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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. QJ © - _I L 1Q1 Well History File Identifier Organizing (done) ❑ Two-sided III IIIIII IIII ❑ Rescan Needed I I I1111111 I RES AN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: 1 IC)lar... OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: alt7iiii. /s/ rYiP Project Proofing 1131111f IIIII BY: Date: DI 7jicc. /s/ (yj 1 Scanning Preparation I x 30 = 30 + ea, = TOTAL PAGES z a (Count does not include cover sheet) " L BY: Maria Date: a 7/I g. /s/ Production Scanning N111111111 VIII Stage 1 Page Count from Scanned File: 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: i YES NO BY: ME .. Date: a/7/ `� /s/ 1m Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /5/ Scanning is complete at this point unless rescanning is required. 1111111111111111 ReScanned II I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 13111111111111 10i')')i)nh 1 tnrell u■cf.,.,,Cite/`.,.,e.D.,.,e a.,,. c c d0 2 w c0> 0) o 3 a co N Z I ❑ O)c` �I, Ili N .4>_ Q m 4 ❑ c as O 0 N N N E co a d 2 O o J co V ❑ z = H OF= 2 2 a Q o v c r 0 0 0 0 0 0 0 • a 0 0 0 •■ J 0 tl N N N N 2 y 0 V Oi Q J N N N N I 2z E c Y - 0 7 c c C C C C E a of c O• U 0 0 0 0 0 0 0 ❑ re Q -c- 11..) co U co 0, O o 0 0 0 0 O d 7 N 2 N N N N N N 0 Z I A J U q rn 01 rn 01 rn co l. ,p y W = d Cl) Z U\6 ca m a , t0N 0000 O v aa)) W z y > J V U Q d a) w Z c 0 0. Z C FO- Q o c I cq h O • 7 I J 0 c >, E I OV N c I J U U U f i Q o o U) d I O N 0. I a) 0 00 E To- ot 0 0 N 1.0 1.0 E fU NT 1 Q O) 0 I 0 = 1- o N M d W r4 c II vI Q ce ❑ d 1 Q Y ° 'I I F— r) O c Q O. Z1 0) .> w w w ' Q 0 U O �!/ N N N di (0 = 'N 0 N a)@ v C7 (0 Q' v) CL OC I Z 2 C c O c O O O O a) O • La C E f) .2) .-5 ti .5 .i (o , co 0 7 a) 7 7 7 0 cfl w Z O c 5 c c c 'a Z CO u• c v N N >- }W G Z d O y O _ o Q o o E E °' Z -0 Z v N w to R J N a' C _ O LL_ > a) o `n p 0 c _- a Q J y Z c. I c o rn ❑ Z lij Ill O y v o -z W g U�U o ❑ Cl a O m CI `'g n ■ ❑ o 0 0 o m 0 >0 . c o I o 0 Ce a. C1 I- J G FT W W Q.' J J J Q > 0 <CC I U U Company ConocoPhillips, Alaska, Inc. Well Name 3A-17AL2-01 Date 11/22/2010 nocoPhillips Alaska Greater Kuparuk Area*** Data Distribut RECIPIENTS No other distribution is allowed without - OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Frin?. NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC Christine Mahnken 1 Graphic image file Dis-'"` 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP ± ,-L:iry Glenn Fredrick 1 Graphic image file I Disk*; P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Wirr State of Alaska; DNR, Div. of Oil and Gas }' Dj. k*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer/ Rig Foreman TOTAL Hardcopy Prints 4 Graphic Image File 4 Electronic Data 5 ;!U -!/C ai6. Page 1 of 4 c0L33 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q e Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: October 11,2010 • 210-116/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 October 8,2010 50-029-22691-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 663'FSL,785'FEL,Sec.7,T12N,R9E, UM • October 10,2010 • 3A-17AL2-01 • Top of Productive Horizon: 8. KB(ft above MSL): 82'RKB 15.Field/Pool(s): 1003'FNL,2312'FEL,Sec. 17,T12N, R9E,UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 265'FNL, 1910'FWL,Sec. 17,T12N,R9E, UM 7362'MD/6006'TVD Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-507663 • y- 5997044• Zone-4 . 9250'MD/6165'TVD' ADL 25631,25632 ' TPI: x-511423 y- 5995383 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-510361 y- 5996120 Zone-4 nipple @ 508'MD/508'TVD 2564,2565 18.Directional Survey: Yes El No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1445'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7760'MD/6137'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 212 sx AS I 7.625" 29.7# L-80 Surf. 3821' Surf. 3306' 9.875" 1020 sx AS III,340 sx Class G 5.5"x 3.5" 15.5#/9.3# L-80 Surf. 7782' Surf. 6334' 6.75" 190 sx Class G 2.375" 4.6# L-80 7382' • 9250' • 6022' 6165' 3" slotted liner t/ 24.Open to production or injection? Yes Ei No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 7272' none slotted liner from 7388'-7420'MD 6027-6051'TVD _ 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 7497'-9249'MD 6096-6165'TVD 'ZNI-LL°IGN. i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1. ,I •/ # - .._ 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 17,2010 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/19/2010 12 hours Test Period--> 984 _ 338 963 24 Bean 421 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 179 psi 269 24-Hour Rate-> 1805 760 1893 23.5 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ECEIV ' NONE RBDMS NOV 051010 �'`') !.3 54 2O�� P3 On,- 41$s1(n Oil&Gas Cares.Conea3° a Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Apehol�t original only /!!P e) �� /1/41.,/,,e, ! -1, /I� 6 28. GEOLOGIC MARKERS(List all formations and markers .icountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1465' 1445' needed,and submit detailed test information per 20 AAC 25.071. A-2 sand 7760' 6137' Bottom A-2 sand 9250' 6165' N/A Formation at total depth: Kuparuk A2 sand 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,definitive directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Na a Ca Title: Alaska Wells Manager vI1i1a Signature Phone 265-6306 Date 11/ Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 0 0 o a m y a o b 0 I-m n° 77,-J ° N N 0 w m m , v 1 c C) .E n N o f «rn o• I A@� d ... >. 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Q H c7,0 CO KUP 3A-17AL2-01 C onocoPhif ips 0,9 Well Attributes Max Angle&MD TD_ __ ll Ala Inc W Ilbore API/UWI IF Field Name Well Status Intl(°) MD(ftKB) Act Btm(ftKB) totwo0ph8917 ^ 50_0292269162 IKUPARUK RIVER UNIT PROD 9,250.0 Comment H2S(ppm) Date Annotation End Date K8-&d(R) Rig Release Date .. well a17AL-01 tN11.1"5107o.n AM SSSV:NIPPLE 220 3/15/2009 Last WO: 41-00 9/2/1996 ���"-3_S __Aygly__- Annotation 'Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 1 Rev Reason:SIDETRACK WELL wMT_ERALS Imosbor _10/12/2010 ICasin Stnn s_ 'Casing Description (String 0.. IString ID...Top(ftKB) Set Depth(f...Set Depth(TVD) String Wt...String..(String Top Thrd t 'li r I LINER AL2-01 2 3/8 1.995 7,381 5 9,250.0 4.60 Il L-80 STL II ti /` Liner Details ' Top Depth (ND) Top feel Nami... Top MOB) (ftKB) C) Item Description Comment ID(in) 7,381.5 DEPLOY (DEPLOYMENT SLEEVE w/PBR 1.995 _ . CONDUCTOR,_ 40-121 Perforations&Slots Shot NIPPLE,508 li Top(rVD) Btm(TVD) Dens Top(ftKB(Bkn MOB) (ftKB) (RKB) Zone Date (sh. Type Comment rtt 7,388-0 7,420.0 A-3, 10/11/2010 32.0 SLOT Slotted pipe-0.125'x2.5"i 4 3A-17AL2-01 circumferential adjacent rows,3- GAS LIFT, centers staggered 18 deg,3'ir 2,962 +. non-slotted ends 7,497.0 9,249.0 A-3, 10/11/2010 32.0 SLOT Slotted pipe-0.125°)2.5"@ 4 3A-17AL2-01 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends Notes:General&Safety SURFACE, °- , End Date Annotation 39-3,621 10/12/2010 NOTE WELL SIDETRACKED.3A-17A,AL1,AL1,AL2,AL2-01 GAS LIFT, -_ 4,236 GAS LIFT,--_5,254 Ill GAS LIFT, 6,114 lir GAS LIFT, 6,753 "'"."'°.-.-"r" GAS LIFT. it 7,198 II NIPPLE,7,251 —– it-I. �33 SEAL ASSY, Y `'- 7,256 WHIPSTOCK (AL2),7,396�..... SLOT,– 7,388-7,420 :I WHIPSTOCK,_ _7,412 Mandrel Details_ Top I— P To P � Port (TVD) loot OD Valve Latch Size TRO Run PRODUCTION Stn Top MUM MKS) (°) Make Model (In) Soon TYPE Type (in) (psi) Run Date Co ...rn 5.5716, 1 2,961.6 BST ATX 1 GAS LIFT DMY T-1 '0.000 0.0 8/20/2010 35-7,782 SLOT, 2 4,235.5 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 9/14/1996 7,488-6,396 SLOT, 3 5,254.5 BST ATX 1 GAS LIFT GLV T-1 0.156 1,335.0 11/30/1996 Note 7,497-9,249 LINERAL2-01, 4 6,114.3 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 9/14/1996 7,381-9,250 TD 5 6,752.7 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 8/22/2010 (3A-17AL2-01), II 9.250 6 7,197.8 BST ATX 1 GAS LIFT DMY T-1 0.000 0.0 2/4/2007 LINER AL1. 7,410-9,430 10 i hiLt4.50 Nowo CEZ Ali V c co 0 - Q co W EX v) 1 Q I--- >, CIN110110111111 CO C MC MIMI N D 13 CL Lca co U 0 O ; z co a) ig to Lo w a co L0 m M O m ti O O O O N c 1-. 0. 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(a 7 10 N CO C) 0 0 0 0) O) N to V N 0) N V N 0) (D co .- a) Lo a) (0 co o N.0 1L_ N n r r N CO 00 CO N N N r N- CO (0 (0 CO U) LO LO LO V V V' CO CO CO CO N CD J > 'L' Z rn 0 W M co CO CO CO CO CO CO CO co co co- CO CO CO CO co CO M CO CO CO CO CO CO CO CO CO CO CO + co O (b r co CO 0) C) C) (D (.0 N LO (O CO 0 0) 0 00 CO c0 LO N LO LO (D N LO N- CO (0 U) h N V' (0 0) CD N CO CO N CO N N 0 C) V' 00 (0 CO N CO O CO N - (D N O) V' Ln U) U) (O O (O N O M N N O 0) O V' O N N 00 O O M N CO CO CO CO (V C) CO CO 0 N C N 0) N LO co 0) OD N LO U) V' CO CO CO CO CO CO CO M • CO (0 O 0. to N U) to V V' V' co co co co co N N N N N N N N N cq N N N N LO O O) `- N CO 0) V' U) CO CO s- 0) LO s- CO CO LO N CO s- N N V' N- N- O N- a) co CO CO O V V N ,- CV V co 0 N CO CO CO N- O N C) O) to N CO N CO .- N (0 V' LO 05 M (D N V' M N 00 O N N U) C) O N M O O O M (O 6) — N V' U) UI U) N U) U) (D (O N N N N N- N N N N N N CO CO (0 (0 (O O (0 CO CO N N N N 0` o 0 o o 0 0 0 0 0 <6 0 o o (Doc, o (6 0 o 0 O o O o O 0 O o 0 H (D (D (D (D (O (D (D (D (D (D (0 CD (O (0 (D CO (D (D (O (O (O (0 (0 (0 (0 (0 (0 (0 (0 (0 to O a) N CO O) V U) < < CO CO 0) 0 U) s- CO 0) LO N CO N N V- N N 0) N a) co CO OD O V V N CV V O0 0 N CO CO CO N (0 N O) 6) to N O N co ,- N ' to 0 U N U) O0 r+ M CO M - V LO U Lou, 0 (0 LO (O LO UD L0 V' V' VV V' V C 7 U LO L0 Li C (O (D (O C6- CO (O (0 (0 (O (O (6 (O (D (D cc O O (0 (D O (D o c0 (O (D cc (O (D (O (O N N as C CC N N V c U) N U) LO CO U) CD 0 0) N CO LCD CO CO U) (D V U) N 0) 0 CO CO N 0) Q D � O N co 0) LO (D N U) N CO O 0 N- N CO o U) N- 41 N 7 V' N U) UJ U) CO O) N d d .v M tb V co O N (0 OD O CO co CO CO V O (6 N 6 U) o (0 N OD M O U) O V V CO N N `- LO V CO CO N O 0 O 0) 0) CO CO CO N N- CO (0 N N- CO CO > CO CO CO M CO CO CO CO CO M N N N N N N N N N N N N N alio 01 z 2 (h `r.: a d Y Y ..... 8 2 I. i O f0 (6 N N- N O CO - (a o CO N O) N a) V' " U7 0 N 0 N CO U) (O N- 6) ' N- CO OD :. C Q Q 0 CD M N co .- co N O O � N 0) (0 N 0) CO 7 .- N c0 .- CO U) V' 0 N U) Z O 7 7 r.Y 6 M V V o) o V W O N W N '7 c0 (0 co CO 0) OD N O V V' (0 O o N 0_ Q Q Q C v O) a) OD N N co co co co co co 0 O 4) O) a) a) m co Q) O co co co co co co co co co 7 p (N (V UV CO 0 CO 0) LO N- O 0 0 CD (O C) O OD N CO 0) CO M 0 CO O) CO 0 0) O a0 01 N V N CO O CO LO LO O 0) N O N CO (0 (0 O CO CO N CO (� U) CO CO CO 0) co o 0) U) N LO T _ O O O o 0 0 O O o O o o O O O o 0 o N O 0 0 0 M N O O o 0 Q c .. 0 co (0 0) r V' N 0 CO (D 0) N LO OD 3- V N- 0 CO _CO 0) N UD CO V' N- 0 CO (D 6) �.i C • v — C N N N CO CD CO CO CO CO O) O O O .- N N ( N CO CO CO V V V' LO LO LO U) O �0 a Q CD 0 N N N N N N N N N N co co co co co co co co co co co co co 00 co OD co co OD co CO LP U• o. Cn 3 0 rn o CO co kw 1 a CO co M 0 O N .( 0) o Co Q 0 U E E 0 Z O O 0 o W I. I- T 7 R V V V 7 7 7 7 V d' V V V C' R 4 d' 4 V 0 m W Z+ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (R• 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 a. LO LO CO 0) F. d' a) CO 6) u) N- 0 CO CO N (0 0 0) u) u) N Cr W C n u) co co V u) F- to 0o co o co N- F- (O o u) V N r- 0) O (+i M M 4 (O F- a0 0) 0 0 0 0 0 0 oP N V (0 N C C O co M o F- - 0 CO N O F- V co O co u) N CO u) CO (0 :L V 7 V V co co co N N N N ,- 0 0 0 0) 0) 4) c0 O) 3 3 O m m M M M M M M (h M M M M M co co M M N N N N N CC I• Y E > v 7 >N 0 O --. co d' u) N 0) N u) F- V' `"' N u) `-' CO 0 N F- N N 0 O O > d CO u) a) ,- O N CO 0) CO (O n (0 01 V F- F- CO F- 10 CO 0 O O i CO O 7 u) W F- N 7 u) F` CO N 0 7 0) V ti u) u) o J ) © E m _ 3 Q n'• F• F- M co C F- 0) co 0) V CO 0 0 V' (0 N M M O. CO F- R GI E 2 u) d' co 0) 0 0 N W 0) 0 d' a) N u) N N F, F- CO Q Q .,'t 2 C aI F- O N O M W V O N V (0 F- F- F- N N co 4 F- F- 4 0 M C 0 F- (0 N o F- u) N O F- R 70 0 u) N 0) (D V aO (O M M I- W O.—,-+0) W W W (0 F- F- F- F- (0 (0 (0 u) u) u) v C V R M M Q30=6-. 0 0 0 0 0 0 0 0 0 0 o a o 0 0 0 0 0 0 0 w t() u) u) u) to to u) u) to u) u) u) to u) u) u) N u) u) to to "C ci 0 a .a Cr)/� C C C 0. 1d. .0 N. V CO M u) CO 00 N N 0) N 7 F- " M M 0 0) 0 _ 1al N N (O 0 N CO 0 CO R CO N u, ■- (0 r (0 0 (0 .- CO tO = D'I m M m 0) o M 0 (O 7 N F- .4 N N aD V O 4 V 0) u V N O C N V u) (0 CO 0 N M U) (O N- N- 00 0) 0 4 N 4- (0 0) 4 • Q) Q' C p.L co (0 (0 (0 (00000) 00)c o c o a) 0 o oo o o 0 0 0 0 a. m O co =u) u) u) u) u) u) u7 up- u) u) u) u) u) u) (0 () co u) o 0) CO _ C v d) rn a) rn a) rn a) a) a) 0 0 0) a) 0) O) O 0 0 6 0) 0 m V f6 Z ui u) up co u) co cc) co co up co to tri ui U ui to- cc; u) to cc; 4 V N y C 0) C L W O _ W 0 m V o, 0) u) u) V' 0 V 4 O O co 00 co 0 04 0) co 00 N u) CO a m C. T 05 F- F- co N M N CO N u) N M to co M 0) 0 u) u) N N CO U (�;.. S d . of ui CO (0 a) ui O ui M 4 N C) NJ 0) 00 00 N F- R V 0) K y CO<a '3. V — co (o M o (0 M co u) O 0) u) N 0 N- u) N V' Gy O G..a+ _ W- N N ,- .- 0 O 0 0 0) 0 0? 00 CO CO CO F- F- F- 0 0 • > Z CO LLI v ri co- M M M M M co- t•) M N N (V N N N N N N N N- 1 7 7 N- 0 to CO 0 (O F- 0) N (O 0) M 0 0 0) V N CO CO N- u) O) CO ,- N F- 'a N- O. 0) N- CO V CO 0 CO 0 F- '7 00 '— N u) O o V u) m M (D u) N 0 M u) N N 4 0 0) F- (0 C N a) CO N- CO u) u) O M s- 0 O u) N N N _ _ 0 0 0 o O o 0 0 0 o a) O) + ' ' V co 0) M a) 4- u) to O N O N V V F- V CO CO N- N N 'Cr ,- o u) CO (O N V u) CO u) N CO CO CO C F- 0) .- �'0 (0 u) M O O) 0) m 0) O N M g V V u) CO M F- F- N- 0 0 0 (O (O (O (0 F- F- 1� F- F- 0 F- F- F. F- CO p 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 • F>- (o CO CO- CO- CO (o CO CO CO- (o (o co- (o (o co- co- co- co- co' (o (fl 7 CO a) CO a) 7 u) 0 0 N 0 N V V F- CO CO N- N N V .- o u) CO (D CO O- u) CO u) N CO CO .- CO 0 F- CO u 7) . () ; CO cc f9.) u- u) (M 0 N) u u u) u uN M M u u D u 0 u)- (o (u0) C w I—--- u) O O (D u) 0 c,5 cci co- co co c0 cc (0 co o co t0 (O (D 0 co y 0 - _ _ _ Q C V D op n N U) N- CO (0 00 (0 N t(f 0 CO CI CO t0O o N u0) CO CO a n i 03 _ o NJ v co of m ui c,-; o u o ui o a v o ui o o o ci u .j n ( a_ Q (v N rn rn o o O o (V rn (V cN o N o N- eN rn al o 0 M M M M Q. O >L F M MOM iYY d Y Y — 0 i i *mini 0 H h r N (0 N 0 (0 U) 0 V 0 V (O 0 0 N U) 10 CD 0) CO'aD M (0 CO 0 u) M N CO � M 0) r` CO � U) V' d' u) CO CO o Q co co C•:co a) 0) 0) 0) a) a) 0) CO co co co co (0 co co (0 co co cco co M U Y Y co co co cv u 0 u) CO OO 0) N 0 0 M co CO(O CO(O CO 00 0) U) CO M N N N 0) U) o (V CO F- CO CD M co a0 co F- co co F- co co F- a) co co co u) a0 O T o O o 0 0 0 O O O 0 o O 0 0 0 F- O O O o 4 0 O C R ;. CO. O C T O N u 00 O. F- O CO ( 0) N U) CO ,- V CO V N- N (O u) F- F- F- CO CO uu CO d) 41 d) O O O N N CD V d m .0 0 0 _ ao a0 ao ao cO c co m co co cO co co a o rn o o) ai 0) 0 cv U 4 !A Ci. N o Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:48 1.80 8,835 8,951 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3400 CTP,4050 BHP 01:48 02:48 1.00 8,951 7,420 PROD3 DRILL WPRT P Wiper to window. Had trouble getting good weight transfer and then 5K over pulls.29K PUW 02:48 03:00 0.20 7,435 8,951 PROD3 DRILL DLOG P Tie-in,-1.5' 03:00 03:42 0.70 8,951 8,951 PROD3 DRILL WPRT P Wiper back in hole,start new mud down coil for mud swap 03:42 05:06 1.40 8,951 9,110 PROD3 DRILL DRLG P Drilling ahead with new mud, 1.4 BPM,3300 CTP,4030 BHP 05:06 07:06 2.00 9,110 9,110 PROD3 DRILL WPRT P Wiper trip,29 K PUW 07:06 07:54 0.80 9,110 9,200 PROD3 DRILL DRLG P 9110', Drill Ahead 1.38 BPM @ 3250 FS BHP=3881, ROP=114 07:54 11:30 3.60 9,200 66 PROD3 DRILL WPRT P Call TD, Pump LoHi sweeps,trip to swab valve 11:30 13:06 1.60 66 7,200 PROD3 DRILL WPRT P Bump Stripper,Set BHA depth 77.57 Run back in well 13:06 13:18 0.20 7,200 7,230 PROD3 DRILL DLOG P Gamma tie in for-8 13:18 14:24 1.10 7,230 9,200 PROD3 DRILL WPRT P Continue in well,Swap to beaded pill @ 8500' Tag TD @ 9200,3 BBIs to beads 14:24 17:06 2.70 9,200 0 PROD3 DRILL TRIP P Trip out laying in beaded liner pill/ KWF Following pressure Schedule Paint EOP flags 6000&7800 17:06 17:24 0.30 0 0 PROD3 DRILL SFTY P Monitor well, PJSM forLay down BHA 17:24 18:30 1.10 0 0 PROD3 DRILL PULD P Lay down Drilling BHA 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P RU floor for liner operations 19:12 19:24 0.20 0 0 COMPZ CASING SFTY P PJSM 19:24 22:24 3.00 0 1,271 COMPZ CASING PUTB P PU 38 joints liner. BOP drill at joint #18,Well secured at 2:40. 22:24 23:48 1.40 1,271 7,271 COMPZ CASING RUNL P RIH 23:48 00:00 0.20 7,271 7,300 COMPZ CASING RUNL P Correct to EOP flag,-3'. 31K PUW, 17K RIW(-2.8 WOB) 10/08/2010 Set anchored billet at 7760'. PU drilling assembly,swap well to flopro and mill off billet,drill ahead to end of turn at 8070'. 00:00 00:42 0.70 7,300 9,204 COMPZ CASING RUNL P Continue to RIH with liner 00:42 01:06 0.40 9,204 7,400 COMPZ CASING RUNL P Tag TD at 9203.65',online with pump at 1.3 BPM,4400 CTP. Release li liner and POOH pumping down backside 01:06 01:18 0.20 7,400 7,420 COMPZ CASING DLOG P Log RA,-5'correction. Deployment sleeve is at 7971.5' 01:18 02:54 1.60 7,420 0 COMPZ CASING RUNL P POOH pumping down CT. Paint EOP flag at 7100' 02:54 03:12 0.30 0 0 COMPZ CASING SFTY P PJSM while monitoring well for no-flow 03:12 05:12 2.00 0 273 COMPZ CASING PUTB P Lay down BHA. PU guide shoe,6 Joints slotted liner,5.85'pup and anchored billet. MU Inteq BHA Page 17 of 20 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:12 07:12 2.00 273 7,381 COMPZ CASING RUNL P RIH 07:12 07:30 0.30 7,381 7,971 COMPZ CASING RUNL P Correct to EOP Flag for-8',Close EDC 07:30 07:42 0.20 7,971 7,199 COMPZ CASING RUNL P Set down @ 7971, Pull up hole,Set back down 7969 Pumps on,see tool shift @ 4K Set down 1.5K on anchor, POOH 07:42 07:57 0.25 7,199 7,220 COMPZ CASING DLOG P Log gamma for a+.75 foot correction BOL=7971,TOL=7760 07:57 09:42 1.75 7,220 59 COMPZ CASING RUNL P Trip out 09:42 10:30 0.80 59 0 COMPZ CASING PULD P PJSM, Flow check well, Lay down BHA#21 10:30 11:30 1.00 0 62 PROD4 STK PULD P P/U BHA#22, 1.7 Degree motor, Bi Center Surface test tool 11:30 13:15 1.75 62 7,200 PROD4 STK TRIP P Trip in well 13:15 13:21 0.10 7,200 7,215 PROD4 STK DLOG P Tie in for a-7'correction 13:21 13:27 0.10 7,215 7,380 PROD4 STK TRIP P RIH to 7380. 13:27 15:12 1.75 7,380 7,380 PROD4 STK CIRC P stop at 7380, Pump spacer, Roll well to flo pro recovering KWF Shut EDC 15:12 15:30 0.30 7,380 7,760 PROD4 STK TRIP P Trip in to kick off billet 15:30 18:42 3.20 7,760 7,770 PROD4 STK KOST P Dry tag billet at 7760,Start sidetracking per recommended practice/procedure 18:42 21:24 2.70 7,770 7,910 PROD4 DRILL DRLG P Continue drilling ahead. Drift billet, clean. Drill some more, 1.4 BPM, 3300 CTP,3800 BHP 21:24 22:24 1.00 7,910 7,910 PROD4 DRILL WPRT P Wiper to window,Tie-in due to BHI computer reboot.Zero correction. 22:24 23:54 1.50 7,910 8,070 PROD4 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 3840 BHP 23:54 00:00 0.10 8,070 PROD4 DRILL TRIP P POOH for AKO adjust 10/09/2010 Drilled AL2-01 lateral 00:00 02:24 2.40 7,800 0 PROD4 DRILL TRIP P Continue POOH for BHA,to PU resistivity tool and lower AKO 02:24 02:36 0.20 0 0 PROD4 DRILL SFTY P PJSM for undeployment 02:36 04:48 2.20 0 0 PROD4 DRILL PULD P Undeploy BHA. PU resistivity and adjust AKO to 1.0. Deploy BHA 04:48 06:48 2.00 0 0 PROD4 DRILL PULD P Deploy BHA#23,Surface test tool All good Tag up,set counters,Open EDC 06:48 08:12 1.40 0 7,205 PROD4 DRILL TRIP P RIH 08:12 08:24 0.20 7,205 7,222 PROD4 DRILL DLOG P Log Tie in for a-10'correction Close EDC 08:24 08:48 0.40 7,222 8,070 PROD4 DRILL TRIP P Trip in to drill,Clean pass through window and past billet 08:48 10:00 1.20 8,070 8,220 PROD4 DRILL DRLG P 8070 Drill Ahead, 1.4 BPM @ 3353 PSI FS BHP=3932 10:00 11:48 1.80 8,220 8,220 PROD4 DRILL WPRT P 8220,Wiper to window with MAD Pass, PUW=29K Page 18 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:48 13:12 1.40 8,220 8,370 PROD4 DRILL DRLG P 8220, Drill ahead, 1.4 BPM @3315 PSI FS, BHP=3964 13:12 14:12 1.00 8,370 8,370 PROD4 DRILL WPRT P 8370,Wiper to window, PUW=30K 14:12 15:12 1.00 8,370 8,520 PROD4 DRILL DRLG P 8370'Drill ahead 1.4 BPM @ 3340 PSI FS 15:12 16:42 1.50 8,520 8,520 PROD4 DRILL WPRT P 8520',Wipe to window with tie in, PUW=28K No Correction on tie in 16:42 18:24 1.70 8,520 8,670 PROD4 DRILL DRLG P 8520', Drill ahead 1.42 BPM @3350 PSI FS BHP=4041 18:24 19:54 1.50 8,670 8,670 PROD4 DRILL WPRT P Wiper to window,29K PUW. Clean trip 19:54 21:12 1.30 8,670 8,820 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM,3400 CTP,4000 BHP 21:12 22:48 1.60 8,820 8,820 PROD4 DRILL WPRT P Wiper trip to window,28K PUW 22:48 00:00 1.20 8,820 8,957 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM,3400 CTP,4050 BHP 10/10/2010 Drilled AL2-01 lateral to TD at 9250'. Condition hole and pump KWF. Run liner. 00:00 00:18 0.30 8,957 8,970 PROD4 DRILL DRLG P Continue drilling ahead, 11K RIW, 1.4 BPM,3455 CTP,4090 BHP 00:18 01:12 0.90 8,970 7,420 PROD4 DRILL WPRT P Wiper to window 01:12 01:24 0.20 7,420 7,440 PROD4 DRILL DLOG P Tie in,zero correction 01:24 02:00 0.60 7,440 8,970 PROD4 DRILL WPRT P Wiper in hole, 15K RIW at window 02:00 03:42 1.70 8,970 9,120 PROD4 DRILL DRLG P Drilling ahead, 11K RIW, 1.4 BPM, 35oo CTP,4100 CTP 03:42 05:48 2.10 9,120 9,120 PROD4 DRILL WPRT P Wiper to window, 28K PUW 05:48 07:12 1.40 9,120 9,250 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM @ 3470 PSI FS BHP=4105 RIW=7K Call TD 9250 07:12 07:42 0.50 9,250 9,250 PROD4 DRILL CIRC P Start LoHi Sweeps 07:42 11:42 4.00 9,250 72 PROD4 DRILL WPRT P Sweeps coming out,Chase to swab No heavy cuttings observed 11:42 13:27 1.75 72 7,215 PROD4 DRILL WPRT P Reset depth at surface, RBIH 13:27 13:33 0.10 7,215 7,225 PROD4 DRILL DLOG P Tie in for a-10'correction 13:33 14:33 1.00 7,225 9,250 PROD4 DRILL WPRT P 9250,Tag TD, 14:33 17:12 2.65 9,250 0 PROD4 DRILL TRIP P Trip out of well laying in Beaded liner pill/KWF. paint flags at 7250'and 5400'EOP 17:12 18:00 0.80 0 0 PROD4 DRILL PULD P Lay down drilling BHA 18:00 19:00 1.00 0 0 COMPZ CASING PUTB P RU floor for liner operations 19:00 19:18 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations 19:18 23:18 4.00 0 1,912 COMPZ CASING PUTB P PU liner string,Safety Joint Drill at joint#33, <4 min. 23:18 00:00 0.70 1,912 4,000 COMPZ CASING RUNL P RIH with liner 10/11/2010 Run liner, recover KWF,FP well, RDMO Page 19 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 4,000 9,250 COMPZ CASING RUNL P Continue RIH with liner. Correct at flag at 5400 EOP,-8.3'. Weight check 30K PUW, 16.5K RIW with -5.5 WOB. 02:00 02:30 0.50 9,250 7,370 COMPZ CASING RUNL P Tag At 9250'. Pump at 1.2 BPM, 4300 CTP and PUH, released from liner. 02:30 03:30 1.00 7,370 7,370 COMPZ CASING DISP P Circulate KWF from hole 03:30 06:15 2.75 7,370 0 COMPZ CASING RUNL P POOH, Lay in diesel FP from 2500' to surface 06:15 08:15 2.00 0 0 COMPZ CASING PULD P PJSM, Undeploy BHA#24 Linner run 08:15 10:00 1.75 0 0 DEMOB WHDBO NUND P PJSM , P/U FMC Lubricator and equipment to set BPV 10:00 10:45 0.75 0 0 DEMOB WHDBO NUND P PJSM,Stab back on well, Flush stack and rig not previously flushed 10:45 12:15 1.50 0 0 DEMOB WHDBO NUND P Blow down coil,stack,and rig. Bleed off and unstab injector 12:15 13:15 1.00 0 0 DEMOB WHDBO SFTY P Finger injury on rig floor,sent IP to medic,made notifications.Safety meeting with crew 13:15 19:15 6.00 0 0 DEMOB WHDBO DMOB P Continue with RD,still emptying pits. ND BOP 19:15 21:00 1.75 0 DEMOB WHDBO DMOB P Rig released at 21:00 Page 20 of 20 3A-17 Well Work Summary 'DATE SUMMARY 10/12/10 RAN MAGNET& BRUSH TO T(., OF LINER @ 7395' RKB. MEASURED Bhr @ 7395' RKB: 3409 PSI. SET CATCHER @ 7251' RKB. IN PROGRESS. 10/13/10 PULLED DV @ 6752' RKB. ATTEMPTED SET OV @ SAME. IN PROGRESS. 10/14/10 PULLED DV @ 6114' RKB. ATTEMPTED SET GLV @ SAME. SET 1/4" OV @ 6752' RKB. IN PROGRESS. 10/15/10 PULLED DVs @ 4235'&2961' RKB. SET GLVs @ 6114', 4235' &2961' RKB. WITH HOLEFINDER IDENTIFIED POSSIBLE LEAK @ GLM @ 4235' RKB. RAN LIB TO CHECK GLM, UNABLE TO SD. PULLED EMPTY CATCHER @ 7251' RKB. IN PROGRESS. 10/16/10 BLED IA f/620 TO 80 PSI, TBG HOLDING @ 825 PSI. OBSERVE 15 MIN, GOOD. PULLED CATCHER. COMPLETE. SUTIE [1 ' SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-17AL2-01 ConocoPhillips Alaska, Inc. Permit No: 210-116 Surface Location: 663' FSL, 785' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 5013' FSL, 3296' FEL, SEC. 17, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3A-17A, Permit No 210- 113, API 50-029-22691-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. 51 Chair DATED this3 I day of August, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA FCEIVPD ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AUG 2 0 2010 20 AAC 25.005 litska CZ. a,G C.C fi Tnissinn la.Type of Work: 1 b.Proposed Well Class: Development-Oil MI • Service-Winj ❑ Single Zone In '1..Spepif , 1 eroposed for: Drill ❑ Re-drill In Stratigraphic Test El Development-Gas❑ Service-Supply El Multiple Zone❑ Coalbed Gast L Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: 0 Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 3A-17AL2-01 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9300' • TVD: 6060' . Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:663'FSL,785'FEL,Sec.7,T12N, R9E, UM • ADL 25631,25632 ' Kuparuk River Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: Top of Kuparuk:4219.95'FSL,2653.2'FEL,Sec.17,T12N,R9E, UM 2564,2565 9/15/2010 Total Depth: 9.Acres in Property: 14.Distance to TD:5013'FSL,3296'FEL,Sec. 17,T12N, R9E,UM 2560 Nearest Property: 21450' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 82 feet ' 15.Distance to Nearest Well Open Surface:x- 507663 • y- 5997044 • Zone- 4 GL Elevation above MSL: 41 feet. to Same Pool: 3A-07,1200' • 16.Deviated wells: Kickoff depth: 7600' •ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 108° • deg. Downhole:4560 psig • Surface:3957 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight , Grade Coupling Length MD _ TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1920 7380 5939 9300 6060 slotted liner , \.. \ 0 N\* 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) I Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 7785' 6336' 7717' 6283' Casing Length Size Cement Volume MD TVD Conductor/Structural 81' 16" 212 sx AS I 121' 121' Surface 3782' 7.625" 1020 sx AS III,340 sx CI G 3821' 3306' Intermediate Production 7747' 5.5"x 3.5" 190 sx Class G 7782' 6334' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7347'-7370',7380'-7390',7474-7504' 5995-6013',6020'-6028',6094-6117' 20.Attachments: Property Plat❑ BOP Sketch In Drilling Program I'ni Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program in 20 AAC 25.050 requirements in 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 �O d i a I i Printed Name V. Cawvey /',t Title Alaska Wells Manager f Signature '�1 tr VCA� -1+c-ilex/ Phon2656306 Date c�(Ici'(. Commission Use Only Permit to Drill API Number: Permit Ap royal ISee cover letter Number: 2-In//6"' 50-Ca'"Z2 -,e P 6Z.- t,"C\ Date:$f at (I O for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: B/ •� 'WOO FS-L.- /3o P 1;5 t Samples req'd: Yes ❑ No lir Mud log req'd: Yes ❑ No Er Other: H2S measures: ((es Q'No ❑ Directional svy req'd: Yes No ❑ LSi 0 Psi. h n w�-c l f-C ,") 8'3 1 /0 / APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 1U-4U1 ( evised 112UUY) This permit is valid for mo th ro e datft of approval(20 AAC 25.005(g)) C / submit in Duplicate 'i � F<27-/0 AO > f -ilk Conoco Phillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 18, 2010 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill 4 lateral sidetracks out of Kuparuk Well 3A-17 using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 3A-17 as early as September 12, 2010. The CTD objective is to drill four lateral sidetracks (3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01); targeting the A2 and A3-sands to access reserves away from the parent wellbore, across isolating faults. Two laterals each will be drilled from two separate casing exits in the 3.5" liner. Attached to this application are the following documents: — Permit to Drill Application Forms for 3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic — Sundry Application— Plug perforations If you have any questions or require additional information please contact me at 907-263-4093. Sincerely, Jill L g Coiled Tubing Drilling En eer Permit to Drill Summary of Operations KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Laterals Coiled Tubing Drilling Well History and Objective Well 3A-17 was originally drilled and completed as an A-sand producing, single completion well in September 1996. The A sands were perforated and fracture stimulated in October/November 1996. The well operated as an A-only producer until 1999 when the C and B sands were perforated in June of that year. Production from 3A-17 has historically been lower than expected. The reservoir in the surrounding area is highly faulted and seismic data confirms the current wellbore position is not optimal. The purpose of the CTD project is to drill four CTD sidetracks in the A2 and A3 sands away from the parent . wellbore and across faults that are believed to be isolating. The new reservoir locations should result in improved sweep efficiency and oil recovery for the pattern. Perforations in the parent wellbore are planned to be plugged prior to CTD rig arrival however the lateral footage drilled in the immediate vicinity of parent well will recover the existing perforations. Operational Outline Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5" liner below the tubing tail. 2. Set a cast iron bridge plug above the A sand perforations (and below the lower CTD kickoff point). 3. Perforate the 3.5" liner across the kickoff point locations 4. Set the lower whipstock at—7412' MD 5. Cement squeeze the B and C sand perforations, cleaning out to the top of the whipstock 6. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Lower Window a. Mill a 2.74"window exit with high-side orientation off of the whipstock previously cemented in place at—7412' MD b. 3A-17A Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL1 lateral c. 3A-17AL1 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top from TD to just inside the window 3. Upper Window a. Set a 3.5" Monobore whipstock at—7395' MD and mill a 2.74"window exit with high-side orientation off of the whipstock set at—7395' MD b. 3A-17AL2 Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL2-01 lateral c. 3A-17AL2-01 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top p from TD to inside the 3.5" liner above the window. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Operational Details Hazards — Shale stability is a potential problem, particularly in the build section when crossing Fault#1. tY P p p Y 9 — Drilling into over-pressured zones is a potential hazard in 3A-17. Nearby injecting well 3A-10 has a bottomhole pressure of—4600 psi but is expected to be fault isolated from the planned laterals. Choke pressure will be maintained while drilling, both for maintaining well control and borehole stability. — Well 3A-17 has 130 ppm H2S as measured on 02/16/10. Well 3A-08 is located 16' to the right side and 3A- 09 is 59' to the left side of the 3A-17 surface location. The H2S measured in 3A-08 is 200 ppm (12/18/09) and 3A-09 is 120 ppm (1/2/09). The maximum H2S level on the pad is 260 ppm from well • 3A-16 (12/19/09). All H25 monitoring equipment will be operational. Fluids Program — Chloride-based Biozan brine(8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (9.8 ppg) for drilling operations. — Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. Disposal — No annular injection on this well. — Class 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. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 3A-17A 7700' 9150' 6038' 6032' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3A-17AL1 7412' 9200' 5963' 6000' 2%" 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 3A-17AL2 7600' 9250' 6043' 6085' 23/ , 4.7#, L-80, ST-L solid/slotted liner; aluminum billet on top. 3A-17AL2-01 7380' 9300' 5939' 6060' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. • Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 121 0 121 1640 630 Surface 7%" 29.7 L-80 BTC-Mod 0 3821 0 3306 6890 4790 Casing 5 %" 15.5 L-80 LTC-Mod 0 7254 0 5922 7000 4990 Liner 3 %" 9.3 L-80 EUE-8rd Mod 7254 7782 5922 6334 10160 10540 Tubing 3 %" 9.3 L-80 EUE-8rd Mod , 0 7267 0 5932 10160 10540 Directional Planning — See attached directional plans for each of the three laterals. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance Lateral Name Distance 3A-17A 22650' 3A-17AL2 21450' 3A-17AL1 22650' 3A-17AL2-01 21450' Page 2 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well Lateral Name Distance Well 3A-17A 1200' Toe measured to 3A-07 3A-17AL2 1200' Toe measured to 3A-07 3A-17AL1 1200' Toe measured to 3A-07 3A-17AL2-01 1200' Toe measured to 3A-07 Logging • MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure — The most recent static BHP survey in well 3A-17 was taken August 12, 2010. The reservoir pressure was measured at 3800 psi at 7426' MD/ 6056' TVD, corresponding to 12.1 ppg EMW. This is also the • highest expected pressure in the targeted fault block. — The highest pressure from any of the surrounding wells that could potentially be anticipated is 4560 psi at 6628' MD/6065' TVD (in nearby injector 3A-10). Well Control — Two well bore volumes (-161 bbl)of KWF will be within a short drive to the rig during drilling operations. In - this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. — BOP diagram is attached for operations with 2" coil tubing. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum surface pressure anticipated while sidetracking out of 3A-17 is 3957 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum reservoir pressure from all nearby wells: 4560 psi at 6628' MD/6065'TVD (in nearby injector 3A-10). — The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 8/18/2010 r] Y L O L n j 0 C D I C :"2 h. ao O 0 N N Q rrz m N n Q T v m I A I0 p I J o m 0 N a Q Co J OJ I m II a I I d J Q I- I W II J _ II E r v I N ZS d 0 N u g II E I E FA n N N n O N \J N \\ ,p N fV a N \n C =n I W E d W O `-- /E r n D U N o O a ',7) (V Y E N o P U N (V N)(V r V / o Co O r a 1 ro O I i I N=0„. Ail:j tit' Y1 J) O J -c:`,' O co CCI r- N N! \ C n o aC y°Q p o Nr C N g ``1 O y o n U W ' Z,-,• CON \p m 1,-s O r V I a I U # � ° X n CI- O Y /0 rn� N n 0 O /%L o rot U Y U NO r N N CO co u /�D O -LLJ N 2 O , II 3•o I C i z a °z 5 0 o N Q N N I u m U Q � N U°6 1Om I ii, Q l- c N J Q F Q J Q Q I Is Zo Ei N- M ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3A Pad 3A-17 3A-17AL2-01 Plan: 3A-17AL2-01_wp02 Standard Planning Report 16 August, 2010 r' I BAKER HUGHES *011'- ConocoPhillips FA- Conocoillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL2-01 Design: 3A-17AL2-01_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3A Pad Site Position: Northing: 5,996,860.05ft Latitude: 70°24'9.520 N From: Map Easting: 507,712.01 ft Longitude: 149°56'14.019 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06° Well 3A-17 Well Position +N/-S 0.00 ft Northing: 5,997,044.46 ft Latitude: 70°24'11.335 N +E/-W 0.00 ft Easting: 507,662.81 ft Longitude: 149°56'15.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.40ft Wellbore 3A-17AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 8/12/2010 17.03 79.83 57,388 Design 3A-17AL2-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -40.40 0.00 0.00 330.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,600.00 83.79 81.30 6,044.44 -1,773.99 3,633.63 0.00 0.00 0.00 0.00 7,640.00 95.79 81.30 6,044.59 -1,767.95 3,673.10 30.00 30.00 0.00 0.00 7,670.00 103.55 76.69 6,039.55 -1,762.32 3,702.10 30.00 25.89 -15.38 330.00 7,700.00 107.91 68.50 6,031.41 -1,753.72 3,729.63 30.00 14.52 -27.28 300.00 7,730.00 104.64 59.77 6,022.99 -1,741.16 3,755.50 30.00 -10.88 -29.13 250.00 7,786.00 89.99 51.46 6,015.86 -1,709.84 3,801.13 30.00 -26.17 -14.84 210.00 8,086.00 90.30 321.46 6,014.89 -1,441.46 3,831.51 30.00 0.10 -30.00 270.30 8,386.00 90.24 285.46 6,013.42 -1,278.78 3,585.31 12.00 -0.02 -12.00 270.00 8,511.00 85.40 271.24 6,018.19 -1,260.67 3,462.08 12.00 -3.87 -11.37 251.00 8,811.00 87.04 307.29 6,038.63 -1,163.45 3,184.22 12.00 0.55 12.01 88.70 8,911.00 87.11 319.30 6,043.75 -1,095.09 3,111.67 12.00 0.06 12.02 90.00 9,300.00 88.02 272.59 6,061.27 -929.79 2,771.81 12.00 0.23 -12.01 270.00 8/16/2010 2.07:13PM Page 2 COMPASS 2003.16 Build 69 Iv' ConocoPhillips WU Conoco Phillips Planning Report BAKIR HUGHIS Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 , Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wei l bore: 3A-17A L2-01 Design: 3A-17AL2-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +Ei-yy Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°i100ft) (°) (ft) (ft) 7,600.00 83.79 81.30 6,044.44 -1,773.99 3,633.63 -3,353.13 0.00 0.00 5,995,274.38 511,297.90 TIP-KOP 3A-17AL2 7,640.00 95.79 81.30 6,044.59 -1,767.95 3,673.10 -3,367.64 30.00 0.00 5,995,280.45 511,337.35 2 7,670.00 103.55 76.69 6,039.55 -1,762.32 3,702.10 -3,377.27 30.00 -30.00 5,995,286.11 511,366.35 3 7,700.00 107.91 68.50 6,031.41 -1,753.72 3,729.63 -3,383.58 30.00 -60.00 5,995,294.74 511,393.86 4 7,730.00 104.64 59.77 6,022.99 -1,741.16 3,755.50 -3,385.64 30.00 -110.00 5,995,307.33 511,419.72 5 7,786.00 89.99 51.46 6,015.86 -1,709.84 3,801.13 -3,381.33 30.00 -150.00 5,995,338.69 511,465.32 6 7,800.00 90.01 47.26 6,015.86 -1,700.73 3,811.75 -3,378.75 30.00 -89.70 5,995,347.81 511,475.93 7,900.00 90.16 17.26 6,015.70 -1,617.12 3,864.52 -3,332.73 30.00 -89.70 5,995,431.46 511,528.60 8,000.00 90.27 347.26 6,015.32 -1,518.34 3,868.41 -3,249.12 30.00 -89.75 5,995,530.24 511,532.39 8,086.00 90.30 321.46 6,014.89 -1,441.46 3,831.51 -3,164.10 30.00 -89.86 5,995,607.07 511,495.41 End 30 deg DLS 1 8,100.00 90.30 319.78 6,014.81 -1,430.64 3,822.62 -3,150.28 12.00 -90.00 5,995,617.88 511,486.52 8,200.00 90.29 307.78 6,014.30 -1,361.59 3,750.55 -3,054.44 12.00 -90.01 5,995,686.86 511,414.38 8,300.00 90.27 295.78 6,013.80 -1,309.02 3,665.70 -2,966.49 12.00 -90.07 5,995,739.33 511,329.48 8,386.00 90.24 285.46 6,013.42 -1,278.78 3,585.31 -2,900.12 12.00 -90.13 5,995,769.48 511,249.07 8 8,400.00 89.70 283.87 6,013.43 -1,275.24 3,571.77 -2,890.27 12.00 -109.00 5,995,773.01 511,235.53 8,500.00 85.82 272.50 6,017.35 -1,261.03 3,473.05 -2,828.61 12.00 -109.00 5,995,787.12 511,136.80 8,511.00 85.40 271.24 6,018.19 -1,260.67 3,462.08 -2,822.82 12.00 -108.55 5,995,787.46 511,125.84 9 8,600.00 85.72 281.95 6,025.10 -1,250.49 3,374.07 -2,769.99 12.00 88.70 5,995,797.55 511,037.82 8,700.00 86.26 293.97 6,032.12 -1,219.78 3,279.35 -2,696.04 12.00 87.87 5,995,828.16 510,943.08 8,800.00 86.96 305.97 6,038.05 -1,170.01 3,193.03 -2,609.77 12.00 87.03 5,995,877.84 510,856.72 8,811.00 87.04 307.29 6,038.63 -1,163.45 3,184.22 -2,599.69 12.00 86.31 5,995,884.39 510,847.90 10 8,900.00 87.10 317.98 6,043.19 -1,103.34 3,118.93 -2,514.98 12.00 90.00 5,995,944.43 510,782.55 8,911.00 87.11 319.30 6,043.75 -1,095.09 3,111.67 -2,504.21 12.00 89.45 5,995,952.67 510,775.29 11 9,000.00 87.16 308.61 6,048.21 -1,033.48 3,047.77 -2,418.91 12.00 -90.00 5,996,014.21 510,711.34 9,100.00 87.33 296.60 6,053.03 -979.76 2,963.78 -2,330.39 12.00 -89.46 5,996,067.84 510,627.30 9,200.00 87.62 284.59 6,057.45 -944.69 2,870.44 -2,253.34 12.00 -88.88 5,996,102.81 510,533.93 9,300.00 88.02 272.59 6,061.27 . -929.79 2,771.81 -2,191.13 12.00 -88.35 5,996,117.60 510,435.29 TD at 9300.00 1 8/16/2010 2:07:13PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips El ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature We l l bore: 3A-17AL2-01 Design: 3A-17AL2-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3A-17AL2-01 t1 0.00 0.00 6,015.00 -1,749.64 3,549.75 5,995,298.63 511,214.00 70°23'54.119 N 149°54'31.471 W -plan misses target center by 92.17ft at 7600.00ft MD(6044.44 TVD,-1773.99 N,3633.63 E) -Point 3A-17AL2,AL2-01 Fa 0.00 0.00 0.00 -751.02 3,034.74 5,996,296.63 510,698.02 70°24'3.942 N 149°54'46.546 W -plan misses target center by 6054.02ft at 8911.00ft MD(6043.75 TVD,-1095.09 N,3111.67 E) -Polygon Point 1 0.00 -751.02 3,034.74 5,996,296.63 510,698.02 Point2 0.00 -1,318.96 2,918.18 5,995,728.63 510,582.05 Point3 0.00 -1,910.76 2,652.57 5,995,136.61 510,317.07 Point 4 0.00 -1,318.96 2,918.18 5,995,728.63 510,582.05 3A-17AL2-01 t2 0.00 0.00 6,060.00 -891.72 2,736.56 5,996,155.63 510,400.01 70°24'2.560 N 149°54'55.283 W -plan misses target center by 51.89ft at 9300.00ft MD(6061.27 TVD,-929.79 N,2771.81 E) -Point 3A-17AL2,AL2-01 Fa 0.00 0.00 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 70°23'58.344 N 149°54'23.542 W -plan misses target center by 6014.84ft at 8200.00ft MD(6014.30 TVD,-1361.59 N,3750.55 E) I -Polygon Point 1 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 Point2 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 Point 3 0.00 -2,782.46 3,242.74 5,994,265.60 510,908.08 1 Point4 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 3A-17AL2,AL2-01 Po 0.00 0.00 0.00 -1,869.89 3,775.65 5,995,178.63 511,440.00 70°23'52.935 N 149°54'24.856 W -plan misses target center by 6018.04ft at 7786.00ft MD(6015.86 TVD,-1709.84 N,3801.13 E) -Polygon Point 1 0.00 -1,869.89 3,775.65 5,995,178.63 511,440.00 Point2 0.00 -1,414.01 3,945.11 5,995,634.64 511,608.97 Point 3 0.00 -757.69 2,653.62 5,996,289.57 510,316.94 Point 4 0.00 -954.61 2,559.42 5,996,092.57 510,222.95 Point 5 0.00 -1,585.86 3,777.93 5,995,462.64 511,441.98 Point 6 0.00 -1,769.65 3,539.72 5,995,278.62 511,203.99 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,821.00 3,223.24 7 5/8" 7-5/8 9-7/8 9,300.00 6,061.27 2 3/8 2-3/8 3 8/16/2010 2.07:13PM Page 4 COMPASS 2003.16 Build 69 ‘1) ConocoPhillips rj Conoco Ph '� illips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature W e l l b o re: 3A-17AL2-01 Design: 3A-17AL2-01_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,600.00 6,044.44 -1,773.99 3,633.63 TIP-KOP 3A-17AL2 7,640.00 6,044.59 -1,767.95 3,673.10 2 7,670.00 6,039.55 -1,762.32 3,702.10 3 7,700.00 6,031.41 -1,753.72 3,729.63 4 7,730.00 6,022.99 -1,741.16 3,755.50 5 7,786.00 6,015.86 -1,709.84 3,801.13 6 8,086.00 6,014.89 -1,441.46 3,831.51 End 30 deg DLS 8,386.00 6,013.42 -1,278.78 3,585.31 8 8,511.00 6,018.19 -1,260.67 3,462.08 9 8,811.00 6,038.63 -1,163.45 3,184.22 10 8,911.00 6,043.75 -1,095.09 3,111.67 11 1 9,300.00 6,061.27 -929.79 2,771.81 TD at 9300.00 8/16/2010 2:07:13PM Page 5 COMPASS 2003.16 Build 69 1 I e .g ry N Ate. o r. ; ; z ° �■■■I Z_GE\► 7 8 ■ LII / � a 1 l i 4 ' • •••W/■ A - m I■II/■■■■�i WV _ ! 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Z Mil 11 ° iliPJIi5Iii,t 1 � a 11 '�/�I■■■■■I/a ► �_� ■ � M c, , i § , 1m \ I ,; 11 V II• ■`i■ . 3 Al IVA 11 A' 1 IIIINIFIN/11111/1" '748 ►\mumml■■■■!■■■■i %■...... ,-,- -i , \■-`_■I,..■■.I/._■ .- ,` : 0:M 4� O \ ��%•��M%�■ ■ " s Ynoai g- a 3^ Iii1HIIUi pp,iiip Pr" a \ ,- o o .< s s A ow OS I)(1)quoN/(-)q nos O O V r Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing ' Lubricator Riser Annular/ Blind/Shear 2"Pipe/Slip(CT) Pump into Lubricator f�/IJ • above BHA rams -1/1441 p Q -4 -.7 1 I Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) Kill •><D<J LB.El - •,.. 1 r lgr' Blind/Shear 2"Pipe/Slip(CT) Choke 2 I Swab Valves ANL Wing Valves ���4Ai Tree Flow Cross 0 Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi IN Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union TRANSMITTAL LETTER CHECKLIST WELL NAME /</ -/-' 3 A - /7/q PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Kyie--r_,z, / �j/ POOL: z � a✓, � % � ( ' Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellb re segme t of existing well (If last two digits in Permit No. 2-It, 1/3 ,API No. 50-/52-``/- 2.2%,/ -6/ 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 L !L J To co a) a U) U) a) a ai o a o m o• _ C N C _c 0 Q 0 0 a 2 a) a) _ N - in C C - a) O 7 7, N 7 O) - O C a) -C _ca. 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