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212-038
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. 1Q - 033/Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: ColoItems: vrayr ❑ Maps: scale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: 4121. Date: O - s /s/ roP Project Proofing BY: dj _ Date: ` /s/ 9 I J4'J 111 f) Scanning Preparation 1 x 30 = © + �9 = TOTAL PAGES (Count does not include cover s eet) BY: Date: I __g /s/ Production Scanning Stage 1 Page Count from Scanned File: _ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: (7Y.ES NO BY: de° Date: 9'/a5//17t. /s/ �/j( r 10 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 Michel 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 I O 1 c76 a N a o w . Em m C a )4. N N:. o N p s co N B T o z 0 'no o-E p-E isErn,,: a) >- �} } O) 0 Co O - C_'L d 03 d m p m + C- = Co N• 5 }I > C 7 C y C9 O a)U' O 000:4=- Co T H £ N p as •et a,> a) .C-•> a) a•- o a c f0 E E o Ea o c T co E u, p E 7.y• y .2-.0. U 0 < Z V'0 O` N 0 N CO 0 N N N aai E N� t t o F. I u) 0 ;1-0_0 2C4C �rxw 2EI o 0 + U a m Q I o f 0 vj 2 2 a C j N N N N N U U J o I d y J o W O N N N N N Q O f0 f0 CO co In N - Cl) O C C Cco C C E /Z / Z J• — OU O 0 0• 0 0 o >- } } Ce O y co a co co co co CO 0 ii: 4. 3 N w 1,,,,,- T. N N N N ISI r+ 6 N J 0 V) 0_0 CO CO CO CO a y E •� is J I � m 0 0 Z 0_i Cl) 0_i W 2 O C .3 C) CO U to CO CO co CO n it E UJ zCo J d N Com c. U c0 0 E J cz Z o j CL 11 o • Co QCo ''. O- C `o 7 -a E -_ a L co 7 o a m 0cn p lj 0 y o 0 o c U U 0_ M c / ZI ' J2 U 0 0 in C r .. 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J_ O V Z Y u N N R �/ • N O IX Q O N a CL _ W a 1 Ce O U W 0 Z J 0 0 C.) -J Z 8 r d) J 0.0 f° 1 CL M c it o O N a O E V U I••• N J a Q o r ~ N iS C Z N C D CO re• it) ill CO ce 0 II `0116 Q m o 11 • a) o Q o Z E U A co 4Z i N 0 0 m' M z _. O N LW 3 N N O to l V II rICO a • a E a 2 U RECEIVED STATE OF ALASKA JUN 14 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORTQCG la.Well Status: Oil a • Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 15,2012 212-038/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 May 3,2012 • 50-029-20479-64 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 653'FSL,633'FEL,Sec. 16,T11N,R10E, UM • May 4,2012 • 1E-05AL2-01 • Top of Productive Horizon: 8. KB(ft above MSL): 101'RKB ' 15.Field/Pool(s): 2169'FSL, 1912'FWL,Sec. 15,T11N,R10E,UM GL(ft above MSL): 69.5'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2066'FSL,2414'FEL,Sec. 15,T11N, R10E, UM 7232'MD/6330'TVD Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-549890 • y- 5960237- Zone-4 • 8216'MD/6327'TVD ' ADL 25651 TPI: x-552421 y- 5961773 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-553376 y- 5961677 Zone-4 1784'MD/1693'TVD 469 18.Directional Survey: Yes ❑� No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1622'MD/ 1554'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7260'MD/6331'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 32' 95' 32' 95' 32" 300 sx Permafrost 13.375" 72# N-80 32' 2416' 32' 2213' 17.5" 2300 sx Fondu,275 sx Permafrost 9.625" 47# L-80 202' 6694' 202' 5968' 12.25" 620 sx Class G 2.375" 4.7# L-80 7232' 8216' 6330' 6327' 8.5" slotted liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 6788' 4802'MD/4159'TVD and 6746'MD/6012'TVD 7241'-8216'MD 6331'-6327'TVD slotted liner 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1 AiV:ifiPLECON Z DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i< ° 1 1 , ' 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) June 9,2012 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/11/2012 17 hours Test Period--> 1785 2251 77 100 Bean 1459 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 285 psi 1282 24-Hour Rate-> 2307 3366 107 23 deg. 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 descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS JUN 15 2012,4*),? Form 10-407 Revised 12/2009 V L-P' CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS(List all formations and n, a encountered): 29. FORMATION TESTS NAME MD TVD Well tested? El Yes Q✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1622' 1554' needed,and submit detailed test information per 20 AAC 25.071. Base Kuparuk A5/Top A4 7730' 6339' N/A Formation at total depth: Kuparuk A5 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey k1/44) &l itI201S 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree©265-6820 Printed Nam L. antt 4. Title: CTD Engineering Supervisor / Signature OTAIy'Ll1` s Ll' CI Phone 263-4021 Date j/2 f 2-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 KUP • 1 E-05AL2-01 Il CO000Pl1llIp5 8 Well Attributes Max Angle&MD TD Alaska,11 N; "`.,... Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Mt Btm(ftKB) 500292047964 KUPARUK RIVER UNIT PROD Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••Well Con%MULTIPLE LATERALS-1E-05AL2-011222012 250 6/18/2006 39.49 8/25/1980 Schemalk-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,152.0 3/21/2012 Rev Reason:ADD SIDETRACKS ninam 5/20/2012 HANGER,26- 'll,— Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)... String Wt...String... String Top Thrd LINER AL2-01 23/8 1.992 7,231.6 8,216.0 4.60 L-80 STL I Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (R103) (°) Rem Description Comment ID(in) 7231.6 BILLET LINER TOP BILLET 1.000 Perforations&Slots Shot CONDUCTOR. 32-95-- Top(TVD) Btm(TVD) Dens Top(kKB) Btm(ftKB) (RKB) (ftKB) _ Zone Date (st,,, Type Comment PRODUCTION 7,241 8,216 5/4/2012 320 SLOTS TIE-BACK. 31-202 Notes:General&Safety End Date Annotation SAFETY VLV. o°I 5/20/2012 NOTE:MULTI-LATERAL WELL:AL1,AL2,AL2-01,AL2-02,AL3 , 1.784 111 [I SURFACE,_ L. 32-2,417 GAS LIFT. _ ri` 2,760 111 GAS LIFT, 4,388 } WHIPSTOCK. 5.014 WINDOW IR, 5,0145,031 GAS LIFT. 5,399 Er B GAS LIFT, 6,069 /11111 I GAS LIFT, W 6,632 Ell PRODUCTION Pont ION 202-6,694 LOCATOR, - 6,718 PBR,6,725 SEAL ASSY, �— 6,745 _ PACKER.6,745 NIPPLE.6.767 WLEG, WHIPSTOCK,OCC. I.m!". 6,967 WHIPSTOCK 6,990 LINER, 4,802-7,267 II SLOTS, 6.797-8.370 SLOTS. 7.241-0,218It SLOTS. 72754.275 1111 LINER 2L2-01, LIAU.1 AL2,. I l LINER 7,2808,275 TD Mandrel Details (1 E-05AL2-01), 8,275 I I I Top Depth Top Port LINER AL3, J r (TVD) Incl OD Valve Latch Size TRO Run 6.780-9,677 I r Ste Top(ftKB) (RKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,760.0 2,488.8 36.77 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/8/2012 A 2 4,387.8 3,786.3 30.07 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/19/2012 3 5,398.8 4,726.4 10.32 CAMCO KBG2-9 I 4 6,089.3 5,405.5 13.17 CAMCO KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 3/22/2012 1 GAS LIFT DMY INT 0.000 0.0 3/22/2012 5 6,631.5 5,913.6 28.65 CAMCO KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 4/7/2012 O. CHne w p 0 0 a C NEr>N a 4)i"- 4 N 'Ic' 9 N rt co NM0 W D) 0) D) ' °° r;' NN 22mmm /\ ~ Y Y Y Q (0 X X X X X c i W (n C) (n C)C) Q pp 44 co -(gyp N 1pCCtlpl �n ooa) in - - Nr Q 4- g lii p CO Co CI o (0 W $ co > ) r- r- a> ( F- N M V LO L() N or 2 'a a y X 3 " i c 14441, 2 pN. r�ivoccoo o 2(D( Nit cc 2 N V 1.0D V O. 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O ti O O O O O O N O O O O ,- O O O O 0 0 O O O O O O O O O C d Q U) U) a) N U) m N U) m .- 7 N- O M m a1 N 7 N- O C1 m al N U) m 7 N- Ocv 0 0-C R C.) O c T ' N N N M M M 7 7 7 U) U) U) m m m m r- f- r m m m m a) m al O O .'- d Ns N N- N- r r I- N- N- h N- n N. N N- N- N- N. N. h r N- N- N- ri n N- N- co co m m O o _ m CO ill a —2CO : 0 o 0 O N CO CO o CO C LLQ 0 U I CO z o 0 °o w is I— r T v v o a c0 (O a) OQ M M N- O N LO▪ 10 CO CO C Ci) cai N- O O e2 er2 v u v 0 0 Z Z CO N M M co- x ; = = d > O O j -O O .-. CO M O I' V O JG vi o 0 O 0 a d co c U Y ❑ va aU E cu _. Q Q ul Q i 9 0 0 : v COCOCOM N LU dj dj W cc c_ o a) o r ui F CL W ,, O.r N CO CO WLO LO N L '• O d l4 lc0 O w d PI N 4 rt d 00 r a)s— cu cz a) o N tD c CO R = 7 Z uD u' u m st- O 2C V ▪ > O r= d 42 R co d d ▪ C U d d er >, 1 N.- o 0 • i� - Et .0 d .0 m Lorivi pn e ❑ ❑ 'tZ v v V Ji- 2Zoo W- cn cn 6' + C C U N N [D = N 1-- el 1 ^ O N CD Z CC O CD N CO N O Cn CI=' N N N CO CO CD } ❑ N N N U = CO C] C) C O O O ug s N =_t Q n -O V u) u) F in Y w •— l d _, Y a ar S Q Q 0 0 0 co N N 1 \ ry. U Y Y UJ W W C m w A� to u la 0 coo f o .. ❑ M `° C co t1 O C �. m N € CV 0 d .. a 0) 0 0) R os 0 U ,...,4; � d a C) c� ain33 ❑ w Conoco Phillips Time Log & Summary Wel/view Web Reporting ^e u o rt Well Name: 1E-05 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/17/2012 8:00:00 PM Rig Release: 5/15/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/17/2012 24 hr Summary Travel from 3K-10,MIRU on 1E-05,cut 2700'of CT for coil life management. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move from 3K to 1E Pad 12:00 15:00 3.00 0 0 MIRU MOVE MOB P Arrive on pad, Unhook jeeps, PJSM for spotting units 15:00 20:00 5.00 0 0 MIRU MOVE MOB P Units spotted on 1E-05,start rig up 20:00 00:00 4.00 0 0 MIRU WHDBOSLPC P Rig accepted RU for pipe cutting,cut 2700'of coil for fatigue management 04/18/2012 Continue cutting CT, rehead CT,test BOP, pull two-way check, PU ws BHA 00:00 04:00 4.00 0 0 MIRU WHDBO SLPC P Continue cutting 2700'of CT 04:00 06:00 2.00 0 0 MIRU WHDBO SLPC P RU to pump slack management, Fill Coil 06:00 09:00 3.00 0 0 MIRU WHDBO CTOP P Pump Slack, no wire movement, Perform shell test, inner reel valve and pack off.Test wire,good Meg test continuity failed,trim wire and retest-no pass on continuity. 09:00 12:00 3.00 0 0 MIRU WHDBO BOPE P Start BOPE Test,Test Witnessed by Matt Herrera,AOGCC. Blind shear seal hydraulic actuator is leaking, goto repair mode.Trim coil additional coil to find good wire cut total of 2730'good wire 12:00 18:00 6.00 0 0 MIRU WHDBO BOPE P Actuator repaired, pass function test continue BOPE Test.CTC installed, Pull test to 35K, Head Up UQC 18:00 18:36 0.60 0 0 MIRU WHDBO SLPC P PT CTC 4200 and TT line to 1500 18:36 21:06 2.50 0 0 MIRU WHDBO BOPE P Pull two way check 21:06 22:24 1.30 0 0 MIRU WHDBO BOPE P PT both PDL to 2300 psi 22:24 23:30 1.10 0 0 SLOT RPEQP1 PULD P Make up BOT 3-1/2 X 5-1/2 thru-tubing whipstock and Inteq BHA 23:30 00:00 0.50 0 0 SLOT RPEQP1TRIP P Pump froward through open EDC to move slack forward 04/19/2012 Set thru tubing whipstock at 7030'oriented 335 deg. Milled window and open hole to 7057'. Swapped well over to 9.6 ppg flo-pro mud system 00:00 02:18 2.30 0 6,760 SLOT RPEQP1TRIP P RIH, circulating through open EDC 02:18 02:36 0.30 6,760 6,790 SLOT RPEQP1DLOG P Tie-in,-12.5 02:36 02:54 0.30 6,790 7,043 SLOT RPEQP1WPST P RIH to setting depth,22K RIW, 35K PUW. Close EDC. Set WS at 335 deg. 2000 psi to set. Set down 5K Page 1 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:54 04:54 2.00 7,043 0 SLOT RPEQP1TRIP P POOH 04:54 07:00 2.10 0 73 SLOT RPEQP1PULD P Lay down WS BHA/P/U BHA#2 with.6 AKO motor,2.80 window mill and 2.79 string reamer 07:00 08:42 1.70 73 6,780 SLOT WHPST TRIP P Trip in hole, EDC open Hold Pre Spud meeting with G. Corder's crew 08:42 08:54 0.20 6,780 6,823 SLOT WHPST DLOG P Log K-1 marker,-13'correction 08:54 09:00 0.10 6,823 6,990 PROD1 WHPST TRIP P Continue Trip in well 09:00 09:12 0.20 6,990 6,990 PROD1 WHPST CIRC P Circ rest of bio milling fluid to bit, Close EDC, PUW=36K 09:12 09:18 0.10 6,990 7,035 PROD1 WHPST TRIP P Trip in to dry tag TOWS 09:18 18:30 9.20 7,035 7,046 PROD1 WHPST MILL P Dry tag Whipstok @ 7035, PUH, Pumps on 1.5 BPM @ 2850 PSI FS, Start time milling from 7034.9 milled to 7035.8 to see consitant WOB. Puts BOW @ 7041.5 by numbers 18:30 20:42 2.20 7,046 7,058 PROD1 WHPST MILL P Drilling rat hole at 4+FPH, 1.5 BPM, 3000 CTP,3440 BHP,0 WHP 20:42 22:30 1.80 7,058 7,020 PROD1 WHPST MILL P Perform 3 reaming passes, 335 deg, 0 deg and 305 deg up and at 335 each down. Dry drift was clean. 22:30 23:00 0.50 7,020 7,020 PROD1 WHPST CIRC P Swap well to flo-pro 23:00 00:00 1.00 7,020 2,100 PROD1 WHPST TRIP P POOH 04/20/2012 Drilled AL1 build section to 7380',tripped for lateral drilling BHA and started drilling lateral. 00:00 00:36 0.60 2,100 0 PROD1 WHPST TRIP P Continue POOH 00:36 01:00 0.40 0 0 PROD1 WHPST SFTY P PJSM,monitor well for no-flow 01:00 02:00 1.00 0 0 PROD1 WHPST PULD P Lay down window milling BHA Mill and string reamer came out 2.79"no-go 02:00 03:00 1.00 0 0 PROD1 DRILL PULD P MU drilling BHA for build section of AL1 lateral,3.0"Bicenter bit and 2.3 deg motor 03:00 04:48 1.80 0 6,770 PROD1 DRILL TRIP P RIH 04:48 05:06 0.30 6,770 6,800 PROD1 DRILL DLOG P Tie-in,-14' 05:06 05:24 0.30 6,800 7,057 PROD1 DRILL TRIP P Continue RIH 05:24 09:54 4.50 7,057 7,210 PROD1 DRILL DRLG P Drilling, 1.44 BPM,3100 CTP, 3800 BHP 09:54 10:54 1.00 7,210 7,210 PROD1 DRILL WPRT P Wiper to window, PUW=33K, Pull up 6765', log K-1 marker for-.5' correction, Log RA Marker @ 7038 10:54 14:24 3.50 7,210 7,319 PROD1 DRILL DRLG P 7210', Drill Ahead, 1.52 BPM @ 3350 PSI FS, BHP=3930 14:24 14:48 0.40 7,319 7,319 PROD1 DRILL WPRT P BHA Wiper, PUW=37K. Holding negative WOB,Wipe to window, Dragging 32K 14:48 16:30 1.70 7,319 7,380 PROD1 DRILL DRLG P 7319', Drill ahead, 1.45 BPM @ 3170 PSI FS, BHP=3900 Page 2 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:48 2.30 7,380 0 PROD1 DRILL TRIP P 7380 End of Build/Turn. PUW=32K, Open EDC above window Jet max rate through 5-1/2 liner up to Tubing tail 18:48 19:06 0.30 0 0 PROD1 DRILL SFTY P PJSM for undeployment 19:06 21:24 2.30 0 0 PROD1 DRILL PULD P Undeploy BHA#3,deploy BHA#4 for drilling AL1 lateral 21:24 23:00 1.60 0 6,780 PROD1 DRILL TRIP P RIH 23:00 23:12 0.20 6,780 6,810 PROD1 DRILL DLOG P Tie-in,-14',31K PUW 23:12 23:36 0.40 6,810 7,380 PROD1 DRILL TRIP P Continue RIH 23:36 00:00 0.40 7,380 7,389 PROD1 DRILL DRLG P Drilling ahead, 1.44 bpm,3100 CTP, 3880 BHP, 04/21/2012 Continued drilling AL1 lateral to 8255' 00:00 03:30 3.50 7,389 7,530 PROD1 DRILL DRLG P Drilling ahead, 1.44 bpm,3100 CTP, 3880 BHP 03:30 04:36 1.10 7,530 7,060 PROD1 DRILL DLOG P Wiper trip with MAD pass from 7380' to window. 31K PUW, low/high vis sweeps 04:36 04:48 0.20 7,060 7,530 PROD1 DRILL WPRT P Wiper back in hole, 18K RIW 04:48 07:36 2.80 7,530 7,680 PROD1 DRILL DRLG P Drilling ahead, 1.44 bpm,3100 CTP, 3880 BHP 07:36 08:30 0.90 7,680 7,680 PROD1 DRILL WPRT P Wiper to window, PUW=32K, Clean trip up and down, RIW=17K 08:30 13:00 4.50 7,680 7,830 PROD1 DRILL DRLG P 7680', Drill Ahead, 1.47 BPM @ 3200 PSI FS, BHP=3930 13:00 15:00 2.00 7,830 7,830 PROD1 DRILL WPRT P Wiper to Tubing tail with tie in and sweeps, Correct-2'.saw little bump coming up through window.Clean back through window.7630 to 7650 light bobbles no motor work at full rate, also saw 7715 going in 15:00 17:18 2.30 7,830 7,980 PROD1 DRILL DRLG P Drill Ahead, 1.45 BPM @ 3300 PSI FS, BHP=3962 17:18 18:24 1.10 7,980 7,980 PROD1 DRILL WPRT P Abreviated wiper,with sweeps, PUW=33K. PUH to 7300' 18:24 21:00 2.60 7,980 8,140 PROD1 DRILL DRLG P Continue drilling, 1.45 BPM,3200 CTP,3950 BHP 21:00 21:54 0.90 8,140 8,140 PROD1 DRILL WPRT P Pump sweeps,wiper trip. 32K PUW, 17K RIW 21:54 00:00 2.10 8,140 8,255 PROD1 DRILL DRLG P Continue drilling ahead, 1.45 BPM, 3300 CTP, 3980 BHP 04/22/2012 Continued drilling AL1 liner, after wiper trip from 8730'unable to pass 7096', POOH for cleanout assembly 00:00 00:42 0.70 8,255 8,280 PROD1 DRILL DRLG P Continue drilling ahead, 1.45 BPM, 3300 CTP,3980 BHP 00:42 02:00 1.30 8,280 7,060 PROD1 DRILL WPRT P Pump sweeps and wiper to tubing tail, 33K PUW 02:00 02:12 0.20 7,060 7,090 PROD1 DRILL DLOG P Tie in,-2.5' 02:12 02:42 0.50 7,090 8,280 PROD1 DRILL WPRT P Wiper back in hole, 18K RIW 02:42 07:00 4.30 8,280 8,430 PROD1 DRILL DRLG P Continue drilling ahead, 1.44 BPM, 3350 CTP,3980 BHP 07:00 08:24 1.40 8,430 8,430 PROD1 DRILL WPRT P Abreviated wiper with sweeps to 7. 530, PUW=32.5K Page 3 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/22/2012 24 hr Summary Continued drilling AL1 liner, after wiper trip from 8730'unable to pass 7096', POOH for cleanout assembly 08:24 11:00 2.60 8,430 8,580 PROD1 DRILL DRLG P 8430', Drill Ahead 1.42 BPM @ 3200 PSI FS, BHP=4000 11:00 12:30 1.50 8,580 8,580 PROD1 DRILL WPRT P 8580',Abreviated wiper to 7500 with sweeps, PUW=33K 12:30 16:00 3.50 8,580 8,730 PROD1 DRILL DRLG P 8580', Drill Ahead, 1.4 BPM @ 3320 PSI FS, BHP=4060. New mud at bit shortly after starting to drill 16:00 17:42 1.70 8,730 7,060 PROD1 DRILL WPRT P Wiper to TT with tie in and sweeps, PUW=35K 17:42 18:00 0.30 7,060 7,090 PROD1 DRILL DLOG P Tie-in,-3.5' 18:00 18:36 0.60 7,090 7,050 PROD1 DRILL WPRT T Wiper back in hole, 18K RIW. Stacked weight at 7096'with .3 BPM pump rate, as drilled TF(335) Tried at 0 pump rate and 12 FPM 335 TF .3 BPM and 10 FPM at 335 and 0 TF .5 BPM and 20 FPM at 335 TF 1 BPM and 4 FPM at 335 TF All attempts resulted in stacking weight and motor work at the same depth 7096' 18:36 20:06 1.50 7,050 0 PROD1 DRILL TRIP T POOH, opened EDC,no large shales at the shaker 20:06 20:24 0.30 0 0 PROD1 DRILL SFTY T PJSM for undeploy/deploy 20:24 21:36 1.20 0 0 PROD1 DRILL PULD T Undeploy drilling 21:36 23:06 1.50 0 0 PROD1 DRILL PULD T Deploy cleanout BHA with 2.3 Deg. motor and 2.73"Hycalog E-1005 bit. Would not go down hole with PDL, shut in SSSV and bleed off wellhead pressure. continue run BHA without managed pressure. 23:06 00:00 0.90 0 3,000 PROD1 DRILL TRIP T RIH following MPD tripping schedule 04/23/2012 Attempted to clean out lateral. Set whipstock at 7012'TOWS, milled window. 00:00 00:42 0.70 3,000 6,770 PROD1 DRILL TRIP T RIH following MPD tripping schedule 00:42 01:00 0.30 6,770 6,790 PROD1 DRILL DLOG T Tie-in,-15' 01:00 01:24 0.40 7,150 7,153 PROD1 DRILL REAM T PUH at 1.4 BPM,clean. RIH at 1.4 BPM,clean Pump 7 bbls.low vis and 7 bbls high vis sweeps 01:24 01:42 0.30 6,790 7,150 PROD1 DRILL REAM T Close EDC and RIH, pumping at 1.2 BPM in open hole,stacked weight with motor work at 7099', PUH and try again, at 7101'stacked weight with motor work,weight came off and continued in hole with minor stacking and motor work @ 7103' Page 4 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:42 02:06 0.40 7,153 7,370 PROD1 DRILL REAM T Stacked weight and motor work at 7153', PUH and try again at.4 BPM and continue RIH brought rate back up to.8 BPM for remainder of trip in hole, had some weight stacking and motor work, reduced pump rate to.3 BPM allowed RIH with no issues 02:06 02:42 0.60 7,370 7,270 PROD1 DRILL REAM T PUH chasing sweeps. Lost returns, able to PUH at 10K overpull(43K) Unable to RIH, BHP at tool 4800. PUH to 7212'bit depth and pulled up to 53K, unable to RIH. Pressured up WH to 950 PSI, able to RIH and establish returns. Continue RIH 18K at 1.4 BPM down CT with full returns and normal pressures 02:42 03:18 0.60 7,270 7,040 PROD1 DRILL REAM T Stacked weight with motor work at 7270', PUH,started to get overpulls and motor work at 7158',-2K WOB and 1000 PSI motor work, PUH at 3-5 FPM and continue to window 03:18 03:54 0.60 7,040 6,776 PROD1 DRILL CIRC T Retruns were normal with no excessive solids, PUH through window and recip in 5-1/2"liner. 03:54 06:00 2.10 6,776 PROD1 DRILL TRIP T POOH 06:00 07:30 1.50 62 0 PROD1 DRILL PULD T At surface, PJSM,Shut SSSV perform no flo,All good Pull BHA#5 from well 07:30 09:00 1.50 0 0 PROD1 DRILL CTOP T S/B on orders,Swap out checks in UQC 09:00 09:54 0.90 0 75 PROD1 WHPST PULD T M/U BHA#6 Whipstock,M/U to Coil track, M/U to coil and surface test tool.Tag up and set counter. 09:54 11:54 2.00 75 6,780 PROD1 WHPST TRIP T RIH, EDC open 11:54 12:12 0.30 6,780 6,814 PROD1 WHPST DLOG T Log Tie in for-15'correction 12:12 12:24 0.20 6,814 7,025 PROD1 WHPST TRIP T Close EDC, PUW=31.5K,trip into set depth 12:24 12:36 0.20 7,025 7,025 PROD1 WHPST WPST T At set depth 7025.0,TOWS=7012, 330 degrees,see shift @ 3500 PSI, set down 4K, Looks good 12:36 14:42 2.10 7,025 75 PROD1 WHPST TRIP T Trip out of hole,Jet SSSV on way out 14:42 16:18 1.60 75 73 PROD1 WHPST PULD T At surface, PJSM, Flo Check well. Lay down Whipstock setting tools, P/U window mill BHA#7 with .6 degree motor,2.80 dimond window mill,2.79 string reamer. M/U to coil and surface test 16:18 18:18 2.00 73 6,760 PROD1 WHPST TRIP T Trip in Hole 18:18 18:36 0.30 6,760 6,790 PROD1 WHPST DLOG T Tie into K1,-15' 18:36 18:54 0.30 6,790 7,015 PROD1 WHPST TRIP T Continue RIH 18:54 00:00 5.10 7,015 7,021 PROD1 WHPST MILL T Tag WS at 7016', 31K PUW, 18K RIW, 1.5 BPM,3300 CTP,3797 BHP,start time milling 1 fph. Page 5 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04/24/2012 24 hr Summary Milled window and rat hole to 7037',drilled AL1 build section to 7330'. 00:00 01:00 1.00 7,021 7,022 PROD1 WHPST MILL T Continue milling window, appear to have exited casing, continue time milling. 01:00 03:00 2.00 7,022 7,037 PROD1 WHPST MILL T Milling rat hole 03:00 04:06 1.10 7,037 7,035 PROD1 WHPST REAM T ream window three times, up at 330 TF,0 TF and 360 TF,down at 330. Last down was with pump down. Window is clean. Swap well over to flo-pro. 04:06 06:06 2.00 7,035 0 PROD1 WHPST TRIP T POOH 06:06 07:06 1.00 0 0 PROD1 WHPST PULD T At surface,crew change out,Shut SSSV bleed off WHP flo check well, PJSM pull tools from dead well,Mill and string reamer out of well @ 2.79" 07:06 08:12 1.10 0 62 PROD1 DRILL PULD T M/U BHA#8,2.25 degree motor and 3"bi center,M/U to coil and surface test,stab on well,tag up and set counters 08:12 10:06 1.90 62 6,775 PROD1 DRILL TRIP T RIH, Pump open SSSV 5500PSI, EDC shut 10:06 10:18 0.20 6,775 6,803 PROD1 DRILL DLOG T Log Gamma Tie into K1,correct-14' to 6789 10:18 10:36 0.30 6,803 7,038 PROD1 DRILL TRIP T Trip into drill 10:36 14:24 3.80 7,038 7,190 PROD1 DRILL DRLG T Drill Ahead 1.41 BPM @ 3250 PSI FS BHP=3778,Adjust BHP for 12Lb at window 14:24 15:42 1.30 7,190 7,190 PROD1 DRILL WPRT T 7190,Wiper to TT(K-1),Tie in RA, K-1 0 correction, Log RA @ 7019.5, TOWS=7012, BOW=7021,saw motor work with overpull @ 7070 15:42 16:42 1.00 7,190 7,215 PROD1 DRILL DRLG T 7190', Drill Ahead, 1.46 @ 3480 PSI FS, BHP=3928 16:42 16:48 0.10 7,215 7,215 PROD1 DRILL WPRT T Pull BHA Wiper, Low ROP, Pump Sweeps, 16:48 20:54 4.10 7,215 7,300 PROD1 DRILL DRLG T 7215', Drilling, Back on bottom with low differential, Sweeps 4 BBIs away, 1.46 BPM @ 3485 PSI FS 20:54 21:42 0.80 7,300 7,300 PROD1 DRILL WPRT T Wiper to tubing tail 21:42 22:27 0.75 7,300 7,330 PROD1 DRILL DRLG T Continue drilling, 1.47 BPM, 3340 CTP, 3835 BHP 22:27 00:00 1.55 7,330 2,300 PROD1 DRILL TRIP T POOH 04/25/2012 Tripped for lateral drilling assembly,drilled AL1 lateral to 7890'. 00:00 00:42 0.70 2,300 0 PROD1 DRILL TRIP T Continue POOH 00:42 01:12 0.50 0 0 PROD1 DRILL SFTY T PJSM, check for flow 01:12 02:42 1.50 0 0 PROD1 DRILL PULD T Lay down build BHA, PU lateral BHA (#9)with USR 02:42 04:12 1.50 0 6,770 PROD1 DRILL TRIP T RIH 04:12 04:24 0.20 6,770 6,800 PROD1 DRILL DLOG T Tie-in,-15.5 04:24 05:00 0.60 6,800 7,315 PROD1 DRILL TRIP T Continue RIH Page 6 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 05:45 0.75 7,315 7,327 PROD1 DRILL DRLG T Had some difficulty getting back to bottom from 7315'to 7330'. Drilling ahead, 1.45 BPM,3300 CTP, 3900 BHP 05:45 06:45 1.00 7,327 7,298 PROD1 DRILL DRLG T P/U to clean hole,500PSI motor work,40K coming off bottom, Showing negative weight on bit, motr work pulling up hole 06:45 08:03 1.30 7,298 7,329 PROD1 DRILL DRLG T working pipe back to bottom, Set downs and motor work, pump sweeps 08:03 08:21 0.30 7,329 7,332 PROD1 DRILL WPRT T BHA Wiper, high differential, PUW=41 K, dragging heavy with motor work, BHP=3910 08:21 11:21 3.00 7,332 7,440 PROD1 DRILL DRLG T 7332', Drilling ahead, 1.45 BPM @ 3550 PSI FS, BHP=3960 11:21 12:15 0.90 7,440 7,440 PROD1 DRILL WPRT T Pull wiper to 7050 with sweeps, PUW=31 K, Over pulls with motor work @ 7315,7230,7175,7170 45 K with Neg WOB,Setdown @ 7240' 12:15 14:51 2.60 7,440 7,590 PROD1 DRILL DRLG T 7440',Drill Ahead, 1.42 BPM @ 3550 PSI FS, BHP=3950, 14:51 15:03 0.20 7,590 7,345 PROD1 DRILL WPRT T Wiper to window with MAD Pass, PUW=31.5K,with sweeps 15:03 15:57 0.90 7,345 7,040 PROD1 DRILL DLOG T Madd Pass-7345 to 7040 15:57 16:27 0.50 7,040 7,592 PROD1 DRILL WPRT T continue wiper to bottom 16:27 19:00 2.55 7,592 7,740 PROD1 DRILL DRLG T 7592',drill ahead 1.44 BPM @ 3470 PSI FS, BHP=3955 19:00 19:42 0.70 7,740 6,810 PROD1 DRILL WPRT T Wiper to TT,32K PUW. Over pull with motor work at 7309',slight overpulls with motor work from 7250' to 7170' 19:42 21:12 1.50 6,810 7,040 PROD1 DRILL WPRT T Packed off as BHA was coming through the tubing tail,between DPS and bit. RBIH,stacked 8K WOB, PUH to neutral weight and then RBIH with equalized pressure and re-establish circulation. Pump 5 bbls low vis,5 Bbls high vis,5 bbls low vis,5 Bbls high vis while recipricating in the 5-1/2"liner. CBU. 21:12 21:24 0.20 7,040 7,060 PROD1 DRILL DLOG T Tie-in, +.5' 21:24 21:42 0.30 7,060 7,740 PROD1 DRILL WPRT T Wiper back in hole 21:42 23:48 2.10 7,740 7,890 PROD1 DRILL DRLG T Drilling ahead, 1.43 BPM,3400 CTP, 3970 BHP. Differentially stuck at 7783',55K to pull free, BHA wiper and resume drilling 23:48 00:00 0.20 7,890 7,890 PROD1 DRILL WPRT T Pumped sweeps,Wiper to tubing tail. 33K PUW 04/26/2012 Drill AL1 lateral to 8325', run 38 joints slotted liner. Page 7 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:54 0.90 7,890 6,805 PROD1 DRILL WPRT T Wiper to tubing tail,33K PUW, 7312'motor work 7186',-5K WOB and 500 PSI motor work 00:54 01:30 0.60 6,805 7,890 PROD1 DRILL WPRT T Wiper back in hole,stacked weight at 7070', 01:30 03:12 1.70 7,890 8,040 PROD1 DRILL DRLG T Continue drilling ahead, 1.43 BPM, 3550 CTP,3988 BHP 03:12 04:36 1.40 8,040 8,040 PROD1 DRILL WPRT T Pumped sweeps,wiper to the window, 32K PUW 04:36 06:06 1.50 8,040 8,175 PROD1 DRILL DRLG T Continue drilling ahead, 1.43 BPM, 3400 CTP,4010 BHP 06:06 08:06 2.00 8,175 7,040 PROD1 DRILL WPRT T Wiper trip to TT, recip 5 1/2 twice at max rate 08:06 08:12 0.10 7,040 7,059 PROD1 DRILL DLOG T Log RA marker for-1.5'correction 08:12 09:24 1.20 7,059 8,175 PROD1 DRILL WPRT T Wiper back to bottom,Stack out @ 7084,work pipe 09:24 12:06 2.70 8,175 8,325 PROD1 DRILL DRLG T 8175',drill ahead, 1.42 BPM @ 3550 PSI FS, BHP=4005 12:06 13:54 1.80 8,325 7,040 PROD1 DRILL WPRT T 8325,Wiper trip to TT. Planning on drilling until)faults or problems. Clean up 5 1/2 and tie in. Pulling heavy @7170,work pipe coming up. Recip 5 1/2 with sweeps 13:54 14:06 0.20 7,040 7,060 PROD1 DRILL DLOG T Log tie in for-1' 14:06 15:36 1.50 7,060 8,290 PROD1 DRILL WPRT T Continue wiper trip to bottom,took some weight @ 7170 no setdown 15:36 16:06 0.50 8,290 8,290 PROD1 DRILL CIRC T Unable to pass 8295,Call TD Start beads down coil while PUH 16:06 19:12 3.10 8,290 0 PROD1 DRILL TRIP P Trip out pumping beaded liner pill, PUW=33K,paint EOP Flags @ 6900 and 5600. Jetted SSSV. No excessive returns. 19:12 19:42 0.50 0 0 PROD1 DRILL SFTY P PJSM,Monitor well for no flow 19:42 20:36 0.90 0 0 PROD1 DRILL PULD P Lay down drilling BHA 20:36 21:00 0.40 0 0 COMPZ CASING PUTB P RIG up for liner 21:00 21:18 0.30 0 0 COMPZ CASING SFTY P PJSM for liner running 21:18 23:12 1.90 0 1,306 COMPZ CASING PUTB P PU 38 Joints slotted liner and inteq BHA 23:12 00:00 0.80 1,306 5,000 COMPZ CASING RUNL P RIH 04/27/2012 Set whipstock at 6990'TOWS for AL2 lateral,milled window. 00:00 00:30 0.50 5,000 6,906 COMPZ CASING RUNL P RIH 00:30 01:12 0.70 6,906 8,273 COMPZ CASING RUNL P Correct depth to EOP flag,31K PUW, 17K RIW, DHWOB set at -4.5K,continue RIH 01:12 02:54 1.70 8,273 0 COMPZ CASING RUNL P 15K RIW, 1.5K WOB, Release liner, PUH,Tie-in to K1,-4'correction. Top of liner at 7008'. POOH 02:54 03:18 0.40 0 0 COMPZ CASING SFTY P PJSM,monitor well for no-flow 03:18 03:48 0.50 0 0 COMPZ CASING PUTB P Lay down liner running BHA Page 8 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:48 04:30 0.70 0 0 PROD2 RPEQP1 PULD P MU whipstock BHA for L2 04:30 06:30 2.00 0 6,780 PROD2 RPEQP1TRIP P RIH 06:30 06:54 0.40 6,780 6,808 PROD2 RPEQP1DLOG P Log K-1 for-12.5'correction, PUW=30.5K 06:54 07:12 0.30 6,808 7,003 PROD2 RPEQP1TRIP P Trip in to set depth,shut EDC,S/B for morning call 07:12 07:24 0.20 7,003 7,003 PROD2 RPEQP1WPST P At set depth 7003,Orient 30ROHS, TOWS=6990, see tool shift @ 3200 PSI,set 1.5K down. Looks good, 07:24 09:36 2.20 7,003 0 PROD2 RPEQP1TRIP P Trip out of hole 09:36 09:48 0.20 0 0 PROD2 RPEQPI OWFF P At surface. Close SSSV. Perform flow check. 09:48 10:00 0.20 0 0 PROD2 RPEQP1SFTY P Conduct PJSM for PU/LD tools. 10:00 11:00 1.00 0 0 PROD2 RPEQP1PULD P Lay down whipstock setting assembly(BHA#11). 11:00 12:00 1.00 0 0 PROD2 RPEQPI SVRG P Perform rig maintenance/inspection on injector, levelwind, reel,&hubs. 12:00 12:12 0.20 0 0 PROD2 WHPST SFTY P Conduct PJSM for PU/LD tools. 12:12 12:48 0.60 0 0 PROD2 WHPST PULD P Pick up window milling BHA(BHA #12). 12:48 15:30 2.70 0 6,780 PROD2 WHPST TRIP P RIH BHA#12. 15:30 15:42 0.20 6,780 6,730 PROD2 WHPST DLOG P Tie in log[-15'correction]. 15:42 18:06 2.40 6,730 6,995 PROD2 WHPST MILL P RIH BHA#12. Dry tag whipstock pinch point at 6993.8'. PUH(32k#) and come online pumping 1.5 bpm, 3000-psi CTP. Run in but stall right away at what appears to be 6990.4' and 6990.6'. Pull up a couple feet and come online and stall directly. Pull up and re-tag at 6995.61'. PUH and run in pumpimg 1.4 bpm. Stall at 6990.6'. Pull up and run back in pumping. Stall at 6990.5'. PU then run in dry to 6991.5'. Stop and come online into stall. PU(32k#). Run in dry to 6992.5'. Come online and stall. PU and RIH dry. Tag and set do 4000#. Pick up to 6992.5'and come online. Stall right away. Pull up to 6988'and run in milling 1.5-bpm, 0.1-fpm. 18:06 21:12 3.10 6,995 6,998 PROD2 WHPST MILL P Start time milling, 18K RIW,O WOB, 1.48 BPM,3600 CTP,3820 BHP 21:12 00:00 2.80 6,998 7,001 PROD2 WHPST MILL P WOB dropped off,exit casing?, continue to time mill 04/28/2012 Milled AL2 window,drilled build section to 7264'. 00:00 02:00 2.00 7,001 7,006 PROD2 WHPST MILL P Continue time milling, increased ROP to 2 FPH 02:00 03:36 1.60 7,006 7,016 PROD2 WHPST MILL P Milling formation,swap mud to new flo-pro system 03:36 05:30 1.90 7,016 7,016 PROD2 WHPST MILL P Ream window at 30,60 and 0 deg up passes. Drifts clean Page 9 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04/28/2012 24 hr Summary Milled AL2 window,drilled build section to 7264'. 05:30 07:18 1.80 7,016 73 PROD2 WHPST TRIP P POOH 07:18 07:36 0.30 73 73 PROD2 WHPST SFTY P Conduct PJSM for laying down tools. 07:36 07:54 0.30 73 73 PROD2 WHPST OWFF P At surface. Close SSSV. Flow check well. 07:54 08:24 0.50 0 0 PROD2 WHPST PULD P Lay down window milling BHA(BHA #12). 08:24 09:24 1.00 0 0 PROD2 DRILL SVRG P Service top drive. 09:24 09:36 0.20 0 0 PROD2 DRILL SFTY P Conduct PJSM for picking up build drilling assembly(BHA#13). 09:36 10:18 0.70 0 73 PROD2 DRILL PULD P Pick up build BHA(BHA#13). 10:18 12:12 1.90 73 6,775 PROD2 DRILL TRIP P RIH BHA#13. 12:12 12:24 0.20 6,775 6,789 PROD2 DRILL DLOG P Tie-in. -15.5'correction. 12:24 12:30 0.10 6,789 7,016 PROD2 DRILL TRIP P RIH BHA#13. 12:30 13:30 1.00 7,016 7,063 PROD2 DRILL DRLG P Drill ahead AL2 build section: 1.44-bpm;3740-psi CTP;3825-psi BHP;25-psi WHP; 1.8k#WOB. 13:30 15:48 2.30 7,063 7,170 PROD2 DRILL DRLG P Stall motor. Pick up(36k#)and drill ahead: 1.44-bpm;3700-psi CTP; 3864-psi BHP;25-psi WHP; 1.8k# WO B. 15:48 16:00 0.20 7,170 6,760 PROD2 DRILL WPRT P Wiper trip. 16:00 16:12 0.20 6,760 6,785 PROD2 DRILL DLOG P Tie in.(+0.5') 16:12 16:24 0.20 6,785 7,018 PROD2 DRILL WPRT P RIH. 16:24 16:30 0.10 7,018 7,030 PROD2 DRILL DLOG P Log RA. (6998'). 16:30 16:36 0.10 7,030 7,170 PROD2 DRILL WPRT P RIH. 16:36 18:06 1.50 7,170 7,265 PROD2 DRILL DRLG P Drill ahead AL2 build section: 1.44-bpm;3800-psi CTP;3969-psi BHP;36-psi WHP; 1.5k#WOB. 18:06 20:36 2.50 7,265 0 PROD2 DRILL TRIP P POOH 20:36 20:54 0.30 0 0 PROD2 DRILL SFTY P PJSM for un-deploy/deploy BHA 20:54 22:18 1.40 0 0 PROD2 DRILL PULD P Undeploy BHA#13, BHA became stuck while undeploying,shut in SSSV and continued with BHA swap. 22:18 23:36 1.30 0 0 PROD2 DRILL PULD P Deploy BHA#14 for drilling AL2 lateral 23:36 00:00 0.40 0 2,000 PROD2 DRILL TRIP P RIH 04/29/2012 Driled AL2 lateral to 7984' 00:00 01:06 1.10 2,000 6,770 PROD2 DRILL TRIP P Continue RIH with BHA#14 for AL2 lateral 01:06 01:24 0.30 6,770 6,800 PROD2 DRILL DLOG P Tie-in,-15' 01:24 01:36 0.20 6,800 7,264 PROD2 DRILL TRIP P Continue to RIH 01:36 07:00 5.40 7,264 7,415 PROD2 DRILL DRLG P Drilling ahead, 1.44 BPM,3600 CTP, 3890 BHP with WOC. Page 10 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 7,415 7,415 PROD2 DRILL WPRT P Wiper trip w/MAD pass (up to 7018'). 08:00 11:24 3.40 7,415 7,570 PROD2 DRILL DRLG P Drilling ahead, 1.44 BPM, 3880 CTP, 3950 BHP with WOC. 11:24 12:06 0.70 7,570 6,800 PROD2 DRILL WPRT P Wiper trip to tubing. Time out hi/low visc pills out bit before picking up. Pulled 31 k#off bottom. 12:06 12:12 0.10 6,800 7,020 PROD2 DRILL WPRT P RIH. 12:12 12:24 0.20 7,020 7,037 PROD2 DRILL DLOG P Tie in. (-1'correction). 12:24 12:36 0.20 7,037 7,570 PROD2 DRILL WPRT P RIH. 12:36 15:48 3.20 7,570 7,735 PROD2 DRILL DRLG P Drilling ahead, 1.42 BPM,3850 CTP, 3930 BHP with WOC. 15:48 16:48 1.00 7,735 7,735 PROD2 DRILL WPRT P Wiper trip#1. Time out hi/low visc pills out bit before picking up. Pulled 33k#off bottom. 16:48 19:36 2.80 7,735 7,885 PROD2 DRILL WPRT P Continue drilling, 1.45 BPM,3500 CTP,3920 BHP 19:36 20:42 1.10 7,885 7,885 PROD2 DRILL WPRT P Wiper trip, 31K PUW, 18 K RIW, clean trip 20:42 00:00 3.30 7,885 7,984 PROD2 DRILL DRLG P Continue drilling, 1.45 BPM,3600 CTP,3940 BHP 04/30/2012 Drilled AL2 lateral to TD at 8275', ran slotted liner to TD with anchored aluminum billet at 7260'oriented 210 deg. 00:00 01:42 1.70 7,984 8,035 PROD2 DRILL DRLG P Continue drilling, 1.45 BPM ,3600 CTP,3940 BHP 01:42 02:36 0.90 8,035 7,000 PROD2 DRILL WPRT P Pump sweeps,wiper to the tubing tail, 32K PUW 02:36 02:54 0.30 7,000 7,050 PROD2 DRILL DLOG P Tie-in,-1' 02:54 03:24 0.50 7,050 8,035 PROD2 DRILL WPRT P Wiper back in hole, 18K RIW 03:24 06:06 2.70 8,035 8,185 PROD2 DRILL DRLG P Continue drilling, 1.45 BPM,3600 CTP,3940 BHP **Gave AOGCC 24 hour notification for BOP testing at 0500** 06:06 07:36 1.50 8,185 8,185 PROD2 DRILL WPRT P Wiper trip#1 to window. 07:36 11:18 3.70 8,185 8,275 PROD2 DRILL DRLG P Drill ahead: 1.42-bpm;3725-psi CTP; 4023-psi BHP; 15-psi WHP. 11:18 12:48 1.50 8,275 6,798 PROD2 DRILL WPRT P Pump sweeps,wiper to tubing tail. 12:48 13:00 0.20 6,798 7,020 PROD2 DRILL WPRT P RIH. 13:00 13:12 0.20 7,020 7,041 PROD2 DRILL DLOG P Tie-in(-1'correction). 13:12 13:42 0.50 7,041 8,275 PROD2 DRILL WPRT P RIH and re-tag TD. 13:42 14:15 0.55 8,275 7,172 PROD2 DRILL WPRT P Lay in liner running pill with Alpine beads. 14:15 14:18 0.05 7,172 7,172 PROD2 DRILL WPRT P Flag pipe for TD flag. (Yellow). 14:18 14:30 0.20 7,172 6,970 PROD2 DRILL WPRT P Continue laying in liner running pill with Alpine beads to TOWS. New mud at bit. 14:30 14:45 0.25 6,970 5,872 PROD2 DRILL TRIP P POOH. 14:45 14:48 0.05 5,872 5,872 PROD2 DRILL TRIP P Paint CT for window flag. (White). Page 11 of 24 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:48 16:06 1.30 5,872 0 PROD2 DRILL TRIP P POOH. Jet SSSV on way up through. 16:06 16:18 0.20 0 PROD2 DRILL TRIP P At surface. Drop back down 350' and POOH. 16:18 16:30 0.20 0 PROD2 DRILL SSSV P Close SSSV and perform 15-min drawdown test. 16:30 16:42 0.20 0 PROD2 DRILL SFTY P PJSM for laying down tools. 16:42 17:24 0.70 0 PROD2 DRILL PULD P Lay down drilling BHA. 17:24 18:00 0.60 0 COMPZ CASING PUTB P Rig up floor for liner operations 18:00 18:30 0.50 0 COMPZ CASING SFTY P Change out, PJSM 18:30 21:00 2.50 0 1,076 COMPZ CASING PUTB P Run 30 joints slotted liner with liner top billet. Inteq tool string 21:00 23:00 2.00 1,076 6,876 COMPZ CASING RUNL P RIH with liner 23:00 23:42 0.70 6,876 8,275 COMPZ CASING RUNL P Correct to EOP flag, 32K PUW, -3.5K WOB, 18 K RIW. Tag bottom at 8274.9'and set anchored billet oriented to 210 deg. 23:42 00:00 0.30 8,275 7,000 COMPZ CASING RUNL P POOH 05/01/2012 Tested BOPE,state witness waived by Bob Noble. Blew down reel with LN2 and swapped reels.Completed BOP test other than inner reel iron. 00:00 00:42 0.70 7,000 4,380 COMPZ CASING RUNL P POOH 00:42 02:18 1.60 4,380 0 COMPZ CASING RUNL P Pin hole on reel,stop pumping down coil and line up on kill line, continue POOH. ***For pin hole depth:pinhole had just made it on to reel with bit depth of 4380'.*** 02:18 02:36 0.30 0 0 COMPZ CASING SFTY P PJSM for laying down BHA 02:36 03:30 0.90 0 0 COMPZ CASING PUTB P Lay down liner running BHA 03:30 05:00 1.50 0 0 PROD3 WHDBO BOPE P Flush stack and displace CT to water 05:00 06:18 1.30 0 0 PROD3 WHDBO BOPE P Prep-for testing BOPE. 06:18 06:30 0.20 0 0 PROD3 WHDBO SFTY P PJSM for BOP test. 06:30 09:30 3.00 0 0 PROD3 WHDBO BOPE P Test BOPE. ***State Witness waived by Bob Noble at 06:30 on 4/30/12*** 09:30 10:00 0.50 0 0 PROD3 RIGMNT CTOP T SLB N2 pumpers on location. Spot/rig up to blow down reel. 10:00 10:18 0.30 0 0 PROD3 RIGMNT CTOP T PSJM for reel blowdown. 10:18 11:30 1.20 0 0 PROD3 RIGMNT CTOP T Blow down reel with N2. 11:30 17:00 5.50 0 0 PROD3 RIGMNT CTOP T Unstab CT and prepare to swap reels. 17:00 22:30 5.50 0 0 PROD3 WHDBO CTOP P Resume testing BOPE from Step 11. Continue pumping MPD. Lower reel onto bed truck. BOPE test completed other than inner reel iron. Page 12 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 PROD3 RIGMNT CTOP T PJSM-Install new Reel 05/02/2012 Complete reel&skate change.Cut 1200ft of coil off new reel. Pump slack and found cable in 5ft. 00:00 06:00 6.00 0 0 PROD3 RIGMNTCTOP T Continue pumping MPD. Install Saddle carriers on reel, install Pressure bulk head&Inner reel iron. Start pulling skates ouot of injector. 06:00 10:30 4.50 0 0 PROD3 RIGMNT CTOP T Swap out injector skates. Make up inner reel iron and pressure bulkhead. Install stripper. 10:30 12:00 1.50 0 0 PROD3 RIGMNT CTOP T Reem coil and install grapple connector and prep for stabbing coil. 12:00 15:00 3.00 0 0 PROD3 RIGMNT CTOP T Stab CT in injector. 15:00 16:12 1.20 0 0 PROD3 RIGMNT CTOP T Rig up counters and prep to cut CT. 16:12 18:12 2.00 0 0 PROD3 RIGMNT CTOP T Cut pipe-1080'ft.Stop.Crew change. 18:12 20:42 2.50 0 0 PROD3 RIGMNTCTOP T Install external grapple,pump slack back through coil. Pump 1.5 reel volume and ramp up. 20:42 21:42 1.00 0 0 PROD3 WHDBO BOPE P Test Inner reel iron&stripper. 21:42 23:42 2.00 0 0 PROD3 RIGMNT CTOP T Set up and cut back pipe. Found cable in 5ft.Cut 120 ft in 6 ft sections for samples. Marked DH 1 - 20&lowside of reel with a grind mark on the pipe.Total pipe cut= 1200ft. 23:42 00:00 0.30 0 0 PROD3 RIGMNT CTOP T MIg cable&start re-heading. 05/03/2012 P/U BHA#16 with 1 AKO&3.25"HCC bit. KOTB from 7257'-two stalls at the start of milling. Complete KO with a clean drift-drill ahead from 7290' 00:00 02:00 2.00 0 0 PROD3 RIGMNT CTOP T Re-head CT-Pull test and pressure test. 02:00 03:00 1.00 0 0 PROD3 RIGMNT CTOP T Perform valve checklist& Re-calibrate out MM-problems with density readings.-good to go. 03:00 03:45 0.75 0 0 PROD3 RIGMNT CTOP T Circ out coil to Flo-pro.Out MM reading better.32 bbls for the reel volume. 03:45 04:45 1.00 0 72 PROD4 STK PULD P PJSM-P/U BHA#16 with 1 degree AKO&3.25"HCC bit. 04:45 06:30 1.75 72 6,770 PROD4 STK TRIP P RIH with EDC open pumping 1 bpm. 06:30 06:42 0.20 6,770 6,795 PROD4 STK DLOG P Log GR. [-8'correction]. 06:42 06:48 0.10 6,795 6,795 PROD4 STK TRIP P Pick up and close EDC. 06:48 07:00 0.20 6,795 7,257 PROD4 STK TRIP P RIH. 07:00 07:12 0.20 7,257 7,257 PROD4 STK TRIP P Dry tag billet. 07:12 07:48 0.60 7,257 7,258 PROD4 STK DRLG P Milling billet. 07:48 08:12 0.40 7,258 7,258 PROD4 STK WPRT P Stall motor twice and seem to have some weight issues. Go ahead and backream up a tool length. 08:12 12:12 4.00 7,258 7,260 PROD4 STK DRLG P RIH.Mill billet per time-drilling schedule. Page 13 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:12 12:24 0.20 7,260 7,290 PROD4 DRILL DRLG P Begin drilling ahead. ROP=35'hr, CTP=3700, BHP=3920, Rate=1.46 bpm. 12:24 12:30 0.10 7,290 7,245 PROD4 DRILL DRLG P Drop rate to min and PUH ; PUW=30k. 12:30 12:36 0.10 7,245 7,290 PROD4 DRILL DRLG P Offline w/pump, RBIH through billet; clean. 12:36 13:48 1.20 7,290 7,430 PROD4 DRILL DRLG P Up rate to 1.45 bpm and resume drilling ahead.CTP=3650, BHP=3934,WOB=1.74, ROP=96'. 13:48 14:18 0.50 7,430 7,029 PROD4 DRILL WPRT P Wiper trip with low/high sweeps. (Wiper#1). 14:18 14:42 0.40 7,029 7,430 PROD4 DRILL WPRT P Run back in hole. 14:42 16:54 2.20 7,430 7,570 PROD4 DRILL DRLG P Drill ahead: 1.45-bpm; 3800-psi CTP; 100-psi WHP;3920-psi BHP; 1.6k# WOB. ROP=90-fph. 16:54 18:06 1.20 7,570 7,570 PROD4 DRILL WPRT P Wiper trip. 18:06 21:36 3.50 7,570 7,720 PROD4 DRILL DRLG P Drilling ahead-1.45 bpm, 3530, BHP 3910, ROP 20,WOB 2.5,Ct weight 14K. 21:36 22:36 1.00 7,720 7,720 PROD4 DRILL WPRT P Pump 5/5 sweeps.Wiper trip-P/U weight 34K.Tie in-1ft correction. 22:36 00:00 1.40 7,720 7,750 PROD4 DRILL DRLG P Drilling ahead-1.43 BPM,3600, BHP 3990,WHP 90,WOB 2.6K,CT weight 6K, ROP 90. BHA Wiper 7750'P/U 35K-drilling poor shale. 05/04/2012 Drill&TD AL2-01 Lateral @ 8216'. Pump liner pill&POOH,close SSSV. P/U 29 joints of 2 3/8"slotted liner with a liner top billet. 00:00 04:30 4.50 7,750 7,870 PROD4 DRILL DRLG P Drilling ahead slowly.Weight checks 34K, poor gamma&resistivity drill ahead to wiper trip to discuss options. 04:30 05:00 0.50 7,870 7,038 PROD4 DRILL WPRT P Wiper trip-P/U weight 34K (Wiper trip#1). 05:00 05:30 0.50 7,038 7,870 PROD4 DRILL WPRT P RBIH. 05:30 08:30 3.00 7,870 8,020 PROD4 DRILL DRLG P Drill ahead: 1.43-BPM; 1.3k#WOB; 3770-psi CTP;4700-psi BHP. 08:30 09:30 1.00 8,020 6,800 PROD4 DRILL WPRT P Wiper trip with hi/lo sweeps-P/U weight 34K (Wiper trip#2). 09:30 09:42 0.20 6,800 7,020 PROD4 DRILL WPRT P RBIH. 09:42 09:48 0.10 7,020 7,040 PROD4 DRILL DLOG P Log GR tie-in, +1.5'correction. 09:48 10:24 0.60 7,040 8,022 PROD4 DRILL WPRT P RIH. 10:24 12:30 2.10 8,022 8,160 PROD4 DRILL DRLG P Drill ahead: 1.43-BPM; 1.9k#WOB; 3755-psi CTP;4700-psi BHP. 12:30 12:51 0.35 8,160 7,450 PROD4 DRILL WPRT P Wiper trip-P/U weight 35K (Wiper trip#1). 12:51 13:18 0.46 7,450 8,160 PROD4 DRILL WPRT P RBIH. 13:18 14:22 1.08 8,160 8,206 PROD4 DRILL DRLG P Drill ahead: 1.47-BPM; 1.15 K WOB; 3842-PSI CTP;4002-psi BHP 14:22 14:28 0.11 8,206 8,216 PROD4 DRILL DRLG P Continue Drilling ahead and start to/hi sweeps; 1.44-BPM; .40k WOB; 3,502-psi CTP;3964-PSI BHP Page 14 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:28 16:34 2.10 8,216 8,216 PROD4 DRILL DRLG P Wiper trip-P/U weight 34k(TD Wiper to TT). Tie-in(-0.5'correction). RIH to lay in beaded liner pill. 16:34 18:34 2.00 8,216 5,500 PROD4 DRILL TRIP P POOH. Lay in beaded liner running pill. (42-bbl).Slow rate down through window and entering 3.5". 18:34 20:04 1.50 5,500 72 PROD4 DRILL TRIP P Reel&injector bouncing once in a while.Stop and inspect,open EDC in case bit is catching collars. POOH pumping 1.5 bpm following MPD. 20:04 21:34 1.50 72 0 PROD4 DRILL PULD P Bump up at surface, Close SSSV- Flow check for 20 minutes. PJSM for laying down BHA. Lay down BHA. 21:34 22:04 0.50 0 0 COMPZ CASING RGRP P Set up floor,Service top drive& injector. 22:04 23:58 1.90 0 1,029 COMPZ CASING PUTB P PJSM P/U 29 joints of 2 3/8"slotted liner&BHA with Knuckle joint. 05/05/2012 RIH and set liner from 8216'-7230'. P/U BHA#18 with 3.25"bit. KOTB from 7229'&continue drilling ahead on AL2-02 Lateral. 00:00 00:30 0.50 1,029 1,029 COMPZ CASING CIRC P Change pack offs on injector.Test Tiger tankl line,tank was swapped out. 00:30 02:30 2.00 1,029 6,930 COMPZ CASING RUNL P Open SSSV-RIH pumping.3 bpm through EDC.Stop at flag-12 ft correction.WOB-4K,CT weight 21K . Stop pumping and P/U weight 34K. 02:30 03:15 0.75 6,930 8,216 COMPZ CASING RUNL P RIH to TD.CT weight 18K,WOB.5K -tag bottom @ 8214',WOB 3K. P/U weight 40K,WOB-2.5K. RIH- set down 3K. Bring pumps up to 1.25 bpm, P/U weight 35K,WOB zero. Release liner. BOL=8216' TOB=7230' 03:15 05:15 2.00 7,230 0 COMPZ CASING TRIP P POOH following MPD. 05:15 06:00 0.75 0 0 COMPZ CASING PULD P Lay down liner running assembly. 06:00 06:18 0.30 0 0 COMPZ CASING SFTY P PJSM for picking up drilling BHA (BHA#18). 06:18 07:00 0.70 0 44 COMPZ CASING PULD P Pick up BHA#18. 07:00 09:00 2.00 44 6,770 COMPZ CASING TRIP P RIH BHA#18. 09:00 09:06 0.10 6,770 6,803 COMPZ CASING DLOG P Log GR tie-in. (-11'correction). 09:06 09:18 0.20 6,803 7,020 PROD5 CASING TRIP P RIH and dry tag top of billet. 09:18 13:06 3.80 7,020 7,029 PROD5 STK DRLG P Drill sidetrack off of billet as per appropriate time drill schedule. 13:06 13:12 0.10 7,060 7,060 PRODS STK DRLG P Drilled 31'formation(including billet) then dry drifted sidetrack. 13:12 13:54 0.70 7,060 7,301 PRODS DRILL DRLG P Drill ahead: 1.44-bpm;3850-psi CTP;4640-psi BHP;85-psi WHP; 1.55k#WOB. 13:54 14:06 0.20 7,301 7,186 PRODS DRILL WPRT P DD Wiper Run 14:06 14:12 0.10 7,186 7,301 PROD5 DRILL WPRT P RIH Page 15 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:12 18:12 4.00 7,301 7,380 PROD5 DRILL DRLG P Drill ahead: 1.46-bpm;3,878-psi CTP;3,942.0 BHP;87psi WHP; 2.67k WOB. 18:12 18:42 0.50 7,380 7,380 PRODS DRILL WPRT P Wiper trip-P/U weight 34K 18:42 22:27 3.75 7,380 7,530 PROD5 DRILL DRLG P Drilling ahead-1.45 bpm,3980, BHP 3950, ROP 33,WOB 1.8K,CT weight 16K 22:27 23:12 0.75 7,530 7,530 PROD5 DRILL WPRT P Pump 5/5 sweep-Wiper trip-33K P/U 23:12 00:00 0.80 7,530 7,551 PROD5 DRILL DRLG P Drilling ahead 1.45 bpm,3850, BHP 3950, ROP 30,WOB 2.7K, CT weight 14.5K. Hit ankerite. 05/06/2012 TD AL2-02 lateral @ 7961',spot liner pill&POOH. Run liner from 7961'-6990'. POOH. 00:00 02:30 2.50 7,551 7,680 PROD5 DRILL DRLG P Drilling ahead-1.45 bpm,3980, BHP 3910, ROP 70,WOB 2.1K, CT weight 17K. 02:30 03:30 1.00 7,680 7,680 PROD5 DRILL WPRT P Wiper trip-34K P/U-tie in zero correction. 03:30 05:30 2.00 7,680 7,830 PRODS DRILL DRLG P Drilling ahead-1.50 bpm,3990, BHP 3926, ROP 70,WOB 1.7K,CT weight 16.7K 05:30 06:30 1.00 7,830 7,830 PROD5 DRILL WPRT P Pump 5/5 sweep,Wiper trip-P/U weight 06:30 09:48 3.30 7,830 7,961 PRODS DRILL DRLG P Drilling ahead-1.50 bpm,3990, BHP 3926, ROP 70,WOB 1.7K, CT weight 16.7K. Pump sweeps around and TD AL2-02 at 7961'. 09:48 10:48 1.00 7,961 6,800 PROD5 DRILL WPRT P Wiper up to tubing. Double jog into the 5.5"to ensure cleaning. RIH for completion fluid. 10:48 10:54 0.10 7,000 7,036 PROD5 DRILL DLOG P Tie in(0'correction). 10:54 11:12 0.30 7,036 7,961 PROD5 DRILL TRIP P RIH to tag. 11:12 14:42 3.50 7,961 0 PRODS DRILL TRIP P POOH laying in beaded liner pill. Paint EOP flags at 6800'and 5900'. 14:42 15:12 0.50 0 0 PRODS DRILL SFTY P PJSM for laying down drilling BHA. 15:12 16:12 1.00 0 0 PRODS DRILL PULD P Lay down BHA#18. Clean up floor and ready equipment for picking up liner. 16:12 17:57 1.75 0 0 COMPZ CASING RGRP P Service top drive, reel&injector. BOT arrived @ 17:30 17:57 18:27 0.50 0 0 COMPZ CASING SFTY P Crew change-PJSM 18:27 20:30 2.05 0 1,015 COMPZ CASING PUTB P P/U 29 joints of liner&coiltrack assembly 20:30 23:15 2.75 1,015 7,961 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm.Tie in at flag-12.5ft, P/U weight 36K,-4.6K WOB. RIH pumps down. 18K CT weight .5K WOB.tag bottom 3.5K WOB 23:15 23:45 0.50 7,961 6,990 COMPZ CASING RUNL P P/U weight 40K&-3K. RIH Set down 4K-Bring pumps up to 1.3 bpm, P/u weight 35K,WOB zero. BOL=7961' TOL=6990' Page 16 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 6,990 6,000 COMPZ CASING TRIP P POOH following MPD. 05/07/2012 Set TOWS 6966'/BOWS 6979'30 deg ROHS. P/U 2.80"milling BHA, RIH and start milling window @ 6971'.Milled window,exit @ 6976'and drilled to 6993'.Clean drift passes through window.Mud swap with 1710'on system. Stalls occured @ 6967'while milling and back reaming window(collar just above the window).Clean drift when pumps are off. 00:00 01:00 1.00 6,000 48 COMPZ CASING TRIP P POOH with liner BHA 01:00 01:45 0.75 48 0 COMPZ CASING PULD P Close SSSV, PJSM flow check. Lay down coiltrak. 01:45 02:30 0.75 0 75 COMPZ WHPST PULD P P/U Whipstock BHA. Open EDC 02:30 04:48 2.30 75 6,979 COMPZ WHPST TRIP P RIH pumping.3bpm through EDC. Tie in as per procedure-14.5 ft correction. P/U weight 32K.Stop pumping,close EDC. RIH to setting depth.CT weight 23K,WOB.45K. 30 ROHS 04:48 05:00 0.20 6,979 6,966 COMPZ WHPST WPST P Pump&set at 3600 psi,WOB 2.8K, Set down weight 4.5K.Good set. TOWS=6966'30 deg ROHS. 05:00 06:00 1.00 6,966 0 COMPZ WHPST TRIP P POOH following MPD 06:00 06:12 0.20 0 0 COMPZ WHPST PULD P Conduct pre-job safety meeting for laying down whipstock running BHA. 06:12 09:30 3.30 0 0 COMPZ WHPST WPST P Pick up window milling BHA. Replace seat in rig choke, inspect packoffs. 09:30 11:48 2.30 0 6,770 COMPZ WHPST WPST P Begin RIH with window milling BHA pumping min. rate.32 bpm, 1700 psi CTP. 11:48 12:06 0.30 6,770 6,940 COMPZ WHPST WPST P Begin tie-in run;-12 correction.Cont. RIH. 12:06 12:18 0.20 6,940 6,971 COMPZ WHPST WPST P At 6940;Offline w/pump. PUW 33K, RIW 18K.Tag @ 6971'. Bring up rate to 1.45 bpm.Stall at 6967.66. PU, and reattempt. 12:18 17:18 5.00 6,971 6,976 COMPZ WHPST MILL P Begin time milling @ 6971'per procedure,0.6'/hr, 3750 CTP, 3800 BHP, 1.48 BPM, 0.3K WOB. Exit window-6976.5 17:18 20:18 3.00 6,976 6,980 COMPZ WHPST MILL P Continue milling formation as per procedure 1 fph for 2ft then increase ROP&WOB. Formation over shakers.Call out Vac trucks for Mud swap. 20:18 22:18 2.00 6,980 6,993 COMPZ WHPST MILL P drill/mill formation-pumping new mud, hold MPD while milling formation. Page 17 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:18 00:00 1.70 6,993 6,993 COMPZ WHPST REAM P Back reaming passes as per procedure from 6965'-6981'.RIH- had stall @ 6967'(Casing collar above the window). P/U weight clean 35K-RIH slow- stall 9667.5'-Stop pumping-Relax BHA-RIH to 6981' Back ream HS-little motor work 9674'-clean RIH with pumps off 30 ROHS Back ream 60 ROHS-little motor work @ 9674'-Clean Dry-drift from 6965'-6985'-Clean 05/08/2012 Drill AL3 Build from 6993'-7485.Avg doglegs 47.4, Seen overpull @ 7215'during wiper trips. POOH from Drilling BHA. 00:00 02:00 2.00 6,993 72 COMPZ WHPST TRIP P POOH with Milling BHA following MPD 02:00 03:30 1.50 72 0 COMPZ WHPST PULD P Close SSSV-PJSM&lay down BHA.Mills=2.80"go,2.79"No-go. Service injector and reel.*Weekly function test of Bop's* 03:30 04:00 0.50 0 62 PROD6 DRILL PULD P P/U Build BHA with 2.3+AKO with Hughes 3" Bi-center. 04:00 06:15 2.25 62 6,993 PROD6 DRILL TRIP P RIH with EDC Open pumping.5 bpm. 06:15 09:00 2.75 6,993 7,130 PROD6 DRILL DRLG P Drilling ahead 50'/hr. 1.3K WOB, 17.6 RIW, 1.45 BPM, 105 psi WHIP,3800 CTP, 3840 psi BHP. 09:00 09:06 0.10 7,130 7,130 PROD6 DRILL WPRT P Wiper trip to 7010'. PUW=32K, 1.47 BPM,76 psi WHTP, 3834 BHP. RBIH. 09:06 11:30 2.41 7,130 7,233 PROD6 DRILL DRLG P Resume drilling build. 11:30 12:15 0.75 7,233 7,233 PROD6 DRILL WPRT P PU tight @ 7215'work 3 times to free up.Wiper up to TT. RBIH. 12:15 15:30 3.25 7,233 7,380 PROD6 DRILL DRLG P Drill ahead,2.4 WOB, 1.46 BPM @ 3738 PSI, BHP 3896 PSI, 15:30 16:15 0.75 7,380 7,380 PROD6 DRILL WPRT P Pull Wiper,still a slight over pull @ 7215'RBIH 16:15 18:15 2.00 7,380 7,485 PROD6 DRILL DRLG P Drill ahead, 1.44 BPM @ 3481 PSI, BHP @ 3899 PSI, 12.07 ECD. Pump 5/5 sweep-TD build section. 18:15 20:45 2.50 7,485 72 PROD6 DRILL TRIP P During Wiper trip seen overpull @ 7285'lower rate to 1 bpm, light weight bobble at 7215'.Clean through window.Open EDC, POOH following MPD. 20:45 22:15 1.50 72 0 PROD6 DRILL PULD P Close SSSV-PJSM&lay down BHA. Service injector 22:15 23:15 1.00 0 72 PROD6 DRILL PULD P P/U BHA#23 with .8 AKO&3" Bi-center 23:15 00:00 0.75 72 5,500 PROD6 DRILL TRIP P RIH pumping .5 bpm. 05/09/2012 Continue drilling ahead on AL3 lateral.Clean wiper trips-orient 20 deg ROHS to slide through window.25 bbls losses/24 hours. **Safety I believe Stand up** Page 18 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 5,500 6,978 PROD6 DRILL TRIP P RIH with drilling BHA tie in-15ft correction to K-1.31K P/U weight- RIH 00:45 01:15 0.50 6,978 7,485 PROD6 DRILL ELOG P Tag bottom of window-6978'-P/U 34K. Roll Pumps to turn bit.@ 6959'. RIH change TF to 20 ROHS- slid right through. Log RA marker. TOWS=6967' RA marker=6974.5' BOW=6977' 01:15 04:00 2.75 7,485 7,635 PROD6 DRILL DRLG P Drilling ahead-1.50 bpm,3810, BHP 3954,WHP 110, ROP 22,WOB 2.2K,CT weight 14K.7495'-Inital losses when crossed a fracture but came back to normal while drilling ahead-P/U 40K, broke over 33K. Drill ahead 04:00 07:30 3.50 7,635 7,635 PROD6 DRILL WPRT P Wiper trip with MADD pass.32K P/U. Did not see any overpulls in troubled section 7212'. Increase in cuttings near the top of the wiper. Wipe into cased hole to reset the choke. RBIH 07:30 09:45 2.25 7,635 7,785 PROD6 DRILL DRLG P Drill ahead 1.49 BPM @ 3842 PSI, 3969 BHP,WHP 115 PSI, ROP 49, WOB 1.16, CT WT 16K drill to 7785' 09:45 10:30 0.75 7,785 7,785 PROD6 DRILL WPRT P Short wiper trip,32K off BTM&clean wipe up to 7225', RBIH 10:30 13:15 2.75 7,785 7,935 PROD6 DRILL DRLG P Drill ahead 1.48 BPM @ 3850 PSI, 3969 BHP,WHP 72, ROP 51 drill to 7935' 13:15 14:45 1.50 7,935 7,935 PROD6 DRILL WPRT P Wiper up to TT,33 k off BTM. No overpulls noted. RBIH,tie into RA for 0'correction. 14:45 16:15 1.50 7,935 7,985 PROD6 DRILL DRLG P Drill ahead 1.49 BPM @ 3900 PSI, 3965 BHP,WHP 50, ROP 58 drill to 7985'. Decided to pull wiper to cased hole so both crews can attend up coming safety meeting. 16:15 17:15 1.00 7,985 6,920 PROD6 DRILL WPRT P Wiper up to cased hole. Clean 5" casing,pump B/U. 17:15 19:45 2.50 6,920 6,920 PROD6 DRILL SFTY P Shut in&trap Bottom hole pressure. **I believe Safety Stand up*' 19:45 20:15 0.50 6,920 7,985 PROD6 DRILL TRIP P RIH to TD-Clean 20:15 23:00 2.75 7,985 8,135 PROD6 DRILL DRLG P Drilling ahead-1.45 bpm,3890, BHP 3960, ROP 21,WOB 2.2K, Ct weight 15K. 23:00 23:45 0.75 8,135 8,135 PROD6 DRILL WPRT P Wiper trip-34K P/U weight-Wipe to Build 7485' 23:45 00:00 0.25 8,135 8,145 PROD6 DRILL DRLG P Drilling ahead 05/10/2012 Drill ahead on AL3 Lateral.Drilling into A-6/B1 shales,lost string weight. Stuck pipe,pulled free @ 45K after LVT pill.Wiper to TT, RIH-clean to TD. Drill ahead, poor drilling&weight transfer. Increase claygaurd to 3% &lubes to 3.5%.Total fluid losses=48bbls/24hours. Page 19 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 8,145 8,275 PROD6 DRILL DRLG P Drilling ahead-1.47 bpm,3890, BHP 4000, ROP 55,WOB 2.1K,Ct weight 14K, ECD 12.4-started losing CT weight transfer 8200', P/U weight clean 34K. Pump 5/5 sweeps. Better wieght transfer, increase in cuttings with sweep.Call out Vac trucks. 03:00 04:30 1.50 8,275 8,275 PROD6 DRILL WPRT P Wiper trip to window-P/U weight 34K. Clean through build section. 04:30 07:45 3.25 8,275 8,425 PROD6 DRILL DRLG P Drilling ahead-1.45 bpm,3980, BHP 3980, ROP 44,WOB 1.8K, Ct weight 14K, ECD 12.3.Start pumping new mud 1350 ft on system. Drill to 8425' 07:45 10:00 2.25 8,425 8,425 PROD6 DRILL WPRT P Wiper to TT 34k off BTM, RBIH tie in for a 0'correction. 10:00 13:00 3.00 8,425 8,568 PROD6 DRILL DRLG P Drilling ahead-1.45 bpm,3780, BHP 3990, ROP 44,WOB 1.97K, Ct weight 13K, ECD 12.3. Drill to 8568', lost string WT rapidly. 13:00 13:45 0.75 8,568 8,515 PROD6 DRILL WPRT P PUH and try to go down again,string wt low,decide to pull wiper,37k off BTM, PUH and hang up @ 8516'. Work up&down. Unable to go down hole.Still getting good returns.Cycle numerous times, no good. 13:45 15:45 2.00 8,515 8,515 PROD6 DRILL WPRT T Pull up to neutral WT. Pump rate @ 1.06 BPM. Stop, allow to relax. Then,work up/down while jacking the pump rates. 15:45 16:30 0.75 8,515 8,515 PROD6 DRILL WPRT T Put coil at neural weight.Trap pressure and let sit not allowing ECD below 11.0. ECD down to 11.0 after 10 minutes,bump it back up to 12.5 &shut in.Cycle pipe @ 11.3 ECD, still no good. ECD @ 11.0, bump it back up and establish circulation at managed pressure. 16:30 17:15 0.75 8,515 8,515 PROD6 DRILL WPRT T Send down a 7 bbls pillof LBT mineral oil to spot around BHA. shut down after 2 bbls of LBT on back side,shut down and let it soak. Pump up Annular to 4000 psi, pull up to 50k,slack off to-5k,pull up came free @ 48k. 17:15 19:45 2.50 8,515 8,515 PROD6 DRILL WPRT P Wiper up to the TT. Clean wiper trip. Weight check @ 8450'-34K. RIH- weight check 8550'to 8500'-P/U weight 34K.Slight drag through 8515' at full rate. RIH to drill. 19:45 20:45 1.00 8,515 8,585 PROD6 DRILL DRLG P Drilling ahead-Sticky drilling- increase claystop to 3%from 2%. 1.45 bpm, 3840, BHP 4010,WHP 80, ECD 12.4, ROP 15,WOB 2.2K, Ct weight 10K. 20:45 21:00 0.25 8,585 8,585 PROD6 DRILL WPRT P Stacking weight-P/U 36K. broke over to 34K,Wipe up to 8500' Page 20 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:45 0.75 8,585 8,605 PROD6 DRILL DRLG P Drilling ahead-1.45 bpm,3820, BHP 4030, ECD 12.4, ROP 12,WOB 2.1K,Ct weight 10K.BHA getting deflected down,cannot steer up. Poor drilling. 21:45 22:00 0.25 8,605 8,605 PROD6 DRILL WPRT P Wiper up 100'overpull-40K,drag weight 37K. Broke over @ 8500' Pump sweep on Bottom. 22:00 00:00 2.00 8,605 8,648 PROD6 DRILL DRLG P Drill ahead,decent weight transfer once sweep hit. Increase lubes to 3.5%in drilling system. BHA wiper @ 8644'. P/U weight 39K, broke over 8570'-Drill ahead, Once lubes hit or formation drill off-gained CT weight back. Drill ahead-1.50 bpm,3800, BHP 4020, ECD 12.4,WOB 1.8K,Ct weight 9K. 05/11/2012 Trip for Agitator,Undeploy. Drill ahead with BHA#24-Agitator, .8 AKO&3"Bi-center bit.Starting to see poor shale section from 8500-8800'during wiper trips. 00:00 02:00 2.00 8,648 8,692 PROD6 DRILL DRLG P Drilling ahead-1.50 bpm,3840, BHP 4040, ROP 19,WOB 1.9K,Ct weight 8K.8670'Ct weight starting to drop quickly, no WOB. BHA wiper,drill ahead. Drilling with 6 attempts of WOB transfer. Pump 5/5 sweep prior to wiper trip for Agitator. 02:00 05:00 3.00 8,692 0 PROD6 DRILL WPRT P P/U weight 36K-POOH for BHA swap.Clean through build/window& continue to pump through bit while POOH. 05:00 07:00 2.00 0 0 PROD6 DRILL PULD P PJSM-pressure undeploy BHA. Modifiy BHA. Remove cks from upper quick. Pick-up agitator. 07:00 09:00 2.00 0 0 PROD6 DRILL PULD P PJSM-Pressure deploy BHA#24 09:00 12:00 3.00 0 8,679 PROD6 DRILL TRIP P RIH to 100'EOP depth.Test agitator, good indication of tool work.Open EDC, RIH while pumping @ min rate maintaining MP.Tie in for-15' RIH, tag up 8679' 12:00 17:30 5.50 8,679 8,830 PROD6 DRILL DRLG P Drilling ahead 1.29 BPM 4179,4032 BHP, ROP 24,WOB 2.4, CT weight 11.3.Slow drilling after a couple feet, 7 ROP,7k coil weight,2.3 WOB, drill to 8685'Do a pick-up,pulling heavy. 1300 DP on bore/Ann. Lower DP by lowering pump-pull free, PUH to 8600'. RBIH start drilling again, started drilling off.getting ROP to 43, 1.42 WOB 10.1 Ct weight, 17:30 20:00 2.50 8,830 8,830 PROD6 DRILL WPRT P Wiper trip to window,saw slight over pull @ 8700'-While RIH noticed weight loss @ 8500'&8680'.-Sat down @ 8780'P/U 34K, lower pump rate to.8 bpm. Drift through, reach TD.Wipe up through troubled spot. RIH Page 21 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 23:00 3.00 8,830 8,995 PROD6 DRILL DRLG P Drilling ahead-1.38 bpm,4050, BHP 4030, ROP 55,WOB 1.1K,Ct weight 10K.WHP 110, ECD 12.5. Better ROP and formation @ 8850' 23:00 00:00 1.00 8,995 8,995 PROD6 DRILL WPRT P Pump 5/5 sweep-Wiper trip to window P/u weight 34K 05/12/2012 Continue drilling ahead to 9380'. Decision made to trip for BHA swap due to drilled footage on BHA.Total 32 hours on Agitator. Mud swap. 00:00 01:30 1.50 8,995 8,995 PROD6 DRILL WPRT P Wiper trip. Light weight loss through shale section 8650'-8820'but no set downs @.8 bpm.Clean to TD. 01:30 04:30 3.00 8,995 9,140 PROD6 DRILL DRLG P Drilling ahead-1.35 bpm,4100, BHP 4040, ROP 75,WOB 1.7K,Ct weight 10K. 04:30 08:00 3.50 9,140 9,140 PROD6 DRILL WPRT P Pump 5/5 sweep-Wiper trip 38K P/U. RBIH 08:00 12:00 4.00 9,140 9,290 PROD6 DRILL DRLG P 9140', back on BTM. Drilling ahead- 1.35 bpm,4014, BHP 4070, ROP 40, WOB 1.3K, Ct weight 12K 12:00 14:45 2.75 9,290 9,290 PROD6 DRILL WPRT P 9290',Wiper up 35k off BTM, pull 43k @ 9145'Wiper up to window. RBIH 14:45 16:30 1.75 9,290 9,380 PROD6 DRILL DRLG P 9290' Drilling ahead-1.35 bpm, 4247, BHP 4082, ROP 40,WOB 1.5K,Ct weight 9k. Decision was made to TOOH to inspect BHA. Line up to swap mud. Drill to 9380'Mud turning the corner 16:30 20:30 4.00 9,380 78 PROD6 DRILL TRIP P POOH while still pumping new mud. Get inside 3.5"Open EDC&POOH • following MPD. Load new BHA in PDL. 20:30 22:00 1.50 78 0 PROD6 DRILL PULD P PJSM for undeploying BHA- Undeploy BHA#24.Service injector/reel. Bit had clean ports but balled up with clay around bit. 22:00 23:30 1.50 0 78 PROD6 DRILL PULD P PJSM-Deploy BHA#25-New coiltrack assembly,motor,agitator& 3"Bi-center. 23:30 00:00 0.50 78 800 PROD6 DRILL TRIP P Close EDC-test Agitator 100ft. Open EDC RIH pumping.5 bpm. 05/13/2012 Drill to TD 9680',pump sweeps&wiper to swab valves. RIH for liner run KWF. 00:00 03:00 3.00 800 9,140 PROD6 DRILL TRIP P RIH with EDC open-tie in.-15ft correction. Close EDC,weight check 33k. RIH clean through window& build.Good weight transfer RIH pumping 1.2 bpm.Yesterday 10- 11 K,today 14-15K.Tagged early at 9140' P/U weight 37K. Page 22 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:00 05:00 2.00 9,140 9,380 PROD6 DRILL TRIP T Continue to work down-tag, 9140', 9149',9161'. P/U weight 41K,break over 34K.Wipe up to 9000' RIH slow pump rate to.5 bpm @ 9100'Drift through to 9250' Wipe up to 9000'overpull @ 9140' RIH.Stacked @ 9296'Overpull 46K, Wiper up to 9000'clean RIH tag again @ 9299'-P/U 38K, RIH drift trhough. 05:00 08:15 3.25 9,380 9,530 PROD6 DRILL DRLG P Drilling ahead-1.35 bpm,4100, BHP 4030,WOB 1.8K,Ct weight 14K, ROP 48,WHP 120, ECD 12.6. Pump 5/5 sweep on bottom. Drill to 9530' 08:15 12:00 3.75 9,530 9,530 PROD6 DRILL WPRT P 9530',Wper up,38k off BTM. Pull up to the window. RBIH. Had to spend sometime working it back down from 9460'to TD. Erratic pick-up/RIH wt's. 12:00 12:45 0.75 9,530 9,550 PROD6 DRILL DRLG P 9530' Drill ahead 1.35 bpm,3979, BHP 4130,WOB 1.06K,Ct weight 7K, ROP 52.6,WHP 172, ECD 12.75.drill to 9550',stacking wt and no wt on bit, PUH 12:45 13:15 0.50 9,550 9,550 PROD6 DRILL WPRT P Wiper up to 9500',Work it back down to TD. 13:15 16:15 3.00 9,550 9,680 PROD6 DRILL DRLG P Drill ahead 1.32 bpm,4105,BHP 4130,WOB 1.33K,Ct weight 4K, ROP 40,WHP 198, ECD 12.75.TD well. 16:15 18:15 2.00 9,680 7,000 PROD6 DRILL WPRT P Pump 5/5 sweeps-P/U weight 39K wiper to window. 18:15 20:45 2.50 7,000 75 PROD6 DRILL WPRT P Pump 10/10 sweep in cased hole, cycle in 5.5"-Wiper to swab valves. Increase in cuttings with sweep, small shale particles over shaker. 20:45 00:00 3.25 75 8,800 PROD6 DRILL TRIP P RIH tie in-16ft. RIH, clean trhough window 20 ROHS. RIH 05/14/2012 Lay in KWF. No-flo at surface. Run Liner run#1, Run liner run#2 with Baker Seal Assembly. BOL-9677'/ TOL 6781' Recover KWF,roll well to SW and freeze protect from 2500'to surface. 00:00 01:00 1.00 8,800 9,681 PROD6 DRILL TRIP P Rlh after wiper to swab valve-tag up @ 9195'@ 1bpm, P/U clean 34K. Lower pump rate to.7 bpm,drift to TD no problems. Pump Liner pill followed by KWF. 01:00 04:30 3.50 9,681 74 PROD6 DRILL TRIP P POOH laying in liner pill Flag pipe @ 8200'&5500'. KWF returns at 1100ft. No recordable losses or gains. 04:30 05:00 0.50 74 74 PROD6 DRILL SFTY P Flow check at surface. PJSM for laying down BHA&settin gup rig floor for liner run. Page 23 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 09:00 4.00 74 74 PROD6 DRILL PULD P Lay down BHA&set up for liner run. Close swab valves. Crew change. Conduct PJSM,pick-up 39 jts of liner. Make up BHA. re-install upper checks. 09:00 11:30 2.50 1,351 9,550 COMPZ CASING TRIP P RIH W/lower liner section.See flag @ 9550.47.Continue RIH, 16k CT weight, 11:30 11:45 0.25 9,550 9,677 COMPZ CASING TRIP P tag BTM @ 9677'. PUH get pick-up wt.of 40k. RBIH tag at the same depth. Pump off liner,33k pick-up looks good. Shut down pump down coil. 11:45 12:15 0.50 9,677 6,700 COMPZ CASING TRIP P TOOH, pump down back side to keep beads in place. 12:15 12:30 0.25 6,700 6,776 COMPZ CASING DLOG P Tie into K-1 for a+2.5' 12:30 14:00 1.50 6,776 45 COMPZ CASING TRIP P POOH pumping down coil to keep the hole full,stop @ 6643.84',paint yellow flag on pipe.Continue POOH to surface. 14:00 14:45 0.75 45 45 COMPZ CASING SFTY P No flow check and conduct PJSM for picking up liner. 14:45 17:00 2.25 0 1,633 COMPZ CASING PULD P Lay down BHA, pick-up 47 Jts of liner&BHA 17:00 19:30 2.50 1,633 8,368 COMPZ CASING TRIP P RIH W/AL3 liner run#2. Flag-17 ft correction. RIH tag TOL @ 8368'. Weight check-P/U weight 41K, -6.6K WOB. Pump-P/U weight 31K, WOB zero. 19:30 20:30 1.00 6,781 6,781 COMPZ CASING CIRC P BOL=9677' TOL=6781' Circulate SW down coil&recover KWF.Tie in zero correction. 20:30 23:00 2.50 6,781 42 COMPZ CASING TRIP P POOH-PJSM-pump diesel down CT string. Freeze protect from 2500' to surface.Open EDC-1200 psi WH P. 23:00 00:00 1.00 42 0 COMPZ CASING PULD P PJSM-undeploy BHA#25. 05/15/2012 Lay down BHA. Rig down all equip and install BPV. Release rig at 12:00. 00:00 01:00 1.00 0 0 COMPZ CASING PULD P Lay down BHA 01:00 04:00 3.00 0 0 DEMOB WELLPF CIRC P Circ&pump inhibitor through CT& Stack. Purge stack. 04:00 07:00 3.00 0 0 DEMOB WHDBO MPSP P FMC rep here. missing some equip, hot shot for tools.Continue rigging down other equip. 07:00 09:00 2.00 0 0 DEMOB WHDBO MPSP P Set BPV-1000 psi below. 09:00 12:00 3.00 0 0 DEMOB WHDBO NUND P continue with rig down of all equip. Nipple down BOP. Rig release 12:00 PM Page 24 of 24 tip'°�� C�,40) G Letter of Transmittal FARM BAKER Date: May 23, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1 E-05AL 1 °3 1E-05AL1PB1 1E-05AL2 A _ • 2s 7 1 -05AL2-01 a 1 . Q► 1 E-05AL2-I ol_4 A , ` 34i 1E-05AL3 . 04a O4a (6) Total prints 41C/Y\ f4- 3 z-f Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return . Sachin Gandra, Baker Hughes, Project EngineerM1)4.131 Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com SEAN PARNELL, GOVERNOR �Y �i��i{{Lpplea]pp]�s�LEE y� ®rya,'LIUIDID \l;T{LA�Jy 333 W.7th AVENUE,SUITE 100 ®d�3�13 EFETAI 1i®A�3 U�ORMEB 11 CED ANCHORAGE ALASKA 99501-3539 PHONE (907)279-1433 L. Gantt FAX (907)276-7542 CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-05AL2-01 ConocoPhillips Alaska, Inc. Permit No: 212-038 Surface Location: 653' FSL, 633' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 2149' FSL, 2366' FEL, SEC. 15, T11N, R10E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-05A, Permit No 211- 156, API 50-029-20479-01. 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 revocation or suspension of the permit. Sincerely, t17 ✓=• Cathy. Foerster Chair DATED this i7 day of March, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) I RECEIVED 1 • STATE OF ALASKA ii ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 0 2012 PERMIT TO DRILL 20 AAC 25.005 ''12s1e'? Oil & Gas Cons. Commission rr'1f;cr 3f:3"c la.Type of Work: 1 b.Proposed Well Class: Development-Oil a• Service-Winj ❑ Single Zone a' 1c.Specify if well is proposed for: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates III Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 _ 1 E-05AL2-01 . 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:8275' • TVDSS: 6222' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:653'FSL,633'FEL,Sec. 16,T11N,R10E, UM • ADL 25651 1 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2204'FSL, 1892'FWL,Sec. 15,T11N,R10E, UM 469 4/10/2012 Total Depth: 9.Acres in Property: 14.Distance to 2149'FSL,2366'FEL,Sec. 15,T11N,R10E, UM 2560 Nearest Property: 19400 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 101 feet 15.Distance to Nearest Well Open Surface:x- 549890 • y- 5960237 ' Zone- 4 GL Elevation above MSL: • 69.5 feet to Same Pool: 1E-19,850 16.Deviated wells: Kickoff depth: 7435 ' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98° deg Downhole:3516 psig Surface:2900 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing - Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 ST-L 1050' 7225'' 6230' 8275' V 6222' 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) 7273 6452 7267 6446' Casing Length Size Cement Volume MD TVD Conductor/Structural 63' 20" 300 sx Permafrost 95' 95' Surface 2385' 13.375" 2300 sx Fondu,275 sx 2417' 2213' Intermediate Permafrost Production 4980' 9.625" 73 bbls Class G 5012' 4359' Liner 2465' 5.5" 720 sx Class G 7267' 6446' Perforation Depth MD(ft): Perforation Depth TVD(ft): none none 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program a Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: 22. I herebycertifythat the foregoing is true and correct. 3 O II/1 2 9 9 Contact Jill Long @ 263-4093 Printed Name L. Gantt Title CTD Engineering Supervisor A,, Signature i fcAji____ Phon 263-4021 Date op9 / Commission Use Only Permit to Drill API Number: I Permit Approval See cover letter Number: 50- c� ,!` 3 1 k i2 for other requirements 2-�,�• ��j �Z-1. ��17 ����7 Date: J ` q Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: Ri f 3540 rs�. &P k a f--Samples req'd: Yes El No Mud log req'd: Yes ❑ No 0'' / s Other: H2S measures: Yes i_ No ❑ Directional svy req'd: Yes g No ❑ 22 Gj t?e,....A4.17 VED BY THE COMMISSIONDATE: 7 .- / �1Z COMMISSION4.-v ER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AA 25.005(g)) Mbinit in Duplicate '(-�� . 3•zS./z . ;'Xyl= RECEIVED I`( ConocoPhillips Alaska �l'`� P.O. BOX 100360 r ANCHORAGE,ALASKA 99510-0360 Alaska Oil � Gas Gans. orr� irsir Anchorage March 19, 2012 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete six laterals from Kuparuk well 1E-05A (PTD# 211-156). Coiled tubing drilling (CTD) operations are scheduled to begin as early as April 10, 2012, using the rig, Nabors CDR2-AC. The objective of the CTD project is to improve A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. Three laterals each are planned to be drilled from two window exits from the 5.5" liner in parent wellbore, 1E-05A. The parent wellbore will have no producing sections; it will be considered "Suspended" until the CTD laterals are drilled and completed. At that point a 10-404 form will be submitted changing the 1E-05A status from "Suspended" to "Oil-Development". For that reason, the laterals will be named: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, and 1 E-05AL2-02. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms: 1E-05AL1, 1E-05AL1-01, 1E-05AL1-02, 1E-05AL2, 1E-05AL2-01, and 1 E-05AL2-02 — Directional Plans: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, and 1 E-05AL2-02. — Current Wellbore Schematic — Proposed Post-CTD Wellbore Schematic If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Jill . Long ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA 'max 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 ' lrt Application for Permit to Drill Document nc 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 4 (Requirements of 20 AAC 25.005(c)(5)) 4 6. Casing and Cementing Program 4 (Requirements of 20 AAC 25.005(c)(6)) 4 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 5 (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 MC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 6 (Requirements of 20 AAC 25.005(c)(13)) 6 Summary of Operations 6 Pressure Deployment of BHA 7 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 8 (Requirements of 20 AAC 25.005(c)(14)) 8 15. Directional Plans for Intentionally Deviated Wells 8 (Requirements of 20 AAC 25.050(b)) 8 16. Quarter Mile Injection Review (for injection wells only) 8 (Requirements of 20 AAC 25.402) 8 17. Attachments 8 Attachment 1: Directional Plans for 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-028 Attachment 2: Current Well Schematic for 1 E-05A 8 Attachment 3: Proposed Well Schematic for 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E- 05AL2-02 8 L I \ IUli iIL Page 1 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1E-05AL2, 1E- 05AL2-01, 1 E-05AL2-02. All six of these laterals will be classified as"Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 653' FSL, 633' FEL, Sec 16, T11N, R10E, UM NAD 1927 RKB Elevation 101 AMSL Northings: 5960237 Eastings: 549890 Pad Elevation 69.5 AMSL 1 E-05AL1 Location at Top of Productive Horizon 2333' FSL, 1436' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7575' Northings: 551943.5 Eastings: 5961933.8 Total Vertical Depth, SS: 6259' Location at Total Depth 2340' FSL, 406' FWL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8650' Northings: 5961933.8 Eastings: 550913.5 Total Vertical Depth, SS: 6160' 1 E-05AL1-01 Location at Top of Productive Horizon 2269' FSL, 337' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 8700' Northings: 5961862 Eastings: 550845 Total Vertical Depth, SS: 6197' Location at Total Depth 2376' FSL, 475' FEL, Sec 16, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 9535' Northings: 5961964 Eastings: 550032 Total Vertical Depth, SS: 6219' 1 E-05AL1-02 Location at Top of Productive Horizon 2124' FSL, 1743' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7030' Northings: 5961727 Eastings: 552252 Total Vertical Depth, SS: 6148' Location at Total Depth 2331' FSL, 539' FEL, Sec 16, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 9590' Northings: 5961964 Eastings: 550032 Total Vertical Depth, SS: 6192' 1 E-05AL2 Location at Top of Productive Horizon 2162' FSL, 2095' FWL, Sec 15, T11N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7435' Northings: 5961768 Eastings: 552604 Total Vertical Depth, SS: 6217' Location at Total Depth 2155' FSL, 2365' FEL, Sec 15, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8265' Northings: 5961766 Eastings: 553423 Total Vertical Depth, SS: 6283' Page 2 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 1 E-05AL2-01 Location at Top of Productive Horizon 2204' FSL, 1892' FWL, Sec 15, T11 N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7225' Northings: 5961808 Eastings: 552401 Total Vertical Depth, SS: 6230' Location at Total Depth 2149' FSL, 2366' FEL, Sec 15, T11N, R10E, UM • NAD 1927 Measured Depth, RKB: 8275' Northings: 5961760 Eastings: 553423 Total Vertical Depth, SS: 6222' 1 E-05AL2-02 Location at Top of Productive Horizon 3181' FNL, 1730' FWL, Sec 15, T11 N, R10E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 6980' Northings: 5961701 Eastings: 552240 Total Vertical Depth, SS: 6106' Location at Total Depth 1949' FSL, 2213' FWL, Sec 15, T11 N, R10E, UM NAD 1927 Measured Depth, RKB: 7700' Northings: 5961555 Eastings: 552723 Total Vertical Depth, SS: 6229' 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. (Using the maximum pressure at which the reservoir was static after drilling the 1 E-05A Rotary Sidetrack of 3516 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2900 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) An updated static bottomhole pressure (BHP) reading was obtained in the parent wellbore, 1 E-05, in December 2011, prior to the rotary sidetrack. The pressure at that time was 2610 psi at 6800' MD/6014' TVDSS. This would be the equivalent of 8.3 ppg fluid. Nordic 3 rig sidetracked 1E-05A out of 1 E-05 in February 2012. The parent wellbore was isolated and the new bottomhole location was positioned in a new fault block. The final fluid weight at the time of TD (7273'MD/6350'TVDSS), with both the A and C sands open, was 11.0 ppg. Based upon this final fluid weight, the maximum anticipated bottomhole pressure at the kickoff points (KOPs) for the CTD laterals is 3516 psi, an 11.0 ppg equivalent mud weight(EMW). Considering all surrounding.wellbores, the most recent pressure surveys indicate pressures no greater than 8.3 ppg to be expected. Because of this surrounding well data, the maximum downhole pressure in the area is expected to be the 11.0 ppg equivalent, mentioned above. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 1E pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Page 3 of 8 3/19/2012 • PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1 E-05A laterals will be at fault crossings and shale interfaces. There are several large fault crossings (with throws of 30' or more) in both the Western and Eastern laterals. This risk has been taken into account by developing plans that call for drilling shorter laterals which will place less drilled footage at risk in the event of a hole collapse. Also, based on lessons learned while drilling 1E-24, if a large fault is crossed in an unfavorable location, consideration will be given to plugback and redrill sooner. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Liner Btm Liner Top Liner Btm Liner Details Top MD MD TVDSS TVDSS 1 E-05AL1 7575' 8650' 6259' 6160' 2%', 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1E-05AL1-01 8700' 9535' 6197' 6219' 2%", 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1E-05AL1-02 7025' 9590' 6144' 6192' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 1 E-05AL2 7435' 8265' 6217' 6283' 2%", 4.7#, L-80, ST-L slotted liner; anchored aluminum billet on top. 1E-05AL2-01 7225' 8275' 6230' 6222' 2%", 4.7#, L-80, ST-L slotted liner; liner top billet on top. 1 E-05AL2-02 6780' 7700' 5940' 6185' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PO) MD MD TVD TVD psi psi Conductor 20" 94 H-40 Welded 0' 95' 0' 95' 1530 520 Surface 13-3/8" 72 N-80 BTC 0' 2416' 0' 2210' 5380 2670 Casing 9-5/8" 47 L-80 BTC 0' 5012' 0' 4356' 6870 4750 Liner 5-1/2 " 15.5 L-80 BTCM 4802' 7267' 4159' 6446' 4990 7000 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0' 4725' 0' 4088' 10540 10160 Tubing 3-1/2 " 9.3 L-80 Hydril 563 4725' 6649' 4088' 5929' 10540 10160 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 6649' 6788' 5929' 6048' 10540 10160 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. Page 4 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine(8.6 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.7 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 E-05A contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) of 12.0 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest IateraT Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. For the CTD work at 1E-05A, a constant BHP target of 11.8 ppg will be targeted at the window. Since this well is proposed as an infield development candidate in an ,actively water flooded field, expected reservoir pressures can be difficult to estimate. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. 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. Page 5 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Kuparuk well 1 E-05A was rotary sidetracked from parent wellbore 1 E-05A and completed in February 2012 as a set-up for the six CTD laterals that this application covers. The liner across the reservoir was cemented in place and has not been perforated. The plan for the parent wellbore is to leave it as "suspended"; i.e. not open the parent up to production. After the CTD laterals are drilled, a 10-404 form will be submitted changing the 1E-05A status from "Suspended" to "Oil-Development". The only production however will come from the CTD laterals from 1E-05A. The CTD sidetracks at 1 E-05A are intended to improve areal sweep efficiency and oil recovery from the 1 E- 05 pattern. The 1 E-05A CTD project is the seventh well in the Re-development program at 1 E pad. Pre-Rig Work 1. Perform drift and tag. If necessary, perform a FCO to remove any fill (i.e. drilling mud) in the wellbore. 2. Perform a dummy whipstock drift as well. 3. Perform GR/CCL log for tie-in purposes to confirm KOP is spaced between collars. 4. Set BPV and prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set 3.5" x 5.5" thru-tubing whipstock at 7030' MD in 1E-05A (+/- 10' to adjust for actual collar locations). 3. Mill a 2.80", single string window exit with high-side orientation. 4. Drill 1 E-05AL1 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8650' MD b. Run 2%" slotted liner from TD to —7575', utilizing the SSSV for deploying the liner 5. Drill 1E-05AL1-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 9535' MD b. Run 2%" slotted liner from TD to —8700', utilizing the SSSV for deploying the liner 6. Drill 1E-05AL1-02 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 9590' MD b. Run 2%" slotted liner from TD up into the 3.5" tubing (to—7025' MD). Leave the top of liner just above the top of the whipstock at—7030' MD. 7. Set 3.5" x 5.5" thru-tubing whipstock at 6980' MD in 1E-05A (+/- 10' to adjust for actual collar locations). 8. Mill a 2.80", single string window exit with high-side orientation. 9. Drill 1E-05AL2 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8265' MD b. Run 2%" slotted liner from TD to—7435', utilizing the SSSV for deploying the liner 10. Drill 1E-05AL2-01 Lateral L oft �j 1.-03a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 8275' MD b. Run 2%" slotted liner from TD to —7225', utilizing the SSSV for deploying the liner 11. Drill 1 E-05AL2-02 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4/A5 sands to a TD of 7700' MD b. Run 2%" slotted liner from TD up into the 3.5" tubing (to—6780' MD). Leave the top of liner below the X nipple at 6776' to allow for use of the X nipple. Page 6 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 12. POOH swapping well over to brine. Freeze protect. 13. Set BPV. ND BOPE. RDMO Nabors CRD2-AC. 14. Handover to Production group. Post-Rig Work 1. Pull BPV and install gas lift design. 2. 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 listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — Since 1E-05A is equipped with a SSSV, the 1E-05A CTD laterals will not need to be displaced to an overbalancing fluid prior to running liner. See the"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. Page 7 of 8 3/19/2012 PTD Application: 1 E-05AL1, 1 E-05AL1-01, 1 E-05AL1-02, 1 E-05AL2, 1 E-05AL2-01, 1 E-05AL2-02 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to Kuparuk PA boundary at closest point) Lateral Name Distance 1 E-05AL1 20700' 1 E-05AL1-01 21200' 1 E-05AL1-02 21750' 1 E-05AL2 19400' 1 E-05AL2-01 19400' 1 E-05AL2-02 20050' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 E-05AL1 930' 1E-19 1 E-05AL1-01 860' 1E-09 1 E-05AL1-02 820' 1E-09 1 E-05AL2 775' 1E-19 1 E-05AL2-01 850' 1E-19 1 E-05AL2-02 850' 1 E-19 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 1E-05AL1, 1E-05AL1-01, 1E-05AL1-02, 1E-05AL2, 1E- 05AL2-01, 1E-05AL2-02 Attachment 2: Current Well Schematic for 1E-05A Attachment 3: Proposed Well Schematic for 1E-05AL1, 1E-05AL1-01, 1E-05AL1-02, 1E-05AL2, 1E-05AL2-01, 1E-05AL2-02 Page 8 of 8 3/19/2012 1E-05A SIDETRACK Updated on 02/21/2012 9-5/8"casing tie-back @ 182' _ - w/Hydril563 02/05/12 - _ 20"Condutor Arctic Pack Job done in @ 95' 8/13/1980 3 %' 49 bbls cement = 116 bbls diesel _ TRMAXX- :;: No record of press.test CMT SCSS 2.813"ID 1,785'MD/: :::: 1,694'TVD:;:; 13-3/8"72#N80 casing @ 2,416'MD!2,210'TVD 3-%z"9.3#,L-80,EUE Tubing @4,714' NMI MD and above 7,7 X/O EUE B X Hydril563 P Baker ZXP lir'. packer @ I KOP in 9-5/8"@ 4,802'MD/4,l.�'1'::::::::: 5 012'MD/4,362'TVD TVD' GLM# TVD ft MD ft Valve Type Mandrel Type -•- :_ 1 2,488 2,762 Dummy 3-1/2"x 1-1/2"MMG ••:.<<,;: 0 2 o o M n m ca N fatlNy . CI 1 C ,6 ma m ao N O N a 1�1�1 M of Ol h a o win Nw0 : 0 0 NNN `*oo JEN '. cG � � E m H22tho th -J oNom mmm N�oo oaII 'Lis'0- Jn100 in _ = Q a . v _ ce cxxxxx w woo 0 crinin J..- i 1I- MMririM a co Zo = � mM � � • a �I II U3 F N M' 7 111 m N in W U m m i = I � II N m O Zo C CO CO O rn CO C 0 N F 2 N CO V N co co J m .j S u \ N O \ :° a O , A C N x 0 07 n a �- N CO V LO 3 (n n 7 v O x o 1 I 0 -c. x = N N N C1 cl C1 W r%1 I p m %-. J LI- C) N 7 // c r , 441r:—Aii II r7- \ dU2 N 1- 03 0- N r N I \ G N .. N 10 i N O a 0 L L O ZI 0 E E / o 2 o 01 V W 0 p - a / 2 a, r N J V °m SI O N M Y O 0 W-O CJ C 1pp�11 O to N ✓1 I() 0 v O_ .0 C O7 �i c a / I bg o J 0 " Y U II U = II 11 « LLI a II II II �Wo I— II II II Wag CO LO a II II Wn. I_I I I 7 a, 0-p moo 0 O 1O i a 1- a o,-o ""o 0 a. E N o w En En a o 0 _:7-ti o a @. o m ^Oo ORI.GNAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-05 1 E-05AL2-01 Plan: 1 E-05AL2-01_wp02 Standard Planning Report 09 March, 2012 ` ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL2-01 Design: 1 E-05AL2-01_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35 45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1 E-05 Well Position +N/-S 0.00 ft Northing: 5,960,237.32 ft Latitude: 70°18'7.714 N +E/-W 0.00 ft Easting: 549,890.40 ft Longitude: 149°35'45.239 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 69.50 ft Wellbore 1 E-05AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 4/15/2012 16.37 79.91 57,376 Design 1 E-05AL2-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,435.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) -69.50 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,435.00 93.52 104.56 6,217.01 1,510.40 2,723.54 0.00 0.00 0.00 0.00 7,515.00 98.27 112.95 6,208.78 1,484.87 2,798.81 12.00 5.93 10.49 60.00 7,615.00 89.03 105.27 6,202.42 1,452.29 2,892.95 12.00 -9.24 -7.68 220.00 7,765.00 90.62 87.34 6,202.89 1,435.88 3,041.43 12.00 1.06 -11.95 275.00 7,865.00 90.60 75.34 6,201.82 1,450.91 3,140.10 12.00 -0.01 -12.00 270.00 8,040.00 84.21 95.37 6,209.81 1,465.06 3,313.36 12.00 -3.65 11.45 108.00 8,275.00 90.05 67.74 6,221.82 1,499.33 3,543.15 12.00 2.48 -11.76 281.00 3/9/2012 3:13:01PM Page 2 COMPASS 2003.16 Build 69 ` ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL2-01 Design: 1 E-05AL2-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +14/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°► (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,435.00 93.52 104.56 6,217.01 1,510.40 2,723.54 2,723.54 0.00 0.00 5,961,765.63 552,603.59 TIP/KOP 7,500.00 97.39 111.37 6,210.82 1,490.47 2,785.05 2,785.05 12.00 60.00 5,961,746.11 552,665.22 7,515.00 98.27 112.95 6,208.78 1,484.87 2,798.81 2,798.81 12.00 60.65 5,961,740.60 552,679.02 2 7,600.00 90.42 106.42 6,202.34 1,456.38 2,878.52 2,878.52 12.00 -140.00 5,961,712.64 552,758.90 7,615.00 89.03 105.27 6,202.42 1,452.29 2,892.95 2,892.95 12.00 -140.50 5,961,708.64 552,773.36 3 7,700.00 89.93 95.11 6,203.20 1,437.27 2,976.49 2,976.49 12.00 -85.00 5,961,694.18 552,856.99 7,765.00 90.62 87.34 6,202.89 1,435.88 3,041.43 3,041.43 12.00 -84.91 5,961,693.23 552,921.93 4 7,800.00 90.62 83.14 6,202.51 1,438.79 3,076.30 3,076.30 12.00 -90.00 5,961,696.36 552,956.78 7,865.00 90.60 75.34 6,201.82 1,450.91 3,140.10 3,140.10 12.00 -90.05 5,961,708.91 553,020.49 5 7,900.00 89.31 79.33 6,201.84 1,458.58 3,174.24 3,174.24 12.00 108.00 5,961,716.80 553,054.58 8,000.00 85.64 90.77 6,206.27 1,467.20 3,273.59 3,273.59 12.00 108.00 5,961,726.08 553,153.86 8,040.00 84.21 95.37 6,209.81 1,465.06 3,313.36 3,313.36 12.00 107.49 5,961,724.21 553,193.64 6 8,100.00 85.62 88.29 6,215.13 1,463.16 3,373.05 3,373.05 12.00 -79.00 5,961,722.70 553,253.34 8,200.00 88.12 76.53 6,220.61 1,476.34 3,471.85 3,471.85 12.00 -78.37 5,961,736.54 553,352.03 8,275.00 . 90.05 67.74 6,221.82 • 1,499.33 3,543.15 3,543.15 12.00 -77.73 5,961,759.99 553,423.17 TD L 3/9/2012 3:13:01PM Page 3 COMPASS 2003.16 Build 69 Are' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL2-01 Design: 1 E-05AL2-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-05AL2-01_T3 0.00 0.00 6,209.00 1,472.47 3,306.96 5,961,731.57 553,187.19 70°18'22.188 N 149°34'8.803 W -plan misses target center by 6.83ft at 8033.16ft MD(6209.14 TVD,1465.65 N,3306.58 E) -Point 1E-05AL2_Faultl 0.00 0.00 6,180.00 1,523.71 2,971.26 5,961,780.58 552,851.19 70°18'22.694 N 149°34'18.591 W -plan misses target center by 88.61ft at 7679.32ft MD(6203.13 TVD,1439.56 N,2955.94 E) -Polygon Point 1 6,180.00 1,689.12 2,911.34 5,961,945.57 552,790.18 Point2 6,180.00 1,523.71 2,971.26 5,961,780.58 552,851.19 Point3 6,180.00 1,355.30 3,030.16 5,961,612.58 552,911.20 1E-05AL2-01_T2 0.00 0.00 6,202.00 1,471.77 3,111.93 5,961,729.58 552,992.19 70°18'22.182 N 149°34'14.490 W -plan misses target center by 26.78ft at 7841.20ft MD(6202.07 TVD,1445.47 N,3116.94 E) -Point 1E-05AL2-01_T4 0.00 0.00 6,222.00 1,490.94 3,537.10 5,961,751.57 553,417.18 70°18'22.369 N 149°34'2.091 W -plan misses target center by 5.56ft at 8266.67ft MD(6221.81 TVD,1496.24 N,3535.41 E) -Point 1E-05AL2-01_T1 0.00 0.00 6,203.00 1,475.96 2,933.94 5,961,732.58 552,814.19 70°18'22.224 N 149°34'19.680 W -plan misses target center by 32.39ft at 7651.21ft MD(6202.91 TVD,1444.08 N,2928.20 E) -Point 1E-05AL2,L2-01 Polyl 0.00 0.00 102.00 1,637.12 3,062.03 5,961,894.57 552,941.19 70°18'23.809 N 149°34'15.943 W -plan misses target center by 6103.16ft at 7865.00ft MD(6201.82 TVD,1450.91 N,3140.10 E) -Polygon Point 1 102.00 1,637.12 3,062.03 5,961,894.57 552,941.19 Point 2 102.00 1,623.58 3,294.97 5,961,882.58 553,174.19 Point 3 102.00 1,609.63 3,590.91 5,961,870.60 553,470.19 Point4 102.00 1,359.57 3,596.26 5,961,620.60 553,477.20 Point 5 102.00 1,370.97 3,079.28 5,961,628.57 552,960.21 Point6 102.00 1,419.33 2,722.55 5,961,674.56 552,603.20 Point 7 102.00 1,497.73 2,511.05 5,961,751.54 552,391.20 Point8 102.00 1,409.41 2,407.45 5,961,662.55 552,288.20 Point9 102.00 1,464.35 2,265.80 5,961,716.54 552,146.20 Point 10 102.00 1,671.45 2,405.18 5,961,924.54 552,284.19 Point 11 102.00 1,665.41 2,563.16 5,961,919.55 552,442.19 Point 12 102.00 1,619.84 2,800.89 5,961,875.56 552,680.20 Point 13 102.00 1,637.12 3,062.03 5,961,894.57 552,941.19 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 2,411.60 2,104.99 13 3/8" 13-3/8 17-1/2 8,275.00 6,221.82 2-3/8" 3 3 3/9/2012 3:13:01PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-05AL2-01 Design: 1 E-05AL2-01_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,435.00 6,217.01 1,510.40 2,723.54 TIP/KOP 7,515.00 6,208.78 1,484.87 2,798.81 2 7,615.00 6,202.42 1,452.29 2,892.95 3 7,765.00 6,202.89 1,435.88 3,041.43 4 7,865.00 6,201.82 1,450.91 3,140.10 5 8,040.00 6,209.81 1,465.06 3,313.36 6 8,275.00 6,221.82 1,499.33 3,543.15 TD II 3/9/2012 3:13:01PM Page 5 COMPASS 2003.16 Build 69 oo 9 M M N 8 en en W 40 h m M M G R orM $ C _ M stii 9 M tv •er e9 en on __Y___ + �' Mc _ el qmn Op ev MN C O M �W n O --r tti4.1 o i /11 TTg- O FZOU O ` P N Q g e2ow_ y E N 3 w ji(tipl, N 1 `� y @ m N y ¢ 5 9 VA' N Z Z a w m '0 U 4 O p � w N D U g v h N a w e M 0 J �O - - M O O i,y R Il 00 N M O Q w 9g 4NNN t:HP .0 rn>j Jr $� CHom . 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B unowi11v �•— -iA : l:mmsmUanmHm •MLA. •l ^ i y ,H...1 imam to. tH n■N1 - - `—B—A •1= — 1 a • _ x- _ ` LLiiiamla �mama-- , + _ ne - - m -ISMte: i IR . 1 . , •—tt— �.--••U•'VC. .• ..mass in -�I � 4L 1 I f' � �1 a t � �v ia i i i .. : fl • I9 pA 8 8d 8 O O8 CG OONO�O C @ M M M t 1 N N N - - - - O [-- ,S •C M 4. 46 0 (al 0 t)/Lii t''6 t.,7 i I\V I 1:1-111.1 + 4 oNu(-)4inos ( 4 ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Reference Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site Error: 0.00ft North Reference: True Reference Well: 1 E-05 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1 E-05AL2-01 Database: EDM Alaska Prod v16 Reference Design: 1 E-05AL2-01_wp02 Offset TVD Reference: Offset Datum Reference 1E-05AL2-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,435.00 to 8,275.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,024.34ft Error Surface: Elliptical Conic Survey Tool Program Date 3/9/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 45.60 4,995.60 1E-05 GyroData_9.625 casing(1E-05) GYD-CT-CMS Gyrodata cont.casing m/s 5,014.74 6,967.53 1E-05A MWD(8200)(1E-05A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,967.53 7,435.00 1 E-05AL2_wp03(1 E-05AL2) MWD MWD-Standard 7,435.00 8,275.00 1E-05AL2-01_wp02(1E-05AL2-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,411.60 2,206.09 13 3/8" 13-3/8 17-1/2 8,275.00 6,322.92 2-3/8" 3 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 1E Pad 1E-121-B Lateral-B-Lat Survey Out of range 1E-121 -D Lateral-D-Lat Survey Out of range Kuparuk 1E Pad 1 E-03-1 E-03-1 E-03 Out of range 1 E-05-1 E-05AL2-1 E-05AL2_wp03 7,449.99 7,450.00 0.47 0.98 -0.42 FAIL-Major Risk 1E-05-1E-05AL2-02-1 E-05AL2-02_wp03 7,444.72 7,450.00 9.45 39.72 -29.82 FAIL-Major Risk 1 E-07-1 E-07-1E-07 Out of range 1 E-07-1 E-07A-1 E-07A Out of range 1 E-07-1 E-07AL1 -1 E-07AL1 Out of range 1 E-07-1 E-07AL2-1 E-07AL2 Out of range 1 E-07-1 E-07AL2-01 -1 E-07AL2-01 Out of range 1E-123-1E-123-1E-123 Out of range 1E-123-1 E-123L1 -1E-123L1 Out of range 1 E-123-1 E-123PB1 -1 E-123PB1 Out of range 1E-126-1E-126-1E-126 Out of range 1E-126-1E-126L1 -1E-126L1 Out of range 1E-126-1E-126L2-1E-126L2 Out of range 1E-19-1E-19-1 E-19 7,450.00 7,225.00 736.49 152.38 586.62 Pass-Major Risk 1 E-20-1 E-20-1 E-20 Out of range 1 E-31-1E-31 -1 E-31 Out of range 1 E-34-1 E-34-1 E-34 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/9/2012 11:15:22AM Page 2 of 6 COMPASS 2003.16 Build 69 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 l5 0SA -v PTD# 2 / L 03E) Development Service Exploratory Stratigraphic Test Non-Conventional Well • / FIELD: (1-X' d'— POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /<2Gk i 2)SA (If last two digits in Permit No. --// /S-6.),API No. 50-G�- ZU /7c} - G l 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 cn D m O D 7 cn D a m 0 rr O ID (a 7l -0 3 p c) Oa o ( • p — 3 0 coco N 3.p AW W 7 W ct O t4 N.o CoNo co rso p 0 '0' OD } c0 N w N. di N M 0 O O O CD O CD O CD Ni N.) Ni W W W W W W W W W W N Ni Ni Ni Ni N r,..) Ni Ni N — CO Co V O) c)7 A W Ni -+ 0 +`y`. cO CC V O 01 A Co Ni O O W V 6) 01 A W Ni -� O c0 CO 6) 01 A W Ni O V +A O cn w 0 m g m * O ao W 0 =. D '4. D n n n n cn n -o D * n v m O O = * * * c i -az ° sz N p o m 'm v cD cD a p O a n n o n o c o = o m m b b a0 v w ° o = m m m ° m m ° m m m m m m ° v m "A m m a . 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