 02:00 03:00 1.00 9,560 7,800 PROD5 DRILL WPRT P 9560ft.Wiper PUW 29K 03:00 04:00 1.00 7,800 9,560 PRODS DRILL WPRT P 7800ft, RBIH RIW 13K 04:00 08:00 4.00 9,560 9,595 PRODS DRILL DRLG P 9560ft, BOBD 1.41 bpm at 3770psi, BHP 4340,WHP 156 08:00 08:12 0.20 9,595 9,595 PRODS DRILL RGRP T P/U to fix sheared bolt on Shaker 08:12 09:42 1.50 9,595 9,700 PROD5 DRILL DRLG P 9595', Drill Ahead, 1.41 BPM @ 3880 PSI FS, BHP=4385 Page 16 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:42 10:42 1.00 9,700 8,900 PROD5 DRILL WPRT P 9700',TD has been extended perform . abbriviated wiper to 8900', PUW=30K 10:42 11:18 0.60 9,700 9,753 PROD5 DRILL DRLG P Drill Ahead to TD @ 9750, 1.43 BPM @ 3825 PSI FS, BHP=4350 11:18 14:00 2.70 9,750 7,235 PROD5 DRILL WPRT P 9750',Call TD, Pump sweeps 10/10 Wiper to TT, PUW=29K 14:00 14:12 0.20 7,235 7,254 PROD5 DRILL DLOG P Log RA marker for+4'correction 14:12 15:18 1.10 7,254 9,753 PROD5 DRILL WPRT P Continue wiper trip to bottom,Tag up at 9753 15:18 18:30 3.20 9,753 0 PROD5 DRILL TRIP P Trip out,lay in beaded liner pill in open hole, PUW=30K,Paint EOP flags @ 8900 and 6400 18:30 19:12 0.70 0 0 PROD5 DRILL PULD P OOH,PJSM-No flow LD BHA#17 19:12 19:42 0.50 0 0 PRODS DRILL SFTY T H2S Alarm occurred from shaker H2S sensor for a short period. Secured well - EVACUATE THE RIG-to the second muster area due to wind direction. Performed roll call every one was accounted for. Initiated call to DSO to sniff pits module for re-entry. DSO cleared pit module for re-entry.Gathered crew up for an AAR. 19:42 21:00 1.30 0 0 PRODS DRILL PULD P PJSM,continue to LD BHA#17 21:00 21:30 0.50 0 0 PRODS DRILL PULD P Tools OOH, Prep rig floor to MU liner 21:30 22:00 0.50 0 0 PRODS DRILL BOPE P Perform BOP function test 22:00 22:18 0.30 0 0 COMPZ CASING SFTY P PJSM for making up liner running BHA 22:18 23:30 1.20 0 603 COMPZ CASING PUTB P MU AL2 liner running BHA, Non Ported Bullnose, 18 Jts 2 3/8" slotted liner,Open hole anchor with aluminum billet 23:30 23:42 0.20 603 603 COMPZ CASING SFTY P PJSM,for MU BHI tools to liner. 23:42 00:00 0.30 603 676 COMPZ CASING PULD P MU BHI tools 09/06/2012 Run AL2 lateral section liner to 9723ft leaving the anchored billet top at 9108ft. POOH MU drilling BHA#19 00:00 01:00 1.00 676 676 COMPZ CASING PULD P Continue to MU BHI tools and strip INJH down over BHA 01:00 03:30 2.50 676 7,083 COMPZ CASING RUNL P RIH with AL2 liner running BHA#18 03:30 03:42 0.20 7,083 7,083 COMPZ CASING DLOG P Tie into first EOP flag at 6400ft correction of-6.6ft, PUW 29k 03:42 04:00 0.30 7,083 7,840 COMPZ CASING RUNL P Contine RIHTB with Liner 04:00 04:12 0.20 7,840 7,855 COMPZ CASING DLOG P Tie into RA marker correction of+ 1.5ft 04:12 05:12 1.00 7,855 9,723 COMPZ CASING RUNL P Continue RIHTB RIW 18k 05:12 08:12 3.00 9,723 75 COMPZ CASING TRIP P 9723ft PUW 33.5k, RBIH to Bottom. Release from liner at 4500psi.5k down WOB. PUW 30k, POOH TOL=9108', BOL=9723',Slip @ 355 Degrees Page 17 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:12 09:42 1.50 75 0 COMPZ CASING PULD P At surface,Shut SSSV, Flow check well,PJSM, PUD BHA#Liner running tools 09:42 10:06 0.40 0 0 COMPZ CASING RGRP T Test/trouble shoot H2S alarm sensor 10:06 12:06 2.00 0 72 PROD6 STK PULD P PJSM, PU BHA#19, KO Billet,0.9 degree motor and RR bi-center bit 12:06 14:06 2.00 72 72 PROD6 STK PULD T Unable to power up tool after stabbing on coil, Disconnect from coil and troubleshoot, E-line test good,Tool not testing, PUD.M/U new Coil track tool and PD,good test 14:06 15:06 1.00 72 72 PROD6 STK PULD P Strip on well, S/D MP pumping and line up down coil,Tag up and set counters 15:06 17:06 2.00 72 6,900 PROD6 STK TRIP P Trip in Hole EDC open 17:06 17:18 0.20 6,900 6,945 PROD6 STK DLOG P Log K1 marker for-6.5ft correction 17:18 18:18 1.00 6,945 9,110 PROD6 STK TRIP P Continue RIHTB RIW 18k 18:18 19:00 0.70 9,110 9,110 PROD6 STK KOST P Dry Tag Billet,9109.5ft, Begin Milling Billet 19:00 19:24 0.40 9,110 9,000 PROD6 STK WPRT P Trouble getting weight transfer. Perform 100ft wiper. 19:24 21:24 2.00 9,110 9,118 PROD6 STK KOST P Milling Billet, 1.45bpm at 3866psi. BHP 4838,WHP 137 21:24 21:54 0.50 9,118 9,150 PROD6 DRILL DRLG P Drill AL2-03 lateral as per geo and DD. 21:54 22:06 0.20 9,150 9,150 PROD6 DRILL WPRT P Pulled up through billet area at min rate and dry run down through billet area clean. 22:06 23:36 1.50 9,150 9,260 PROD6 DRILL DRLG P Drill LA2-03 lateral, 1.45bpm at 3860psi, BHP 4333,WHP 130 23:36 00:00 0.40 9,260 8,046 PROD6 DRILL WPRT P Wiper to the window 09/07/2012 Drilled AL2-03 to TD(9700ft),Condition hole for Liner.MU and Run Liner into 7381ft. 00:00 00:18 0.30 8,046 7,250 PROD6 DRILL WPRT P Continue wiper to the window 00:18 01:18 1.00 7,250 9,260 PROD6 DRILL WPRT P Wiper back in hole. RIW=17k 01:18 03:18 2.00 9,260 9,410 PROD6 DRILL DRLG P BOBD. 1.39bpm at 3863psi, BHP 4337,WHP 136 03:18 04:00 0.70 9,410 8,300 PROD6 DRILL WPRT P Wiper to the window PUW=29k 04:00 04:30 0.50 8,300 9,410 PROD6 DRILL WPRT P Wiper back in hole RIW=16k 04:30 05:48 1.30 9,410 9,560 PROD6 DRILL DRLG P BOBD 1.40bpm at 3900psi, BHP 4330,WHP 116 05:48 07:54 2.10 9,560 7,235 PROD6 DRILL WPRT P Wiper to the TT 6900',PUW=32K, 07:54 08:00 0.10 7,235 7,257 PROD6 DRILL DLOG P Log RA Marker for+3.5' 08:00 09:24 1.40 7,257 9,560 PROD6 DRILL WPRT P Continue wiper back to bottom, Clean trip,start Mud Swap 09:24 11:06 1.70 9,560 9,700 PROD6 DRILL DRLG P 9562'Drill ahead on new mud, 1.4 BPM @ 4K PSI FS, RIW=15K, BHP=4311 11:06 13:06 2.00 9,700 7,235 PROD6 DRILL WPRT P 9700',TD AL2-03, PUW=30K Page 18 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:06 13:12 0.10 7,235 7,254 PROD6 DRILL DLOG P Tie in to RA for+1'correction 13:12 14:42 1.50 7,254 9,700 PROD6 DRILL WPRT P Continue wiper to bottom 14:42 17:42 3.00 9,700 0 PROD6 DRILL TRIP P Tag bottom,corrected TD 9700', POOH laying in beaded liner running pill, PUW=30K, Paint EOP flags @ 8700 and 6200' 17:42 18:00 0.30 0 0 PROD6 DRILL PULD P Pumps down,Close SSSV, Flow check well. 18:00 18:18 0.30 0 0 PROD6 DRILL SFTY P Crew change, PJSM for LD AL2 lateral drilling BHA#19 18:18 19:42 1.40 0 0 PROD6 DRILL PULD P Break off INJH, Lay down BHA 19:42 20:00 0.30 0 0 COMPZ CASING SFTY P PJSM for picking up liner 20:00 21:30 1.50 0 821 COMPZ CASING PUTB P Start making up first section of liner for AL2-03 lateral 21:30 21:42 0.20 821 821 COMPZ CASING SFTY P PJSM for MU deployment sleeve with BHI tools 21:42 23:54 2.20 821 7,073 COMPZ CASING RUNL P RIH with AL2-03 Liner BHA 23:54 00:00 0.10 7,073 7,381 COMPZ CASING DLOG P Correct to the Flag with a correction of-7.9ft,Continue into the hole. 09/08/2012 TD AL2-03 lateral and run completion to TD 9700ft TOL-7940ft/BOL-9700ft 00:00 01:00 1.00 7,381 9,700 COMPZ CASING RUNL P Continue into the hole 01:00 01:12 0.20 9,700 9,700 COMPZ CASING RUNL P Tag bottom with Liner at 9700ft, PUW 32k, DHWOB 3.2k,bring pumps up to 3500psi-1.3bpm and release from liner. PUW 28k BOL=9700ft TOL=8878.65ft TracerCo Pup oil-T722 TracerCo Pup water -T804 01:12 03:42 2.50 9,700 0 COMPZ CASING TRIP P Paint EOP flags at 6099.9ft and 7800.Oft, POOH 03:42 04:42 1.00 0 0 COMPZ CASING PULD P Tag up,Close SSSV, PJSM, Lay down liner running tools BHA#20 04:42 07:42 3.00 0 981 COMPZ CASING PUTB P PJSM- PU upper AL2-03 liner section, Ported Bullnose,25 Jts slotted 2 3/8 Liner,Tracer pup #165A,tracer pup#911,2 Jts slotted liner, 1 9.81'pup,and aluminum billet.make up to coil and surface test 07:42 09:42 2.00 981 7,090 COMPZ CASING RUNL P Trip in well with liner, EDC closed, 09:42 09:48 0.10 7,090 7,090 COMPZ CASING DLOG P Tie into 6100'EOP flag for-8.6 09:48 10:24 0.60 7,090 8,145 COMPZ CASING RUNL P Continue RIH 10:24 10:30 0.10 8,145 8,160 COMPZ CASING DLOG P Tie into RA,correct+1.5 10:30 10:54 0.40 8,160 8,878 COMPZ CASING RUNL P Continue in hole 10:54 11:00 0.10 8,878 8,878 COMPZ CASING RUNL P Tag At 8878.64, PUW=30.5 DHWOB=-3.3,Set back down. Pumps on 1.3 BPM @ 4K PSI, PUW=27.5K, DHWOB=-1.2, Upper section BOL=8878,TOL Billet=7941 • Page 19 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 11:00 11:24 0.40 8,878 8,100 COMPZ CASING TRIP P Trip out after liner release 11:24 13:18 1.90 8,100 7,162 COMPZ CASING TRIP P Remove 937'from counters, Liner left in hole,continue trip out, PJSM Load next BHA in PDL 13:18 14:48 1.50 7,162 34 COMPZ CASING PULD P Tag up,space out, PJSM to LD BHA #21 liner running BHA 14:48 16:12 1.40 0 72 PROD7 STK PULD P PJSM,PD BHA#22, Kick off liner top billet,0.9 degree motor and rebuild bi center,Stab on coil and surface test tools 16:12 18:00 1.80 72 6,905 PROD7 STK TRIP P RIH, EDC Open 18:00 18:12 0.20 6,905 6,936 PROD7 STK DLOG P Tie into K1 marker correction of-9ft 18:12 18:54 0.70 6,936 7,940 PROD7 STK TRIP P Continue in hole, RIW 18k 18:54 19:06 0.20 7,940 7,927 PROD7 STK TRIP P Tag Liner at 7940ft, PUW 30k 19:06 21:12 2.10 7,927 7,950 PROD7 STK KOST P 7940ft,OBM, 1.42bpm at 3830psi, BHP 4170,WHP 98 Kick off of billet: 1 fph-1 ft 2fph-1ft 3fph-1 ft 10 fph-5ft 20fph-2ft 21:12 23:00 1.80 7,950 8,090 PROD7 DRILL DRLG P Dry drift billet-Clean.Drill Ahead from 7950ft, ROP 108fph, DHWOB 1.6k, 1.43bpm at 3830psi, BHP 4228,WHP 130 23:00 23:30 0.50 8,090 7,240 PROD7 DRILL WPRT P Wiper from 8090ft-7240ft 23:30 00:00 0.50 7,240 8,090 PROD7 DRILL WPRT P Wiper back in hole from 7240ft- 8090ft 09/09/2012 Drill AL2-01 Lateral in the A3 formation 00:00 02:30 2.50 8,090 8,240 PROD7 DRILL DRLG P 8090ft, BOBD 1.43bpm at 3830psi, BHP 4257,WHP 127,DHWOB 2.18k ROP 100fph 02:30 03:00 0.50 8,240 7,240 PROD7 DRILL WPRT P Wiper up to 7240ft, PUW 28k 03:00 03:30 0.50 7,240 8,240 PROD7 DRILL WPRT P Wiper back in hole to Bottom 8240ft, RIW 18k 03:30 05:30 2.00 8,240 8,390 PROD7 DRILL DRLG P 8240ft, BOBD 1.43bpm at 3815psi, BHP 4233,WHP 100 DHWOB 1.3k, ROP 122fph 05:30 07:00 1.50 8,390 7,235 PROD7 DRILL WPRT P Wiper to TT,6875', PUW=28K, BHP=4234 07:00 07:06 0.10 7,235 7,253 PROD7 DRILL DLOG P Log RA tag for+3.5' 07:06 07:48 0.70 7,253 8,390 PROD7 DRILL WPRT P Continue in hole to drill, 07:48 09:54 2.10 8,390 8,540 PROD7 DRILL DRLG P 8390', Drill Ahead. 1.44 BPM @ 3800 PSI FS, BHP=4200, RIW=16K, WHP=100 09:54 11:24 1.50 8,540 7,540 PROD7 DRILL WPRT P Wiper trip,Abbriviated 1000', PUW=28K, RIW=16K,BHP=4230 11:24 13:24 2.00 8,540 8,690 PROD7 DRILL DRLG P 8540', Drill Ahead, 1.4 BPM @ 3660 PSI FS, BHP=4235 Page 20 of 26 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:24 15:00 1.60 8,690 7,500 PROD7 DRILL WPRT P 8690,Wiper to 7500', PUW=28K, BHP=4280 15:00 17:00 2.00 8,690 8,840 PROD7 DRILL DRLG P 8690', Drill Ahead, 1.45 BPM @3800 PSI FS, BHP=4260 17:00 18:30 1.50 8,840 6,900 PROD7 DRILL WPRT P Wiper up to the Tubing Tail(6900ft) PUW 29k 18:30 18:42 0.20 6,900 7,235 PROD7 DRILL WPRT P Wiper back in hole. RIW 19k 18:42 18:54 0.20 7,235 7,251 PROD7 DRILL DLOG P Tie into RA from 7235'-7251'. Correction of+3.5' 18:54 19:30 0.60 7,251 8,840 PROD7 DRILL WPRT P Continue wiper in hole 19:30 21:00 1.50 8,840 8,990 PROD7 DRILL DRLG P 8040'BOBD 1.4bpm at 3830psi. BHP 4315,WHP 108 21:00 21:42 0.70 8,990 7,240 PROD7 DRILL WPRT P Wiper to the bottom of the window _ (8990'-7240')PUW-28k 21:42 22:42 1.00 7,240 8,990 PROD7 DRILL WPRT P Wiper back in hole RIW 16k(7240'- 8990') 22:42 00:00 1.30 8,990 9,095 PROD7 DRILL DRLG P 8990'BOBD 1.4bpm at 3850psi. BHP 4298,WHP 70. DHWOB 1.5k, ROP 115fph 09/10/2012 TD AL2-01 lateral. Circulated completion fluid,POOH cleaning tubing.MU First AL2-01 liner section, RIH,and set it on bottom 9191'.POOH and LD liner running BHA.MU the second liner section. 00:00 00:30 0.50 9,095 9,140 PROD7 DRILL DRLG P 9095'OBD 1.4bpm at 3850psi, BHP 4288,WHP 40, DHWOB 1.2k, ROP 145fph 00:30 01:00 0.50 9,140 8,340 PROD7 DRILL WPRT P Wiper from(9140'-8340')PUW 29k 01:00 01:30 0.50 8,340 9,140 PROD7 DRILL WPRT P Wiper back in hole(8340'-9140') RIW 15k 01:30 02:00 0.50 9,140 9,191 PROD7 DRILL DRLG P 9140'BOBD 1.4bpm at 3850psi, BHP 4286,WHP 41 02:00 04:00 2.00 9,190 6,900 PROD7 DRILL WPRT P 9190'TD well,Pump 10 High/Low sweep,Wiper up to the Tubing Tail (9190'-6900') 04:00 04:12 0.20 6,900 7,251 PROD7 DRILL DLOG P Wiper back in hole.Tie into the RA marker 7235'-7251'with a correction of+2.5' 04:12 05:12 1.00 7,251 9,191 PROD7 DRILL WPRT P Wiper back in hole to confirm TD 05:12 07:57 2.75 9,191 65 PROD7 DRILL WPRT P POOH Laying in completion fluild from TD 9191',Paint EOP Flags @ 7800 and 5800, 07:57 09:42 1.75 65 0 PROD7 DRILL PULD P At surface,Close SSSV and flo check well. PJSM lay down tools on dead well 09:42 11:12 1.50 0 0 COMPZ CASING RURD P R/U floor to run liner,service top drive and tongs 11:12 13:12 2.00 0 1,334 COMPZ CASING PUTB P PJSM,M/U BHA#23, Non Ported bullnose,34 jts 2 3/8 slotted liner, Tracer pup T-165F Green,T-158A Blue,4 Jts 2 3/8 Slotted,and shorty deployment sleeve.Make up to coil track and surface test tool. 13:12 15:06 1.90 1,334 7,143 COMPZ CASING RUNL P Trip in with BHA#23, EDC Shut 15:06 15:12 0.10 7,143 7,134 COMPZ CASING DLOG P Correct to 5800'EOP flag,-9.9 15:12 15:54 0.70 7,134 8,500 COMPZ CASING RUNL P Continue in well Page 21 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:54 16:00 0.10 8,500 8,512 COMPZ CASING DLOG P Log RA marker,correct+.5 16:00 16:18 0.30 8,512 9,191 COMPZ CASING RUNL P Continue with liner to bottom 16:18 16:30 0.20 9,191 9,192 COMPZ CASING RUNL P 9190.55,Tag bottom, PUW=32.5K, Set back down, Pumps on 1.3 BPM @ 4K PSI, Release liner, PUW=26.5,TOL Lower section=7899 16:30 17:15 0.75 9,192 4,500 COMPZ CASING TRIP P Trip out of hole, Paint EOP flag @ 6800 EOP 17:15 19:21 2.10 4,500 4,500 COMPZ CASING SFTY T Safety stand up with both crews. CPA well supt discuss recent incidents. 19:21 20:39 1.30 4,500 61 COMPZ CASING TRIP P Continue out of well 20:39 21:39 1.00 61 0 COMPZ CASING PULD P Tag Up at surface,Shut SSSV, PJSM to pull liner running tools from dead well while flow checking well 21:39 23:09 1.50 0 271 COMPZ CASING PUTB P PJSM, P/U AL2-01 Upper liner section 23:09 00:00 0.85 271 271 COMPZ CASING RGRP T Lower MP 2 3/8 pipe/slip rams, High/low bypass valve was leaking. 09/11/2012 Run second liner section in AL2-01 lateral, POOH,conduct BOP test, RIH with AL2-02 BHA#25. 00:00 01:15 1.25 271 271 COMPZ CASING RGRP T Continue to repair Lower MP 2 3/8 pipe/slips rams high/low pressure bypass valve leak. 01:15 03:15 2.00 271 7,430 COMPZ CASING RUNL P RIH with second section of liner for AL2-01 BHA#24. Open EDC and line up to open SSSV. 03:15 03:30 0.25 7,430 7,452 COMPZ CASING DLOG P Set Depth to Flag, +9.9',Continue in hole.Tie into RA with a 0.5' correction. 03:30 04:00 0.50 7,452 7,900 COMPZ CASING RUNL P RIH 04:00 04:15 0.25 7,900 7,900 COMPZ CASING RUNL P Tag bottom section of liner at 7899.9. PUW 29k.Orientate upper slips to • 155° for a 125°kick off. Pressure up to 4530psi and release from liner. PUW 27.5k. TOL-7689.83' 04:15 06:00 1.75 7,900 0 COMPZ CASING TRIP P Remove BHA length from counter and POOH 06:00 08:30 2.50 0 0 COMPZ CASING PULD P OOH, PJSM, Undeploy Liner running BHA 08:30 11:00 2.50 0 0 PROD8 STK BOPE P Jet BOPE with nozzle,and flush surface lines with fresh water 11:00 21:00 10.00 0 0 PROD8 STK BOPE P PJSM-Grease Tree valves and Nabors valves.Conduct BOPE Testing. 21:00 21:30 0.50 0 0 PROD8 STK SFTY P PJSM. 21:30 23:30 2.00 0 0 PROD8 STK TRIP P Rig up BHA and pressure deploy. 23:30 00:00 0.50 0 2,100 PROD8 STK TRIP P RIH 09/12/2012 Drill AL2-01 Lateral in the Al formation from 7690 to 8567. Page 22 of 26 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 2,100 7,689 PROD8 STK TRIP P RIH with BHA#25.Tagged top of Billet at 7690'MD. 02:30 05:00 2.50 7,689 7,701 PRODS STK KOST P Start milling billet. 1.42bpm at 3700psi. BHP 4205,WHP 142 1 fph for 1' 2 fph for 1' 3 fph for 1' 10 fph for 5' 20 fph for 2' 05:00 05:30 0.50 7,701 7,725 PROD8 DRILL DRLG P Drilling Ahead 1.42bpm at 3962psi. BHP 4884,WHP 144 05:30 05:45 0.25 7,725 7,705 PROD8 DRILL WPRT P PU hole 05:45 06:00 0.25 7,705 7,725 PROD8 DRILL WPRT P RBIH dry drift billet area, looks clean 06:00 07:00 1.00 7,725 7,840 PROD8 DRILL DRLG P BOBD 1.42bpm at 3745psi, BHP 4728,WHP 140 07:00 07:30 0.50 7,840 7,240 PRODS DRILL WPRT P Wiper up to 7240'PUW 27k 07:30 08:00 0.50 7,240 7,840 PROD8 DRILL WPRT P Wiper back in hole. RIW 19k 08:00 10:00 2.00 7,840 7,990 PROD8 DRILL DRLG P BOBD 1.42bpm at 3840psi. BHP 4850,WHP 143 10:00 10:30 0.50 7,990 7,240 PRODS DRILL WPRT P Wiper up tp 7240',PUW 28k 10:30 11:00 0.50 7,240 7,990 PRODS DRILL WPRT P Wiper back in hole. RIW 17k 11:00 13:00 2.00 7,990 8,140 PROD8 DRILL DRLG P 7990'MD BOBD 1.42bpm at 3840', BHP 4242,WHP 144 13:00 14:00 1.00 8,140 6,900 PROD8 DRILL WPRT P Wiper up to TT 6900'. PUW 27k 14:00 14:15 0.25 6,900 7,235 PRODS DRILL WPRT P RBIH RIW 20k 14:15 14:30 0.25 7,235 7,251 PROD8 DRILL DLOG P Tie into RA Marker 7235'MD bit depth-7251'MD bit depth correction of+2.5'. 14:30 15:00 0.50 7,251 8,140 PROD8 DRILL WPRT P Continue wiper in hole from 7251'MD -8140'MD.Start Mud swap. 15:00 15:45 0.75 8,140 8,156 PROD8 DRILL DRLG P 8140'MD New Mud at Bit, BOBD 1.33 bpm at 3850. BHP 4208,WHP 168 15:45 16:15 0.50 8,156 7,865 PROD8 DRILL WPRT T High Pump pressure, PU off bottom and troubleshoot.Switch filters.Mud man grabbed a sample. Found Mud to be cold and vis was high. 16:15 16:30 0.25 7,865 8,156 PROD8 DRILL WPRT P 7865'RBIHTB RIW 18k 16:30 18:30 2.00 8,156 8,290 PROD8 DRILL DRLG P 8156'MD OBD 1.34bpm at 3970psi, BHP 4187 WHP 59 18:30 19:00 0.50 8,290 7,266 PROD8 DRILL WPRT P Wiper trip up to 7266, PU WT is 28k. 19:00 19:30 0.50 7,266 8,290 PROD8 DRILL WPRT P RBIH to 8290. 19:30 21:12 1.70 8,290 8,440 PROD8 DRILL DRLG P 8290 start drilling, 1.38 bpm @ 4090psi, BHP=4213,WHP=137. 21:12 21:36 0.40 8,440 7,266 PROD8 DRILL WPRT P Wiper trip up to 7266, PU WT is 28k. 21:36 22:06 0.50 7,266 8,440 PROD8 DRILL WPRT P RBIH from 7266 to 8440'. 22:06 00:00 1.90 8,440 8,567 PROD8 DRILL DRLG P 8440 MD, BOBD, 1.39 bpm @ 3940psi, BHP=4120,WHP=139 Page 23 of 26 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 09/13/2012 24 hr Summary Drill AL2-01 Lateral in the Al formation from 8567 to 9490. 00:00 00:36 0.60 8,567 8,590 PROD8 DRILL DRLG P Continue drilling from 8567 to 8590. 1.39 bpm @ 3980 psi. 00:36 01:18 0.70 8,590 6,940 PROD8 DRILL WPRT P Start wiper trip to TTL, PU WT is 29k, Recip in 4.5 liner section to clean up, PUH to 6940. 01:18 01:42 0.40 6,940 7,213 PROD8 DRILL WPRT P RBIH,20k PW, 01:42 01:54 0.20 7,213 8,590 PROD8 DRILL WPRT P Tie into RA Marker+2'correction. RIH, 01:54 02:30 0.60 8,590 8,740 PROD8 DRILL DRLG P 8590'BOBD, Pump rate 1.41 bpm @ 3785 psi, BHP=4222psi 02:30 04:00 1.50 8,740 7,270 PRODS DRILL WPRT P @ depth of 8740',Start wiper trip, PUH to 7270' 04:00 05:00 1.00 7,270 8,740 PROD8 DRILL WPRT P Wiper back in hole. RIW 19k 05:00 07:15 2.25 8,740 8,890 PROD8 DRILL DRLG P 8740'BOBD 1.41bpm at 3796psi. BHP 4731,WHP 89 07:15 08:00 0.75 8,890 7,700 PROD8 DRILL WPRT P 8890'Wiper up to 7700', PUW 30k 08:00 08:30 0.50 7,890 8,890 PROD8 DRILL WPRT P 7700',Wiper back in hole. RIW 18k 08:30 11:00 2.50 8,890 9,040 PROD8 DRILL DRLG P 8890'BOBD 1.41bpm at 3751psi. BHP 4267.WHP 81 11:00 11:45 0.75 9,040 6,900 PROD8 DRILL WPRT P 9040'Wiper up to TT-6900'. PUW 29k 11:45 12:00 0.25 6,900 7,235 PROD8 DRILL WPRT P 6900'Wiper back in hole. RIW 18k 12:00 12:15 0.25 7,235 7,255 PROD8 DRILL DLOG P Tie into RA Marker from 7235'bit depth to 7255'correction of+3.0' 12:15 13:15 1.00 7,255 9,040 PROD8 DRILL WPRT P 7255'Wiper back in hole.RIW 18k 13:15 14:30 1.25 9,040 9,190 PROD8 DRILL DRLG P 9040ft-BOBD 1.41bpm at 3850psi. BHP 4186,WHP 88 14:30 15:30 1.00 9,190 8,000 PROD8 DRILL WPRT P 9190'Wiper up to 8000'. PUW 29k 15:30 16:00 0.50 8,000 9,190 PROD8 DRILL WPRT P . 8000'Wiper back in hole.RIW 13k 16:00 18:00 2.00 9,190 9,340 PROD8 DRILL DRLG P 9190'-BOBD 1.41bpm at 3780psi. BHP 4318,WHP 99 18:00 19:00 1.00 9,340 6,900 PROD8 DRILL WPRT P 9340'-Wiper up to the TT 6900'PU WT is 28k. 19:00 20:00 1.00 6,900 9,340 PROD8 DRILL WPRT P RBIH,Tie into RA Marker @ 7213', 1.5'correction. RIH, 20:00 22:42 2.70 9,340 9,490 PROD8 DRILL DRLG P 9340 BOBD 1.43 bpm at 3743psi, BHP=4357,WHP=95 22:42 23:12 0.50 9,490 7,300 PRODS DRILL WPRT P 9490'Wiper up to 7300'PU WT is 29k. 23:12 00:00 0.80 7,300 9,490 PROD8 DRILL WPRT P 7300,Wiper back in hole. 09/14/2012 Completed drilling AL2-02 Lateral to TD of 9700'Ran lower liner in AL2-02. 00:00 02:00 2.00 9,490 9,640 PROD8 DRILL DRLG P 9490 BOBD 1.48 bpm at 3782psi, BHP=4320,WHP=99 02:00 02:30 0.50 9,640 8,800 PROD8 DRILL WPRT P Start wiper from 9640'to 8800' 02:30 03:00 0.50 8,800 9,640 PROD8 DRILL WPRT P Wiper back to 9640' 03:00 04:00 1.00 9,640 9,703 PROD8 DRILL DRLG P 9640 BOBD 1.42 bpm at 3774psi, BHP=4052,WHP=116 Page 24 of 26 Time Logs - - Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:12 0.20 9,700 9,700 PRODS DRILL WPRT P Reached TD @ 9700',pump 10 bbl low and 10 bbl high vis pill 04:12 06:00 1.80 9,700 6,890 PROD8 DRILL WPRT P PUH to Chase sweep to TTL. 06:00 06:15 0.25 6,890 7,235 PROD8 DRILL WPRT P 6890'-Wiper back in hole. RIW 18k 06:15 06:30 0.25 7,235 7,251 PROD8 DRILL DLOG P 7235'Bit depth tie into RA marker for a correction of+2.5' 06:30 07:30 1.00 7,251 9,703 PROD8 DRILL WPRT P 7251'-wiper back in hole. 07:30 08:30 1.00 9,703 9,560 PROD8 DRILL WPRT P Confirm TD 9703'-PUH and start liner pill down coil. 08:30 11:30 3.00 9,560 72 PROD8 DRILL SFTY P Tag surface,close SSSV with 860psi on well. Bleed down to 100psi and monitor well for 15min. No change. Bleed well off and monitor well for flow for 15min no flow.PJSM for LD AL2-02 lateral drilling BHA. 11:30 12:00 0.50 72 0 COMPZ CASING PULD P OOH with BHI tools. PJSM-Rig up rig floor for liner running. 12:00 14:15 2.25 0 1,072 COMPZ CASING PUTB P PJSM-MU AL2-02 lower liner section 14:15 14:30 0.25 1,072 1,072 COMPZ CASING SFTY P Kick while tripping tubing drill.All crews reported in including BOT hand. Drill time 2min 25sec. 14:30 16:00 1.50 1,072 1,581 COMPZ CASING PUTB P Joint#32 Continue picking up liner 16:00 17:30 1.50 1,581 7,159 COMPZ CASING RUNL P RIH with AL2-02 lower liner section 17:30 17:45 0.25 7,159 7,159 COMPZ CASING DLOG P 7159'-Correct to the EOP flag- 11.6' 17:45 18:45 1.00 7,159 9,703 COMPZ CASING RUNL P RIH to tag depth of 9703'online with pumps,release GS from liner top, POOH, 18:45 19:00 0.25 9,703 7,213 COMPZ CASING DLOG P Tie into RA with a correction of+1. POOH 19:00 20:00 1.00 7,213 0 COMPZ CASING TRIP P Continue POOH 20:00 21:00 1.00 0 0 COMPZ CASING TRIP P Tag up,Close SSSV,PJSM, Lay down liner running tools BHA#26 21:00 23:54 2.90 0 961 COMPZ CASING PUTB P PJSM-MU AL2-02 Upper liner section 23:54 00:00 0.10 961 961 COMPZ CASING SFTY P Conduct kick drill. 09/15/2012 Completed running AL2-02 upper liner,swapped well over to S/W with freeze protect to 2500', rig down for rig move. 00:00 00:30 0.50 961 961 COMPZ CASING PULD P RU BHA#27. 00:30 02:42 2.20 961 7,072 COMPZ CASING RUNL P RIH with AL2-02 Upper liner section 02:42 03:06 0.40 7,072 8,088 COMPZ CASING RUNL P Correction at flag is-11ft. PU WT is 29k, RIH 03:06 03:36 0.50 8,088 7,153 COMPZ CASING RUNL P Tagged lower liner at 8088,Top of liner is at 7171'online with pump, unlatch GS, PUH. PU WT is 27k. 03:36 05:06 1.50 7,153 7,153 COMPZ CASING DISP P PUH to 7153,open EDC,Start displacing with S/W. 05:06 06:30 1.40 7,153 2,549 COMPZ CASING TRIP P 7153'-POOH PUW 29k Page 25 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:30 07:30 1.00 2,549 2,549 COMPZ CASING DISP P 2549'-Hook up diesel and pump 35bbls.Swap to diesel,freeze protect from 2500'. 07:30 08:00 0.50 2,549 0 COMPZ CASING TRIP P POOH 08:00 11:00 3.00 0 0 COMPZ CASING PULD P PJSM- OOH undeploy BHA.Tools OOH 11:00 13:00 2.00 0 0 DEMOB WELLPF DISP P PU nozzle,flush BOPE and Rig, pump inhibitor thru coil and rig. Line up big air compressor to blow down coil. 13:00 21:00 8.00 0 0 DEMOB WHDBO NUND P Release rig at 21:00 hrs. Page 26 of 26 3N-07 Well Work Summary DATE SUMMARY F 3/1/12 WEATHER-DELAYED START. PULLED XXN PLUG @ 7128' RKB. MEASURED BHP @ 7300' RKB: 3637 PSI. IN PROGRESS. 3/2/12 WEATHER-DELAYED START. BRUSHED& FLUSHED TBG TO XN @ 7128' RKB. SET XXN PLUG @ 7088'SLM, 7128' RKB. COMPLETE. 3/8/12 WC MIT-OA(PASSED) 3/27/12 DRIFTED TBG WITH 2.25"x 15' BAILER TO XXN PLUG @ 7129' RKB. IN PROGRESS. 3/28/12 WEATHER DELAYED START. SET CATCHER @ 7092' SLM. PULLED OV @ 6383' RKB. ATTEMPTED SET DV @ 6383' RKB, UNSUCCESSFUL. PULLED GLVs @ 5454', 4235', &2705' RKB. IN PROGRESS. 3/29/12 SET DVs @ 2705', 4235', 5454', &6383' RKB. MIT TBG & MIT IA 2500 PSI, PASSED. PULLED DV @ 6973' RKB. IN PROGRESS. 3/30/12 PULLED DV @ 2705' RKB. PULLED CATCHER @ 7092' SLM. COMPLETE. 4/7/12 PUMPED .875 BALL CALIBRATED REEL VOLUME. CONDITIONED WELL TO SEAWATER. SET CEMENT RETAINER AT 6900' MD. FREEZE PROTECTED WELL FROM 2700'ND. RESTART IN AM. JOB IN PROGRESS. 4/8/12 PUMPED CEMENT THROUGH RETAINER SET AT 6900' MD TO OPEN GLM AT 6973' MD UP THE IA TO 6591' BY VOLUME. STUNG OUT OF RETAINER AND LAYED IN 1 BBL CEMENT TO 6728' MD. WASHED DOWN TO TOC WITH BIO. FREEZE PROTECTED WELL TO 3000'ND. JOB COMPLETE. COPY OF THE PUMP REPORT AND CEMENT TEST IN THE ATTACHMENTS. 4/11/12 TAGGED @ 6863' SLM. CMIT TO 1700 PSI, PASSED. GOOD DRAWDOWN TEST. SET SLIPSTOP CATCHER @ 5750' SLM. SET DV @ 2705' RKB. PULLED CATCHER. IN PROGRESS. 4/15/12 DUMP BAIL 5 GALLONS OF CEMENT @ 6865' SLM —20'TBG VOLUME. IN PROGRESS. 4/17/12 DRIFTED TBG WITH 1.75" DD BAILER. TAGGED TOC @ 6860' SLM. JOB COMPLETE. 4/20/12 CUT TUBING AT A DEPTH OF 6015' IN THE MIDDLE OF A JOINT USING 2.125"JRC JET CUTTER. NO PRESSURE DIFFERENCE WAS SEEN ON TUBING AND IA DUE TO GAS CAP. RIG WILL COMFIRM CUT. 4/21/12 (MISC) : REPLACE BENT LDS, IC PPPOT PASSED, TORQUED LDS TO 450 LBS. 4/22/12 Attempt to circulate down tubing through jet cut at 6015' RKB. Tubing pressured up to 2000 psi after 1.5 bbls with IA at 0 psi after 5 min. Attempt to circulate down IA. IA pressured up to 1800 psi with tubing at 480 psi after 5 min. Unable to circulate. 4/29/12 SET CATCHER @ 5700' SLM. PULLED DV @ 2705' RKB. CONFIRMED TBG x IA COMMUNICATION. SET NEW DV. PULLED DV @ 5454' RKB. CONFIRMED TBG x IA COMMUNICATION. SET NEW DV. PULLED CATCHER. READY FOR E/L. 5/5/12 PERFORMED RCBL NO CEMENT OBSERVED AT OR ABOVE 6015'. PERFORMED TUBING CUT AT 5985', CCL TO CUTTER OFFSET 5', CCL STOP AT 5980', POSITIVE INDICATION FROM TUBING X IA COMMUNICATION AFTER CUT. 7/29/12 GAUGED TUBING & LINER 2.80"TO 7331' RKB. DRIFTED TO 7331' RKB W/ 17.5'x 2.62" BAKER DUMMY WHIPSTOCK. CLOSURE TEST TRDP. SET SLIP STOP CATCHER @ 6742' SLM. PULLED 1.5"SOV FROM 6736' RKB AND REPLACED W/DV. PULLED CATCHER. ( BLEED IA TO ZERO) UNABLE TO MIT IA DUE TO CDR MUD SWAP. READY FOR E-LINE. 8/2/12 (PRE-CTD) MITIA-PASSED; PT& DD MV-PASSED; SSV- PASSED; SV-PASSED 8/5/12 RIH WITH RADIAL CEMENT BOND LOGGING TOOL AND LOG THE 4 1/2" LINER FROM 7256'(TD) UP THRU GLM @ 6736' 9/23/12 CONFIRMED TRDP FUNCTIONING. RAN BRUSH &2.62" MAGNET TO LINER TOP @ 6791' RKB. IN PROGRESS. 9/24/12 MEASURED BHP @ 6791' RKB ( 3927 psi ) . SET 2.81"XX PLUG @ 6791' RKB. SET 2.75"AVA CATCHER ON PLUG @ 6768' SLM. PULLED DV FROM 6736' RKB. IN PROGRESS. 9/25/12 CIRC OUT W/DIESEL. SET 1/4"OV @ 6736' RKB. PULLED DV FROM 6186' RKB AND SET GLV . CALLED TO ASSIST E-LINE. IN PROGRESS. 9/27/12 JOB POSTPONED FOR CIVIL TO WORK ON WELL HOUSE 9/28/12 DRIFT TO TRSSSV @ 1817' RKB AND ENSURE ITS OPEN. PULLED DV AND SET GLV @ 5545' RKB. IN PROGRESS. 9/29/12 PULLED DVs @ 4809' , 3894'&2639' RKB; SET GLVs @ 4809' &3894' RKB. IN PROGRESS 9/30/12 SET GLV @ 2639' RKB, GOOD TBG TEST TO 2500 ( GLVs HAVE FLOATING CHECKS), PULLED CATCHER ON AND 2.81 XX PLUG @ 6791' RKB. COMPLETE. 212-12.._7 _ 2� 16s ,�� PRINT DISTRIBUTION TION LIST U HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 3N-07AL1-03 RUN NUMBER (mandatory; FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: August 31,2012 TODAYS DATE: 10/10/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Uf F'HIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I I 1 1 1 I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP 1 1 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 1 I 1 I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 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 Letter of Transmittal rails RECEIVED BAKER Date: SEP 2 5 2012 September 24, 2012 HUGHES AOGCC To: From: Christine Mahnken Carl Ulrich i oachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3N-07AL1 3N-07AL1-01 r 110 -07• -I • i 3N-07AL1-03 At r a 7 3N-07AL2 l _ Z 3N-07AL2-01 3N-07AL2-02 1 a_ ( 1 9 3N-07AL2-03 a 1 _ 13,-( 4( (8) Total prints .(/J� j i i ` 1 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 ret ail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com (0- r A\ E n [13 nsEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COM1'HSSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-07AL1-03 ConocoPhillips Alaska, Inc. Permit No: 212-127 Surface Location: 1561' FSL, 304' FEL, SEC. 29, T13N, RO9E, UM Bottomhole Location: 1096' FNL, 1497' FEL, SEC. 29, T13N, RO9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3N-07A, Permit No 212- 052, API 50-029-21539-01. 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 revoc.lion or suspension of the permit. e , jtr ij•�j� or sio er DATED this l day of August, 2012. 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 AUG 2 7 2012 PERMIT TO DRILL A r 20 AAC 25.005 la.Type of Work: - 1 b Proposed Well Class: Development-Oil ❑✓ ' Service-Winj ❑ Single Zone E• 1c.Specify if well is proposed for: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: a Blanket U Single Well 11 Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180-- 3N-07AL1-03 ' 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:8645' • TVDSS: 6356' Kuparuk River Field 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1561'FSL,304'FEL,Sec.29,T13N, RO9E,UM - ADL 25521 Kuparuk River Oil Pool' Top of Productive Horizon. 8.Land Use Permit: 13.Approximate Spud Date: 744'FNL, 1034'FEL,Sec.29,T13N, RO9E, UM 471 8/29/2012 Total Depth: 9.Acres in Property: 14 Distance to 1096'FNL, 1497'FEL,Sec.29,T13N,RO9E,UM 2560 Nearest Property: 13070 4b Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL , 61 feet 15.Distance to Nearest Well Open Surface:x- 518096 y- 6013799 Zone- 4 GL Elevation above MSL. 34 feet to Same Pool: 3N-11A,1060 16 Deviated wells: Kickoff depth. 7965 ' ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 105° deg Downhole:4828 psig . Surface:4183 psig • 18.Casing Procrram: 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 1417 7228' 6373' 8645' 6356' 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) 9850 6350 9739 6293 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 235 sx CS II 115' 115' Surface(new window) 2564' 9.625" new window cut in 7/2012 2599' 2599' Surface(Original) 3654' 9.625" 1070 sx PF"E",280 sx Class G 3691' 3610' Production 7003' 7" 42 5 bbls Class G,32 bbls CI G 7041' 6304' Liner 626' 4.5" 19 bbls Class G 7448' 6588' Perforation Depth MD(ft): Perforation Depth ND(ft): none none 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date. 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 //0 "A Printed Name L. Gantt Title CTD Supervisor G`�tiAxY iG4 ft" Signature * J --- Phon 263-4021 Date e / /( ...)4.coW �Vh` Commission Use Only (Z 7 Permit to Drill API Number: Permit Apoval See cover letter Number 2.,12_ / �1? I 50- -2/5-37_ -{j( 1 Date l) .P for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: LJ ,� 415—CO ,psi W (cel Samples req'd: Yes ❑ /No M • o. req'd: Yes ❑, No 0 Other: / H2S measures: Yes Er No ❑ Direct s req'd: Yes © No ❑ c� i ' i. '•'OVED BY THE COMMISSION AT Form 10-401 (Revised 7/2009) This permit is vW f♦r Y4in 8 flog tile Lt f app'• . (20 AA r" 5.'' (g)) r_ Submit in COM•aISSIONER v V 74- ,./ 21.r L- v /1' ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED August 27, 2012 AUG 2 7 2012 Commissioner-State of Alaska AOGCC Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: r i ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill (PTD)application to add a seventh horizontal CTD • lateral from Kuparuk well 3N-07A(PTD#212-052). This seventh lateral is 3N-07AL1-03, which is being added to pick up Al sand pay that was bypassed while drilling earlier laterals due to geologic complexity. This particular lateral will likely spud Wednesday, August 29, 2012. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary(updated information for 3N-07AL1-03 in blue font) — Permit to Drill application form and directional plan — Proposed wellbore schematic following CTD operations, updated as of August 27 If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, /61( s /6),/2- 4,11-0Y £ati2 J. Gary Eller ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA 3N-07AL1, 3N-07AL1-01, 3N-07AL1-02, CIJ 3N-07AL2, 3N-07AL2-01, & 3N-07AL2-02 2RC Drilling Program Summary Update for Addition of 3N-07AL1-03 Lateral (blue font) 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 Attachment 1: Directional Plan for 3N-07AL1-03 7 Attachment 2: Updated Proposed Well Schematic for 3N-07A CTD Laterals 7 Page 1 of 7 ORIGINAL Updated 8/27/12 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are six proposed laterals described in this document: KRU 3N-07AL1, 3N-07AL1-01, 3N-07AL1-02, 3N-07AL2, 3N-07AL2-01, and 3N-07AL2-02. These laterals will exit from the 3N-07A motherbore. All will be classified as "Development- Oif'wells along with the 3N-07A motherbore. The 3N-07AL1-03 lateral is being added to pick up additional Al sand pay that was bypassed due to geologic complexity. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A3, A2, and Al sands in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of each of the 3N-07A laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4600 psi. Using a maximum potential formation pressure of 4828 psi, the maximum potential surface pressure is 4183 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) There has not been a static BHP measurement made in well 3N-07A since the well was only drilled and completed in July 2012. An 11.6 ppg fluid was required to maintain overbalance while running 4%" liner, which is consistent with measurements of formation pressure in offset wells. Our expectation is that we will not encounter formation pressure in excess pf 12.0 ppg EMW(i.e. 4019 psi at 6441' TVD) during the drilling of the 3N-07A CTD laterals. - Maximum potential formation pressure is based on the November 2011 pressure from 3N-05 to the southwest, which had measured formation pressure of 4705 psi at 7412' MD, 6277' TVD for a gradient of 14.4 ppg. In 3N-07A this equates to a maximum potential formation pressure of 4828 psi (7238' MD, 64'41-'-TVD")"and a maximum potential surface pressure of 4183 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled. 3N pad is a water only injection pad. It is unlikely that an influx while drilling will produce a significant amount of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 3N-07A laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.0 ppg I MW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 3N-07A laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. A 1 Page 2 of 7 ,; t'\ 1 t3 1 y"; Updated 8/27/12 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 3N-07AL1 8170' 9575 6357' 6357' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-07AL1-01 7900' 9655' 6398' 6332' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-07AL1-02 7965' 9730' 6375' 6385' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-07AL1-03 7228' 8645' 6373' 6356' 23/8', 4.7#, L-80, ST-L slotted liner up v inside 4W liner 3N-07AL2 7825' 9700' 6376' 6370' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-07AL2-01 7582' 9685' 6399' 6361' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-07AL2-02 7194' 9675' 6349' 6408' 2%", 4.7#, L-80, ST-L slotted liner up inside 4'/2" liner Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (ppfl Grade Connection MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 9%" 36 J-55 BTC 0' 2599' 0' 2598' 3520 2020 Casing 7" 26 J-55 BTC 0' 7040' 0' 6303' 4980 4320 Liner 4W 12.6 L-80 IBT& BTC 6842' 7748' 6165' 6803' 8430 7500 Tubing 3W 9.3 L-80 EUE 8rd-Mod 0' 6874' 0' 6187' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.9 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.9 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3N-07A motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3N-07A contains a subsurface safety valve (SSSV) at 1818' MD. The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. Page 3 of 7 [) R f ! E A 1 Updated 8/27/12 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) pi 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 3N-07A laterals we will target a constant BHP of 12.0 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 3N-07AL1 Window(7238' MD, 6441' TVD, 6380' SSTVD) Using MPD Pumps On ✓ (1.5 bpm) Pumps Off A-sand Formation Pressure (11.6 ppg) 3885 psi 3885 psi Mud Hydrostatic(9.9 ppg) 3316 psi 3316 psi Annular friction (i.e. ECD, 0.090 psi/ft) 651 psi 0 psi Mud + ECD Combined 3967 psi 3316 psi (no choke pressure) (overbalanced (underbalanced —80 psi) —570 psi) IP at Window(12.0 ppg) 4019 psi 4019 psi Choke Pressure Required to Maintain 50 psi 700 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-07A is a recent lateral of the 3N-07 A-sand producer. Well 3N-07A will remain suspended until the completion of six CTD laterals, which are being drilled to increase reservoir exposure and improve waterflood sweep in the Al, A2, and A3 sands. Four laterals will be drilled south of 3N-07A and three will be drilled north. A mechanical whipstock will be placed in the 4W liner at the first planned kickoff point for the southern laterals. The 3N-07AL1 lateral will exit the 4W liner at 7238' MD and will target the A2 sand south of the Page 4 of 7 Updated 8/27/12 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 existing well with a 2337' lateral. The hole will be completed with a 2%'slotted liner to the TD of 9575' MD with an aluminum billet at 8170' MD. The 3N-07AL1-01 lateral will kick off from the aluminum billet at 8170' MD and will target the A3 sand south of the existing well with a 1485' lateral. The hole will be completed with a 2%'slotted liner to the TD of 9655' MD with an aluminum billet at 7900' MD. The 3N-07AL1-02 lateral will kick off from the aluminum billet at 7900' MD and will target the Al sand south of the existing well with an 1830' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9730' MD with an aluminum billet at 7965' MD. The 3N-07AL1-03 lateral will kick off from the aluminum billet at 7965' MD and will target the Al sand south / of the existing well with a 680' lateral. The hole will be completed with a 2%"slotted liner to the TD of 8645' MD with the final liner top located inside the 4W liner at 7228' MD. A mechanical whipstock will be placed in the 4W liner at the planned kickoff point for the northern laterals. The 3N-07AL2 lateral will exit the 4W liner at 7204' MD and will target the A2 sand north of the existing well with a 2496' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9700' MD with an aluminum billet at 7825' MD. The 3N-07AL2-01 lateral will kick off from the aluminum billet at 7825' MD and will target the A3 sand north of the existing well with an 1860' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9685' MD with an aluminum billet at 7582' MD. The 3N-07AL2-02 lateral will kick off from the aluminum billet at 7582' MD and will target the Al sand north of the existing well with a 2093' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9675' MD with the final liner top located inside the 4W liner at 7194' MD. Pre-CTD Work 1. RU e-line. Run whipstock dummy and GR/CCL correlation log inside 4W liner. 2. RU slickline. Install dummy valve in GLM#6 at 6736' MD. 3. 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. 3N-07AL1 Lateral (A2 sand, south) a. Set whipstock at 7238' MD with 15° LOHS orientation. b. Mill 2.80"window through 4W liner at 7238' MD c. Drill 2.70" x 3" bi-center lateral to TD of 9575' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8170', using the SSSV as a barrier to formation pressure if available 3. 3N-07AL1-01 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8170' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9655' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7900', using the SSSV as a barrier to formation pressure if available 4. 3N-07AL1-02 Lateral (Al sand, south) a. Kick off of the aluminum billet at 7900' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9730' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7965', using the SSSV as a barrier to formation pressure if available Page 5 of 7 0 R. 1GIN�A L Updated 8/27/l2 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 5. 3N-07AL1-03 Lateral (Al sand, south) a. Kick off of the aluminum billet at 7965' MD 1,11)); b. Drill 2.70"x 3" bi-center lateral to TD of 8645' MD c. Run 2%" slotted liner with from TD to 7228' up into the 4W liner, using the SSSV as a barrier to formation pressure if available 6. 3N-07AL2 Lateral (A2 sand, north) a. Set whipstock at 7204' MD with 15° ROHS orientation. b. Mill 2.80"window through 4W liner at 7204" MD c. Drill 2.70"x 3" bi-center lateral to TD of 9700' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7825', using the SSSV as a barrier to formation pressure if available 7. 3N-07AL2-01 Lateral (A3 sands, north) a. Kick off of the aluminum billet at 7825' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9685' MD c. Run 2%" slotted liner with an aluminum billet from TD to 7582', using the SSSV as a barrier to formation pressure if available 8. 3N-07AL2-02 Lateral (Al sands, north) a. Kick off of the aluminum billet at 7582' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9675' MD c. Run 2%" slotted liner from TD up to 7194' MD, inside the 4W liner. Will use the SSSV as a barrier to formation pressure if available while picking up liner. 9. Freeze protect. Set BPV, ND BOPE. 10. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Perform static BHP survey 3. Put on production. Pressure Deployment of BHA The planned bottomhole assemblies(BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. � RIGIM Page 6 of 7 Updated 8/27/12 PTD Applications for KRU 3N-07AL1, AL1-01, AL1-02, AL1-03 AL2, AL2-01, & AL2-02 During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Since 3N-07A is equipped with a SSSV, the CTD laterals will not need to be displaced to an over- balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 3N-07AL1 06 13,070' 1,060' 3N-11A 3N-07AL1-01 02 13,070' 1,060' 3N-11A 3N-07AL1-02 02 13,070' 1,060' 3N-11A 3N-07AL1-03 01 13,070' 1,060' 3N-11A 3N-07AL2 08 13,070' 1,590' 3N-11A 3N-07AL2-01 02 13,070' 1,590' 3N-11A 3N-07AL2-01 02 13,070' 1,590' 3N-11A Attachment 1: Directional Plan for 3N-07AL1-03 Attachment 2: Updated Proposed Well Schematic for 3N-07A CTD Laterals Page 7 of 7 O I I J f,r L Updated 8/27/12 (-,.i O) 7 l0 Q m m 0 N @ N L N N @ I 11! Z _ -c in Z II I No IIU, M ' O r N m .-v)- O N O I N ca ca N g I J n J m c. 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ClI i9 1■ H■tl@N ■NH •tl H MUM MI Mil i NN @ •p q V�aamaga,�,■NB I= ' 1,.■, @.,• Btl.•N. 1:1:11gNIMM RIM INIMMIIII IMIll ■NN B■ BN, _.-_. +-IllamN■@ B.ORM tl•••N,tl■■q,tlm:. =0 3 Ste. 1,.tl N,■■ Ntl,•H■ .._ MIRE ■H H@• -_. ■N p/Hq■,■,■N , sg@§ uw qN• • UUUUUU •N I I r-- ■_N a..-. ...N `-' $,�, `•,u' I:m,N• U:U$ $$ Htl,■tlB�,�ma®gym @UI■,U i I ''''"-".14".-' •�U H■U■■mB:ma:U ` r I - p r.' !..g • l .7 -1 I•N• U■a @NN N■UN@.NN■mm:ammm:U i•p B••■•tlNNN q•tl i- - ' �o Ii; ConocoPhilli s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-07 3N-07AL1-03 Plan: 3N-07AL1-03_wp01 Standard Planning Report 27 August, 2012 BAKER HUGHES ORIGINAL I.-- Baker Hughes INTEQ FG'" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level • Project: Kuparuk River Unit MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) - Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07AL1-03 Design: 3N-07AL1-03_wp01 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 3N Pad Site Position: Northing: 6,013,799.17 ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14 ° Well 3N-07 Well Position +N/-S 0.00 ft Northing: 6,013,799.44 ft . Latitude: 70°26'55.956 N +E/-W 0.00 ft Easting: 518,096.21 ft - Longitude: 149°51'8.533 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.90 ft . Wellbore 3N-07AL1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2011 9/1/2012 16.07 80.00 57,387 Design 3N-07AL1-03_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,950.38 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -33.90 0.00 0.00 230.00 1 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,950.38 105.25 285.52 6,378.84 2,970.41 -724.09 0.00 0.00 0.00 0.00 7,965.00 104.92 283.60 6,375.03 2,973.96 -737.75 12.88 -2.26 -13.13 -99.84 8,065.00 86.07 276.87 6,365.49 2,991.46 -835.23 20.00 -18.85 -6.73 200.00 8,265.00 92.48 237.36 6,368.13 2,947.71 -1,026.23 20.00 3.21 -19.75 278.60 8,515.00 91.60 187.33 6,358.62 2,743.29 -1,155.66 20.00 -0.35 -20.01 270.00 8,645.00 90.65 213.32 6,356.03 2,622.45 -1,200.43 20.00 -0.73 19.99 91.80 8/27/2012 1:20:49PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ril CIIN - Baker Hughes INTEQ IS' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07AL1-03 Design: 3N-07AL1-03_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (ft) (') (°) (ft) (ft) (ft) (ft) (°I100ft) C) (ft) (ft) 7,950.38 105.25 285.52 6,378.84 2,970.41 -724.09 -1,354.66 0.00 0.00 6,016,767.79 517,364.98 TIP 7,965.00 • 104.92 283.60 6,375.03 2,973.96 -737.75 -1,346.47 12.88 -99.84 6,016,771.30 517,351.31 KOP 8,000.00 98.33 281.19 6,367.98 2,981.30 -771.21 -1,325.56 20.00 -160.00 6,016,778.56 517,317.84 8,065.00 86.07 276.87 6,365.49 2,991.46 -835.23 -1,283.05 20.00 -160.49 6,016,788.57 517,253.81 3 8,100.00 87.14 269.94 6,367.57 2,993.53 -870.08 -1,257.68 20.00 -81.40 6,016,790.55 517,218.95 8,200.00 90.38 250.19 6,369.76 2,976.36 -968.06 -1,171.59 20.00 -80.99 6,016,773.14 517,121.03 8,265.00 92.48 237.36 6,368.13 2,947.71 -1,026.23 -1,108.62 20.00 -80.56 6,016,744.36 517,062.93'' 4 8,300.00 92.46 230.35 6,366.62 2,927.10 -1,054.45 -1,073.75 20.00 -90.00 6,016,723.68 517,034.77 8,400.00 92.21 210.34 6,362.49 2,851.34 -1,118.80 -975.75 20.00 -90.30 6,016,647.77 516,970.60 8,500.00 91.69 190.33 6,359.05 2,758.10 -1,153.35 -889.35 20.00 -91.13 6,016,554.46 516,936.28 8,515.00 91.60 187.33 6,358.62 2,743.29 -1,155.66 -878.07 20.00 -91.82 6,016,539.64 516,934.01 5 8,600.00 91.00 204.33 6,356.68 2,661.83 -1,178.76 -808.01 20.00 91.80 6,016,458.14 516,911.11 8,645.00 . 90.65 213.32 6,356.03 2,622.45 • -1,200.43 • -766.10 20.00 92.19 6,016,418.71 516,889.54 TD at 8645.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3N-07AL1_Polygon(c 0.00 0.00 0.00 3,048.81 -289.52 6,016,847.23 517,799.32 70°27'25.940 N 149°51'17.038 W -plan misses target center by 6386.53ft at 8000.00ft MD(6367.98 TVD,2981.30 N,-771.21 E) -Polygon Point 1 0.00 3,048.81 -289.52 6,016,847.23 517,799.32 Point2 0.00 3,076.17 -1,280.56 6,016,872.19 516,808.32 Point3 0.00 1,285.87 -2,075.89 6,015,080.14 516,017.42 Point 4 0.00 1,056.92 -1,683.40 6,014,852.16 516,410.42 Point 5 0.00 2,532.64 -1,079.83 6,016,329.20 517,010.35 Point 6 0.00 2,784.70 -675.19 6,016,582.22 517,414.33 Point 7 0.00 2,613.07 -416.57 6,016,411.23 517,673.34 Point 8 0.00 3,048.81 -289.52 6,016,847.23 517,799.32 3N-07AL1-03_T1 0.00 0.00 6,369.00 2,997.32 -904.73 6,016,794.25 517,184.30 70°27'25.433 N 149°51'35.111 W -plan misses target center by 5.87ft at 8133.67ft MD(6368.94 TVD,2991.54 N,-903.64 E) -Point 3N-07AL1-03_T2 0.00 0.00 6,363.00 2,875.84 -1,124.05 6,016,672.26 516,965.29 70°27'24.238 N 149°51'41.554 W -plan misses target center by 17.61ft at 8384.64ft MD(6363.10 TVD,2864.37 N,-1110.70 E) -Point 3N-07AL1_Faultl (col 0.00 0.00 6,424.00 3,625.33 -482.14 6,017,423.23 517,605.32 70°27'31.610 N 149°51'22.698 W -plan misses target center by 699.65ft at 7950.38ft MD(6378.84 TVD,2970.41 N,-724.09 E) -Polygon Point 1 6,424.00 3,625.33 -482.14 6,017,423.23 517,605.32 Point 2 6,424.00 1,651.13 -905.87 6,015,448.21 517,186.43 Point 3 6,424.00 571.50 -1,105.46 6,014,368.20 516,989.48 3N-07AL1-03_T3 0.00 0.00 6,356.00 2,624.00 -1,197.68 6,016,420.26 516,892.28 70°27'21.761 N 149°51'43.716 W -plan misses target center by 1.46ft at 8642.31 ft MD(6356.06 TVD,2624.70 N,-1198.96 E) -Point 8/27/2012 1:20:49PM Page 3 COMPASS 2003.16 Build 69 OR ! ` 1 1 A. I 1.-' Baker Hughes INTEQ (/r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07AL1-03 Design: 3N-07AL1-03_wp01 [Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") C') 108.95 48.00 16"Conductor 16 24 8,645.00 6,356.03 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,950.38 6,378.84 2,970.41 -724.09 TIP 7,965.00 6,375.03 2,973.96 -737.75 KOP 8,065.00 6,365.49 2,991.46 -835.23 3 8,265.00 6,368.13 2,947.71 -1,026.23 4 , 8,515.00 6,358.62 2,743.29 -1,155.66 5 8,645.00 6,356.03 2,622.45 -1,200.43 TD at 8645.00 8/27/2012 1:20:49PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-07 3N-07AL1-03 3N-07AL1-03_wp01 Travelling Cylinder Report 27 August, 2012 Iral�r BAKER HUGHES 0 R C! �. ConocoPhillips or its affiliates (/,- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-07 Project: Kuparuk River Unit TVD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Reference Site: Kuparuk 3N Pad MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site Error: 0.00ft North Reference: True Reference Well: 3N-07 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 3N-07AL1-03 Database: EDM Alaska Prod v16 Reference Design: 3N-07AL1-03_wp01 Offset TVD Reference: Offset Datum Reference 3N-07AL1-03_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,950.38 to 8,645.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,061.80ft Error Surface: Elliptical Conic Survey Tool Program Date 8/27/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 93.95 2,599.00 3N-07(3N-07) GCT-MS Schlumberger GCT multishot 2,640.47 7,233.69 3N-07A(3N-07A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,238.00 7,950.38 3N-07AL1 (3N-07AL1) MWD MWD-Standard 7,950.38 8,645.00 3N-07AL1-03_wp01 (3N-07AL1-03) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") 1") 108.95 108.95 16"Conductor 16 24 8,645.00 6,416.98 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3N Pad 3N-07-3N-07AL1 -3N-07AL1 7,975.00 7,975.00 0.15 5.48 -3.54 FAIL-Major Risk 3N-07-3N-07AL1-01 -3N-07AL1-01 7,975.00 7,975.00 0.15 5.48 -3.54 FAIL-Major Risk 3N-07-3N-07AL1-02-3N-07AL1-02 7,975.00 7,975.00 0.15 6.05 -4.11 FAIL-Major Risk 3N-09-3N-09-3N-09 Out of range 3N-11 -3N-11 -3N-11 Out of range 3N-11 -3N-11A-3N-11A Out of range 3N-11 -3N-11AL1 -3N-11AL1 Out of range 3N-11 -3N-11AL2-3N-11AL2 Out of range 3N-11 -3N-11AL2-01 -3N-11AL2-01 Out of range 3N-11 -3N-11AL3-3N-11AL3 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/27/2012 11:05:21 AM Page 2 of 6 COMPASS 2003.16 Build 69 [E 1 "' 1N. I 4 ConocoPhillips or its affiliates �l/r ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-07 Project: Kuparuk River Unit TVD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Reference Site: Kuparuk 3N Pad MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site Error: 0.00ft North Reference: True Reference Well: 3N-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3N-07AL1-03 Database: EDM Alaska Prod v16 Reference Design: 3N-07AL1-03_wp01 Offset TVD Reference: Offset Datum Reference Depths are relative to 3N-07A @ 60.95ft(D141 (28.1+33.9))Coordinates are relative to:3N-07 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.14° Ladder Plot I I 240 I I I I I I I I I I J J J J _ ---J_ I I I I I I I I I I I 1 I 1 I I I I I I 1 80 I I I I C I I I I I I I I I I {p 1 I I I I 1 I I 1 I C J J J J _ ___J ____J P3) I I I I I w I I 1 I I a) 1 I I I 1 I I I I I 120 I I I I I I C 1 1 I I I 4? I I I I C I I I I f I I I I 60 I I 1 1 I I I I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I I 1 I I I I 0 I I 0 1500 3000 4500 6000 7500 9000 M ensured Depth LEGEND 3N-0 7.3N-07AL1.3 N-07 AL1 VO 3N-0 7.3N-07 AL1-01.3N-07AL1-01 VO .-. ,..- 3NO7,3N-07AL1-02.3N-07AL1-02VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/27/2012 11:05:20AM Page 6 of 6 COMPASS 2003.16 Build 69 l4 .r C 6 o \; o Y 4 ,A $ - Y z �W < 9 , 4 ' N Z e co 4mLn '8 2 .o 0 4 ilk 4. o M\ 0a u _ _o 8 g ohm 8 z 2 ` n z.moo § co ,.� _ Y o n vs 9 �h-o4 4 -N ' z $ ¢ o Ii ^ o g s I°d ,1 �' M Z - o z ^ti a CO" 8s .o 1 . o 4 tv '8 8 rn M 2rn 4 x -g O C) oi do X 'o I o 0 LP' 3 0 O 8 o 8 o 8 8 8 8. „. ..8..- o 8 0 0 0 LllN m m Q ro N o m~ M (!/►3 051) +)ilLioN/�-)LDnoS N . - o coMN 03 a o c W c w U Q, o 4g � CO Ibrei c v 07, Ie81 Zm GGa0 0 0 0 QHYNf�en.9 1111 ' M, . ir,11111 gFmNNo o0IIJ CQ W,� NO 0000 ,Ni,`- . ^ c on po<nom9, Z Ja 1-O�NNNm O .h rMJ 2 J pQ �i6 aQ M 3 8,0000 M. .zza Z O"oC)00Y Y M M,- NNNNp N drail o -41i°' hillik < o a 111 N S mi rn cY eo SQ 4 O a -yq N J IN-,Nr�O-N CpyQ MJ^ 11 Q_ J 0 Z .—.--0,.. M ¢ v,rnv-1- o J gqN N NNNNNN E c 8 Es N MQ"c7N CJ C9 Wm C'�p LIP-�RppamO N M�L7M M 0 Q •A - 82 NmN T Z V0 _^ n O 2^ N 1 o- Y ...3. 'n 1'0 _c`4rn �m1n 7 Y ONTO f mm No Nr 7 6' ������< 8 8 8 8 8 8 8 8 2 tO V mmmm Wel eagueayg ON Za 8 (MAI OE)1300(1 1091 A a"kL (JRfl3INA 1 N A, L OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME k e I L 3` - 07A L I - 03 PTD# ._ / 2- I Z'7 ./ Development Service Exploratory Stratigraphic Test Non-Conventional Well /6-'(7,1 � / FIELD: ky6—r-C4--- /�[ '� POOL: /�-cz (--j ���( 1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well I� r z(-( At —C-7 ! 1 (If last two digits in Permit No. 21 Z C='S Z,API No. 50-U /S -U I I. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 Ca w 0) O (p CO 0 O N a) 6 a) o 0U co a) N 0 -o a c a • E- 5 E i E 0 o a 0 c = a) Ca L 7• a (O O1 _ O 2 c c c o a N V) - 7 C 3 7 a) ._ -00)O E O C o. O O C OD L 0 45 U) U) (s C w• (n p c 3 a) D t) L O a) 0) 7 O) N • O Q .N U @ E a 3 E O 0 a) m ca a °- - :2 m m :-E _ C 3 0) 0 O L C N N 3 O) 0) a co a M 3 U O N Ul L a �" J v @ c 0 Ch uCi r 3 m 3 2 0 0 0 0 °� _ 0 .— 7 J 0(O N � � N � O N m y a) 0) o a) N Fw. 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