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210-089
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. cQ10 - Of Well History File Identifier Organizing (done) Two-sided III 111111111 IIIII ❑ Rescan Needed II 0111111 I 111111 RES AN DIGITAL DATA OVERSIZED (Scannable) or Items: ❑ Di ttes, No. ❑ Maps: Greyscale Items: Other, No/Type: C3 No, r ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: El Logs of various kinds: NOTES: nn ❑ Other:: BY: Date: cat" `1-t /s/ n'iP Project Proofing 1101111110111111 BY: Maria Date: i p�. `Li /s/ il , Scanning Preparation I x 30 = 3 0 + .2D = TOTAL PAGES �0 (Count does not include cover sheet) ii i BY: Date: /ca$' /s/ Production Scanning 11111111111111 II III Stage 1 Page Count from Scanned File: 5 1 (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: �ES NO BY: AP Date: 1 IPS `If /s/ nip Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II I I III ReScanned I I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 01111 I 11111111 12/22/2011 Well History File Cover Paoe.doc o :E- 9 o m 2 to /&. 3 N_ co - cc) } 0 oU co to N = X ea o > >I c 0 0 =,u a) o E 0 co a N d U d a c ° 2 O 2 2 0 U 0 0 aZ co z d u) c ° y Q a) o 0 0 1 0 0 > Z y a) N N N O) Z E aci y 2 S C C C C C C rIS A� ,c C") 0 0 0 0 0 0 E co ii li -J• c w U o o 0 0 0 v OCO of 0 0 0 0 y a _1 U N o 0 0 0 0 0 ao a (3 RN 0 W = a! z G. c Et p .. N- N- °v N-EL NI- °v CO a W z a) > Z U Z _ o ° ' ° ' z i- CC z ZS u) o co - Om _. t J a 0 -al ° o 0 o ..c ^ E CM o ZI J U U U N Q LL G N a, N a, OO> E a RI N U) c) / 1 N 0 E J CO CO V CD U J Q N I . M p r I- o co Z N ZS Tti • N C CO 00 r v/ Q p W Q a • o n z c.,) ai 'z• z w w Q c Z o ce > > > > > > Q d 0 O V) •N N N > > V) u) N N CO -0 0 N W Ce X X Z 7 6 C C C C C C d a) O o 0 0 o O Oo C N a) U 7 7 7 7 E r O co w Z Q p c c c V a Z rn E O "� cr) z0 . ; ya °v o CZ� m O Q Z L C w 0 Z N U) >- N C71 2 p Q �. a7 a+ d y LL p. > to a)•� LL• Z v L N u co J re 0a Q Z Q y cy cn C O v c • E Q w \ \ U Q U a •a) E a CI) 0 W I- O- m °)s 0 o a o 0 0 0 m o m - c CD o 0 a CC 0 i 3 -1o1-�w w 3 Q 0 ¢� U 0 ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage,AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Diskk/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage,Alaska 99501 CGM/TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM/TIFF LIS Anchorage,Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM/TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage,Alaska 99501-3510 LIS Jio -o 9 a604 \ ' _ ?_.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0 WAG ❑ WDSPL ❑ No.of Completions: Service El Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 23,2010 210-089/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 August 11,2010 50-029-21655-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1109'FSL,316'FWL,Sec.35,T13N, R9E, UM August 15,2010 3K-12L1 Top of Productive Horizon: 8. KB(ft above MSL): 69'RKB 15.Field/Pool(s): 1329'FNL,282'FWL,Sec. 1,T12N, R9E, UM GL(ft above MSL): 31'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1004'FSL,512'FWL, Sec.35,T13N, R9E, UM 7527'MD/6743'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-529306 y- 6008104 Zone-4 10504'MD/6709'TVD ADL 25519,25629 TPI: x-529807 y- 6005667 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-529502 y- 6007999 Zone-4 1840'MD/1840'TVD 2555,2562 18.Directional Survey: Yes 0 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) 1700'MD/1700'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 7400'MD/6673'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 20" 1540#Poleset 9.625" 36# J-55 Surf. 3978' Surf. 3887' 12.25" 980 sx AS IV,320 sx Class G 7" 26# J-55 Surf. 7754' Surf. 6965' 8.5" 300 sx Class G,175 sx AS 1 2-3/8" 4.4# L-80 8200' 10504' 6770' 6709' 3" 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/TVD) 3.5" 7445' 7239'MD/6540'TVD 8207'-10502'MD 6770'-6709'TVD 7430'MD/6696'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. . COMPLE1(t DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i t, 's' Ail, one St4i, 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) August 23,2010 injector-shut in Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL 'OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 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. . ,.,i• NONE ``_ 2010 ,. t (ISSIOfi RBDMS SEP 2,0 2010 P x: Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only ,4_, /0(' 1(),,,,f4A0 • 28. GEOLOGIC MARKERS(List all formations and markers encountered): _ 29. FORMATION TESTS NAME MD TVD Well tested? 0 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 1700' 1740' needed,and submit detailed test information per 20 AAC 25.071. Top of Kuparuk A2 7567' 6758' Top of Kuparuk A3 10434' 6723' Top of Kuparuk A4 10460' 6717' N/A Formation at total depth: Kuparuk A5 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Ohlinger @ 2651102 Printed N•\e V wve Title: Alaska Wells Manager Date 9/1 /000 Signature .vi _1-.01111■ Phone 265-6306 Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 L d YJ 44 QJ]1 I I _ a(s li In , To r ,, -„. ,. W W�— o o l'� \ O Y o N aN d G p illaci(DE O-o c�V o o —g rn M6 mrn E 't O W N H N s c w z ° H 3 O a E_ co 2 J=LL G W 7 mi ❑Ed.N µ I I N i,. .,.,„ n- 1,,U o 2 M n -E`N O 6 4 m . iN < i w o K E �a°v M o N N of <" hi N N CO • CO M h ,/ ? v i (DE ts, 7 Mill t 1111.1,, 1 '27:7c‘16'2: N I (X a�Q ci�❑ M W m t W j'm C Y n v �' .,84S14�.++N ICI 130 H N N d a d N n to 11,_ . . „ , In T g `off 6_ 3 _p O O c,io J yyyy Ni0 _ a p 2 W L v n n ca b oh gy�p`` OO N O C ,�p`` 1)tif- T Y C E ¢n, J (V N (.7)— 1 Co) r KUP 3K 12L1 ConocoPhldh1�35 Well Attributes Max Angle&MD. TD A(LSttti (11) ,) Wellbore APVUWI F Id Name Well Status Inc!() MD(ftKB) Act Btm(ftKB) / 500292165560 KUPARUK RIVER UNIT I PROD 10_0.90 10,460.27 1C ent IH2S(ppn) 'Date - Annotation End Date KB-Grd(ft) Rig Release Date -,._.Wee_Coplig:.,c3Jf gy,l,,g/SR,0103.-v 541'M 1 !I Last WO: 5/30/2010 _ 39.01 11/12/1986__ Annotation Depth(ftKB) End Date Annotation Last Mod. End Date $Qlgpa0c AffiuBL-... -.__-- Last Tag SLM i 1 8/23/2010 'Annotation Reason:SIDETRACK,TAG Imosbor Casing Strings - De ( f iCasing Description St 3779 0... String ID...ITop(MB) Set Depth(f...Set Depth(ND) String Wt.. String...String Top Thrd "' LINLR L 1 2 3/8 1 000. 1..8,198.5 I 10,504.0 I 6,708.7 4 60 L-80 I STL Liner Details HANGER,42 Top Depth (TVD) Top Intl N mi... Top(BKB) (ftKB) (') Item Desodption Comment ID(in) 8,198.5 6,7702 94.10 BILLET WHIPSTOCK-ANCHOR BILLET 1.995 9,246.7 6,776.6 91.34 DEPLOY 2 3/8 SHORTY DEPLOYMENT SLEEVE 1.995 CONDUCTOR,_ '. 3&110 . Perforations&Slots SAFETY VLV, ! '� Top(.D) elm(1VD) Dent Shot 1.841 4!' Top(BOB) Btm(ftKB) (8103) (8103) Zone DM. ( Type Comment III!: 8,207 9,245 6,769.5 6,776.6 8/16/2010 32.0 SLOTS Alternating solid/slotted pipe- 0.125'x2.5"@ 4 circumferential adjacent rows,3"centers staggered ' 18 deg,3'non-slotted ends -_ SURFACE, 9.247 10503 6776.6 6,708.9 8I76/2010 32.0 SLOTS Alternating solid/slotted pipe- 3]-3,978 0.125'x2.5"@ 4 circumferential adjacent rows,3"centers staggered GAS LIFT -_ 18 deg,3'non-slotted ends 7.166 Notes:General&Safety _- �: End Date Annotation 6/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematiic9.0 LOCATOR, -�' 8/22/2010 NOTE:CTD SIDETRACK 3K-12L1,3K-12L1-01 7,223 PBR,7.226 --� PACKER,7,240 -- - -� NIPPLE,7,263-....__.._.. ._ p.� 7.3047.310 -.'. APERF, ^._• 7,400-7,410 -'rte- '' 41+44" aer: PLUG,7,425 ¢. SEAL ASSY, +, 7,426 PACKER,7,430 SBE,7,433 - r.._ NIPPLE,7,440--- I- _1��. SOS,7,444-- { -I IPERF, 4 2 7,4747,480 - ! I RPERF, a 7,472-7,489 IPERF, 7,482-7,483 IPERF. 7,484-7,4E5 ' I Yfi IPERF, 7,486-7,487 .7 507 7,506-7,507 IPERF, 7,512-7,513 - IPERF, 7,520-7,521 ee RPERF, i 7,506-7,536 IPERF,__. - 7,526-7,529 IPERF,_-. 7,535-7.536 IPERF, - - 7,542-7,543 IPERF. __ 7 7,549-7,550 - IPERF, Mandrel Details 7,556-7,561 _. Top Depth Top 1 Port (TVD) Inc! OD Valve Latch Size TRO Run FISH,7,615 St Top(ftKB) (ftKB) (") Make Model (in) Sere Type Type BO (psi) Run Date Com... t 7,166.4 6,480.2 34.561CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/8/2010 PRODUCTKM, 34-7,754 TO(3102L1), 7,775 SLOTS,LOTS, G 8,207 6 SLOTS, 9.247-10,503 0'..5 7.- •.. LINER LI, fl,198-10,504 3K-12 Pre and Post Rig Wellwork DATE SUMMARY 7/17/10 TAGGED @ 7497' SLM WITH 11'x 2.5" DUMMY GUN, NO PROBLEMS ECOUNTERED. READY FOR CTU. 7/19/10 FCC) FROM 7531' CTMD TO 7615' CTMD (BTM PERF @ 7561' RKB)W/SLICK SEAWATER & BIOZAN SWEEPS. FREEZE PROTECT TBG TO 2500 ND W/DIESEL. READY FOR E-LINE. 7/20/10 SET HALLIBURTON 3.5" LW FAS DRILL BRIDGE PLUG AT A DEPTH OF 7425' (MID ELEMENT). CCL TO MID ELEMENT MEASURED AT 15.5'. CCL STOP DEPTH RECORDED AT 7409.5'. PRESSURE TESTED PLUG WITH LRS TO 2000 PSI FOR 15 MINUTES (PASSED) 7/21/10 PERFORATED AT A DEPTH OF 7300'-7310'AND 7400'-7410' USING 2"X10', 6 SPF, 60 DEG PHASING, MILLENIUM BIG HOLE CHARGES. LOG WAS CORRELATED TO GEARHART CBL LOG DATED 11/17/86. PLUG SET AT A DEPTH OF 7425' ON PREVIOUS DAY WAS CORRELATED TO TUBING TALLY RECORD. A 4 FOOT DIFFERENCE IN CORRELATION DEPTHS BETWEEN RUNS WAS RECORDED. 7/22/10 PRE CTD MIT-OA( PASSED ), PT SV, MV,SSV( PASSED ) DDT SV, MV, SSV&SSSV( PASSED ) 7/24/10 PUMPED 11 BBLS 15.8#CLASS G CEMENT, PLACED CEMENT FROM 7425 RKB TO TARGET TOC @ 7300 RKB, FREEZE PROTECTED AND TRAPPED 500 WHP. 7/26/10 TAGGED TOC @ 7251' SLM. TESTED TBG 1500 PSI, GOOD. READY FOR CTU. 7/28/10 MILL OUT FROM INITIAL TAG @ 7284 CTMD 1 FT MIN , BREAK THRU CBP @ 7429_CTMD, RIH TO 7550 CTMD, POH TO 7284 CTMD, MILL AGAIN TO 7429, POH, FREEZE PROTECT, READY FOR SL. 7/30/10 BRUSH TBG TO TTL @ 7443' RKB, TAG @ 7587' SLM, DRIFT 2.65" DUMMY WHIPSTOCK TO 7425' SLM. READY FOR E-LINE. 7/31/10 RAN 1-11/16" RADIAL CEMENT BOND TOOL TO 7448'AT THE TUBING TAIL., LOG FROM 7100' TO 7448' CEMENT TOP BETWEEN THE 3.5"X 7". GOOD CEMENT BOND FROM TOP OF CEMENT AT 7298' TO 7436'. 8/23/10 TAG @ 7373' SLM; MEASURE BHP @ 7390' RKB (3619-PSI); GRADIENT @ 7269' RKB (3574- PSI). COMPLETE. ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 3K-12 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/8/2010 1:00:00 PM Rig Release: 8/22/2010 12:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08/06/2010 24 hr Summary R/D off 31-11 and mobilize toward 3K 16:00 19:00 3.00 0 0 MIRU MOVE MOB P Trucks on location. Hook up and move 19:00 22:00 3.00 0 0 MIRU MOVE MOB T Unable to start sow.Mechanic dispatched to location 22:00 23:00 1.00 0 0 MIRU MOVE MOB T Pulling sow break down- Transmission problems 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Pull pit module to 3K Pad 08/07/2010 Rig up on 3K-12.Swap reel,perform reel drive motor&Injector Maint. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Mud Sub on 3K @ 02:00. Return to 31 pad to get drilling Sub 03:00 06:00 3.00 0 0 MIRU MOVE MOB T Pull drill sub to 3K Pad 06:00 08:00 2.00 0 0 MIRU MOVE MOB P Both subs now on 3K pad,Crew change, PJSM,spot modules on 3k-12 08:00 09:00 1.00 0 0 MIRU MOVE MOB P MIRU,Stairs, putz, power,etc 09:00 11:00 2.00 0 0 SURPRI WELLPF CTOP P Nipple up stack to get top drive clear for injector maintenance Reel ready to swap 11:00 13:00 2.00 0 0 SURPRI WELLPF CTOP P PJSM Remove used CT String from rig and secure to truck for transport to 1Q Pad 13:00 15:00 2.00 0 0 SURPRI WELLPF CTOP T Replace CT storage reel drive motor and pillow block bearings before able to pick up new CT string Start NAD Downtime 15:00 18:00 3.00 0 0 SURPRI WELLPF CTOP P End Nabors downtime PJSM, P/U new CT String and plumb inner reel iron 18:00 00:00 6.00 0 0 SURPRI WELLPF CTOP T Completing Motor swap on Reel drive from 18:00 hrs to midnight. Injector repairs from 19:00 hrs- 23:00 hrs. Installed new skates, design has flaw in guide plate.Start removing @ 23:30 hrs. 08/08/2010 Complete Rig repairs.**Rig accept @ 10:00 HRS**. Stab pipe&make up inner reel iron. BOP test started @ 13:00 hrs.Waived by Bob Noble. 00:00 03:00 3.00 0 0 SURPRI WELLPF CTOP T Complete installing skates and chains. Page 1 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:30 3.50 0 0 SURPRI WELLPF CTOP T Start working on reel sprocket, levelwind and installing stripper& gooseneck on injector. Begin taking on Water for BOP testing and slack MNGT. 06:30 10:00 3.50 0 0 SURPRI WELLPF CTOP T Trouble shoot reel drive circutry/ Clean Rig from Injector repairs 10:00 13:00 3.00 0 0 MIRU WHDBO PRTS P ***Rig Accept***Off Nabors Downtime Reel repairs complete/Injector repairs complete PJSM R/U and stab coil 13:00 21:00 8.00 0 0 MIRU WHDBO BOPE P Begin BOPE Test 250 low&4000 high.All valves tested other than Bravo 8. Move onto slack management. 21:00 22:30 1.50 0 0 MIRU WHDBO SLPC P Set up valves&CT for reverse circulating. Pump slack. 22:30 00:00 1.50 0 0 MIRU WHDBO BOPE P Inner reel valves&R-6 leaked (replaced). Re test inner reel valve and pack-off. Low 250/high 4000psi 08/09/2010 Complete BOP test. RIH with dummy WS drift to 7450'. POOH close&test SSSV with 600 psi WHP.Good test. P/U Whipstock assembly. 00:00 00:30 0.50 0 0 MIRU RIGMNT SFTY P Completed inner reel valve&pack off.250 low/4000 high.Safety meeting for next steps. 00:30 03:00 2.50 0 0 MIRU RIGMNI CTOP P Move injector back,cut off 6 ft pipe and install CT connector. Pull test- 40K, pressure test 4000psi. Replace Bravo 8 at the same time. retest-failed. 03:00 05:30 2.50 0 0 MIRU WHDBO BOPE P BOP-Bravo 8-replacing Hyd. actuator. 05:30 09:00 3.50 0 0 MIRU WHDBO BOPE T Replace Brovo 8 valve Nabors down time> 12hrs test time 09:00 11:00 2.00 0 0 MIRU WHDBO BOPE P PJSM, P/U FMC Lubricator pull BPV End NAD Downtime WHP=700PSI IA=0,OA=46 11:00 13:00 2.00 0 0 MIRU WHDBO PRTS P PJSM Load PDL, install quick test sub, 13:00 13:54 0.90 0 0 PROD1 RPEQP1SFTY P VP tour, hold pre-spud meeting. 13:54 15:54 2.00 0 0 PROD1 RPEQP1PULD P PJSM,pressure deploy BHA#1 surface test strip on well 15:54 18:30 2.60 0 7,450 PROD1 RPEQP1TRIP P RIH w/BHA#1, pumping.5 bpm with SW. BHI counter not recording- stop and clean wheel.Tie in @ 6960' -7040'-+3.5 ft correction. Stop pumping @ 7390'-Drift down to 7450'.Clean P/U 26K. Page 2 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 7,450 7,300 PROD1 RPEQP1CIRC P P/U to 7380'&Circ B/U with SW. Fix BHI counter IA 0 OA 60psi 19:30 21:30 2.00 7,300 71 PROD1 RPEQP1TRIP P POOH pumping SW.Ct @ surface with 600 WHP. 21:30 22:30 1.00 71 71 PROD1 RPEQPI OWFF P Safety meeting with SLB SSSV. Test SSSV-static shut=WHP 600 psi-5000psi on SSSV line. Function SSSV close-open-close. Bleed down WHP to 300 psi-did not hold Bleed down WHP to zero-Held-5 minutes with closed choke-no pressure build Open choke-watch for 10 minutes. 22:30 23:30 1.00 71 71 PROD1 RPEQPI PULD P Lay down Dummy Whipstock/P/U BOT Whipstock assembly. 23:30 00:00 0.50 71 900 PROD1 WHPST TRIP P Open EDC-RIH 400 ft-choke open. Break circ. @.3 bpm.Close choke- pressure up to 600 psi&open the SSSV.Continue RIH 08/10/2010 Set TOWS @ 7400'-Mill 3.5"from 7401.5'-7407.5'. No stalls.Clean drift. P/U BHA for 7"exit. 164 bbls of 9.8 milling fluid lost to perforations. 00:00 02:00 2.00 900 7,410 PROD1 WHPST TRIP P RIH 60 fpm with WS assembly.Tie in @ 7000'+11.5'correction. RIH to 7420'P/U to setting depth CT weight 25K. 02:00 02:30 0.50 7,410 7,400 PROD1 WHPST WPST P Orient HS-Close EDC. Bit depth 7410'-TOWS 7400.2. . Bring pumps online to 1 bpm.Tool set @ 3950 psi. Stop pumping. Set down 5K-P/U weight 25K. 02:30 03:30 1.00 7,400 7,380 PROD1 WHPST CIRC P P/U to 7380'-start pumping milling fluid. B/U 03:30 05:00 1.50 7,380 0 PROD1 WHPST TRIP P POOH 05:00 09:30 4.50 0 0 PROD1 WHPST PULD P at surface. check for flow have pressure PJSM, undeploy BHA#2 PJSM, Deploy BHA#3.6 deg motor, 2.80"mill&2.79"string mill. 09:30 11:00 1.50 0 7,000 PROD1 WHPST TRIP P RIH with BHA#3 Window mill first run 11:00 11:12 0.20 7,000 7,032 PROD1 WHPST DLOG P Tie into formation, +11 11:12 11:24 0.20 7,032 7,400 PROD1 WHPST TRIP P Dry tag Whipstock @ 7402, PUH pumps on to 1.4 BPM Drinking.8 BPM. reduce rate to 1.3 and losses to.6 BHP=4009 11:24 11:36 0.20 7,402 7,402 PROD1 WHPST MILL P Tag whipstock @ 7401.5 1.3 BPM @ 3689 PSI FS.8 BPM returns BHP=4104 11:36 12:36 1.00 7,402 7,402 PROD1 WHPST PRTS P Pull off tray obtain Static BHP 40 Min Static 3602PSI still dropping Page 3 of 14 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:36 18:06 5.50 7,402 7,407 PROD1 WHPST MILL P RBIH tag @ 7401.75, 1.3 bpm @ 3700 psi.start milling. returns @.87 after 4 hours of milling, rate 1.35 BPM, returns @ 1.11, depth of 7405.64.still pumping 9.8 mud. Start pumping BIO-17:00hrs 18:06 18:45 0.65 7,407 7,407 PROD1 WHPST MILL P Bio around-1:1 returns. Looks like contact with 7"WOB 2.5K slow mill off. IA=689,OA 482 18:45 19:15 0.50 7,407 7,407 PROD1 WHPST REAM P Complete milling 6'down to 7407.5' No stalls. Backreaming 1 -2 fpm to 7400'- clean.Stop pumping dry tag-clean down to 7407.4'. BHP 3420 psi not pumping with SW. 19:15 21:45 2.50 7,407 7,407 PROD1 WHPST TRIP P Open EDC-POOH pumping 1.4 bpm. Holding 300 psi on choke. 21:45 23:00 1.25 7,407 68 PROD1 WHPST PULD P CT @ surface-undeploy BHA- 2.79"No-go 23:00 00:00 1.00 68 0 PROD1 WHPST PULD P Make up equipment on rig floor-pre spud with crew. 08/11/2010 Mill window from 7401.5 to 7409.7'. No stalls with clean drift. P/U Build BHA with 2.3 AKO.Swap to 9.1# Flo-pro. 00:00 01:00 1.00 0 74 PROD1 WHPST PULD P Deploy Milling BHA with 2.0 AKO Weatherfrod motor 01:00 04:00 3.00 74 7,263 PROD1 WHPST TRIP P Rih pumping. 3bpm EDC open.Start pumping gel pill while RIH. RIH speed 50 fpm due to BHA&catching collars.Tie+11 ft.Start squeezing slurry into perfs. Pumping 1 bpm- returns.3 bpm. 04:00 04:30 0.50 7,263 7,407 PROD1 WHPST TRIP P Tagged up on collar @ 7263'P/U and finish pumping slurry,prior to closing EDC.-Passed thorugh clean. RIH to pinch point. 04:30 09:00 4.50 7,407 7,410 PROD1 WHPST MILL P Start time milling-motor work @ 7407.3'-1.45 bpm,3900 psi, BHP 3900,WOB.7K,CT weight 9.6K. 09:00 13:30 4.50 7,410 7,420 PROD1 WHPST MILL P mill to btm of window @ 7409.76, 1.45 bpm @ 3540 PSI mill down into formation to 7420' Ream up to 7399'and back down to 7314'@ 15 deg right. 2 milling passes @ 45 deg to milled tool face. @ 7390'tool @ 15 deg right.pumps off, dry drift down @ 15 FPM stop @ 7417'looks clean. 13:30 15:30 2.00 7,420 0 PROD1 WHPST TRIP P Bleed coil psi down to eq. across EDC. POOH to surface. 15:30 17:00 1.50 0 0 PROD1 WHPST PULD P On surface. PJSM. undeploy BHA#4 -2.79"No-go. 17:00 19:00 2.00 0 62 PROD1 DRILL PULD P P/U Build section BHA w 2.3 degree motor and Bi Center Bit-crew change. Page 4 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:30 2.50 62 7,350 PROD1 DRILL TRIP P RIH-100'choke problems.Stop RIH &flush choke from window milling. Continue RIH.Tie in-+13ft. Lowering WHP as RIH to keep 1:1 returns. 21:30 22:00 0.50 7,350 7,350 PROD1 DRILL CIRC P Circulate 9.1 Flo-pro around. P/U weight check-21K. little under 1:1 returns. BHP-3800 psi-WHP 50 9.1 mud to surface-Shut down pumping trap 500 psi.-Close EDC. 22:00 22:15 0.25 7,350 7,421 PROD1 DRILL TRIP P RIH slowly through window-Very slight bobble @ bottom of window, clean. Bring pumps online @ 7415'- Start seeing motor work @ 7421'. 22:15 00:00 1.75 7,421 7,457 PROD1 DRILL DRLG P Start drilling build section-1.40 bpm, 3400 psi, BHP 3950, ECD 11.5,WHP 80 psi. ROP-20,WOB 1K,CT weight 8K. Poor ROP- Gamma 150+outside the window. 08/12/2010 Drill build section to 7730'. P/U 1.0 AKO BHA and Start drilling L1 lateral.48 bbl losses in 24hours. 00:00 02:00 2.00 7,457 7,498 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3570 psi, BHP 3960,WHP 80, ECD 11.5, ROP 25, Ct weight 8K,WOB 2.2K. Losing 1 -2 bph. Pump 7 bbls of drillzone. 02:00 02:30 0.50 7,498 7,000 PROD1 DRILL WPRT P Wiper trip to check if gamma is working correctly. Log&tie in during wiper trip. P/U weight 21K.gamma working fine. 02:30 03:00 0.50 7,000 7,498 PROD1 DRILL DLOG P Tie into casing-1ft-Tie into PIP tag (7408').Window clean up/down. TOW=7401.5 BOW=7411.5'-RIH. 03:00 06:54 3.90 7,498 7,633 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3500psi, BHP 4020, ECD 11.6,WOB 2.5,Ct weight 8K, ROP 25. 7561'-pump 5 bbl drillzone 06:54 07:00 0.10 7,633 7,630 PROD1 DRILL WPRT P BHA Wiper-Lost motor work and stacked out PUW=26K, 1.37 BPM @ 3300 PSi FS BHP=4025 07:00 07:18 0.30 7,633 7,642 PROD1 DRILL DRLG P 7633', Drill Ahead RIW=10K, DHWOB=I.4K ROP=25 to 30FPH 07:18 07:36 0.30 7,642 7,642 PROD1 DRILL WPRT P 7642',Wiper to window PUW=22K 07:36 09:54 2.30 7,642 7,730 PROD1 DRILL DRLG P 7642', Drill Ahead 1.4 BPM @ 3326 PSI FS BHP=4047 09:54 11:54 2.00 7,730 0 PROD1 DRILL TRIP P End of Build/Turn Trip Out on MP schedule PUW=30K BHP=4027 11:54 14:42 2.80 0 0 PROD1 DRILL PULD P On Surface, PJSM PUD BHA#5 Deploy BHA#6 1 Degree motor, resistivity _Hughs bi-Center RR Page 5 of 14 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:42 16:12 1.50 0 6,990 PROD1 DRILL TRIP P Trip in well with BHA#6 16:12 16:30 0.30 6,990 7,038 PROD1 DRILL DLOG P Tie In for+12'Correction,Close EDC, RIH to drill 16:30 16:45 0.25 7,038 7,429 PROD1 DRILL TRIP P RIH to drill,Clean trip through window 16:45 19:00 2.25 7,730 7,880 PROD1 DRILL DRLG P 7730', Drill Ahead 1.41 BPM @ 3486 PSI FS BHP=4092 Wide open Choke ECD 11.5 7,880 PROD1 DRILL WPRT P 19:00 20:00 1.00 ,880 7 880 PR O Wiper trip with MAD pass P/U weight off bottom-22K.7 bbl loss for past 2 hours. 20:00 22:00 2.00 7,880 8,030 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3700 psi, BHP 4050,WHP 50, ECD 11.6, ROP 90,WOB 2.2K,CT weight 8k. 22:00 22:30 0.50 8,030 8,030 PROD1 DRILL WPRT P Wiper trip-P/U 23K. 22:30 00:00 1.50 8,030 8,131 PROD1 DRILL DRLG P Drilling ahead-1.44 bpm,3600 psi, BHP 4086,WHP 50, ECD 11.7, ROP 90,WOB 1.9K,Ct weight 9K. Total 15 bbl losses since 18:00 hrs. 08/13/2010 Drilling ahead in AL1 Lateral,Sticky section during wiper trip @ 8430', Mud swap perfromed with 1408'on system.46 bbl losses in 24 hours. 00:00 00:30 0.50 8,131 8,180 PROD1 DRILL DRLG P Drilling ahead 00:30 01:45 1.25 8,180 8,180 PROD1 DRILL WPRT P Wiper trip P/U weight 22K. Tie in -2ft. 01:45 03:30 1.75 8,180 8,330 PROD1 DRILL DRLG P Drilling ahead-1.43 bpm,3700 psi, BHP 4080,WHP 0, ECD 11.7, ROP 95,WOB 1.5,Ct weight 8K. 03:30 05:00 1.50 8,330 8,330 PROD1 DRILL WPRT P Wiper trip P/U weight 22K. 05:00 07:00 2.00 8,330 8,480 PROD1 DRILL DRLG P Drilling ahead 07:00 08:30 1.50 8,480 8,480 PROD1 DRILL WPRT P Wiper trip P/U weight 22k 08:30 10:45 2.25 8,480 8,630 PROD1 DRILL DRLG P Drilling Ahead 10:45 12:27 1.70 8,630 8,630 PROD1 DRILL WPRT P Wiper Trip P/U weight 22k.Tie in -6.5ft correction 12:27 14:24 1.96 8,630 8,780 PROD1 DRILL DRLG P Drilling Ahead-1.48 BPM,3793 psi, BHP 4152,WHP 68, ECD 11.96, ROP 58,WOB 1.67,CT weight 5k 14:24 16:15 1.85 8,780 8,780 PROD1 DRILL WPRT P Wiper Trip P/U 20k.RBIH Set down at 8414',TF at 70,puh 80', rbih set down at 8433'TF at 120,set down 8437'TF at 120, all at 25 ft/min, puh, rbih 35 ft/min with TF at 120 drift thru. 16:15 18:00 1.75 8,780 8,930 PROD1 DRILL DRLG P Drilling Ahead-1.4 BPM,3601 psi, BHP 4575,WHP 45, ECD 11.9, ROP 93,WOB 1.71,CT weight 5.7k Swap to new mud 18:00 20:00 2.00 8,930 8,930 PROD1 DRILL WPRT P Wiper Trip P/U weight 22k. RBIH Set down 8430',TF 90R, puh reduce pump rate to.8 bpm, rbih, passed thru area, increase rate to 1 bpm continue rih Page 6 of 14 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 21:00 1.00 8,930 9,080 PROD1 DRILL DRLG P Drilling Ahead-1.45 bpm,3700, BHP 4130, ECD 11.8, ROP 130, WOB 1.9K,Ct weight 7K,WHP 120 psi. 21:00 23:15 2.25 9,080 9,080 PROD1 DRILL WPRT P Wiper Trip P/U weight 22k.Tie in -9.0ft correction.Tough section @ 8440'. Increase claygaurd to 3%. 23:15 23:59 0.74 9,080 9,175 PROD1 DRILL DRLG P Drilling Ahead-1.4 BPM,3820 psi, BHP 4180, ECD 11.9, ROP 140, WOB 2.0k,Ct weight 2.5k,WHP 54 psi, Formation&Rez change around _ 9100'.4 bph losses. 08/14/2010 Drilling ahead in AL1 Lateral,Trouble Spot at 8440-8380, Back Reamed from 8440-8380 @ 180 degrees.Able to pass thru area without any set downs.68 bbl losses in 24 hours. 00:00 00:30 0.50 9,175 9,230 PROD1 DRILL DRLG P Drilling Ahead-1.4 BPM,3820 psi, BHP 4180, ECD 11.9, ROP 140, WOB 2.0k,Ct weight 2.5k,WHP 54 psi 00:30 02:30 2.00 9,230 9,230 PROD1 DRILL WPRT P Wiper trip-P/U weight 24K.-Pulling heavy&motor work @ 8385'. RIH- Lower pump rate through bad section of 8300-8600'. 02:30 03:30 1.00 9,230 9,380 PROD1 DRILL DRLG P Drilling ahead-140 bpm,3800, BHP 4150, ECD 11.9,WHP 50, ROP 150, WOB 2.1, CT weight 5K. 03:30 06:00 2.50 9,380 9,380 PROD1 DRILL WPRT P Wiper trip-25K off bottom.8390'- Saw weight&pressure gain while POOH.Slow rate down to slide through. 06:00 07:30 1.50 9,380 9,530 PROD1 DRILL DRLG P 9380', Drill Ahead 1.44 BPM @ 3508PS1 FS RIW=6.8K,WOB=1.6K BHP=4126 07:30 10:00 2.50 9,530 9,524 PROD1 DRILL WPRT P 9530',Wiper Trip to window with Tie In PUW=23K, Back ream tight areas on way up @ 180 degrees out 8440 to 8380.Tie in for a-9'. Saw WOB @ 8408&8518 No setdowns 10:00 11:25 1.42 9,524 9,680 PROD1 DRILL DRLG P 9524', Drill ahead 1.46 BPM @ 3689PSI FS BHP=4215 6.5K Slackoff, 1.5K WOB 11:25 14:07 2.70 9,680 9,680 PROD1 DRILL WPRT P 9680',Wiper Trip to window PUW=21 k 14:07 16:37 2.50 9,680 9,840 PROD1 DRILL DRLG P 9680', Drill Ahead 1.43 BPM @ 3633PSI FS BHP=4248 6.5k Slackoff,2.5k WOB 16:37 19:29 2.88 9,840 9,840 PROD1 DRILL WPRT P 9840'Wiper Trip PUW=20k 19:29 21:23 1.90 9,840 9,990 PROD1 DRILL DRLG P 9840'Drill Ahead 1.4 BPM @ 3700PSI FS BHP=4245 6.5 Slackoff,2.5k WOB Page 7 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:23 23:59 2.60 9,990 9,990 PROD1 DRILL WPRT P 9990'Wiper Trip to window with Tie In-7'Correction PUW=22k 08/15/2010 TD'd AL1 Lateral at 10504', Pumped Hi/Lo Vis sweeps and chased back to window,Tie in pass resulted in-1 correction. Layed in liner bead pill from TD to window, Painted coil flags for depth control 00:00 00:33 0.55 9,990 9,990 PROD1 DRILL WPRT P Wiper Trip,Tie in-7 00:33 02:24 1.85 9,990 10,140 PROD1 DRILL DRLG P 9990'Drilling Ahead 1.3 BPM,3500psi FS,4205 BHP 2.3k WOB, 5.6k Slackoff weight 02:24 05:24 3.00 10,140 10,140 PROD1 DRILL WPRT P 10140'-Wiper Trip PUW=22k 8402 to 8390 Over pull with pressure spike 05:24 07:24 2.00 10,140 10,290 PROD1 DRILL DRLG P 10140', Drill Ahead 1.34 BPM @3734PSI FS 3.8K Slackoff w/2.5K WOB BHP=4212 07:24 10:39 3.25 10,290 10,290 PROD1 DRILL WPRT P 10290 Wiper to window PUW=22K 8402 to 8390 Overpull 10:39 12:15 1.60 10,290 10,440 PROD1 DRILL DRLG P 10290'Drill Ahead 1.42 BPM @ 3754PSI FS Slackoff=1.7K WOB=1.9k 12:15 15:15 3.00 10,440 10,440 PROD1 DRILL WPRT P 10440',wipe to window with tie in,-5' correction setdown @ 8408, reduced pump to 1BPM and tripped through Setdown @ 10089 went through without pickup Swap to new mud 1612'on system 15:15 16:00 0.75 10,440 10,490 PROD1 DRILL DRLG P 10440, Drill Ahead TD Extended 1.4 BPM @ 3550PSI FS RIW=6.6K Slackoff=-1.2K, WOB=2.52 ROP=120FPH 16:00 16:12 0.20 10,490 10,505 PROD1 DRILL DRLG P 10490'. New mud around, holding 150 PSI on Choke 1.4 in-1.3 out BHP=4252, ECD=12.31 Slackoff=-.7k,WOB=2.33 16:12 16:57 0.76 10,505 10,505 PROD1 DRILL CIRC P Call TD-Pick up off bottom and start to-hi vis sweeps Slackoff weight-1K WOB=2.5K WOB, PUW=21K 16:57 18:57 2.00 10,505 10,505 PROD1 DRILL WPRT P Lo Hi vis sweeps out.Chase to window and Tie in PUW=21K 18:57 20:36 1.66 10,505 10,505 PROD1 DRILL TRIP P RBIH for correlation pass,Tie in-1' correction. Continue RIH to TD. Slackoff weight 12.6k 20:36 21:20 0.74 10,505 10,505 PROD1 DRILL TRIP P Tag TD @ 10504'(Minus Correction) 21:20 21:22 0.04 10,505 10,505 PROD1 DRILL TRIP P POOH laying in liner beads 1:1 1.4 BPM,2011 PSI PUW=21k 21:22 21:25 0.05 10,505 10,505 PROD1 DRILL TRIP P 9171.93', Paint RED flag Page 8 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:25 22:31 1.10 10,505 10,505 PROD1 DRILL TRIP P Continue POOH using Managed Pressure Schedule 22:31 22:33 0.04 10,505 10,505 PROD1 DRILL TRIP P 6071.88',(EOP=6200')Paint WHITE flag for window marker. 22:33 23:48 1.25 10,505 10,505 PROD1 DRILL TRIP P Continue POOH using Managed Pressure Schedule 23:48 23:57 0.16 10,505 1,685 PROD1 DRILL OTHR P 1685',Park coil and prep to dump saftey valve 08/16/2010 Deoloved AL1 liner in two sections consisting of 9'Aluminum Billet,71jts 2 3/8 4.4#L-80 Slotted Liner,with 2 biased edge indexing guide shoes. Logged correlation pass resulting in-2'correction placing top of billet at 8199' 00:00 00:30 0.50 1,684 1,684 PROD1 DRILL OTHR P 1684',park coil and perform closure test on SSSV 00:30 01:00 0.50 1,684 0 PROD1 DRILL TRIP P Saftey valve holding, bring pumps back online,continue pooh 01:00 01:15 0.25 0 0 PROD1 DRILL SFTY P PJSM for undeployment of BHI tool string. 01:15 02:00 0.75 0 0 PROD1 DRILL TRIP P BHI tool string OOH, Prep to pick up liner 02:00 02:15 0.25 0 0 COMPZ CASING SFTY P PJSM for running liner. 02:15 04:45 2.50 0 0 COMPZ CASING PUTB P Begin running section 1 of AL1 liner consisting of 2 3/8 indexing guide shoe,39jts 2 3/8 sltd liner,2 3/8 shorty deployment sub. 04:45 06:00 1.25 0 1,302 COMPZ CASING PUTB P Service Injector,Stab on and surface test,tag up and set depth 06:00 08:00 2.00 1,302 7,290 COMPZ CASING TRIP P Trip in well with AL1 lower liner section 08:00 09:27 1.45 7,289 7,259 COMPZ CASING TRIP P Stop and correct at first flag,-33.3' RIH 09:27 10:45 1.30 7,259 10,467 COMPZ CASING TRIP P Drive by second flag, @ 10359 right where it should be. Tag @ 10467'. Hard tag seems like bottom.Consult town bottom of pay 10430. Release from liner. PUH to tie in 10:45 11:30 0.75 10,467 8,226 COMPZ CASING DLOG P Reset togs depth of 6969. Log gamma to Formation missed first pass. PUH and try again.Correct +39. Confusion has set in RBIH to tag TOL. 11:30 13:15 1.75 8,226 9,246 COMPZ CASING TRIP P RBIH to tag TOL 13:15 13:21 0.10 9,247 9,247 COMPZ CASING TRIP P Tag liner @ 9246'Pick it up RBIH and release. 13:21 16:06 2.75 9,247 1,500 COMPZ CASING TRIP P Trip out of well, Paint EOP Flags @ 8000&6200 16:06 16:21 0.25 1,500 1,500 COMPZ CASING OWFF P Stop and close SSSV. Observe well for flow 16:21 16:36 0.25 1,500 0 COMPZ CASING TRIP P Good no flo test.Continue out of well 16:36 16:46 0.17 0 0 COMPZ CASING PUTB P PJSM,Observe for flow Pull liner running tools from well 16:46 17:00 0.24 0 0 COMPZ CASING PUTB P Surface,check well for flow. Pop off well stand back BHI, prep to pick up section 2 of AL1 liner Page 9 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:21 0.35 0 0 COMPZ CASING BOPE P Weekly function test of BOP 17:21 18:00 0.65 0 0 COMPZ CASING PUTB P Pick up section 2 of AU liner_ consisting of 2 3/8 indexing guide shoe,32jts 2 3/8 4.4#L-80,2 5/8" Allum. Billit 18:00 18:06 0.10 0 6,183 COMPZ CASING TRIP P Increase WHP to 800#,Open SSSV, WHP balaced out at 670psi, RIH with liner as per MPS .2 BPM, 1512psi -3k Slackoff weight 18:06 21:30 3.40 7,293 7,293 COMPZ CASING TRIP P 6183.7'-At yellow flag(6200')correct depth to 7292.87'=(bha length to btm of guide shoe). 21:30 21:36 0.10 7,293 9,193 COMPZ CASING TRIP P Continue RIH with section 2 of AL1 Liner 21:36 22:06 0.50 9,193 9,248 COMPZ CASING TRIP P Saw second flag at 9192'drillers depth, RIHW 7k 22:06 22:12 0.10 9,248 9,252 COMPZ CASING DLOG P Set down at 9252',slackoff weight -1k, Bring pumps on line at 1.5bpm,4500 psi PUH release from liner pUW=22k Got weight back at 9245.7'(top of billet) 22:12 22:21 0.15 9,252 6,985 COMPZ CASING TRIP P POOH as per MPS 22:21 22:51 0.50 6,985 6,985 COMPZ CASING DLOG P Reset to gs depth of 6969. Log gamma to Formation.Correction=- 2' 22:51 23:59 1.14 6,985 2,105 COMPZ CASING TRIP P POOH as per MPS 08/17/2010 Tagged top of Billet at 8200',Time drilled off billet from 8200'-8240'dry drifted past billet without any problems. 120-150 FPH ROP to 8810'ROP fell off to 3-4 FPH,GEO confirmed Ankerite,Continue drilling ahead on BL1 Lateral 00:00 00:30 0.50 2,105 0 COMPZ CASING TRIP P Continue POOH Q 00:30 00:45 0.25 0 0 COMPZ CASING SFTY P Surface, PJSM for pressure 1, f`v deploy/undeploy L 00:45 02:15 1.50 0 0 PROD2 DRILL SVRG P Undeploy/Deploy comoplete, continue service injector 02:15 03:27 1.20 0 7,015 PROD2 STK TRIP P RIH with drilling BHA#9 03:27 04:51 1.40 7,015 7,055 PROD2 STK TRIP P 7015'-Slackoff weight=13k Tie in=+9' Close EDC continue rih 04:51 05:51 1.00 7,055 8,200 PROD2 STK TRIP P Trip in well to Billit @ 8200 PUH, Pumps on Find Billet @ 8200. 1 stall and 1 reset due to stacking 05:51 10:09 4.30 8,200 8,240 PROD2 STK KOST P Time milling off liner top billit 1.34 BPM @ 3227 PSi FS BHP=4114 10:09 10:24 0.25 8,240 8,240 PROD2 STK KOST P PUH dry drifting side track, Looks good 10:24 12:24 2.00 8,240 8,370 PROD2 DRILL DRLG P Drill Ahead 40-100 FPH,3950 CTP, 2-3K WOB,6K CTW, 1.43 BPM, 164 WHP 12:24 13:36 1.20 8,370 8,370 PROD2 DRILL WPRT P Wiper trip#1 to window,22K PUW Page 10 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:36 15:36 2.00 8,370 8,510 PROD2 DRILL DRLG P Drill Ahead 40-100 FPH, 3950 CTP, 2-3K WOB,6K CTW, 1.43 BPM, 164 WHP 15:36 17:06 1.50 8,510 8,510 PROD2 DRILL WPRT P Wiper Trip#2 to window,22K PUW 17:06 18:06 1.00 8,510 8,510 PROD2 DRILL DRLG P Drill Ahead 40-100 FPH, 3950 CTP, 2-3K WOB,6K CTW, 1.43 BPM, 164 WHP 18:06 18:12 0.10 8,563 8,563 PROD2 DRILL WPRT P Crew Change, BHA Wiper Trip,22k PUW 18:12 20:12 2.00 8,563 8,660 PROD2 DRILL DRLG P Drill Ahead 60-150 FPH,3890 CTP, 2-3 WOB,6.7 CTW,1.4 BPM,132 WHP,4092 BHP 20:12 21:50 1.64 8,660 8,660 PROD2 DRILL WPRT P Wiper Trip#3 to window,22k PUW, Tie in-2' Have crew rack and talley 96jts SLTD and 5jts Blank Liner 21:50 22:59 1.16 8,660 8,810 PROD2 DRILL DRLG P Drill Ahead 100-120 FPH, 3789 CTP, 1.7 WOB,8.6 CTW,1.4 BPM,152 WHP,4094 BHP 22:59 23:59 1.00 8,810 8,810 PROD2 DRILL WPRT P Wiper Trip#4 to window,22k PUW 08/18/2010 9410'Drilling Ahead in BL1 Lateral,Avg. 1-1.2 BPH Losses with.5%DS @ 1274 ft on mud system#3. 00:00 00:40 0.67 8,810 8,810 PROD2 DRILL WPRT P Continue wiper trip from 8/17/10 00:40 02:22 1.70 8,810 8,881 PROD2 DRILL DRLG P 8810'-Drilling Ahead 7.5k Slackoff weight,133 WHP,3874 CTP 80-120 FPH 1.4 WOB 02:22 04:28 2.10 8,881 8,890 PROD2 DRILL DRLG P 8881'-Drilling Ahead Ok Slackoff weight,156 WHP,3874 CTP 4-7 FPH, 3.0 WOB Hard drilling 04:28 04:46 0.30 8,890 8,890 PROD2 DRILL WPRT P BHA wiper trip 21k PUW,3475 FS, 150 WHP, 1.43 BPM 04:46 10:31 5.75 8,890 8,960 PROD2 DRILL DRLG P 8890'-Drilling Ahead 2-3 FPH,3-4K WOB.Ankerite 10:31 12:31 2.00 8,960 8,960 PROD2 DRILL WPRT P Wiper trip to window,22K PUW 12:31 15:01 2.50 8,960 9,099 PROD2 DRILL DRLG P Drill Ahead,40-80 FPH,3800 CTP, 1.4 BPM,2-3K WOB,2-3K CTW, 125 WHP 15:01 17:37 2.60 9,099 9,099 PROD2 DRILL WPRT P Wiper trip to window,Tie in depth to RA marker-3.5' 17:37 18:01 0.40 9,099 9,179 PROD2 DRILL DRLG P CREW CHANGE 18:01 18:45 0.74 9,179 9,260 PROD2 DRILL DRLG P Drill Ahead,40-100 FPH,4000 CTP,1.4 BPM,1.5 WOB,4.8 CTW,123 WHP 18:45 21:00 2.25 9,260 9,260 PROD2 DRILL WPRT P Wiper trip to window,22k PUW, 11.9 ECD,3650 CTP, 123 WHP 21:00 22:30 1.50 9,260 9,410 PROD2 DRILL DRLG P 9260'-Drilling Ahead. 120-150 FPH, 1.6 WOB,3909 CTP,4936 BHP,11.9 ECD, 126 WHP 22:30 23:59 1.49 9,410 9,410 PROD2 DRILL WPRT P Wiper trip to window,22k PUW,11.9 ECD,3747 CTP,4188 BHP,126 WHP Page 11 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/19/2010 24 hr Summary Performed mud swap, 10142'Drilling Ahead in BL1 Lateral, ROP decline at 10132'appears to be Ankerite, -432'currently drilled on mud system#4 with .2%DS 00:00 00:50 0.84 9,410 9,410 PROD2 DRILL WPRT P Continue wiper trip 00:50 01:35 0.75 9,410 9,470 PROD2 DRILL DRLG P 9410'-Drilling ahead,4042 CTP, 130-150 FPH,2.4 WOB, 126 WHP 01:35 01:56 0.35 9,470 9,472 PROD2 DRILL DRLG P 9470'Drilling ahead,3963 CTP, 16 FPH,2.1 WOB, 126 WHP,SLOW GOING 01:56 02:08 0.20 9,472 9,472 PROD2 DRILL WPRT P BHA Wiper,21k PUW, Pump HI/LO vis sweep 02:08 02:20 0.20 9,472 9,480 PROD2 DRILL DRLG P Drilling ahead,caught drilling break, ROPS back to 110-120 FPH 02:20 03:08 0.80 9,480 9,560 PROD2 DRILL DRLG P 9480'drilling ahead,4016 CTP,2.5 WOB 03:08 05:44 2.60 9,560 9,560 PROD2 DRILL WPRT P 9560'Wiper trip to window,21k PUW,Tie in to RA marker-6' 05:44 06:59 1.25 9,560 9,710 PROD2 DRILL DRLG P Drill Ahead 1.4BPM,4100 CTP,-3K CTW, 120-150 FPH 06:59 09:44 2.75 9,710 9,710 PROD2 DRILL WPRT P Wiper trip to window,21K PUW, Perform mud swap 09:44 10:56 1.20 9,710 9,816 PROD2 DRILL DRLG P Drill Ahead 100-150 FPH, 1.4 BPM, 3361 CTP,0-3K CTW, 1-2K WOB. 10:56 11:11 0.25 9,816 9,816 PROD2 DRILL WPRT P Stacking weight PUH, 100' 11:11 11:59 0.80 9,816 9,860 PROD2 DRILL DRLG P Drill Ahead 40-50FPH, 1.4BPM, 3400CTP, 1-1.5K WOB,3-5K CTW 11:59 14:59 3.00 9,860 9,860 PROD2 DRILL WPRT P Wiper trip back to window,21K PUW 14:59 17:05 2.10 9,860 10,010 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3640 CTP, 70-80FPH,4K CTW,2K WOB 17:05 20:11 3.10 10,010 10,010 PROD2 DRILL WPRT P Wiper trip to window,Tie in depth to RA marker,correction-5' 20:11 22:32 2.36 10,010 10,136 PROD2 DRILL DRLG P 10010'-Drilling Ahead,3581 CTP,4760 BHP, 125 WHP,2.5 WOB, 1.4 BPM 22:32 22:50 0.30 10,136 10,136 PROD2 DRILL WPRT P Short wiper 22:50 23:59 1.15 10,136 10,142 PROD2 DRILL DRLG P 10142'-Drilling Ahead, 3-4 FPH,3.5k WOB,3711 CTP,12 ECD 08/20/2010 TD'd BL1 Lateral at 10462',Qumped Lo/Hi Vis sweeps and chase back to window. 00:00 03:30 3.50 10,142 10,155 PROD2 DRILL DRLG P 10142'drilling ahead,3.4 WOB,3-9 FPH, 3625 CTP,203 WHP, 12.15 ECD, BHA wiper 03:30 05:30 2.00 10,155 10,160 PROD2 DRILL DRLG P Lo/Hi Vis Sweep @ Bit,3.7 WOB, 2.8 ROP, 187 WHP,4200 BHP 05:30 08:45 3.25 10,160 10,160 PROD2 DRILL WPRT P Wiper trip to window, 19K PUW 08:45 15:00 6.25 10,160 10,184 PROD2 DRILL DRLG P Drill Ahead,3 FPH,2.7 WOB, 1.4 BPM,3760 CTP,0-1 CTW 15:00 16:30 1.50 10,184 10,310 PROD2 DRILL DRLG P Break through Ankerite 10184' Drill Ahead 100FPH, 1.8K WOB, 4-5K CTW, 1.4 BPM 3750 CTP 16:30 17:00 0.50 10,310 10,310 PROD2 DRILL WPRT P Wiper trip to window,21K PUW 17:00 19:00 2.00 10,310 10,310 PROD2 DRILL WPRT P New Crew Change,continue wiper from 10310',Tie in to RA-16' Page 12 of 14 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:00 21:57 2.95 10,310 10,464 PROD2 DRILL DRLG P 10310'-Drilling ahead to TD, 1.4 BPM,3673 CTP,26 WHP,4220 BHP 21:57 22:00 0.05 10,464 10,464 PROD2 DRILL WPRT P 10464'-GEO called TD, PUH start 5bbl Lo/10bb1 Hi Vis sweep,23k PUW,3718 CTP,4277 BHP,76 WHP, 1.4 BPM 22:00 00:00 2.00 10,464 8,100 PROD2 DRILL WPRT P 10450'-Lo/HI sweep at bit,Chase sweep back to window, PUW 21k, 3775 CTP,91 WHP,4266 BHP.1.4 BPM 08/21/2010 Layed in liner running pill from TD to TOWS,Ran lower section of BL1 liner to TD @ 10462' 00:00 00:36 0.60 8,100 7,000 PROD2 DRILL WPRT P Continue to chase Lo/Hi vis sweep to window 00:36 02:12 1.60 7,000 10,462 PROD2 DRILL WPRT P RBIH,Tie in at RA=-4',Continue to TD to reconfirm bottom 02:12 02:18 0.10 10,462 8,771 PROD2 DRILL TRIP P Tag TD with correction at 10462', PUH to 8771'paint yellow flag 02:18 02:54 0.60 8,771 5,671 PROD2 DRILL TRIP P Continue pooh laying in liner pill to TOWS following MPS 02:54 03:54 1.00 5,671 5,671 PROD2 DRILL TRIP P 5671',Stop for TOWS coil flag. (RED) 03:54 03:55 0.03 5,671 0 PROD2 DRILL TRIP P POOH as per MPS 03:55 05:25 1.50 0 0 PROD2 DRILL PULD P Surface, PJSM,prep for pressure undeploy milling bha 05:25 05:40 0.25 0 0 PROD2 DRILL SFTY P Crew Change, PJSM 05:40 07:22 1.70 0 0 PROD2 DRILL PULD P Continue undeployment 07:22 08:52 1.50 0 0 COMPZ CASING OWFF P Bleed well to 500psi. Let stabilize 20 min.Close SSSV. Monitor well for 20min. Prep floor and equipment to run liner. 08:52 11:52 3.00 0 0 COMPZ CASING PUTB P PU 52 jnts liner,MU BHA 11:52 13:07 1.25 0 7,289 COMPZ CASING RUNL P RIH 13:07 14:37 1.50 7,289 10,452 COMPZ CASING RUNL P Tie into EOP flag. No correction, Perform weight check,22.5K PUW, RIH 14:37 14:49 0.20 10,452 10,452 COMPZ CASING RUNL P Liner on bottom,4200psi CTP, PUH 22.5 PUW. Liner released 14:49 15:49 1.00 7,400 7,400 COMPZ CASING RUNL P POOH pumping across top 15:49 17:04 1.25 7,000 0 COMPZ CASING RUNL P Tie in depth+7'correction POOH displacing mud down CT 17:04 17:34 0.50 1,500 0 COMPZ CASING OWFF P CLose SSSV, Monitor well 17:34 17:59 0.43 0 0 COMPZ CASING PULD P Surface,Crew Change, LD BHA 17:59 21:59 4.00 0 0 COMPZ CASING PULD P PJSM, Pick up liner 21:59 22:29 0.50 0 0 COMPZ CASING PULD P Section#2 of BL1 liner in hole,MU coil 22:29 23:58 1.49 0 5,700 COMPZ CASING RUNL P Equilize SSSV with WHP and Hydralic's, RIH with liner 08/22/2010 Swap well to SW,and freeze protect well. Set BPV, RD/ND, Move from 3K-12 to 3N-16. 00:00 00:40 0.68 5,700 7,676 COMPZ CASING RUNL P Continue RIH with section#2 of BL1 liner Page 13 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:40 01:00 0.34 7,685 8,750 COMPZ CASING RUNL P Stop mat faig and correct drillers depth to btm of liner to 7684.7' 01:00 01:06 0.10 8,750 8,813 COMPZ CASING RUNL P 8750',25k PUW,11k RIHW1785 CTP,297 WHP 01:06 01:06 0.01 8,813 8,815 COMPZ CASING RUNL P Tag bottom,Set down 8k, Increase pump rate to 1.5 bpm 01:06 01:09 0.05 8,815 8,795 COMPZ CASING RUNL P PUH,dropped 5k in string weight, pick up to 8795' 01:09 01:54 0.75 8,795 8,795 COMPZ CASING CIRC P Park at 8795',begin displacing well to seawater 01:54 02:30 0.60 8,795 4,800 COMPZ CASING CIRC P 20 BBIs seawater around,Open EDC, POOH 02:30 03:00 0.50 4,800 2,100 COMPZ CASING FRZP P Swap to to diesel,continue to POOH 03:00 03:30 0.50 2,100 0 COMPZ CASING FRZP P Diesel at bit continue to POOH 1:1 03:30 04:00 0.50 0 0 COMPZ CASING FRZP P Surface, Pumps down let well stabilize, Record pressures, Close SSSV 04:00 05:30 1.50 0 0 COMPZ CASING PULD P LD BHA, RU to flush and purge rig and stack 05:30 06:30 1.00 0 0 DEMOB WHDBO DMOB P Crew change, PJSM 06:30 07:30 1.00 0 0 DEMOB WHDBO DMOB P Flush and purge stack 07:30 08:00 0.50 0 0 DEMOB WHDBO DMOB P Set BPV 08:00 10:00 2.00 0 0 DEMOB WHDBO DMOB P Finish flush and purge, RD/ND, prepare for demob 10:00 11:29 1.49 0 0 DEMOB MOVE DMOB P Wait on trucks. 11:29 11:57 0.48 0 0 DEMOB MOVE DMOB P Trucks on location, PJSM Rig Release 11:57 23:57 12.00 0 0 DEMOB MOVE DMOB P Mobilize rig from 3K-12 to 3N-16. 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M N 7 (O CO C') )0 N- CI o J F- 2 Z C$) 0 W (C ti Li 4 80 2 r N N 7 N N- O O M o 1. M 41 to N C) (C M C) O Cl) 0) 1- co N co N- O _co co o co co co ": C'? C) M M M N N N + u N 7 O CO (C U ti 7 N (C CO LO CD ,- I() N UO O) M O) CO CC 7 CO (C N CO CO U) N O O) (C M CO M I- d) U) co Co N- N. � N- co co CC (C) u) 7 CO -Y >0 F 0 ) M O N CO n CC 7(C n N C(D ::". r 7 UO O(O imc o M f�C CO i,.O(C n r M M O(C N O N O() 7 C O O O)O O(6 O CD N O O N 1- C U C F (o o o o u ro ( o o 0 U U =C Q D -O 03 CO O CO CO s-, CO (O CO u) .-- > M M M M M VI C p_ 4) Q. •Q,. () M M M Cr)M M 0 _ a a C Y IIIMINIO 0 i U i ""v' O C u7 N U) N 7 CO UO LL7 CO M O O (- 0 d Q U",^ f` n (n O Q) CO (O co CO to co d) d) W.w Up UO N. (O 7 N co (n O C) O co O CL 0• Y Y co co Co C ) rn a) rn rn C) C) commoc, co It co ' M O UO UO N UO C CO N CA 7 O N O T C' teN 7 (C M C C (C C M N CO 01 O 6 O 0 0 0 0 0 O o 0 0 0 7 • C . co . . T 0 co O C) N (O 0 7 N- O CO O O N N N M M M Cr 7 7 (C O F l i S d )_ y N O o O O O O co O O O O O O .. U C) O d 0) 0 7 u) cd N N. Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, July 22, 2010 4:25 PM To: 'Gantt, Lamar L' Subject: RE: 3K-12 BHP (PTD 210-089) Lamar, Thank you for the follow- up email. I can see where the confusion could happen. I will change the PTD to reflect the correct Max pressure. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Gantt, Lamar L [mailto:Lamar.L.Gantt @conocophillips.com] Sent: Thursday, July 22, 2010 4:14 PM To: Schwartz, Guy L (DOA) Cc: Ohlinger, James J Subject: RE: 3K-12 BHP (PTD 210-089) Guy Sorry for the delay getting back to you. James took his working file home, so I had to dig out the information. It looks like he based the downhole pressure on the last pressure measured in the wellbore (3568) The max expected pressure is a 13 ppg, so I agree the downhole pressure should have been 4462 as you stated below. The max surface pressure of 3802 should be correct. I will communicate to the group that they should be using the max expected pressures for the calculations in box 17. Lamar From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, July 22, 2010 11:25 AM To: Gantt, Lamar L Subject: FW: 3K-12 BHP(PTD 210-089) Larmar, The max fm pressure anticipated during drilling should be listed on the PTD form ( Box 17)... not the actual pressure for the current well. I get a pressure of 4462 psi (13 ppg) .. can you verify this and I will change the PTD number to reflect this. Thanks, 7/22/2010 4 Page 2 of 2 . R Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Thursday,July 22, 2010 11:18 AM To: Ohlinger, James J Subject: 3K-12 BHP (PTD 210-089) James, I am confused with the Max and formation pressures listed on the PTD application. The MASP is higher than the expected formation pressure. Can you call me to discuss? I think I see where you are getting the numbers but I need to understand. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 7/22/2010 SlinTrE OF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL A.NJ) GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMAIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-12L1 ConocoPhillips Alaska, Inc. Permit No: 210-089 Surface Location: 1109' FSL, 316' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 914' FSL, 398' FWL, Sec. 35, T13N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 3K-12, Permit No 186- 165, API 50-029-21655-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a 2 mission order, or the terms and conditions of this permit may result ' 'revoc- io or suspension of the permit. Si, ce ref / D.. ie .un i Jr. air DATED this?/kiay of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 22, 2010 RECEIVED Commissioner- State of Alaska JUL 0 2 2010 Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Alaska Oil&Gas Cn�; . COrnmissiorr Anchorage, Alaska 99501 Anchorage Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a dual lateral out of the Kuparuk Well 3K-12 using the coiled tubing drilling rig, Nabors CDR2-AC. The CTD laterals will be drilled for A2 &A3 each to provide injection support in an adjacent fault block to the northwest, and maintain injection to existing wellbore perfs. 3K-09B, BL1, BL1-01 BL2, and BL2-01 were J 9 P recently drilled that will be supported by this injection from sweep efficiency. 3K-10 to the SE is located in a dead segment and will gain injection support. The original A-sand perforations will be re-main open to inject into the region of the mother-bore. Attached to this application are the following documents: — Permit to Drill Application Form for 3K-12L1 and 3K-12L1-01 — Sundry for 3K-12, perforations — %Mile Injection Summary — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, _ G James Ohlinger Coiled Tubing Drilling Engineer , STATE OF ASKA ALASKA OIL AND GAS CONSERVAT ON COMMISSION RECEIVED PERMIT TO DRILL n JUL 0 2 2010 20 AAC 25.005 g. rr la.Type of Work: . lb.Proposed Well Class: Development 1 el. Single WICdd licLinrBNQ io .41Qfl ype po p ❑ Service-Win' Sin le Zone Lam. , Drill ❑ Re-drill El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply El Multiple Zone❑ Coalbed aI'r r uge Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Ell Blanket fl Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 3K-12L1 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10450' • TVD: 6728' Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1109'FSL,316'FWL,Sec.35,T13N, R9E,UM • ADL 25519,25629 Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1201'FNL,312'FWL,Sec. 1,T12N, R9E, UM 2555,2562 8/9/2010 Total Depth: 9.Acres in Property: 14.Distance to 914'FSL,398'FWL,Sec.35,T13N,R9E,UM 2560 Nearest Property: 9800 4b.Location of Well(State Base Plane Coordinates-NAD 27): • 10.KB Elevation above MSL: • 69 feet 15.Distance to Nearest Well Open Surface:x- 529306 • y- 6008104 • Zone- 4 GL Elevation above MSL: feet to Same Pool: 3K-10,1300 16.Deviated wells: Kickoff depth: 7400 . ft. 17.Maximum Anticipated Pressures in psig(see3 MC 25.035) `I4IbZ foss: ?2z./e• Maximum Hole Angle: 97° deg Downhole:-3468 psig urface:3802 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1750' 8700' 6675' 10450' 6728' 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) 7770 6977 7667 6892 Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 1540#poleset 110' 110' Surface 3941' 9.625" 980 sx AS IV& 3978' 3887' Intermediate 320 sx Class G Production 7720' 7" 300 sx CI G, 175 sx AS 1 7754' 6965' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7472'-7489',7506-7536',7542'-7543',7549'-7550',7556'-7561' 6732'-6746', 6760'-6785', 6790'-6791', 6796'-6796', 6801'-6805' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program mi 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 71.22. I hereby certify that the foregoing is true and correct. Contact J. Ohlinger @ 265-1102 Printed Name V. Cawvey Title Alaska Wells Manager Signature i i -T_(a� jue_y Phon 265-6306 Date 6/30//0 Vry\l Commission Use Only Permit to Drill API Number: / Permit Approval See cover lett er Number: :2(C-0 50- O 29 _2f(>S 6C'- -G Date: i (aa, J J V for other requirements 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: d yoa0 p-' 1' ' Ic_rt Samples req'd: Yes Cl/No , •d log req'd: Yes ❑ No [ Other: -1Z 5O6 /54 Ann 1 TL-1-6••••,..... J� 1C`•••,, H2S measures: Yes [ No ❑ D. -ction.I svy req'd: Yes [� No ❑ O pt4'G�T:6n ;h ct.c- .or..P ,.o( A l U Z e 1", _ , ri re�w,..,��. y�� APPROVED BY THE COMMISSION DATE: R fI t�J A A ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 h3 franc t& ate• •v 25.005(g)) Submit in Duplicate 74. 7-ZZ-/o r` e' 7'- ?/ ` Permit to Drill Summary of Operations KRU 3K-12L1, 3K-12L1-01 Laterals Coiled Tubing Drilling Overview: The 3K-12 injection well is in an area that contains many sealing and highly baffling faults. The scope of the project has included a workover for the 3K-12 motherbore in order to upsize the tubing to allow for CTD access and to subsequently drill two CTD laterals from the motherbore to provide injection support to the 3K-10 - production well and to increase sweep efficiency to the planned 3K-09A CTD production laterals. The CTD laterals will be named 3K-12L1 &3K-12L1-01, and target to add 4800' in the Kuparuk A2 and A3 sands. 4I0,., 'NV"- The sidetrack will utilize a monobore whipstock to conduct a dual string exit through the 3-1/2"tubing and 7" liner. The top of the whipstock is planned for 7400' MD within the straddle that was installed during the RWO, with Packers set at 7240' and 7430 MD. The 3K-12 motherbore completion will be retained by use of a flow through whipstock to maintain injection support in the original area. The first CTD lateral will target the A2 sand and will be drilled across the large southwest to northeast trending fault into the block containing the 3K-10 production well. The second lateral will target the A3 sand and will kick out of the first lateral. It will run parallel to the first lateral so that both A-sands will have sufficient reservoir exposure on that side of the fault. The 3K-12L is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-01 lateral at—8,700' MD. 3K-12L1-01 will be completed with 2-3/8" slotted liner from TD to —7390' MD in the original well bore. Operational Outline Pre-Rig Work • Slickline: Dummy perf gun drift,tag fill ' • Coil: FCO to bottom of perfs - 7,561' MD • • E-line: Run GR/CCL jewelry log/tie-in log(6900' to 7500' RKB; K1 Marker at 6990'). Shoot holes in the 31/2"tubing 7300' -7312' MD, and 7400' -7412' MD. • • E-line: Set HES "FasDrill" composite bridge plug (CBP) @ 7423' MD; CCL tie-in • • Coil: Lay in cement plug from CBP up to the perf holes @ 7300' MD. • • Slickline: Tag TOC and PT to 1500 psi. • Coil: Drill out cement and Composite Bridge plug w/ special clearance bi-center bit.' • Slickline: Run dummy whipstock • E-line: Run slimhole CBL to evaluate cement behind the 3V2" x 7" • • Set BPV, and prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test 2. Set top of whipstock at 7,400' MD • 3. Mill 2.80"window at 7,400'; dual string exit 3-1/2"x 7" 4. 3K-12L1 Sidetrack a. Drill a 2.70"x 3" bi-center lateral to a TD of 10,450' MD . Page 2 of 5 ORIGINAL 6/29/2010 Permit to Drill Summary or Operations Cont. KRU 3K-12L1,3K-12L1-01 b. Run the 2%" slotted liner from TD to 8,700' MD. An aluminum liner top billet will be placed at 8,700' MD. 5. 3K-12L1-01 Sidetrack a. Kick off of the aluminum liner top billet at-8,700' MD PTD b. Drill a 2.70"x 3"bi-center lateral to a TD of 10,450' MD c. Run the 2%" slotted liner from TD to 7,390' MD, inside the 7" casing ;ID- 096 Post-Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system ° 54.4. Mud Program • Chloride-based Biozan brine (8.9 ppg) for milling operations, and chloride-based Flo-Pro mud (-9.80 ppg) for drilling operations. • There is an SSSV installed in 3K-12 so we will not have to load the well with completion fluid to deploy the 2-%" slotted liner. Disposal: • No annular injection on this well. . • Class I I liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 3K-12L1 8,700 10,450 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3K-12L1-01 7,390 10,450 2%", 4.7#, L-80, ST-L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H-40 0 110 1640 670 Surface 9'/8" 36 J-55 0 3,978 3520 2020 Casing 7" 26 J-55 0 7,754 4980 4320 Tubing 3 '/2" 9.3 L-80 0 7,445 10,160 10,530 Page 3 of 6 6/30/2010 OR1rIMAI Permit to Drill Summary of Operations Cont. KRU 3K-12L1,3K-12L1-01 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid . may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure is 3802 psi assuming a gas gradient to surface based on the potential pressure / of an equivalent 13.0 ppg mud weight. • The annular preventer will be tested to 250 psi and 2500 psi. NP Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 3K-12L1 9800' 3K-12L1-01 10225' • Distance to Nearest Well within Pool (toe measured to offset well 3K-10) Lateral Name Distance 3K-12L1 1300' 3K-12L1-01 1300' Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. ' Reservoir Pressure / 3K-12 is an injector in the A-sand interval and had a static bottom hole pressure of 3568 psi (10.4 ppg EMW). 3K-12 has been flowing back for several months to bring the reservoir pressure down. 3K-05 has been shut in since October '09 from injecting water and it measured 4564 ps (13.2 ppg EMW, Feb. '10). Similar pressures / are expected as the laterals are drilled. The most recent static bottom hole pressure reading in 3K-09 was 2065 psi (6.0 ppg EMW). The 3K-09 has been shut-in for 5 months to allow the reservoir pressure to build up high enough to drill without excessive losses and to mitigate high differential pressure at fault crossings. Hazards • Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 9.8 ppg mud system and annular friction will supply enough pressure to overbalance. • Well 3K-09 has 120 ppm H25 as measured on Feb. '09. The maximum H25 level on the 3K pad is 400 • ppm measured on Jan. '09 at 3K-27. All H2S monitoring equipment will be operational. . Page 4 of 6 ORIGIN L 6/29/2010 Permit to Drill Summary of Operations Cont. KRU 3K-12L1,3K-12L1-01 Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by • using 9.80 ppg drilling fluid in combination with annular friction losses and if needed applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 3K-12 does have a SSSV, so the well will not have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off' conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 3568 psi 3568 psi Mud Hydrostatic(9.80 ppg) 3365 psi 3365 psi Annular friction (i.e. ECD) 703 psi 0 psi Mud + ECD Combined 4068 psi 3365 psi (no choke pressure) (overbalanced (underbalanced —500 psi) —203 psi) Target Pressure (11.8 ppg) 4052 psi 4052 psi Choke Pressure Required 0 psi 685 psi to Maintain 11.8 ppg Example: Using the 3K-12 SBHP from June '10 with a reservoir pressure of 3568 psi at 6600 TVDss (10.4 ppg EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 9.80 mud (3365 psi), plus an estimated 703 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 4068 psi BHP (11.85 ppg EMW) and overbalance the reservoir by—500 psi. When circulation is shut down, the mud will be underbalanced to the reservoir pressure. However maintaining —685 psi at surface when the pumps are .. shut down will maintain a constant 11.8 ppg EMW to promote wellbore stability. Page 5 of 6 i'1 6/29/2010 Permit to Drill Summary of Operations Cont. KRU 3K-12L1, 3K-12L1-01 3K-12L1/L1-01 Proposed CTD Sidetrack 16"62#H-40 shoe SLB TRMAXX-CMT @ 1840.84'MD (min ID=2.813") 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG GLM w/SOV @ 7166.40'MD @ 110'MD ssV — �5 i 9-5/8"36#J-55 shoe @ 3978'MD #, Seal Assembly Locator(spaced out 30 Baker 80-40 3-1/2"EUE PBR @ 7226.31 MD(XX"ID) Baker 47B @-7 26#FHL packer @ 7239.69 MD(XX"ID) —i 2.813"XN Nipple @ 7263.34'MD Perfs for Cement 50-40 3 5"El; coded Seal Assembly w/Locator(spaced out 1') - 7300'-7310' Baker F-1 packer @ 7430'MD(XX"ID) KOP @ 7400'MD ',�g Baker 80-40 SBE @ 7433.31'MD fi 'u I3-1/2" monobore whipstock l 3-1/2"w/2.813"Profile 3.5"EUE HES"X"profile nipple @ 7440.33'MD Perfs for Cement 3-1/2"EUE Box up Shear Out w/LEG Guide @ 7443.93'MD z ' 3K-12L1 WP01:TD-10,450' . ��-�� iA-sand perfs ---------------- -------- - 7472'-7561' _ I - — - Top of Billet-8700' 3K-12L1-01 WP01:TD-10,450' 7"26#J-55 shoe @ 7754'MD l■ Page 6 of 6 OR1G1I\! iL 6/29/2010 ✓ Coiled Tubing Drilling 6/29/2010 ConocoPhillip5 '/a-Mile Sundry–Cement Evaluation for Injection Permit Assessment of Cement and Wells With-in One-Quarter Mile for Application to extend the Water Injection Well: 3K-12L1 and 3K-12L1-01 Rig: Nabors CDR-2AC Well 3K-12 is currently an injector completed in the A-sand with 7" liner and 3-1/2"tubing. The CTD laterals will be named 3K-12L1 & 3K-12L1-01. It will target to add a dual lateral for A2 & A3 each to provide injection support in an adjacent fault block to the northwest, and maintain ' injection to existing wellbore perfs. 3K-12 was recently wore—over with the Nordic 3 rig to pull out the 2-7/8"tubing and replaced it with 3-1/2"tubing. The sidetrack will utilize a monobore whipstock to conduct a dual string exit through the 3-1/2"tubing and 7" liner. The top of the whipstock is planned for 7400' MD within the straddle that was installed during the RWO, with Packers set at 7240' and 7430 MD. The annulus created with the straddle will be cement squeezed before the window is milled. The completions will consist of a 23/8" slotted liner and tied into the straddle-packer completion. The original perforations in the 7" liner will be left open to maintain parent bore injection post- drill. The CBL log ran on 11/17/86 in the 7" liner shows excellent cement coverage for extending 3K-12. 3K-09 3K-09BL2 is planned to be 1,238' away at a MD of 9,750' in 3K-12L1. 3K-09BL2-01 is planned to be 1,203' away at a MD of 9,725' in 3K-12L1. Well 3K-09B+is currently a producer completed in the A3 and A2 sands through the 7" production casing with 3-1/2"tubing to surface. Five CTD sidetracks (3K-09B, 3K-09BL1, 3K-09BL1-01, 3K-09BL2, and 3K-09BL2-01)were drilled in the A3 and A2-sands to provide off-take in two dead segments to the north of 3K-09A, and replace the existing production near the (cemented)mother-bore, and improve sweep efficiency across two baffling fault zones south of the parent well. A cement plug was placed across the existing perforations, and a 2.80"pilot hole was drilled on the high-side of the 7" casing to a depth of approximately 7,250' MD. Two whipstocks were set at 7,200' MD and 7,150 for high-side casing exits. All five laterals were lined with 2-3/8" slotted liner and completed within the 7" liner. 3K-10 3K-10 is planned to be 1,081' away at a MD of 10,425' in 3K-12L1. 3K-11 is a producer with a"normal"Ann-Comm status, and as of 12/09 passed its last MITOA, TIFL, T-POT, and IC-POT. The well was originally completed 10/86 with 7" 26# J-55 casing with TD at 7,274' MD and 2-7/8"tubing from 6,931' MD to surface. The well is currently producing from the A-sand perforations from 7,009' MD to 7,091' MD. The bond log(Gearhart CBL– 11/16/86) shows solid cement from 7173' (bottom of log)to 5900' MD. James Ohlinger 1/4-Mile Sundry—Cement Evaluation Page 1 of 2 ORIGINAL Coiled Tubing Drilling 6/29/2010 COnocOPhillips 1/4-Mile Sundry—Cement Evaluation for Injection Permit 3K-11 3K-11 is planned to be 900' away at a MD of 8,750' in 3K-12L1. 3K-11 is a producer with IA x OA communication; however a revised waiver was received on 7/15/09. The well was originally completed 11/05/86 with 7"26#J-55 casing with TD at 7838' MD and 2-7/8"tubing from 7478' MD to surface. The well is currently producing from the A- sand perforations from 7544' MD to 7642' MD. The bond log (Gearhart CBL— 11/16/86) shows solid cement from 7730' (bottom of log)to 6400' MD. James Ohlinger '/-Mile R Gliek‘A-uitIon Page 2 of 2 ConocoPh i I I i s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K-12 3K-12L1 Plan: 3K-12L1_wp01 Standard Planning Report 16 June, 2010 rr BAKER HUGHES ORIGINAL ConocoPhillips Fa it ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-12 @ 69.00ft(3K-12) Site: Kuparuk 3K Pad North Reference: True Well: 3K-12 Survey Calculation Method: Minimum Curvature Wellbore: 3K-12L1 Design: 3K-12L1_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70°26'2.781 N From: Map Easting: 529,306.18ft Longitude: 149°45'39.930 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well 3K-12 'Well Position +N/-S 0.00 ft Northing: 6,008,103.63 ft Latitude: 70°25'59.583 N +E/-W 0.00 ft Easting: 529,305.72 ft • Longitude: 149°45'39.981 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3K-12L1 •Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2009 8/1/2010 17.13 79.87 57,396 Design 3K-12L1_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 0.00 0.00 0.00 350.00 1 6/16/2010 2:48 27PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL �-' ConocoPhillips Fa'ii ConocoPhillips Planning Report BAKER s Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-12 @ 69.00ft(3K-12) Site: Kuparuk 3K Pad North Reference: True Well: 3K-12 Survey Calculation Method: Minimum Curvature Welibore: 3K-12L1 Design: 3K-12L1_wp01 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 7,400.00 34.57 160.11 6,603.72 -2,310.61 522.45 0.00 0.00 0.00 0.00 7,420.00 36.37 160.11 6,620.01 -2,321.52 526.40 9.00 9.00 0.00 0.00 7,440.00 44.37 160.11 6,635.24 -2,333.69 530.81 40.00 40.00 0.00 0.00 7,470.00 55.02 167.40 6,654.63 -2,355.63 537.08 40.00 35.50 24.30 30.00 r 7,600.04 86.00 212.64 6,699.57 -2,470.21 511.96 40.00 23.82 34.79 64.00 ■ 7,800.04 89.31 292.67 6,709.41 -2,524.85 336.39 40.00 1.65 40.01 90.00 7,950.04 90.27 310.64 6,709.98 -2,446.45 209.23 12.00 0.64 11.98 87.00 8,200.04 93.97 340.44 6,700.52 -2,242.86 69.43 12.00 1.48 11.92 82.50 8,350.04 93.78 322.40 6,690.29 -2,111.99 -1.87 12.00 -0.13 -12.03 270.00 8,450.04 97.59 333.84 6,680.36 -2,027.67 -54.36 12.00 3.81 11.44 71.00 8,600.04 90.05 317.44 6,670.31 -1,904.68 -138.56 12.00 -5.02 -10.93 246.00 8,675.04 85.98 325.47 6,672.90 -1,846.12 -185.22 12.00 -5.43 10.71 117.00 8,825.04 86.18 343.51 6,683.24 -1,711.62 -249.39 12.00 0.13 12.03 90.00 8,900.04 85.60 334.51 6,688.63 -1,641.85 -276.16 12.00 -0.77 -12.01 266.00 9,000.04 85.70 346.54 6,696.25 -1,548.02 -309.34 12.00 0.10 12.03 90.00 9,175.04 83.12 7.49 6,713.49 -1,375.09 -318.42 12.00 -1.47 11.97 98.00 9,275.04 90.07 17.29 6,719.44 -1,277.78 -297.01 12.00 6.95 9.81 55.00 9,475.04 90.47 41.29 6,718.48 -1,104.62 -199.88 12.00 0.20 12.00 89.00 9,875.04 90.31 353.29 6,715.57 -733.78 -84.45 12.00 -0.04 -12.00 270.00 10,225.04 88.03 35.23 6,720.87 -402.14 -0.19 12.00 -0.65 11.98 93.30 10,450.00 88.24 8.23 6,728.33 -195.21 82.28 12.00 0.10 -12.01 270.00 6/16/2010 2:48:27PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ♦-' ConocoPhillips Vaal ConocoPhillips Planning Report BAKER Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-12 @ 69.00ft(3K-12) Site: Kuparuk 3K Pad North Reference: True Well: 3K-12 Survey Calculation Method: Minimum Curvature Wellbore: 3K-12L1 Design: 3K-12L1_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-1N Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) 0100ft) (°) (ft) (ft) 7,400.00 34.57 160.11 6,603.72 -2,310.61 522.45 -2,366.23 0.00 0.00 6,005,795.32 529,837.20 TIP/KOP 3K-12 7,420.00 36.37 160.11 6,620.01 -2,321.52 526.40 -2,377.66 9.00 0.00 6,005,784.43 529,841.19 End of DLS 9 7,440.00 44.37 160.11 6,635.24 -2,333.69 530.81 -2,390.41 40.00 0.00 6,005,772.27 529,845.64 3 7,470.00 55.02 167.40 6,654.63 -2,355.63 537.08 -2,413.10 40.00 30.00 6,005,750.36 529,852.00 4 7,600.04 86.00 212.64 6,699.57 -2,470.21 511.96 -2,521.59 40.00 64.00 6,005,635.69 529,827.33 5 7,800.04 89.31 292.67 6,709.41 -2,524.85 336.39 -2,544.91 40.00 90.00 6,005,580.37 529,651.99 End of DLS 40 7,950.04 90.27 310.64 6,709.98 -2,446.45 209.23 -2,445.62 12.00 87.00 6,005,658.26 529,524.54 7 8,200.04 93.97 340.44 6,700.52 -2,242.86 69.43 -2,220.84 12.00 82.50 6,005,861.28 529,383.95 8 8,350.04 93.78 322.40 6,690.29 -2,111.99 -1.87 -2,079.58 12.00 -90.00 6,005,991.86 529,312.14 9 8,450.04 97.59 333.84 6,680.36 -2,027.67 -54.36 -1,987.42 12.00 71.00 6,006,075.97 529,259.33 10 8,600.04 90.05 317.44 6,670.31 -1,904.68 -138.56 -1,851.69 12.00 -114.00 6,006,198.60 529,174.66 11 8,675.04 85.98 325.47 6,672.90 -1,846.12 -185.22 -1,785.91 12.00 117.00 6,006,256.98 529,127.77 12 8,825.04 86.18 343.51 6,683.24 -1,711.62 -249.39 -1,642.31 12.00 90.00 6,006,391.21 529,063.08 13 8,900.04 85.60 334.51 6,688.63 -1,641.85 -276.16 -1,568.95 12.00 -94.00 6,006,460.87 529,036.04 14 9,000.04 85.70 346.54 6,696.25 -1,548.02 -309.34 -1,470.78 12.00 90.00 6,006,554.56 529,002.50 15 9,175.04 83.12 7.49 6,713.49 -1,375.09 -318.42 -1,298.91 12.00 98.00 6,006,727.44 528,992.73 16 9,275.04 90.07 17.29 6,719.44 -1,277.78 -297.01 -1,206.79 12.00 55.00 6,006,824.82 529,013.76 17 9,475.04 90.47 41.29 6,718.48 -1,104.62 -199.88 -1,053.13 12.00 89.00 6,006,998.34 529,110.20 18 9,875.04 90.31 353.29 6,715.57 -733.78 -84.45 -707.97 12.00 -90.00 6,007,369.60 529,224.16 19 10,225.04 88.03 35.23 6,720.87 -402.14 -0.19 -396.00 12.00 93.30 6,007,701.53 529,307.11 20 10,450.00 88.24 8.23 6,728.33 -195.21 82.28 -206.53 12.00 -90.00 6,007,908.76 529,388.76 TD I 6/16/2010 2.48:27PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ►- ConocoPhillips i ConocoPhslhpss Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-12 @ 69.00ft(3K-12) Site: Kuparuk 3K Pad North Reference: True Well: 3K-12 Survey Calculation Method: Minimum Curvature Welibore: 3K-12L1 Design: 3K-12L1_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3K-12L1 t8 0.00 0.00 6,716.00 -735.29 -84.01 6,007,368.08 529,224.61 70°25'52.351 N 149°45'42.445 W -plan hits target center -Point 3K-12L1 t3 0.00 0.00 6,691.00 -2,119.77 3.55 6,005,984.10 529,317.59 70°25'38.735 N 149°45 39.877 W -plan hits target center -Point 3K-12L1 t2 0.00 0.00 6,710.00 -2,449.62 213.28 6,005,655.10 529,528.60 70°25'35.491 N 149°45'33.724 W -plan hits target center -Point 3K-12L1 t5 0.00 0.00 6,684.00 -1,699.71 -253.83 6,006,403.10 529,058.59 70°25'42.866 N 149°45'47.427 W -plan hits target center -Point 3K-12L1 t9 0.00 0.00 6,728.00 -194.90 82.15 6,007,909.07 529,388.62 70°25'57.666 N 149°45'37.570 W -plan hits target center -Circle(radius 1,350.00) 3K-12L1 Fault 2 0.00 0.00 0.00 -2,357.83 -239.42 6,005,745.11 529,075.58 70°25'36.394 N 149°45'47.004 W -plan misses target center by 6647.70ft at 7400.00ft MD(6603.72 TVD,-2310.61 N,522.45 E) -Polygon Point 1 0.00 -2,357.83 -239.42 6,005,745.11 529,075.58 Point 2 0.00 -2,119.75 3.53 6,005,984.12 529,317.57 Point 3 0.00 -1,908.59 226.37 6,006,196.14 529,539.56 Point 4 0.00 -2,119.75 3.53 6,005,984.12 529,317.57 3K-12L1 t4 0.00 0.00 6,670.00 -1,905.19 -137.63 6,006,198.10 529,175.59 70°25'40.846 N 149°45 44.018 W -plan hits target center -Circle(radius 1,350.00) 3K-12L1,L1-01 Fault 0.00 0.00 0.00 -1,892.85 -476.63 6,006,209.11 528,836.58 70°25'40.967 N 149°45'53.963 W -plan misses target center by 6678.88ft at 8600.04ft MD(6670.31 TVD,-1904.68 N,-138.56 E) -Polygon Point 1 0.00 -1,892.85 -476.63 6,006,209.11 528,836.58 Point 2 0.00 -1,699.69 -253.86 6,006,403.13 529,058.57 Point 3 0.00 -1,545.58 -20.24 6,006,558.14 529,291.56 Point4 0.00 -1,699.69 -253.86 6,006,403.13 529,058.57 3K-12L1 t6 0.00 0.00 6,696.00 -1,546.47 -310.24 6,006,556.10 529,001.59 70°25'44.373 N 149°45 49.082 W -plan hits target center -Point 3K-12L1 Fault 1 0.00 0.00 0.00 -2,441.02 -192.75 6,005,662.11 529,122.58 70°25'35.576 N 149°45 45.635 W -plan misses target center by 6643.625 at 7400.005 MD(6603.72 TVD,-2310.61 N,522.45 E) -Polygon Point 1 0.00 -2,441.02 -192.75 6,005,662.11 529,122.58 Point 2 0.00 -2,205.95 54.19 6,005,898.13 529,368.57 Point3 0.00 -1,961.88 299.16 6,006,143.14 529,612.56 Point 4 0.00 -2,205.95 54.19 6,005,898.13 529,368.57 3K-12L1,L1-01 Polyg 0.00 0.00 0.00 -2,264.77 507.05 6,005,841.09 529,821.61 70°25'37.309 N 149°45'25.107 W -plan misses target center by 6603.905 at 7400.005 MD(6603.72 TVD,-2310.61 N,522.45 E) -Polygon Point 1 0.00 -2,264.77 507.05 6,005,841.09 529,821.61 Point 2 0.00 -2,261.44 680.08 6,005,845.10 529,994.61 Point 3 0.00 -2,699.12 585.37 6,005,407.10 529,901.63 Point 4 0.00 -2,707.76 233.30 6,005,397.08 529,549.63 Point 5 0.00 -2,424.68 -37.63 6,005,679.06 529,277.62 Point6 0.00 -1,747.17 -406.04 6,006,355.05 528,906.58 Point 7 0.00 -1,421.83 -484.79 6,006,680.05 528,826.57 Point 8 0.00 -1,034.00 -430.28 6,007,068.05 528,879.55 6/16/2010 2:48:27PM 0RIGNAL COMPASS 2003.16 Build 69 ConocoPhillips ra,►111 ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-12 @ 69.00ft(3K-12) Site Kuparuk 3K Pad North Reference: True Well: 3K-12 Survey Calculation Method: Minimum Curvature Welibore: 3K-12L1 Design: 3K-12L1_wp01 F,7 .....,.......1.4.91.1.4..........t."....4....^,,,.d° ,,aws+ . . ,.,rr ..... 1"te.. f✓.n,■ Point 9 0.00 175.65 -50.55 6,008,279.06 529,254.48 Point 10 0.00 54.09 350.02 6,008,159.09 529,655.49 Point 11 0.00 -1,224.45 -61.98 6,006,879.07 529,248.55 Point 12 0.00 -1,565.49 -61.30 6,006,538.07 529,250.57 Point 13 0.00 -2,277.12 337.98 6,005,828.08 529,652.61 Point 14 0.00 -2,264.77 507.05 6,005,841.09 529,821.61 3K-12L1 t7 0.00 0.00 6,719.00 -1,279.50 -297.18 6,006,823.10 529,013.60 70°25'46.999 N 149°45'48.700 W -plan hits target center -Point 3K-12L1 t1 0.00 0.00 6,701.00 -2,489.74 494.16 6,005,616.10 529,809.61 70°25'35.097 N 149°45'25.485 W -plan misses target center by 2.73ft at 7624.85ft MD(6701.29 TVD,-2489.79 N,496.87 E) -Circle(radius 1,350.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 10,450.00 6,728.33 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) (ft) (ft) Comment 7,400.00 6,603.72 -2,310.61 522.45 TIP/KOP 3K-12 7,420.00 6,620.01 -2,321.52 526.40 End of DLS 9 7,440.00 6,635.24 -2,333.69 530.81 3 7,470.00 6,654.63 -2,355.63 537.08 4 7,600.04 6,699.57 -2,470.21 511.96 5 7,800.04 6,709.41 -2,524.85 336.39 End of DLS 40 7,950.04 6,709.98 -2,446.45 209.23 7 8,200.04 6,700.52 -2,242.86 69.43 8 8,350.04 6,690.29 -2,111.99 -1.87 9 8,450.04 6,680.36 -2,027.67 -54.36 10 8,600.04 6,670.31 -1,904.68 -138.56 11 8,675.04 6,672.90 -1,846.12 -185.22 12 1 8,825.04 6,683.24 -1,711.62 -249.39 13 8,900.04 6,688.63 -1,641.85 -276.16 14 9,000.04 6,696.25 -1,548.02 -309.34 15 9,175.04 6,713.49 -1,375.09 -318.42 16 9,275.04 6,719.44 -1,277.78 -297.01 17 9,475.04 6,718.48 -1,104.62 -199.88 18 9,875.04 6,715.57 -733.78 -84.45 19 10,225.04 6,720.87 -402.14 -0.19 20 10,450.00 6,728.33 -195.21 82.28 TD 6/16/2010 2:48.27PM Page 6 COMPASS 2003.16 Build 69 RIG1NAL • MO 's § 's .< '8 ° 8 N a 8 a Q ,e 8 ° S 8 ° N a, m M ' g X ' 1 _' � - C N - hHI W ° Dili LE rd w&.; —414111114111111111011 ,, s 8 8 g N° p co g .0 $ O si•m o r O K 3 d. g g g $ g .g O. 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A � ■ _ ■ _ _ g ry, ■ wil- ■_ ■■■ 1 8 " 4 4 C e S 8 Mai 00Z) (+)1411°1\110 n�S v 4 i 0 8 ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator r�i J • above BHA rams — ��� i�i�� i 1 Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) BUJ LJ L Kill � . 1r 8 Blind/Shear 2" Pipe/Slip(CT) Choke 2 t Swab Valves JIIIL Wing Valves C4,C-i' Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union ORIGINAL TRANSMITTAL LETTER CHECKLIST WELL NAME /E l'( 3K- 12_ 1- 1 PTD# C Development /Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (,& POOL: K -1--r2 -,) t4 - I 1 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing / well 1.‹R tC 3K- /Z_ �/ (If last two digits in Permit No. /i 3 'j 6 S,API No. 50- 1/6 -e. 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 perforate and 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: 1/11/2008 �I1. I O) O to• .N 0 ❑ . o co ▪ Q Q a m 0 c o p 'co c C 7 a C E o 0 0) co c 2 •° 0 _ a) O o rn : N _ o C E m N 5 a) '3 �', L 0 E oo = ° w. N O 0 'O O "O. a) 3 0 L Co O 2 0 Co O U T '0 0 c 3 `0) U L E 5 m o m E o _o _ _- a` M 3 -0 a cn o. m n °c) 3 p Y (n = m L o a U) 2 0 o c 3 c 3 o ai ao -a y 0 U) o Z -° `) C o L O 0) m v, 0 • 0 o in - -o ` °- 3 -o M a o O @ Y _ 0 N w > C 0) i M 7 O 0 N , tT O C O 'j O _ -O -° N 0- a c O • ,� m m c a m a .3 �' • J U) ` m • U) a > °. 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