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212-081
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. QZ t og - 0 gj Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: Xyscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 1 /s/ yvir Project Proofing BY: derMDate: r g / /s/ 14 1 Scanning Preparation 1 x 30 = 30 + 1 =TOTAL PAGESI (Count does not include cover s eet) BY: Maria Date: IS �� /s/ Production Scanning Stage 1 Page Count from Scanned File: LJ'ca (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: kS NO BY: aria� Date: 1111 U 11f /s/ P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc O I 2 (aa 00 m CO CO a CC / /�m O cif Z ❑ aa)) } } } M U Y3 �` cn cn CO 'w u) co aa) I oZ E1Uit)i y C Nco Lu g o O JN O O U U m Q En O ,.� Z 1 U2 0 ❑ > E v OaO o + ° o a p 11 a U m 1, Q 1, No 'O a) 2 2 1 I, ! CO 0 j 11 N N N N N U U J li CL m J N N N 1N N 0 0 0 1, U O a) V V V V Q J N N N N co• Z n n n c Q Q N j ro o d Z /Z C C C C C Q x x ° a) a) a) a) E Ca y a OUiO O O O O o }�} } ❑ QC . U m Q) O m a'0 o 0 0 0 ii d j ° CO LO LO `nCO`na« a :° m a U I �,rn rn ) rn rn Ey E p m o Wa 4!IL) (LO II))i C)i el co Z co LL OU i Cl) n N. N. N. on _ W Zm N ° J a) co °) a U 8 q 1 E .3 E co Z ' ° ._ 0 Q 10 / aN 7 rZo rn JaC • =m oU UO O � O O O c i c OIZU U U (M p J 2 n y N y I a a) cn al 0 22 ti E a J 0 N u) LO Ill Q v. /Z J a >- >- } ICC Tr fi r N °' II I— N N Z O > fa C 2 d N E I ' 11 11 W / Nn C ~ E II I CO Q c N C 11 I �i ICC 0 Y o p U Q) Q a /ZI cn w Y o m O ' C 0 z o > > > > 1 a) U 0 .N .V) .co _N Z b 2 o E ! J N V) N N C C C C C irbf a) a) O O O O p y co } } } lb y y 0) CO 3 c o 0 Z O / r J a0 W CO c m` �,) E fD 5 O Ca N -o tri 0 N < ZO W ❑ Z N a) W o N 0 Q O m .+ a a) o E > o ce z 2 u € 4 LL ' co m o N co O rx H m 1 a) Q ❑ O v 5 oy w � Q o C - ' c °) re Z w 0 2 U o 2 .� 0 .2 d 1° J 0 Et a 0 E a Q y 0 a E p C7 H m rn Q O o CO CO a a) a o o aa) o 0 a ! 0 i 3 .°� 0 H W J J J d' ? 0 a 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 13.Well Status. Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25 105 20AAC 25.110 Development ❑✓ • 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 July 2,2012 212-081 / 3.Address: 6.Date Spudded Z°I2.r 13.API Number P.O. Box 100360,Anchorage,AK 99510-0360 Jun,28-2012 1 �'� 50-103-20112-60 - 4a.Location of Well(Governmental Section): 7.Date TD Reached 14.Well Name and Number. Surface: 94'FNL,94'FEL,Sec. 11,T1ON, RO8E,UM • July 1,2012 • 2K-14AL1 Top of Productive Horizon 8. KB(ft above MSL): 154'RKB 15.Field/Pool(s) 1345'FNL, 1435'FWL,Sec. 11,T1ON,RO8E, UM GL(ft above MSL): 118.5'AMSL - Kuparuk River Field Total Depth 9.Plug Back Depth(MD+TVD): 330'FSL,556'FNL,Sec.2,T1ON, ROBE,UM . 9850'MD/6184'ND • Kuparuk River Oil Pool • 4b Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+ND) 16 Property Designation. Surface: x-498310 • y- 5938210' Zone-4 _ • 9850'MD/6184'ND • ADL 25588 TPI: x-494561 y- 5936961 Zone-4 11 SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-493681 y- 5938636 Zone-4 1811'MD/1805'ND 2674 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) 1400'MD/1400'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/ND GR/Res 7907'MD/6281'ND 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND - HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 110 sx AS II 9.625" 36# J-55 35' 3173' 35' 2935' 12.25" 1000 sx AS III,500 sx Class G 7" 26# J-55 1796' 8147' r 1791' 6560' 8.5" 225 sx Class G 4.5" 11.6" L-80 7534' 7805' 6059' 6262' 6" 91 sx Class G 2.375" 4.7# L-80 7702' 9850' 6190' 6184' 3" slotted liner 24 Open to production or injection? Yes ❑ 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" 7578' 7534'MD/6059'ND slotted liner 7703'-9848'MD 6190'-6184'ND i COMPLE WNL RECEIVED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r; . l',, 7r.,rioll JUL 16 2012 . .—, AOGCC 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL 'GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press psi 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS JUL 16 201126/1 011 , /1 Form 10-407 Revised 12/2009 V 1/F CONTINUED ON REVERSE Submit original only 1'iTia I) „- '.4,. , fi, ''''G 28 GEOLOGIC MARKERS(List all formations and ma..._.s encountered) 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ 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 1400' 1400' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A4 9744' 6210' Kuparuk A5 9817' 6193' N/A Formation at total depth: Kuparuk A5 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Gary Eller @ 263-4172 Printed Na L antt Title: CTD Supervisor Signature OI L- Phone 263-4021 Date 7"13•"12., 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. 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IF t 0 C CC 0 N (O (O N- O U) 00 V U) m m CD N- O N V o CO3- 0/ 01 ,- U) m r (O O M N CD N N- 04) 7, w R N (O .- M n CO N U) CO U) U) N M N .- N M N- I-- N 07 a- m O m I` co V co CO M R L 0 -0 MO i V N N: rmN oi O O M VOO N N NNM UCON CCOOO N o7VU) CD NV CON O Ct N N N N N N N N N N N N N M M M M M M M M M V V V V V V V U) U) v 0 3 2 Z y O +� 1 v g 1 v q v v q v v v v v Y Y '1 NiY I V 't 1' Y Y Y Y Y 4 O C 0 C.) — a a CO V V CO U) U) _ V N CO CO _U) CO 0 O CO M CO 0 N _ V a N U) (0 N- N co N- V m U) M V CO N a O N- n co I- a V 0 n N V N n V n CO V O V .— h 5N N M V m m m M N 6 W O V N (0 C]V m N I� UI coCD U) N a CO M 6 O N. V m M O N 0 NN 6 O O M m a ID CO O M Cco F Cn V 4 Y P7 C7 .? C? N N N .- N N N N 2 + CO N (D r V r N CD m CD m C0 CD M U) C0 NON N M M U) 7 CD N .4 M N U) m a0 m 0 m m4 co n m I. (”) co. CO M s- s- m O m N4 N CO O co O N- m m M N o O O m r n 1. ti N m O mJ W 6 V N N N N hO o m m 60) co WCCOmr N- r ti r ti N- CO CO m CD N- n n N- r r N- n I-- n CD CO O 0 = 0 00000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 (C) (O co- CO 6 co- CO Co (O CO (O (O co (o (O (O tO (O (O 6 (o CO (O co (O (O (o CO (O CO (o i '.. CO N CO N V 0- N (D m CO m 03 CA M U) 00 a U) N a M M IO V CO N V M U) m cO m o m m V U) N- 6 n co (D CO co m o m co V Cu CO O m O N m m r m N V V N N V U( U) 6 V N Oi oo [D O m O U] Ui V V 6 N O UM M M M M M M M M M M M M M M M M M N Na N N N N N ND! N N N C t = N N N N N N N N N N N N N N N N a a N N N N N N N N N a N N N — CO CO CO CO CO CO CO CO (O CD CD CO (O (O CO CO CO CO CO CO CO CO CO CO CO (D CO CO CD CO CO CO i CO R C V 01 1.-- .0. 01 01 0- 0- 01N. 03 O N U) 01 .4 (OVm m N m CD N 1a N ONO Q ❑ -O 0101V (0N01 o- mf- MmUDNtD ` ) NNrm (OO (OmM coo VM N- U) CO oU) (NUOmmrV O V M N V O O O O M O m N ar V M NM S 0M 0 m NO N N N IiY c) d ..1 `— M (7M M MM MM M MMM N ; N LE Ci- Y Y U g_ g_ •_ O COR V U) m V M O CO V U) U) O 03 (O CO CO CO 0 CO V O V N 0) a V n N CO 0 - C CO 6 N O (0 m CO CO CO V t` N M CO M tO V V m m N m O U) N \ , 0Nmm m 0VV0m0mmmU Y Y N N N C .. 0) 0) 0 mm mmm OC0C0mmmO) O) am 00) m m m0) ci 05 Pelil a co"53- 0 V N N r O N V I` m m n U) M O N c0 r N M r CO CD CO O O m m N U) coO O V U) M M V V V N CO CO N M U) V V V N V V co co N V V N M co co '7 N N ( T _ O 6 0 0 0 0 tJ lJ O O O O O O O O O O O 6 o Ui Ui U1 C Ui U7 U) Ui Ui Ci N C .. d Q CD 5 V N. O M CO m N U) CD a- V N O M CO m N U) CO 0 M CO CO N U) c0 V I- r' CR 0 C >) n O co. CO m a m m 0 0 0 c- •-• e- N a N N M M M V V: V V U) U) U) CD CO CO Cd d d a) Q1• c" D COO CO COCOCO W m m m m O) P co m m m a 0 m m CC ) C 0 0 m m m V 0a- (▪ 5550 co ` R a) Ai 1 cc I CO 0 O O N { 0 co 4 C vi cC Q 0 U m 2 0 2 o w H TM M M M M 0 N W Z 000003 1 co m2 0- N. NNV(0 M V.2 M N N , T s ✓ V --' V $o m W 0)) aa) o (p a) 07 N N N N N M O 0 7 "O O O f6 2 ° N. O O V 0 O O d co o O ao O V O 4 4Y Q p ai 0 t- (O (O 0 CO LO C6 NU gE CO W r ¢ _O o (O LO v CO N W GO co N. .c- . C Q a V f: a) N O O N N N I..' W d C CO r r r n coO C13 41 2 co a) a) m m m C) W Ti- v v v v o c fl. C a o 49 {y a) d O N O M € TN 2 III M N. V O O IC N V , O M L C p,L a) co (a in co co Q Z 01 p 0f O O co- m m os l0 V � 2 0 0 O W aM) aM) O) N 112. () a V 0) C ' Z a a f1 a V] a) d C w 6,1 O) > C a) ` V 01 a7 C O '.- Q' T R o v ti co(ov a) .. U m y�• N is �,.L ..c yea .G 03 W. M 0 N. o_ ai C 0 0 o) o CO N m CO L7 ; M 2 m 2 N t CO CO M M C Z M 1 ✓ a) O = O) N { N O r V O CA c- U) ❑= 0 0 0 O o (O (D co-O (D co' (Ma 1.-- a m m I- N. N-- O O N V ( C �,- N N N N O C (O (O (O O O CO (6 Y - co Q LI C IC; c° � O a) a) a (� O_iii) co V V M M C) N N Y 0) 0 M M M M M M r/�i J i •Yi N .0 W N 4 Y Y ..... 2 `- `- O (6 RN N. C) N M M i C d d V CO M o? U) (a (!) O O 3 Y Y Y C°„r m o _co 0 o o g O U Y Y N N N 0- 10 V' V � V N N. O O 0 T. N N M N O O C C .. `1 ❑ O CO CO a) ,- O .,-- AO N V _ 0 C T r r co co ^ d N .0 al co m of a) ai cc 0 Uoo g .,.° a) ; ) U n en s s ❑ UJ ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2K-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/22/2012 12:00:00 PM Rig Release: 7/3/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/20/2012 24 hr Summary Released from 2M-01. Start rig maintenance 10:00 00:00 14.00 MIRU MOVE SVRG P Rig maintenance-replacing BOP stack ***7 hours billable rig repair*** 06/21/2012 Move Rig from 2M pad to 2K-14.Spot rig NU BOP's 00:00 11:00 11.00 MIRU MOVE SVRG P Rig maintenance-replacing BOP stack 11:00 18:00 7.00 MIRU MOVE MOB P Move rig from 2M pad to 2K-14 18:00 21:00 3.00 MIRU MOVE MOB P Spot rig onto well 21:00 00:00 3.00 MIRU WHDBO NUND P NU BOP's 06/22/2012 Complete BOPE maint.Start/Complete BOPE testing.Test waived by Matt Herrera 00:00 12:00 12.00 MIRU WHDBO SVRG P Rig maintenance-replace BOP stack. 12:00 00:00 12.00 MIRU WHDBO BOPE P Accept rig at noon. BOPE equipment testing.Witness of test waived by Matt Herrera. 06/23/2012 Stab CT, Perform Slack Management,Cut 20'. E-line found at 10'.MU UQC, RIH with dummy whipstock drift, tag at 7780'. Perform CCL, POOH 00:00 05:00 5.00 0 0 SLOT WELLPF CTOP P MU inner reel iron and psi bulkhead inside reel 05:00 06:30 1.50 0 0 SLOT WELLPF CTOP P Prepare to stab CT 06:30 07:30 1.00 0 0 SLOT WELLPF BOPE P Pull BPV 07:30 13:12 5.70 0 0 SLOT WELLPF CTOP P Stab coil,fill coil, pressure test coil, inner reel iron, stripper,tiger tank line. Pump slack,cut 10'to find wire,cut total of 20'. install CTC,pull test to 35K, install UQC,pressure test to 4000 psi. 13:12 13:30 0.30 0 0 PROD1 RPEQP1SFTY P PJSM for PU BHA 13:30 14:30 1.00 0 0 PROD1 RPEQP1PULD P MU Dummy Whipstock BHA 14:30 16:30 2.00 0 0 PROD1 RPEQP1 EQRP T Tool test failed,trouble shoot short 16:30 18:30 2.00 0 7,546 PROD1 RPEQP1TRIP P Circulate forward, RIH 18:30 19:00 0.50 7,579 7,580 PROD1 RPEQP1DLOG P Tie in depth to K1,Correct depth+1' 19:00 19:30 0.50 7,580 7,780 PROD1 RPEQP1TRIP P Tag 7780'. PU for CCL 33K PUW 19:30 20:00 0.50 7,650 7,750 PROD1 RPEQP1 DLOG P Log CCL,4-1/2"collar at 7720'as it should have been. Page 1 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:15 2.25 7,750 0 PROD1 RPEQP1TRIP P POOH, Injector making popping noises.TP inspect.Assures it is new gripper blocks. 22:15 22:30 0.25 0 0 PROD1 RPEQP1SFTY P At surface, PJSM 22:30 00:00 1.50 0 0 PROD1 RPEQP1PULD P LD BHA,Service injector head 06/24/2012 Set whipstock HS 7735'TOWS. PU/MU/RIH first run milling BHA.Mill window down to 7742'. PU/MU/RIH second run milling BHA. Continue milling window. 00:00 01:00 1.00 0 0 PROD1 RPEQP1PULD P PU BHA#2(Whipstock) 01:00 03:00 2.00 75 1,000 PROD1 RPEQP1TRIP P RIH, 03:00 03:30 0.50 7,580 7,580 PROD1 RPEQPI DLOG P Tie in depth to K1. Popping noise on injector head smoothing out. RIH. -15'correction 03:30 03:48 0.30 7,580 7,748 PROD1 RPEQP1TRIP P Close EDC, RIH to 7748' to set WS, 03:48 04:06 0.30 7,748 7,748 PROD1 RPEQP1WPST P PU string weight,Set WS highside at 7735'TOWS.3000psi. 04:06 06:06 2.00 7,748 0 PROD1 RPEQP1TRIP P POOH 06:06 06:42 0.60 0 0 PROD1 RPEQP1PULD P lay down whipstock setting tools 06:42 07:12 0.50 0 0 PROD1 WHPST PULD P PU 2.80"DSM,2.80"string reamer, 0.6 deg motor and 10'pup joint 07:12 09:12 2.00 0 7,600 PROD1 WHPST TRIP P RIH 09:12 09:30 0.30 7,600 7,641 PROD1 WHPST DLOG P Tie-in to K1,-15'correction 09:30 14:42 5.20 7,738 7,743 PROD1 WHPST MILL P 35K PUW, 15K RIW,Tag whipstock at 7738', 1.6 BPM,3120 CTP, Milling at 1 FPH,starting at 7737.6' 14:42 15:36 0.90 7,743 7,730 PROD1 WHPST REAM P Ream up and down three times. Dry drift clean. 15:36 17:30 1.90 7,730 0 PROD1 WHPST TRIP P POOH 17:30 19:30 2.00 0 0 PROD1 WHPST PULD P Lay down motor and mills, PU 1.2 deg Weatherford motor with window mill&string reamer. 19:30 21:45 2.25 76 7,580 PROD1 WHPST TRIP P RIH 21:45 22:00 0.25 7,580 7,580 PROD1 WHPST DLOG P Tie in depth to K1 -14'correction 22:00 22:15 0.25 7,580 7,742 PROD1 WHPST TRIP P RIH, 22:15 22.30 0.25 7,742 7,742 PROD1 WHPST TRIP P Dry tag 7743.7'PU 42K, break back to 34K.Online with pumps 1.59BPM, 3155 CTP, 13.5 RIHW, 36K PUW, RIH to mill 22:30 22:45 0.25 7,740 7,740 PROD1 WHPST TRIP P Injector making popping noises.TP inspected&gives ok to continue. 22:45 00:00 1.25 7,743 7,743 PROD1 WHPST MILL P Start milling following time table in program 06/25/2012 Complete window milling.TOW-7735', BOW-7748'. PU/MU/RIH build BHA.(2.3deg AKO, Bi-center). Drill build section. 00:00 03:00 3.00 7,743 7,744 PROD1 WHPST MILL P Cont.milling following time table, 1.6 bpm,3255 ctp, 140 diff psi. .5k wob 03:00 04:12 1.20 7,744 7,746 PROD1 WHPST MILL P Set auto driller to 1 fph Page 2 of 9 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:12 04:18 0.10 7,746 7,746 PROD1 WHPST MILL P Vibrations in red(4).Cont. milling at 1 fph. 04:18 06:18 2.00 7,746 7,749 PROD1 WHPST MILL P Increase ROP 2 fph.Vibrations come down green(2)Cont milling. 1.6 bpm,3369 ctp,2.9 wob, 10 ctw Motor work spike at 7747.7'and 7748.2'. WOB dropped off, Bottom of window. Continue at 2 FPH. The time milling schedule was not followed correctly, ROP increase to 2 FPH was 2 foot early. 06:18 08:42 2.40 7,749 7,763 PROD1 WHPST MILL P Milling formation,start flo-pro down coil. 1.5 BPM,3400 CTP,after flo-pro to surface BHP is 3720, 11.85 ECD with 170 WHP. Some vibration at 7750-52' 08:42 12:24 3.70 7,763 7,763 PROD1 WHPST REAM P Ream window, PUH at.5 FPM in window interval from 7752 to 7735', Oriented HS on first pass., 30L, 30R and 180. Drift window with pump down. 12:24 14:24 2.00 7,763 0 PROD1 WHPST TRIP P POOH,following MPD tripping schedule 14:24 14:48 0.40 0 0 PROD1 WHPST SFTY P Shut in SSSV, PJSM for BHA swap, monitor well for no-flow 14:48 15:42 0.90 0 0 PROD1 WHPST PULD P Lay down milling BHA,mill aand string mill both 2.80"go,2.79"no-go 15:42 16:42 1.00 0 0 PROD1 DRILL PULD P MU Drilling BHA for build section of 2K-14A lateral 16:42 18:42 2.00 72 7,550 PROD1 DRILL TRIP P RIH with build BHA 18:42 19:00 0.30 7,550 7,550 PROD1 DRILL DLOG P Tie in depth to K1 -16.5'correction 19:00 19:12 0.20 7,550 7,763 PROD1 DRILL TRIP P RIH to drill build 19:12 19:42 0.50 7,763 7,791 PROD1 DRILL DRLG P Drill Ahead 1.53 bpm,3754 ctp,260 whp, 3830 bhp, 19:42 20:12 0.50 7,791 7,791 PROD1 DRILL WPRT P MP choke lost it's mind. Fully opened without command. PUH 30k into casing. reboot system. looks good. RBIH 20:12 22:42 2.50 7,791 7,915 PROD1 DRILL DRLG P Drill Ahead 1.53 bpm, 3824 ctp,3860 bhp,270 whp 22:42 23:12 0.50 7,915 7,915 PROD1 DRILL WPRT P Wiper trip back to window 31k 23:12 23:27 0.25 7,915 7,915 PROD1 DRILL DLOG P Tie in depth to K1.+.5'correction RBIH log RA marker 7742.5' 23:27 00:00 0.55 7,915 7,952 PROD1 DRILL DRLG P Drill ahead 1.5 bpm,3830 ctp,3886 bhp, 13.5k ctw,250 whp. 06/26/2012 Completed Build section,tested SSSV-failed. Undeploy BHA and P/U drilling BHA with.8 AKO&bi-center bit. Drill A lateral. 00:00 01:00 1.00 7,952 8,065 PROD1 DRILL DRLG P Cont.drilling build 01:00 01:42 0.70 8,065 8,065 PROD1 DRILL WPRT P Wiper trip to window 30K puw 01:42 02:12 0.50 8,065 8,125 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3900 ctp,200 whp, 3910 bhp 02:12 04:42 2.50 8,125 0 PROD1 DRILL TRIP P Land build POOH.30K puw Page 3 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:42 05:06 0.40 0 0 PROD1 DRILL SFTY P Shut SSSV and monitor well for flow, PJSM for laying down BHA 05:06 08:36 3.50 0 0 PROD1 DRILL PULD P SSSV was not holding pressure, undeploy BHA with managed pressure pumping,deploy lateral drilling BHA#6 08:36 10:36 2.00 72 7,580 PROD1 DRILL TRIP P RIH with lateral drilling BHA 10:36 10:51 0.25 7,580 7,580 PROD1 DRILL DLOG P Tie in depth to K1, 10:51 11:21 0.50 7,580 8,125 PROD1 DRILL TRIP P RIH to drill,window looked good with 0.8 deg AKO.Mud pump jacking. Work air out of pump. 11:21 13:06 1.75 8,125 8,275 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3900 ctp, 170 whp, 15k ctw, 13:06 13:36 0.50 8,275 8,275 PROD1 DRILL WPRT P Wiper trip to window 30K puw 13:36 15:36 2.00 8,275 8,425 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3900 ctp, 160 whp, 15k ctw, 15:36 16:36 1.00 8,425 8,425 PROD1 DRILL WPRT P Wiper trip to window 29K puw 16:36 18:06 1.50 8,425 8,575 PROD1 DRILL DRLG P Drill ahead 1.55 bpm,3983 ctp, 161 whp, 10k ctw. 18:06 19:30 1.40 8,575 8,575 PROD1 DRILL WPRT P Wiper trip to TT with Tie in+2 ft. 19:30 21:00 1.50 8,575 8,725 PROD1 DRILL DRLG P Drilling ahead 1.55 bpm,3980, BHP 3927, ECD 12.3, ROP 80,WOB 2.2K, CT weight 11.3K.whp 155. 21:00 22:00 1.00 8,725 8,725 PROD1 DRILL WPRT P Wiper trip 30K off bottom. 22:00 23:12 1.20 8,725 8,875 PROD1 DRILL DRLG P Drilling ahead-1.55 bpm,3940, BHP 3977,WOB 1.5K, ROP 144,Ct weight 11, ECD 12.6,WHP 155. 23:12 00:00 0.80 8,875 8,875 PROD1 DRILL WPRT P Wiper trip-P/U weight 29K 06/27/2012 Drilling and TD A lateral.Mud swap with 1300ft on system, increase mud weight to 9.8#. 00:00 01:00 1.00 8,875 8,875 PROD1 DRILL WPRT P Wiper trip-started to drill ahead and got trip crude/gas.Take returns to TT,wiper up slowly-RIH to TD.took 40 bbls out TT. 01:00 02:00 1.00 8,875 9,025 PROD1 DRILL DRLG P Drilling ahead-1.55 bpm,3930, BHP 3990,WHP 200, ROP 120,WOB 1.5K,Ct weight 12K. 02:00 03:30 1.50 9,025 9,025 PROD1 DRILL WPRT P Wiper trip to tubing tail, holding additional WHP during wiper-vac trucks en route for mud swap.Tie in correction zero.Start taking returns to TT for mud swap.Got trip gas/oil once at bottom. 03:30 04:30 1.00 9,025 9,175 PROD1 DRILL DRLG P Start pumping new 9.5#mud- Drilling ahead-1.55 bpm,4040, BHP 4085,WHP 220, ROP 120,WOB 1.5,CT weight 11.5K. 04:30 06:00 1.50 9,175 9,175 PROD1 DRILL TRIP P Wiper trip-P/U weight 30K 06:00 07:30 1.50 9,175 9,315 PROD1 DRILL DRLG P Drilling ahead-1.55 bpm,3876, BHP 4037,WHP 260, ROP 120,WOB 1.5K,Ct weight 12K.Gas at surface once on bottom.take returns to TT. 15bbrls. Page4of9 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:30 10:00 2.50 9,315 9,315 PROD1 DRILL WPRT P Loose prime on pump.Mud swap not complete.400brl swap.With returns taken to TT,vol. in active 250. running on 2 pit system.weighted up 9.8ppg in route from MI plant. PU 30K puw. Pull wiper trip to window early. 10:00 11:42 1.70 9,315 9,475 PROD1 DRILL DRLG P Drill Ahead, 1.5 bpm,4088 ctp,300 whp,4150 bhp, 10k ctw. 11:42 14:12 2.50 9,475 9,475 PROD1 DRILL WPRT P Wiper trip to window. Log RA marker.0 correction RBIH 14:12 15:57 1.75 9,475 9,625 PROD1 DRILL DRLG P Drilling ahead-1.47 bpm,4051, BHP 4164,WHP 288,WOB 2.2K,Ct weight 9K. 15:57 17:03 1.10 9,625 9,625 PROD1 DRILL WPRT P Wiper trip 850'22fpm out 33 fpm, in hole.Start sending returns out to TT for mud swap.9.8ppg new mud on location. 17:03 18:33 1.50 9,625 9,775 PROD1 DRILL DRLG P Drilling ahead, pump new 9.8#mud stay on 2 pit system. 18:33 19:51 1.30 9,775 9,775 PROD1 DRILL WPRT P 900'Wiper trip-P/U weight 33K. Choke acting up-panel problems with auto choke. Fixed. RIH. 19:51 21:30 1.65 9,775 9,907 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,4080, BHP 4230,WHP 255, ROP 90,WOB 2.1, CT weight 10K. Pump 10/10 sweeps prior to TD. 21:30 00:00 2.50 9,907 2,000 PROD1 DRILL WPRT P Wiper trip to swab valves.Pump 10/10 sweep in cased hole. Increase in cutting from B/U of sweeps. 06/28/2012 Ran liner from 9907'-7910'with a liner top billet.Weekly function test of BOP's. P/U 2.3 AKO with bi-center, RIH circ out KWF and Start KOTB from 7907'. 00:00 01:00 1.00 2,000 72 PROD1 DRILL WPRT P Wiper to swab valves. 01:00 04:00 3.00 72 9,907 PROD1 DRILL TRIP P RIH-tie minus 17,clean through window. RIH start pumping 13.1# liner pill.tag bottom @ 9907' 04:00 07:00 3.00 9,907 0 PROD1 DRILL TRIP P P/U weight 32K. POOH laying in KWF Liner pill. EOP flag 7800'& 5600' 07:00 07:15 0.25 0 0 PROD1 DRILL SFTY P At surface, PJSM,monitor well for flow 07:15 08:15 1.00 0 0 PROD1 DRILL PULD P LD BHA 08:15 08:45 0.50 0 0 COMPZ CASING PUTB P Prep floor to MU liner 08:45 12:30 3.75 0 0 COMPZ CASING PUTB P PU/MU"A"liner 12:30 13:45 1.25 2,040 7,658 COMPZ CASING RUNL P RIH with liner 13:45 14:00 0.25 7,658 7,658 COMPZ CASING DLOG P Tie in depth to EOP flag-18' correction, Record up and down weight.30K puw,21K RIW. 14:00 14:45 0.75 7,658 9,907 COMPZ CASING RUNL P RIH to TD 14:45 14:51 0.10 9,907 9,700 COMPZ CASING RUNL P Tag bottom 9906.5'.Online with pumps,4000psi, 1.23 bpm, PU.28K puw,WOB 0. POOH Page5of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:51 14:57 0.10 9,700 7,700 COMPZ CASING TRIP P Remove liner length from bit depth., cont POOH 14:57 15:06 0.15 7,581 7,581 COMPZ CASING DLOG P Tie in depth to K1 +1.5'correction 15:06 17:06 2.00 7,581 7,581 COMPZ CASING TRIP P POOH 17:06 17:21 0.25 7,581 0 COMPZ CASING SFTY P At surface. PJSM. Monitor well for flow 17:21 18:21 1.00 0 0 COMPZ CASING PULD P LD BHA.**Weekly function test of BOP's** 18:21 20:00 1.65 0 72 PROD2 STK PULD P P/U Build BHA with 2.3 AKO& bi-center bit.Troubleshoot software for BHI tool. Good test. 20:00 23:00 3.00 72 7,720 PROD2 STK TRIP P Open EDC-RIH.Sit at 7720&circ out KWF with sweep&9.8 Flo pro. Tie in correction-15ft. Close EDC. 23:00 23:30 0.50 7,720 7,907 PROD2 STK TRIP P RIH dry tag TOB @ 7907.5'-P/U kick on pumps and set up for milling. 23:30 00:00 0.50 7,907 7,907 PROD2 STK KOST P 90 ROHS-KOTB as per procedure. 1.40 bpm,3600,BHP 4000,WOB .6K,Ct weight 17.5, ROP 1,WHP 165. 06/29/2012 KOTB from 7907'drill build to 8120'. P/U BHA#9 with RSM and 3"Bi-center. Drilling AL1 lateral. 00:00 02:00 2.00 7,907 7,915 PROD2 STK KOST P KOTB-1.40 bpm,3590, BHP 4000, WHP 190,WOB.4, ROP 2fph.Alum returns to surface. Increase to 10 fph 7910',increase to 20 @ 7915'. 02:00 03:00 1.00 7,915 7,960 PROD2 DRILL DRLG P Drilling ahead to 7960'wiper&drift ,pillet 03:00 03:30 0.50 7,960 7,748 PROD2 DRILL WPRT P Wiper and clean drift through billet. Tie in with Zero correction.TOB 7907' 03:30 06:00 2.50 7,960 8,105 PROD2 DRILL DRLG P_Drill ahead-1.43 bpm,3700, BHP 4030,WHP 180,WOB 1.8K, Ct weight 15K, ROP 50. Dogleg 40's. 06:00 06:15 0.25 8,105 7,608 PROD2 DRILL WPRT P Land build. POOH 06:15 06:30 0.25 7,608 7,685 PROD2 DRILL WPRT P Open EDC, perform jog in 4.5". 06:30 08:30 2.00 7,685 0 PROD2 DRILL TRIP P POOH 08:30 08:45 0.25 0 0 PROD2 DRILL SFTY P At surface, PJSM, 08:45 10:00 1.25 0 0 PROD2 DRILL PULD P Undeploy 8 10:00 11:45 1.75 0 0 PROD2 DRILL PULD P Deploy BHA 9(Rib Steer Motor). Service Injector Head,check packoffs. 11:45 13:30 1.75 68 7,633 PROD2 DRILL TRIP P RIH 13:30 13:45 0.25 7,633 7,633 PROD2 DRILL DLOG P Tie in depth to K1,-15'correction 13:45 14:00 0.25 7,633 8,107 PROD2 DRILL TRIP P RIH to drill,Window looked good. Set down at billet @ 20 FPM. PU 29K PUW, RIH 10 FPM.slip thru. RIH 14:00 16:45 2.75 8,107 8,260 PROD2 DRILL DRLG P Drill Ahead. 1.43 bpm,3580 ctp, 4017 bhp, 150 whp, 15K ctw, 16:45 17:00 0.25 8,260 8,120 PROD2 DRILL WPRT P Wiper trip to end of build 8120' Page 6 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:00 3.00 8,260 8,410 PROD2 DRILL DRLG P Drill Ahead 1.43 bpm,3758 ctp, 126 whp, 15k ctw,4073 bhp 20:00 20:30 0.50 8,410 8,120 PROD2 DRILL WPRT P P/U weight 28K Wiper to EOB 8120' 20:30 22:30 2.00 8,410 8,560 PROD2 DRILL DRLG P Drilling ahead 1.45 bpm,3930, BHP 4076,WHP 130, ECD 12.9,WOB 2.5,CT weight 12K. 22:30 00:00 1.50 8,560 8,560 PROD2 DRILL WPRT P Wiper trip to 3.5"P/U weight 29K. Motor work&drag in build section. Min. rate through billet-drag increase 2-3K.Clean through window.Jog 4.5"-RIH.Tie in+1.5ft. 06/30/2012 Drilled ahead AU lateral.Wiping past billet every third pass.Mud swap with 1750'on system. 00:00 02:00 2.00 8,560 8,710 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3970, BHP 4080,WHP 120, ECD 13, ROP 60, WOB 1.5K,Ct weight 13K. Poor Rez in formation. 02:00 03:30 1.50 8,710 7,760 PROD2 DRILL WPRT P P/U weight 28K-wiper to window. Much less weight drag through build but did see a drag a billet section. RIH-tag TOB, P/U spin bit-RIH dry again,clean drift-RIH. 03:30 05:00 1.50 8,710 8,860 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3890 CTP, BHP 4060,WHP 100, ROP 120, WOB 1.8K,Ct weight 15K. Poor Rez in formation. 05:00 06:00 1.00 8,860 8,120 PROD2 DRILL WPRT P P/U weight 29K Wiper trip to EOB 8120' 06:00 08:00 2.00 8,860 9,010 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3900 ctp, 4100 bhp, 120 whp, 11k ctw, 08:00 10:00 2.00 9,010 7,600 PROD2 DRILL WPRT P Wiper trip back to TT.29k puw.2k overpull thru billet. Pulling thru build/window looked good. Log RA marker on RBIH. +1.5'correction. Set down 3 different times at billet. 10, 12, 14 fpm. On 4th try RIH 6 fpm. Slide thru.Cycle pumps before all 3 attempts. 10:00 13:00 3.00 9,010 9,185 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,4058 ctp, 4130 bhp, 130 whp, 12k ctw. 13:00 14:30 1.50 9,185 8,120 PROD2 DRILL WPRT P Pump low/high sweeps.Wiper trip back to 8120, No increase of cuttings in sweeps 14:30 17:00 2.50 9,185 9,335 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,4058 ctp, 4130 bhp, 130 whp, 12k ctw. 17:00 18:30 1.50 9,335 8,120 PROD2 DRILL WPRT P Wiper to 8120' 18:30 20:30 2.00 9,335 9,485 PROD2 DRILL DRLG P Drilling ahead-take return to TT for mud swap 1750'on system. 1.44 bpm,4100, BHP 4177, ROP 100, ECD 13.2,WOB 1.7K,Ct weight 11K. Page 7 of 9 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 20:30 23:00 2.50 7,650 9,485 PROD2 DRILL WPRT P 29 K P/U weight-wiper to Tubing tail. Bring returns inside to montior cuttings in build.Very small increase in cuttings.Take returns to TT. RIH. tie in+3ft correction. Tag TOB 7909'P/U rotate bit-drift through. RIH start pumping new mud. 23:00 00:00 1.00 9,485 9,556 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3800, BHP 4180,WHP 220,WOB 1.7K, ROP 88, CT weight 14K. 07/01/2012 _Drill to a TD of 9850',Wiper to swab valves, RIH Lay in KWF. Reel swivel stopped rotating. Replace. Lay down BHA&service equipment.Start P/U AL1 liner assembly with an indexing guide shoe. 00:00 01:00 1.00 9,556 9,635 PROD2 DRILL DRLG P Drilling ahead 01:00 02:00 1.00 9,635 8,785 PROD2 DRILL WPRT P 850'Wiper trip,-P/U weight 28K 02:00 04:30 2.50 9,635 9,785 PROD2 DRILL DRLG P Drilling ahead-steering up for the A-5. 1.45 bpm, 3800, BHP 4220, WHP 240, ECD 12.9, ROP 50,WOB 2K. Just starting to come out of the A-4. Pump low/high sweeps. 04:30 06:30 2.00 9,785 8,120 PROD2 DRILL WPRT P Wiper trip-P/U weight 28K.Good cutting coming across during sweep, wipe up to 8120' 06:30 07:45 1.25 9,785 9,850 PROD2 DRILL DRLG P Drill Ahead 1.44 bpm,3986 ctp, 1.3 k wob12 k ctw,4183 bhp 07:45 11:45 4.00 9,850 8,120 PROD2 DRILL WPRT P TD AL1 Lateral. Pump low/high sweeps Wiper trip to 8120'. RBIH spot 12.8ppg Formate with Alpine beads from TD to window. 9850'-7735' 11:45 13:30 1.75 8,120 3,731 PROD2 DRILL WPRT P POOH to swab valves pumping Flo-Pro 13:30 15:30 2.00 3,731 3,731 PROD2 DRILL RGRP T Inner reel iron loose inside reel.Stop. PJSM. Lockout reel. MU inner iron, Reel swival bearing locked up.Swap out swival. Pressure test swival and inner reel iron. RBIH to straighten up loose wraps on reel. ***Nabors 2hrs of Billable Rig Repair*** 15:30 16:30 1.00 3,731 0 PROD2 DRILL WPRT P POOH to swabs. 16:30 18:00 1.50 0 7,581 PROD2 DRILL WPRT P RBIH to window 18:00 19:00 1.00 7,581 7,700 PROD2 DRILL DLOG P Tie in depth to K1 marker, start pumping KWF. 19:00 21:00 2.00 7,700 68 PROD2 DRILL TRIP P POOH laying in 13.1 KWF. EOP flags 7500&5400'. KWF to surface @ 3000'. 21:00 22:30 1.50 68 0 PROD2 DRILL PULD P No-flow check, PJSM for laying down BHA. Inspect reel iron&swivel, service the injector. 22:30 23:15 0.75 0 0 COMPZ CASING SFTY P Inspect Top drive, set up rig floor. PJSM for P/U Liner. Page 8 of 9 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 23:15 00:00 0.75 0 0 COMPZ CASING PUTB P Start P/U Liner run-Indexing guide shoe,66 joints of 2-3/8"slotted liner with shorty deployment sleeve. 07/02/2012 Set liner from 9850'-7702'. Recover KWF&pump SW followed by freeze protect from 2500'. Blow down reel &BOP stack.Set BPV with 1000psi below. RDMO. ***Rig release at Midnight*** 00:00 02:00 2.00 500 2,145 COMPZ CASING PUTB P P/U Liner 02:00 03:00 1.00 2,145 2,192 COMPZ CASING PULD P P/U Coiltrack assembly 03:00 05:00 2.00 2,192 7,750 COMPZ CASING RUNL P RIH with EDC open pumping .3 bpm. Tie in minus 18.3. Stop pumping. P/U weight 33k,WOB-7.6K. 05:00 06:00 1.00 7,750 9,850 COMPZ CASING RUNL P RIH clean through billet.Tag bottom @ 9849'-Had to push 7K to get to bottom.Ct weight 5K,WOB 9K.Pump 1.1 bpm, release off liner. P/U weight 28K WOB zero. BOL =9850' TOL=7702' 06:00 07:30 1.50 7,680 2,500 COMPZ CASING DISP P Circ out KWF. POOH 07:30 09:15 1.75 2,500 0 COMPZ CASING FRZP P POOH. Jet across SSSV with diesel to clean it up. Freeze protect well 09:15 09:30 0.25 0 0 COMPZ CASING SSSV T Re-test SSSV,still did not hold. 09:30 09:45 0.25 0 0 COMPZ CASING SFTY P PJSM 09:45 11;15 1.50 0 0 COMPZ CASING PULD P Undeploy BHA 10 11:15 11:30 0.25 0 0 DEMOB WHDBO SFTY P PJSM 11:30 13:30 2.00 0 0 DEMOB WHDBO CIRC P Pump inhibitor and flush thru out CT, BOP's and Rig lines. 13:30 15:30 2.00 0 0 DEMOB WHDBO NUND P RU and BPV. 1st attempt dit not set. 2nd successful 15:30 16:15 0.75 0 0 DEMOB WHDBO NUND P RD BPV lubricator. 16:15 16:45 0.50 0 0 DEMOB WHDBO CTOP P Blow down CT and rig 16:45 17:45 1.00 0 0 DEMOB WHDBO SFTY P Shut down for After Action Review (AAR)on reel swival swap while tripping out of hole yesterday. 17:45 20:00 2.25 0 0 DEMOB WHDBO CIRC P Crew Change, PJSM-Blow down reel,&lines.Clean pits 20:00 00:00 4.00 0 0 DEMOB WHDBO RURD P Rig down lines to stack, hard iron for testing&lay down PDL.Secure tree &BOP stack. Close windwall— d' be check for space of CT/Injector clearance. *****Rig release at Midnight**** Page 9 of 9 Letter of Transmittal vpu BAKER Date: July 9, 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): 2K-14A - © $0 (2) Total prints DiZ' (./YL Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Ai Carl.Ulrich@BakerHughes.com it ��i t y d ( '� `P SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Lamar Gantt FAX (907)276-7542 Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-14AL1 ConocoPhillips Alaska, Inc. Permit No: 212-081 Surface Location: 94' FNL, 94' FEL, SEC. 11, T1ON, RO8E, UM Bottomhole Location: 605' FSL, 39' FWL, SEC. 2, T1ON, RO8E, 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 2K-14A, Permit No 212- 080, API 50-103-20112-01. 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, Cathy . Fo rster Chair DATED this /g day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) '110V- ConocoPhillips philli Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 JUN 1 3 2012 June 12, 2012 AOGCC 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 2K-14A and 2K-14AL1 from Kuparuk well 2K-14 (PTD# 189-088). Coiled tubing drilling (CTD) operations are scheduled to begin July 1, 2012 using the Nabors CDR2-AC rig. The objective of the CTD project is to improve Kuparuk A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. A workover has recently been completed which installed a 4'/2"scab liner inside the 7" casing adjacent to the Kuparuk sands. The cementing of that scab liner also effectively squeezed the existing A and C-sand perfs as per sundry 312-129. Once CTD operations are completed then a 10-407 will be submitted to classify the original 2K-14 completion as `Abandoned'. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 2K-14A and 2K-14AL1 — Directional plans for 2K-14A and 2K-14AL1 — Current wellbore schematic following the rig workover — Proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-263-4172. SiI \ly, J. a Eller Con• o"hillips a Coiled ubing Drilling Engineer STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 3 2012 PERMIT TO DRILL 20 AAC 25.005 AOG CC 1 a Type of Work: • 1 b.Proposed Well Class: Development-Oil 0 ' Service-Winj ❑ Single Zone 0 • lc.Specify if well is proposed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates 0 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 • 2K-14AL1 . 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10350' ' TVDSS: 6063' • Kuparuk River Field 4a. Location of Well(Governmental Section) 7.Property Designation(Lease Number): Surface:94'FNL,94'FEL,Sec. 11,T1ON, RO8E, UM ADL 25588 • Kuparuk River Oil Pool • Top of Productive Horizon: 8 Land Use Permit. 13.Approximate Spud Date 1347'FNL, 1421'FWL,Sec. 11,T1ON, RO8E, UM 2674 7/1/2012 Total Depth 9.Acres in Property: 14.Distance to 605'FSL,39'FWL,Sec.2,T1ON, RO8E, UM 2560 Nearest Property: 13645 / 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL:Is/ 1.1.8-5-fere 15 Distance to Nearest Well Open Surface:x- 498310 • y- 5938210 • Zone- 4 GL Elevation above MSL://pet �oiSamez� Pool: 2K-08A,1458 �D/u.% 16.Deviated wells Kickoff depth 7820 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle 101° deg Downhole:4395 psig Surface:3774 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 2650' 7700' 6034' 10350' 6063' slotted/solid liner , 19 PRESENT WELL CONDITION SUMMARY (To be completed for Rednll and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft). Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft). Junk(measured) 8202 6608 8042 6484 Casing Length Size Cement Volume MD ND Conductor/Structural 79' 16" 110 sx AS II 115' 115' Surface 3138' 9.625" 1000 sx AS III,500 sx Class G 3173' 2935' Intermediate Production 8117' 7" 225 sx Class G 8147' 6560' Scal Liner 250' 4.5" 7805' 6271' Perforation Depth MD(ft): Perforation Depth TVD(ft): 7682'-7696',7761'-7801' 6174'-6185',6236'-6270' 20.Attachments Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Dnlling Fluid Program 0 20 AAC 25 050 requirements 0 21.Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 t J I0h4 12 Printed Name L. Gantt Title Wells Supervisor SignaturePhon 263-4021 Date (.,,,//2`� z 6.nhL1iV Commission Use Only Permit to Drill API Number Permit Approval, See cover letter Number: Z ( 50-�L/57' //Z-6G Date: ` 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 Itr 4` yOOQps•' &DP 7;:f-- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ z No [� Other: i H2S measures: Yes [J No ❑ Directional svy req'd: Yes [>f No ❑ Pk-4A APPRO ED BY THE COMMISSION DATE 6 —1 gt -" ' 1(( A /'", 1 a = /j ,COMMISSIONER) ✓ Form 10-401 (Revised 7/2009) This ermit is valid for 24"mor the frorlf-thl Jatg df a�p!al(20 AAt'25.005(g)) S mit in Duplicate h,h• t, (V•i 2__ �17 L. NABQRSALASKA KuparukCTD Laterals � 2K-14A and 2K-14AL1 CuJ' Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 6 (Requirements of 20 AAC 25.402) 6 17. Attachments 6 Attachment 1: Directional Plans for 2K-14A and 2K-14AL1 6 Attachment 2: Current Well Schematic for 2K-14 6 Attachment 3: Proposed Well Schematic for 2K-14A and 2K-14AL1 6 Page 1 of 6 L RIG I N. i June 12, 2012 PTD Application t1/4,1- KRU 2K-14A and 2K-14AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are KRU 2K-14A and 2K-14AL1. 2K-14A will be a sidetrack from the 2K-14 motherbore, and 2K-14AL1 will be a horizontal lateral branching off the 2K-14A. Both laterals will be classified as"Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Both of these laterals will target the A4 sand in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of the 2K-14A and 2K-14AL1 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4300 psi. Using a maximum potential formation pressure of 4395 psi, the maximum potential surface pressure is 3774 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The most recent static BHP measurement in well 2K-14 was taken in April 2012 recording a pressure of 2466 • psi at 7764' MD, 6239' TVD for a 7.6 ppg gradient. The proposed 2K-14 CTD laterals will approach existing injection wells so our expectation is that we will encounter increasing formation pressure as the laterals are drilled. The most likely sources of elevated formation pressure, if we encounter such, would be from injection wells 2K-13A to the west and 2K-28A to the southeast. Their most recent surveys showed formation pressures - of 12.4 ppg EWM but they have been on continuous injection since those measurements were taken. I estimate that we are likely to encounter formation pressure of 11.8 ppg while drilling the 2K-14 CTD laterals, but it has potential to be higher. Maximum potential formation pressure is based on the January 2011 pressure from 2K-06 to the north, which had measured formation pressure of 4336 psi at 7600' MD, 6157' TVD for a gradient of 13.6 ppg. A measurement in April 2012 showed that the pressure in 2K-06 has declined to 11.8 ppg, • but the 13.6 ppg represents a conservative maximum potential pressure than can be encountered while drilling the 2K-14 laterals. In 2K-14A this equates to a maximum potential formation pressure of 4395 psi (7735' MD, 6216' TVD) and a maximum potential surface pressure of 3774 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled. Well 2K-13 to the west had a significant slug of miscible gas injected in 2010, so it is possible that an influx will yield significant quantities of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 2K-14 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining target ECD of 11.8 ppg at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2K-14A and 2K-14AL1 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so • formation integrity tests are not required. I Page 2 of 6 t � ' June 12,2012 • PTD Application 'rue KRU 2K-14A and 2K-14AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Liner Liner Liner Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 2K-14A 7820' 9855' 6111' 6147' 2W, 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2K-14AL1 7700' 10,350' 6034' 6063' 2%", 4.7#, L-80, ST-L slotted liner up v- inside 4%2" liner Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 9%" 36 J-55 BTC 0' 3173' 0' 2935' 3520 2020 Casing 7" 26 J-55 BTC 0' 8147' 0' 6560' 4980 4320 Scab liner 4W 12.6 L-80 IBT& BTC 7555' 7805' 6075' 6271' 8430 7500 Tubing 3W 9.3 L-80 EUE 8rd-M 0' 7578' 0' 6093' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.3 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.3 ppg). This mud weight will hydrostatically overbalance formation pressure in the 2K-14 motherbore, but is not likely to over-balance the increased formation pressure encountered while drilling away from the motherbore. Overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2K-14 contains a subsurface safety valve (SSSV) at 1811' MD. The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-180 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 2K-14 laterals we will target a constant BHP of 11.8 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole . stability but not necessarily for well control. ORIGINAL P of Page 3 6 June 12, 2012 I PTD Application tui KRU 2K-14A and 2K-14AL1 Pressure at the 2K-14A Window (7735' MD, 6216' TVD, 6062' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.8 ppg) 3814 psi 3814 psi Mud Hydrostatic (9.3 ppg) 3006 psi 3006 psi Annular friction (i.e. ECD, 0.095 psi/ft) 735 psi 0 psi Mud + ECD Combined 3662 psi 3006 psi (underbalanced (underbalanced (no choke pressure) —70 psi) 808 psi) larget 'at Window(11.8 ppg) 3814 psi 3814 psi Choke Pressure Required to Maintain 70 psi 800 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 2K-14 is an NC-sand producer that was recently worked over to install a 4W scab liner over damaged 7" casing near the existing Kuparuk perfs. The existing NC-sand perfs were squeezed with cement as part of that workover, and our plans are to not re-perf the C-sand. Two proposed A-sand CTD laterals will increase reservoir exposure and improve waterflood sweep. A separate sundry request(312- 129)was approved for the abandonment of the original 2K-14 completion in preparation for these CTD sidetracks. A mechanical whipstock will be placed in the 4W scab liner at the planned kickoff point. The 2K-14A sidetrack will exit the 4W liner and 7" casing at 7735' MD and will target the A4 sand south of the existing well with a 2120' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9855' MD with an aluminum billet at 7820' MD. The 2K-14AL1 lateral will kick off from the aluminum billet at 7820' MD and will target the A4 sand north of the existing well with a 2530' lateral. The hole will be completed with a 2%' slotted liner to the TD of 10,350' - MD with the final liner top located inside the 4W liner at 7700' MD. Page 4 of 6 ORI 01 N JA\ _ June 12, 2012 • PTD Application tue KRU 2K-14A and 2K-14AL1 Pre-CTD Work 1. RU e-line. Get updated GR/CCL correlation across the 4%" scab liner and tag fill. 2. Run whipstock dummy. 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2K-14A Sidetrack (A4 sand, south) a. Set whipstock at 7735' MD with high-side orientation. b. Mill 2.80"window through 4%" liner and 7"casing at 7735' MD c. Drill 2.70" x 3" bi-center lateral to TD of 9855' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7820', using the SSSV as a barrier to formation pressure 3. 2K-14AL1 Lateral (A4 sand, north) a. Kick off of the aluminum billet at 7820' MD b. Drill 2.70" x 3" bi-center lateral to TD of 10,350' MD A - •l c. Run 2%" slotted liner from TD up to 7700' MD, inside the 4%" liner. Will use the SSSV as a ,* barrier to formation pressure while picking up liner. 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Perform static BHP survey 3. Put on production. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Page 5 of 6 ti ' ' = • _ L. June 12,2012 • PTD Application tK,r KRU 2K-14A and 2K-14AL1 Liner Running - Since 2K-14 is equipped with a SSSV, the CTD laterals will not need to be displaced to an over-balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the"Drilling Fluids" section for more details. - While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) - No annular injection on this well. - Class II liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - There are no other affected owners - Please see attached directional plans for each lateral. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 2K-14A WP07 9710' 758' 2K-28AL1 2K-14AL1 WP07 13,645' 1458' 2K-08A • 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for these laterals since they are intended to serve as producers. 17. Attachments Attachment 1: Directional Plans for 2K-14A and 2K-14AL1 Attachment 2: Current Well Schematic for 2K-14 Attachment 3: Proposed Well Schematic for 2K-14A and 2K-14AL1 `l n ! t,. ' g f 1 { June 12, 2012 Pa e6of6 ! ; t s - N N— , C 7 N ❑ ❑ 0o 1 1 tea C LO j N N _ CO O co M (6 CO _JO u) co ,- Q '4-V © �,V V v Cn b _ N N m l6 CO L J N.c(0 m Q a a m a) 1 a -0 N a) a) N- OO 0 U _. 0 _C ❑ ,- N C C o_ a) a)0 CO O V 0 0 • �• O +� O O co O O C6 .O N <- 1111 0M \ a O C V S1 M L O X W (0 rn _ ti ti ❑ a m �° m is W 2 tY b LLI co a) • a o ate) cl °)co I H o N J X as c co l0 _ O_ (6 - I m co co O U Q) M m M CO W L Y �' ul in I I Mi LO (II n 00 Jco cn ai U 2 co N vo cO a n. 0 �_ (V N N N U Y Y x Y 3 O I Q 0 c0 i r r r O (0 c a) cu N C I , CO C a)) 0) O co CO M M J CO co W CO C 'in . a) O `" _o a) C O U / U E f I c n3 N <n L - 0 M V / m i i i .1 RS r 1 L N --------- 44 il II r r N I— C)U aPI !ITT!!! 1 a, 0 1 a L in a) -O I— cr❑ n ❑ Cf) a❑ @) U cn 2 ❑ a a- —3 CO CC) to - 0 O �# V Tr CO a) a0 CO o `;) Co 't rn Y a ti N CO _ M Cas r- CO N N CO ©© () N Q N- co co .c in _c O r- CO O) co ORG1NAL D a) as M -0 co o_ N- - (0 06 as O _J (D L L L N- M 'a Q -0 O a) (0U O -0 L a) U N- O a) to 7-21 _c0 0 O ' _ N C C LU o_ a) a) O CO 0 O `t CO c N- 0 0 0 CO o0 E � D D (6 N N V (6 > FE co -a-) 63 a3 (n N (n O U) 0 e0 (6 OU 0 0 2 72 (6 71- (moi L() in M Lo Lo CO U m co co H X W a3 g I� m (ts cu cu Q ots n3 E (6 a) W U IY• °° O V (n a) C (n ~ coN J U X co - O- (6 O m co co 4t E co h- EN a _c o in O co o) oD M X U O 100 (6 oO U) rn 0 I o Co N p co -J N_ a 1--- EN N N N N (6 a) a) J a) a Ln C 06 id U Y Y x Y 0-In O (6 a3 a5 M (6 M Co Co CO J co Co ...i_ on LO (..E. 0) 0 a) _C C0 S E a3 _o 0 aS O N U — i U i i i 4 O 0 ;: E al CI III_I III11IIIIII i li 47, ia RS n. - ` ; 1 C , a) : ` r � �>0 lCn re ,' ( ( ( ( -,--(--(,- II 11111111111 MI o Uo j) isj Lot � � 1* � O Ln �� 007 QN. N cO p Q� Y I CO O I a3 N N � _c•-) /�1 � � `— w (�o co r Co ir) O U ti ORIGINAL 2 ....... % _ § rr, .s Q= 8 .e" • M m M Z Q to g zy8g g v - - ^ c E. tiLR_. E_ o [CSC] c + QQQ C p M i V LL 3 q N Lu 2 y¢1 m o m yl Q 8 N _,a�ppm m II O N _u C U \ v' C Qj ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-14 2K-14AL1 Plan: 2K-14AL1_wp07 Standard Planning Report 15 May, 2012 'flu BAKER HUGHES n Ni in\ v-- ConocoPhillips or its affiliates MT ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-14 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-14 @ 154.00ft(D14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-14 Survey Calculation Method: Minimum Curvature Wellbore: 2K-14AL1 Design: 2K-14AL1_wp07 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 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W, Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-14 Well Position +N/-S 0.00 ft Northing: 5,938,210.14 ft • Latitude: 70°14'32.683 N +E/-W 0.00 ft Easting: 498,310.16 ft • Longitude: 150°0'49.131 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50ft Wellbore 2K-14AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2011 7/1/2012 16.07 79.83 57,357 I Design 2K-14AL1_wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,820.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -118.50 0.00 0.00 325.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°1100ft) (1100ft) (0) Target 7,820.00 71.63 259.93 6,110.65 -1,265.26 -3,835.99 0.00 0.00 0.00 0.00 7,949.03 100.00 311.28 6,120.65 -1,231.07 -3,954.32 45.00 21.99 39.80 65.00 7,995.00 101.11 332.30 6,112.14 -1,195.78 -3,982.12 45.00 2.42 45.72 85.00 8,050.00 101.06 337.90 6,101.55 -1,146.85 -4,004.83 10.00 -0.09 10.19 90.00 8,120.00 100.56 340.71 6,088.41 -1,082.54 -4,029.13 4.00 -0.71 4.01 100.00 8,345.00 91.56 340.71 6,064.67 -871.58 -4,102.98 4.00 -4.00 0.00 180.00 8,695.00 89.35 354.53 6,061.87 -530.58 -4,177.84 4.00 -0.63 3.95 99.00 9,245.00 89.40 332.53 6,067.96 -6.41 -4,332.80 4.00 0.01 -4.00 270.00 9,595.00 92.30 318.83 6,062.76 281.91 -4,529.61 4.00 0.83 -3.91 282.00 9,795.00 89.61 311.29 6,059.42 423.35 -4,670.75 4.00 -1.34 -3.77 250.50 10,350.00 89.64 289.09 6,063.06 700.70 -5,147.46 4.00 0.01 -4.00 270.00 5/15/2012 12:54:41 PM Page 2 COMPASS 2003.16 Build 69 ORIGIN AL ti- ConocoPhillips or its affiliates ®�r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-14 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-14 @ 154.00ft(D14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-14 Survey Calculation Method: Minimum Curvature Wellbore: 2K-14AL1 • Design: 2 K-14AL1_wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map ' Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,820.00 71.63 259.93 6,110.65 -1,265.26 -3,835.99 1,163.80 0.00 0.00 5,936,945.87 494,474.27 TIP/KOP 7,900.00 88.90 292.13 6,124.48 -1,256.54 -3,912.96 1,215.08 45.00 65.00 5,936,954.60 494,397.31 7,949.03 100.00 311.28 6,120.65 -1,231.07 -3,954.32 1,259.67 45.00 59.35 5,936,980.08 494,355.96 2 7,995.00 101.11 332.30 6,112.14 -1,195.78 -3,982.12 1,304.52 45.00 85.00 5,937,015.37 494,328.17 End of 45DLS 8,000.00 101.11 332.81 6,111.17 -1,191.43 -3,984.38 1,309.39 10.00 90.00 5,937,019.73 494,325.91 8,050.00 101.06 337.90 6,101.55 -1,146.85 -4,004.83 1,357.64 10.00 90.10 5,937,064.30 494,305.47 Pickup RSM 8,100.00 100.71 339.91 6,092.11 -1,101.04 -4,022.51 1,405.30 4.00 100.00 5,937,110.11 494,287.81 8,120.00 100.56 340.71 6,088.41 -1,082.54 -4,029.13 1,424.25 4.00 100.38 5,937,128.62 494,281.19 5 8,200.00 97.36 340.71 6,075.95 -1,007.96 -4,055.24 1,500.32 4.00 -180.00 5,937,203.19 494,255.10 8,300.00 93.36 340.71 6,066.60 -914.01 -4,088.13 1,596.15 4.00 -180.00 5,937,297.14 494,222.23 8,345.00 91.56 340.71 6,064.67 -871.58 -4,102.98 1,639.42 4.00 -180.00 5,937,339.57 494,207.39 6 8,400.00 91.22 342.88 6,063.33 -819.35 -4,120.16 1,692.06 4.00 99.00 5,937,391.80 494,190.23 8,500.00 90.59 346.83 6,061.76 -722.85 -4,146.28 1,786.08 4.00 99.05 5,937,488.29 494,164.1311, 8,600.00 89.95 350.78 6,061.29 -624.77 -4,165.69 1,877.56 4.00 99.12 5,937,586.36 494,144.74 8,695.00 89.35 354.53 6,061.87 -530.58 -4,177.84 1,961.68 4.00 99.13 5,937,680.55 494,132.62 7 8,700.00 89.35 354.33 6,061.92 -525.60 -4,178.32 1,966.04 4.00 -90.00 5,937,685.53 494,132.14 8,800.00 89.35 350.33 6,063.06 -426.52 -4,191.66 2,054.86 4.00 -90.00 5,937,784.60 494,118.82 8,900.00 89.36 346.33 6,064.19 -328.61 -4,211.88 2,146.66 4.00 -89.95 5,937,882.51 494,098.62 9,000.00 89.36 342.33 6,065.30 -232.35 -4,238.89 2,240.99 4.00 -89.91 5,937,978.76 494,071.64 9,100.00 89.38 338.33 6,066.40 -138.21 -4,272.54 2,337.41 4.00 -89.86 5,938,072.90 494,038.02 9,200.00 89.39 334.33 6,067.48 -46.65 -4,312.68 2,435.43 4.00 -89.82 5,938,164.46 493,997.91 9,245.00 89.40 332.53 6,067.96 -6.41 -4,332.80 2,479.94 4.00 -89.78 5,938,204.70 493,977.79 8 9,300.00 89.85 330.38 6,068.32 41.90 -4,359.08 2,534.59 4.00 -78.00 5,938,253.01 493,951.52 9,400.00 90.69 326.47 6,067.84 127.08 -4,411.44 2,634.39 4.00 -77.99 5,938,338.19 493,899.19 9,500.00 91.52 322.55 6,065.92 208.46 -4,469.47 2,734.35 4.00 -78.00 5,938,419.59 493,841.18 9,595.00 92.30 318.83 6,062.76 281.91 -4,529.61 2,829.01 4.00 -78.08 5,938,493.04 493,781.07 9 9,600.00 92.23 318.64 6,062.56 285.67 -4,532.91 2,833.98 4.00 -109.50 5,938,496.80 493,777.77 9,700.00 90.89 314.87 6,059.84 358.47 -4,601.38 2,932.89 4.00 -109.51 5,938,569.61 493,709.32 9,795.00 89.61 311.29 6,059.42 423.35 -4,670.75 3,025.82 4.00 -109.61 5,938,634.49 493,639.97 10 9,800.00 89.61 311.09 6,059.45 426.64 -4,674.51 3,030.68 4.00 -90.00 5,938,637.79 493,636.21 9,900.00 89.62 307.09 6,060.12 489.68 -4,752.11 3,126.82 4.00 -90.00 5,938,700.84 493,558.63 10,000.00 89.62 303.09 6,060.79 547.16 -4,833.92 3,220.83 4.00 -89.97 5,938,758.33 493,476.85 10,100.00 89.62 299.09 6,061.45 598.79 -4,919.53 3,312.23 4.00 -89.95 5,938,809.97 493,391.26 10,200.00 89.63 295.09 6,062.10 644.32 -5,008.54 3,400.58 4.00 -89.92 5,938,855.52 493,302.27 10,300.00 89.64 291.09 6,062.74 683.53 -5,100.51 3,485.45 4.00 -89.89 5,938,894.74 493,210.321 1 10,350.00 89.64 289.09 6,063.06 700.70 -5,147.46 3,526.44 4.00 -89.87 5,938,911.93 493,163.37 TD at 10350.00 5/15/2012 12:54:41 PM Page 3 COMPASS 2003.16 Build 69 A � ConocoPhillips or its affiliates !3'' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-14 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-14 @ 154.00ft(D14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-14 Survey Calculation Method: Minimum Curvature Wellbore: 2K-14AL1 Design: 2K-14AL1_wp07 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-14AL1_Fault 1 0.00 0.00 6,074.00 488.62 -5,916.80 5,938,700.03 492,394.06 70°14'37.466 N 150°3'41.152 W -plan misses target center by 798.12ft at 10350.00ft MD(6063.06 TVD,700.70 N,-5147.46 E) -Polygon Point 1 6,074.00 488.62 -5,916.80 5,938,700.03 492,394.06 Point 2 6,074.00 -329.69 -3,096.29 5,937,881.17 495,214.10 2K-14AL1_T3 0.00 0.00 6,060.00 412.90 -4,537.61 5,938,624.01 493,773.09 70°14'36.730 N 150°3'1.053 W -plan misses target center by 83.615 at 9695.955 MD(6059.90 TVD,355.62 N,-4598.52 E) -Point 2K-14AL1_Polygon 0.00 0.00 154.00 761.68 -5,699.83 5,938,973.02 492,611.07 70°14'40.153 N 150°3'34.850 W -plan misses target center by 5935.13ft at 10350.00ft MD(6063.06 TVD,700.70 N,-5147.46 E) -Polygon Point 1 154.00 761.68 -5,699.83 5,938,973.02 492,611.07 Point2 154.00 1,163.85 -5,214.89 5,939,375.04 493,096.05 Point 3 154.00 459.06 -4,198.60 5,938,670.10 494,112.08 Point 4 154.00 -859.90 -3,570.17 5,937,351.13 494,740.15 Point 5 154.00 -1,429.09 -4,077.07 5,936,782.11 494,233.17 Point 6 154.00 -238.12 -4,598.44 5,937,973.08 493,712.12 2K-14AL1_T2 0.00 0.00 6,068.00 52.88 -4,496.53 5,938,264.02 493,814.09 70°14'33.190 N 150°2'59.853 W', -plan misses target center by 111.87ft at 9381.34ft MD(6068.04 TVD,111.46 N,-4401.23 E) -Point 2K-14AL1_T4 0.00 0.00 6,063.00 655.78 -5,205.75 5,938,867.02 493,105.08 70°14'39.115 N 150°3'20.483 W -plan misses target center by 73.60ft at 10350.00ft MD(6063.06 TVD,700.70 N,-5147.46 E) -Point 2K-14AL1_T1 0.00 0.00 6,064.00 -991.12 -4,113.26 5,937,220.04 494,197.09 70°14'22.924 N 150°2'48.694 W -plan misses target center by 49.82ft at 8236.03ft MD(6071.78 TVD,-974.18 N,-4067.06 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") („) 3,173.00 2,781.14 9 5/8" 9-5/8 12-1/4 10,350.00 6,063.06 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,820.00 6,110.65 -1,265.26 -3,835.99 TIP/KOP 7,949.03 6,120.65 -1,231.07 -3,954.32 2 7,995.00 6,112.14 -1,195.78 -3,982.12 End of45DLS 8,050.00 6,101.55 -1,146.85 -4,004.83 Pickup RSM 8,120.00 6,088.41 -1,082.54 -4,029.13 5 8,345.00 6,064.67 -871.58 -4,102.98 6 8,695.00 6,061.87 -530.58 -4,177.84 7 9,245.00 6,067.96 -6.41 -4,332.80 8 9,595.00 6,062.76 281.91 -4,529.61 9 9,795.00 6,059.42 423.35 -4,670.75 10 10,350.00 6,063.06 700.70 -5,147.46 TD at 10350.00 5/15/2012 12:54:41PM Page 4 COMPASS 2003.16 Build 69 øpGNAt._ ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-14 2K-14AL1 2K-14AL1_wp07 Travelling Cylinder Report 11 May, 2012 BAKER HUGHES ORIGINAL • ..,- ConocoPhillips or its affiliates Irl/ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-14 Project: Kuparuk River Unit TVD Reference: 2K-14 @ 154.00ft(D14) Reference Site: Kuparuk 2K Pad MD Reference: 2K-14 @ 154.00ft(D14) Site Error: 0.00ft North Reference: True Reference Well: 2K-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-14AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-14AL1_wp07 Offset TVD Reference: Offset Datum Reference 2K-14AL1_wp07 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,820.00 to 10,350.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,231.45ft Error Surface: Elliptical Conic Survey Tool Program Date 5/11/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 7,725.00 2K-14 GyroData_25'(2K-14) GYD-CT-CMS Gyrodata cont.casing m/s 7,725.00 7,820.00 2K-14A_wp07(2K-14A) MWD MWD-Standard 7,820.00 10,350.00 2K-14AL1_wp07(2K-14AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C.) 3,173.00 2,935.14 9 5/8" 9-5/8 12-1/4 10,350.00 6,217.06 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-06-2K-06-2K-06 Out of range 2K-08-2K-08-2K-08 10,350.00 7,800.00 849.16 241.41 708.53 Pass-Major Risk 2K-08-2K-08A-2K-08A 10,336.80 7,750.00 900.60 235.45 768.13 Pass-Major Risk 2K-08-2K-08APB1 -2K-08APB1 10,215.46 7,580.00 978.76 232.51 846.16 Pass-Major Risk 2K-08-2K-08APB2-2K-08APB2 10,337.03 7,750.00 901.16 235.48 768.53 Pass-Major Risk 2K-08-2K-08APB3-2K-08APB3 10,337.03 7,750.00 901.16 235.67 768.34 Pass-Major Risk 2K-08-2K-08BPB1 -2K-08BPB1 10,336.80 7,750.00 900.60 235.45 768.13 Pass-Major Risk 2K-08-2K-08BPB2-2K-08BPB2 10,336.80 7,750.00 900.60 235.51 768.08 Pass-Major Risk 2K-08-2K-08BPB3-2K-08BPB3 10,336.80 7,750.00 900.60 235.47 768.13 Pass-Major Risk 2K-09-2K-09-2K-09 Out of range 2K-10-2K-10-2K-10 Out of range 2K-13-2K-13-2K-13 Out of range 2K-13-2K-13A-2K-13A Out of range 2K-13-2K-13AL1 -2K-13AL1 Out of range 2K-13-2K-13AL2-2K-13AL2 Out of range 2K-14-2K-14-2K-14 7,832.55 7,850.00 41.17 71.53 12.45 Pass-Major Risk 2K-14-2K-14A-2K-14A_wp07 7,825.00 7,825.00 0.10 0.47 -0.22 FAIL-Major Risk 2K-19-2K-19-2K-19 Out of range 2K-19-2K-19A-2K-19A Out of range 2K-19-2K-19AL1 -2K-19AL1 Out of range 2K-20-2K-20-2K-20 Out of range 2K-21 -2K-21 -2K-21 Out of range 2K-21 -2K-21A-2K-21A Out of range 2K-28-2K-28A-2K-28A Out of range 2K-28-2K-28AL1 -2K-28AL1 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/11/2012 1:13:44PM Page 2 of 14 COMPASS 2003.16 Build 69 1-1)11- ConocoPhillips or its affiliates Ir/ii Conoco�'liilups Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-14 Project: Kuparuk River Unit TVD Reference: 2K-14 @ 154.00ft(D14) Reference Site: Kuparuk 2K Pad MD Reference: 2K-14 @ 154.00ft(D14) Site Error: 0.00ft North Reference: True Reference Well: 2K-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-14AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-14AL1_wp07 Offset TVD Reference: Offset Datum Reference Depths are relative to 2K-14 @ 154.00ft(D14) Coordinates are relative to:2K-14 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.02° Ladder Plot I 1 1 1 1 I I 1200 ' 1 I I I I I I 1 1 1 I I 1 1 1 1 I I I 1 1 1 I I _ I I I I 1 I I I 1 I 1 1 I I I I I I 900 ' C 1 I 1 I I I .12 1 I 1 I t I I t6 I 1 1 I I I 1 I I I I 1 IZ J J __ __J J ____J J _ 41 I I I I I I U] I I I I I I 41 I 1 I 1 I I rpt I I I 1 I I E., 600 C) I I I I I 1 I I I I 1 I O 1 1 1 1 1 I 2 I I I I I I C I I I I I I as I I 1 I I 1 V 1 1 I I I 1 I I I I I I 300 I I I I I I 1 I I I I I 1 I I I I I I I I I I I J J __ __J_ ____J____ J J I I I I I I I I I I I I I I I 1 I I I 1 I I I I I 0 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND 2K-08,2K-08,2K-08 VO 2K-08,2K-08APB3.2K-O8AP93VU -4- 2K-14.2K-14.2K-14V0 -)4- 2K-08.2K-08 A.2K-08AVD it, 2K-08.2K-088PB1,2K-08BPB1V0 2K-14,2K-14A,2K14Awp07VO - - 2K-08,2K-08APB1.2K-08 AP B1 E,0 --8- 2K-08.2K-08BPB2,2K-088PB2VD -a- 2K-08.2K-08AP92,2K-D8 AP 92 VD 2K-08.2K-088P1:13.2K-08BPB3VU CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/11/2012 1:13:44PM Page 14 of 14 COMPASS 2003.16 Build 69 ORIGINAL 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 kE (/( 2_/(-/(1/q 6- f PTD# ? 12 CB I ✓ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (�Gt�6�l ak— /(. POOL: k i- tt L eL C� t J 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 K/�a zK-/(4 , (If last two digits in Permit No. 2-f 1(0 CAAPI No. 50-/63-2C-1/47-- - D/. 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. 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