Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
210-115
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. 02) 0 - J I S Well History File Identifier Organizing (done) ❑ Two-sided II 111111 I III II III ❑ Rescan Needed III IiIIIIII I III RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: �Gr yscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: I a. OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: OM Date: a (f' 'ti. /s/ 111P Project Proofing I111111011111 BY: f�Maria Date: a /s/ rY) Scanning Preparation I x 30 = 3 0 + `i- = TOTAL PAGES 3 LI- (Count does not include cover sheet) r/Y/) BY: Maria Date: 6 , f /s/ r r Production Scanning 13111111111 Stage 1 Page Count from Scanned File: 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: (Mart) Date: /s/ 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: al 4 l l LI... Is,' Scanning is complete at this point unless rescanning is required. 111111111111111111 ReScanned 1111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked III Dliii 1111111 III I o c � ai co 4 co Z 0 y N N = O O) f%q� N 0 a)I ° . D X X C7 1 .4 } o a s O O 0 a; E 2 0 IX lo 17) o aa)) g E 11� 2 2 >m Z ° U OH 2 2 1- d u) c Q o a) o 0 0 0 ° ° 0 E. 0 0 -J N W V N N N N 0) d N V V V' o N N N N U � _I ‘.- 4 Z ' � , c o i 2 — c c c c c c y c = U a s O n a n o £E r)O O O O O O o o 11""' N J to -- Q c a) a) 0. 0 0 0 0 0 0 A0 _, v -0 a co rn rn 0) 0) 0) 0) jq a z z A/ ' C ILL) 0 Ci N. 0)) 00)1 00) 00)1 \�J/ Lf 0 Cl)� N. i N- I N. W Z d > V o U J o > U) U Z Q o CL re z o I- < V ca 7 N O a 0 i 0 .t;O c o 0 o >. E o I 'm O aN c Z J D c O E u m y I i E O n N in L0 0 E J (/) r...J N ' a Qr 0. i1 O O ~ O _ co �y� Z N la W > o C ''=A • m v+ u) Q D 0. a Y o m Q o Z a) '0 I W T j Y N U 0 CC a) .N 7c7) V to - . r. Ft) = N N U) Z 7 1 C c C C C C y d O o O O O O u°) f 0 co ` 7 ` 7 7 7 <o Z Q C 5 C C C •0 y Z rn „ .- E p IA o J y N M w H/j LJ Z m 1- V ..+ E O C Q r.c .O cO r =O W 0 Z N Q, �- d N Q O A .+ d y Z u. (.. > 0 LL? ° v 0 E m CC C 0 -- u u Ce .2 Q Z Q . .• ° 0 0 d En' d d N =° N O E Z W 0 2 r ` \ \ I U ° H a) a) • U h N.' E d E Q y J y 0 w ° -y o) a o o m 0 0 o O >° C c ac)y I o 0 d Q T re 0 F- J 0 F- W W J J J 3 Q 0 Q Q' 1 U 0 Company ConocoPhillips, Alaska, Inc. Well Name 3A-17AL2 Date 11/22/2010 nocoPhillips Alaska Greater Kuparuk Area*** Data Distribut 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 Fina ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 hi Christine Mahnken 1 Graphic image file 1 Disk / 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP i rdc a • Petrotechnical Data Center, MB33 1 Graphic image file 'i Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP -;; y-;y?p;o `; Glenn Fredrick 1 Graphic image file 1 Di k*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS MRT 1 hz State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer/ Rig Foreman TOTAL Hardcopy Prints 4 Graphic Image File 4 1 t (eLt ( cal U &• ao43a Page 1 of 4 7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development IN • 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.: October 11,2010 • 210-115/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 October 3,2010 . 50-029-22691-61 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 663'FSL,785'FEL,Sec.7,T12N,R9E, UM / October 7,2010 • 3A-17AL2 Top of Productive Horizon: 8. KB(ft above MSL): 82'RKB 15.Field/Pool(s): 1105'FNL,2471'FEL,Sec. 17,T12N,R9E,UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): • 247'FNL,3329'FEL,Sec. 17,T12N,R9E, UM 7362'MD/6006'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-507663 , y- 5997044 - Zone-4 • 9200'MD/6150'TVD • ADL 25631,25632 • TPI: x-511265 y- 5995281 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-510402 y- 5996138 Zone-4 nipple @ 508'MD/508'TVD 2564,2565 18.Directional Survey: Yes Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1445'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 7397'MD/5955'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. 121' Surf. 121' 24" 212 sx AS I 7.625" 29.7# L-80 Surf. 3821' Surf. 3306' 9.875" 1020 sx AS III,340 sx Class G 5.5"x 3.5" 15.5#/9.3# L-80 Surf. 7782' Surf. 6334' 6.75" 190 sx Class G 2.375" 4.6# L-80 7760' - 9198' - 6136' 6150' 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/ND) 3.5" 7272' none slotted liner from 7777-7970'MD 6136-6116'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 7972'-9197'MD 6116-6151'TVD l$ I I $', DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 17,2010 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/19/2010 12 hours Test Period-> 984 338 963 24 Bean 421 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 179 psi 269 24-Hour Rate-> 1805 760 1893 23.5 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 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 1ECEI VEms''` RBDMS NOV 0 5 2010r Oil ry v p 1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE U�� Gas mit or COPS. a ol-nl" "' . I L I 11' `!/�/d Q� �� y - , G 28. GEOLOGIC MARKERS(List all formations and markers wncountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1465' 1445' needed,and submit detailed test information per 20 AAC 25.071. A-2 sand 7565' 6122' Bottom A-2 sand 8842' 6147' N/A Formation at total depth: Kuparuk A2 sand 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,definitive directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 th q11(05110 Printed Na V.Cawv Title: Alaska Wells Manager Signature Phone 265-6306 Date li�lA4r0 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 ti?1 . KU P 3A-17AL2 ConocoPhiftips a wen Attributes --- Max Angle&MD TD Ala+ a Wellbore APW WI I Field Name I Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) yapi,y�r5 500292269161 KUPARUK RIVER UNIT PROD 9,198.0 Comment HYS(ppm) Dab Annotation End Date KB-Grd(R) Rig Release Date -- SSSV:NIPPLE 220 3/15/2009 Last WO' '. 41.00 9/2/1996 WAf Cglgt.-.3/G17 1/031201074755 AM --.---- ._ - Last Nil Annotation Depth(ftKB) End Data Annotation Last Mod By End Date I.....:.-... Last l ag: Rev Reason:SIDETRACK WELL w/LATERALSI Imosbor 10/12/2010 Casing Strings � �:. f Casing Description String O String ID_.._Top(ftKB) Set Depth P th(f. Set Depth(ND) I Strg Wt String String Top Thrd HANGER,37 LINER A LL 23/8 1995 7759.8 91980 n.60 L80 STL Liner Details _ Top Depth -.. .. ITVDI Top Incl ID(M). Top(REEL (ftKB) (') Item Description Comment ID(in) CONDUCTOR, 7,759.8 BILLET ALUMINUM BILLET 1.995 40'121 7,768.8 ANCHOR OPEN HOLE ANCHOR 1.995 NIPPLE.508 -- 1$ 7,970.9 ,DEPLOY SHORTY DEPLOYMEN I SLEEVE 1.995 Perforations&Slots �, ---Shot GAS LIFT, Top(11/0) Btm(TVD) Dens r 2,962 :: Top MKS)Bbn(RKB) (ftKB) (61KB) Zone Date )oh... Comment 11 7,777.0 7,970.0 A-2,A-3, 10/8/2010 32.0 SLOT Slotted pipe-0.125"x2.5"@ 4 ;: 3A-17AL2 circumferential adjacent rows,3" centers staggered 18 deg,3' •,"(. t non-slotted ends ,I. 7,972.0 9,197.0 ---. A-3,A-2, 10/8/2010 32.0 SLOT Slotted pipe-0.125'52.5'CO 4 • 3A-17AL2 circumferential adjacent rows,3" SURFACE, -/ centers staggered 18 d 3' 39-3.621 99 e9• Inon-Slotted ends GAS LIFT. :-... Notes:General&Safety -- -------__----- -- --4,236 " End Date Annotation 10/12/2010 NOTE:WELL SIDETRACKED,3A-17A,AL7,AL7,AL2,AL2-01 GAS LOT 5.254 GAS LIFT,- 6,114 ...-4 GAS LIFT, 6,753 GAS LIFT, __ 7,196 NIPPLE,7,251---- i 1 SEAL ASSY, L__---1 I 7.258 ---_ I ! WHIPSTOCK (AL2).7,396\`_. 7,388-7,420 WHIPSTOCK, 7,412 PRODUCTION\ 5.5'835 . , \ - 35-7,782 SLOT. 7,777-7,970 SLOT. 7,488-8,396 SLOT. 7,497-9,249 SLOT. 7,972-9,197 LINER AL2, ' 7,7-1701.26 TD(39,-1]9,1 9), 9,198 LINER AL2-01, 7.381-9.250 Mandrel Details $j She Top{kKB'Top /TVD/thy Top Port (TVD) Inc! OD Valve Latch Size TRO Run ( ("I Make Model (!n) Sery Type Type (in) (pai) Run Date Corn... { .6 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 8/20/2010 LINERALI, I 1 2,961 2 4,235.5 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 9/14/1996 __------._ 3 5,254.5 BST ATX 1 GAS LIFT GLV T-1 0.156 1,335.0 11/30/1996 Note 4 6,114.3 BST ATX 1 GAS LIFT OMY T-1 0.000 0.0 9/14/1996 5 6,752.7 BST ATX 1 GAS LIFT DMY T-1 0-000 0.0 8/22/2010 6 7,197.8 BST ATX 1 GAS LIFT OMY T-1 0.000 0.0 2/4/2007 Pli 0 \ O r. ° n a n b v 0 j C 1-00 O g�` N O> OE V 'J O d w N v I-c n m M_ n O E I JA @).2 N a w o II ° b `y G , Q F-(n J I o E o J @B-' 111 . G o N La `N"' \\\\ d 0 �\. o M � n 114...\\\ca NI-y ' N V 1\\\ °• ou) © 9 I \\\1 0 /NV� I_ E 1 a V 0i1 t0 a- O %% 11 o co C C $ \\I II II 0. p E N ;; 45 =. I I // w v 0 _ 'C0 c a I I // 00• 0 0� o E E d o � ////: N 0 ak N ,,, — J° p O c U 6 co U M QF-COW< // N fV (V tV N i/ Y 1 CO 1 i i/ // N cn // 1 V / a o / CD O \ iii t 21=1:)///�illj o iv 411 ! iLLiEiI ICI` -�:\ U \ o I ri J �3 t p k \\ 2 o CO C I 2 rid o.r- \\ Qn LL aN °m ,v M a c- .0°c° mg oX Un m � n \\\ CD w \\ �2 �n o o`n I 11 (V =N n y uY i II CL Q <0 ��pp D Y 11 II t0 V J m LII I°r 11 r E Ud II ° 0 _J o� 11 II I- c.) Q E,� �,2 II I. A oy Q � �f? U U O C w 5 J rn c r J° O N I Q F-cn 0 Cr) • ri Lie z Wtgo to fitz co V ca co a co w it cin RS ,a 2 cn Z � . to MC =OM INNIMM O CL , ca c0 o V O > Q r > O ■ N O -� N L = L N &.- &.- 4- O t .0 C 0 a a- r 9 CO W o ■ z Cr)co kilt )n b S MVV ^F. m M m R O O) O V -co N r ° N ,- N OM (/) c to 3'O h O v N ` o r- y W c co Cl) Q. 0 C 0 C o T iii O (83 O o L.s O in N O N ° O R > Cl) N O W CO - N N O -I N 3 6 0 w C 3 0) 3 N O Ol m J _.1 V' O) CO L Q- O N N a C c ° (6 N 3 3 (o O 0 CK W 2 > N a E 0 o i d O) co c (V N 0 cII c O 'N co�` a0 Y I` V a Q N w j- O C 'Q '6 as 3 E , U N })v 0 C O C (.Qj• Q Q i 0 N U O c0 co co (o c') F 2 W a) N a m V1 4 c Ts o co > v N s v (o c m O CO O 0 t W rn LO c rn CO rn a m O - .0 N v -a 0 0 C 3 ° n CV C > ° m ro s N m C •... a w m U 0 c a a >. (a ° m U V o m O 0 z U J 2 z N a 3 v F- + O O} 3 3 To c rn d 1�- C7 ° s c .c °) z w � ' N >. a) CO o c) G) O G (N E co R C Cl) 0) O J J CV o Q C N- < u) (n = ' m z Q E °m m co M cr C 1-- Z _ 0 0 0 N .0 T O Q (6 — N O O O O N a a) 1` n O t w U m .- D a) 0 v a ° a to co i rai co Q D p > m Z a) o co co E 4.01��yr,rr� - > d N N c0 J z O J s L c¢7 m 6' N ^ N N. O a00 CO o - - Q (/) m 'C o CO h O CO 0 CO Q O ‹k O N (V U• Y Y co i M M a E o 0 d c O V O c N N N a. m E .d .rN v p U d n O L a. W 0 O R O" O c i• m O o 0 c Z >. ^ 0 (0 o 0 a m .. s 0 d (A ° N a J) c m N 0 0 `4- o °) OD•pO m m 4 N m R _ R m 7 0 W ,„ m d Gf m 0 3 C 1.00. _h55o a 202 3 3 a 3 2 ° a > > co o C) 110 Y CO MV U a O • O kill v., Q oa co i:IC — C O -O -6 -O 0 O d N N Q N N. O W M� ~ C fln O . 0. 0) C a a 0 � a a Q H Y c c c Z 0 U m E m Z 0 0 > v M M M M M M M (-•, 00000, 0, M M M M M M C7 C7 C] M M M M M M M M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LO CO V 0) LO n " CD O m CD O m Ca O n O n O CM N CO CO O m 'C CO N CD d'' <" <- C co 4 M V CV O n V co Y co V' CV m O O O O CD .-- 0 O CO O N CO, N O N N Q 1O co 1O n co M N CO •- CO V to N CO CO M n 0 L- 0 0 " N M R n '. n CD •- d' CD m 0 L- CO V V CO a) V CO N O m CO CO " CO CO N CO CO CO C) n 3 3 t i) N- N- N- CO m CO CO CD 0) m C m CD U) CD m CO N- N- CO CD CD CO C Cp m 0 M M M C7 C? C?- ?) M M C''. M M M M M M ''.5. C?-. C?-. M M M M M M C?'. C7 C7 M C7 C'.) W W N a ..i O O > 2 e-- ' O CN m Cn O a) M n M n n O M R O M m O n O O n O m M m " m O n m O M O O d 0)Q V O 6 n o h D D D 6 O r D D O D n h 4 D co CD D r--:N N co c .1 " co co co N N N N N N N N N N N N N N CO N N N 6 O U N) o v© © E m N- D Q n n CO M '7 CO CO LO CD LO m LC) CO V O m CO N O O N C CO CD LO O CD n CD £ 2 V m 0 a- co N- N- 0 O m n CO a, O V n n O 7 0 N N Co O C O m a) co Q <k i _O 0 m N m O " O N O M O M O M R M m M O 6 m M 7 0 M m O 6 N 4 O M C n N CO n a) N CO n O M O CO 0 N CO V' CO CO CO to 'C C) m O V " o) O co Can CD F 2 w •^ O N N N CO CO CO V V' '7 '7 V '7 cC 7 V V V M M M CO N N N R CO CO CD Ca Cn m 1O CO to CO to CO N to to CD to CD to to CD to to CD CO CO CO Cn to to -t W /U) 0. mC .0 0 i.f. G 0 N N CD R " CO CD CD n M m 0 CT O O O CO N d' C() O CD CO N- CO O N CO CC) M me. CO CD m CJ n M CC) O M M V M O 4 M DC 6) M M O O D O) m a) R 66 " m = >, 0 2 a O O n D DC O O M O O m C M Q O Cn CO 4) V N 6) M O C N n N O C N O M m m N m m a) O N M CO m O M O a) N O C O O M CC) n a) O N co V L' Q) C4 C Q.- M M N N N N N N N M M M M M V V 4 V Cn CCU to O O O O O N N N n 0. 2 t0 V '- 0 rn rn DC a? C rn a) rn rn am a) rn op rn C) O) o) o) o) am a) rn rn o) rn o) a) o) a) C) O G Z lC1 N 1n m In 6 Ln Cn N up- Ca Cn to- CO 1O 1O 1O CO CO CO 1. Cn to- up to 1n N U In Ca- M 'a c V m 3 N o• 0> Q i i w N C o ) d m ca a'N O m O m O m O CO CT V N N M O O Cn O O n V V V M M CO O O m a O C.) m .� f6 CV 1O N- " O CO V N- 7 LO CO C CO O CA CO N- n CO R O CO M CO m CD m " " Ca 'V a CC R r, ' .Q co' 4 O n N CO O R N a O m O CD O CO CO N O 4 a) O O 6) n 7 O a) " N (3) O Q E IS O O m O M CD m .- C O m " < -,, r-- coma) a) O m O V N O m CO N O N v v ..t. CO in 1a Co Co co O n n n n N- n 1 1--- n 1-- - 1-- I- Co CO CO CO 1n� > - Z W r M M C M co r M M M M M M co M M C M co- r M M M M M M M M M CJ ca 0 + n CO M " m N m COCOON- O a) O O " O m IO M O C C') a) CO O (D M CO M N O a) n N 0 0 0 0 m CA N OLD ,- m m CO CO CO 7 co V co V m P 0 a) CO m n M d' M m 0 m V 6 r- N M 6 6 6 6 4 S N O O n (a N • " R O 6 6 6 6 6 O R N m O M m O N a) (0 M O) N O 7 N L- 0 • r n N- N- r N- N- n n n n n O O O O CO CO CO 4 V ,c V co co co co co co. Ch (00, 0000 0 0 d' CD O CO CO CO CO CO CO n CO CO CO V 7 " a) CO N O n n CO N... CA O CO CO N N CO V' V M CD CO n m <h <t 6) CO 4) " O CO O CO N- CO O 7 " O M O O 6 <Y 6 V .- O m m O V N 6 la N m O V N N M O m O . n O n a) s- N M V CO O O O O O 6 4 V V M M M M M M M M M M 44 m a) a) moo O O O O O O O O O O O O O O O O O O 0 0 0 0 0 O O CO 1O CO O O O O O O O co- O O O O O O O co O O Co O O O O O (.6 (.6 C CD CO m CO O O <t CD 6) CO CO CO CO CO CO n CO CO CO V a 0 m N O n n V CO 6) 6) CO N N N CO •t CO CD CO n CO V 6) CO CO " O CO 0 CO N- CO O R " CO Q^ 1O N 5°- n Si O n O M m 0 0 m O V n V O m O d' V• M M 1O m 0 N M Ci 0 w CO M n a O " N M M V V M M M M N N N N N N a) O O O O F`- CO O O O O O O O O O O O O O O O O O O O O O O• O O O O O CO O —CO Y N Ca }' C O V O O C) V m N- CO CO O N a) CO N- 0 0 CO N- V N N V CO 7 CO CO O CD 1O a D L5 M in 10 10 CO M n N V O m V O CO 1O NY O m 60 6) O .- O N O M 'R CA 071. CV N N N O O 4 n d M O A M O m 0 .. M O n 6 O N n M m M a) 7N CD Vi 1 O_ a Q N " " " v- O a) m n O O CO <f M N " " O R M N N 0006) CO C M M M M M M M M N N N N ] aC L E C) .— O 7 7 YrY 0 CO cu n N- h- O W O V CO A V O N N N m 0 O R M N " O O O O " M M O 6) t c U_ c " M V O CON- NCO V M L- O a) " " O M a) U) m N ' M N O M CDm n V F t I O = = CO CO CO 0 C CO CO C W m U )) D O 7 m Ci OJ N ) 7 D C m N- CD V ri — — — N- O V O n O p M M v n CO CD N- n n m m rn rn rn rn rn rn C) rn rn rn m m m m m m fy o ) 0 O N O O N C' N- CO CO 0 m O O 117 V V O CO CO 4) O V C) O CD CD CO N O O CO n CV CO 0 'R V n M CD O M ,r CO 'C CO n O O CO O m CO CO CO O " 6) N n CO n O T m N- D O O O O O O O O O O O O O O O O C 0 0 0 0 N O O O 0 0 C) C a aA M O d N Cn co .- V n O co O A N CO CO V n O M co a) N to m V p c > N CO V 'N V CO 1) O CO CO CO n n n n CO CO, CO CO C D CO O O 0 0 " " s N N Q / a. N _ 2! Of m G N- N- 1- n n n n n n N- N- n N- N N N N N- N- h n co CO CO CO CO CO CO Co CO F w C1 fL. t%? .`�'. " to 0 (r le I 0) AO a CO 0 0 N al CO C) Q Sc 0 U a) E co Z O O F T coop co rococo M M M M M M M M M M M M M M M M M co M M M M cocoa) m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0: U) 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 U) LO LO 0) V CO LO O N LO CO V CO N CO 0 V CO 0) CO ' N •- U) 0) O) 0 V O N O C (O O co U LO co co N V co V u) n 0) co co n co co 0) Ni r O r ,- co .- V V N N N o O U O N V O V h O A O O d O O N M n D N O CD r O O O O o C O z U N O N- U) co O n V U) LO N O L- V co U) N O CO CO ,- CO LO N O ti V N :E' V..U) U) U) 'Cr "Cr "Cr V CO M co N N N N O O O O 0) O co co OO co co n h r CO m m M M M M M M M M M M L M M M M M M M M M ? (V N N ci. N N ci. N N ( N O• O >N N v v O r� V V n O U) (O V N- CO O LU co co M N V V CO 0) N- O CO O N CO CO OD N O O 1� r O O M U) O co. LD OO co. co. 7 M U) 0) OO O co. co. U) M N O r N CO. n V V 6. O O �- G M U) s— V N O) CO CD CO N I N- CO LO CO o V N- O N- ,— r O CO LO 0) CO CO J N U .. 0.. N .- N CO• oD\J \J E LO v , � 0) 0 O CO d' V V L CO CO V O CO O V D n n CO CO CO N U) U) O N N CO _ ,- m � V co M V r D ? N D O N- .- 0 (n V CO � � N N U) OD co O N ..- (O N- < L C o co � h r L� : M O `n U O U V V U V N di V D ,- M V V n Ni: O M W V Oi M M M F CO 0O LO N 0) 0 d .- A U) U0) M Lc � r O V r O o O O h n LV — V) LV D V N R roE- - — O � 0 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 0 o (D- E W Ln co co U) LO LO U) LO L U) LO u) to in LO LO to N N 6 LL7 L0 L0 to to Ln LO LO LO to La ^ {m� O o . N(D i.. ..c L0 OO CO 0) N `- CO N V CO N- `- O •- CO V 0) LO LO OO L- O LO CO LO CD LO N- CO W W N V CO CO 0 N CO 'Cr to co t- to N O V co N N- V O V up •-• .- Ni r N V CO V O m CD r .- M M M LO O O M O D O t- V D 0 V (0 O co D N co n O co 05 o N`Y m 2 C V U) U) LO L0 LO CO LO CO O) .- N V N- O ,- co to 1- O 0) O N N CO U) LO t` 0) -- s O) C Q t ti r N- 1` N- N. N r r CO CO CO CO CO 0) 0) O 0) 0) 0) O O O o o O O O O Q, -' ' C R -'rn rn rn rn to- m .. ..-,- rn rn rn C) rn m rn rn rn rn rn cu m ( ( ( rn rn ( rn cc rn rn = R 8 'R 20 m m rn rn rn 0) rn 0) m rn m o) rn 0) 0) 0) 0) 0) rn 0) rn 2 rn rn Cn rn Ca rn rn rn 2 0 (.j _5 v v _ � 2 Lri LLi Ln Ln LL) LC. 1. Lo Lri Lri 0 Lo Lri LU Ln (6 Ln (6 u) N LLB Ln 6 Ln 1 LD Lri U Lri Ln up- 1' O 0) `o E w m o .. ro m .. m _ r1 C m y O 0) U) V U) N CO CO O N- N- CO N O OD N- CO 0) N 0) 9 CO O LO O 7 V o w ty V O C_ V m >s co V O co O O O co co o V co M O V O CO W N- CO CO O CO N r co co N m ....5 M M M M M M R U) N: — Ln O . O U) O V f` 0 0 `- N M 4: O V t- (D 0 R 4! s V t- co to N 0) co co O co to M ,- 0) N- U) N O CO LO N O r V ,- CO LO N O CO CO Q) O O a O O .1 E U) U) V V cF CO CO CO CO CV N N N .- .- n- .- O O O 0) 0) O 0) OD CO_ co U) r r Q a Z CO Q M co co M M M M M M co M M M co- M M M co- M cM M N N N N N CV N N CV N CO `- O V CO CO r 0) V' N CD CO r V O 1- 4) r O 0) N- O 0) O 0) CO N- CO V CO 0) N- U) N CO n LO V ,- r N LO CO V V' V O N LO .- O LO CO CO N. N at LO O) CO O LD V V V LO O n V r O O (O M .- 6 LO - O) 0) - U) LO 0) n M n co (O N O O 0) 0) 0) 0) 0 N- CO LO CO .- 03 N- LO CO ,- CT N- CO V CO CO N O O) CO LO V CO E CO CV N N N N N N N N N N _ 0 O O O O O O O O m 03 CD a) LA CD O ti O U) OD N- N- CO CO n V V N N CO V N CO O O •- N O V 0) U) CO 'Cr LID c0 N CO CO Ln 0) co r- N V V O U) O O V co O 7 h 0 u? co 7 V V V co U) 0) M V V V M N ,- t .- N V LO 0) M Ln 1- O N V 6 t- V h N- O U) V V N O en•-•y V V V V V V V V V V' V V V V LO U U o co LO O N- N- ti N- N- N- n n n r 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O O O 0 0 0 0 0 O O O v (O (O (O CO cc (D (D (D co- (O o (O (6 (D (O (D (D cD (O co- (D co- co- O (D (D (D (D (D LO O O r O U) CO 1- N- CO CO N- V V N N CO V N CO O O N O V O) LO CO Cr LO CO CO CO N- LO 0) OD 1� N V V C) U) 0) O V CO O s- N- O u? U) .- d' V 'Cr OD LO 0) CO N N N N O 000^ N N N N N N N N N CO M CO M M CO M R V to LO U) LO LO U) LO U U to U) C _ .i co-M O o O O co-O co-O LD CO tD t0 (D LO co-(O cD (O (O O 0 (O (O O (O o o co- co- (O (O (0 (D R ) co .• C CC 0) 0) CO r U) N 0 0) CO CO CO CO U) U) (O CO N r O CO 1) N 03 LO N 03 O N V Q -tO V CO U) M CO O 1-- O O r N- V O 0) t- at N N N V CV N O (V 0 U) CO N .- r .- O O U N N O) R O) 7 ,- D O O 7 O CO hi: V 1+ N V O IO O O O V . N d 7 O 1N 1N LU h 1N- N N N O O M M M N M M M O O N) O 0N N N N N T O O O M M M( r 0 E. ...?- L W M d Y Y "row 8 L i 0 (U (6 h V co (O O N N 0) LO CO O OO V M CO V (DCVO V M M r M N M O C011- 01 C U. 0. ` .- O A N LD O V ti U) (D N O CO U) CJ U) (D M V O O M M O M M CO V (0 N V O F co O O - N 7 O O OO r (O V N U) U) to (D LD V M M V ti N V V Cl. `` O Y Y M co co C `O.- co co 0) 0) O O 0) co co co co co co co co co O co co co co co co co co O LA co co co 0) d O N V O N O 1� O N N V O) V O (0 OD M CO NO O O 0) CO LO N CO CO O 0 co r (O co r co co co n c0 CO r O W O) LO Cl. CO U) V CO CO n U) V CO CO CD OO T O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O N O 0 0 0 LJ m ti O co co 0) N U) co •— V N- O CO CO O N LO CO 1— V N- O co co co N U) co V co " C .. _ L 0 CO_ o O O .- C ++. N CO CO CO M V V V U) U) LD (O co(O co,(O h h co c0 co O co.(0 O O) O O O ♦i. Q. N _ ,Q » m � co co CO CO CO CO CO CO CO CO CO co CO CO c CO � CO CO CO CO CO CO OD ao rn rn CD CI) CD rn N j Ci O in O co O co INI co kill 1 ki4g a m co gZ -,-- O °o 0 _ N N co O co Q Z 0 U as E0 Z o o o O -w r I- > 0 0 I,w = ; a Cl) a LO _ N N W C M C3 G RS RI .a. m 5.N CO >d) o o 7 -o O O o °o co n- N 0 o N N ° J w co U m boy £ m N- = Q N Q Q i _CO at ch c-) r F w ca c co E W O w U) V ii (1) 0 c o 0. i t co > m 2 m ai S N C4 c at a o � � z is ..;.= 2 0 rn 0 U) c v ci c f0 z ,o L0 0 3 m Ci a m rn C '..�—.. o m d m V m a O c m d re co � as N a 0 o 0 V Cl)' d12 t 2 .0 m o p � N J m z N 0 `-- ti_ co co• 0 z , + .. 0 47 2.)43 C w 0 3--- L 0 CD O 0) ti a c >w 6 H� 6. m Y Ca (0 C Q D - Vf a a7 a o Lfr to L 2' M Mini a Y Y • - O i i e.. O a7 0. a)C p 4 V ; ;: :. ; ;��� .1 N N o O 0 O ,.d, d d d 3 C9 4 co 0 co o Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:00 15:30 1.50 100 7,200 PROD2 DRILL TRIP P RBIH 15:30 15:45 0.25 7,200 7,300 PROD2 DRILL DLOG P Log for Tie in -4.5'. 15:45 17:00 1.25 7,300 9,432 PROD2 DRILL TRIP P RBIH,close EDC @ 7402' Tag TD @ 9432 17:00 17:30 0.50 9,432 9,432 PROD2 DRILL CIRC P Circulating Beaded liner pill down coil 17:30 20:18 2.80 9,432 71 PROD2 DRILL TRIP P Trip out of well laying in beaded liner running pill/KWF Paint EOP flags @ 7200,6200 EOP 20:18 21:48 1.50 71 0 PROD2 DRILL PULD P Lay down BHA#12. Blow down and break down. Prep to run liner 21:48 22:15 0.45 0 0 COMPZ CASING PUTB P PJSM, P/U AL1 lower section of liner Indexing guide shoe,32 joints slotted liner Shorty deployment sleeve Perform safety joint drill 22:15 23:06 0.85 0 0 COMPZ CASING SFTY T Hand Injured on rig/transport to medic/Stand down 23:06 23:59 0.89 0 0 COMPZ CASING SFTY T Stand down 10/02/2010 Run AL1 Liner in two sections BOL 9430'TOL @7411, RIH with Upper Whipstock 00:00 05:00 5.00 0 0 COMPZ CASING SFTY T Suspend ops for injury investigation 05:00 08:00 3.00 0 0 COMPZ CASING PUTB P PJSM-P/U liner. 08:00 10:30 2.50 0 9,432 COMPZ CASING RUNL P RIH W/liner run#1.Get pu wt of 30k. Rih down AL1 lat, smooth all the way to tag up 9432'.Pump off liner w/no problem-POOH 10:30 11:30 1.00 9,432 9,432 COMPZ CASING DLOG P Stop @ 8210'. Re-set bit depth to 7175'. Log down to RA marker, TOWS @ 7413'. PUH,paint flag. 11:30 13:15 1.75 9,432 0 COMPZ CASING TRIP P POOH to Surface. 13:15 17:00 3.75 0 0 COMPZ CASING PULD P OOH. Conduct Un-deploy safety meeting.Stab off well,LD BHA. Load up AU Liner#2 17:00 18:24 1.40 0 7,238 COMPZ CASING RUNL P RIH W/AL1 Liner Run#2 18:24 19:18 0.90 7,238 7,229 COMPZ CASING RUNL P Stop and correct to flag,-8.3' PUW=29k 19:18 19:33 0.25 8,396 7,247 COMPZ CASING RUNL P 8396',Tag up, Pump off liner, 1.3 BPM @ 39K PUW=26K TOL=7410 Remove Liner lenth from counters PUH to 7170 and tie in 19:33 19:39 0.10 7,247 7,198 COMPZ CASING DLOG P 7170,Tie in,-.5'correction calling TOL 7410 19:39 21:24 1.75 7,198 65 COMPZ CASING TRIP P Continue out of well 21:24 21:39 0.25 65 65 COMPZ CASING SFTY P PJSM/Flo test well 21:39 22:33 0.90 65 0 COMPZ CASING PULD P Lay down BHA#14 Liner running tool 22:33 23:51 1.30 0 70 PRODS RPEQP1PULD P P/U BHA 15 Upper whipstock Surface test tool,tag up and set depth Open EDC Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:51 00:00 0.15 70 70 PROD3 RPEQP1TRIP P RIH with whipstock 10/03/2010 Set Upper whipstock @ 7395', Mill Window 7396.7 to 7402, POOH for full BOPE Test 00:00 01:48 1.80 70 7,205 PROD3 RPEQP1TRIP P Running in with whipstock 01:48 02:00 0.20 7,205 7,226 PROD3 RPEQP1 DLOG P Log Gamma tie in,-8'correction, Shut down pump close EDC, PUW=29k, 02:00 02:30 0.50 7,226 7,403 PROD3 RPEQP1WPST P 7403.7',Orient to high side,TOW 7395 Pumps on,Tool shifted @ 3700 PSI, Set down 2K POOH 02:30 04:15 1.75 7,403 63 PROD3 RPEQP1TRIP P Trip out of well 04:15 05:00 0.75 63 0 PROD3 WHPST PULD P PJSM/Flo check well. Pull BHA #15 from well Whipstock setting tools 05:00 06:30 1.50 0 0 PROD3 WHPST PULD P P/U BHA#16 Window milling BHA .6 degree motor,2.74 Mill and string reamer 06:30 09:30 3.00 0 7,380 PROD3 WHPST TRIP P RIH W/Window milling BHA stop @ 7380' 09:30 11:30 2.00 7,380 7,380 PROD3 WHPST DISP P Arrive @ 7380'.open EDC Pump 20 bbls viscosified spacer,displace w/ drilling fluid&recover KWF.Shut EDC 11:30 16:45 5.25 7,380 7,402 PROD3 WHPST MILL P RIH,dry tag whip stock @ 7397' PUH to 7288' 27k pu wt. Pump on line 1.41 BPM @ 3600 PSI FS. RIH pinch point @ 7396.77 stall out motor. Pick off,start time drilling. 16:45 20:30 3.75 7,402 7,412 PROD3 WHPST MILL P 7402,Call BOW,start milling formation down to 7412 per procedure 20:30 22:00 1.50 7,412 7,412 PROD3 WHPST MILL P Ream window 22:00 00:00 2.00 7,412 200 PROD3 WHPST TRIP P Dry pass through window looks good Trip out following MP Schedule PUW=28K 10/04/2010 Complete BOPE test,Witnessed by Chuck S.AOGCC 00:00 00:21 0.35 200 0 PROD3 WHPST TRIP P Continue out of well with window milling BHA 00:21 02:00 1.65 0 0 PROD3 WHPST PULD P PJSM, PUD BHA#15 02:00 03:00 1.00 0 0 PROD3 WHPST CTOP P PJSM Unload PDL 03:00 03:45 0.75 0 0 PROD3 DRILL CTOP P Service tree and valves 03:45 04:00 0.25 0 0 PROD3 DRILL SFTY P PJSM for BOPE Test 04:00 16:00 12.00 0 0 PROD3 DRILL BOPE P Perform BOPE Test. Have to change out B-4. Re-tested good. 16:00 17:15 1.25 0 0 PROD3 DRILL BOPE P R/U to test Inner reel valve,remove checks from UQC,Stab on Injector 17:15 17:45 0.50 0 0 PROD3 DRILL PULD P Prep,pick up Build section BHA. reinstall checks in UQC Page 14 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:45 18:00 0.25 0 0 PROD3 DRILL SFTY P Post BOPE test, Pre job. Normal up &BHA pick up. Crew change,Valve alignment checklist 18:00 18:45 0.75 0 0 PROD3 DRILL CIRC P Circulate coil back to drilling fluid Un stab injector 18:45 22:15 3.50 0 0 PROD3 DRILL PULD P PJSM, Load PDL with BHA#17. Pressure deploy 2.0 Degree motor and Bi-Center Bit. Surface test tool 22:15 23:51 1.60 62 7,205 PROD3 DRILL TRIP P RIH 23:51 00:00 0.15 7,205 7,215 PROD3 DRILL DLOG P Tie in 10/05/2010 Drilled build and turn for AL2 lateral. Tripped during build to reduce AKO in order to stay on plan/in ploygon. 00:00 00:06 0.10 7,215 7,223 PROD3 DRILL DLOG P Tie in for a-8'correction, Close EDC 00:06 00:27 0.35 7,223 7,412 PROD3 DRILL TRIP P Continue in well to drill Swap to new Mud 00:27 01:33 1.10 7,412 7,461 PROD3 DRILL DRLG P Clean pass through window, Dry Tag @7412 PUH, PUW=28K 1.4 BPM@ 3300 PSI FS, BHP=3899 01:33 02:03 0.50 7,461 7,202 PROD3 DRILL WPRT P Wiper trip to tie in RA.Getting to much DLS Est-40 degrees 02:03 02:09 0.10 7,202 7,218 PROD3 DRILL DLOG P Log Gamma tie in 0 correction RIH to log RA Log RA @ 7401.3 02:09 03:09 1.00 7,218 7,238 PROD3 DRILL CIRC P Recip up hole while formulating directional plan 03:09 05:00 1.85 7,238 0 PROD3 DRILL TRIP P POOH for AKO Change 05:00 05:15 0.25 0 0 PROD3 DRILL SFTY P Hold PJSM for Pressure un-deploy 05:15 08:45 3.50 0 0 PROD3 DRILL PULD P Start to un-deploy.Shift change during. Lay down BHA and adjust AKO from 2 to 1.6. Pressure deploy. 08:45 10:15 1.50 0 7,200 PROD3 DRILL TRIP P RIH w/Build BHA#18 10:15 10:30 0.25 7,200 7,223 PROD3 DRILL DLOG P Tie in for a-9'correction,Close EDC PUW=27K 10:30 10:36 0.10 7,223 7,461 PROD3 DRILL TRIP P RIH,Clean pass through window 10:36 12:51 2.25 7,461 7,615 PROD3 DRILL DRLG P 7461', Drill Ahead 1.4 BPM @ 3500 PSI FS BHP=3838 12:51 13:06 0.25 7,615 7,765 PROD3 DRILL WPRT P Wiper to window 28K 13:06 14:42 1.60 7,765 7,765 PROD3 DRILL DRLG P 7765', Drill Ahead 1.4 BPM @ 3500 FS BHP=3933 14:42 15:12 0.50 7,765 7,765 PROD3 DRILL WPRT P Wiper to window PUW=28K 15:12 16:27 1.25 7,765 7,915 PROD3 DRILL DRLG P 7765 Drill Ahead 1.4 BPM @ 3461 PSI FS BHP=3971 Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:27 16:54 0.45 7,915 7,415 PROD3 DRILL WPRT P Wiper trip to window with tie in PUW=29 16:54 17:06 0.20 7,415 7,433 PROD3 DRILL DLOG P Tie in with zero correction 17:06 17:36 0.50 7,433 7,915 PROD3 DRILL WPRT P Continue with wiper 17:36 19:06 1.50 7,915 8,065 PROD3 DRILL DRLG P Continue drilling ahead 19:06 20:54 1.80 8,065 0 PROD3 DRILL TRIP P Finished drilling build section. POOH for BHA,opened EDC at the window. 20:54 21:06 0.20 0 0 PROD3 DRILL SFTY P PJSM for undeploy 21:06 00:00 2.90 0 0 PROD3 DRILL PULD P Undeploy/deploy BHA 10/06/2010 Drilled AL2 lateral from 8065'to 8835' 00:00 02:00 2.00 0 0 PROD3 DRILL PULD P Continue with Deployment of lateral drilling BHA 02:00 03:54 1.90 0 7,205 PROD3 DRILL TRIP P RIH 03:54 04:06 0.20 7,205 7,228 PROD3 DRILL DLOG P Tie in,-8'correction,close EDC,27K PUW 04:06 04:24 0.30 7,228 8,065 PROD3 DRILL TRIP P Continue RIH, 15 K RIW 04:24 06:24 2.00 8,065 8,215 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 3900 BHP with wide open choke, 27K PUW, 15K RIW 06:24 08:24 2.00 8,215 8,215 PROD3 DRILL WPRT P Wiper to window with Madd pass 8076 to 7416 PUW=28K 08:24 10:18 1.90 8,215 8,365 PROD3 DRILL DRLG P 8215', Drill Ahead 1.4 BPM @ 3623 PSI FS 11.7K Slackoff, BHP=3959 10:18 11:33 1.25 8,365 8,365 PROD3 DRILL WPRT P Wiper to window, PUW=28K 11:33 12:57 1.40 8,365 8,515 PROD3 DRILL DRLG P 8365 Drill Ahead 1.4 BPM @ 3631 PSI FS BHP=3972 12:57 13:42 0.75 8,515 7,420 PROD3 DRILL WPRT P Wiper to window with tie in PUW=26K 13:42 13:48 0.10 7,420 7,445 PROD3 DRILL DLOG P Tie in to RA Marker, No Correction 13:48 14:33 0.75 7,445 8,515 PROD3 DRILL WPRT P Continue wiper to bottom 14:33 16:24 1.85 8,515 8,665 PROD3 DRILL DRLG P 8515', Drill ahead 1.4 BPM @ 3511 PSI FS BHP=4020 16:24 17:24 1.00 8,665 7,300 PROD3 DRILL WPRT P Wiper to window PUW=30K 17:24 19:24 2.00 7,300 7,300 PROD3 DRILL SFTY P Safety meeting with Wheatall. Pull into cased hole and circulate 19:24 20:24 1.00 7,300 8,665 PROD3 DRILL WPRT P Wiper to bottom, 16K RIW 20:24 22:06 1.70 8,665 8,815 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3450 CTP,4000 BHP w/wide open choke 22:06 23:36 1.50 8,815 8,815 PROD3 DRILL WPRT P Wiper to window,29K PUW. Clean trip., DS @.6% 23:36 00:00 0.40 8,815 8,835 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3400 CTP, 4050 BHP 10/07/2010 Drilled to TD at 9200', Layed in KWF and PU liner string Page 16 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:48 1.80 8,835 8,951 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3400 CTP,4050 BHP 01:48 02:48 1.00 8,951 7,420 PROD3 DRILL WPRT P Wiper to window. Had trouble getting good weight transfer and then 5K over pulls.29K PUW 02:48 03:00 0.20 7,435 8,951 PROD3 DRILL DLOG P Tie-in,-1.5' 03:00 03:42 0.70 8,951 8,951 PROD3 DRILL WPRT P Wiper back in hole,start new mud down coil for mud swap 03:42 05:06 1.40 8,951 9,110 PROD3 DRILL DRLG P Drilling ahead with new mud, 1.4 BPM,3300 CTP,4030 BHP 05:06 07:06 2.00 9,110 9,110 PROD3 DRILL WPRT P Wiper trip,29 K PUW 07:06 07:54 0.80 9,110 9,200 PROD3 DRILL DRLG P 9110', Drill Ahead 1.38 BPM @ 3250 FS BHP=3881, ROP=114 07:54 11:30 3.60 9,200 66 PROD3 DRILL WPRT P Call TD, Pump LoHi sweeps,trip to swab valve 11:30 13:06 1.60 66 7,200 PROD3 DRILL WPRT P Bump Stripper, Set BHA depth 77.57 Run back in well 13:06 13:18 0.20 7,200 7,230 PROD3 DRILL DLOG P Gamma tie in for-8 13:18 14:24 1.10 7,230 9,200 PROD3 DRILL WPRT P Continue in well,Swap to beaded pill @ 8500' Tag TD @ 9200,3 BBIs to beads 14:24 17:06 2.70 9,200 0 PROD3 DRILL TRIP P Trip out laying in beaded liner pill/ KWF Following pressure Schedule Paint EOP flags 6000&7800 17:06 17:24 0.30 0 0 PROD3 DRILL SFTY P Monitor well, PJSM forLay down BHA 17:24 18:30 1.10 0 0 PROD3 DRILL PULD P Lay down Drilling BHA 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P RU floor for liner operations 19:12 19:24 0.20 0 0 COMPZ CASING SFTY P PJSM 19:24 22:24 3.00 0 1,271 COMPZ CASING PUTB P PU 38 joints liner. BOP drill at joint #18,Well secured at 2:40. 22:24 23:48 1.40 1,271 7,271 COMPZ CASING RUNL P RIH 23:48 00:00 0.20 7,271 7,300 COMPZ CASING RUNL P Correct to EOP flag,-3'. 31K PUW, 17K RIW(-2.8 WOB) 10/08/2010 Set anchored billet at 7760'. PU drilling assembly,swap well to flopro and mill off billet,drill ahead to end of turn at 8070'. 00:00 00:42 0.70 7,300 9,204 COMPZ CASING RUNL P Continue to RIH with liner 00:42 01:06 0.40 9,204 7,400 COMPZ CASING RUNL P Tag TD at 9203.65',online with pump at 1.3 BPM,4400 CTP. Release liner and POOH pumping down backside 01:06 01:18 0.20 7,400 7,420 COMPZ CASING DLOG P Log RA,-5'correction. Deployment sleeve is at 7971.5' 01:18 02:54 1.60 7,420 0 COMPZ CASING RUNL P POOH pumping down CT. Paint EOP flag at 7100' 02:54 03:12 0.30 0 0 COMPZ CASING SFTY P PJSM while monitoring well for no-flow 03:12 05:12 2.00 0 273 COMPZ CASING PUTB P Lay down BHA. PU guide shoe,6 Joints slotted liner,5.85'pup and anchored billet. MU Inteq BHA Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:12 07:12 2.00 273 7,381 COMPZ CASING RUNL P RIH 07:12 07:30 0.30 7,381 7,971 COMPZ CASING RUNL P Correct to EOP Flag for-8',Close EDC 07:30 07:42 0.20 7,971 7,199 COMPZ CASING RUNL P Set down @ 7971, Pull up hole,Set back down 7969 Pumps on,see tool shift @ 4K Set down 1.5K on anchor, POOH 07:42 07:57 0.25 7,199 7,220 COMPZ CASING DLOG P Log gamma for a+.75 foot correction BOL=7971,TOL=7760 07:57 09:42 1.75 7,220 59 COMPZ CASING RUNL P Trip out 09:42 10:30 0.80 59 0 COMPZ CASING PULD P PJSM, Flow check well, Lay down BHA#21 10:30 11:30 1.00 0 62 PROD4 STK PULD P P/U BHA#22, 1.7 Degree motor, Bi Center Surface test tool 11:30 13:15 1.75 62 7,200 PROD4 STK TRIP P Trip in well 13:15 13:21 0.10 7,200 7,215 PROD4 STK DLOG P Tie in for a-7'correction 13:21 13:27 0.10 7,215 7,380 PROD4 STK TRIP P RIH to 7380. 13:27 15:12 1.75 7,380 7,380 PROD4 STK CIRC P stop at 7380, Pump spacer, Roll well to flo pro recovering KWF Shut EDC 15:12 15:30 0.30 7,380 7,760 PROD4 STK TRIP P Trip in to kick off billet 15:30 18:42 3.20 7,760 7,770 PROD4 STK KOST P Dry tag billet at 7760,Start sidetracking per recommended practice/procedure 18:42 21:24 2.70 7,770 7,910 PROD4 DRILL DRLG P Continue drilling ahead. Drift billet, clean. Drill some more, 1.4 BPM, 3300 CTP,3800 BHP 21:24 22:24 1.00 7,910 7,910 PROD4 DRILL WPRT P Wiper to window,Tie-in due to BHI computer reboot.Zero correction. 22:24 23:54 1.50 7,910 8,070 PROD4 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 3840 BHP 23:54 00:00 0.10 8,070 PROD4 DRILL TRIP P POOH for AKO adjust 10/09/2010 Drilled AL2-01 lateral 00:00 02:24 2.40 7,800 0 PROD4 DRILL TRIP P Continue POOH for BHA,to PU resistivity tool and lower AKO 02:24 02:36 0.20 0 0 PROD4 DRILL SFTY P PJSM for undeployment 02:36 04:48 2.20 0 0 PROD4 DRILL PULD P Undeploy BHA. PU resistivity and adjust AKO to 1.0. Deploy BHA 04:48 06:48 2.00 0 0 PROD4 DRILL PULD P Deploy BHA#23,Surface test tool All good Tag up,set counters,Open EDC 06:48 08:12 1.40 0 7,205 PROD4 DRILL TRIP P RIH 08:12 08:24 0.20 7,205 7,222 PROD4 DRILL DLOG P Log Tie in for a-10'correction Close EDC 08:24 08:48 0.40 7,222 8,070 PROD4 DRILL TRIP P Trip in to drill,Clean pass through window and past billet 08:48 10:00 1.20 8,070 8,220 PROD4 DRILL DRLG P 8070 Drill Ahead, 1.4 BPM @ 3353 PSI FS BHP=3932 10:00 11:48 1.80 8,220 8,220 PROD4 DRILL WPRT P 8220,Wiper to window with MAD Pass, PUW=29K Page 18 of 20 JL&\ EE orjc a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION 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, 3A-17AL2 ConocoPhillips Alaska, Inc. Permit No: 210-115 Surface Location: 663'FSL, 785' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 5073' FSL, 3349.5' FEL, SEC. 17, T12N, R9E, UM Dear Mr. Cawvey: 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 3A-17A, Permit No 210- 113, API 50-029-22691-01. 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, 4?1"-- 7°. Daniel T. Seamount, Jr. Chair DATED this3 day of August, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ECE!VED STATE OF ALASKA A(16 2 0 201(1 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska i+"` Gs;Cm.Commission 20 AAC 25.005 viCliJrJfle la.Type of Work: , lb.Proposed Well Class: Development-Oil FA • Service-Winj ❑ Single Zone 0 - 1c.Specify if well is proposed for: Drill ❑ Re-drill 0 Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: lg Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 . 3A-17AL2 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9250' TVD: 6085 ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): t Surface:663'FSL,785'FEL,Sec.7,T12N,R9E,UM ADL 25631,25632 • Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: Top of Kuparuk:4219.95'FSL,2653.2'FEL,Sec.17,T12N,R9E,UM 2564,2565 9/10/2010 Total Depth: 9.Acres in Property: 14.Distance to TD:5073'FSL,3349.5'FEL,Sec. 17,T12N,R9E,UM 2560 Nearest Property: 21450' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 82 feet• 15.Distance to Nearest Well Open Surface:x- 507663 • y- 5997044 • Zone- 4 GL Elevation above MSL: 41 feet to Same Pool: 3A-07,1200' - 16.Deviated wells: Kickoff depth: 7395' ft. • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91° deg. Downhole:4560 psig . Surface:3957 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 1650 7600 6043 9250 6085 slotted liner cytik\ 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) 7785' 6336' 7717' 6283' Casing Length Size Cement Volume MD TVD Conductor/Structural 81' 16" 212 sx AS I 121' 121' Surface 3782' 7.625" 1020 sx AS III,340 sx CI G 3821' 3306' Intermediate Production 7747' 5.5"x 3.5" 190 sx Class G 7782' 6334' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7347-7370',7380'-7390',7474-7504' 5995-6013',6020'-6028',6094-6117' 20.Attachments: Property Plat❑ BOP Sketch in Drilling Program ini Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program 51 20 AAC 25.050 requirements r 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 QLg)l ' Printed Name V. Cawvey Title Alaska Wells Manager Signature r✓ Phon 2ssso s.. ki fi_L,r- VC0 OitiAly -f Date K ey f o Commission Use Only Permit to Drill API Number: Permit Appro al See cover letter Number: .21 D // 50-C;2-4/ 2-2-0/- / Date: for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales: L'_I -44.11000 r s'- Fw P /c$t- Samples req'd: Yes ❑ o Mud log req'd: Yes ❑ No 0 Other: / ,f. H2S mgasures: Yes 0 No ❑ Directional svy req'd: Yes No ❑ U-43/evise/O APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form U1 ( d 11200Y) This permit is valid fo months from the date of approval(20 AAC 25.005(g)) Submit n Duplicate - P27-/c) .��2 f D �".1.6,-72" oP Conochilli s p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 18, 2010 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 an application for permits to drill 4 lateral sidetracks out of Kuparuk Well 3A-17 using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 3A-17 as early as September 12, 2010. The CTD objective is to drill four lateral sidetracks (3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01); targeting the A2 and A3-sands to access reserves away from the parent wellbore, across isolating faults. Two laterals each will be drilled from two separate casing exits in the 3.5" liner. Attached to this application are the following documents: — Permit to Drill Application Forms for 3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic — Sundry Application—Plug perforations If you have any questions or require additional information please contact me at 907-263-4093. Sincerely, Jill Lon 6)12-- Coiled ubing Drilling Engin Permit to Drill Summary of Operations KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Laterals Coiled Tubing Drilling Well History and Objective Well 3A-17 was originally drilled and completed as an A-sand producing, single completion well in September 1996. The A sands were perforated and fracture stimulated in October/November 1996. The well operated as an A-only producer until 1999 when the C and B sands were perforated in June of that year. Production from 3A-17 has historically been lower than expected. The reservoir in the surrounding area is highly faulted and seismic data confirms the current wellbore position is not optimal. The purpose of the CTD project is to drill four CTD sidetracks in the A2 and A3 sands away from the parent • wellbore and across faults that are believed to be isolating. The new reservoir locations should result in improved sweep efficiency and oil recovery for the pattern. Perforations in the parent wellbore are planned to be plugged prior to CTD rig arrival however the lateral footage drilled in the immediate vicinity of parent well will recover the existing perforations. Operational Outline Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5" liner below the tubing tail. 2. Set a cast iron bridge plug above the A sand perforations and below the lower CTD kickoff point). 9 p 9 p (and P ) 3. Perforate the 3.5" liner across the kickoff point locations 4. Set the lower whipstock at—7412' MD 5. Cement squeeze the B and C sand perforations, cleaning out to the top of the whipstock 6. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Lower Window a. Mill a 2.74"window exit with high-side orientation off of the whipstock previously cemented in place at—7412' MD b. 3A-17A Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL1 lateral c. 3A-17AL1 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top from TD to just inside the window 3. Upper Window a. Set a 3.5" Monobore whipstock at—7395' MD and mill a 2.74"window exit with high-side orientation off of the whipstock set at—7395' MD —Otis b. 3A-17AL2 Lateral FD i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL2-01 lateral c. 3A-17AL2-01 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 23/" slotted liner with a shorty deployment sleeve on top from TD to inside the 3.5" liner above the window. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Operational Details Hazards — Shale stability is a potential problem, particularly in the build section when crossing Fault#1. — Drilling into over-pressured zones is a potential hazard in 3A-17. Nearby injecting well 3A-10 has a bottomhole pressure of—4600 psi but is expected to be fault isolated from the planned laterals. Choke pressure will be maintained while drilling, both for maintaining well control and borehole stability. — Well 3A-17 has 130 ppm H2S as measured on 02/16/10. Well 3A-08 is located 16' to the right side and 3A- 09 is 59' to the left side of the 3A-17 surface location. The H2S measured in 3A-08 is 200 ppm (12/18/09) and 3A-09 is 120 ppm (1/2/09). The maximum H2S level on the pad is 260 ppm from well 3A-16 (12/19/09). All H2S monitoring equipment will be operational. Fluids Program — Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (9.8 ppg)for drilling operations. • — Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. 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 om seton Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 3A-17A 7700' 9150' 6038' 6032' 23h , 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3A-17AL1 7412' 9200' 5963' 6000' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 3A-17AL2 7600' 9250' 6043' 6085' 23/8', 4.7#, L-80, ST-L solid/slotted liner; aluminum billet on top. 2%" 4/# L-8 slotted ST-L s t ed lin e r' shorty 7380' 9300' 5939' 6060 y deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 121 0 121 1640 630 Surface 7%" 29.7 L-80 BTC-Mod 0 3821 0 3306 6890 4790 Casing 5 %" 15.5 L-80 LTC-Mod 0 7254 0 5922 7000 4990 Liner 3 % " 9.3 L-80 EUE-8rd Mod 7254 7782 5922 6334 10160 10540 Tubing 3 %" 9.3 L-80 EUE-8rd Mod 0 7267 0 5932 10160 10540 Directional Planning — See attached directional plans for each of the three laterals. — 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 Lateral Name Distance 3A-17A 22650' 3A-17AL2 21450' 3A-17AL1 22650' 3A-17AL2-01 21450' Page 2 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-1 IAL1, 3A-17AL2, 3A-17AL2-01 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well Lateral Name Distance Well 3A-17A 1200' Toe measured to 3A-07 3A-17AL2 1200' Toe measured to 3A-07 3A-17AL1 1200' Toe measured to 3A-07 3A-17AL2-01 1200' Toe measured to 3A-07 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. . Reservoir Pressure — The most recent static BHP survey in well 3A-17 was taken August 12, 2010. The reservoir pressure was measured at 3800 psi at 7426' MD/ 6056' TVD, corresponding to 12.1 ppg EMW. This is also the , highest expected pressure in the targeted fault block. — The highest pressure from any of the surrounding wells that could potentially be anticipated is 4560 psi at o' 6628' MD/6065'TVD (in nearby injector 3A-10). Well Control — Two well bore volumes (-161 bbl) of KWF will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. — 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 surface pressure anticipated while sidetracking out of 3A-17 is 3957 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum reservoir pressure from all nearby wells: 4560 psi at 6628' MD/6065' TVD (in nearby injector 3A-10). — The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.8 ppg drilling fluid in combination with annular friction losses and 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 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 installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 8/18/2010 O r cc O N 0 0 L_ n _ > > O L N N 0 CO 0 J co C N W < y Q n N- o n 0 m°o a �)°nn O J m I I N O N o C o ° ` II d J _ ,D CV Q I-J QOm I N I N o ; I 2 to N-� O N V 1I H 1` T O N L m N _g E I °' C I N n U 0 ti cn Ud F d E m I I y n m c a n w e E L. `■ I o a o m\ 8 m m 8 0 \ 8 (V c o u) N \ V U of m U ci \\j V CV CV -- N al \ I M M C) C co ii co o V a O 4/://4-. .-;:t.t.:,,-:,lits410".7:: *a2' r-c°&2C) - 0 A 1 A A 1 ,, - o - II _ -1: K I: E p n o 0 I U N U e4 o Q @).6 b " y o m� -T I— 2 inO o_ Qp Qr- N °m w v N O = N >T 0 r- N 0 N y x CV N O 2 O o N N V n \ o q " r�N UY @ \ • 2 o, a a 0 o C0@ Nm I 11 t I / , N ////A J / CO L I r 1 N N z I 3 J a I I Q T I z I I FI J N I N Q a) r- Q J O l/ \ / U O M n \J O Q O t0 d N r A N II C ONi N 1` Q O J N 11 N— I Q OF m Q CO ConocoPh i l l i s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3A Pad 3A-17 3A-17AL2 Plan: 3A-17AL2_wp05 Standard Planning Report 16 August, 2010 BAKER HUGHES r.' ConocoPhillips (,'- ConocoPhillips Planning Report BAKER Aka HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) . Site: Kuparuk 3A Pad North Reference: True • Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL2 Design: 3A-17AL2_wp05 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 3A Pad Site Position: Northing: 5,996,860.05ft Latitude: 70°24'9.520 N From: Map Easting: 507,712.01 ft Longitude: 149°56 14.019 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06 ° Well 3A-17 Well Position +N/-S 0.00 ft Northing: 5,997,044.46 ft • Latitude: 70°24'11.335 N +E/-W 0.00 ft Easting: 507,662.81 ft ' Longitude: 149°56'15.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.40 ft 1 Wellbore 3A-17AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 (°) (°) (nT) BGGM2009 8/11/2010 17.03 79.83 57,388 Design 3A-17AL2_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,297.80 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -40.40 0.00 0.00 290.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,297.80 38.30 112.30 5,873.96 -1,718.31 3,408.20 0.00 0.00 0.00 0.00 7,395.00 38.48 112.54 5,950.15 -1,741.33 3,464.00 0.24 0.19 0.25 39.72 7,410.00 39.83 112.54 5,961.78 -1,744.96 3,472.75 9.00 9.00 0.00 0.00 7,470.00 57.83 112.54 6,001.11 -1,762.21 3,514.30 30.00 30.00 0.00 0.00 7,628.80 90.00 75.29 6,046.00 -1,768.15 3,661.76 30.00 20.26 -23.46 305.00 7,978.80 90.97 330.29 6,041.81 -1,488.81 3,779.16 30.00 0.28 -30.00 271.00 8,078.80 89.90 315.33 6,041.05 -1,409.38 3,718.88 15.00 -1.07 -14.96 266.00 8,378.80 89.93 270.33 6,041.53 -1,295.97 3,449.43 15.00 0.01 -15.00 270.00 8,640.00 89.94 309.51 6,041.83 -1,208.72 3,208.61 15.00 0.01 15.00 90.00 8,720.00 82.43 318.89 6,047.16 -1,153.19 3,151.46 15.00 -9.40 11.73 129.00 8,910.00 87.60 290.74 6,064.00 -1,046.42 2,997.59 15.00 2.72 -14.81 279.00 8,960.00 87.36 283.24 6,066.20 -1,031.83 2,949.85 15.00 -0.48 -15.01 268.00 9,250.00 85.33 326.79 6,085.61, -869.89 2,718.47 15.00 -0.70 15.02 94.00 8/16/2010 2.04.07PM Page 2 COMPASS 2003.16 Build 69 r•' ConocoPhillips F/- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Welibore: 3A-17AL2 Design: 3A-17AL2_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map j Depth Inclination Azimuth System +NI-S +E/-w Section Rate Azimuth Northing Easting (ft) C) (°) (ft) (ft) (ft) (ft) (°HOOft) (°) (ft) (ft) 7,297.80 38.30 112.30 5,873.96 -1,718.31 3,408.20 -3,790.36 0.00 0.00 5,995,329.82 511,072.43 TIP 3A-17 7,300.00 38.30 112.31 5,875.69 -1,718.83 3,409.47 -3,791.72 0.24 39.72 5,995,329.30 511,073.70 . 7,395.00 38.48 112.54 5,950.15 -1,741.33 3,464.00 -3,850.67 0.24 39.72 5,995,306.85 511,128.25 KOP I 7,400.00 38.93 112.54 5,954.05 -1,742.53 3,466.89 -3,853.79 9.00 0.00 5,995,305.66 511,131.14 7,410.00 39.83 112.54 5,961.78 -1,744.96 3,472.75 -3,860.13 9.00 0.00 5,995,303.23 511,137.00 End 9 deg DLS 7,470.00 57.83 112.54 6,001.11 -1,762.21 3,514.30 -3,905.07 30.00 0.00 5,995,286.04 511,178.56 4 1 7,500.00 63.26 104.29 6,015.88 -1,770.40 3,539.06 -3,931.14 30.00 -55.00 5,995,277.87 511,203.33 7,600.00 83.79 81.30 6,044.44 -1,773.99 3,633.63 -4,021.24 30.00 -50.93 5,995,274.38 511,297.90 7,628.80 90.00 75.29 6,046.00 -1,768.15 3,661.76 -4,045.67 30.00 -44.23 5,995,280.24 511,326.02 5 7,700.00 90.36 53.93 6,045.78 -1,737.80 3,725.72 -4,095.39 30.00 -89.00 5,995,310.65 511,389.931! 7,800.00 90.78 23.93 6,044.75 -1,660.91 3,787.84 -4,127.47 30.00 -89.07 5,995,387.61 511,451.97 7,900.00 90.99 353.93 6,043.17 -1,563.26 3,803.19 -4,108.49 30.00 -89.38 5,995,485.26 511,467.22 7,978.80 90.97 330.29 6,041.81 -1,488.81 3,779.16 -4,060.45 30.00 -89.85 5,995,559.67 511,443.12 1 End 30 deg DLS I 8,000.00 90.74 327.12 6,041.49 -1,470.70 3,768.15 -4,043.91 15.00 -94.00 5,995,577.77 511,432.09 j 8,078.80 89.90 315.33 6,041.05 -1,409.38 3,718.88 -3,976.64 15.00 -94.05 5,995,639.03 511,382.76 1 7 8,100.00 89.90 312.15 6,041.09 -1,394.72 3,703.56 -3,957.23 15.00 -90.00 5,995,653.67 511,367.43 8,200.00 89.90 297.15 6,041.26 -1,338.04 3,621.53 -3,860.76 15.00 -89.99 5,995,710.27 511,285.35 8,300.00 89.92 282.15 6,041.42 -1,304.51 3,527.62 -3,761.05 15.00 -89.97 5,995,743.70 511,191.41 8,378.80 89.93 270.33 6,041.53 -1,295.97 3,449.43 -3,684.65 15.00 -89.94 5,995,752.16 511,113.221 8 8,400.00 89.93 273.51 6,041.55 -1,295.26 3,428.24 -3,664.50 15.00 90.00 5,995,752.85 511,092.03 8,500.00 89.93 288.51 6,041.68 -1,276.22 3,330.36 -3,566.01 15.00 90.00 5,995,771.78 510,994.14 8,600.00 89.94 303.51 6,041.79 -1,232.50 3,240.74 -3,466.84 15.00 89.98 5,995,815.41 510,904.49 8,640.00 89.94 309.51 6,041.83 -1,208.72 3,208.61 -3,428.51 15.00 89.96 5,995,839.16 510,872.33 9 8,700.00 84.29 316.52 6,044.85 -1,167.88 3,164.83 -3,373.41 15.00 129.00 5,995,879.94 510,828.52 8,720.00 82.43 318.89 6,047.16 -1,153.19 3,151.46 -3,355.82 15.00 128.65 5,995,894.61 510,815.14 10 8,800.00 84.45 306.98 6,056.33 -1,099.17 3,093.37 -3,282.76 15.00 -81.00 5,995,948.57 510,757.00 8,900.00 87.30 292.21 6,063.56 -1,050.07 3,006.88 -3,184.69 15.00 -79.63 5,995,997.58 510,670.47 8,910.00 87.60 290.74 6,064.00 -1,046.42 2,997.59 -3,174.71 15.00 -78.57 5,996,001.22 510,661.17 11 8,960.00 87.36 283.24 6,066.20 -1,031.83 2,949.85 -3,124.86 15.00 -92.00 5,996,015.76 510,613.43 12 9,000.00 86.96 289.23 6,068.18 -1,020.66 2,911.51 -3,085.01 15.00 94.00 5,996,026.88 510,575.07 9,100.00 86.10 304.24 6,074.27 -975.89 2,822.62 -2,986.17 15.00 93.70 5,996,071.56 510,486.15 9,200.00 85.52 319.27 6,081.62 -909.68 2,748.43 -2,893.80 15.00 92.79 5,996,137.69 510,411.89 , 9,250.00 85.33 326.79 6,085.61 " -869.89 2,718.47 -2,852.05 15.00 91.69 5,996,177.44 510,381.90 TD at 9250.00 8/162010 2:04:07PM Page 3 COMPASS 2003.16 Build 69 r•' ConocoPhillips (/'� ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL2 Design: 3A-17AL2_wp05 Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3A-17AL2 t1 0.00 0.00 5,949.00 -1,720.56 3,474.77 5,995,327.63 511,139.00 70°23'54.405 N 149°54'33.667 W -plan misses target center by 23.42ft at 7395.35ft MD(5950.42 TVD,-1741.42 N,3464.20 E) -Circle(radius 1,320.00) 3A-17AL2,AL2-01 Fa 0.00 0.00 0.00 -751.02 3,034.74 5,996,296.63 510,698.02 70°24'3.942 N 149°54'46.546 W -plan misses target center by 5964.78ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -751.02 3,034.74 5,996,296.63 510,698.02 Point2 0.00 -1,318.96 2,918.18 5,995,728.63 510,582.05 Point3 0.00 -1,910.76 2,652.57 5,995,136.61 510,317.07 Point4 0.00 -1,318.96 2,918.18 5,995,728.63 510,582.05 3A-17AL2,AL2-01 Fa 0.00 0.00 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 70°23'58.344 N 149°54'23.542 W -plan misses target center by 5901.86ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 Point2 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 Point 3 0.00 -2,782.46 3,242.74 5,994,265.60 510,908.08 Point4 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 3A-17AL2 t2 0.00 0.00 6,045.00 -1,746.77 3,673.77 5,995,301.63 511,338.00 70°23'54.147 N 149°54'27.838 W -plan misses target center by 16.88ft at 7648.93ft MD(6045.99 TVD,-1762.03 N,3680.93 E) -Point 3A-17AL2,AL2-01 Po 0.00 0.00 0.00 -1,869.89 3,775.65 5,995,178.63 511,440.00 70°23'52.935 N 149°54'24.856 W -plan misses target center by 5887.39ft at 7297.80ft MD(5873.96 TVD,-1718.31 N,3408.20 E) -Polygon Point 1 0.00 -1,869.89 3,775.65 5,995,178.63 511,440.00 Point2 0.00 -1,414.01 3,945.11 5,995,634.64 511,608.97 Point 3 0.00 -757.69 2,653.62 5,996,289.57 510,316.94 Point 4 0.00 -954.61 2,559.42 5,996,092.57 510,222.95 Point 5 0.00 -1,585.86 3,777.93 5,995,462.64 511,441.98 Point6 0.00 -1,769.65 3,539.72 5,995,278.62 511,203.99 3A-17AL2 t3 0.00 0.00 6,085.00 -848.71 2,728.61 5,996,198.63 510,392.01 70°24'2.983 N 149°54'55.516 W -plan misses target center by 23.49ft at 9250.00ft MD(6085.61 TVD,-869.89 N,2718.47 E) -Circle(radius 1,320.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C') 3,821.00 3,223.24 7 5/8" 7-5/8 9-7/8 9,250 00 6,085.61 2 3/8" 2-3/8 3 8/16/2010 2:04..07PM Page 4 COMPASS 2003.16 Build 69 v.-' ConocoPhillips Irk-- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL2 Design: 3A-17AL2_wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,297.80 5,873.96 -1,718.31 3,408.20 TIP 3A-17 7,395.00 5,950.15 -1,741.33 3,464.00 KOP 7,410.00 5,961.78 -1,744.96 3,472.75 End 9 deg DLS 7,470.00 6,001.11 -1,762.21 3,514.30 4 7,628.80 6,046.00 -1,768.15 3,661.76 5 7,978.80 6,041.81 -1,488.81 3,779.16 End 30 deg DLS 8,078.80 6,041.05 -1,409.38 3,718.88 7 8,378.80 6,041.53 -1,295.97 3,449.43 8 8,640.00 6,041.83 -1,208.72 3,208.61 9 8,720.00 6,047.16 -1,153.19 3,151.46 10 8,910.00 6,064.00 -1,046.42 2,997.59 11 8,960.00 6,066.20 -1,031.83 2,949.85 12 9,250.00 6,085.61 -869.89 2,718.47 TD at 9250.00 III 8/162010 2 04:07PM Page 5 COMPASS 2003.16 Build 69 l . 1 gg_ i o We 4 R Q pppp NN a P ■■■■■■■�AINIMB .■■■■■■■Qmmikin y A ■■■■■■RI INI MN S F ■■1■■■■I/I�■�i►_ S mq.. ■.■■...M// .: 1, , g F ry I l i a ■■■ENIM ell all■ s 2 E r ■1MIWA_I=..■_�■■■ u $§ � M G =1 W� ■■■NVI►:■■//■■■ .; _ g- U ■IW/NIM■I ►,N■■ _ ■1LMIA■■■BEM• 1 ■LBEN ■� HI g th Q0 n ,, SA S w z� n N o %E, _ _ _ - _ - _ $ ^� 8 7 a m (~ ( /U 001)(+)q1oN/(-)91noS V U YW Z J N il 5" : I1I Aaom.12 QQ 3 n m 7 'F' M X R. .P4. ,aona°od R N 'J Q 6' z J ssgsssso YA 22 �:2 120 A Es�ss s s s sn s,nsn sua s, 23 y ; '_ 2AA i z poo rngi eg.n, n.n ,• 2 5 o l � �i1Rg��in�2 G v�j2v v p` 4 a°aN J wsaryi«oico of c7 .ao 'U , vai m o — 1_ o Q r E. o,e �'' i {q'gig nmQ:5�gin .n 4 co e )404¢ o *Rs A�25 m%gs g 2 1 0 s 2 W s g (u?/8 50 ilidOG IeotuaA acui �t m �N V g L-nm,..noomo7 . h W gz R s 1 By,. s i , .m , i 21 s IDA 2- Qgk /s 8 P . Allailiblitikkil!.., do I ■ ■■IVARO MOM �ValliiiIIPMEIWAUFAIWAILIMIRS =. III■■ILEMEME,_■`BINI i it Aga irvoiliiismopr _g .. . i ilAiiiiiitiiii AS .. 11/1111111111111111 S < P _,_■I,..■■.,%■-■■ �_ Mg ��1� I►i■■P.iA■ ■■�� Y , -, O -J UIW__ TIIiiiiHhl I/MMERIMM■■■■OI■■ ippli, p/ p F i 8 _ o ° $ Y o g _ S 8 i t (u?/8 ocd(+)quor/(-)i$nos Q Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator 6SEI Riser \Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator J ` • above BHA rams PP-1. l Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) Kill 1›<J LG-iJ L •{ 1 r [8 Blind/Shear 2" Pipe/Slip(CT) Choke 2 i Swab Valves Wing Valves li L — 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, C062 Union TRANSMITTAL LETTER CHECKLIST WELL NAME Kie /74 7- PTD# -1(3/ L Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /ett- ) POOL: Kva.--iikk r_i/ c''�) 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 wellb re segmenn of existing well t!{ .5 0--/-77q V (If last two digits in Permit No. API No. 50 ; -Z4-4. API number are / �( -r2-9-2-Z0/ 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 [ I I _J To co a O1) a N !n a) 0 a) O 0 _co a) Q - 0 C T.) C L U Q 0 a a 2 a) a) n N - u) C c C. 3 a) O > > o c o) w V E O C a) C 0 W o E h O c c co ° a) n H o p 0- o.)` c >m (N 0 co rn 00 U L v ai L W = a N M 3 -0 °- o .§ o) ° 0 V u) - N . - a N C > '— a o 0 Z —° a) c L o v ° CO- < 3 P. ., a) - a 0 O `) ° @ o° - a) m 0 c o° Q E o ) O N � U N ` a) C • Z co 0 N > p a _ u) O L o a) > a a E ,_ a 2 t o v 0 N 3 c co a U N a 3 L c v 00 a) a3 a E. c o c m v -o a) a o) - ° T '- m o O a o c E a Z ~ Q c I = a .N o co ' a -o o U L N O p °- a °° >• M ° as 3 Q N to m o 0 o = co U N a) M o co m C .- V E (N > N - C r C Q NO N N .V o m o N D 00 0) . o >, . -0 co L E 5_ II a)) N .@ N 0) J _ Q a) C - c Q O O Z o o CO C 7 2 _0 o L a. O Q O .0 Oa .0 a) N. -o oa > N > o) 6 >. �. Yao c a a M E C) a) N - '00 c N a) O) C .N.. N aj a) .N a = 'o ate) co c c o U c C '( U a Z _ a) O 0 0 a N 0) 0) .N _m d T _m ° V co o a; o co > o@ ` a) c c a) c a - 0 a O CO N 'N c E a) a .� aXi `O co o o c a) co `° M < a C no 0 Z U 0 a) O C '- U U ° co E co O II C M d 0 -O CO N L a 0 U 'O CO CO CO C "0 CO a3 a3 -� L X X u) D ° o cu Z 0 0 O O o O 0 0 O O o .„ @ Q N a W u) Y U a 0 u) W a W a 0, CI_a 5 E 2 S Y W V a. > a a to a) N U) N V) U) N N N u) (1) U) U) U) V) (I) a) U) U) (1) N N o Q a) o a) a) a) a) a) Cl) Cl) o a) a) Q Q Q Q Q Q Q Q o Cl) a) Cl) a) Q a) a) a) a) Cl) a) Q 0 a) Q Q Q , a z >- >- >- >- >- >- >- >- >- >- >- >- z z z z z z z z z >- >- >- >- z >- >- >- >- >- >- z z >- z Z z N a) Na ' 0 1 (5 7.1i o @ c o E E 3 — E a) O U U 0 N 0 N O O O c 161 O i `0 0 v dIv' 0 L o _ # ° c a) T U _� > ° E 3 0 m > O ° c o o •� y Q E v, m Y Z, - a) > o U CO N Q 0) O E o a) D no a) co cc 0 > 'C ° N N U a a) U I 2 a) a)• Q O L.L C C 7 0- o > a -a -O O Q CO Cr) 2 C a) o) V a) N N N CO L w a) o «- 0 'O N 'O o U di f6 N co "co— W - o C a 'c - o o .. N 4 'O �7• c E L N a CO C o E N N CZ 0 a) C to > W o) 3 «. o ? a3 0 o O O a) a 2 a) N O. O E a) 0 'a O co 'O 0 0 N co E U = L o) ° Z u) co 3 O u) c m L C ° ° 6 c) 0 < V) 0 o a) rn • z "o O c "o o a) 'E •O a3 9 0 D o c o m 0 0 O) o . CD .0 t ca c ° n )° m a) > ° o c D E E = -o c c E o co M c NF- c ' x a L c o o $ o o@ N a) > to° 3 0a Y - N aQ ._1 i — E a o 3 o Q 0 U ° 03 o m Q m v a o ) 0 C a .8 ° a) a) ' E o - - ° . J « E a o c° C° m .( > a o 0 a O a $ 0 0 E m i o .E 5 0 3 > 0 a) L o w ° .E T LY L cu 0 `E) -O C a a o '- 0 0, a a O C 0 - C E Q, 0 C -0 0 0 co a o_ - -0 a) 'o E a) C 0 co n co L N O 0 T o 01 O ' a) cn m > o 3 3 a) La6 a) O o -O °° v a ° 2 O o a . 5 m o o 0 m 0 W c C N ` O a o a o roc =a) • m Q a 'O a 'O a 6 C N j a)O a c a0 o N ° E h N 00 °- L o 'aa y c J a) a a o -o 0 0 a c ° ° a 0 a) 0 _ N a N -0 N E c) O 3 N _ N CO L o o a 0 L 'o 0 ° -0 2 o E a) m o ° ,n E (n m > > co 0 ° 2 o T ( -0 = c v, o a LL a s 0 CO -0 CO O) 0) c � a) 6 a a c °) N 0- a) m a) ° 0 °O s -o -o -o > N 'n L v . a) a) > ' CO a -, ° a c Ca ° E co O ° E aa) a) am . 0 L c c - I ° c a) -o -o o � = - a o a E o u c ac ° _ c CO ° CO C Cal." OZ --ai ° ° m U U .o o o Y m■ w a a ° .) o c ,o a° o o _ ) a -_ la) r w a ° E C 2 ° -o a) 0 U .> a 6 E a -„CD N aJ U E N - - - m > > E is> �0 - ° °) °) c ) c c t co o ? o O w N a c ° a) a) co - o o ° .e 2 2 a) -o m -o a = O O L a) a) a) a a) o 0 V c T a J ai co = 0 0 a a U Q a z 0 co o 0 0 0 Q ', Q a m m U - 2 a a cn u) 0 IW a O N M V a7 N W 0) O N M V (0 h (0 0) O N M V C) (° I- M 0) EO ,— N CO V )f') co I-- co 0) ° '- N 't N °° N N N N N N N N N N c') C') C) C) C) M C) C) C) C) U 0 0 0 o O o 0 W O o i O c f6 N CO N lC N U 0 IX 0 0 O n 0 0 0)`�N m N N O 1. y w a0 c co W O. O 0 E N N o T J •c N � O +�W+� 0▪ :E aU c 8. (.0 0 CI) Qo U w1.. a Q Q W 0 Q co
