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210-158
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. cQL Q - 1 53 Well History File Identifier Organizing (done) x/w o-sided III 111111111111111 ❑ Rescan Needed Ill II II II Il I 1111111 RES AN DIGITAL DATA OVERSIZED (Scannable) C Ior Items: ❑ Diskettes, No. ❑ Maps' Greyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner L 03s ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: / ❑ Other:: BY: AD Date: 4/ ` �' /s/ rylio 1 Project Proofing I IIIIIIIIIIII I BY: Maria Date: 14/7//q— /s/ ill P Scanning Preparation o x 30 = (p0 + I = TOTAL PAGES (p ` / (Count does not include cover sheet) vyl BY: 62..A21ia..) Date: //4 /s/ Production Scanning II 11E1111101W Stage 1 Page Count from Scanned File: g..- (Count does include cover heet) Page Count Matches Number in Scanni /g-�Preparation: YES NO BY: `_ Date: '/ !� /s/ ryi p 1 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. 111111111111111111 ReScanned 1111111111110111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 1111111111111 III 0 o c m oa m Q mu_ ✓ m Cema Tr 0 baa Nct U(n O N _ >N . Ce dCe N 'i 0 E a a g tnEf: rt C[c- o g o 2 2O -J(.2 0 a 2 0 > ¢ m z o c 2 2 1-- 0c U0 E.• I. To o v 0 0 >I Z La.. d0 N O. N N N 0d H m O o ce a-- Ni- -- Z > I J M M M M - - H EO N Q > �_ c c c C c C E Y �u C Z`a a o. a o. o. �/ Q )_Nc 00000000 0 Q a co2 1 0 O J V - R N o 0 0 0 0 0 0.y a Z Z C. ., Z \ l.J'' J W �/ o rn rn o 0 0 co y Z U 2 ago 20 m m m n cs, v W z z ' 0 U0 Z 8 C 0 cc o QS Z ' F _ R g c l a " o � J 0. ca co 'f i 0 CT E' a zl ) N o J i 21 11 N 2 — N N H N ON a ° 1 al Ei 0 o N n Ln / . C.) co ~ J Q LQ N 1"" O Oa 1— O 5 co G Z N — � CV CV C D V 2 Cl) a o cn d0 ' S II • m < ZI co At > L` Z EO a 0 N ? .? .? .? 0) 0 co Z N y N N E J 1 7 7 C) N N N CO 0 coco z Til f6 0 c c cc 0) O 0 O O O 0 E R'.0 0 > 0 0 > C 0 0 c0 1 d' Z Q c c c E '- co z o o) E O o J ya w to y E r c OQ Z .t.. C W O N N a' R-3-' X t N 2 O O « _d 0 HCC i t0 a+ , a0) Li. I O a O E E 1 I E E ? v .` r Z r2 V to N N <0 f0 J co a Q V C _O Q J co Z Q 'O O d Z , U n, +� r I 1 C Z W 0 r2 U \ ` ss 0 O O H 0 N E 1 Q ami o , ] > \ .`J V p U a ? E p C7 ►- a d as'� a c O o 0 o O y oa5 z c N o n re o 3 3 o �1 WW J J --/ W 3 a 0 a CL 1 0 O O O <O rt d. N ›- Cil N U_ N 5 0 in o Z Y. Q z1 0 a C..) ai ta R LL Q y O " a CL .7., U J_ W = et a O U W 0 2 z Q it. _ N J Q ro 13- O u) N cc NN a VN U ti J IJ 0 Q a c 701 o .4.., Q a Q p U O co o co in I- m O -a0 3 N d 0) a. 0 N. u O O C a+ (0 a+ .Q a O a 2 U STATE OF ALASKA (4 ALASKA _AND GAS CONSERVATION COMMISSk `. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Perforations E Stimulate r Other 17 Prod to WAGINJ Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program l Operat.Shutdown E Perforate r" Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 210-158-0 1 3.Address: 6.API Number: Stratigraphic r Service r O P. O. Box 100360,Anchorage,Alaska 99510 " 50-029-22544-60+40 7.Property Designation, Lease Number): 8.Well Name and Number: ADL 25646,25645 ` 2Z-23AL1 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 10677 feet Plugs(measured) None true vertical 6050 feet Junk(measured) None Effective Depth measured 10677 feet Packer(measured) 7289, 7299, 7313, 7500, 7500 true vertical 6050 feet (true vertucal) 5741, 5748, 5759, 5899, 5899 Casing Length Size MD ND Burst Collapse LINER AL1 2601 2.625 10677 6050 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 8087-8447, 8443-10677 ` - EC EI A True Vertical Depth: 6077-6062, 6062-6050 ! n�,t/ED Tubing(size,grade,MD,and TVD) 2.875, J-55, 7596 MD, 5948 TVD , � I & Gay :8862- . or+amission Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO W-1 SELECTIVE LANDING NIPPLE @ 7289 MailendtferVgiVD PBR-BAKER PBR @ 7299 MD and 5748 TVD PACKER-BAKER'NFL' RETRIEVABLE PACKER731 and 5759 TVD WINDOW'A-SIDETRACK WINDOW @ 7500 MD and 5899 TVD WHIPSTOCK-BAKER WHIPSTOCK PRE-CTD; 2.7 DEGREES, LOHS @ 7500 MD and 5899 TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 271 455 330 1198 184 __ Subsequent to operation 0 2799 633 2166 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic IT 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations GSTOR E WIND r WAG , GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: /� �p `/ r. 311-185 Contact Kelli Wilmot Atie.A.,' (tiPrinted Name Kelli Wilmot Title Drilling &Wells Engineering Technician Signature Phone:265-6309 Date:7/13/11 Form 10-404 Revised 10/2010 RBDMS JUL 14 7 /.1^7 _ f r ii/,S bmit Original Only ` . 2Z-23AL1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/16/11 DRIFT TBG TO 2.80" &TAGGED LINER TOP @ 7462' RKB. MEASURED SBHP @ 7450' RKB (2203 psi) & GRADIENT @ 7316' RKB (2197 psi) SET 2.81" MA-2 PLUG @ 7288' RKB. P/T TBG TO 2500, PASSED. IN PROGRESS 6/17/11 Summary PULLED OV @ 7245' RKB. LOAD TBG & IA W/245 BBLS DIESEL. SET DMY VLV @ 7245' RKB. MITIA TO 3000 PSI, PASSED. PULLED 2.81" MA-2 PLUG @ 7288' RKB. COMPLETE 6/22/11 MITIA(Passed), Initial T/I/O= 2160/175/180. IA FL @ NS. Pressured up IA with 4 bbl of diesel, Start MITIA. T/I/O= 2160/3000/260 15 min T/I/O=2160/3000/260, 30 min T/I/O= 2160/3000/260. Bleed IA down, Final T/I/O= 2160/900/180. 6/22/2011 PM Initial State Witnessed MITIA- Passed, (John Crisp). Initial T/I/O= 2270/980/160, Pressured up IA to 3000 psi with 2.4 bbls of diesel. Start MITIA, T/I/O= 2270/3000/260, 15 min T/I/O= 2270/2860/250, 30 min T/I/O= 2270/2820/245,bleed IA down. Final T/I/O= 2270/425/120. SII • Lo c O 113 00 N p iC) < 0 0 H CO i., 4- N I I \\ N N J t` .D II \\ a oo I� N I I \\ a I-- N- J oO — a) II \\ .2 a To o Q N— p 11 \\ t o 1 o a N I I N 11 \\ J o 2 • Z 1 O U \\ \\ N 11 L E N p 11 \\ Nos = iv N I— Cn Q \\ \\ .4 a co- m o .E \\ \1 co _ Y \1 1\ co w0i 11 CL Y u N - N II II U N N CO N- CI- CK m CO , CO u, - o N Y Y o m ih Ch a Co Ce ty '^ // // C., m m _a m Y r- (D N. m // ii ) la E E w o c @�(N- �r-` a) Y 1/ i/ To " 4) a Cl)co ca -UcL a) N M C) (Da) al w .E ; 11 // c I ' o gnW. .E D 0 0) uo) @)N- r U u' 0 co c�5 \\ Ii it o a 0 m - 2 N N — \\ I I I I -I o E- Lo a " �o - Y z - \\ II - eD oo ) co) c°� No_ o ,- --- @ X a) I/ I I 4 a W N c•) as N = c m N Q. — - a- o _ I a 8 c U rn U U co a. U U x in O / ,= I t•11:4 No22 N N N N Y Y N E N - N // // H to m r r e- N ro r- (a f i0i t i i� C.) i i 0 I III i 1� I, / // 4A AO o i I •L I ►� T ,. • / ter--- u) lEn-Irl CL N • QI e• - - a i it t III !H CI r N I emm22 N g Q CD D I W J `mwwww bco _..- cc W O CSD N in u1 <D O) CJ J r�n�n� r 4) n a0 an a0 m N a r- N- _1ct V -J� g Naob NCO aD a) ur a0 LC) y I,- U) - m N 22 "9L �°7vv < NI i- r` 1 � o) w ar` r` N N N cfl ` join - m o v M N N N 11 SITAUE OF ALASKA 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 Darrell R. Humphery Production Engineering Specialist ' [' ConocoPhillips Alaska, Inc. II a — `J " P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2Z-23AL1 Sundry Number: 311-185 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this z day of June, 2011. Encl. al • T STATE OF ALASKA n,v�� l EC EIV ALASKA ulL AND GAS CONSERVATION COMMISSION I 1 APPLICATION FOR SUNDRY APPROVALS` 6 vt MAY 2 6 2011 20 MC 25.280 1.Type of Request Abandon r Rug for Redrill r Porforate New Pod r Repair wet AlackedittilaisaFgeniki OM mission Suspend r Rug Porforations r Perforate f Rill Tubing r D Operational Shutdown Re-enter Susp.WellGN ❑ p r stimulate r Alter casing [,� Other:Prod to WAGINJ p- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Devebpment FA Exploratory r 210-158-0 " 3.Address: Stratigraphic r Service e.API Number. P.O.Box 100360,Anchorage,Alaska 99510 50-029-22544-60 ' 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number where ownership or landownership changes: Spacing Exception Required? Yes r No [J 2Z-23AL1 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25646,25645 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(o): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10677 6050 , 10677' 6050' Casing Length Size MD " TVD Burst Collapse LINER AL1 2601 2.625 10677' 6050' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8087-8447,8443-10677 6077-6062,6062-6050 2.875 J-55 7596 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) NIPPLE-CAMCO W-1 SELECTIVE LANDING NIPPLE MD=7289 TVD=5741 PBR-BAKER PBR MD=7299 TVD=5748 PACKER-BAKER'HFL'RETRIEVABLE PACKER MD=7313 TVD=5759 WINDOW'A'-SIDETRACK WINDOW MD=7500 TVD=5899 WHIPSTOCK-BAKER WHIPSTOCK PRE-CTD;2.7 DEGREES,LOI.MD=7500 ND=5899 SSSV-None 12.Attachments: Description Summary of Proposal d; 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development 17 Service 1 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2011 Oil r Gas r WDSPL ❑ Suspended r 18.Verbal Approval: Date: WINJ r GINJ r WAG 1 Abandoned r Commission Representative: GSTOR r SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Darrell Humphrey/Bob Christesen Printed Name Darrell R.Humphrey Title: Production Engineering Specialist Signature ��,, e 4. - Phone:659-7535 Date 6---,2,.G`, /C �^� Comm Ion Use Only Sundry Number. 3\l--''S Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical IntegrityTest)( Location Clearance r Other. Subsequent Form Required: /8 — 7 O y APPROVED BY f7. Approved by: COMMISSIONER THE COMMISSION Date: 1 " . RS. /SJUN i6,. 1.1( _,X. 5-/,_ /4 r • N 2Z-23AL1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 2Z-23A,2Z-23AL1, 2Z-23AL1-01 from Oil Production service to WAG Injection service.Well 2Z-23A will be used for reservoir pressure support for 2X- 18. The 16"Conductor was cemented with 200sx ASI (121'and/121'tvd). The 9-5/8"Surface casing (4242' and/ 3474'tvd)was cemented with 890sx AS III, and 480sx Class G. The 7" Production casing (7960' and/6232' tvd)was cemented with 338sx Class G. The top of the Kuparuk B was found at 7500' and/5899'tvd. The top of the Kuparuk A was found at 7792' and/6028'tvd. The injection tubing/casing annulus is isolated via Baker'HFL" retrievable packer 3.5"located @ 7313' and/ 5759'tvd. 11/29/10 An MIT-TAG CMT @ 7395'SLM . MIT TBG#2500, PASS. COMPLETE. START MIT, (TBG#300, IA#225, OA#0), TBG#2525, IA#225, OA#0, WATCH 15 MINS, TBG#2450, IA#225, OA#0, WATCH 15 MINS, TBG#2430, IA#225, OA#0, **PASS** tveN �O�.�rrd'—t el to A4 col :4/ec rais 10 Te5er-'e5 °ew rep rd, 0 . ; t r- t 4 C 1 d , . 1. KUP 2Z-23AL1 ConocoPhillips . . e Attributes .4 Angle&MD TD Alaska, Wellbore API/UWI Field Nam. Well Status reel(') MD lhRB) Act Btm(MB)�. �1i1Np, 500292254460 KUPARUK RIVER UNIT INJ 100.65 9,400.46 10,677.0 Comment H2S(ppm) Date Annotation End Date KB-lard(ft) Rig Release Date walCongo:-2z-z3AL1,17J92D111zaos4 PM —SSSV:NIPPLE Last WO: 40.60 2/12/1995 Schematic•Muni Annotation Depth MKS) End Date Annotation Last Mod... End Date Last Tag:SLM Rev Reason:GLV C/O Imosbor 1/29/2011 Casing Strings Casing Description String 0... String ID...Top MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,37 L . LINER AL1 2 318 1.995 8,076.1 10677.0 6050.3 4.60 L-80 STL Liner Details Top Depth (TVD) Top Incl Noml... Top(ftKB) (ftKB) I") Item Description Comment ID(In) 8,076.1 6,077.4 90.12 BILLET Anchored Billet 1.995 _ 8,085.1 6,077.1 90.62 ANCHOR Open hole anchor 1.995 11 8,447.5 6,061.6 89.31 DEPLOY Shorty Deployment sleeve 1.995 CONDUCTOR, Perforations&Slots 41-121 Shot Top(TVD) Btm(TVD) Dens 1. Top(ftKB) Btm(MB) (MB) (ftKB) Zone Date ("iii Type Comment 8,087.0 8,447.0 6,077.1 6,061.6 12/22/2010 32.0 SLOTS slotted pipe-0.125"x2.5"@ 4 NIPPLE.493 1 circumferential adjacent rows,3" I centers staggered 18 deg,3' non-slotted ends 8,443.0 10,677.0 6,061.6 6,050.3 12/22/2010 32.0 SLOTS slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends SU41.4,242 `RFACE. I Notes:General&Safety End Date Annotation mr 12/27/2010 NOTE:WELL SIDETRACKED 2Z-23A,AL1,AL1-01 IF GAS LIFT, 1/1/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 7,246 IL R-. MI III NIPPLE.7,289 •tee PBR,7,299 PACKER,7,313 :-t— INJECTION, 7,357\ [PERF, 7,400-7,418 !PERF, 7,445-7,495 WHIPSTOCK 7,500 WINDOW A., 7,500 SLEEVE-C, 7,553 LOCATOR, 7,589 PACKER,7,571 - NIPPLE,7,587 SOS,7,596 CMR PLUG, 7.395 STAGE 1, 7,395 PRODUCTION, 35-7,960 f SLOTS, \ SLOT 7,9 5 SLOTS, "BLOW,SLOTS, 87\_11(Iiii LINER,8 L LINER AL o 77Z-2213AT TL Mandrel Details 10,677 Top Depth Top Port LINER A 7,90310,810 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top MAN) (ftKB) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 7,245.6 5,708.9 41.61 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 1/15/2011 2 7,357.3 5,792.1 41.37 CAMCO MMM 1 1/2 INJ DMY RK 0.000 0.0 10/20/2010 PRINT DISTRIBUTION LIST BAKER HUGHES COMPANY CONOCOPHILLIPS ALASKA,INC. INTERMEDIATE FINAL Yes (mandatory) WELL NAME RUN NUMBER (mandatory) FIELD KUPARUK RIVER UNIT BH SALESMAN (mandatory) (mandatory) COUNTY NORTH SLOPE BOROUGH BH DISTRICT (mandatory) (mandatory) STATE ALASKA PAGE OF (mandatory) -- LOG DATE: TODAYS DATE: (mandatory) DISTRIBUTION LIST AUTHORIZED BY: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY E-LOG E-LOG ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) FIELD FINAL LAS (CD) LIS (CD) FILM PERSON ATTENTION #OF PRINTS #Of- I HIN I S#OF COPIES#OF COPIES#OF COPIES 1 I ConocoPhillips Alaska,Inc. I 1 I 1 I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 C Street, Anchorage,AK 99501 2 AOGCC I 1 I I 1 I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 O/U abs 3IBP I 1 I I 1 I Petrotechnical Data Center,MB33 David Douglas I P.O.Box 196612 n' Anchorage,Alaska 99519-6612 010— is-8 a 026 4ICHEVRON/KRU REP I 1 I I 1 I Glenn Fredrick P.O.Box 196247 ' /4// Anchorage,Alaska 99519 � � 010-(4404 5 Brandon Tucker,NRT I I I I 1 I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 I �I TOTALS FOR THIS PAGE: C 4 4- TOTALS TOTALS FOR ALL PAGES: 0 4 0 4 McMains, Stephen E (DOA) From: NSK Prod Engr Specialist[n1139@conocophillips.com] Sent: Tuesday, February 08, 2011 1:34 PM To: McMains, Stephen E (DOA) Subject: Request for changes to 2Z-23A, 2Z-23AL1, and 2Z-23AL1-01 Well Completion Report Importance: High Steve, We are requesting a correction to the recently submitted 10-407's on wells 2Z-23A(PTD 210-157), 2Z-23AL1 (PTD 210- 158), and 2Z-23AL1-01 (PTD 210-184). Specifically, we are requesting a status change from 1WINJ to 1-OIL as these injectors are to be pre-produced for a minimum 60 days with production potentially continuing for an indefinite period. First production is planned to start within 5 days. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska,Inc. Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: N5K-69 This email may contain confidential information.If you receive this e-mail in error,please notify the sender and delete this email immediately. 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: ON] ,, Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 1 WAG ❑ WDSPL ❑ No.of Completions: , Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,- sW) 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: Nover 27,2010 210-158/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 13,2010 50-029-22544-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1304'FSL,334'FEL,Sec. 11,T11 N,R9E,UM December 21,2010 2Z-23AL1 Top of Productive Horizon: 8.KB(ft above MSL): 112'RKB 15.Field/Pool(s): 2443'FSL,888'FEL,Sec. 10,T11 N,R9E,UM GL(ft above MSL): 70.6'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2508'FNL, 1784'FEL,Sec. 10,T11 N,R9E, UM 10677'MD/6050'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-529376 y- 5966062 Zone-4 10677'MD/6050'ND ADL 25646,25645 TPI: x-523537 y- 5967180 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-522640 y- 5967507 Zone-4 landing nipple©493'MD/491'ND 2577,2576 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1331'MD/1268'ND 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 7903'MD/6064'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE - WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# 1-40 Surf. _ 121' Surf. _ 121' 24" 200 sx AS I 9.625" 36# J-55 Surf. 4242' Surf. 3474' 12.25" 890 sx ASIII,480 sx Class G 7" 26.0# L-80 Surf. 7960' Surf. 6232' 8.5" 338 sx Class G 2.375" 4.6# L-80 8076' 10677' 6077' 6050' 3" slotted liner 24.Open to production or injection? Yes ❑ No 0 If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 7597' 7313'MD!5759'ND slotted liner 7571'MD/5939'ND . c Sac 8087'-8447'MD 6077-6062'ND `> 1'� o erg 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 8443'-10677'MD 6062'-6050'ND ! /,'.,e-v DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7'4" 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) shut-in Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. l �°� al 0 NONE 'a�'`L. Ir JAN 2 0 2011 ` p Form 10-407 Revised 12/2009 RBDMS JAN 2 0 201f ONTINUED ON REVERSE ?�� 5�� el C1IDD� aIW'�4 ; ..,$$�Qn 0-1-// Ancnrrdge ,- ..9,67(r G 28. GEOLOGIC MARKERS(List all formations and market.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 1331' 1268' needed,and submit detailed test information per 20 AAC 25.071. A3 9335' 6060' A4 9350' 6058' A5 9516' 6034' A4 9720' 6043' N/A Formation at total depth: Kuparuk A4 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: Jill Long @ 263-4093 0t0lV) I Printed NaCa Title: Alaska Wells Manager 1a /U1) Signature Phone 263-4619 Date V !(/ 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 ND 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 KUP 2Z-23AL1 ConocoPhillips well Attributes Max Angie&MD TD Nark. Wellbore APWWI P1.14 Name Well Status Incl MD KB Act Bim KKB ,�. I 500292254460 I KUPARUK RIVER UNIT I INJ j-10065 1 9,400.46 10,6770 C ent N25(ppm) (Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV NIPPLE 11 Last WO: 11 40 60 2/12/1995 Wen CPA.-969 4l/+ ,,,911 221,$Pni --- ---- - - Annotation [Depth ftKB) End Date Annotation Last Mod.. End Date � �Awl___._, __ Last Tag:SLM _-_ 'Rev Reason:SIDETRACK w/LATERALS Imosbor 171/2011 Casing Strings Casing Description String 0... 'String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ,,ANGER,31 raj �`" LINER AL1 2 3/8 I 1 995 1 8,076.1 10,67/.0 6,050 3 4 60 L-80 STL Liner Details 1. Top Depth ' , (TVD) Top Inc! — Komi... Top(ftKB) (ftKe B) (°) awn Description Comment ID(in) 8,076.1 6,077.4 90.12 BILLET Anchored Billet 1.995 8,085.1 6,077.1 90.62 ANCHOR Open hole anchor 1.995 8,447.5 6,061.6 89.31 DEPLOY Shorty Deployment sleeve 1.995 CONDUCTOR, !' Perforations&Slots a1-121 - Shot Top(TVD) Bim(TVD) Dens Top(ftKB)Ban(ftKB) MKIM ( ) Zona Dab (ah--- Type Comment 8,087.0 8,447.0 6,077.1 6,061.6 12/22/2010 32.0 SLOTS slotted pipe-0.125"x2.5"@ 4 NIPPLE.493 I I. circumferential adjacent rows,3" -,, centers staggered 18 deg,3' non-slotted ends 8,443.0 10,677.0 6,061.6 6,050.3 1222/2010 32.0 SLOTS slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3" •I centers staggered 18 deg,3' non-slotted ends S 4742 2 Notes:General&Saf. ; .j : _ ' End Date Annotation 12/27/2010 NOTE:WELL SIDETRACKED 2Z-23A,All,AL1-01 1/1/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS UFT, - -- 7,246 NIPPLE,7,289 _f ill PBR,7,299 I PACKER,7,313 - irINJECTION. 1 .. 7,357—. -.. 1PERT, 7,400-7,418 'PERF,EFtF, 7,4M' WHIPSTOCK, 7,500 WINDOW A'7,500, I SLEEVE-C, ` 7,553 LOCATOR, 18, 7,569 PACKER,7,571- NIPPLE,7,581- i II?, SOS 7,596- •CMT PLUG, 7,395 STAGE 1, 7,395 PRODUCTION, 35-7,960 - (0 BB- '- if t • SLOTS, 7,923-8,445 SLOTS,OTS, 8,087-8,447 SLOTS, 8,443-10,677 LINER AL1, 8,076-10,677 TD(2Z-23AL1), = "- 10,677 ___._ - - Top Depth Top 1 Port LINERi �,, � (TVD) Ind OD Valve Latch Sit. TRO Run 7,903-10,810 it 8\ , Sin Top)ftKB) (ftKB) (( Make Model (in) Sery Type TIT. (in) (psi) Run Date Corn... 1 7,245.6 5,708.9 42.11 CAMCO MMG-2 1 12 GAS I.IFI DMY RK 0.000 0.0 5/6/1995 2 7,357.3 5,792.1 41.50 CAMCO MMM 1 12 INJ 'DMY RK 0.000 0.0 10/20/2010 i I w '„I I c:\ \ I \\\ W E m I \\ om _ o a o 0 1 \\ .1. R Q 0 a ~0D \ \\E Do _ o E. ° 11 ° 1 \\ 3 m 2ZJ c N D \\ \\ M o y E. Q j p= N N Q C_ Q o'_m N \\ \\ N F-CO Q N " V o 1\ co m N Y = E i 2 O5 \11 \1 Y CO ib Q to- II 11 II0ED Et M v ))i) CA 00 I CO I CO � o Ce c.., Y 00 // / Y ° o -o // / iZ Ua r— CD Y q a) ° u N m a°i a� w c 11 // m � Lu 0 5 2 0 3 C LI \\ I �° I • e • o E J Q L a 8 a N - - z \\ I I so O M O O - Q U U X OI I m E Xk N J co . N I a o-0 m (0 co (0 (0 ' = (0 co CV - I `\` I Q rn a 0 O o 0 0 tri u_ U ° x w- O . Ili I c'p 11.2 m CV N N CV Y Y N N CV CV 1j �� I cN~ m m r CZ CO CO _ e- r- I I M M M M m m M C I i co D i i i i IlIlI ` ,a+g. 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Depth Phase Code Subcode T Comment 12/02/2010 24 hr Summary Arrived @ 2Z-23 @ 16:00 MIRU 06:00 16:00 10.00 MIRU MOVE MOB P Move CDR 2 from 3-k to 2Z Pad 16:00 00:00 8.00 MIRU MOVE MOB P Arrive on 2Z Pad, Spot drilling sub and mud pits.MIRU 12/03/2010 Rig maintenance, Change skates. Start testing BOP equipment. State witness waived by Chuck Scheve. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Continue to rig up 05:00 15:30 10.50 0 0 MIRU RIGMNT RGRP P Unstab coil, R&R Injector skates 15:30 16:00 0.50 0 0 MIRU RIGMNT RGRP P Injector complete, R/U to install pipe in injector 16:00 18:00 2.00 0 0 MIRU RIGMNT RGRP P PJSM to stab pipe 18:00 00:00 6.00 0 0 MIRU WHDBO BOPE P Test BOP equipment,State witness waived by Chuck Scheve Rig Accept 18:00 12/04/2010 Complete testing BOP, perform slack management, MU BHA and mill cement from 7387'to 7470' 00:00 06:00 6.00 0 0 MIRU WHDBO BOPE P Continue testing BOP equipment 06:00 09:00 3.00 0 0 MIRU WHDBO BOPE P PJSM, Pull BPV, R/D BPV lubricator and load out 09:00 09:30 0.50 0 0 MIRU WHDBO BOPE P Pressure test PDL 09:30 12:00 2.50 0 0 MIRU WELLPF SLPC P Seal end of a-line,stab on injector, Fill coil, perform slack mgmt PT and chart inner reel valve. 12:00 13:00 1.00 0 0 MIRU WELLPF SLPC P Cut 11 feet coil, Install CTC connector and pull test to 35K 13:00 14:42 1.70 0 0 MIRU WELLPF SLPC P Baker tested E-Line, Head up upper quick connect PT Coil connector to 4K,stab on well and verify no pressure 14:42 15:36 0.90 0 0 SURPRI WELLPF MILL P PJSM, P/U BHA#1Cement milling 0 degree motor and turned down Bi Center, Surface test tool 15:36 16:42 1.10 0 0 SURPRI WELLPF MILL T No surface test. Unstab and trouble shoot 16:42 16:54 0.20 0 0 SURPRI WELLPF MILL P Surface test tool. Problem traced to wire connector in PUTZ corridor, Open EDC, Set counters 16:54 18:54 2.00 0 7,387 SURPRI WELLPF MILL P Trip in well,displace FP diesel to TT with SW,Tie in to K1 at 7274',+2' correction. Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:54 00:00 5.10 7,387 7,470 SURPRI WELLPF MILL P Start used flo-pro for milling operations,dry tag cement at 7387'. Strt pumping at 1.4 BPM,3200 CTP, 390 down hole differential pressure. Start milling cement, numerous stalls, -20 FPH while milling 12/05/2010 Milled cement to 7500', milled two string window 00:00 02:00 2.00 7,470 7,500 SURPRI WELLPF MILL P Continue milling 02:00 04:00 2.00 7,500 0 SURPRI WELLPF MILL P POOH 04:00 04:30 0.50 0 0 SURPRI WELLPF MILL P Lay down cement milling BHA 04:30 05:00 0.50 0 0 PROD1 WHPST PULD P MU window milling BHA DSM is 2.80"go/2.79'no-go String Reamer is 2.79"go/2.78" no-go 05:00 06:45 1.75 0 7,295 PROD1 WHPST TRIP P RIH 06:45 06:51 0.10 7,295 7,314 PROD1 WHPST DLOG P Log K-1, +.5' 06:51 08:21 1.50 7,314 7,502 PROD1 WHPST TRIP P RIH to tag TOC,Stack out @ 7404 dry, Pumps on,stacked out @ 7412, Start working to bottom. mill cement to top of whipstock 08:21 14:57 6.60 7,502 7,508 PROD1 WHPST MILL P Call pinch point @ 7502, Start time milling 14:57 16:42 1.75 7,508 78 PROD1 WHPST TRIP P Made 6'past pinch point. Good metal filings on ditch magnets. POOH for 2 degree motor 16:42 18:42 2.00 78 74 PROD1 WHPST PULD P At Surface, PJSM while flow checking well for flow. LD BHA#2, Mill still 2.80",string reamer is still 2.79" PU BHA#3 with 2 deg fixed Weatherford motor and fat radius window mill at 2.80"go/2.79"no-go 18:42 20:12 1.50 74 7,295 PROD1 WHPST TRIP P RIH with EDC closed and pumping .25 BPM 20:12 20:24 0.20 7,295 7,507 PROD1 WHPST DLOG P Tie-in, +.5' 20:24 00:00 3.60 7,507 7,509 PROD1 WHPST MILL P 1.4 BPM, 3640 CTP, 780 free spin differential pressure at the BHA, Start time milling from 7507' 12/06/2010 Completed milling window,TOWS at 7500', RA marker at 7506', BOW at 7507. Drill build to land at 8120' 00:00 03:12 3.20 7,509 7,513 PROD1 WHPST MILL P Continue milling window,WOB dropped off at 7509.5'. Continue time milling at 1 FPH 03:12 04:36 1.40 7,513 7,520 PROD1 WHPST MILL P Drill ahead at-5 FPH,2K WOB, 3800 CTP 04:36 06:00 1.40 7,520 7,520 PROD1 WHPST REAM P Ream window, Up at 15,330, 60. Down at 15 deg. Dry Drift was clean 06:00 08:06 2.10 7,520 80 PROD1 WHPST TRIP P Trip out of well Page 2 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:06 08:36 0.50 80 0 PROD1 WHPST PULD P At surface, PJSM monitor well, lay down window milling BHA Mill 2.79 NoGo 08:36 09:12 0.60 0 62 PROD1 DRILL PULD P M/U BHA#4 "A"Lateral build 2.3 degree motor,Surface test tool 09:12 10:48 1.60 62 7,285 PROD1 DRILL TRIP P Trip in well 10:48 11:00 0.20 7,285 7,301 PROD1 DRILL DLOG P Tie in fora+.5'correction Close EDC 11:00 11:12 0.20 7,301 7,520 PROD1 DRILL TRIP P RIH to drill, Clean pass through window 11:12 13:48 2.60 7,520 7,670 PROD1 DRILL DRLG P 7520', Drill ahead 1.44 BPM @ 3420 PSI FS Start New Mud down Coil 13:48 14:42 0.90 7,670 7,670 PROD1 DRILL WPRT P Wiper to window, Log RA Marker @ 7506.25 Pull up and log K1 for no correction TOW=7500.2, BOW=7508 RBIH to drill 14:42 17:24 2.70 7,670 7,820 PROD1 DRILL DRLG P 7670' Drill Ahead 1.41 BPM @ 3626PS1 FS BHP=3866 17:24 18:06 0.70 7,820 7,820 PROD1 DRILL WPRT P Wiper to window, 31K PUW, 14K RIW 18:06 20:06 2.00 7,820 7,970 PROD1 DRILL DRLG P Continue drilling ahead, 1.3 BPM, 3600 CTP,3780 BHP with WOC 20:06 20:54 0.80 7,970 7,970 PROD1 DRILL WPRT P Wiper to window, 30K PUW, 14K RIW 20:54 00:00 3.10 7,970 8,110 PROD1 DRILL DRLG P Continue drilling ahead, 1.3 BPM, 3600 CTP, 3780 BHP with WOC 12/07/2010 Drilled"A"lateral to 8572' 00:00 00:12 0.20 8,110 8,120 PROD1 DRILL DRLG P Continue drilling ahead, 1.3 BPM, 3600 CTP, 3780 BHP with WOC 00:12 02:36 2.40 8,120 0 PROD1 DRILL TRIP P POOH, open EDC when above window 02:36 04:06 1.50 0 0 PROD1 DRILL PULD P Undeploy BHA 4 04:06 06:24 2.30 0 68 PROD1 DRILL PULD P Deploy BHA#5, Lateral Rib Steer w/ Bi-Center Surface test 06:24 08:00 1.60 68 7,290 PROD1 DRILL TRIP P Trip in well 08:00 08:12 0.20 7,290 7,308 PROD1 DRILL DLOG P Tie in for a-1'correction,Close EDC PUW=27K 08:12 08:42 0.50 7,308 8,120 PROD1 DRILL TRIP P Trip in hole, Clean pass through window 08:42 13:12 4.50 8,120 8,270 PROD1 DRILL DRLG P 8120', Drill Ahead, 1.4 BPM @ 3600 FS BHP=3878 Slow drilling 8140 to 8181,<10 FPH 13:12 16:00 2.80 8,270 8,270 PROD1 DRILL WPRT P Wiper to window with MADD pass from 8135 to 7523 PUW=28K 16:00 18:18 2.30 8,270 8,420 PROD1 DRILL DRLG P 8270', Drill Ahead 1.37 BPM @ 3060 PSI FS BHP=3883, RIW=12.6K Page 3 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:18 19:30 1.20 8,420 8,420 PROD1 DRILL WPRT P Wiper trip to window,29K PUW, 16K RIW, clean trip 19:30 22:24 2.90 8,420 8,570 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP,3857 BHP with WOC, 14K RIW 22:24 23:12 0.80 8,570 7,520 PROD1 DRILL WPRT P Wiper to window,29K PUW 23:12 23:24 0.20 7,520 7,550 PROD1 DRILL DLOG P Tie-in,-3' 23:24 23:54 0.50 7,550 8,570 PROD1 DRILL WPRT P Wiper back in hole 23:54 00:00 0.10 8,570 8,572 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3875 BHP with WOC, 14K RIW 12/08/2010 Drilled"A"lateral to 9190' 00:00 04:30 4.50 8,572 8,720 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3880 BHP, 14K RIW 04:30 06:00 1.50 8,720 8,720 PROD1 DRILL WPRT P Wiper trip to window, 30K PUW 06:00 10:45 4.75 8,720 8,870 PROD1 DRILL DRLG P 8720', Drill Ahead 1.33 BPM @ 3250 FS RIW=15K, BHP=3954 10:45 12:15 1.50 8,870 8,870 PROD1 DRILL WPRT P 8870 Wipe to window, PUW=31k 12:15 15:30 3.25 8,870 9,020 PROD1 DRILL DRLG P 8870', Drill Ahead 1.38 BPM @ 3380 PSI FS RIW=11.7K, BHP=4000,WOC 15:30 17:24 1.90 9,020 9,020 PROD1 DRILL WPRT P 9020',Wipe to window with Tie into RA for a+1 foot correction PUW=31 K 17:24 21:06 3.70 9,020 9,170 PROD1 DRILL DRLG P Continue drilling, 1.34 BPM,3600 CTP,4000 BHP, 10K RIW 21:06 23:18 2.20 9,170 9,170 PROD1 DRILL WPRT P Wiper to window, 29K PUW, 14K RIW 23:18 00:00 0.70 9,170 9,190 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM,3750 CTP, 4050 BHP, 10K RIW 12/09/2010 Drilled"A"lateral to 9722' 00:00 05:18 5.30 9,190 9,320 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM, 3750 CTP, 4050 BHP, 10K RIW Mud swap 05:18 07:48 2.50 9,320 9,320 PROD1 DRILL WPRT P Wiper to window PUW=32K, BHP=3922 07:48 11:36 3.80 9,320 9,393 PROD1 DRILL DRLG P 9320', Drill Ahead 1.39 BPM @ PSI FS BHP=3895 11:36 13:48 2.20 9,393 9,470 PROD1 DRILL DRLG P Pump lo hi vis sweep, Hi vis with drill zone No marked difference in ROP 13:48 16:18 2.50 9,470 9,470 PROD1 DRILL WPRT P Wiper trip to window, PUW=33K Tie into RA marker for a-1'correction Clean trip in and out 16:18 19:06 2.80 9,470 9,620 PROD1 DRILL DRLG P 9470, Drill ahead 1.4 BPM @ 3450 PSI FS BHP=3930 19:06 21:42 2.60 9,620 9,620 PROD1 DRILL WPRT P Wiper trip to window, 32K PUW, 14K RIW 21:42 00:00 2.30 9,620 9,722 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3940 BHP, 9K RIW Page 4 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12/10/2010 24 hr Summary Drilled"A"lateral to 10380' 00:00 01:24 1.40 9,722 9,770 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3940 BHP, 9K RIW 01:24 04:12 2.80 9,770 9,770 PROD1 DRILL WPRT P Wiper to window, 31K PUW, 14K RIW Clean trip 04:12 06:42 2.50 9,770 9,927 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3700 CTP, 3980 BHP, 10K RIW 06:42 09:42 3.00 9,927 9,927 PROD1 DRILL WPRT P 9927',Wipe to window with tie in for -2'correction PUW=32K 09:42 11:48 2.10 9,927 10,074 PROD1 DRILL DRLG P 9927', Drill ahead 1.39 BPM @ 3650'FS RIW=8K,WOB=1.7K, BHP=4029 11:48 14:48 3.00 10,074 10,074 PROD1 DRILL WPRT P wiper to window, PUW=29K 14:48 16:48 2.00 10,074 10,230 PROD1 DRILL DRLG P 10074', Drill Ahead 1.37 BPM @ 3600 PSI FS RIW=7K,WOB-1.5K, BHP=4040 16:48 20:06 3.30 10,230 10,230 PROD1 DRILL WPRT P 10230',wipe to window, PUW=29K 20:06 22:06 2.00 10,230 10,380 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3700 CTP,4060 BHP,8K RIW 22:06 23:54 1.80 10,380 7,525 PROD1 DRILL WPRT P Wiper to window,31K PUW 23:54 00:00 0.10 7,525 7,560 PROD1 DRILL DLOG P Tie-in,-3' 12/11/2010 Drilled"A"lateral to TD at 10810', condition hole 00:00 01:30 1.50 7,560 10,380 PROD1 DRILL WPRT P Wiper trip in hole,start mud swap while RIH. 14K RIW at window, down to 2-4K RIW at bottom 01:30 04:00 2.50 10,380 10,497 PROD1 DRILL DRLG P Drilling ahead, 1.4 BPM,3500 CTP, 3990 BHP with 50 WHP. Able to drill ahead at 4-8K surface weight with 1-2K WOB At 10496 started to stack weight, 100'wiper did not improve situation 04:00 07:30 3.50 10,497 10,497 PROD1 DRILL WPRT P Wiper to window, 34K PUW 07:30 11:45 4.25 10,497 10,650 PROD1 DRILL DRLG P 10497', Drill Ahead,Got back to hard spot able to get 3k DHWOB @-1 K surface weight 1.38 BPM @ 3350 PSI FS BHP=3962, Broke through @ 10,528 11:45 15:30 3.75 10,650 10,650 PROD1 DRILL WPRT P Wiper to window PUW=31 K Clean trip in and out. Little motor work @ 10525 going down RIW=4k 200'from bottom 15:30 18:12 2.70 10,650 10,775 PROD1 DRILL DRLG P 10650', Drill Ahead 1.4 BPM @ 3500 PSI FS RIW=-1.3 w/2.4K WOB, ROP=50 FPH Page 5 of 20 r • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 18:12 19:18 1.10 10,775 10,810 PROD1 DRILL DRLG P Stacking weight,pulled up hole to 10500', ran back in and able to drill ahead,-2K sufrace weight, 1 -2K WOB,with 200-300 motor work. 1.4 BPM,3550 CTP,4000 BHP 19:18 23:30 4.20 10,810 80 PROD1 DRILL WPRT P Pump Low/High vs sweeps and POOH for a wiper trip to the swab valve 23:30 00:00 0.50 80 2,500 PROD1 DRILL WPRT P RBIH 12/12/2010 Finished hole conditioning run and circulate well to 12.0 PPG KWF. Run lower liner section to TD at 10810. 00:00 01:00 1.00 2,500 7,250 PROD1 DRILL WPRT P Continue RIH for wiper to swab 01:00 01:12 0.20 7,250 7,300 PROD1 DRILL DLOG P Tie-in,-6' 01:12 03:12 2.00 7,300 10,810 PROD1 DRILL WPRT P Continue RIH 03:12 07:06 3.90 10,810 78 PROD1 DRILL TRIP P Tag TD at 10810',lay in 12.0 ppg liner running pill to wiindow then 12.0 ppg KWF while POOH 07:06 07:18 0.20 78 78 PROD1 DRILL SFTY P At surface, PJSM to lay down laterl drilling BHA#5 Monitor well for flow 07:18 08:18 1.00 78 0 PROD1 DRILL PULD P Lay down lateral drilling BHA#5 08:18 08:54 0.60 0 0 PROD1 DRILL BOPE P Function test BOPE 08:54 09:30 0.60 0 0 COMPZ CASING SFTY P R/U floor to run"A"lateral Liner, PJSM 09:30 12:30 3.00 0 0 COMPZ CASING PUTB P M/U"Eller"Guide shoe,72 Joints 2 3/8 Tubing For"A"lateral liner Perform BOPE Drill.good drill all hands responded properly 12:30 13:30 1.00 0 0 COMPZ CASING PUTB P Liner in well,M/U Coil track to liner While making up quickconnect a connection above slips below quick connect un tourqued. Undo quick connect and slide injector cart out of the way 13:30 15:00 1.50 0 0 COMPZ CASING PULD T Put lift nubbin on top of coiltrack. Latch up elevators. Bring elevators up to contact nubbin before opening slips Over pulled with top drive.Toolstring slipped up through deployment rams damaging EDC. Break down coiltrack replace EDC One and one half hours Nabors billable rig repair time 15:00 15:30 0.50 0 2,408 COMPZ CASING PULD P Stab injector onto coil track.Surface test 15:30 16:45 1.25 2,408 7,403 COMPZ CASING RUNL P RIH with lower section lateral"A" slotted liner Page 6 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:18 1.55 7,403 10,810 COMPZ CASING RUNL P Correct to flag, +5'correction PUW=31 K,Continue in hole 18:18 19:18 1.00 10,810 7,250 COMPZ CASING RUNL P Tag TD at 10814',Confirmed weights, 44K PUW,-3K WOB, 8K RIW, 3K WOB. Pumped off liner with 1.2 BPM,4000 PSI, 28K PUW,+1K WOB. POOH 19:18 21:06 1.80 7,250 0 COMPZ CASING PUTB P Tie in to K1 and correct depth,-2'. Continue POOH 21:06 21:18 0.20 0 0 COMPZ CASING SFTY P PJSM while checking well for no-flow 21:18 22:00 0.70 0 0 COMPZ CASING PUTB P Lay down inteq tools 22:00 00:00 2.00 0 0 COMPZ CASING BOPE T Blow down stack, changeout 2 3/8" deployment Rams *****1.5 hours Nabors billable rig repair time***** 12/13/2010 Ran upper liner with anchored aluminum billet in"A"lateral at 7903'. Kicked off billet and drilled"ALl"lateral to 8070'and tripped for lateral drilling assembly with resistivity and RSM 00:00 02:30 2.50 0 0 COMPZ CASING RGRP T Change out 2 3/8"Pipe/Slip rams to check for any damage due to pulling BHA into them. Tested rams to 200/3500 psi charted. ****4.5 hours Nabors billable rig repair time*** 02:30 02:48 0.30 0 0 COMPZ CASING SFTY P PJSM for PU liner 02:48 04:48 2.00 0 606 COMPZ CASING PUTB P PU 16 Joints slotted liner, pup joint, anchored billet, 543.56'. MU Inteq tools. 04:48 06:33 1.75 606 7,403 COMPZ CASING RUNL P RIH, BHA#7"A"Liner upper section 06:33 07:03 0.50 7,403 8,447 COMPZ CASING RUNL P Correct+2.8 @ EOP Flag, Close EDC PUW=30K, Continue in hole 07:03 07:15 0.20 8,447 8,447 COMPZ CASING RUNL P Tag Lower deployment sleeve, Set anchor @ 150 Left Pump and set anchor on upper section of liner BOL=8445',TOL=7902, overall BOL=10810 07:15 09:15 2.00 8,447 65 COMPZ CASING TRIP P Trip out of well after setting liner 09:15 10:00 0.75 65 0 COMPZ CASING PULD P Lay down Liner running tools, BHA#7 10:00 11:00 1.00 0 62 PROD2 STK PULD P P/U Drill by(Al Build)BHA#8. 1.1 degree bent motor Bi Center Bit. Install new database for this lateral 11:00 12:30 1.50 62 7,289 PROD2 STK TRIP P RIH, EDC closed 12:30 12:42 0.20 7,289 7,305 PROD2 STK DLOG P Tie in for a+2'correction OPen EDC to circulate out KWF Page 7 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:42 14:42 2.00 7,305 7,446 PROD2 STK CIRC P RIH just above window Pump Spacer /9.6 PPG Flo Pro Started out.5BPM In-.3 Out Started with 205 BBIs recovered 186 BBIs 12Lb 14:42 15:06 0.40 7,446 7,903 PROD2 STK TRIP P Close EDC,Trip in hole, Clean pass through window 7903.1 Dry tag TOB 15:06 17:00 1.90 7,903 7,912 PROD2 STK KOST P Pumps on 1.33 BPM @ 3630 PSI FS Start time milling 105L TF 17:00 19:18 2.30 7,912 8,070 PROD2 DRILL DRLG P Milled 10'per procedure. Drill ahead 1.35 BPM @ 3430 PSI FS RIW=12.2 DHWOB=1.2K BHP=3780 Billet dry drift was clean 19:18 21:30 2.20 8,070 0 PROD2 DRILL TRIP P POOH for lateral drilling assembly with resistivity and RSM 21:30 00:00 2.50 0 0 PROD2 DRILL PULD P Undeploy BHA#8, Deploy BHA#9 12/14/2010 Drill AU Lateral 8070'-8240'with BHA data issues, possible magnetic activity. POOH,swap complete BHA. Drill ahead 8240'-8390'with continued BHA issues,magnetic interference. Continue drilling conservative adjusting Azm.toolface to IFR report. 1-2dec survey adjustments. 00:00 01:30 1.50 0 68 PROD2 DRILL PULD P Continue with pressure deploy drilling BHA 01:30 03:06 1.60 68 7,290 PROD2 DRILL TRIP P RIH with lateral drilling BHA with resistivity and RSM 03:06 03:18 0.20 7,290 7,308 PROD2 DRILL DLOG P Tie-in, +1' Close EDC 03:18 03:48 0.50 7,308 8,070 PROD2 DRILL TRIP P Continue RIH 03:48 04:12 0.40 8,070 8,113 PROD2 DRILL DRLG P Drill ahead, 1.4 BPM,3500 CTP, 3890 BHP, 14.5K RIW 04:12 05:48 1.60 8,113 8,113 PROD2 DRILL DLOG P Perform MAD pass while trouble shooting survey problem. RBIH. 05:48 06:18 0.50 8,113 8,157 PROD2 DRILL DRLG P Drill ahead, 1.4 BPM,3495 CTP, 3840 BHP, 10K RIW 06:18 06:30 0.20 8,157 8,157 PROD2 DRILL DLOG P Survey wiper. 06:30 07:15 0.75 8,157 8,220 PROD2 DRILL DRLG P Drill ahead, 1.4 BPM,3575 CTP, 3870 BHP, 10K RIW 07:15 09:45 2.50 8,220 8,220 PROD2 DRILL WPRT P Wiper trip to window#1. 09:45 10:15 0.50 8,220 8,240 PROD2 DRILL DRLG P Drill ahead, 1.4 BPM,3575 CTP, 3870 BHP, 10K RIW. Survey not cleaning up. 10:15 13:15 3.00 8,240 71 PROD2 DRILL TRIP P PUH slow. DD evaluating survey data. Discussions with Geo, BHI, and town. POOH to swap toolstring. 13:15 14:45 1.50 71 0 PROD2 DRILL PULD P PJSM-Undeploy BHA#9 14:45 17:15 2.50 0 68 PROD2 DRILL PULD P Deploy BHA#10 with 2.73"& RSM 17:15 18:45 1.50 800 7,290 PROD2 DRILL TRIP P RIH-close EDC-RIH 18:45 19:00 0.25 7,290 7,300 PROD2 DRILL DLOG P Tie in depth, 0 correection 19:00 20:42 1.70 8,240 8,340 PROD2 DRILL DRLG P Drill Ahead 100-120 FPH, 1.4BPM in, 1.4 BPM out, 3500 CTP 3905 BHP, 11K CTW, 2 K WOB, • Page 8 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:42 21:57 1.25 8,340 7,520 PROD2 DRILL DLOG P PUH 28K, Experiencing magnetic interference,MADD pass 8250-7520'. 7-8 FPM. 21:57 22:39 0.70 7,520 8,340 PROD2 DRILL DLOG P RIH to drill, Request IFR report from Sperry. 22:39 23:39 1.00 8,340 8,390 PROD2 DRILL DRLG P Drill Ahead 50-60 FPH, 1.4BPM in, 1.4 BPM out, 3550 CTP 3895 BHP, 12K CTW, 1K WOB, 23:39 00:00 0.35 8,390 8,390 PROD2 DRILL WPRT P Wiper trip to correct survey data 12/15/2010 Drill AL1 Lateral 8390'-8995'. Pinhole Coil Tubing during wiper trip. POOH. RD CT reel for reel swap. 00:00 01:30 1.50 8,390 8,390 PROD2 DRILL WPRT P Continue wiper trip 01:30 05:00 3.50 8,390 8,545 PROD2 DRILL DRLG P Drill Ahead 30-60 FPH Holding back ROP for TF drop, 1.4 BPM in and out.3471 CTP, 1-1.5K WOB, 3900 BHP, 11KCTW. Start sending new mud down CT,for mud swap,330am New mud to surface 0430am 05:00 06:00 1.00 8,545 8,545 PROD2 DRILL WPRT P Wiper trip to window 06:00 08:30 2.50 8,545 8,695 PROD2 DRILL DRLG P Drilling ahead-short survey's looking cleaner.Ankerite @ 8550' li 08:30 10:00 1.50 8,695 8,695 PROD2 DRILL WPRT P Wiper trip. P/U weight 28K 10:00 11:30 1.50 8,695 8,845 PROD2 DRILL DRLG P Drilling ahead-1.40 BPM,3500 psi, BHP 3900,ROP 100,WHP 0,WOB 1.8K,CT weight 11 k 11:30 13:00 1.50 8,845 8,845 PROD2 DRILL WPRT P Wiper trip-27K.Samples-good A-4 sand samples with heavy oil. 13:00 14:30 1.50 8,845 8,940 PROD2 DRILL DRLG P Drilling ahead-1.43 bpm,3400psi, BHP 3867, ROP 90, ECD 12.5,CT weight 10K,WOB 1.6K. 14:30 15:00 0.50 8,940 8,995 PROD2 DRILL DRLG P Pull BHA wiper due to weight transfer. P/U weight 27K.Continue drilling ahead-1.42 bpm,3200, BHP 3860, ECD 12.4,WOB 1.4,CT weight 9K, ROP 110 15:00 15:36 0.60 8,995 8,165 PROD2 DRILL WPRT P Wiper trip-P/U weight 27K, 15:36 16:21 0.75 8,165 8,165 PROD2 DRILL CTOP T Pinhole CT string,. Stop pumping, spraying inside injector chain. Leak stopped.Check valves holding.Shut in well. PJSM for pulling pipe from injector.Set up MPD line to hold pressure on well.Install additional containment outside under reel sump. 16:21 18:21 2.00 8,165 0 PROD2 DRILL TRIP T POOH slowly and watch pinhole through camera on reel. Flag pinhole, POOH pumping down MPD.CT life @ 31%coil life, pinhole not injector damage. 18:21 18:36 0.25 0 0 PROD2 DRILL SFTY T PJSM Undeploy BHA 18:36 20:36 2.00 0 0 PROD2 DRILL PULD T Undeploy Page 9 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/15/2010 24 hr Summary Drill AL1 Lateral 8390'-8995'. Pinhole Coil Tubing during wiper trip. POOH. RD CT reel for reel swap. 20:36 21:36 1.00 0 0 PROD2 DRILL CTOP T Flush stack 21:36 21:51 0.25 0 0 PROD2 DRILL CTOP T Blow down CT 21:51 00:00 2.15 0 0 PROD2 DRILL CTOP T Prepare to unstab CT 12/16/2010 Swap out reels, RU/MU reel. 00:00 01:00 1.00 0 0 PROD2 DRILL CTOP T Prepare to unstab CT 01:00 03:00 2.00 0 0 PROD2 DRILL CTOP T Unstab CT and secure to drum 03:00 06:00 3.00 0 0 PROD2 DRILL CTOP T RD reel-lower onto truck 06:00 11:00 5.00 0 0 PROD2 DRILL CTOP T switch flanges on reels&spot truck up to Sub module(tight fit due to hi-line power stand and edge of pad. 11:00 13:00 2.00 0 0 PROD2 DRILL CTOP T Install new Reel into stand. 13:00 17:00 4.00 0 0 PROD2 DRILL CTOP T Inspect injector&stripper prior to stabbing or moving pipe. New CT string thawing out. 17:00 19:00 2.00 0 0 PROD2 DRILL CTOP T Begin stabbing pipe.**5 bbls injected past 12 hours** 19:00 20:00 1.00 0 0 PROD2 DRILL CTOP T RD stabbing device 20:00 21:00 1.00 0 0 PROD2 DRILL CTOP T MU inside reel iron 21:00 00:00 3.00 0 0 PROD2 DRILL CTOP T Cut inner brace to MU stand pipe to • reel swival. Fabricate clamp for stand pipe to swival. 12/17/2010 Complete reel swap,Complete Bi-weekly BOP test. Pump slack management, Cut 2'CT finding E-line,MU CTC and drilling head. Pressure and pull test. Deploy BHA 11.Surface test did not pass on electronics. Rewire pressure bulk head,surface test, pressure test.(Pass). Complete deployment BHA 11. RIH 00:00 02:00 2.00 0 0 PROD2 DRILL CTOP T Cont.working on reel, rigging up stand pipe from reel swival to ineer reel iron. 02:00 06:00 4.00 0 0 PROD2 WHDBO BOPE P Start BOP testing-***State Witness waived by John Crisp** . Begin making up inner reel iron and build pressure bulk head. 06:00 09:30 3.50 0 0 PROD2 WHDBO BOPE P Completed Bulk head-Mig line. Completed with BOP test other than inner reel iron.Zero failures. BOP testing complete 09:30 12:00 2.50 0 0 PROD2 DRILL CIRC P Start filling reel for slack management&pressure test inner reel iron. Inner reel iron leaked. Stopped to hammer up. Re-test. 12:00 13:30 1.50 0 0 PROD2 DRILL CIRC P Pump Mud into CT, pop off well&cut back pipe. 13:30 15:00 1.50 0 0 PROD2 DRILL CTOP P Re-head CT string. Pull&pressure test. 15:00 17:15 2.25 0 68 PROD2 DRILL PULD P PJSM-start P/U and deploying new BHA. Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:00 0.75 68 68 PROD2 DRILL ELOG T Electronic's failed surface test, Lift injector off well. Postion reel to diagnose short. 18:00 00:00 6.00 68 68 PROD2 DRILL ELOG T Re-wire pressure bulk head,and swap out flow tube in BHA drilling head. Surface test, Pressure test, Good. 12/18/2010 RIH BHA 11, Drill AL1 lateral 8995-9167'. Perform MADD pass 9120-7834'. Inner reel iron leak during drilling operations. POOH to repair. 00:00 01:00 1.00 68 68 PROD2 DRILL PULD P Complete deploying BHA 11 01:00 03:00 2.00 68 7,290 PROD2 DRILL TRIP P RIH 03:00 03:06 0.10 7,280 7,280 PROD2 DRILL DLOG P Tie in depth, +2'correction 03:06 03:21 0.25 7,280 7,880 PROD2 DRILL TRIP P RIH to drill 03:21 04:21 1.00 7,880 7,880 PROD2 DRILL WPRT P Wiper trip back to window from top of billet 04:21 06:51 2.50 8,995 9,145 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM in/out, 1-2K WOB, 70-120FPH, 11-12K CTW, 3888 CTP,4000BHP, 06:51 07:21 0.50 9,145 9,018 PROD2 DRILL WPRT P Wiper trip-pick up weight 34 K. Weight increased to 41K @ 9020' Cycle pipe to try and clean up.Good returns but annular climbing. movement from 9025'to 9016'.WOB indicates pipe stuck, not BHA.max. P/U 55K. Heavy cuttings coming over shaker. 07:21 08:06 0.75 9,018 9,120 PROD2 DRILL WPRT T Pump 7 bbls low/High sweeps. Slowly move pipe while pumping 1.40 bpm, returns 1.34 bpm. Increase pump rate to 1.55 bpm, 60 fpm speed. Broke through while RIH on 6th attempt. RIH to 9120' 08:06 10:06 2.00 9,120 9,020 PROD2 DRILL WPRT P P/U weight 29K.Wiper trip to window. Heavy cutting coming over shaker with sweeps.Cuttings cleaned up. RIH to 9020' 10:06 14:57 4.85 9,020 9,145 PROD2 DRILL ELOG T Start MADD pass @ 5 fpm.pumping 1.3 bpm. 14:57 15:09 0.20 9,145 9,167 PROD2 DRILL DRLG P Back on bottom drilling-1.40 bpm, 3800 psi, BHP 3930, ECD 12.6, ROP 100,WOB 1.8K,CT weight 9K 15:09 16:39 1.50 9,167 7,400 PROD2 DRILL TRIP T Inner reel iron started leaking. P/U off bottom 36K.-check source, iron is binding-POOH to window to fix. Set up and pump down backside to keep MPD on well-should have clean hole only 20 ft drilled.CT weight 35K. ****6 hours Nabors on billable rig repair rate*** Page 11 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:39 17:39 1.00 7,400 7,400 PROD2 DRILL CTOP T PJSM for inner reel iron. Bleed off back to pits, Shut Isolation valve on inner reel.Continue pumping down backside holding MPD,roughly.15 bpm(10 bph).Fix bracket but seal leaking on 1502 wing.Tightening didn't help. 17:39 19:39 2.00 7,400 0 PROD2 DRILL TRIP T POOH to change out seal of 1502 iron. 19:39 20:39 1.00 0 0 PROD2 DRILL PULD T At surface, PJSM, Undeploy BHA, leaving BHA in deployment slips, holding 723psi on well(MP). Double isolate reel from MP line. 20:39 21:00 0.35 0 0 PROD2 DRILL RGRP T PJSM, Repair leak on inner reel iron. ***Nabors Billable rig repair rate expired*** 21:00 00:00 3.00 0 0 PROD2 DRILL RGRP T Conitnue working on reel. Found no 2"1502 weco seal in leaking union. ****Nabors 3 hours non-billable repair rate**** 12/19t2010 At surface, repaired leak on inner reel iron,rebuild pressure bulk head. Deploy BHA 11 w/Rib Steer Motor, Drill AL1 Lateral 9167-9615'. Lost returns drilling across fault#2B,9330'. Drilled ahead with .3 BPM losses. Chase low/high sweeps with wiper trips every 150'drilled back to window. Mud losses 241 bbls for 24 hours. 00:00 01:30 1.50 0 0 PROD2 DRILL RGRP T Continue working on reel, rebuild pressure bulk head ***Nabors 5 hours non-billable rig repair rate*** 01:30 02:30 1.00 0 0 PROD2 DRILL PULD T Pressure and surface test good. Deploy BHA 11 02:30 04:15 1.75 68 7,290 PROD2 DRILL TRIP T RIH 04:15 04:30 0.25 7,290 7,290 PROD2 DRILL DLOG T Tie in depth,-2'correction, close EDC 04:30 05:00 0.50 7,290 9,167 PROD2 DRILL TRIP T RIH to TD***Nabors NPT ends*** 05:00 07:30 2.50 9,167 9,167 PROD2 DRILL WPRT P Tag TD,wiper trip back to window 07:30 09:30 2.00 9,167 9,315 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3700, BHP 3920, ECD 12.6, ROP 70,WOB 1.4, Ct weight 11K.730'of mud system. Stacking weight @ surface 7215'. P/U-BHA wiper 30K and try quicker speed.Good WOB 1.2,CT weight 10K-drill ahead. 09:30 11:30 2.00 9,315 9,315 PROD2 DRILL WPRT P Out rate returns dropped off right before wiper trip to.8 bpm.from 1.28 bpm.Wiper trip-P/U weight 31K. Returns coming back @ 8000' 11:30 12:00 0.50 9,315 9,337 PROD2 DRILL DRLG P Drill ahead-1.40 bpm,3700, BHP 3870, ECD 12.5, ROP 80,WOB 1.5, CT weight 8K 9333'-lost all returns to surface. 1.40 bpm,3500 psi, BHP 3480, ECD 11.0. Page 12 of 20 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 13:00 1.00 9,337 9,333 PROD2 DRILL DRLG P P/U for weight check-heavy 46K. BHA sticking.Rate out and annular name up&weight dropped to 30K. BHA wiper-RIH tagged up early @ 9333'-P/U and RIH with rib steer on last 5'due to well Inclination-97. Difficult getting started due to motor stalls&differentail pressure.5 or 6 attempts. 13:00 14:00 1.00 9,333 9,360 PROD2 DRILL DRLG P Try drilling ahead from 9332'-1.40 bpm,3730, BHP 3550,WOB 2.6K, CT weight 7K, ROP 5.Zero returns from 9331'.Started getting better ROP&returns from 9334'. Drill ahead for 20 ft then BHA wiper. Shale in samples. 14:00 15:00 1.00 9,360 9,360 PROD2 DRILL REAM P BHA Wiper 31K-RIH-tagging up @ 9334',P/U try with ribs on,stack, P/U try with low pump rate. Drifted through by working the pumps&Rib steer on then off. RIH to TD-P/U and backream troubled spot.9345'- 9325'.Clean drift. 15:00 17:00 2.00 9,360 9,465 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3750, BHP 3890, ECD 12.6, ROP 60,WOB 2.2K,Ct weight 8K, returns.95 bpm. 17:00 19:15 2.25 9,465 9,465 PROD2 DRILL WPRT P Wiper trip-P/U weight 31K.**170 bbls loss for 12 hours** 19:15 20:00 0.75 9,465 9,515 PROD2 DRILL DRLG P Drill ahead 1.3 BPM in, .94 BPM out, 3780 CTP, 12.7 ECD,3922 BHP, 10K CTW, 100 FPH, (limit ROP to 100 FPH due to losses) 20:00 20.15 0.25 9,515 9,524 PROD2 DRILL DRLG P Limit WOB to 1.8K allowing BHA to drop. Prevent drilling out of the top of A4 20:15 20.30 0.25 9,524 9,524 PROD2 DRILL WPRT P Stall PU 32K, RIH to drill,stack out. PU 40K.PUH for BHA wiper 20:30 22:30 2.00 9,524 9,615 PROD2 DRILL DRLG P Drill ahead 1.3 BPM in, .94 BPM out, 3780 CTP, 12.7 ECD,3922 BHP, 10K CTW, 100 FPH, (limit ROP to 100 FPH due to losses) Pump 10 bbrl low followed by 10 bbrl high vis sweep 22:30 00:00 1.50 9,615 9,615 PROD2 DRILL WPRT P Wiper trip back to window,chasing sweep 12/20/2010 Drill AL1 Lateral 9615-10215',chasing low/high sweeps with wiper trips back to window every 150'drilled. Current losses.2 BPM.Total losses for last 24 hours, 134 Bbrls. 00:00 01:15 1.25 9,615 9,615 PROD2 DRILL WPRT P Conintue wiper trip to window Tie in depth to RA marker-3', RIH 01:15 05:00 3.75 9,615 9,765 PROD2 DRILL DRLG P Drill ahead 1.3 BPM in, .98 BPM out, 3874 CTP, 12.85 ECD,3949 BHP, 10K CTW,30-40FPH 05:00 07:45 2.75 9,765 9,765 PROD2 DRILL WPRT P Wiper trip back to window, 132 bbrls loss to formation last 12 hours.A-5 section was good during wiper. Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:45 2.00 9,765 9,914 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm 3600, BHP 3908, ECD 12.7, ROP 90,WOB 2.2K,Ct weight 6K, rate out 1.10 bpm. 09:45 12:45 3.00 9,914 9,914 PROD2 DRILL WPRT P Wiper trip-32K P/U weight.Time sweep out on bottom. Shale area looked good during wiper. 12:45 16:15 3.50 9,914 10,065 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3800 psi, BHP 3923, ECD 12.7, ROP 28, WOB 3K,CT weight 7K. 1.2 rate out. Stacked out-P/U 30 ft early. BHA wiper-P/U weight 35K. pump sweeps.Good ROP 100 fph. 16:15 19:30 3.25 10,065 10,065 PROD2 DRILL WPRT P Sweep @ bit-Wiper trip 32K- 73 bbls losses in past 12 hours. Tie in depth to RA marker, -2' Correction Did not set down weight through troubled area. 9330-9345' Wiper trip looked good 19:30 21:30 2.00 10,065 10,215. PROD2 DRILL DRLG P Drilling ahead-1.32 bpm, 1.2 BPM out, 3925 BHP, 3923 CTP, ECD 12.25,WOB 1-2K, 7-10K CTW surface. 80-100 FPH 21:30 00:00 2.50 10,215 10,215 PROD2 DRILL WPRT P Wiper trip to window, 32K PUW 12/21/2010 Drill AL1 lateral 10215 to 10677'TD. Perform wiper trip to surface pumping low/high vis sweeps. RBIH to TD. Total of 118 bbls losses to fo/mation. 00:00 01:00 1.00 10,215 10,215 PROD2 DRILL WPRT P 1 Conitnue wiper trip 01:00 03:00 2.00 10,215 10,365 PROD2 DRILL DRLG P Drilling ahead-1.32 bpm, 1.2 BPM out, 3925 BHP, 3923 CTP, ECD 12.25,WOB 1-2K, 7-10K CTW _surface.60-80 FPH 03:00 06:30 3.50 10,365 10,365 PROD2 DRILL WPRT P Wiper trip to window chasing low/high sweep, 32K PUW 06:30 09:30 3.00 10,365 10,515 PROD2 DRILL DRLG ,P Drilling ahead-1.40 bpm,3850, BHP 3970, ECD 12.8,WOB 2K, Ct weight 7K, ROP 90, Out rate 1.18 bpm. Cutting looking consulidated clay-silt, heavier than normal. Pump a sweep after 100ft drilled&Pull a mini-wiper of 200'. P/U weight 31K. Drill ahead. 09:30 13:00 3.50 10,515 10,515 PROD2 DRILL 'WPRT P Wiper trip-31K-cutting cleaned up &brought up more near the top of the wiper.Tie in correction-3 ft. 13:00 15:30 2.50 10,515 10,620 PROD2 DRILL DRLG P Drilling ahead-1.38 bpm, 3700, BHP 3980, ECD 12.9, ROP 100,WOB 1.8, CT weight 7K.Weight transfer @ 10620'-P/U 200'31K. Pump Sweep 7 low,7 high. Page 14 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 17:00 1.50 10,620 10,677 PROD2 DRILL DRLG P Sweeps at bit while on bottom drilling.Good ROP 100 fph until found ceiling of A-4 @ 10677'ROP slowed to 15 FPH.TD. 17:00 21:30 4.50 10,677 0 PROD2 DRILL WPRT P **TD Lateral"*-Wiper trip to Swab valves chasing low/high sweep. P/U weight-31K Pump low/high sweep at window, Cont. POOH to surface,drilling rate through bit. 21:30 23:00 1.50 0 7,450 PROD2 DRILL WPRT P At surface, RBIH with EDC open, pumping 1.3 BPM 23:00 23:15 0.25 7,450 7,450 PROD2 DRILL WPRT P At window close EDC. RIH to TD,get SBHP 23:15 00:00 0.75 7,450 10,000 PROD2 DRILL WPRT P Tie in depth to RA marker.-8' correction. RIH to TD 12/22/2010 Lay in liner running pill TD to 8000'. Displace well to 12ppg KWF 8000'to surface. Maintenance/Repair top drive. PU/MU liner segment#1,68jnts slotted liner with shorty deployment sleeve. RIH, releasing liner on bottom 10687',TOL 8447'. POOH keeping well dead.Service/Repair injector head. 00:00 01:00 1.00 10,000 10,677 PROD2 DRILL WPRT P Continue RIH to TD. SBHP 3625 psi 01:00 02:30 1.50 10,677 8,050 PROD2 DRILL TRIP P Tag TD, POOH laying in Liner running pill 1 for 1, paint flag 8368', EOP 8300'. 02:30 04:30 2.00 8,050 0 PROD2 DRILL TRIP P POOH, Displace well to 12ppg KWF from 8050'to surface. Paint flag 5168'. EOP 5300'. 04:30 04:45 0.25 0 0 PROD2 DRILL OWFF P At surface, monitor well for flow 04:45 06:15 1.50 0 0 PROD2 DRILL PULD P PJSM, LD tools 06:15 07:15 1.00 0 0 COMPZ CASING RURD P Prepare rig floor for running liner. Monitor well for losses.Well is taking about 1 bph to keep topped up. 07:15 10:00 2.75 0 0 COMPZ CASING RGRP T Weight sensor not functioning properly on TOP drive system. Troubleshoot-fix hydraulic fittings and replace hose while working out electronic load cell issues. 10:00 11:30 1.50 0 0 COMPZ CASING RGRP T Electrician continuing to work on load sensor&re-calibrate load cell program. ***Nabors 1.5hrs Non Billable Rig Repair*** 11:30 14:30 3.00 0 2,228 COMPZ CASING PUTB P PJSM-Start P/U liner assembly total of 68 joints with shorty deployment sleeve. 14:30 15:00 0.50 2,228 2,273 COMPZ CASING PULD P P/U Liner running BHA with Baker GS. 15:00 18:00 3.00 2,273 9,795 COMPZ CASING RUNL P RIH pumping .3 bpm of 12.0 KWF. Tie in+5ft correction to flag.Weight check 30K. RIH weight 18K. Clean through window. Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:15 0.25 9,795 9,795 COMPZ CASING RUNL P Set down weight-8K at 9795'. BHA is approximately across window. Try to work string down. Had heavy P/U to 52K to 9400', had to work up at a quicker speed to break free. 18:15 18:30 0.25 9,795 10,687 COMPZ CASING RUNL P RIH 70 FPM, past 9795', Continue RIH to TD 18:30 19:00 0.50 10,687 7,265 COMPZ CASING RUNL P Tag bottom 10687',Online with pumps,to release off liner. 1.5 BPM, 4300psi, PUH 31K CTW. Liner released. Pump KWF across top, PUH to window. Subtract liner length from depth. Swap pumping down the CT KWF. POOH 19:00 19:15 0.25 7,265 7,265 COMPZ CASING DLOG P Tie in depth with gamma.-5' correction 19:15 21:30 2.25 7,265 0 COMPZ CASING RUNL P POOH, Paint flag 7045', EOP 7400' 21:30 22:45 1.25 0 0 COMPZ CASING PULD P At surace, Flow check good, PJSM, lay down tools 22:45 23:45 1.00 0 0 COMPZ CASING RGRP T Found broken dove tail in injector sump from gripper block carrier.Also found broken gripper block bolt on seperate carrier. Hot tap broken stud.**Non-billable time** 23:45 00:00 0.25 0 0 COMPZ CASING SFTY P PJSM, running liner. 12/23/2010 PU/MU 11 jnts Slotted Liner with OH anchored billet. RIH,tag 8447'TOL segment 1,set OH anchor with single slip 180deg.TOL 8076'. POOH keeping well dead. Perform Bi-Weekly BOP function test. PU/MU BHA 13, 1.1 AKO. RIH sidetrack for AL1-01 lateral off alluminum billet. Drill Ahead AL1-01 lateral 8076-8177'. Gamma component failed. POOH, undeploy BHA 13, Deploy BHA 14 with new Gamma component, 1.1 AKO, RIH.Total 103 bbrls of 12ppg KWF(Sodium Bromide Brine)lost to formation running AL1 liner. 00:00 01:30 1.50 0 0 COMPZ CASING PUTB P PUMU liner segment#2, 11 jnts slotted liner, OH anchored billet and coil track 01:30 03:30 2.00 433 7,433 COMPZ CASING RUNL P RIH 03:30 03:45 0.25 7,433 7,433 COMPZ CASING RUNL P Tie in depth to EOP flag-2' correction, Close EDC, RIH to liner segment#1 Weight check 30K, RIHW 18K 03:45 04:15 0.50 7,433 8,447 COMPZ CASING RUNL P Tag liner segment#1, 8447', 3K WOB. PUH to neutral weight on WOB. Online with pumps setting OH anchor. single slip 180deg. Set-3500 CTP,3.6K WOB. TOL 8074' 04:15 06:45 2.50 8,447 44 COMPZ CASING TRIP P POOH 06:45 07:45 1.00 44 0 COMPZ CASING PULD P CT @ surface-flow check&lay down BHA. Inspect injector at the same time. No segments found during inspection. 07:45 08:15 0.50 0 0 COMPZ CASING BOPE P Weekly Function test BOP's. PJSM for P/U BHA. 08:15 09:15 1.00 0 72 PROD3 STK PULD T P/U BHA#14-1.1 AKO with 2.73" Bi-center Page 16 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:45 2.50 72 7,465 PROD3 STK TRIP T RIH pumping.3 bpm.Tie in-2ft& swap well over to old drilling mud. P/U weight 27K. **total losses of 103 bbls**during liner runs. 11:45 12:15 0.50 7,465 8,075 PROD3 STK TRIP T RIH clean through window,dry tag @ 8075' P/U&set up to STK. 12:15 14:15 2.00 8,075 8,078 PROD3 STK KOST T Start time milling -1.40 bpm, 3700 psi, BHP 3780, ECD 12.2, returns 1 bpm,WOB 1.1K,CT weight 14K. Light Alum.shaving over shakers 1 ft • into. 14:15 15:00 0.75 8,078 8,105 PROD3 STK KOST T Increase speed to 15-20 fph. Drill to 8105 and dry run through billet. clean. 15:00 16:00 1.00 8,105 8,177 PROD3 DRILL DRLG T Drilling ahead- 1.40 bpm,3800, BHP 3840, ECD 12.4,WOB 1K, CT weight 13K, ROP 100, Rate out 1.3 bpm. 16:00 16:30 0.50 8,177 7,500 PROD3 DRILL WPRT T Geo wiper-P/U weight 30K.Gamma tool failed-try&troubleshoot while wiping to window. 16:30 19:00 2.50 7,500 0 PROD3 DRILL TRIP T Open EDC-POOH to change out Gamma tool ***BHI non-billable rig time*** 19:00 19:15 0.25 0 0 PROD3 DRILL SFTY T At surface, PJSM 19:15 20:15 1.00 0 0 PROD3 DRILL PULD T Undeploy BHA 20:15 21:15 1.00 0 0 PROD3 DRILL PULD T Build BHA with new gamma,same Resistivity tool Service injector head Planned time, ConocoPhillips request to run same Resistivity BHA component. 21:15 21:30 0.25 0 0 PROD3 DRILL SFTY T PJSM 21:30 22:30 1.00 0 0 PROD3 DRILL PULD T Deploy BHA 14, 1.1 AKO with Bi-Center, new Gamma component, RR resistivity component. 22:30 23:45 1.25 0 7,290 PROD3 DRILL TRIP T RIH 23:45 00:00 0.25 7,290 7,290 PROD3 DRILL DLOG T Tie in depth-4'Correction, RIH 12/24/2010 Drill AL1-01 Lateral 7675'-8694', performing wiper trips back to window 7500',every 150'drilled. Drill Ankerite 8643'-8694'. Tie in depth to RA marker every 3rd wiper trip.Total Losses 24hrs. 31 bbrls 00:00 02:30 2.50 8,177 8,330 PROD3 DRILL DRLG T Drill Ahead, 1.4 BPM in, 1.26 BPM out, 3500 CTP, 14 CTW,2K WOB, 12.4 ECD, 3734 BHP. Perform mud swap. 02:30 03:30 1.00 8,330 8,330 PROD3 DRILL WPRT T Wiper trip to window, 32K PUW 03:30 05:30 2.00 8,330 8,480 PROD3 DRILL DRLG T Drill Ahead, 1.4 BPM in, 1.26 BPM out, 3500 CTP, 14 CTW,2K WOB, 12.4 ECD, 3734 BHP. 05:30 07:00 1.50 8,480 8,480 PROD3 DRILL WPRT T Wiper trip-clean Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 12:30 5.50 8,480 8,635 PROD3 DRILL DRLG T Drilling ahead in A-3 sand-Hit ankerite 8523'. 1.40 bpm,3800, BHP 3750, ECD 12,WOB 3K,Ct weight 9K, ROP 7. Losing 1 -2 bph. 12:30 14:00 1.50 8,635 8,635 PROD3 DRILL WPRT T Wiper trip with tie in Zero correction. P/U weight 32K 14:00 00:00 10.00 8,635 8,694 PROD3 DRILL DRLG T Drilling ahead-1.37 bpm, 3600, BHP 3775, ECD 12.2, ROP 120,WOB 1.6K, CT weight 11K, 1.26 bpm out. More ankerite 8643'.3-7 FPH. Losing 1 -2 bph. 12/25/2010 Drill AL1 Lateral 8694-8900'. Drill thorugh ankerite stringers starting 8523'to TD.TD AL1 Lateral 8900'. PUH to 5000'chasing low/high sweeps. RIH, layin liner running pill(12ppg KWF with beads)TD to window. Displace KWF from window to surface.24 hr.Total Losses 32 bbrls FloPro 00:00 06:30 6.50 8,694 8,719 PROD3 DRILL DRLG T Drilling ahead-1.37 bpm, 3600, BHP 3775, ECD 12.2,WOB 1.6K, CT weight 11K, 1.26 bpm out. More ankerite 8643'.3-4 FPH. Losing 1 -2 bph. 06:30 06:45 0.25 8,719 8,719 PROD3 DRILL WPRT T Do a 50' P/U to check weight and bit cleaning. 32K. 06:45 07:00 0.25 8,719 8,722 PROD3 DRILL DRLG T Drilling ahead-1.45 bpm, 3900, BHP 3810, ECD 12.1, ROP 15 fph, CT weight 9.5K,WOB 3K. 07:00 11:00 4.00 8,722 8,810 PROD3 DRILL DRLG T ROP change to 110 fph-back into Ankerite @ 8793' 11:00 12:30 1.50 8,810 8,810 PROD3 DRILL WPRT T Wiper trip-P/U weight 32K.Zero correction on tie in. 12:30 14:30 2.00 8,810 8,850 PROD3 DRILL DRLG T Drilling ahead-1.35 bpm, 3500, BHP 3810, ECD 12.2, ROP 80,WOB 1.5, CT weight 11K, rate out 1.25 bpm. 14:30 16:00 1.50 8,850 8,865 PROD3 DRILL DRLG T Slow ROP-P/U weight 32 K-wipe up 100'- Drill ahead CT weight stacking to zero with 2.6K on bit. ROP 8 fph. Pump 5/5 sweeps. Not much change in weight transfer. Possible bit dulling? 16:00 19:00 3.00 8,865 8,900 PROD3 DRILL DRLG T P/U wiper 200'.Weight 32K. Drill ahead-1.30 bpm, 3560, BHP 3820, ECD 12.2, ROP 2,WOB 3.5K,CT weight 3K. Spoke with town and 18:00 maybe TD. 19:00 22:00 3.00 8,900 5,000 PROD3 DRILL WPRT T TD AL1-01 Lateral, pump low/high vis sweeps,chasing sweeps back up to 5000'. Returns look good.RIH 22:00 22:15 0.25 5,000 7,290 PROD3 DRILL DLOG T Tie in depth with Gamma 0 correction. 22:15 23:00 0.75 7,290 8,900 PROD3 DRILL WPRT T RIH to TD 23:00 00:00 1.00 8,900 7,500 PROD3 DRILL WPRT T Tag TD, PUH laying KWF with beads to window 12/26/2010 POOH displacing well to 12ppg KWF. PU/MU AL1 liner(32jnts slotted, 11jnts solid). RIH setting liner on bottom 8900',TOL 7468'. POOH, keeping well dead. PU/MU, KB Liner Top Packer setting on top AL1 liner. Top of packer 7461.95'. Displace well to Sea Water,freeze protect well 2500'to surface. Undeploy BHA 17. Total bbrls lost 72 bbrls 12ppg KWF. Page 18 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 7,500 0 PROD3 DRILL TRIP T POOH,displacing well to KWF Paint EOP flag 7300'and 5300' 02:00 02:15 0.25 0 0 PROD3 DRILL OWFF T At surface. Monitor well for flow 02:15 03:45 1.50 0 0 PROD3 DRILL PULD T PJSM,Work draw works up and down,-68 below windchill. LD BHA 15. 03:45 04:30 0.75 0 0 COMPZ CASING RURD T Prep floor for running liner 04:30 06:30 2.00 0 0 COMPZ CASING PUTB T PU liner-crew change-top up fluid level 3 bbls. 06:30 09:30 3.00 0 1,474 COMPZ CASING PUTB T Continue P/U Liner. 32 slotted/12 solid&Sealbore Deployment Sleeve &BHI coiltrack assembly 09:30 11:15 1.75 1,474 8,901 COMPZ CASING RUNL T RIH pumping through GS profile @.3 bpm. P/U weight 33 K at the window. Correction +1ft. Clean through window. Set down @ 8901.5'to 6K. P/U weight 38K. Set down 5K. 8901.5' 11:15 11:45 0.50 8,900 7,470 COMPZ CASING DLOG T Increase pump rate to 1.2 bpm, P/U weight 30 K. **Liner&seal bore deployment sleeve set from 8900-7469'** POOH&Log from 7265'-1ft correction. 11:45 13:15 1.50 7,470 55 COMPZ CASING TRIP T POOH laying in KWF 13:15 14:00 0.75 55 55 COMPZ CASING PULD T PJSM-work top drive for 30 mintues prior to P/U BHA due to temperatures. 14:00 14:30 0.50 0 55 COMPZ RPEQPI PULD T Lay down BHA&P/U Liner top Packer assembly-guage the 5/8" ball. Max. OD is 2.78". Set ball in liner setting tool. 14:30 16:30 2.00 55 7,200 COMPZ RPEQP1TRIP T RIH @ 50 fpm with EDC open pumping .3bpm from 100'. Slow down during restrictions to 25 fpm. 16:30 17:00 0.50 7,200 7,450 COMPZ RPEQPI DLOG T Tie in from 7270'-2ft correction. Continue RIH slowly. P/U weight 31K. Stop @ 7450'close EDC.Stop pumping. 17:00 17:30 0.50 7,450 7,471 COMPZ RPEQPI PACK T Tag @ 7471'-Set down 5K to 7472'. P/U weight 33K. RIH tag again. 7471' -P/U 2 ft past break over-7468.5'. Start pumping down CT to 1500psi. Stop pumping and slack off weight. Set down 6 K @ 7469.8'Good set of packer element. Pressure up backside to 800 psi. IA 240/OA zero.**Max.differential presure the element is good for is 2500 psi.**Holding 800 solid, Good test. Bleed off to pits. Pressure up to 2800 psi down CT string. Set collets and P/U on CT. Page 19 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:30 19:00 1.50 7,471 7,450 COMPZ CASING DISP P P/U weight 31K.Top of packer @ 7462'.Open EDC and circulate out KWF with SW. 19:00 20:45 1.75 7,450 2,500 COMPZ CASING TRIP T POOH 20:45 21:15 0.50 2,500 2,500 COMPZ CASING DISP P Circulate diesel 28bbrls in CT. Circulate 19bbrls hot diesel through reverse circulating line out to tiget tank to warm up TT line. 21:15 21:45 0.50 2,500 2,500 COMPZ CASING FRZP P Circulate diesel out CT with SW, freeze protecting well. 21:45 22:30 0.75 2,500 0 COMPZ CASING TRIP P POOH, 1 for 1 22:30 00:00 1.50 0 0 COMPZ CASING PULD P At surface, PJSM. Undeploy BHA 12/27/2010 LD BHA 17, Flush and Purge stack and rig. Unstab CT.Swap out skates on Injector.Stab CT Head while waiting on weather. 00:00 00:30 0.50 0 0 COMPZ CASING PULD P LD BHA 00:30 02:00 1.50 0 0 DEMOB WHDBO MPSP P PJSM,set BPV 02:00 04:00 2.00 0 0 DEMOB WHDBO CIRC P Flush and Purge stack and rig 04:00 06:00 2.00 0 0 DEMOB WHDBO RURD P Rig down-low pressure return line froze off. Start chasing frozen lines. 06:00 09:00 3.00 0 0 DEMOB WHDBO CIRC P PJSM-set up to ciculate down CT string back to pits to keep fluid moving while thawing out low pressure return lines. Current ambient temp is-47. 09:00 11:00 2.00 0 0 DEMOB WHDBO CIRC P All lines are ice free. Begin purging CT string with compressor. recovered 17 bbls. 11:00 13:00 2.00 0 0 DEMOB WHDBO CIRC P Begin blowing down BOP lines& HP iron. Freeze protect wellhead&swab valves. 13:00 14:30 1.50 0 0 DEMOB WHDBO CTOP P PJSM for unstabbing pipe. Unstab CT from injector. Secure pipe for rig move.Vac truck disabled on location. Last load waiting to be removed. 14:30 16:00 1.50 0 0 DEMOB WHDBO RGRP P Remove stipper from Injector. Roll chains out of injector. removed last load of fluid off location. 16:00 00:00 8.00 0 0 DEMOB WHDBO RGRP T Replace skates in injector and lower top drive to warm up. RD/ND Wait in weather, Charges transfer to 1B-19 Page 20 of 20 sifigriE tIE) LEF AttnsEn, 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 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2Z-23AL1 ConocoPhillips Alaska, Inc. Permit No: 210-158 Surface Location: 1304' FSL, 334'FEL, SEC. 11, T11N, R9E, UM Bottomhole Location: 2560' FNL, 1670' FEL, SEC. 10, T11N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 2Z-23A, Permit No 210- 157, API 50-029-22544-01. 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, 7 D. - Seamount, Jr. Chair DATED this — day of October, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) AECEIVED STATE OF ALASKA OCT 2 6 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Airmitat g&ea' sCons.Comdnion 20 AAC 25.005 Anchcrage la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑✓ , Single Zone ❑✓ . 1c.Specify if well is proposed for: Drill ❑ Re-drill LTJ 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: i] Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2Z-23AL1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10620' TVD: 6000' Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1304'FSL,334'FEL,Sec. 11,T11N,R9E, UM . ADL 25646,25645 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1392'FSL,248'FWL,Sec. 11,T11N, R9E,UM 2577,2576 11/15/2010 Total Depth: 9.Acres in Property: 14.Distance to 2560'FNL, 1670'FEL,Sec. 10,T11N, R9E, UM 2560 Nearest Property: 30400 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 112 feet 15.Distance to Nearest Well Open Surface:x- 529376 • y- 5966062 • Zone- 4 GL Elevation above MSL: ' 71 feet to Same Pool: 2X-15,1250 16.Deviated wells: Kickoff depth: 8180 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95° deg Downhole:3500 psig Surface:3000 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 3120' 7500' 5787' 10620' 6000' 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) 7972 6259 7870 6163 Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx ASI 121' 121' Surface 4242' 9.625" 890 sx AS III,480 sx Class G 4242' 3465' Intermediate Production 7960' 7" 338 sx Class G 7960' 6232' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7400'-7418',7445'-7495',7678'-7688',7696'-7726',7750'-7770',7804'-7809' 5807-5821',5841'-5879',6017-6025',6031'-6054',6072'-6087',6113'-6117' 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements Li 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 `D1 k ti:) Printed Name V. Cawvey Title Alaska Wells Manager Signature Phon265-63o6 Date ii/�jz ,o `•P�� Commission Use Only Permit to Drill API Nu Permit Approval See cover letter Number: 2. C-; /58 50- 0 '��!7 V/ 6.c% ' Date: 10(al l 1 V for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,orproduce coalbed m ah e,gas hydrates,or gas contained in shales: * 3so0 Y is Se. �Q P/ /e S+ Samples req'd: Yes ❑ No I`'1 Mud log req'd: Yes ❑ No [t� Other: l, 2 Sega los e, Aim..AA Te-S-1- (sse. .j S measures: Yes 2/No ❑ Directional svy req'd: Yes Q/ No ❑ - ut/T'iSt 4 4 erc-ki eL. .; k%. 4 c_c.c0 fiat La /410 2.6 — /4 1 r Pe r.t,i.et i / a e . , .. . APPROVED BY THE COMMISSION /OA—!7 0 DATE: 0 � ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for•4 �nfLIfr rGrgtlIe Q.f p6roval(20 AAC 25.005(g)) Submit in Duplicate ii `� tI J tttt LLLLL����. ilk I .>"t irr.21, • ,C- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 21, 2010 lECEIVED Commissioner- State of Alaska ()r T 2 6 2010 Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 4I3€1 a oil&Sas Cons.Commission Anchorage, Alaska 99501AAEhuBg@ Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill two lateral sidetracks out of Kuparuk Well 2Z-23 using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 2Z-23 in later November 2010. The CTD objective is to drill two lateral sidetracks (2Z-23A and 2Z-23AL1); targeting the A3 and A4-sands to access reserves away from the parent wellbore, across isolating faults. The two laterals will be drilled from one, dual string casing exit through the selective interval (3.5"tubing x 7" casing). Attached to this application are the following documents: - Permit to Drill Application Forms for 2Z-23A and 2Z-23AL1 - Detailed Summary of Operations - Proposed Schematic - Directional Plans - Anti-collision Review - BOP Schematic If you have any questions or require additional information please contact me at 907-263-4093. Sincerely, 11tJill g 6 Coiled Tubing Drilling Engineer Permit to Drill Summary of Operations KRU 2Z-23 and 2Z-23AL1 Lateral Sidetracks Coiled Tubing Drilling Well History and Objective Injecting well 2Z-23 was originally drilled and completed as in 1995 as a single, selective completion with both the A and C sands perforated. The 2Z-23 wellbore is in an area that contains many sealing and highly baffling faults, as well as a prolific C-sand. This faulting has caused a significant amount of compartmentalization in the A sands and has resulted in lower than expected oil recovery. The purpose of the CTD project is to drill two CTD lateral sidetracks in the A4 and A3 sands away from the parent • wellbore and across faults that are believed to be isolating. The sidetracks will be injecting laterals, the same as the parent wellbore. The outcome expected is improved sweep efficiency and oil recovery. Both the A and C sand perforations in the parent wellbore are planned to be plugged using cement prior to CTD rig arrival. The lateral footage drilled in the immediate vicinity of parent well will recover the existing A sand perforations. A review of the C sand in the area confirmed that abandoning the C sand perforations in this parent wellbore should not have a significant impact on the rates of offset producers. 9 P Operational Outline Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5"tubing across the selective interval. 2. Set a plug just above the bottom packer, isolating the A sand perforations. Pressure test the tubing to confirm integrity of the selective. 3. Punch holes —5' of holes below the sliding sleeve (to ensure cement in the annulus below the sliding sleeve). 4. Set EZSV cement retainer 5. Pump cement into the 3.5" x 7" annulus, squeezing off the A and C sand perforations and placing good cement in the annulus across from the CTD KOP 6. Perform a dummy whipstock drift. Set the lower whipstock at—7510' 7. Set BPV and prepare wellsite for rig arrival. eot Rig Work General Plan 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPELtest. 2. Mill a 2.80", dual-string window exit with high-side orientation off of the whipstock set pre-rig arrival 3. 2Z-23A Lateral a. Drill 2.70"x 3" bi-center lateral in the A4 sand b. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to f") the kickoff point for the 2Z-23AL1 lateral 4. 2Z-23AL1 Lateral a. Drill 2.70"x 3" bi-center lateral in the A3 sand b. Load well with kill weight fluid. Run 2%"slotted liner with a deployment sleeve on top from TD to just inside the window 5. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 Q R I G I AL 10/21/2010 PTD Applications KRU 2Z-23A and 2Z-23AL1 Operational Details Hazards — Shale stability is a potential problem. Well 2Z-23 is in close proximity to 2Z-13 which encountered . significant shale problems while drilling. Managed pressure drilling (MPD) will be utilized on this well to minimize exposure problems. — Drillsite 2Z is an H2S pad. The maximum recorded H2S reading on the pad in 2010 was 135 ppm on well 2Z-10 measured on 01/13/2010. Well 2Z-29 is the closest producing well to 2Z-23 (located —90' to the right on surface) and had an H2S reading of 50 ppm on 01/13/2010. All H2S monitoring equipment will be operational. Fluids Program — Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (9.8 ppg)for drilling operations. — 2Z-23 does not contain a subsurface safety valve so completion kill weight fluid 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 2Z-23A 8180' 10800' 5970' 6006' 2%", 4.7#, L-80, ST-L slotted liner; aluminum liner top billet on top. 2%", 4.7#, L-80, ST-L slotted liner; 2Z-23AL1 7500' 10620' 5787' 6000' deployment sleeve on top. Blank liner will be placed across the Build section and shale sections. 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 9%" 40 L-80 BTC 0 4242 0 3474 5750 3090 Casing 7" 26 L-80 BTC-Mod 0 7960 0 6250 7240 5410 Tubing 3 V2" 9.3 L-80 ABM-EUE 0 7568 0 5950 10160 10540 Tubing 2-'/8" 6.5 J-55 ABM-EUE, IPC 7568 7597 5950 5972 7260 7680 Page 2 of 3 n I ! /1\1A 10/21/2010 PTD Applications KRU 2Z-23A and 2Z-23AL1 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 2Z-23A 29800' 2Z-23AL1 30400' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 2Z-23A 1300' Toe measured to 2X-15 2Z-23AL1 1250' Toe measured to 2X-15 • 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 2Z-23 was taken August 2009. The reservoir pressure was measured at 2725 psi at 7567' MD/5840' TVDss, corresponding to 9.0 ppg EMW: Well Control — Two well bore volumes (-190 bbl) of 12.0 ppg kill weight fluid 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 3500 psi. Maximum surface pressure anticipated while sidetracking out of 2Z-23 is —3000 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum expected reservoir " pressure from 2Z-23 based on recent injection wellhead pressures at 2Z-23. (Recent wellhead pressure readings have been —950 psi which correlates to a bottomhole pressure at the kickoff point of —3500 psi. Assuming a gas gradient of 0.1 psi/ft, the maximum surface pressure expected would be —3000 psi.) — 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 ORIGINAL 10/21/2010 PTD Applications KRU 2Z-23A and 2Z-23AL1 Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 2Z-23 CTD laterals. The distances noted are the closest proximity between these wellbores and any point along the planned CTD laterals. — 2X-16 (active producer)—This wellbore is located —1245' to the southwest of laterals 2Z-23A and 2Z-23AL1. This well is a single completion with commingled production from perforations in both the A and C sands. — 2X-15 (active producer)—This wellbore is located —1285' to the northeast of laterals 2Z-23A and 2Z-23AL1. This well is a selective completion with capability to produce from both the A and C sands. — 2Z-03 (shut-in injector) —This wellbore is located —1295' to the west of laterals 2Z-23A and 2Z-23AL1. This well is a selective completion with capability to inject into both the A and C sands. The well is currently shut-in awaiting a flowline repair that will not likely occur until the year 2011. 6 Page 4 of 3 ORIGINAL 10/21/2010 p 0 C p Z Q © O Ta 0 —CV 0I- CU aD Y c E `°' a N CC CO Cr En — (V (0 J N N C (p U N 4) el t� N 41 N CO N 0 N O as n CO aa\\ CO r'i Y ao N t N V Y CC N O ("Ni LJ m 7 @ h. o - ct Y Y - N •- • o � Co - N 0) �6 n co CO E , in r- co v E c c aN-1 �r`1 a) Y g I- _ a) ih O a) V V _Q cc O r 4,:. N W Cl) ) N h a) a) W c dO_ a) N- .0 —N > co 0O) N- 1.1JJ O N �`�` N c rr`` /a��1 Y V 0 co • V a) CI CO 2 m Y 2 a U 3 N A —(� U -O Cl. n - '.L is O • O 0 Cu(6 O rn - Y Z — E t O O - Q. O N. N x • 0 E o 3 u! E E E `�' J E m _ U 6) 0 0 M 11 0 O X O .. c O` O O N N N N Y Y N E N � N CV = Co . (n--- c - . -c-- a) co .- N Co O M (h M M m CU M UA I- M M Q c ( U h N (Oil I IIII I iiii III �.1 11111 iii1��s id IA , 1ii RS i _ - ( 4:1,) - r 2:1 :.---1 .a .— U) ,, CI 1 X11, 11 .1 HtIfi !_r___/,!1 in inI O 0 H J J J J 2 L m W W W W N O o�i�in ED I! ! co N i� n ib ii) W m* " 0 Ycil coo 0(V co M N � -o U N to (cpb 0 a 1 (nov 0 N Era aU U r- r Y ORIGINAL ConocóPhiIli s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2Z Pad 2Z-23 2Z-23AL1 Plan: 2Z-23AL1_wp01 Standard Planning Report 12 October, 2010 'flu BAKER HUGHES ORIGINAL r' ConocoPhillips Irr~ ConocoPhllIips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2Z-23 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2Z-23 @ 112.00ft(2Z-23) Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-23 Survey Calculation Method: Minimum Curvature Wellbore: 2Z-23AL1 Design: 2Z-23AL1_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAB 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2Z Pad Site Position: Northing: 5,966,526.92ft Latitude: 70°19'10.651 N From: Map Easting: 529,130.68ft Longitude: 149°45'49.854 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22 ° Well 2Z-23 Well Position +N/-S 0.00 ft Northing: 5,966,062.01 ft Latitude: 70°19'6.069 N +E/-W 0.00 ft Easting: 529,376.25 ft Longitude: 149°45'42.741 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 71.00ft Wellbore 2Z-23AL1 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 12/15/2010 16.91 79.84 57,348 Design 2Z-23AL1_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (') -71.00 0.00 0.00 330.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°/100ft) (°/100ft) (°) Target 8,100.00 90.32 342.82 5,964.02 13.58 -4,674.33 0.00 0.00 0.00 0.00 8,180.00 80.72 342.82 5,970.26 89.69 -4,697.86 12.00 -12.00 0.00 180.00 8,340.00 81.24 323.38 5,995.58 229.90 -4,769.00 12.00 0.33 -12.15 270.00 8,490.00 86.88 321.33 6,011.09 347.97 -4,860.09 4.00 3.76 -1.37 340.00 8,660.00 86.43 328.13 6,021.01 486.45 -4,958.03 4.00 -0.27 4.00 94.00 8,760.00 88.62 324.77 6,025.33 569.70 -5,013.23 4.00 2.18 -3.35 303.00 9,020.00 90.08 314.48 6,028.29 767.49 -5,181.41 4.00 0.56 -3.96 278.00 9,220.00 93.48 302.96 6,022.06 892.31 -5,337.08 6.00 1.70 -5.76 286.60 9,570.00 93.38 288.94 6,001.01 1,044.81 -5,650.44 4.00 -0.03 -4.01 270.00 9,820.00 94.88 279.03 5,982.96 1,105.00 -5,892.09 4.00 0.60 -3.96 279.00 10,020.00 90.05 285.41 5,974.34 1,147.26 -6,087.21 4.00 -2.42 3.19 127.00 10,620.00 85.08 308.91 6,000.21 1,418.70 -6,616.76 4.00 -0.83 3.92 102.30 10/12/2010 2:33:46PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips Et ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2Z-23 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2Z-23 @ 112.00ft(2Z-23) Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-23 Survey Calculation Method: Minimum Curvature • Wellbore: 2Z-23AL1 Design: 2Z-23AL1_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (0) (0) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) 8,100.00 - 90.32 342.82 5,964.02 13.58 -4,674.33 2,348.92 0.00 0.00 5,966,057.30 524,702.37 TIP/KOP 8,180.00 80.72 342.82 5,970.26 89.69 -4,697.86 2,426.60 12.00 -180.00 5,966,133.30 524,678.54 , 2 I 8,200.00 80.73 340.39 5,973.48 108.42 -4,704.09 2,445.93 12.00 -90.00 5,966,152.01 524,672.24 8,300.00 81.02 328.24 5,989.40 197.21 -4,746.80 2,544.19 12.00 -89.61 5,966,240.63 524,629.18 8,340.00 81.24 323.38 5,995.58 229.90 -4,769.00 2,583.60 12.00 -87.67 5,966,273.22 524,606.86 End of DLS 12 8,400.00 83.50 322.56 6,003.54 277.37 -4,804.81 2,642.62 4.00 -20.00 5,966,320.55 524,570.86 8,490.00 86.88 321.33 6,011.09 347.97 -4,860.09 2,731.40 4.00 -19.89 5,966,390.93 524,515.32 4 8,500.00 86.86 321.73 6,011.63 355.79 -4,866.30 2,741.28 4.00 94.00 5,966,398.72 524,509.08 8,600.00 86.59 325.73 6,017.35 436.27 -4,925.35 2,840.49 4.00 93.98 5,966,478.96 524,449.72 8,660.00 86.43 328.13 6,021.01 486.45 -4,958.03 2,900.29 4.00 93.75 5,966,529.01 524,416.85 5 8,700.00 87.31 326.79 6,023.19 520.12 -4,979.51 2,940.19 4.00 -57.00 5,966,562.59 524,395.24 8,760.00 88.62 324.77 6,025.33 569.70 -5,013.23 2,999.99 4.00 -56.93 5,966,612.03 524,361.33 I 6 8,800.00 88.84 323.19 6,026.21 602.04 -5,036.74 3,039.76 4.00 -82.00 5,966,644.28 524,337.69 8,900.00 89.40 319.23 6,027.75 679.96 -5,099.37 3,138.55 4.00 -81.96 5,966,721.94 524,274.76 I 9,000.00 89.97 315.27 6,028.30 753.38 -5,167.24 3,236.06 4.00 -81.90 5,966,795.09 524,206.61 9,020.00 90.08 314.48 6,028.29 767.49 -5,181.41 3,255.37 4.00 -81.88 5,966,809.14 524,192.39 ` 7 9,100.00 91.45 309.88 6,027.23 821.18 -5,240.68 3,331.50 6.00 -73.40 5,966,862.59 524,132.92 9,200.00 93.15 304.12 6,023.22 881.28 -5,320.44 3,423.43 6.00 -73.46 5,966,922.38 524,052.93 9,220.00 93.48 302.96 6,022.06 892.31 -5,337.08 3,441.31 6.00 -73.69 5,966,933.34 524,036.25 8 9,300.00 93.48 299.76 6,017.20 933.86 -5,405.26 3,511.38 4.00 -90.00 5,966,974.62 523,967.91 9,400.00 93.45 295.75 6,011.16 980.34 -5,493.58 3,595.78 4.00 -90.19 5,967,020.74 523,879.42 9,500.00 93.42 291.74 6,005.16 1,020.52 -5,584.93 3,676.26 4.00 -90.44 5,967,060.57 523,787.92 9,570.00 93.38 288.94 6,001.01 1,044.81 -5,650.44 3,730.05 4.00 -90.68 5,967,084.60 523,722.32 9 9,600.00 93.57 287.75 5,999.20 1,054.23 -5,678.86 3,752.42 4.00 -81.00 5,967,093.91 523,693.87 9,700.00 94.18 283.79 5,992.44 1,081.34 -5,774.86 3,823.90 4.00 -81.07 5,967,120.64 523,597.77 9,800.00 94.77 279.82 5,984.64 1,101.73 -5,872.43 3,890.34 4.00 -81.34 5,967,140.65 523,500.14 9,820.00 94.88 279.03 5,982.96 1,105.00 -5,892.09 3,903.00 4.00 -81.65 5,967,143.83 523,480.47 10 9,900.00 92.95 281.58 5,977.49 1,119.27 -5,970.60 3,954.62 4.00 127.00 5,967,157.80 523,401.90 10,000.00 90.53 284.77 5,974.44 1,142.06 -6,067.90 4,023.00 4.00 127.17 5,967,180.20 523,304.52 10,020.00 90.05 285.41 5,974.34 1,147.26 -6,087.21 4,037.17 4.00 127.27 5,967,185.33 523,285.20 11 10,100.00 89.37 288.53 5,974.74 1,170.61 -6,163.72 4,095.64 4.00 102.30 5,967,208.38 523,208.61 10,200.00 88.52 292.44 5,976.59 1,205.60 -6,257.36 4,172.76 4.00 102.28 5,967,242.99 523,114.84 10,300.00 87.68 296.36 5,979.91 1,246.88 -6,348.36 4,254.01 4.00 102.21 5,967,283.91 523,023.69 10,400.00 86.85 300.27 5,984.69 1,294.24 -6,436.28 4,338.99 4.00 102.08 5,967,330.93 522,935.59 10,500.00 86.03 304.20 5,990.90 1,347.47 -6,520.68 4,427.28 4.00 101.90 5,967,383.82 522,850.99 10,600.00 85.23 308.13 5,998.52 1,406.29 -6,601.17 4,518.47 4.00 101.65 5,967,442.32 522,770.28 ,10,620.00 85.08 308.91 6,000.21 - 1,418.70 -6,616.76 4,537.01 4.00 101.35 5,967,454.67 522,754.64 TD i 10/12/2010 2:33:46PM Page 3 COMPASS 2003.16 Build 69 ORtGINAL ConocoPhillips [ r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2Z-23 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2Z-23 @ 112.00ft(2Z-23) Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-23 Survey Calculation Method: Minimum Curvature Wellbore: 2Z-23AL1 Design: 2Z-23AL1_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2Z-23AL1 t4 0.00 0.00 6,009.00 994.68 -5,525.88 5,967,034.96 523,847.06 70°19'15.831 N 149°48'24.002 W -plan hits target center -Point 2Z-23AL1 t3 0.00 0.00 6,028.00 764.29 -5,177.74 5,966,805.96 524,196.07 70°19'13.568 N 149°48'13.838 W -plan hits target center -Point 2Z-23AL1 t5 0.00 0.00 5,975.00 1,168.16 -6,154.29 5,967,205.97 523,218.05 70°19'17.533 N 149°48'42.345 W -plan hits target center -Point 2Z-23AL1 t2 0.00 0.00 6,019.00 453.31 -4,935.92 5,966,495.96 524,439.08 70°19'10.511 N 149°48'6.775 W -plan hits target center -Point 2Z-23AL1 t6 0.00 0.00 6,000.00 1,419.00 -6,617.37 5,967,454.97 522,754.03 70°19'19.996 N 149°48'55.866 W -plan hits target center -Point 2Z-23A,AL1 Polygon 0.00 0.00 0.00 1,665.78 -6,808.43 5,967,700.97 522,562.03 70°19'22.421 N 149°49'1.448 W -plan misses target center by 6006.25ft at 10500.00ft MD(5990.90 TVD,1347.47 N,-6520.68 E) -Polygon Point 1 0.00 1,665.78 -6,808.43 5,967,700.97 522,562.03 Point 2 0.00 1,168.00 -5,584.22 5,967,208.03 523,788.06 Point 3 0.00 660.92 -4,800.10 5,966,704.07 524,574.08 Point 4 0.00 -132.52 -4,451.12 5,965,912.08 524,926.12 Point 5 0.00 -92.33 -4,238.95 5,965,953.10 525,138.11 Point 6 0.00 -397.11 -4,305.13 5,965,648.09 525,073.13 Point 7 0.00 -448.93 -4,610.36 5,965,595.08 524,768.14 Point 8 0.00 -284.42 -4,738.74 5,965,759.07 524,639.13 Point 9 0.00 521.12 -5,116.67 5,966,563.05 524,258.09 Point 10 0.00 822.24 -5,655.56 5,966,862.03 523,718.08 Point 11 0.00 1,332.20 -6,926.73 5,967,366.96 522,445.05 Point 12 0.00 1,665.78 -6,808.43 5,967,700.97 522,562.03 2Z-23A,AL1 fault 2 0.00 0.00 0.00 1,247.95 -5,589.90 5,967,287.95 523,782.06 70°19'18.322 N 149°48'25.876 W -plan misses target center by 5990.98ft at 9900.00ft MD(5977.49 TVD,1119.27 N,-5970.60 E) -Polygon Point 1 0.00 1,247.95 -5,589.90 5,967,287.95 523,782.06 Point 2 0.00 943.93 -5,594.07 5,966,983.95 523,779.08 Point 3 0.00 862.25 -5,679.40 5,966,901.95 523,694.08 Point 4 0.00 943.93 -5,594.07 5,966,983.95 523,779.08 2Z-23A,AL1 Hard Lin 0.00 0.00 0.00 1,167.92 -5,58421 5,967,207.96 523,788.06 70°19'17.535 N 149°48'25.708 W -plan misses target center by 5990.16ft at 9900.00ft MD(5977.49 TVD,1119.27 N,-5970.60 E) -Polygon Point 1 0.00 1,167.92 -5,584.21 5,967,207.96 523,788.06 Point 2 0.00 1,664.70 -6,808.42 5,967,699.89 522,562.04 Point 3 0.00 1,331.12 -6,926.72 5,967,365.89 522,445.06 Point4 0.00 1,664.70 -6,808.42 5,967,699.89 522,562.04 2Z-23A,AL1 fault 1 0.00 0.00 0.00 859.54 -4,984.34 5,966,901.95 524,389.08 70°19'14.506 N 149°48'8.196 W -plan misses target center by 6026.50ft at 8180.00ft MD(5970.26 TVD,89.69 N,-4697.86 E) -Polygon Point 1 0.00 859.54 -4,984.34 5,966,901.95 524,389.08 Point 2 0.00 455.17 -4,900.89 5,966,497.95 524,474.10 Point 3 0.00 474.10 -5,140.85 5,966,515.94 524,234.10 Point 4 0.00 455.17 -4,900.89 5,966,497.95 524,474.10 2Z-23AL1 t1 0.00 0.00 6,002.00 269.76 -4,798.62 5,966,312.96 524,577.08 70°19'8.707 N 149°48'2.765 W plan hits target center 10/12/2010 2:33:46PM Page 4 COMPASS 2003.16 Build 69 IvConocoPhillips Ifr ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2Z-23 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2Z-23 @ 112.00ft(2Z-23) Site: Kuparuk 2Z Pad North Reference: True Well: 2Z-23 Survey Calculation Method: Minimum Curvature Wellbore: 2Z-23AL1 Design: 2Z-23AL 1_wp01 -Point _ __.----- --- -- Casing Points i I Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 4,242.00 3,362.28 9-5/8" 9-5/8 12-1/4 10,620.00 6,000.21 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nt-S +EI-W (ft) (ft) (ft) (ft) Comment 8,100.00 5,964.02 13.58 -4,674.33 TIP/KOP 8,180.00 5,970.26 89.69 -4,697.86 2 8,340.00 5,995.58 229.90 -4,769.00 End of DLS 12 8,490.00 6,011.09 347.97 -4,860.09 4 8,660.00 6,021.01 486.45 -4,958.03 5 8,760.00 6,025.33 569.70 -5,013.23 6 9,020.00 6,028.29 767.49 -5,181.41 7 9,220.00 6,022.06 892.31 -5,337.08 8 9,570.00 6,001.01 1,044.81 -5,650.44 9 9,820.00 5,982.96 1,105.00 -5,892.09 10 10,020.00 5,974.34 1,147.26 -6,087.21 11 10,620.00 6,000.21 1,418.70 -6,616.76 TD I 6 f l I 1011212010 2:33:46PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Project Kuparuk River Unit7 2�. WELLBORE DETAILS:22.23,87.1 RSH+LIKE NFORIMT ON Site.Kuparuk2Z Pad - Coar6,tate(WE)Reference 06022.27 True NOW rdI Well:7Z-23 paa Parent Wellbore:22.23.4 I., mpu.rame'n verlca(ivot Rereren.me.Sea lava ire tr( yyat CoroeoPhiUhps e'pUt l Dve 1.4201u Tie m MD:8100,00 �K/A iG WebOte:22-23,87.1 np-u.E Saolon(VS)Reference Sot•(000N 0.00E) P1r1:27.23,87.1_ ?2-23/22-23,87.1 xww az;cxcory Meaepe4 Dept)Reference 2Z230112000(27.23) -._ Ca laoonW at L1i°mmcmape HUGHES 210 - ..._,. _ ._ ...,_..,.......... .-r S 1050 I II WELL DETALS:22-23 .11 Ground Level: n oo l -. ♦NS .0.00 Nor0201 Eae4rg LSIaluae Longitude SAW 1 22-2' Z7, 0.00 0.00 5966062 01 52937625 70.19'6.069 N 149.45'42]41 W 1 _ _-.-_I n SECTION DETALS ANNOTATIONS r J 23.22-2ALi n Sec MD Inc Aa TVDSS +96-S •EFW OLeg Trace VSec Target Annotafon 1- -... y n i 1 1 810000 90.32 34282 596402 1358 -467433 000 0.00 2348.9 TIP/KOP 13 1 - 2 818000 80.72 34282 597026 89.69 4697.86 1200 180.00 2426.60 2 1 \\ = '-_ _..__*__.1 TD - 3 8340.00 8124 323,38 599558 229.90 -076900 12.00 27000 258360 End 01 DLS 12 1 fi- I I 1 4 0490.00 86.88 321.33 6011.09 347.97 -4860.09 4,00 34000 2731.40 4 ' "^- - 5 8660.00 86.43 328.13 6021.01 486.45 -0958.03 4.00 94.00 290029 5 1 1 6 8760.00 88.62 324.77 6025.33 569.70 •501323 4.00 303.00 2999.99 6 O r _ .. _ a 7 902000 90.08 314.48 6028.29 787.49 Fort -4"` F -`- "' -. 10 �4 _ _ •5181.41 4.00 27800 3255.37 7 1 8 9220.00 93.48 392.96 6022.06 892.31 533708 8.00 286.60 3441.31 8 `-� 9 9 9570:00 93.38 288.94 6001.01 1044,81 -5650.44 4.00 27000 373005 9 -Y 9" " ! _ - _.. 1', _.. _.. I 10 9820.00 94.88 279.03 5982.96 1105.00 -5892.09 4.00 279.00 3903.00 10 8 11 10020.00 9005 285.41 5974.34 114726 -6087.21 4.00 127.00 4037,17 11 c 7r I - 1 - 1 ' 12 10620.00 85.08 308.91 6000.21 1418.70 8616.76 4.00 102.30 4537.01 TD I 7 \ ..‘IaI ] I °' \,.. ;Iw t I II I \ �I , 15 - _ _ - 0.. .. ....... .......................... 6665D}a12 2 I 6 , 1TW..1 r,- ,- ,+- . , I.. 1.. r.. I ...I , P -7200-7050-6900-6750-6600-64511-6346-6150-6000-5850-5700-5550-5900-5250 5100-4950-4800-4650-4500 est- + In 5500 1 I I 1 .... -+- ,---`- I I I w 0 58,1 i.. } '' 1. DI 101 TIE tier __. y 1 11 1 z_}ar.ai f rrdnrnL51 r 2Z-23'1 1 /27.-2-3.6L11 j a 6301 I 4 I E" ! I I I I fI , 1400 1500 1600 1700 1000 1900 2080 2190 2200 2306 2400 2500 2600 2700 2801 2900 5000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4606 4700 4800 4900 5000 5100 5200 • Vertical Section at 330.00°(100 ft/in) ORIGINAL I 11 Project:KMpa�uk River Unit .myeeJT�N..a61�• WELLBORE DETAILS:2Z-23A REFERENCE 6E0000T10N prig''..1; KMpark22 Pad ll .yam mp event WOIIbge:2Z-23 CooNrele(N,EJ ReM rd We,172.23,hue No0 �r Well:22-23 sveyv�S�0.emT �n'✓�l�'OI Reference:12.23 @ 112000112-H) Ali .,,,,.,.�( - W&b000 22-23A n p Tie on MD:7500.00S.pn 04) Ej UL IVWTT i��I� P6n:22-23A_wp03(2Z-7312223A) eatsm,o Depth Ref...,22.23 1120011(2 n°'O Dm''m'0 Me�reE O�tl�Rek -?Z-23@1/2.00fl(12.23) HUG_..___.. CBWaI NFfMO:Mrnimm CurvalMeN�I . ... .. .. Il ' I L r _ � _ I I , L3' I ..• .I. ; }- . 1f IL i ' "./;14,-.1.41.-'.1,....1.41 4I2X0f � 1 t .� .. 0 _ ut I . I I I I III: I ( 1 o- 2211 . , i ' I' 1' �i 131 { t 1211 i .. '',.,. I'.. 11111111S I i , ' ;1I I 11 \ . 0 �' lN -1 O I I H 1 1'. I'' ri I I _fin;.. i . i j -12 1 • 1 i _fn -loll i. 22 � j 2 1 f -.4-,-----1--,4c,--,--. -- — — .,,-t-.,-., 'r, 1-1111;-- �. � -+T.—,- I -9401-9204 9000-x300-3600 1134(0)-1400 3(x00 7x00-7600 7400.20 0.. 0 -; . 0 �; _ _: _,-4200 . . t :.: —37 -�.-, ._.,...r - _7200 7000-bit[NI-titi00-6400-ti,'00 4(410-5000-.iAW-540(1-5206-500(1-0300-4600-4400-0200-0000 3x00-3ti00.3400-32f10 3000-2R00-2600 24011 2200 2Z-23 @ 112.00ft(2Z-23) West(-)/East(+)(200 ft/in) ORIGINAL ConocoPhillips r�'" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2Z-23 Project: Kuparuk River Unit TVD Reference: 2Z-23 @ 112.00ft(2Z-23) Reference Site: Kuparuk 2Z Pad MD Reference: 2Z-23 @ 112.00ft(2Z-23) Site Error: 0.00ft North Reference: True Reference Well: 2Z-23 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2Z-23AL1 Database: EDM Alaska Prod v16 Reference Design: 2Z-23AL1_wp01 Offset TVD Reference: Offset Datum Reference 2Z-23AL1_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referen Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,100.00 to 10,620.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,257.90ft Error Surface: Elliptical Conic Survey Tool Program Date 10/12/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 60.00 7,500.00 2Z-23 GyroData(2Z-23) GYD-CT-CMS Gyrodata cont.casing m/s 7,500.00 8,100.00 2Z-23A_wp03(2Z-23A) MWD MWD-Standard 8,100.00 10,620.00 2Z-23AL1_wp01 (2Z-23AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") C') 4,242.00 3,474.28 9-5/8" 9-5/8 12-1/4 10,620.00 6,112.21 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2X Pad 2X-16-2X-16-2X-16 10,200.00 8,700.00 1,186.92 307.37 890.15 Pass-Major Risk Kuparuk 2Z Pad 2Z-16-2Z-16-2Z-16 Out of range 2Z-23-2Z-23A-2Z-23A wp03 8,100.00 8,100.00 0.00 0.34 -0.22 FAIL-No Errors CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/21/2010 3:41:53PM Page 2 of 7 COMPASS 2003.16 Build 69 ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser Annular Blind/Shear 2"Pipe/Slip(CT) Pump into Lubricator �TI�\/� L ❑ // above BHA rams ►Imo/�' j/<><� r Choke 1 'I 2-3/8"Pipe/Slip(BHA) I Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) ' I KillJ L ►I>�1<X '>< � ► W ► r Blind/Shear 2"Pipe/Slip(CT) low Choke 2 'Swab Valves •• L Wing Valves WWI Mpg Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST t / WELL NAME PTD# 40. L f Z" DevelopmentExploratory. Service Ex lorato Stratigraphic Test Non-Conventional Well FIELD: eu _ fz--, lam' POOL: ^ �� / Circle Appropriate Letter I 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 re GC ` (If last two digits in Permit No. Z/4-'1 1 ,API No. 50- 626)*- �Z-S - )I. W 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 C1 Ta U) 0) o a) a U) co a) 0 os _ C 0 a) 0 a 2 O 3 7 I O N O C a) 0 .Cr co cn O c 1) E 0 48 c = E O U) o C o a ._• a) Q) O 0 E co 0 m U L E cC) 0 2 2 cri M .3 n a 6o L 0 a Co v 0 = C a) N a) 3 3 2 (n o 0 3 rn -- o 2 2 a- 0 N z c y c - ° "0 p U O 3 O j - Q - a) O > < O a a@ a L a)a) a co 3 c o -a a) a) a) c o c o ami n ng @ a c r J D a 0 0 CO 0- >O N O w Cr) 3 co F L M Z N o E a a rn ou 6 O a) N C fa) .0 N ° a 5 .N E .> E > @ c 3 a m a N (0 0 y N 3 C a) 0 • a 0 N - 0. 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