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
211-015
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. cg] t - 045 Well History File Identifier Organizing (done) E Two-sided 111111111 lll I III ❑ Rescan Needed II 1111 1111 1 111111 1 RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: o Diskettes, No. 0 Maps: eyscale Items: ❑ Other, No/Type: er Items Scannable by a Large Scanner ❑ Poor Quality Originals: 11015 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: 1 NOTES: 0 Other:: BY: Clai.......)ia Date: 14/Ohl. /s/ 01 P Project Proofing 111111111111 I BY: Maria Date: (4/04 /s/ 01 P 1 1 Scanning Preparation I x 30 =_3Q_ + aa = TOTAL PAGES 5a BY: al, Date: (op Opt/. (Count does not include cover sheet) (ii p /s/ Production Scanning II IIIIIIIIIII 11111 Stage 1 Page Count from Scanned File: 53 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: �ES NO BY: Date: (a/ /o//t /s/ � I ryI p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. Ill II1111111I1 11111 ReScanned I Dliii 11111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111111 III III I c c c o • cd y t0 o a0 a3 J ca a (a IN Z 0 d E — Q Ui' m E m m o Z 2 U . Uw Z ° ° o o 2 2 P d FL U c g -o 0 0 > d O N 0 0 0 0 0 J Uy 0 NNNNNN c) N N N N N o 0 , J N N N N 9 P Z 0-1 M V V = y 7 - = _ c c c c N `� a) a) a) a) .. Q (AY L7o0 �/ J c ' co Q Nco r n r r n r Od j (a O co N co co co N ar d Z Z a a C6 cNa c>73 W = r co z t tO N U Cl) a) rn 0) o) -a w Z v Ja) U v q a) 0 Z _ ° Ce a ft o Q a) = , N o 0. m co _ ta O Z7) o ° 0 0 0 c T E CL N co ZI J � U U U H Q N `^ N a a) 01 CO N N E I a J N N LO U co 9 0 �c J Q 03 I- 7 co G = O d co > w re N > > a) t a o co < a Y47- g ° � I Q C a 1 ZI L w w w Q z o m aTi > > > d U o Z Z yN N 1/ c c c `c c m a) 0 o o .o .o .o 0 • CD c E 0 '0 0 0 0 �(0 o a 0 d d > > ° ._ c CO ' �' Z c c c rn t y D — — — as z rnE O t/ ,,,,D >j z y a M P' z z m c Q o 9 N CC tU CO 7 O « W O Z N R } 'C, 3 OH a7 �+ a 41 0 P• > ILL < 0 E - E 0 E E Z re Q N- z ate+ ,o Q J N Z Q (�. .? d V z w c 6 � ) ` o $ cu " ami a) 1° E 15 Q y -' U U n �.a>i E ° m o W 1 Q o m rnfc4- a a o 0 0 0 0 o o a' t c aa) o 0 a l; re I o 1- 3 -i0i- W J J J W 3 Q U Q� v v I IIIA` BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL (mandatory) WELL NAME 2X-18L1;2X-18L-D1;2X-18L2;2X-18L2-01;2X-18L2-02 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 2/4/2011 TODAYS DATE: (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD (digital digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) FIELD LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Oh-THIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 I I I NSK Wells Aide,N5K 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I Christine'Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I 1 Petrotechnical Data Center,MB33 David Douglas _ 900 East Benson Blvd @-1 0 - 1.5 �a'}33 3-10.--7 -6 a-ce 3cf Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I _ Glenn Fredrick 3800 Center Point Drive,Suite 100 /� Anchorage,Alaska 99503 910 (--)-?(�? 909 35 RECEIVED APR $ 2011 5 Brandon Tucker,NRT I I I 1 Ission State of Alaska;DNR,Div.of Oil and Gas ii V �17 :)._,t C13(m 550 W.7th Ave,Suite 800 3/0— 1 "`i'E Anchorage,Alaska 99501-3510 .9-IG I _O 16 = TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil o • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.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.: February 10,2011' , 211-015/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 February 3,2011 50-029-22608-64 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 675'FSL,241'FEL,Sec.4,T11 N,R9E,UM February 4,2011 • 2X-18L2-02 Top of Productive Horizon: 8.KB(ft above MSL): il 77'RKB 15.Field/Pool(s): 1087'FSL,2453'FEL,Sec. 10,T11 N,R9E, UM GL(ft above MSL): 118'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 1121'FSL,2488'FEL,Sec. 10,T11 N,R9E,UM 11137'MD/6023'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-518889 y- 5970679 Zone-4 . 11287'MD/6009'TVD ADL 25645 TPI: x-521979 y- 5965820 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-521944 y- 5965853 Zone-4 nipple @ 490'MD/489'ND 2576 18.Directional Survey: Yes E 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) 1608'MD/1508'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 10743'MD/6044'ND 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" 300 sx AS I 7.625" 29.7# L-80 Surf. 5130' Surf. 3398' 9.875" 750 sx AS III,470 sx Class G 5.5" 15.5# L-80 Surf. 9930' Surf. 6223' 6.75" 165 sx Class G 2.375" 4.7# L-80 9570' 11137' 5974' 6023' 3" slotted liner 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 9458' 9217'MD/5714'TVD 9374'-9420'MD 5834'-5868'ND 9440'MD/5884'ND 9618'-9638'MD 6020'-6036'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9666'-9684'MD 6058'-6072'ND DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9704'-11136'MD 6017'-6023'ND 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 2 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 �S u RECEIVED rr. RBDMS MAR 01 2011" � � __ MAR 01 2011 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Alaska Oil&vas 444O rt1 A 3 1/r acoOru(� A 3./7•// 28. GEOLOGIC MARKERS(List all formations and markers 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 1608' 1508' needed,and submit detailed test information per 20 AAC 25.071. A5 10830' 6032' A4 10876' 6024' A5 11160' 6021' A6 11238' 6013' N/A Formation at total depth: Kuparuk A3 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'- V 'a .L Title: Alaska Wells Manager Signature . ��' e- y Phone 265-6306 Date 7.121?'i 11 111. Sharon Allsup-Drake INSTRUCTIONS 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 .n ll N !7 CMD M to p M N _ (0)CD -O — N E ✓ r N N to O M (VCD N (D r O 0 <--a co asp O O oo O m 0 p rn rn as _1 rn m p 0 c rn 0 p p V `- NHUco 0) O t 2 r N 'O —a co9N"0l6 ONE EO O O _N = OO p�0) -60 m0) Nv : — In _1 — u) a w (n W mCNI CO U . m N 0 X p M X p M 0 co° Yot$ > Q XY ` Q 'E NHN NHN O J O D (O OU 00 O M 0) E O E M -co-) C U ai as 0LL O0 13 E < LL N N N O (B N N E Y Y N N N 1- c- 7 l4 RS \, M CO M � (nM d) C; E mm Co p• 0 a) - \ CO _ N N 0) � � O O_ U a' W O O cco 0X n- p pI Np ag C Oas N V p aN XY Na N LE • M = In W I e"..5 ? � x / QNMrnc0 U I N 0) M / 0 . (0 CO CO g t` / I I4 Q O) O) "t" ''f, ,i4:: L 111__-.:■� :. • `��1 V NS cts t \\ i3 I CO co LO N O CO w � LO o 1 *tY CD qrt� o @x a I \ o `qct mo_ N � a co I N = N N Y M = p 0 I N o CO O 2 II \\ /�� N 0 t0 V > ill C.) co o m• Y " w °° v o corn Z Q �- a) I co 0) I I v 0 0 I N O J � l� rn J rn To MOM pII I � 0co � X NON N-o NF- N N No o LJ (�\.. J O In M W O c? N Y N 4=1.IA i C �. KUP 2X-18L2-02 ConocoPhillips Well Attributes Max Angle&MD TD ,sem {I N, ' Wellbore APIIUWI Field Name Well Status Incl(°) MD(ftKB) Act Bbn(HKB) L6lrxtcrt1710kps 500292260864 IKUPARUK RIVER UNIT PROD 11.28/.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLE 10 1/13/2010 .Last WO_- 12/21/2010 41.00 5/9/1996 ;.,.._,n..._-Wfi WIAH'.ii2K-(420.2(2048,1i244b36 PM _.,- Sct1d?14dic-AtluaL. Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM Rev Reason:ADD CTD LATERALS,GLV C/O Imosbor 2/20/2011 FIANGER,36-- Casing Strings E.-;:: Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top That L2-02 LINER 23/8... 1.992 9,570.0 11,137.0 4.60. L-80 STL - Liner Details - --- TopDepth (1 ) Top Incl Komi... 4 Top(ftKB) (ftKBKB) C) Item Description Comment ID(in) 9,570.0 JUNCTION ALUMINUM JUNCTION(anchor billet) 1.992 H, . 9,582.2 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.992 Perforations&Slots CONDUCTOR, I Shot Shot 42-121 Top(TVD) Btm(TVD) Dens Top(ftKB) Btm MKS) (ftKB) (ftKB) Zone Date (ah-- Type Comment 9,704.0 11,136.0 2/6/2011 32.0 SLOTS SLOTTED LINER-slotted pipe- NIPPLE,490 0.125"k2.5"@ 4 circumferential lir adjacent rows,3"centers staggered 18 deg 3'non slotted ends --- 'Notes:General&Safety GAS 3LFT,_ End Date Annotation ,I262 __.. _.. 2/11/2011 NO I L:CI U LA I EPALS L1.L1-01 L2,L2-01,L2-01 DRILL ED i ' ,' SURFACE, 41-5,t30 GAS LIFT, 5,632 GAS LIFT, 7,220 GAS LIFT, 8,419 a III .111 9,150 LOCATOR,—.. 9,200 PBR,9,203-- ,I SEAL ASSY -- 9,217 PACKER,9,217 IF NIPPLE,9,267--- --- GAS LIFT /111 APERF, r JET' 9,374-9,394 4 7 APERF,__.. - 9,394-9,420 ' 1- J SEAL ASSY, Y 9.410 PACKER,9,440 Mandrel_Details 77 Top Depth!Top I I Pon WLEG.9,{59 (TVD) Inc) OD Valve Latch Size TRO Run WNW.*,500�- _ t Stn Top(ftKB) (ftKB) (°) Make Model (in) Seen Type Type (tn) (psi) Run Date Com_.. PRODUCTION,_.-. 1 3,261.7 2,446.7 57.44 CAMCO KBG-2-9 1 GAS LIFT GLV DK-1 0.156 1,210.0 2/19/2011 37-9,930 2 5,631.7 3,698.8 59.42 CAMCO KBG-2-9 1 GAS LIFT GLV DK-1 0.156 1,190.0 2/1812011 f� 3 SLOTS, L\ 7,220.0 4,546.5 59.03 CAMCO KBG-2-9 1 GAS LIFT GLV DK-1 0.188 1,207.0 2/18/2011 _ 9.704-11.136 -,, 4 8,419.5 5,162.1 54.90 CAMCO KBG-2-9 1 GAS LIFT GLV DK-1 0.188 1,189.0 2/18/2011 L2-02 LINER. 9,570-11.137 5 9,149.7 5,662.6 41.74 CAMCO KBG-2-9 1 GAS LIFT OV DKA 0.250 0.0 2/18/2011 TD (2x-181-2-02), 6 9,313.2 5,787.1 39.89 CAMCO KBG-2-9 11GAS LIFT DMY DK-1 0.000 0.0 12/20/2010 11,267 L2 LtNER, 10,742-11,405 .0- 44 Nr, 1 1 0 tW ON gig Z gl W 0 III c CU 0 Q co LLI Ce V/ 1 Q I— >, is2 u) z w a1111111111111 Cn MC immi O > X c = .> N N S.. C c 2 2 J N � �C as OO N � .5 VYYNLLS CO 0 0 gr, A z g a o v — 0 f �Z ▪ o m f. CO m p 0 0 0 C'D 40 Fa Lo i v i 7-a N N N $ O t, O O 'a CO C 7N CO 3 N 0 N W 6) N N 0) A itCO O C U 1 o m ? O N O 1 CI) CD ai a -."'▪ c O m R O 3 J J (7 ) a 91 • LO If) C a.N N a v O 5 N a p Y • ,_ n a a. a > ti t< O O O E C O O a O 00 co LU c c m U o V n a)w o CO Q W O c -o a C O c c 'E U N + O U al N7 EN .. w C Qco o o J a N y Ol (/) a g V CO > O co W p O CI, i L c 0) 0) 1--- co co c Lc) Q' <...w a) m c c co co O CO N.- Cl. - 2 ° `r' v o p O m= O• d c N a) 0 > . � da d R w CO - C ; c ., a`) a) U w r . aa) 4 O vi-- V m s m .0a es p E U V o p r :° aa)) 0O • o Z O J � � z° r'no E v F zea 6 0 2 m E c a) d F 0 2 0 1. L c L E O Z W 5s in a) I as i' p N O co c [ `- <- O D > N J W cn U) H F a c6 o x N m z Q £^ o d 0 X ° °XO w w w > o C 0 0 0 O J 1 Z OOOcoL a) co co U m a 0 is = a v 0 U) N N N Q D a a) C Z O `'.. N > 56 Z N N. O N • to a7 E O CV Q >_ x Y a) N N N Z N J o CO •r L a' N E a) (B CO 9 I co d co O O CL m - _ ..� o co co n cn Q m X Z W X C7 N H oLO N- N CO Q o. 7 7 7 Y D Z Q ' N + + .>' N �' CO 7 O �y O ��L . UYYNNN r : N = 0) CD7-1 O 0) V N E N _ 7 u) w of O O cV C C i co w c c c E V O a O O n R G — O C U >, N O O O N C w c0 N w. O w O to 7 a a) ,O C) a) co p N a .Q C -._a) U a) L O O n O U[ ' p O w of N a) O R a) lab ai a) y d R d 3 d d 3 LL co O O 0 a` co 0 a E c9 E - s a. 2 0 Q > > co a 0) ilk0 MI -4-) a 6 °' m MI6 m 7. CO mZ a CO o O 1--- co Q OY O ' U p CO Z o o p O w F I- T N M CO CO CO CO CO CO CO CO CO CO CO M CO CO CO CO M W CD o p p 0 0 0 0 O p p p 0 0 0 0 p O O p O 01• 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 a ; In LO LO N 7 N O 0 n C. 0) N O O CD N 0 7 N `' 0 CO N N C n n .- 0 N O N CO 0 7 R N t0 V c0 Cr, 0 7 U 0 _0 0 N '' n 0) O O M co O V 0 0 6 7 6 0 U) Y - N 0) co co O co UO N 0 co V co N CO 0 CO M ▪ Z. N N r- .- e- •- 0 0 0 0 a co co 0 co co 0 n n n (Q (0 co N N O O O 0 O OO O (O 0 UO UO U0 vi Un t0 l0 Uri Un U() u) CI d > 0) 8 —� -0 _ 80 .-. 0 n 0) co UO n 0) 0) (0 V op O N- •- 'a O N N- O O O i C O (O O V 0 c0 .- V N 0 O ,- N 0 V CO a O ' ! CO 00 J O 10 CO (0 O O •- v 0) 0) CO CO M Ts, 0 n N CO O z L/ V E vo Q 3 CO co co 0 O N co M Co n n n co n 0) O co co n co n 7 n o n CO O co co 7 CO N CO 0 CO O n V co — N co C O a ) O n 4 O 0 Un N O M n N 10 CO N CO M .- co 1` CO N X X C - N- CO R N 0) n c0 M CO (O M O 0 10 M 0) n R N N f W w w co co M co N N N N N •- •- •- •- O O O O 0 0) 0 N N N N N N N N N N N N N N N N N N 2 N NNNN NCVNNN N (V N N N N N N N N N LU 00 0 (0 10 co LO l0 UO UO U0 Un UO UO U0 U0 0 U0 U0 N 0 al U) p- c N O 0. � ' OO 0 N O 0 n n N 0 M 0) N 0) (O C. O N 7 N M t u_. w O a) d' n cO O CO O N n 10 O .- (0 N V O V 0) V CO 0 y N .- 00 CO M M M V c0 v 0 7 n 0 0 0 10 O " M C N co Un n CO CO CO n CO O .- M V CO CO O N U0 Cl) re C Q co to to co to UA co co co co co n n n n n co co co a. ' .. o (u .�V..co Uri co to to co 1n (L) 1n 00000 Uri Uri to cn Uri 0 ' �y d ._ "O CO CO 0 CD CO 00 CD CO CO CO CO CO 0 CO CO CO (O CO CD y Cl) (4 -- O • 0 6) 0) 0) CO O) 0) CO O) O) 0) 0) 0) 0) 0) 0) 0) 0) 0 0) 0) O vJ •C O N Z 1n Uri 0 c[) u) Uri Uri co co) co co Un to Uri Uri co 6 Uri Uri Un ,. co V -a C o d Cl) ® o ,_ 0 is B w V Cl) CO N O N O UO V 0 V 0 n CO O 1O O N (0 e{ 0 n' d .0 0 0 e , 0) .Q (0 c0 CO O c0 V N - 0 0 N R n o N N O n O N 5 V R i U) n CO V 0 n O M O OD co CO O CO 40 C') 0) n et 0 O p O a m _ `^ '7 V V etCO CO CO CO M N CU N N •- .- M 0 0 O - .0 2 Z 0 O W '' M M M CO) M M M M M M M M M M M CO. M M M t i Y 1.. _ `I M V O s CO n N OD 0 0 0 M O N CO V 0) O an Z. N t0 O M V V' (V C') n N 0) O C0 c0 UO M 4. n (O ^ M 0 n UO M 0 0 CO 1r) CO N O CO CO CO . e- e- O O O O 0 0 CO co O) co co co_ co co co R G, =co to 1r) 1r) (r) (n 1n u) ui q -c q q q v c c c n t. r t 3"' i s(O V 0 M O N n O 7 co co " 10 '7 10 C 0 N x i co n 0 0 0 .- co (V co 00 co N V V 0 co co n '7 co CO ( _ N c0 cr) O 7 00 10 4 V N O O 0 (O V N6 n V _ 0) N N N (V O O O O 0000 ° O O 0 0) 0 0) f.. 0 0) 0) 0) d) •0 0 0 0) 0 0 0 0) 0) 0 0) a1 co co co co t *.. > v Un N U U) co1n 6 lO N cO cO UO (n <6U0 Un Uri U) N co-. H _ _ U0 7 co Co O N n O N 0 co co CO U0 '' 0 N E n 0 0 co r M N Un CO CO N R V O V7 CO n C c0 M M 7 M 0 N co M N N M C 7 V 4 N O n 1O N 0 a U CI w et R O CO CO (Si N N N N N N N CV N N C O 4 C 0 0 0 a 0 0 0 0 0 0 0 0 0 0 O O O O O O s — H (O (O co 0 (O O O co O c0 cc 0 0 (O O CO c0 0 O c0 a 8 N I.oz _ _ _ C CO 0) 0 N CO V 0) n CO U0 O n n O O O QD -a n .- 0 0 n V 0 O 0 r• � n t0 (h O 0 O 0 0 V M M vl (6 'C co co co 0 — '' co ,- c0 O 0 M O n O (O 0 M M (/y ') 0. 4-) d , o 0 0 0 0 O 0 0 0 0 0 O M M CO CO CO CO CO CO CO CO CO N N CO CO CO CO M M M F, !i i� N r 0 Y Y `• 0 >_ L U N n M N 0) r' O COCO0) 0 7 R N CD n 0 10 ' CO CO OD O (II (O s `- O N CO U0 LO CO O c0 O •- CO n (V M O 0 CO M � e 0 a n X X X c ' coDco°Dm o CO rn m co co co°Dm m co a) rn 0 0 O) O) 0 a_ L./y+.q U Y Y N N N — V N N O CD CO CD 00 0) n CO CO V V C' CO N 'C' CO cn CO O € C)' O CO Un M CO CO UO 1n UO CO CO n N •- N M CO CO O r ;V •- N O O 0 0 0 0 0 O O_ O O O R O O O_ O n CCC .. y) .. Q ^ M V n 0 CO CD O N 0 CO d' N- O CO CD 0) '' OD a 0 •V O C T �+- n n n co c0 Co co 0 0) 0) O O 0 _ _ N N N y v v a` �n ocn g g g 2X-18 Well Work Summary DATE SUMMARY 12/31/10 ASSISTED ASRC IN REMOVAL OF BPV. ATTEMPTED TO PULL BALL & ROD. IN PROGRESS. 1/1/11 PULLED BALL& ROD; RHC PLUG BODY @ 9269'RKB. TAG @ 9664' SLM. MEASURED BHP @ 9628' RKB(2434 PSI). PULLED SOV @ 9150' RKB. IN PROGRESS. 1/4/11 WEATHER DELAYED START. DISPLACED IA WITH 100 BBL DSL. SET DV @ 9150' RKB. MIT IA 2500 PSI, PASSED. IN PROGRESS. 1/5/11 DRIFTED TBG TO 9663' SLM WITH 2.70"x 18.5' DUMMY WHIPSTOCK. READY FOR E-LINE. 1/6/11 SET 3-1/2"X 5-1/2" BAKER GEN II WHIPSTOCK AT 9560' (TOWS). ORIENTAION OF WHIPSTOCK WAS COMFIRMED WITH DPU-I TO BE 0.5 DEGREES LEFT OF HIGH SIDE UPON SETTING. *** FISH -SHEAR BLOCK WAS MISSING FROM BAKER SETTING ADAPTER. SHEAR BLOCK IS 1"X 1"X 4". 1/7/11 WITH LIB CONFIRMED LOST SETTING ADAPTOR @ 9554' SLM. ATTEMPTED FISH WITH MAGNET, NO RECOVERY. IN PROGRESS. 1/8/11 ATTEMPTED FISH SETTING ADAPTOR, NO RECOVERY. CONFIRMED FISH @ 6 O'CLOCK WITH LIB. IN PROGRESS. 1/10/11 RAN 2.25" LIB; SET DOWN @ TOP OF SETTING ADAPTOR. RAN BOWEN OVERSHOT TO TOP OF WHIPSTOCK @ 9541' SLM. UNABLE TO WORK PAST TO FISH @ 9546'SLM. IN PROGRESS. 1/11/11 RAN 1" OVER SHOT TO 9546' SLM, RAN 1 3/8" OVERSHOT TO SAME; UNABLE TO LATCH FISH. RDMO. 1/13/11 SET 3-1/2"X 5-1/2" BAKER GEN II WHIPSTOCK WITH TOWS AT 9545'AND ORIENTED 13 DEGREES LEFT OF HIGH SIDE. RA TAG LOCATED AT 9552.3'. 1/16/11 PRE CTD PT SV, MV,SSV( PASSED ) DDT SV, SSV ( PASSED ) 2X-18 Post Rig Well Work DATE SUMMARY 2/17/11 TAGGED LINER TOP @ 9446' SLM. MEASURED SBHP @ 9440' RKB. SET SV @ 9269' RKB. PULLED DVs @ 9149', 8419' RKB. IN PROGRESS. 2/18/11 PULL DVs @ 7220', 5631' RKB. SET GLVs @ 9149', 8419', 7220', 5631' RKB. ATTEMPT TO PULL DV @ 3261' RKB, NO SUCCESS. (LOST NOSE CONE OFF DV @ 7220' RKB). IN PROGRESS. 2/19/11 PULL DV @ 3261' RKB. SET GLV @ 3261' RKB. PULL CATCHER SUB @ 9269' RKB. POST RIG GAS LIFT VALVE INSTALL COMPLETE. ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 2X-18 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 1/20/2011 12:00:00 AM Rig Release: 2/10/2011 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/17/2011 24 hr Summary Rig maintenance at 1B-19 18:00 00:00 6.00 MIRU MOVE RGRP X Rig maintenance at 1B-19. Replacing injector skates and lowered mast to work on job arm. 01/18/2011 Rig Maint. injector skate repairs 00:00 19:00 19.00 MIRU MOVE RGRP X Rig maintenance at 1B-19. Continued skate repair. Stood mast back up without being able to work on jib arm. 19:00 00:00 5.00 MIRU MOVE MOB P Start moving rig from 1B-pad to 2X-pad. Nabors standard pad-to-pad move. 01/19/2011 Spot rig over 2Z-19, RU. Rig repairs on Mast. 00:00 09:00 9.00 MIRU MOVE MOB P Move onto location and spot over well. 09:00 20:00 11.00 MIRU MOVE RGRP X Start working on Mast operations. Lay over mast, repair top cylinder of jib arm. 20:00 00:00 4.00 MIRU MOVE RGRP X Raise mast,test JIB boom.Still not working. String cables,stab CT,MU PDL's and stand in derrick with JIB booms. 01/20/2011 Pump slack management,cut 50'CT finding E-line at 4'. Perform BOP test,MU CTC and Drilling Head. Deploy BHA#1,straight motor with window mill and string mill. 00:00 01:00 1.00 SURPRI WELLPF CIRC P Load 100deg seawater onto rig. Displace throughout rig warming up. ****Rig Accept at 00:00 hrs**** 01:00 03:00 2.00 SURPRI WELLPF SLPC P Pump slack management,Cut 50' CT. Found cable 3'cut 03:00 04:00 1.00 MIRU WHDBO BOPE P Prepare for BOP testing 04:00 06:00 2.00 MIRU WHDBO BOPE P **State test waived by Lou Grimaldi*** Start BOP testing.Tree valves good R-1 failed/Pass.Continue with BOP testing. 06:00 13:30 7.50 MIRU WHDBO BOPE P Complete BOP test,alarms& drawdown test. 13:30 15:00 1.50 MIRU WHDBO SEQP P Cycle and thaw return line,P/U lubricator and clean up rig floor from BOP test. Page 1 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 MIRU WHDBO BOPE P Rig up and pull BPV. IA=1500/OA 330/SITP 180.Shut in master& swab valve. Unseated BPV but did not latch. 16:30 17:30 1.00 MIRU WHDBO BOPE P Try again with adding a 3ft extension &new stinger sub. BPV pulled. 17:30 18:00 0.50 MIRU WHDBO BOPE P Rig down&crew change. 18:00 19:30 1.50 SURPRI WELLPFSLPC P MU Coiled Tubing connector,pull test 30K,good 19:30 21:00 1.50 SURPRI WELLPFSLPC P MU BHI Drilling head 21:00 21:30 0.50 SURPRI WELLPFSLPC P Test drilling head,good. Pressure test CTC 4500 psi,good, Prepare to PU milling BHA 21:30 21:45 0.25 PROD1 WHPST SFTY P PJSM pick up tools 21:45 22:30 0.75 PROD1 WHPST PULD P PU/MU tools into PDL. 22:30 22:45 0.25 PROD1 WHPST PRTS P PT PDL, 1500 psi good. 22:45 00:00 1.25 PROD1 WHPST PULD P Deploy BHA 1 01/21/2011 RIH with BHA#1 (straight motor window mill with string mill).Tag at 3264'. Ice plug,milled through,cont. RIH. Swap well over to Biozan milling fluid. Pump 15bbrls high vis pill into perfs establishing returns with.4 BPM losses. Mill window 9548.7'-9564'with approx. 15'of rat hole. Backream,drift and squeeze high vis pill into perfs POOH following MP. PU,deploy drilling BHA. HOT(orienter)failure at surface. Undeploy BHA 2, Deploy BHA3. 00:00 01:00 1.00 0 3,264 PROD1 WHPST TRIP P RIH 01:00 01:15 0.25 3,264 3,266 PROD1 WHPST TRIP P Tag up. PUH close EDC.Online with pumps 1 BPM in, .4 BPM out.RIH slowly 1 BPM in. POP through. Possible ice plug. PUH through trouble spot. RIH,see nothing 01:15 02:45 1.50 3,266 9,250 PROD1 WHPST TRIP P Continue RIH 02:45 03:00 0.25 9,250 9,250 PROD1 WHPST DLOG P Tie in depth+6'correction. Differential will not equalize. Unable to open EDC. 03:00 03:15 0.25 9,500 9,500 PROD1 WHPST CIRC P RIH 9500'PUH 10 FPM, unable to establish returns. 1.4 BPM.70 psi WHP.closed choke.75 bbrls pumped from RIH. 03:15 03:45 0.50 9,500 9,549 PROD1 WHPST CIRC P Send pill 20 bbrls of high vis pill (plug)to establish returns, recipricating pipe inside 5.5"tubing. Manipulate MP choke to squeeze pill into perfs. .65 BPM.300 psi WHP, 11.8 ECD. 150 bbls diverted to Tiger tank 03:45 04:45 1.00 9,549 9,549 PROD1 WHPST CIRC P Start maintaining returns 1.4 BPM in, .95 BPM out.Offline with pumps dry tag WS.9549'. PUH,34K PUW. 04:45 06:45 2.00 9,549 9,550 PROD1 WHPST MILL P Start milling, 1.4 BPM in, .9 BPM out,50 MP choke.3400 CTP,484 off bottom diff,550 on bottom diff. Higher vibrations on BHA. Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:15 1.50 9,550 9,552 PROD1 WHPST MILL P Light metal shavings over shaker. Continue milling window. 1.35 bpm, 3600 psi, BHP 3550,WHP 50, ECD 11.7. High vibrations on motor.Solid 4. 08:15 13:15 5.00 9,552 9,564 PROD1 WHPST MILL P Continue milling as per procedure. Exit @ 9553.2'.Vibrations between 3 &4.Good formation in returns @ 9557'-Increase ROP 3-5 fph,WOB .8K 13:15 14:45 1.50 9,564 9,564 PROD1 WHPST REAM P Start backreaming passes&dry run -clean.Start pumping 30 bbl LCM pill. Pill at bit trap 200 psi on choke BHP -3650 psi. 1.3 bpm in,out.7bpm. Open choke slowly as BHP is climbing after 20 bbls away. IA 450/ OA 400 14:45 17:15 2.50 9,564 0 PROD1 WHPST TRIP P POOH following MPD. 17:15 17:45 0.50 0 0 PROD1 WHPST SFTY P At surface,PJSM, Undeploy,Crew Change,PJSM with new crew 17:45 19:15 1.50 0 0 PROD1 WHPST PULD P Undeploy BHA 1 and LD Mill gauged 2.8 tight go,2.79 No-Go 19:15 20:15 1.00 0 0 PROD1 DRILL PULD P PU/MU BHA. (This time needed due to not having 2nd PDL) 20:15 20:30 0.25 0 0 PROD1 DRILL SFTY P PJSM,deploy BHA 2, (2 Deg AKO) 20:30 21:30 1.00 0 0 PROD1 DRILL PULD P Deploy BHA, Unable to communicate to HOT(Orienter). 21:30 21:45 0.25 0 0 PROD1 DRILL SFTY T PJSM ***BHI Non Billable Time*** 21:45 22:30 0.75 0 0 PROD1 DRILL PULD T Undeploy BHA 2 22:30 23:15 0.75 0 0 PROD1 DRILL PULD T Swap out HOT 23:15 23:30 0.25 0 0 PROD1 DRILL SFTY T PJSM 23:30 00:00 0.50 0 0 PROD1 DRILL PULD T Deploy BHA#3(2 deg AKO) 01/22/2011 RIH swap well over to new Flo-Pro. Drill build section, 9564'to 9705'. POOH. Undeploy BHA 3,deploy BHA 4. (.8 deg AKO). Drill L1 lateral 9705'to 9855'.After tie into RA marker confirmed window depths,TOW=9548'/ BOW=9553'/RA tag=9552' 00:00 00:30 0.50 0 0 PROD1 DRILL PULD T Deply BHA#3(2 deg AKO) 00:30 02:45 2.25 72 9,280 PROD1 DRILL TRIP P RIH 02:45 03:00 0.25 9,280 9,545 PROD1 DRILL DLOG P Tie in depth+6'correction 03:00 03:21 0.35 9,545 9,545 PROD1 DRILL TRIP P RIH 15K RIW,34K PUW to 9500'. Close EDC,drift window with 2 deg AKO. 03:21 04:51 1.50 9,535 9,535 PROD1 DRILL CIRC P Drift good, PUH 35K.Open EDC. Displace well to new Flo-Pro 1.4 BPM in, 1.1 BPM out. 11.98 ECD open choke 04:51 06:21 1.50 9,564 9,600 PROD1 DRILL DRLG P Close EDC-drift through window- Start drilling build. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:21 09:21 3.00 9,600 9,705 PROD1 DRILL DRLG P Drilling build section-1.40 bpm, 3500, BHP 3660, ECD 11.9, ROP 70,WOB 1.3,Ct weight 12K.rate out 1.15 bpm.TD build section. Better sand quality near the end of the build. 09:21 09:51 0.50 9,705 9,550 PROD1 DRILL DLOG P P/U weight 31K,Wiper up through window&tie in to formation&RA tag to correct window depths.Tie in correction+0.5'RA marker @ 9552'. Had 2-3 K overpull at window when P/U through it @ 20 left.Came through smoother second time, smaller weight bobble. 09:51 12:00 2.15 9,550 72 PROD1 DRILL TRIP P TOW=9548', RA 9552',BOW 9553' -POOH to change BHA following MPD. 12:00 14:00 2.00 72 0 PROD1 DRILL PULD P PJSM-Undeploy BHA, injecting @ 1/4 bpm at surface. 14:00 14:30 0.50 0 0 PROD1 DRILL SFTY P Secure well. Have a pre-spud meeting with new day crew. 14:30 16:00 1.50 0 72 PROD1 DRILL PULD P Deploy drilling BHA with.8 AKO& new style 2.73"Bi-center bit. Hydraulics on PDL running slow due to cold temperatures. 16:00 18:15 2.25 72 9,280 PROD1 DRILL TRIP P RIH following MPD. 18:15 18:30 0.25 9,280 9,705 PROD1 DRILL DLOG P Tie in+3'Correction, RIH 18:30 21:15 2.75 9,705 9,811 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.16 BPM out,30-50 FPH,3790 CTP, 13K • CTW,3678 BHP, 11.9 ECD, 2 K WOB, 125 MP choke 21:15 21:30 0.25 9,811 9,760 PROD1 DRILL WPRT T Lose prime on pump PUH 32K 21:30 23:30 2.00 9,811 9,855 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.2 BPM out, 10-50 FPH,3790 CTP, 13K CTW, 3678 BHP, 11.9 ECD,2 K WOB, 125 MP choke 23:30 00:00 0.50 9,855 9,855 PROD1 DRILL WPRT P Wiper trip to window,32K PUW 01/23/2011 Drill L1 Lateral 9855-10599'.Total losses past 24hrs. 135bbrls. 00:00 02:15 2.25 9,855 9,910 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.2 BPM out, 10-50 FPH,3790 CTP, 13K CTW,3678 BHP, 11.9 ECD, 2 K WOB, 125 MP choke 02:15 02:36 0.35 9,910 9,910 PROD1 DRILL WPRT P Geo wiper,32K PUW 02:36 03:51 1.25 9,910 9,955 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.2 BPM out, 10-50 FPH,3790 CTP, 13K CTW,3728 BHP, 12 ECD,2-3 K WOB, 125 MP choke 03:51 06:51 3.00 9,955 10,005 PROD1 DRILL DRLG P PUH 38K,4Koverpulls,Hard formation.Stall X 4.Continue _ attempting to drill past. 06:51 07:21 0.50 10,005 10,005 PROD1 DRILL WPRT P Wiper trip-P/U 33K Page 4 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:21 10:21 3.00 10,005 10,155 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3500, BHP 3705, ECD 12,WHP 150, ROP 90, WOB 2.2,CT weight 12K. Losses are roughly 4 bbls per hour 10:21 11:21 1.00 10,155 10,155 PROD1 DRILL WPRT P Wiper trip-34K off bottom,nice clean sand in returns.Tie in with+3 ft correction. 11:21 14:51 3.50 10,155 10,305 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3700, BHP 3720, ECD 12,WHP 150, ROP 50, WOB 2.1,Ct weight 13K,rate out 1.15.Turning up to get back into good sand. 14:51 15:51 1.00 10,305 10,305 PROD1 DRILL WPRT P Wiper trip-P/U weight 35K 15:51 17:51 2.00 10,305 10,455 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3580, BHP 3710, ECD 11.9,WHP 100 psi, WOB 1.6K, ROP 80,Ct weight 14K, rate out 1.2 bpm. 17:51 19:06 1.25 10,455 10,455 PROD1 DRILL WPRT P Wiper trip to window-PUW 35K 19:06 21:45 2.65 10,455 10,576 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3580, BHP 3710, ECD 11.9,WHP 100 psi, WOB 1.6K, ROP 40-80,Ct weight 13K,rate out 1.2 bpm. 21:45 22:00 0.25 10,576 10,576 PROD1 DRILL WPRT P BHA Wiper PUW 34K 22:00 00:00 2.00 10,576 10,599 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3580, BHP 3710, ECD 11.9,WHP 100 psi, WOB 1.6K, ROP 10-40,Ct weight 12K,rate out 1.2 bpm. 01/24/2011 Drill L1 lateral 10599'to 11221'(TD). POOH to surface chasing sweeps. RIH to TD to lay in liner running pill. 00:00 00:21 0.35 10,599 10,605 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3880, BHP 3710, ECD 11.9,WHP 100 psi, WOB 1.6K, ROP 10-40,Ct weight 12K,rate out 1.2 bpm. 00:21 01:00 0.65 10,605 9,545 PROD1 DRILL WPRT P Wiper trip to window 33K PUW 01:00 01:15 0.25 9,545 9,545 PROD1 DRILL DLOG P Tie in depth to RA marker.+2.5' 01:15 02:00 0.75 9,545 10,605 PROD1 DRILL WPRT P RIH 02:00 06:30 4.50 10,605 10,755 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3780, BHP 3780, ECD 11.9,WHP 100 psi, WOB 2K, ROP 10-50,Ct weight 12K, rate out 1.2 bpm. 06:30 08:00 1.50 10,755 10,755 PROD1 DRILL WPRT P Wiper trip-P/U weight 34K 08:00 09:30 1.50 10,755 10,905 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3800, BHP 3770, ECD 12.2, ROP 90,WOB 1.9K,CT weight 12K, rate out 1.2 bpm. Losses=5 bph. 09:30 11:00 1.50 10,905 10,905 PROD1 DRILL WPRT P Wiper trip-P/U weight 33K. 11:00 13:00 2.00 10,905 11,055 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3800, BHP 3760, ECD 12.2, ROP 110,WOB 1.5,Ct weight 12K, rate out 1.15 13:00 15:00 2.00 11,055 11,055 PROD1 DRILL WPRT P Wiper trip with tie in with+3 ft • correction. Page 5 of 18 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 15:00 16:45 1.75 11,055 11,221 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3850,BHP 3820, ECD 12.4,WHP 50, ROP 110, WOB 1.1K,CT weight 11k.Pump 10 bbls Low/high sweeps. 16:45 21:00 4.25 11,221 0 PROD1 DRILL WPRT P TD lateral-P/U weight 34K.Wiper to window,continue chasing sweeps to swab valves. Good cuttings returns during trip to swab. 21:00 23:00 2.00 0 9,275 PROD1 DRILL TRIP P RIH from surface 23:00 23:15 0.25 9,275 9,275 PROD1 DRILL DLOG P Tie in depth+11'correction 23:15 00:00 0.75 9,275 11,221 PROD1 DRILL TRIP P Close EDC, RIH through window to TD 01/25/2011 Drilling BHA became stuck in window,pulled free and ran a crayola mill to redress window. Displaced well to KWF. 00:00 01:15 1.25 11,221 9,553 PROD1 DRILL TRIP P Tag TD 11221'POOH laying in liner pill 01:15 03:45 2.50 9,548 9,548 PROD1 DRILL TRIP T Pull up in window, BHA torqued up, get—5K overpull on WOB sensor. Bit stuck at very top of window. Try to get free pushing down.Work pipe max.down 11K,Max P/U 3K on bit. Sit for 30 minutes,discuss with town.P/U to 10K over surface weight,-5K WOB and popped free. 03:45 05:45 2.00 9,548 9,500 PROD1 DRILL CIRC T POOH to 9500'-Clean out the trip pit,start circulating out the KWF from CT string with milling fluid while POOH slowly.Stop&Open EDC once beads are clear. Milling fluid @ bit. RIH to circulate out well following MPD. 05:45 07:45 2.00 9,500 0 PROD1 DRILL TRIP T POOH following MPD 07:45 09:45 2.00 0 0 PROD1 DRILL PULD T PJSM-Undeploy BHA-hydraulics on jib running slow due to-40 temps. Service injector&MPD choke. Bit shows damage&evidence of where we hung up on the reamer blade. 09:45 11:15 1.50 0 0 PROD1 DRILL PULD T MU milling BHA#5 to dress window (straight AKO motor,string mill, crayola mill, no HOT) 11:15 12:30 1.25 0 63 PROD1 DRILL PULD T Deploy BHA#5, 12:30 13:30 1.00 63 63 PROD1 DRILL RGRP T MP choke not working properly, diagnose problem 13:30 15:45 2.25 63 9,275 PROD1 DRILL TRIP T RIH 15:45 16:00 0.25 9,275 9,545 PROD1 DRILL DLOG T Tie in depth,+2'correction 16:00 16:15 0.25 9,545 9,560 PROD1 DRILL TRIP T RIH,through window dry,small set down 0.5K WOB. Page 6 of 18 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:15 16:45 0.50 9,560 9,560 PROD1 DRILL REAM T PUH 1 FPM backreaming window X 2, Dry running down through window. 50psi increase on diff. 1.2 BPM in, 1 BPM out.32K PUW, 82 WHP,3700 CTP,250psi off bottom. 16:45 19:00 2.25 9,560 9,560 PROD1 DRILL REAM T RIH through window pumps on, PUH backreaming.See nothing.30 psi increase on diff.when running through window. Tie into RA,on depth, Back ream two more passes. 19:00 23:00 4.00 9,560 0 PROD1 DRILL DISP P Open EDC and circulate in 12.0 ppg KWF, POOH 23:00 23:30 0.50 0 0 PROD1 DRILL SFTY P PJSM for LD BHA,discuss top drive and other operations in extreme cold weather. 23:30 00:00 0.50 0 0 PROD1 DRILL PULD T Lay down milling BHA,blow down BHA and surface lines 01/26/2011 Ran L1 lateral liner to TD at 11221', liner top billet at 9733',milled off billet and continued drilling L1-01 lateral 00:00 01:00 1.00 0 0 PROD1 DRILL PULD T Continue to lay down milling BHA 01:00 01:30 0.50 0 0 COMPZ CASING PUTB P Rig up floor for liner operations 01:30 01:54 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations 01:54 06:45 4.85 0 1,532 COMPZ CASING PUTB P PU 45 joints of slotted liner and coil track BHA,MU injector to well 06:45 08:36 1.85 1,532 9,335 COMPZ CASING RUNL P RIH Counter for BHI depth control not working. Remove to repair.RIH to EOP flag. 08:36 09:15 0.65 9,335 9,335 COMPZ CASING RGRP P Install counter for BHI depth control 09:15 10:00 0.75 9,335 11,221 COMPZ CASING RUNL P RIH to TD. Record up and down weights.34K PUW, 17K RIW 10:00 12:30 2.50 11,220 11,000 COMPZ CASING RUNL P Tag TD, 11221.0',Online with pumps,release off line.34K PUW. BOT concerned of release. RIH tag TOL, PU 41K, RIH to TD online with pumps,4200psi, PUH 35K, POOH 12:30 12:45 0.25 11,000 0 COMPZ CASING OWFF P at surface.flow check well 12:45 13:45 1.00 0 0 COMPZ CASING PULD P LD BHA#6, Function test BOP's 13:45 14:45 1.00 0 0 PROD2 STK PULD P PU BHA 7,(1.4 deg AKO, used Razor) 14:45 16:45 2.00 0 9,278 PROD2 STK TRIP P RIH 16:45 17:00 0.25 9,278 9,310 PROD2 STK DLOG P Tie in depth,+11' 17:00 17:30 0.50 9,500 9,500 PROD2 STK EQRP T Change out BHI depth counter assembly 17:30 18:30 1.00 9,500 9,500 PROD2 STK DISP P Displace KWF from well 18:30 18:54 0.40 9,500 9,733 PROD2 STK TRIP P Continue RIH,drifted throuhg window clean. Page 7 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:54 22:06 3.20 9,733 9,760 PROD2 STK KOST P Tag billet,bring pump online at 1.4 BPM,4000 CTP,33K PUW, 15K RIW,Mill on billet starting at 1 FPH for 1 foot,then 2 and three FPH for 1 foot each then drill ahead. 22:06 22:18 0.20 9,760 9,760 PROD2 STK KOST P Pull op hole past billet at m.3 BPM, RIH with pump off. 22:18 00:00 1.70 9,760 9,837 PROD2 DRILL DRLG P Continue drilling ahead 01/27/2011 Drilled L1-01 lateral to TD at 10,672' 00:00 01:42 1.70 9,837 9,910 PROD2 DRILL DRLG P Continue drilling L1-01 lateral, 1.4 BPM,3900 CTP,3700 BHP, 114K RIW,33K PUW 01:42 02:12 0.50 9,910 9,910 PROD2 DRILL WPRT P Wiper trip to window,33K PUW 02:12 04:12 2.00 9,910 10,060 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3930 CTP, 3730 BHP, 14K RIW 04:12 05:27 1.25 10,060 10,060 PROD2 DRILL WPRT P Wiper trip to the window,31K 05:27 08:42 3.25 10,060 10,210 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3930 CTP, 3730 BHP, 14K RIW 08:42 10:12 1.50 10,210 10,210 PROD2 DRILL WPRT P Wiper trip to the window,31K 10:12 10:27 0.25 10,210 10,210 PROD2 DRILL DLOG P tie in depth to RA marker, +.5' correction 10:27 12:27 2.00 10,210 10,361 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3930 CTP, 3730 BHP, 14K RIW 12:27 13:42 1.25 10,361 10,361 PROD2 DRILL WPRT P Wiper trip to the window,31K 13:42 17:30 3.80 10,361 10,510 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3930 CTP, 3730 BHP, 14K RIW 17:30 18:48 1.30 10,510 10,510 PROD2 DRILL WPRT P Wiper trip to window,34K PUW 18:48 20:36 1.80 10,510 10,672 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3900 CTP, 3740 BHP, 13K RIW 20:36 22:00 1.40 10,672 9,570 PROD2 DRILL WPRT P TD at 10,670', pump 10 bbl low vis sweep then 10 bbl high vis sweep. Wiper to window 22:00 22:12 0.20 9,570 9,600 PROD2 DRILL DLOG P Tie-in,+2.5' 22:12 23:00 0.80 9,600 10,672 PROD2 DRILL WPRT P Wiper trip back in hole, 15K RIW 23:00 00:00 1.00 10,672 9,400 PROD2 DRILL DISP P Tagged TD at 10672', lay in liner running pill while POOH. No problem pulling bit through window. 01/28/2011 Circulated well to KWF, ran liner to TD,liner top at 9547', Displace KWF with flo-pro. POOH for WS.(80bbrls total losses of KWF) 00:00 02:06 2.10 9,400 0 PROD2 DRILL WPRT P Continue wiper trip to the swab valve circulating at 1.4 BPM through the open EDC. 02:06 04:18 2.20 0 9,540 PROD2 DRILL WPRT P Wiper back in hole from the swab valve 04:18 04:54 0.60 9,245 9,540 PROD2 DRILL DLOG P Tie-in at K1,+25'(Counter wheel was changed on last run) 04:54 05:54 1.00 9,540 9,540 PROD2 DRILL DISP P Circulate KWF, POOH and paint flags at 9400'EOP and 8300'EOP. 05:54 07:54 2.00 9,540 0 PROD2 DRILL TRIP P POOH 07:54 08:09 0.25 0 0 PROD2 DRILL OWFF P At surface, Flow check, PJSM Page 8 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:09 09:24 1.25 0 0 PROD2 DRILL PULD P LD BHA 09:24 09:39 0.25 0 0 COMPZ CASING PUTB P Prep floor to run liner 09:39 09:54 0.25 0 0 COMPZ CASING SFTY P PJSM running liner 09:54 11:54 2.00 0 0 COMPZ CASING PUTB P PU/MU Liner 11:54 12:24 0.50 0 0 COMPZ CASING SFTY P Crew change, PJSM 12:24 12:54 0.50 0 0 COMPZ CASING PUTB P MU BHA to liner 12:54 14:54 2.00 1,169 9,440 COMPZ CASING RUNL P RIH 14:54 16:00 1.10 9,468 10,673 COMPZ CASING RUNL P Tie into EOP flag. +25'correction. RIH Record up wt 33K, RIH to TD 16:00 16:12 0.20 10,673 10,673 COMPZ CASING RUNL P Release off liner 4200 psi,32 K PUW, 10K to 2K WOB,Good release, PUH to cased hole tie in marker, Remove Liner length from Bit Depth. 16:12 16:30 0.30 9,230 9,230 COMPZ CASING DLOG P Tie in depth(gamma)+25.5' correction Liner on bottom 10672.5,TOL 9547' 16:30 18:00 1.50 9,525 9,525 COMPZ CASING DISP P RIH displace well back to Flo-Pro 18:00 20:30 2.50 9,525 0 COMPZ CASING TRIP P POOH 20:30 22:00 1.50 0 0 COMPZ CASING PULD P Undeploy liner running BHA 22:00 00:00 2.00 0 0 PROD3 RPEQPI PULD P Deploy Whipstock setting BHA 01/29/2011 Set Whipstock at 9500'TOWS,milled window and 10'formation, back reamed window. 00:00 02:18 2.30 0 9,260 PROD3 RPEQP1TRIP P RIH with Whipstock setting BHA 02:18 02:30 0.20 9,260 9,300 PROD3 RPEQPI DLOG P Tie in to K1,+24' 02:30 02:48 0.30 9,300 9,513 PROD3 RPEQP1 WPST P Set whipstock at 9500'TOWS, oriented 25 ROHS,pumped at.4 BPM,set at 3500 CTP,set down 5K 02:48 05:00 2.20 9,513 0 PROD3 RPEQP1TRIP P POOH 05:00 06:30 1.50 0 0 PROD3 RPEQP1PULD P Undeploy whipstock setting BHA 06:30 08:30 2.00 0 0 PROD3 WHPST PULD P Deply BHA 10(0.6 AKO window mill with string mill) 08:30 10:45 2.25 0 9,255 PROD3 WHPST TRIP P RIH 10:45 11:00 0.25 9,255 9,255 PROD3 WHPST DLOG P Tie in depth,+23.5'.Close EDC, Record up weight 31K, RIH to WS 11:00 12:15 1.25 9,504 9,504 PROD3 WHPST MILL P Dry tag pinch point 9504.4',.5K WOB. PUH 32K. RIH to mill,stall 9500.4 TOWS, PUH 32K. RIH slower ROP to start milling. 12:15 13:15 1.00 9,504 9,505 PROD3 WHPST MILL P Strat milling window 9504.4'..1 FPH auto driller,341 off bottom diff, 366 on bottom and increasing, 1.44 BPM in, 1.27 BPM out,3756 CTP, 14.5K CTW, 1K WOB Page 9 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:15 1.00 9,505 9,507 PROD3 WHPST MILL P Continue milling window 9505.4'..1 FPH auto driller,341 off bottom diff, 475 on bottom, 1.44 BPM in, 1.27 BPM out,3830 CTP, 13.5K CTW, 1.4K WOB 14:15 15:15 1.00 9,507 9,508 PROD3 WHPST MILL P Continue milling window 9506.6'..1 FPH auto driller,341 off bottom diff, 508 on bottom, 1.44 BPM in, 1.27 BPM out,3754 CTP, 12.7K CTW,2K WOB 15:15 16:30 1.25 9,508 9,510 PROD3 WHPST MILL P Continue milling window 9509'..1 FPH auto driller,341 off bottom diff, 472 on bottom, 1.44 BPM in, 1.27 BPM out,3815 CTP, 12.8K CTW, 1K WOB,diff psi and WOB dropping off 16:30 19:48 3.30 9,510 9,514 PROD3 WHPST MILL P Continue milling window 9510'..2 FPH auto driller,341 off bottom diff, 418 on bottom, 1.44 BPM in, 1.27 BPM out,3822 CTP, 13.7K CTW, .5K WOB 19:48 20:30 0.70 9,514 9,519 PROD3 WHPST MILL P Drilling formation 20:30 22:00 1.50 9,519 9,519 PROD3 WHPST REAM P Back ream window 4 times at 1 FPM,dry pass down then up, clean. 22:00 00:00 2.00 9,519 1,000 PROD3 WHPST TRIP P POOH 01/30/2011 POOH,undeploy window milling BHA.Test BOP equipment. Deploy drilling BHA for L2 build section and RIH,start drillin . 00:00 00:24 0.40 1,000 0 PROD3 WHPST TRIP P Continue POOH, PJSM for undeploy. 00:24 01:36 1.20 0 0 PROD3 WHPST PULD P Undeploy milling BHA 01:36 04:00 2.40 0 0 PROD3 DRILL BOPE P Prep for BOP test,jet stack, circulate in water for BOP test 04:00 14:00 10.00 0 0 PROD3 DRILL BOPE P Start testing BOP. ***State witnessing of test was waived by John Crisp*** 14:00 16:00 2.00 0 0 PROD3 DRILL BOPE P PJSM, LD BOP test joint.MU QTS onto well, Install check valves into MHA. Drilling did not pass meg test. Swap out flow sub in drilling head. Meg test good 16:00 18:00 2.00 0 0 PROD3 DRILL PULD P PJSM, Deploy build BHA(2.3+deg motor, Hughes Z-cutter bi-center bit) 18:00 20:18 2.30 0 9,260 PROD3 DRILL TRIP P RIH 20:18 20:42 0.40 9,260 9,519 PROD3 DRILL DLOG P Tie in,+23',close EDC and RIH through window,clean. 20:42 00:00 3.30 9,519 9,638 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3650 BHP,31KPUW, 14K RIW, losing 6 BPH. 01/31/2011 Landed build section at 9900',tripped for lateral BHA and drilled ahead to 10510' 00:00 01:36 1.60 9,638 9,670 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3650 BHP,31KPUW, 14K RIW, losing 6 BPH. 01:36 01:48 0.20 9,670 9,670 PROD3 DRILL WPRT P Wiper trip to the window Page 10 of 18 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:48 03:06 1.30 9,670 9,830 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3700 BHP,31KPUW, 14K RIW, losing 6 BPH. Start mud swap at 9700' 03:06 03:18 0.20 9,830 9,830 PROD3 DRILL WPRT P Wiper to the window 03:18 04:54 1.60 9,830 9,900 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3600 CTP, 3650 BHP w/150 WHP 32K PUW, 14K RIW 04:54 08:24 3.50 9,900 0 PROD3 DRILL TRIP P POOH,Tie in to K1 and RA, RA came in at 9507' 08:24 08:39 0.25 0 0 PROD3 DRILL SFTY P At surface, PJSM 08:39 10:09 1.50 0 0 PROD3 DRILL PULD P Undeploy BHA and LD,Service Injector Head and change stripper 10:09 11:39 1.50 0 0 PROD3 DRILL PULD P PU BHA 12(.8 deg AKO),Deploy 11:39 13:39 2.00 0 72 PROD3 DRILL TRIP P RIH 13:39 13:54 0.25 72 7,255 PROD3 DRILL DLOG P Tie in depth,+23' 13:54 14:24 0.50 7,255 9,900 PROD3 DRILL TRIP P RIH 14:24 16:36 2.20 9,900 10,060 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3680 BHP,31 KPUW, 14K RIW, 16:36 17:36 1.00 10,060 10,060 PROD3 DRILL WPRT P Wiper trip to window 17:36 18:36 1.00 10,060 10,210 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,4000 CTP, 3736 BHP,31K PUW, 14K RIW, 18:36 19:36 1.00 10,210 10,210 PROD3 DRILL WPRT P Wiper Trip to window 19:36 21:06 1.50 10,210 10,360 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3941 CTP, 3756 BHP,31K PUW, 14K RIW, 21:06 22:06 1.00 10,360 10,360 PROD3 DRILL WPRT P Wiper trip to window,Tie into RA marker,no correction 22:06 23:36 1.50 10,360 10,510 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3650 BHP,31KPUW, 14K RIW 23:36 00:00 0.40 10,510 10,510 PROD3 DRILL WPRT P Wiper trip to window 02/01/2011 Drill 10,510 to 11,296', 00:00 00:48 0.80 10,510 10,510 PROD3 DRILL WPRT P Continue wiper trip to window 00:48 01:54 1.10 10,510 10,662 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3650 BHP,31KPUW, 14K RIW 01:54 03:06 1.20 10,662 10,662 PROD3 DRILL WPRT P Wiper to window,32K PUW 03:06 04:06 1.00 10,662 10,798 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3750 BHP,32K PUW, 14K RIW 04:06 04:42 0.60 10,798 9,520 PROD3 DRILL WPRT P Wiper to window,stacking excessive surface weight,33K PUW 04:42 04:48 0.10 9,520 9,550 PROD3 DRILL DLOG P Tie-in,Zero correction 04:48 05:30 0.70 9,550 10,798 PROD3 DRILL WPRT P Wiper back in hole, 14K RIW 05:30 11:18 5.80 10,798 10,960 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3775 BHP,32K PUW, 13K RIW. Drilled into shale and seem to have had some bit balling issues 11:18 13:00 1.70 10,960 10,960 PROD3 DRILL WPRT P Wiper to window,33K PUW Page 11 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:00 14:06 1.10 10,960 11,110 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3850 BHP, 12K RIW, 14:06 16:06 2.00 11,110 11,110 PROD3 DRILL WPRT P Wiper to window,34K PUW tight spot @ 10700 PUW=41 K 16:06 17:30 1.40 11,110 11,120 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3800 CTP, 3860 BHP, 12K RIW, 17:30 18:00 0.50 11,120 11,120 PRODS DRILL DRLG P Pulled mini wiper past 10700, 18:00 20:30 2.50 11,120 11,260 PROD3 DRILL DRLG P Continue drilling ahead 1.4 BPM @ 3900PSi FS, BHP=3837 20:30 21:36 1.10 11,260 9,530 PROD3 DRILL WPRT P Wiper trip to window with tie in PUW=33k 21:36 21:48 0.20 9,530 9,547 PROD3 DRILL DLOG P Log tie in,+1.5'correction 21:48 22:33 0.75 9,547 11,260 PROD3 DRILL WPRT P Continue wiper trip in hole 22:33 00:00 1.45 11,260 11,296 PROD3 DRILL DRLG P 11260', Drill Ahead,Turning up for last part of well for geo correlation. 1.39 BPM @ 3800 PSI FS, BHP=3791 RIW=5K WOB=2.5K, Revised TD=11410 11296 @ Midnight 02/02/2011 TD well @ 11406,Condition hole, P/U L2 Liner and trip in well 00:00 02:30 2.50 11,296 11,330 PROD3 DRILL DRLG P Drilling Ahead, 1.39 BPM @ 3800 PSI FS BHP=3858 02:30 04:18 1.80 11,330 11,380 PROD3 DRILL DRLG P Go to control drilling attempting to build angle 04:18 04:30 0.20 11,380 11,380 PROD3 DRILL WPRT P Mini Wiper, PUW=42K, 04:30 04:54 0.40 11,380 11,406 PROD3 DRILL DRLG P TD well at 11406',pump sweeps 04:54 09:18 4.40 11,406 0 PROD3 DRILL WPRT P Wiper to the swab,motor work and overpull at 9670',continued up to 9550', RBIH to 9780'at.3 BPM,wipe up to window at 1.4 BPM, <2K over pull and<100 PSI motor work. Continue wiper to swab. 09:18 11:36 2.30 0 9,280 PROD3 DRILL WPRT P RBIH 11:36 12:06 0.50 9,280 9,280 PROD3 DRILL WPRT T MWD failure,trouble shoot problem. No comms to BHA. Decide to not trip back thru window into open hole since unable to orient or function EDC. Did not lay beaded liner pill in open hole. 12:06 13:06 1.00 9,280 9,470 PROD3 DRILL DISP P Displace well to KWF 13:06 16:06 3.00 9,470 0 PROD3 DRILL TRIP P POOH 16:06 17:42 1.60 0 0 PROD3 DRILL PULD P Lay down drilling BHA. Wire and UQC tested good. 17:42 18:36 0.90 0 0 COMPZ CASING PULD P Prep for liner run, Hook up tongs,Re locate PDL 18:36 19:06 0.50 0 0 COMPZ CASING SFTY P PJSM to pick up liner.Fill hole, Investigate drip on top drive 19:06 19:54 0.80 0 652 COMPZ CASING PUTB P P/U Bull Nose,20 Jts slotted liner Page 12 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:54 21:00 1.10 652 652 COMPZ CASING PULD P P/U Anchored Billet&MWD. Hang off in hole 21:00 21:45 0.75 652 652 COMPZ CASING SVRG P Service Injector 21:45 22:30 0.75 652 724 COMPZ CASING PULD P Skid injector over tool string and Make up. Make up to well and surface test tool. Bump up and set counters 22:30 00:00 1.50 724 5,165 COMPZ CASING RUNL P trip in well,Midnight 5165' 02/03/2011 Run L2 Liner to 10405,TOL @ 10742, P/U L2-02 drilling BHA,drill past billet,drill ahead 00:00 01:15 1.25 5,165 9,237 COMPZ CASING RUNL P Continue in well with liner 01:15 01:30 0.25 9,237 9,276 COMPZ CASING DLOG P Log K Marker, +23'correction Shut EDC, PUW=31.5K 01:30 02:24 0.90 9,276 11,406 COMPZ CASING RUNL P Continue in well with liner. Smooth trip in hole to TD despite not having beaded pill in the hole. 02:24 02:30 0.10 11,406 10,100 COMPZ CASING RUNL P Tag bottom, PUW=40K, RBIH to 11405,Oriented anchor slip to 20L Setting tool shifted @ 3700PSI,Set down on anchor Looks good POOH PUW=35K BOL=11405,TOL=10742 02:30 06:00 3.50 10,100 0 COMPZ CASING TRIP P Stop and remove liner length from counters Continue trip out of well 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P PJSM for BHA swap,no flow check 06:30 07:18 0.80 0 0 COMPZ CASING PULD P Lay down liner BHA 07:18 08:12 0.90 0 0 PROD4 STK PULD P PU drilling BHA for L2-02 lateral 08:12 10:42 2.50 0 0 PROD4 STK TRIP P RIH 10:42 10:54 0.20 9,260 9,300 PROD4 STK DLOG P Tie in, +23', 10:54 12:18 1.40 9,470 9,470 PROD4 STK DISP P Circulate KWF from well 12:18 13:00 0.70 9,470 10,742 PROD4 STK TRIP P Close EDC,continue RIH 13:00 15:18 2.30 10,743 10,746 PROD4 STK KOST P Tag billet at 10742.9',sticking while trying to get started milling,mill at 1 FPH. 1.4 BPM,3950 CTP,3800 BHP, 14K RIW. Followed time drill schedule in procedure. 15:18 15:48 0.50 10,746 10,755 PROD4 STK KOST P Drilling formation 15:48 16:06 0.30 10,755 10,755 PROD4 STK REAM P Drift billet,clean,32K PUW, 12K RIW 16:06 18:06 2.00 10,755 10,890 PROD4 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3800 CTP,3820 BHP, 12K RIW 18:06 19:48 1.70 10,890 10,890 PROD4 DRILL WPRT P Wipe to window PUW=37K Slight overpull in shale @ 9635 coming up, No Motorwork Clean trip back in 19:48 21:42 1.90 10,890 11,040 PROD4 DRILL DRLG P 10890', Drill Ahead 1.41 BPM @ 3660 PSI FS, BHP=3820 RIW=11.5, WOB=1.4K Page 13 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:42 23:12 1.50 11,040 11,040 PROD4 DRILL WPRT P 11040'Wipe to 9790 below shaley area, PUW=34.5K 23:12 00:00 0.80 11,040 11,108 PROD4 DRILL DRLG P 11040', Drill Ahead 1.36 BPM @ 3600 PSI FS BHP=3850 Midnight= 11,108' 02/04/2011 Drilled ahead to 11,287.Called TD due to poor geological conditions. POOH @ 9261 had chain failure 00:00 01:48 1.80 11,108 11,190 PROD4 DRILL DRLG P Continue drilling ahead 11040', Drill Ahead 1.36 BPM @ 3600 PSI FS BHP=3850 01:48 03:00 1.20 11,190 9,524 PROD4 DRILL WPRT P Wiper trip to window with tie in 03:00 03:06 0.10 9,524 9,546 PROD4 DRILL DLOG P Log RA Marker for+1.5' 03:06 03:54 0.80 9,546 11,190 PROD4 DRILL WPRT P Continue wiper to bottom, RIW=13K Clean wiper trip to bottom 03:54 06:30 2.60 11,190 11,287 PROD4 DRILL DRLG P 1190', Drill ahead 1.37 BPM @ 3580 PSI FS BHP=3853 06:30 08:00 1.50 11,287 9,216 PROD4 DRILL WPRT P Having trouble getting WOB and motor work,slight over pulls, 34K PUW. Well is TD at 11287', continue wiper to the swab. 1500 lbs over pull at 9638' 08:00 10:00 2.00 9,216 9,216 PROD4 DRILL CIRC T Injector chain coming apart,set pipe slips,open EDC and CBU 10:00 11:30 1.50 9,216 9,216 PROD4 DRILL DISP T Displace well to KWF and flow check. 11:30 19:54 8.40 9,216 9,216 PROD4 DRILL RGRP T Repair injector. Closed and locked both upper and lower pipe slips while working on injector chains. Monitoring well at the managed pressure line 19:54 22:48 2.90 9,216 72 PROD4 DRILL TRIP T Repairs to chains complete, Pull test against pipe slips. Unlock pipe slips,open and move pipe out of hole. No visable damage to coil. Continue out of well at reduced speed watching pipe for damage 22:48 23:48 1.00 72 0 PROD4 DRILL PULD T PJSM at surface,monitor well for flow, Unstab injector Blow down and lay down BHA#14 23:48 00:00 0.20 0 0 PROD4 DRILL SFTY T PJSM 02/05/2011 Repair chains and POOH, R&R Chains and skates, RIH with clean out BHA 00:00 03:00 3.00 0 0 PROD4 DRILL CTOP T Cut coil connector off install grapple and unstab coil,Secure coil remove stuffing box 03:00 06:00 3.00 0 0 PROD4 DRILL RGRP T Prep injector for chain/Skate removal. Pull chains and skates Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 17:00 11.00 0 0 PROD4 DRILL RGRP T Crew change and PJSM,continue with injector repairs Suspend NAD dowtime to pump slack and re head 17:00 19:30 2.50 0 0 PROD4 DRILL CTOP T Pump slack mgmt,Cut 10'found wire,test wire Install CTC, Pull test 35K Function test BOPE 19:30 20:30 1.00 0 0 PROD4 DRILL CTOP T Head up Inteq upper quick connect, PT to 4K PSI 20:30 21:00 0.50 0 0 PROD4 DRILL CTOP T Inspect packoffs 1 Install counters 21:00 22:30 1.50 0 62 PROD4 DRILL PULD T PJSM, P/U clean out BHA 1.1 degree motor and Bi Center Bit, make up coil to coiltrack and surface test Resume NAD dowtime 22:30 00:00 1.50 62 5,507 PROD4 DRILL TRIP T Trip in well, EDC open Midnight 5507 02/06/2011 Cleanout run to 11234',condition hole for liner. Setliner at 11137',deployment sleeve at 9582'. Debris in injector chain damaged pipe while POOH from 9500'-8233' 00:00 00:48 0.80 5,507 9,274 PROD4 DRILL TRIP T Tripping in well, EDC open 00:48 01:00 0.20 9,274 9,290 PROD4 DRILL DLOG T Log tie in, +11',correction, PUW=32K 01:00 02:00 1.00 9,450 9,450 PROD4 DRILL CIRC T 9450'Circulate well back to Flo Pro mud 02:00 02:51 0.85 9,450 11,180 PROD4 DRILL TRIP P KWF out of well,Trap pressure,S/D Pump,close EDC. Trip in well. End NAD Downtime 02:51 03:00 0.15 11,180 11,234 PROD4 DRILL TRIP P 11180 hard setdown, PUW=33K, P/U and go down 11204 Set down, PUW=33K, P/U and go down 11234 Setdown,Sticky heavy overpull to get free. Not going deeper, last pay @ 11150.Sweeps coming out wipe to window 03:00 04:18 1.30 11,234 9,600 PROD4 DRILL WPRT P 9650 to 9630 numerous overpulls with motor work. Hole falling apart here. 04:18 04:30 0.20 9,523 9,540 PROD4 DRILL DLOG P Tie into RA 9523,-0.5'. RIH to lay in beads. Didn't see 9630 to 9650 area but are pumping at minimum rate in build. 04:30 05:30 1.00 9,540 11,170 PROD4 DRILL WPRT P RIH to 11170', 05:30 06:00 0.50 11,170 9,480 PROD4 DRILL DISP P Lay in liner running pill while POOH 06:00 06:30 0.50 9,480 9,480 PROD4 DRILL DISP P Displace to KWF 06:30 09:00 2.50 9,480 0 PROD4 DRILL TRIP P POOH,paint EOP flags 9500'and 7900' 09:00 09:18 0.30 0 0 PROD4 DRILL SFTY P PJSM,flow-check well 09:18 09:48 0.50 0 0 PROD4 DRILL PULD P Lay down drilling BHA Page 15 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:48 10:18 0.50 0 0 COMPZ CASING PUTB P Rig up for liner ops 10:18 10:36 0.30 0 0 COMPZ CASING SFTY P PJSM for liner running 10:36 12:42 2.10 0 0 COMPZ CASING PUTB P Pick up slotted liner 12:42 13:48 1.10 0 0 COMPZ CASING SVRG P Service injector 13:48 14:12 0.40 0 0 COMPZ CASING PUTB P MU injector to BHA 14:12 16:54 2.70 0 11,137 COMPZ CASING RUNL P RIH,correct depth at flag. 34K PUW,Clean run in hole. 16:54 17:24 0.50 11,137 8,233 COMPZ CASING TRIP P Release from liner, POOH,deduct liner length. Liner set from 9582'- 11,137'(intentionally left bottom of hole unlined). 17:24 20:18 2.90 8,233 9,500 COMPZ CASING SVRG T Discovered dimples in CT from junk in the chains. Found piece of metal on gripper block,inspect pipe, dimples from 8233'to 9500'. Inspected injector. 20:18 22:48 2.50 9,500 0 COMPZ CASING TRIP P Continue POOH 22:48 00:00 1.20 0 0 PROD5 STK PULD P Change out BHA 02/07/2011 Set Anchored billet @ 9582,TOB=9570. Drill by from 9570 to 9880 EOB 00:00 00:30 0.50 0 0 PROD5 STK PULD P Continue PU BHA#17,anchored billet 00:30 03:00 2.50 0 9,260 PROD5 STK TRIP P RIH with open EDC 03:00 03:12 0.20 9,260 9,300 PROD5 STK DLOG P Tie-in, +23' 03:12 03:30 0.30 9,300 9,582 PROD5 STK TRIP P Continue RIH 03:30 06:00 2.50 9,582 0 PROD5 STK WPST P Tag liner top,set anchored billet,Top of billet at 9570'. POOH 06:00 06:02 0.04 0 0 PROD5 STK SFTY P PJSM 06:02 07:20 1.30 0 0 PROD5 STK PULD P Lay down billet setting BHA, PU drilling BHA 07:20 08:20 1.00 0 0 PROD5 STK SVRG P Service injector 08:20 11:08 2.80 0 9,460 PROD5 STK TRIP P RIH,tie in 11:08 13:08 2.00 9,460 9,570 PRODS STK DISP P Displace well to flo-pro 13:08 17:08 4.00 9,570 9,600 PRODS STK KOST P Tag billet at 9570',start milling per procedure,drift past billet clean 17:08 19:44 2.60 9,600 9,720 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM,3650 CTP, 3680 BHP, 11K RIW 19:44 20:14 0.50 9,720 9,720 PROD5 DRILL WPRT P Wipe to Billet 9590 20:14 23:08 2.90 9,720 9,880 PRODS DRILL DRLG P 9720 Drill ahead 1.35 BPM @ 3420 PSI FS BHP=3730, RIW=12.5K 23:08 23:59 0.86 9,880 7,900 PRODS DRILL TRIP P 9880 End of Build Avg DLS=39.9 degrees PUW=41 K 02/08/2011 P/U BHA#19 with 0.8 AKO and continue drilling ahead on L2-01 lateral.Total of 32 bbls losses for 24 hours. 00:00 02:00 2.00 7,900 86 PRODS DRILL TRIP P Tripping out for planned AKO change 02:00 05:30 3.50 86 0 PRODS DRILL PULD P Undeploy BHA#18, Deploy BHA #19 for lateral Page 16 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05:30 07:42 2.20 0 9,260 PROD5 DRILL TRIP P RIH 07:42 07:54 0.20 9,260 9,300 PROD5 DRILL DLOG P Tie in,+21',close EDC 07:54 08:12 0.30 9,300 9,880 PROD5 DRILL TRIP P Continue RIH 08:12 10:06 1.90 9,880 10,030 PROD5 DRILL DRLG P Drilling, 1.4 BPM,3800 CTP,3766 BHP, 13K RIW 10:06 11:12 1.10 10,030 10,030 PROD5 DRILL WPRT P Wiper trip with Madd Pass 9860 to 9590, PUW=30K Clean trip in and out 11:12 12:48 1.60 10,030 10,180 PROD5 DRILL DRLG P 10030', Drill Ahead 1.40 BPM @ 3550PS1 FS BHP=3769 12:48 13:36 0.80 10,180 10,180 PROD5 DRILL WPRT P 10180,Wiper to 9700, PUW=31 K 13:36 15:36 2.00 10,180 10,330 PROD5 DRILL DRLG P 10180', Drill Ahead 1.40 BPM @ 3550PSI FS BHP=3824, RIW=9K 15:36 16:42 1.10 10,330 10,330 PROD5 DRILL WPRT P 10330,Wipe to window with tie in, PUW=32K No correction from tie in 16:42 19:12 2.50 10,330 10,480 PROD5 DRILL DRLG P 10330',Drill ahead 1.41 BPM @ 3800 PSI FS BHP=3800 19:12 20:12 1.00 10,480 10,480 PROD5 DRILL WPRT P Wiper trip to 9585'-P/U weight 33K 20:12 22:12 2.00 10,480 10,630 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,3980 psi, BHP 3835, ECD 12.4, ROP 110, WOB 1.7,Ct weight 11K.rate out 1.25 bpm. 22:12 23:30 1.30 10,630 10,630 PROD5 DRILL WPRT P Wiper trip-P/U weight 33K 23:30 00:00 0.50 10,630 10,655 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,3980, BHP 3851, ECD 12.5, ROP 90,WOB 1.7, CT weight 11K, Rate out 1.28 bpm. 02/09/2011 TD L2-01 Lateral @ 10866'. Lay in Liner pill&KWF. P/U liner string with.33 slotted&3 solid with long deployment sleeve. RIH&Set liner from 10,622'-9454'. 00:00 02:30 2.50 10,655 10,790 PROD5 DRILL DRLG P 1.40 bpm,3990, BHP 3850, ECD 12.45, ROP 80,WOB 1.6,CT weight 10K, rate out 1.30 bpm. 02:30 04:00 1.50 10,790 10,790 PROD5 DRILL WPRT P Wiper trip with tie in-P/U weight 33K.Zero correction. 04:00 06:12 2.20 10,790 10,886 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,3950, BHP 3870, ECD 12.5, ROP 60,WOB 2.1, CT weight 10K. Pump Low/High sweeps near TD. 06:12 10:00 3.80 10,886 110 PROD5 DRILL WPRT P Call TD, Pump Lo/Hi sweeps and chase to swab PUW=32K.Got some additional _ cuttings when sweeps got to surface 10:00 12:00 2.00 110 9,258 PRODS DRILL WPRT P Run back in hole. 12:00 12:06 0.10 9,258 9,304 PRODS DRILL DLOG P Log Tie in for-2'correction 12:06 13:36 1.50 9,304 10,886 PRODS DRILL WPRT P Continue in hole 13:36 17:06 3.50 10,886 72 PRODS DRILL WPRT P POOH Laying in beaded liner pill followed by KWF Paint EOP Flags @ 9300&8200 Page 17 of 18 v � Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:06 18:36 1.50 72 0 COMPZ CASING SFTY P Set up rig floor for liner running.Crew change and PJSM for P/U Liner. 18:36 21:06 2.50 0 1,211 COMPZ CASING PUTB P P/U liner-33 slotted&3 solid with deployment sleeve with 6'PBR 21:06 23:45 2.65 1,211 10,620 COMPZ CASING RUNL P RIH pumping through EDC @.3 bpm.Tie in=19.6ft @ 9600'. RIH to 10,620'. P/U weight 39K(-5K WOB). RIH to 10,620'Bring pumps on-line. P/U weight 31K.(WOB zero).TOL= 9452' 23:45 00:00 0.25 9,452 9,260 COMPZ CASING DLOG P POOH to Tie in @ 9260'prior to recovering KWF.correction+2 ft. Liner depth=BOL 10,622'-TOL 9454' 02/10/2011 Freeze protect well, Pump corrosion inhibitor, N2 reel blowdown, Unstab and secure coil for reel swap, RDMO, Rig Release 18:00 00:00 01:00 1.00 9,420 9,420 COMPZ CASING CIRC P Begin pumping sweep&SW to recover KWF. Losses=6 bbls of KWF. 01:00 04:30 3.50 9,420 55 COMPZ CASING TRIP P Start POOH pumping SW.Hold PJSM for pumping diesel. Pump 30 bbls to freeze protect well from 2500' to surface. 04:30 06:30 2.00 55 0 COMPZ CASING PULD P CT @ surface-undeploy BHA Blow down lay down 06:30 09:30 3.00 0 0 DEMOB WHDBO PULL P Rig up BPV Lubricator,Set BPV, R/d 09:30 10:45 1.25 0 0 DEMOB WHDBO SFTY P PJSM,Mix and circulate corrosion inhibitor 10:45 11:30 0.75 0 0 DEMOB WHDBO CTOP T PJSM,CT Reel N2 Blowdown, Bleed down 11:30 12:00 0.50 0 0 DEMOB WHDBO CTOP T Unstab Injector, Remove counters 12:00 14:30 2.50 0 0 DEMOB WHDBO CTOP T PJSM,Remove UQC and coil connector Rig up and unstab coil 14:30 15:30 1.00 0 0 DEMOB WHDBO CTOP T Remove inner reel iron and secure coil on reel 15:30 18:00 2.50 0 DEMOB WHDBO NUND P Nipple down stack,M/U to bridge crane, R/D cellar lines, Hard line, Install tree cap Rig Release @ 18:00 Page 18 of 18 Transmittal Letter IIIBAKER Date: HUGHES March 7, 2011 To: From: State of Alaska, AOGCC Okey Anyanwu Christine Mahnken 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): • 2X-18L1 2X-18L1-01 2X-18L2 2X-18L2-01 2X-18L2-02 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files RECEIV -, 10 ' omatNior Afic, , 1 Ofro-r? 5 .tt -- OI6 Arflt\_, s SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMlMIISSION ANCHORAGE,ALASKA 99501-3539 ® PHONE (907)279-1433 6/ 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, 2X-18L2-02 ConocoPhillips Alaska, Inc. Permit No: 211-015 Surface Location: 675' FSL, 241' FEL, SEC. 04, T11N, R9E, UM Bottomhole Location: 1218' FSL, 2554' FEL, SEC. 10, T11N, 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 2X-18, Permit No 195- 160, API 50-029-22608-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 111. Daniel T. Seamount, Jr. Chair DATED this 1 day of February, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECE \; .. r FEB 03 February 2, 2011 114a MI G&Coos.C .. Awn Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission "�nt'nat� � 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill applications for an unplanned coiled tubing drilling (CTD) laterals out of Kuparuk well 2X-18 (PTD# 195-160) using the Nabors CDR2-AC coiled tubing drilling rig. The additional lateral, 2X-18L2-02, is needed to capture pay that was missed due to geologic complexity. Verbal authorization to continue with drilling operations without interruption was granted by the Commission on February 2, 2011 as per 20 AAC 25.015(b)(2). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Form for 2X-18L2-02 — Current/Proposed Wellbore Schematic — BOP Schematic (unchanged from previous) — Detailed Summary of Operations — Directional Plans If you have any questions or require additional information please contact me at my office 907-263-4172. incerely, Gary Eller ConocoP Alaska Coiled Tubing Drilling Engineer , E'io,.C']..jai l.-.2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION :LE 0 3 all PERMIT TO DRILL 20 AAC 25.005 ,M•!... ..4.? Rg 1. ?'"> Cons.Cr 3sion la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ 'Service-Winj ❑ Single Zone ❑✓ lc.Specify if well iif tprppl4t 0-: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2X-18L2-02 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11410' TVD: 5904' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:675'FSL,241'FEL,Sec.4,T11 N,R9E, UM ADL 25645 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 788'FSL,2066'FEL,Sec. 10,T11 N,R9E,UM 2576 2/2/2011 Total Depth: 9.Acres in Property: 14.Distance to 1218'FSL,2554'FEL,Sec. 10,T11 N,R9E, UM 2560 Nearest Property: 29300 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 118 feet 15.Distance to Nearest Well Open Surface:x- 518889 y- 5970679 Zone- 4 GL Elevation above MSL: 77 feet to Same Pool: 2X-16,1200 16.Deviated wells: Kickoff depth: 10743 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 100° deg Downhole:2718 psig Surface:2155 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) its.- 2 3•// _ _ _ 3" 2.375" 4.7# L-80 ST-L 1460' 142,' i 6225' .///ilia 5904' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9943' 6234' 9841' 6150' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 300 sx AS 1 121' 121' Surface 5090' 7.625" 750 sx ASIII,470 sx Class G 5130' 3398' Intermediate Production 9890' 5.5 165 sx Class G 9930' 6223' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 9374'-9420',9618'-9638',9666-9684' 5783'-5824',5971'-5986',6009'-6023' 20.Attachments: Property Plat❑ BOP Sketch E Drilling Program Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑., 21.Verbal Approval: Commission Representative: Date: February 2,2011 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 Printed Na e V. \.. Caw ey Title Alaska Wells Manager Signature , Phon 265-6306Date 2124\t Commission Use Only Permit to Drill AP ber: Permit Appprro a See cover letter Number: p2/,'®/� 50-17a(9,2a6,0 76 L�� Date: /�/ 14 1 1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coal edm thane,gas hydrates,or gas contained in shales: ❑ 4 3S06s OOP /c,f" Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No ZOther: P ^Nn (t H2S measures: Yes M No ❑ Directional svy req'd: Yes V No ❑ Zs—Lb ,DS /'F J APPROVED BY THE COMMISSION / DATE: .0/ ll i ,COMMISSIONER Form 0 401 (R `ised 7/2009) This permit is valid f• o t h t oval(20 AAC 25.005(g)) mit in Duplicate 74, z'3. i1,/-0,- //i KRU 2X-18L1, L1-01, L2, L2-01, & L2-02 — Coiled Tubing Drilling Summary of Operations: Well 2X-18 is a commingled Kuparuk A-sand and C-sand production well equipped with 3'/2"tubing and 5'/2" production casing. Five A-sand CTD laterals will increase reservoir exposure and offset the planned 2Z-23 CTD injection laterals. Well 2X-18 will be worked over to upsize it to 31/2" tubing and to install an isolation straddle assembly over the C-sand perfs. All existing perfs in the 2X-18 well will remain viable following drilling of these laterals, although it is only planned to continue to produce from the A-sand perfs. The 2X-18L1 lateral will exit through the 51/2"casing at 9560' MD. It will target the A3/4 sand east of the existing well with a 1690' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,250' MD with an aluminum billet at 9750' MD. The 2X-18L1-01 lateral will kick off from the aluminum billet at 9750' MD and will target the A4 sand east of the existing well with a 700' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,450' MD with the final liner top located just inside the 5'/2"casing at 9550' MD. The 2X-18L2 lateral will make a second window exit through the 51/2" casing at 9505' MD. It will target the A4 sand west of the existing well with an 1815' lateral. The hole will be completed with a 23/x" slotted liner to the TD of 11,320' MD with an aluminum billet at 10,743' MD. The 2X-18L2-02 lateral will kick off from the aluminum billet at 10,743' MD and will target the A4 sand west of the existing well with a 667' lateral. The hole will be completed with a 2%" slotted liner to the TD of J� 11,410' MD with an aluminum billet at 9950' MD. The 2X-I8L2-01 lateral will kick off from the aluminum billet at 9950' MD and will target the A3 sand west of the existing well with a 1320' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,270' MD with the final liner top located just inside the 3'/2"tubing at 9430' MD. CTD Drill and Complete 2X-18 Laterals: January 2011 Post-Workover, Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. Load tbg&IA. MIT-IA. MIT-OA. Test packoffs—T & IC. 3. RU slickline. Obtain updated static BHP on A-sand. Run whipstock dummy. RD slickline. 4. 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. 2X-18L1 Lateral (A3/4 sand, east) a. Set a mechanical whipstock at 9560' b. Mill a 2.80"window in the 51/2"casing at 9560' c. Drill 2.70" x 3"bi-center lateral to TD of 11,250' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 9750' 3. 2X-18L1-01 Lateral (A4 sand, east) a. Kick off of the aluminum billet at 9750' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,450 MD c. Run 2%" slotted liner from TD up inside the 5'/2"casing at 9550' Page 2 of 5 O R I G I N A L February 2, 2011, UPDATE KRU 2X-18L1, L1-01, L2, L2-01, & L2-02 — Coiled Tubing Drilling 4. 2X-18L2 Lateral (A4 sand,west) a. Set a mechanical whipstock at 9505' b. Mill a 2.80"2-string window at 9505' c. Drill 2.70"x 3"bi-center lateral to TD of 11,320' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 10,743' 5. 2X-18L2-02 Lateral (A4 sand, west) a. Kick off of the aluminum billet at 10,743' MD f '' b. Drill 2.70" x 3" bi-center lateral to TD of 11,410' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 9950' 6. 2X-18L2-01 Lateral (A3 sand,west) a. Kick off of the aluminum billet at 9950' MD b. Drill 2.70" x 3"bi-center lateral to TD of 11,270' MD c. Run 2%" slotted liner from TD up to 9430' MD, up inside the 3'/2"tubing 7. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.7 ppg)for milling operations, and chloride- based Flo-Pro mud(8.7 ppg) for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%" slotted liner in the four laterals. Disposal: • 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. Casing Program: • 2X-18L1: 2%", 4.7#, L-80, ST-L slotted/solid liner from 9750' MD to 11,250' MD • 2X-18L1-01: 2%", 4.7#, L-80, ST-L slotted/solid liner from 9550' MD to 10,450' MD • 2X-18L2: 2%",4.7#, L-80, ST-L slotted/solid liner from 10,743' MD to 11,320' MD • 2X-18L2-02: 2%",4.7#, L-80, ST-L slotted/solid liner from 9950' MD to 11,410' MD • 2X-18L2-01: 2%", 4.7#,L-80, ST-L slotted/solid liner from 9430' MD to 11,270' MD Existing Casing/Liner Information Surface: 7%", L-80, 29.7 ppf Burst 6890 psi Collapse 4790 psi Production: 5'/2", L-80, 15.5 ppf Burst 7000 psi Collapse 4990 psi Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 2X-18 was taken November 2010. The commingled A/C-sand reservoir pressure was measured at 2330 psi at 9669' MD, 5942' SSTVD, corresponding to 7.6 ppg EMW. We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Page 3 of 5 ORIGINAL February 2, 2011, UPDATE • KRU 2X-18L1, L1-01, L2, L2-01, & L2-02 — Coiled Tubing Drilling Well Control: • Two well bore volumes (-210 bbl)of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. ✓ • Pipe rams,blind rams and the CT pack off will be pressure tested to 250 psi and to 3000 psi. Maximum potential surface pressure in 2X-18 is 2155 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 2718 psi at 5850' SSTVD taken in well 2Z-23 in August 2009, corresponding to 9.0 ppg formation pressure. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 2X-18L1,plan#4 2. 2X-18L1-01,plan #1 3. 2X-18L2,plan #2 4. 2X-18L2-02, plan #2 5. 2X-18L2-01,plan#1 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2X-18 eastern CTD laterals(L1 &L1-01): —28,900' to property line, 1100' to well 2Z-23 • 2X-18 western CTD laterals (L2,L2-01, & L2-02):—29,300' to property line, 1200' to well 2X-16 Hazards • Shale stability is the most significant problem expected due to somewhat low reservoir pressure and the significant number of fault crossings expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has been no MI gas injection in the vicinity of 2X-18, so it is unlikely that an influx will yield significant quantities of gas. • Well 2X-18 has 10 ppm measured H2S as of January 2010. Well 2X-17 is located 15' to the right side and 2X-01 is 165' to the left side of the 2X-18 surface location. Well 2X-01 has no measured H25 since it is an injector,and 2X-17 has 25 ppm H2S as of Jan-10. The maximum H25 level on the pad is 175 ppm— from well 2X-12A(1/13/10). All H2S monitoring equipment will be operational. Page 4 of 5 ORIGINAL February 2, 2011, UPDATE KRU 2X-18L1, L1-01, L2, L2-01, & L2-02 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD) techniques will be employed to provide constant bottom hole pressure by using 8.7 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the ROPE 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 23/4"BHA will be accomplished utilizing the 23/8"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. The well 2X-18 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2315 psi at 9560' MD(5857' SSTVD), or 7.6 ppg EMW. • Expected annular friction losses while circulating: 956 psi (assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 8.7 ppg equates to 2650 psi hydrostatic bottom hole pressure at 5857' SSTVD. Mud hydrostatic pressure alone is expected to be sufficient to overbalance formation pressure. • While circulating 8.7 ppg mud,bottom hole circulating pressure is estimated to be 3606 psi or 11.8 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2X-18. 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. • When circulation is stopped,—960 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Page 5 of 5 ORIGINAL February 2, 2011, UPDATE ( . . } ~ & \ co 2 ] \ / E - ¥ \ / \ co ci co Co N E/ \ ¢ \ ƒ a k \ \ � � � . \ \_ \ , & * J 5 - E & ƒ\ \ / \] E / » a - t /a _ % eE 2 \ EE — % { ED 5 ® 2 \ $ / Q3 / a\ � a\ .71- } ) § » ^ \ £$ § \ F \ / / \ © \ @G ©E § 7 % - - j 0 k a 2 5 m e 7 \ j ] 0 /? \ } a ] / ® \ \ » Y , / } E > E E ( E E / m / \ / a / e ` } / / \ ƒ \ OJ N & / & } } § � . \ r \ \ \ \ \ \ 52 \ \ § � co Ph 00_ $ /\ ƒ >� § , \ / \ ga & A = \\ < ° + 2 2 } l \ 1 il II T @ . a - _, , \\ �\\ n ° _ WI 1 -, . � @ e E » CL / > 7 . / 'Itt co a § . .� kj 0 1 / j j \ \ / \ $ Itm 2 ~ b E§ 33 $ §o ��� �It ) � \ \ / \ j j \ \ \ \ § \ \ U) It \ \ $ 6 ' § / .o \ \ / e CI 11 / , = k § < H » � k I- \ \ } \ \ \ \ � - 1 1127- / \ GG e � / I— .11- \� \ § ®Qa � � � `,-2 @.) ° o e � 2Oa- \ � r (N ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing l Lubricator lti'l .':.1 Riser r Annular Blind Blind/Shear 2" Pipe/Slip (CT) Pump into Lubricator \4/\/I L above BHA rams ►/`/\ >< i Choke 1 2-3/8" Pipe/Slip (BHA) , Choke Equalize Manifold 2-3/8" Pipe/Slip (BHA) i L Kill ►>i<>< ><I>< L ► — 1 r Blind/Shear 2" Pipe/Slip (CT) Choke 2 i Swab Valves I Wing Valves 0®4 S Tree Flow Cross gi Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi 0 Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union ORIGINAL ConocoPhilli s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2X Pad 2X-18 2X-18L2-02 Plan: 2X-18L2-02_wp02 Standard Planning Report 02 February, 2011 BAKER HUGHES ORIGINAL v--` ConocoPhillips (/r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2X-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2X-18 @ 118.00ft(Parker 245) Site: Kuparuk 2X Pad North Reference: True Well: 2X-18 Survey Calculation Method: Minimum Curvature Wellbore: 2X-18L2-02 Design: 2X-18L2-02_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2X Pad Site Position: Northing: 5,970,513.01 ft Latitude: 70°19'50.180 N From: Map Easting: 518,889.00ft Longitude: 149°50'48.451 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14° Well 2X-18 Well Position +N/-S 0.00 ft Northing: 5,970,678.63 ft Latitude: 70° 19'51.809 N +EI-W 0.00 ft Easting: 518,888.80 ft Longitude: 149°50'48.445 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 77.00ft Wellbore 2X-18L2-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2010 1/17/2011 16.83 79.84 57,347 Design 2X-18L2-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,731.15 Vertical Section: Depth From(ND) +N/-S +EJ-W Direction (ft) (ft) (ft) (0) -77.00 0.00 0.00 303.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 10,731.15 88.62 304.76 5,925.75 -5,172.43 3,475.28 0.00 0.00 0.00 0.00 10,743.00 88.24 306.32 5,926.07 -5,165.55 3,465.64 13.54 -3.21 13.16 103.72 10,823.00 100.24 306.32 5,920.17 -5,118.38 3,401.48 15.00 15.00 0.00 0.00 10,883.00 98.25 315.21 5,910.51 -5,079.74 3,356.69 15.00 -3.31 14.82 102.00 10,963.00 89.71 306.76 5,904.95 -5,027.52 3,296.54 15.00 -10.68 -10.57 225.00 11,063.00 89.72 291.76 5,905.44 -4,978.78 3,209.54 15.00 0.01 -15.00 270.00 11,213.00 95.42 313.56 5,898.63 -4,898.49 3,084.17 15.00 3.80 14.53 75.00 11,410.00 81.47 339.68 5,904.05 -4,735.96 2,976.89 15.00 -7.08 13.26 118.00 212/2011 1:49:52PM Page 2 COMPASS 2003.16 Build 6V ORIGiNAL .1,-' ConocoPhillips ted, ConocoPhilhhps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2X-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2X-18 @ 118.00ft(Parker 245) Site: Kuparuk 2X Pad North Reference: True Well: 2X-18 Survey Calculation Method: Minimum Curvature Wellbore: 2X-18L2-02 Design: 2X-18L2-02_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (o) (1 (ft) (ft) (ft) (ft) (1100ft) (°) (ft) (ft) 10,731.15 88.62 304.76 5,925.75 -5,172.43 3,475.28 -5,731.73 0.00 0.00 5,965,515.48 522,376.75 TIP 10,743.00 88.24 306.32 5,926.07 -5,165.55 3,465.64 -5,719.89 13.54 103.72 5,965,522.34 522,367.09 KOP 10,800.00 96.79 306.32 5,923.57 -5,131.85 3,419.80 -5,663.10 15.00 0.00 5,965,555.92 522,321.17 10,823.00 100.24 306.32 5,920.17 -5,118.38 3,401.48 -5,640.39 15.00 0.00 5,965,569.34 522,302.82 3 10,883.00 98.25 315.21 5,910.51 -5,079.74 3,356.69 -5,581.78 15.00 102.00 5,965,607.86 522,257.93 4 10,900.00 96.45 313.40 5,908.33 -5,067.97 3,344.62 -5,565.25 15.00 -135.00 5,965,619.60 522,245.84 10,963.00 89.71 306.76 5,904.95 -5,027.52 3,296.54 -5,502.89 15.00 -135.23 5,965,659.93 522,197.65 5 11,000.00 89.71 301.21 5,905.13 -5,006.84 3,265.87 -5,465.91 15.00 -90.00 5,965,680.52 522,166.94 11,063.00 89.72 291.76 5,905.44 -4,978.78 3,209.54 -5,403.39 15.00 -89.97 5,965,708.44 522,110.55 6 11,100.00 91.16 297.12 5,905.16 -4,963.48 3,175.87 -5,366.82 15.00 75.00 5,965,723.66 522,076.84 11,200.00 94.95 311.66 5,899.81 -4,907.26 3,093.69 -5,267.27 15.00 75.04 5,965,779.67 521,994.53 11,213.00 95.42 313.56 5,898.63 -4,898.49 3,084.17 -5,254.51 15.00 75.82 5,965,788.40 521,984.981 7 11,300.00 89.23 325.06 5,895.09 -4,832.71 3,027.63 -5,171.27 15.00 118.00 5,965,854.04 521,928.28 11,400.00 82.16 338.34 5,902.62 -4,745.20 2,980.43 -5,084.02 15.00 118.47 5,965,941.42 521,880.88 11,410.00 81.47 339.68 5,904.05 -4,735.96 2,976.89 -5,076.02 15.00 117.47 5,965,950.66 521,877.31 TD 2/2/2011 1:49:52PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2X-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2X-18 @ 118.00ft(Parker 245) Site: Kuparuk 2X Pad North Reference: True Well: 2X-18 Survey Calculation Method: Minimum Curvature Wellbore: 2X-18L2-02 Design: 2X-18L2-02_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2X-18L2-02 t3 0.00 0.00 5,926.00 -5,161.48 3,459.86 5,965,526.39 522,361.30 70° 19'1.038 N 149°49'7.496 W -plan hits target center -Circle(radius 30.00) 2X-18L2,L2-01 Polyg 0.00 0.00 0.00 -4,730.66 3,002.60 5,965,956.02 521,903.00 70°19'5.277 N 149°49'20.833 W -plan misses target center by 5896.03ft at 11300.00ft MD(5895.09 TVD,-4832.71 N,3027.63 E) -Polygon Point 1 0.00 -4,730.66 3,002.60 5,965,956.02 521,903.00 Point 2 0.00 -5,113.14 3,587.72 5,965,575.05 522,489.02 Point 3 0.00 -5,507.69 4,196.81 5,965,182.07 523,099.04 Point4 0.00 -5,261.85 4,273.42 5,965,428.08 523,175.03 Point 5 0.00 -5,385.50 4,532.14 5,965,305.09 523,434.03 Point 6 0.00 -5,667.35 4,460.44 5,965,023.09 523,363.05 Point 7 0.00 -5,730.78 4,226.26 5,964,959.08 523,129.05 Point 8 0.00 -5,589.64 3,768.56 5,965,099.05 522,671.04 Point 9 0.00 -5,189.21 3,206.49 5,965,498.03 522,108.02 Point 10 0.00 -4,965.38 2,878.01 5,965,721.01 521,779.01 Point 11 0.00 -4,730.66 3,002.60 5,965,956.02 521,903.00 2X-18L2-02 t5 0.00 0.00 5,906.00 -4,988.50 3,204.70 5,965,698.71 522,105.73 70°19'2.741 N 149°49'14.939 W -plan misses target center by 10.85ft at 11063.38ft MD(5905.45 TVD,-4978.64 N,3209.19 E) -Circle(radius 30.00) 2X-18L2-02 t4 0.00 0.00 5,912.00 -5,077.69 3,356.88 5,965,609.92 522,258.12 70°19'1.863 N 149°49'10.500 W -plan misses target center by 2.30ft at 10884.10ft MD(5910.35 TVD,-5078.97 N,3355.92 E) -Circle(radius 30.00) 2X-18L2-02 t6 0.00 0.00 5,899.00 -4,947.25 3,052.99 5,965,739.57 521,953.93 70°19'3.147 N 149°49'19.365 W -plan misses target center by 56.96ft at 11202.95ft MD(5899.55 TVD,-4905.30 N,3091.51 E) -Circle(radius 30.00) 2X-18L2-02 t2 0.00 0.00 5,905.00 -4,973.35 3,167.71 5,965,713.77 522,068.70 70°19'2.890 N 149°49'16.018 W -plan misses target center by 12.61ft at 11101.18ft MD(5905.14 TVD,-4962.94 N,3174.83 E) -Circle(radius 30.00) 2X-18L2-02 t1 0.00 0.00 5,908.00 -5,067.91 3,343.08 5,965,619.66 522,244.30 70°19'1.959 N 149°49'10.902 W -plan misses target center by 1.03ft at 10901.23ft MD(5908.19 TVD,-5067.13 N,3343.73 E) -Circle(radius 30.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (•') 5,130.00 3,319.04 7 5/8" 7-5/8 9-7/8 11,410.00 5,904.05 2 3/8" 2-3/8 3 2/2/2011 1:49:52PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL Np•, ConocoPhillips 111"C' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2X-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2X-18 @ 118.00ft(Parker 245) Site: Kuparuk 2X Pad North Reference: True Well: 2X-18 Survey Calculation Method: Minimum Curvature Wellbore: 2X-18L2-02 Design: 2X-18L2-02_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 10,731.15 5,925.75 -5,172.43 3,475.28 TIP 10,743.00 5,926.07 -5,165.55 3,465.64 KOP 10,823.00 5,920.17 -5,118.38 3,401.48 3 10,883.00 5,910.51 -5,079.74 3,356.69 4 10,963.00 5,904.95 -5,027.52 3,296.54 5 11,063.00 5,905.44 -4,978.78 3,209.54 6 11,213.00 5,898.63 -4,898.49 3,084.17 7 11,410.00 5,904.05 -4,735.96 2,976.89 TD 2/2/2011 1:49:52PM Page 5 COMPASS 2003.16 Build 69 TTp II O I Iii �D LIIIwe 8 T T J T T J �� I r IJ JC4 IR T J co N K T f 0 r , _ 5 FPS+ N T J t J 3 o - J r N oz o = T �_ - 8 a N 1 sfl 4 - —2,_ - E 1 '1 _... m ___. ...1.-_ ____ .—.-• . _ N I 33§H3 1 El Is I t - t --.. at Q 18 y M c Al T I iI 8'o U 1 I oc 8 . , N _ M N J ... N M cd 18 Xo •'i -t r, 0 N J al U J a $ �, I 8-ii.� N N N NP- m M m - ,N Lu m 1 a 2 G a N , 8= 'VF-- e,1 z0 0 a p SJ 0 I I W Cb I-,-0M I 3 D.,-....1•3 .1 X8 1 eOp Ic c 8 _tk _ \wp JJOtiB®5880 O MOojruN � `, JX HOOh . +N N i NF, YyN . ..coA 08g888888 3 3 N 8O M Vi 6 Hi.�i Lei.e'i ' ..._ vii az4 I e 3n°oI ^' o °' co wC'.uuz$er'.2."pfpppSOQ-p2 . 8 ,- .8 8 - yam. . .,- . 8 .8 p§ . 8 a''• C 3''' rJO, r M .VMMM6�,f N N N N , ..T,, , ,D .JG, '2 '.G 'G J h or, W X o D m �p N Q .. N'Q Mti..1P2.V* I- F- Z N m m (at/#j 0£) todaQ tea!uaA mi, a w +:n,n:n iiF W q 3 (7 m�o :n$4.x,8 w2R8tR6 7, ' g v) c r� MMMM.'+N MM C24FZ CCNO N N N h~.N—�!R ..._ <t 888A M9;; N i fr/E 38 o�8iii 6 �8p8•888 • V C N N e ?o toy r N CO Yl.us l0 r-OG kJ ORIGINAL 01 W i iI I I 1 8 ! , 1gjib ' , o V 8 C • 1 s CZ m 1 Is e • I I g v e . w awd e I oI 'fie `ll a -a 3?5Ai i 1 I _o m13 Q o�� I I ;8 1 ,,, r.y o , v 7 cii N r. O a, ,_ ; I 1 ' y 1I s r s° a S y 1 z I ! r _g I j sII N 1ccz,4 . y `ma xY •cG 04 , I I I I N o o X i j cs, I I S (11)/$00Z) (+)quorsu(-)Yllnos a 8 U o �y 03W @J 03 t° ORIGINAL a) u. N - O) V O U a5 CV N E N co N CO O CO co CsJ —C QOj V COV in awll N N p 8 p L- a0 .a) V1 co C _ (y = c\j a ) g ^ N a) N -0 CI -o c p rn V c 0 o 1 _ co f6 o Q C O) 0 J ‘a) U I J gU) D) la r13 2 c0 io �. V = = o - N 'E >,o 0 X0 ? XpM ~' N ON O CsJ O _0 � 2 NIHI Ni- N O O O ©5 = O co lii V n W O-N co N a) N W co p Y a X YQ fa U �l � (U Fp- OU J OU (D OU U 0 (0 0) `' (`7E E -0 co c a1 (h a) Q a) m C Q z U rn U o . LL U U Q u_ co - N N N N NTo — N N _. Y N M M M KS (n A A A m m M n 0 II co(o p I O N U V In 1 r U // 0 co ' O) (O O O. O ��W gx n- % a °° rn a � 3 `° � � I O M — i II Q rn co ilijk pi i 1._— CD ---1)117 1 —7:111111-7 r RS n lrl✓ cru . C In IT! F- 1 `o •C 3 III tr RSQ a) \ofr fi p CL zci- ( m coco N 1.4 O CO -NCV rn o J m � 0 aa)) Q x W Q 2 Q c° a ' u-) tr RS * e a act a`) 2 max` Lo CD O d7 �u71 O N O 3 a) b \ 0 _ co i-si co = N N V u) m Yc7 — ulN \ C N N to O U 3 .- _Q \\ CO a IA g 0 O p m d E- as Q U 2 v- N cr9CO 1 -JI N e- io ' r co O 3 p O O q P °° 0m J o • p c app NF- J r N 0 jj _ Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 02, 2011 11:43 AM To: 'Eller, J Gary' p7 2 /1 - 0/ 5 Subject: RE: PTD for Unplanned 2X-18L2-02 Lateral +� Gary, �► re-f' — e4.,.eL. 2 —z-+( You have verbal approval to proceed with the additional lateral (2X-18L2-02) as stated below. Please submit the 401 PTD as soon as possible. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, 3 Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, February 02, 2011 8:49 AM To: Schwartz, Guy L(DOA) Cc: Gantt, Lamar L Subject: PTD for Unplanned 2X-18L2-02 Lateral Guy-Good morning! As per our phone conversation, we need to drill an additional CTD lateral from well KRU 2X-18. This new lateral will be called 2X-18L2-02, and it is needed to capture pay that we bypassed due to geologic complexity. I have attached an updated wellbore schematic which shows the laterals that we have completed (yellow)and the laterals that we have not yet completed (blue). As you can see, we TD'd the L2 lateral (210-177) last night at 11,406' MD. We plan to run liner today. The proposed L2-02 lateral will kick off of the L2 lateral at 10,750' and TD at 11,200'. We will then finish 2X-18 with the L2-01 lateral (210-178). The 2X-18 laterals are all producers so there is no quarter-mile review needed, and in map-view the new lateral will almost directly overlie the laterals that have already been permitted. My intent is to provide you with a written 10-401 for the 2X-18L2-02 lateral sometime this afternoon. However, given that we will be ready to resume drilling by tomorrow, I request oral authorization from the Commission to proceed with drilling operations without interruption as per 20 AAC 25.015(b)(2). Please let me know if you have any questions. I hope you get feeling better quickly, and it was good talking to you. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 2/2/2011 Alaska Department of Natural " sources Land Administration System Page 1 of 1 7rtNIAlaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ! find'l Alaska DNR Case Summary File Type: ADL File Number: 25645 d Printable Case File Summary See Township,Range,Section and Acreage? @ Yes 0 No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 25645 Search for Status Plat Updates As of 02/03/2011 Customer: 000106346 CONOCOPHILLIPS ALASKA,INC. ATTENTION:LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 01/28/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date:01/14/2011 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 01IN Range: 009E Section: 03 Section Acres:640 Search Plats Meridian: U Township: 01I N Range: 009E Section: 04 Section Acres:640 Meridian: U Township: 011N Range: 009E Section: 09 Section Acres:640 Meridian: U Township: O11N Range: 009E Section: 10 Section Acres:640 Legal Description 11-02-1964 ***SALE NOTICE LEGAL DESCRIPTION*** U-3-6-20 ALL SEC. 3, T.I IN,R9E,UM 640 ALL SEC.4, " 640 ALL SEC.9, """640 ALL SEC. 10, """640 CONTAINING 2560 ACRES,MORE OR LESS. End of Case Summary Last updated on 02/03/2011. Not sure who to contact?Have a question about DNR?Visit the Public Information Center. Report technical problems with this page to the Webmaster. Site optimized for Netscape 7,IE 6 or above. This site also requires that all COOKIES must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=25645... 2/3/2011 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 ,'et/ / O ? PTD# 21,101 Y Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: l/s',ae.i.l'z/d' z- POOL: ,t4//eg,A4/ .e/1�iZ OIL 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 I� , (If last two digits in permit No. /9S/60 ,API No. 50-Ooh-,&:26.0/00 o0. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 12 0 13 O r- (0 o -0 31 D m 7 3G) ' co (A r 3 o '" .- -u N N 7 N) @ O m O O N tt) N a) CO N ) 0) 7 O g 7 n co FD, 1 O CD Oo N o O C) w w CO w CO I W CO w CO CO N N N N N N N N N N -, -, -, -, -‘..-‘ -, -, CO CO V 0) CT A w N — 3 (O 00 V O CT A w N — O O 0) V O U) A w N — O CO CU O (P A w N -, O J .0 m O cn cn o m ;K �, g oW W o -, D �, D o 000 cn o -oD * o - voo -* cn * * * cr b z ,z n O 0 v C. d 0 0 -o 0 0 O O0 = a CD °' m _ , 3 0 * 0 = 0 0 m m CD 0 0 0 E 0 CD 7 0 r m , v 3 3 7. 0 it ; m m 5 o .o m a N a o 0 3 3 < 0 c 0 3 0 th co a co 0 CD (o c c (0 g < < 0 0 o o o 0 0 o O 7• a co-' 0 3 - �n (D o) a v a = 'o o '0 0 a rn 3 o o m ? v v v F c 'CD '< Z - 3 7 :N j �Q SU S 00 �0 O �- CD . `,- Nrip �o �a �a, N 4, 1 co 3 a 7.: Q �Q �N 7 a n �a a �a Q �d �• O TI O O. `(-1,- a CD 0 Oa O �d N 14 c (D y x '7 <D C C 2, d s. * 4D '0 'CD 0) '< N 'CD .C' 'C7 _ 0 0 Ft r 42 ,0 jr-13- 73 D 70 rn o N 2 ° . +< � '3 o m cfl v v D) N -o m 1 D vi y V f m v 3 s 0 _ °- .E.,- o oo c : w I__ o (0. 3 d .a m' 0 n o a am. A 5--. -o c c o 0 Q c0 0 a -0 0 O r m c N a J ro 3 v 3 n m O o 7 S S m o 0 3 v o a a v o a q '� o ° ? o o m w m d o o �, 0 0 ;a c O 0 - a 0' w S n 0 0 o m o (n b n O w O N N ;CDS• co O. � CD N a •:�• 0• 'O 'O CO '(n 0 7 !n S o g v 0 b m o . ;� '<' co v co a v a) Q iv Q 'n c °1 y D 3 0 g of 7 m o o c 3 o v y m 7 0 0 o Q D 0 0 0 3 0 r c 0 o CO v, v v v : ! 3 0 o o 7• v '0 o c• c o g cD 0 o 0 o D m 0 m y o F v ' m o o o o n a 0 70 m a 0 a 7 ^ D )77 o v, 0 g v n o c 0. o 'o N > > v 7• N - 0 7 7 m Qo o 7 -{ 7 7 o iD 3 'o '7• a = '3 3 w C `° o c 0 - ! 9 3 CD 0 '00- o co m ,� o C a a 5 m o a o o. Z (O CD N N c Oi C y 7 7' O 7 0 c 3D n ;05 ;1 O n .ZJ FL; �' �' C > a w o c v 0 3 Q° o o- 0 0 -. •< v m cCD - y' y a O -0 '� O. N -q o ;n * ( 0 ;0 * m 0 7 co W �I<i'I NCD 7 N �y� . O O O+ pl j N < 7 0 X CD 0 Q 3 0 *N O Z 'CD �, (0 a 'N CCD D co N n S?° n. CD 51 a o y a ° (D X N ':"-el X00 N O �y O ::N LS N 7J oN 0 o Co 0 CD T s33 0 0 23 O : CD 7 : 3 N 0 : 0 * CD '0 r 0 co O : : .O # A < co A 1 0 5 o T 0 7 :1 zo 0 m. CD N 7 N 1 ) 0 Ali co O Z Z z z 'zz -< -< -< -< -< -< Z -< z -< -< Z 'Z 'Z 'z z z z z -< -< -< -< -< -< -< -< -< -<; -< -< 'Z z m > > > > 0 D 0 CD CD CD CD 0 'D 0 'D ;CD CD '0 D D D D D 'D 'D 0 CD CD CD CD CD CD CD CD, CD CD CD 'D 'D 0 CA 00 CA CA 0 CA CA N 0 to CO CD CO CA CA 0 0 coS m I ; m N I '> ;0 'C '3 '0 C 0 13�i 0 c c �O ;B C m X In �(Dp X � X 0 ��. 3 '3 'D. 7 0 CD CD X N -0 a K o _v6' :CD �0 �0 �o CD 0 �W .T_1 m 3 N 1 v V) CD 0 — 0 N CA N 7 O In °1 01 y 0 CO• 7 °1 a 50 ' fD D a c 0 +� a * 0 y m to _ O m 7 y O N to 0 3 N O 0 CD : (0 : - C m 1 ° • ,o r,..5 CA '0 7 3 X c0 C 0- co * W CD o cp v > > N oo o D 0 a N 7 N 00 :Coil 00 71 O a) ,p D 7 (Da x OD C "' A n o O 03 :o. m a .X N < V o m O C 3 I 0 a -07 w' m z _ 0- w ton o vl 4 0 O Rl .O LS 0 1I CD N '0 d [U co X C C OZ 7 C N D: n a) wI s 0 co o au co co o I o (0 3 p, v c O 3 d ',. 7 n O o m y < 0 0 0 co 0 a c 0 I 0 > 0 c a v o 0 CD Cn o fo w
