Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
210-057
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. cP I 0 - 057 Well History File Identifier Organizing(done) "Iwo-sided II 0111111 IIII ❑ Rescan Needed H I IIIfl Hull RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Aor Quality Originals: I par OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: 0 OP if /s/ PI P Project Proofing II I BY: Maria Date: ` 3 Q /ii, /s/ nip Scanning Preparation I x 30 = 3 0 + ta a. = TOTAL PAGES J (Count does not include cover sheet) 64 BY: CMaria Date: 1 t 30 ! li. /s/ Production Scanning I 111111 11111 Stage 1 Page Count from Scanned File: 3 (Count does include cover heet) Page Count Matches Number in Scanning Pr partition: VY6ES NO illf BY: Date: //3 0 `4 Is! 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. 11E11111 I ReScanned 111111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111 I 19/99/91111 1A/all Hictnni Filc("mica.Pnnc rinn o I I o .c m Pl. m 2 -o cv) co co el ---0 a u- N \ a) • d ur Ce Ct d z° z v �� >o> J = 0 WI- 2 2 h �� Q (73 o -0 • r > 0 0 0 0 o o f Z d )• N N N N Z 0 y 0) U > Q J M M M M Z W co W 00 7 2 - C C C C C C _ = a) a a) a) a) a) E .. N I— a 0' .. OU O O O O O O E 0 LI Q c U _ m a a as N Z t M N N d U o c0N 0 °° M LO Ill M IX c co 00 0o ro 0, rn W 2 > p ✓ 0 o > d m Z c y cc CU a y 7 0 z` Fo- i0 Q Z o O 4) = c J 0. 0 = .� i 0 i I o 0 o >. E c Z J •U U U N Q `p 0 o NN a) iE a o N N LO to co U N U co J co J a F" % o o M Z o t0 N I 2 z CO cC i• zz c Y• a) t a p , o I d C Q Y 0 I I— a) ZI co r a` w Q C Z c-o w > > > > o o r T Q m"iii 0 E J CL aaii a) a4/i a`�i in iq Z 0 Ce CC C CL C m g c c c c c c ■ O a,) 0 0 0 0 0 0 • to E E ti v t> u E rn o = a) 0 O co y Z c c c c p p R Z I O p Z j1ilp H 0 O O 0 C 01.a J Q ) 7/3 z a N V « Z lL go p O 0 \\U \i p O �' a�i d R0 y J � � l l U 2 U ur to•a>—, E a N O I _ d L C O a W I a T O O O 1 o F- 3 � cI- W -I -I J W a 0 <X 0 1 U STATE OF ALASKA ALASKA uiL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Perforations ❑ Stimulate r Other p PROD to WINJ Alter Casing r Pull Tubing r Perforate New Fbol r Waiver ❑ Time Extension ❑ Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well rj 2.Operator Name: 4.Current Well Status: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fj Exploratory r -. 210-057 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service ❑ 50-029-21331-60 -r76 7.Property Designation: 8.Well Name and Number: ADL 25635,25640 .,1 R-06AL1 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 11585 feet Plugs(measured) None true vertical 6635 feet Junk(measured) None Effective Depth measured 11585 feet Packer(measured) 8435,8909 true vertical 6635 feet (true vertucal) 6266,6628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 12 4659 3694 0 0 WINDOW"A" 12 8 8832 8832 0 0 PRODUCTION 9244 7 9279 6729 0 0 "A"LINER 785 2.625 10245 6635 0 0 0 0 0 Perforation depth: Measured depth: Slots: 10126-11583 True Vertical Depth: 6683-6635 RECEIVED Tubing(size,grade,MD,and ND) 3.5,J-55,8931 MD,6640 ND DEC 0 1 2010 Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER @ 8435 MD and 6266 ND tSiB`.:` U'I Gas Cons. Commission PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND AncSor8Q8 SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 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 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 429 1195 109 1500 159 Subsequent to operation 1089 700 1864 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service �i 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ T SUSP r SPLUG ❑ 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 310-331 _ Contact Bob Christensen/Darrell Humphrey Printed Name Ro.ert ! Christensen Title Production Engineering Specialist Signature . Phone:659-7535 Date Form 10-404 Revised 10/2010 RBDMS DEC 01 2010 `'t Submit Original Only 1 R-06AL1 DESCRIPTION OF WORK COMPLETED SUMMARY • Date Event Summary Pre Produced Injector turned to Water Injection service 10/28/10 TAG LINER TOP @ 8781' RKB. PERFORMED 30 MINS SBHPS @ 8500'RKB= 1943 PSI, 145 DEG F. 15 MIN GRADIENT STOP @= 1938 PSI. 10/29/10 SET 3.5"WEATHERFORD WRP@ 8455' USING 1-11/16"SHORTY LONGSTROKE • SETTING TOOL. CCL-ME=15.7'CCL STOP DEPTH-8439.3' 10/30/10 DEPLOYED 2.75 AVA CATCHER SUB ONTOP OF WRP @ 8455' RKB. PULLED GLVS @ 2043',4326', 6285',7615' RKB AND SET DV'S. PULLED OV @ 8381' RKB AND LEFT POCKET OPEN FOR CIRC OUT. 10/31/10 CIRC OUT TBG X IA. SET DV @ 8381'RKB. MIT TBG TO 2500 PSI. PASSED. MIT-IA TO 3000 PSI-PASS. IN PROGRESS. 11/01/10 PULLED CATCHER SUB AND WRP©8455'RKB. 11/27/10 Commenced Water Injection service a 1 KUP 1R-06.01 ConocoPhillips 8 ell Attributes Iltax Ankle&MD TD Al,f�,f.II I,. Weilbore API/UWI Field Name Well Status Inc((°) MD(MB) Act Btm(MB) Loroconrgn 500292133160 KUPARUK RIVER UNIT INJ 100.22 9,515.03 11,585.0 •-'' Comment H2S(ppm) Dam Annotation End Date 88-Ord(R) Rig Release Date Well Cones:-1R-06AL1,10/31/20109.3/:09 AM -SSSV:TROP Last WO: 37.61 5/15/1985 Schematic-Actual Annotation Depth(f8(8) End Date Annotation Lest Mod...End Date Last Tag: Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 HANGER,33- t ) Casing Strings Casing Descripton String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd Ili AL7 LINER 23/8 1.995 10,116.6 11,585.0 6,635.0 4.43 L-80 STL Liner Details I Top Depth CONDUCTOR, (TVD) Top Intl Noml... 38-110 Top(m(8) (R1(B) I°) Rem Description Comment ID(In) 10,116.6• 6,681.3 84.46 BILLET Aluminum Liner Top Billet 1.000 SAFETY VLV, S/'—1 Perforations&Slots 1908 Shot GAS LIFT, Top(TVD) Btm(TVD) Dens 2,041 - Top(11KB) Btm(RKB) (R881 (RKB) Zone Date (eh... Type Comment 10,126.0 11,583.0 6,682.6 6,635.3 627/2010 32.O'SLOT Altemating solid/slotted pipe- GAS LIFT 0.125"x2.5"@ 4 circumferential 4926 adjacent rows,3"centers staggered 18 deg,3'non-slotted ends SURFACE, -A r . 37-4,659 Notes:General&Safety GAS LIFT, j' End Date Annotation 5,631 1 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 GAS LIFT. r 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 8,20.5 ■ _ 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT. j 8,782 1 GAS LIFT, 7,188 II- GAS 7,8 LIFT, 75 GAS LIFT, 8,081 GAS LIFT, y 8.381 7 PBR,8,421 } PACKER,8,435 CATCHER, 8.454 I.°...1 PLUG,8,455 GAS LIFT, 8,473 GAS LIFT, 8,545 WHIPSTOCK, I 8,879 WINDOW W. ° 8,820.,832 GAS LIFT MMG,8,890 EFE4 LOCATOR, 1 L PACKER,8,909 C) 58E.8,913 } ( CIBP,8,921 NIPPLE,8,924 - l Mandrel Details SOS,8 931 -- Top Depth Top Port -- (TVD) not 01) Valve Latch Size TRO Run Stn Top(18(8) (RKB) (°) Make Model (in) Seen Type Type On/ (poll Run Date Com... 4 1 2,040.8 1,963.6 33.06 CAMCO KBUG 1 GAS LIFT DMY BK 10/30/2010 FISH,9,115 - 2 4,326.0 3,449.3 43.06'CAMCO KBUG 1 GAS LIFT'DMY BK 0.000 0.0 10/30/2010 3 5,630.9 4,355.6 49.21'CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 4,787.6 48.27 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 PRODUCTION, 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 • 35.9.279 6 7,198.2 5,396.4 47.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 k7 7,615.3 5,683.7 46.14'CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 sloT. 8 8,060.9 5,995.7 44.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10,126-11,583 9 8,381.1 6,225.9 42.60 CAMCO KBUG 1 12 PROD DMY rdo20 0.000 0.0 10/30/2010 AN 70.7L7 17-1LI1,ER.586 10 8,473.5 6,294.9 40.49 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 TD(18.6.11), II I�' 11,585 i KU P 1 R-06AL1 ConocoPhillips x •. COno0•PhiMps KB-Ord(R) Rig Release Date •• Well Config.-1R-86AL/,10/3120109.3009 AM __ _ — 37'61 5/15/198$ Schematic-Actual __ .�HANGER,33 q ••t1 CONDUCTOR, I 38-110 • SAFETY VLV. 1 1 IoJ 1,808 GAS LIFT. f 2.041 4 GAS LIFT, 4,325 SURFACE, J L. 371,689 GAS LIFT, j 5,631 OAS LIFT, 8,285 IF GAS LIFT, j 8,782 1 C GAS LIFT, 7,198 - GAS LIFT j 7,815 GAS LIFT, 8,081 GAS LIFT. 8,381 PBR,8,421 PACKER,8,435- ( CATCHER, _ 8,451 .1, PLUG,8.455 '/2A GAS LIFT, ,473 8,173 GAS LIFT, .545 8,515 I ill U II WHIPSTOCK, i I 8.819 WINDOW'W. 8,820-8,832 T1 IIIII GAS LIFT MMG,8,890 LOCATOR. m 8,908 '-4 PACKER,5909 SBE,8,913 r CIBP,8,921 NIPPLE,8,921 Mandrel Details 505.8.931 Top Depth Top Port (TVD) Inc! OD Valve Latch Site TRO Run Stn Top MKS) (RKB) (') Make Mode (In) Sery Type Type Ilk) (psi) Run Date Coon,. 4 11 8,544.5 6,349.5 39.15 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 FISH,9,115 12 8,890.3 6,616.8 52.78 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 5/21/2010 PRODUCTION, 35-9279 nL\ O SLOT, 10.12511.583 AL1 LINER, 15177 11.5R. TD(1 R.OBAL1), 11,585 . ✓ ° KUP 1 R-06AL1 ConocoPhilli ell Attributes ax Angle s MD TD Weilbore APIAIWI Field Name Well Statue Incl(°) MD(flAB) Act Btm(RKB) Alaska.Inc. 500292133160 KUPARUK RIVER UNIT INJ 100.22 9,515.03 11,585.0 Comment 425(ppm) Date Annotation End Dab KB13N(R) Rig Release Date Well contu.-1R0sAU,10/3112010 s34s7 AM SSSV:TRDP Last WO: 37.61 5/15/1985 Scherneto-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 ifwAiir HANGER,33 Casing Strings Casing Description String 0... String ID...Top(IIKB) Set Depth(I...Set Depth(TVO)... ng Wt.. String... String Top Thrd AL1 LINER I 23/8 I 1.995 I 10,116.6 'Set I 6,635.0 'String I L-80 I STL Liner Details Top Depth CONDUCTO +10 Top(RKB) (RKB) (°) item Description Comment ID(in) IJ El 10,116.6 6,681.3 84.46 BILLET Aluminum Liner Top Billet 1.000 SAFETY vLV. _ _l �o Perforations&Slots 1,908 Shot GAS LIFT, Top ITVD) etm(TVD) Dens 2041 r 11= Top MKS)Bbn MKS) MS) (RKB) Zone _ Date OK,. Type Comment Ell 10,126.0 11,583.0 6,682.6 6,635.3 6/27/2010 32.0 SLOT Altematingsolid/slottedpipe- GAS LIFT, I 0.125"o2.5"@ 4 circumferential 4, adjacent rows,3"centers staggered 18 deg,3'non-slotted ends SURFACE, 37°� Notes:General&Safety GAS LIFT, End Date Annotation 5.631 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 GAS LIFT, i 7/19/2010 NOTE WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 8,295 IIIII 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT. 6,762 GAS LIFT, 7,198 ( GAS LIFT I L 7,615 l GAS LIFT,�j 8,1181 T GAS LIFT, 1 .. 8,331 C PBR,8,421 PACKER,8,435 .IC. ..0. CATCHER, 8,454 PLUG,8,455 GAS LIFT, r 8,473 7 GAS LIFT. r� 8.545 1 imi WHIPSTOCK, \ I 8,819 111 WINDOW'A', • 8,8208,832 1 r t� GAS LIFT Jr'� WAG,8,890 r` LOCATOR, 8,9 i" 08 PACKER,8509- SBE,8,913 CIBP,8.921 NIPPLE,8,924 - Mandrel Details SOS,8,931 — -- -11.e. Top Depth Top Port (TVD) Ind OD Valve Latch Sine TRO Run Stn Top MKS) (RKB) I°) Make Model (in) Sery Type Type ON (p.0 Run Date Corn... 1 2,040.8' 1,963.6 33.06 CAMCO KBUG 1 GAS LIFT DMY BK 10/30/2010 FISH,9.145 4 2 4,326.0 3,449.3 43.06 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 3 5,630.9 4,355.6 49.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 4,787.6 48.27 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 PRODUCTION, 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 35-9.279 6 7,198.2 5,396.4 47.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 V7 7,615.3' 5,683.7 48.14 CAMCO KBUG 1 GAS LIFT DMY BK 0.000' 0.0 10/30/2010 SLOT, 8 8,060.9 5,995.7 44.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10.12611.583 9 8,381.1' 6,225.9 42.60 CAMCO KBUG 1 1/2 PROD DMY rdo20 0.000' 0.0 10/30/2010 ALt LINER, L - 10,++7-11.595 + TO(+R-O6AL1), ■ 10 8,473.5 6,294.9 40.49 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 11,585 KU P 1 R-06AL1 • ConocoPhillips Alaska,Inc. ' tmrxonaltips KB-Ord(R) Rig Release Date "' 37.61 5/15/1985 Well ContiLl-1R-06AL1,10131/N109.3057 AM Schematic-ACNal HANGER,33 tr CONOUCTO FI 38-110 0 J ' SAFETY VLV, 1.908 GAS UFT. j 2,041 1 GAS LIFT. - 1,328 SUCE, 37-RF1A,659 _ GAS LIFT, / 5,531 GAS LIFT, 6,285 GAS LIFT, 6,762 GAS LIFT, C 7,198 t GAS UFT, 7,615 OAS LIFT, _l 8,081 GAS LIFT, 8,381 KER, 8,421 PACKER,8,135 CATCHER, 8454 I.•_4 II PLUG,8,455 �7A GAS LIFT IMO 8,473 GAS LIFT, 8,545 WHIPSTOCK, _ I 8,819 WINDOW'A'. 0,820-8,832 • GAS UFT MMG,8890 LOCATOR, 8908 PACKER,8809 SBE,8,913 �.. CUSP,8,921 NIPPLE,8,924 - Mandrel Details SOS,8,931 - / Top Depth Top Port (TVD) lent OD Valve Latch Size TRO Run Stn Top(ftKB) MB) (9 Make Model (in) Sees Type Type (In) (pal) Run Dab Com... 11 8,544.5 6,349.5 39.15 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 FISH,9,115 - 4 12 8,890.3 6,616.8 52.78 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 • PRODUCTION. 35-9,279 1 1 SLOT, 10,126.11,583 _ _ ALl LINER, 1 . 85 TD 18(1 R1711,57),-OBAL 11,585 siroE 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 Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. I o 57 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1R-06AL1 Sundry Number: 310-331 Dear Mr. Christensen: 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 T- day of October, 2010. Encl. i 0 STATE OF ALASKA �(b 'p' A' ALASK JIL AND GAS CONSERVATION COMMISS._.4 E�J�'EMD lo-`'� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 S E P 2 9 2010 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r c�n e ppr ved Program Suspend r Rug Perforations r Perforate r Rill Tubing roam 0� Pion Operational Shutdown r Re-enter Susp.Well r Stimulate r After casing J 17 • g r Other: P f 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r. • Exploratory r 210-057 ' 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21331-60 - • 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 r 1 R-06AL1 • 9.Property Designation: 10.Field/Pool(s): ADL 25635,25640 Kuparuk River Field/Kuparuk Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total_depth�M�}{ft): Total Depth N,D(ft): Effective Depth MD4 t): Effective_Depth ND(ft): Plugs(measured): Junk(measured): 1155 �e�[O '0,.4''L 3 ic,�1V ii5V71 ,cb•;1•', 6-V, §7r' 4.;r u- Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 _ 110' 110' •SURFACE 4622 12 4659' 3694' WINDOW"A" 12 8 8832' 8832' PRODUCTION 9244 7 9279' 6729' "AU"LINER 1468 2.625 11585' 6635' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots: 10126-11583 6683-6635 3.5 J-55 8931 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER'FHL'PACKER MD=8435 TVD=6266 PACKER-BAKER'FB-1'PACKER MD=8909 TVD=6628 SAFETY VLV-CAMCO TRDP-1A SSSV MD=1908 TVD=1850 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Title: Production Engineering Specialist i i 1 Signature ,..r ; " A ,414 Phone:659-7535 Date Q Va.-7-//0 - Commission Use Only 2 Sundry Number:5/0 —331 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Subsequent Form Required: ,/ ..4/0 Lt ` APPROVED BY / Approved by* /e COMMISSIONER THE COMMISSION Date: / 0 /411 o Form 10-403 '7'h. ,• zlecr Q' •�/./p Submit in Duplicate .R 161 NAL �D /sC /dKb 1 R-06AL1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1 R-06AL1 (PTD 210-057)from Oil Production service to Water Injection service. Well 1 R-06AL1 (CTD Sidetrack)was completed in the Kuparuk formation on July 19, 2010 as a pre-producing injector with initial production commencing on July 25, 2010. Conversion to Injection service is required due to potential reservoir depletion. The 16"Conductor was cemented with 215sx of CS II. The 9-5/8" Surface casing (4659' and/3694'tvd)was cemented with 1390sx Permafrost E and 425sx PF C. The 7" Production casing (9279' and/6729'tvd)was cemented with 510 sx Class"G"and 250sx PFC. The top of the Kuparuk B sand was found at 8820' and/6568'tvd. The top of the Kuparuk AS sand was found at 9455' and/6727'tvd. The injection tubing/casing annulus is isolated via Baker FHL Packer located @ 8435' and/6266'tvd. . r ° KUP 1R-06AL1 ConocoPhillips • ieli Attributes Max Angle&MD TD Wellbore APIAIWI Field Name Well Status Inc'(") MD(RKB) .Act Btm(ftKB) Alaska,Inc. 500292133160 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Date K8-Ord(R) Rig Release Date ... Well coar.9.-1R-WAL1.721201012:42:44 PM -SSSV:TRDP Last WO: 37.61 5/15/1985 Schematic-Actual Annotation Depth(MEI) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 RANGER 33 - 'i " Casing Strings 'r Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt.,.String...String Top Thrd - "l AL1 LINER 12 3/8 I 1.995 I 10,116.6 I 11,585.0 I I 4.43 L-80 I STL • I Liner Details CONDUCTOR, Top Depth 38.110 (TVD) Top Ind Nomi... Top IRKS) (RKB) (°) Item Description Comment ID(In) 10,116.6 BILLET Aluminum Liner Top Billet 1.000 SAFETY VLV, I & 1,906 _» Perforations&Slots Shot GAS LIFT, _ Top(TVD) Btm(TVD) Dens 2,041 _ Top(RKB) Btm(RKB) (RKB) (RKB) _ zone Date Ins..• Type Comment 10,126 11,583 6/27/2010 32.0 SLOT Alternatingsolid/slottedpipe- GAS LIFT, 326 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered SURFACE, 18 deg,3'non-slotted ends 37-4,659 GAS LIFT. Notes:General&Safety 8831 End Date Annotation 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED GAS LIFT, 8,285 7/21/2010 NOTE:View Schematic w/AlaskeSchematic9.0 IMI OAS LIFT, 6,762 OAS LIFT. _ . 7,1W GAS LIFT, e. _ 7,815 0AS 8 LI0FT, ,81 OAS LIFT, 8,381 PBR,8,421 PACKER,8,435 GM LIFT. 8,473 GAS LIFT, j 8,545 T WHIPST8,819 OCK, WINDOW'A', • 8,8208,832 MN GAS LIFT MMG,83390 _ LOCATOR. 8,908 M I, PACKER,8,909 SBE,8.913 W CIBP,8,921 NIPPLE,8,924 NE SOS.8.931 I� FISH,9.145 Mandrel Details !Top Depth Top Port (TVD) Incl OD Valve Latch Sloe TRO Run Stn Top(RKB) )RKB) I') Make Model (In) Sery Type Type (In) (p81) Run Date Corn... PRODUCTION. 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 35-9,279 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 SLOT, 9,471,10,244 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV 'BK 0.156 1,319.0 7212010 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 6/30/1985 "A'LINER, 9,460.10,245 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 SLOT, 10.126-11,583\ 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 11/10/1987 TD(IR-MALI). \ 10900 9 8,381.1 CAMCO KBUG 1 12 PROD OV 'rdo20 0.188 0.0 7/21/2010 AL1 LINER, ■ 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN ' 0.000 0.0 11/21/1993 13.117-11,585 ill ill IIIMNZ Cog fltz c' . ... ... ,f , „ -.,•,,,::::: r - - ' - r,"--. -:....,:4r• ---- — F ., .. . :... ' . 1 1....LJ , _.,...,„, ---,• :::.--3 0 ' ' " • - ' -.14•1.--4- .,-7., _. •!,: -=•••.: . .-. ._ .. . :„. : . . . . • , . . . • . . . •_ .. • ,...:„.:::, . .:.•.- -.•:::. - . • . . .! . • .. • a3 ..41—, Cli ... . . . . . . ._. ,..„ .... . ... . ..„ ., . . , . _. . . . .. .. . ...:, . ,. , , . .. ...... . . . „ ... .. .. , . . . .. „, . . . . -IC : ..:... .:, ,... . , „ , . . .., . . , . .. . , ..• . . , . . . CO . a) •• . . . . . .... , . , . . C - . . . a) ,.... (0 ea —, Ia' ____ .c.) _ .._ cy) co ,— 1) a. < . C Zs E .,----: c a z 0 ... 0 03 u) 5 1— Lu 4..' 0 CO 0 CO CIO '.— (i) ■- *6 -:i 5 1.1 71 a) . EL s_ u.1_a) -=-I 2 co -=-'= 2 cn _ a) Lu- _ _92 I II Lu l 4 8 a) 0 > E Ca a) 8 rn -Ii-e •-•.,' `-- * — CD CO u_ •r_.- a.) C6 Li_ 7: 0 .0 u_ C " —I C •' CC M EL 6: as u- E : LL ;-,-- co-- a)• a. 0) _ 0 >, - t. rz E gi 17- ,?,- cliti I= III 0 ai Z en CO ii: 2 ca. _.-, o o „ .._ _le o E ' 0 0 '6 -- 2 015 -- TS "6 --- CD 2 ' 2 ' 1E 2 o 2 i 4--' g T.--, c,__ -. LE . ,, -2 . 0 (71j i w 0 cid,.p. (13 CO 01 CT) - 2 Li: 0 CD C) a..5- cl.0 ,-. co c_.a.) Fo• 03 = as _ 0 cu _ 0 i_ ‘- i ,-. E .c — ..— o. < _ = • . o (n .. • 0. c) u• .1. 6-- = •- , O al cx _c c • -- O ce co a. c.) — o c.) co O S co o 0 C cn C) iE .c2- .— = m ,, 0 3 E cv * ,, c..) C') os co E op c., 3 a 0 2 P 6 15 t° c. el >+ 4) 0 0 i ... U CD ci o a) • . c • E To o r. 0 c co Lj c • o. ‘-. ‘- .-. 0 c a) a > o v- „.., - o o etS ca CD scs) C) g 1E c„i cs) - .= ,,..°) go a) to Zs; CI CO ID E a) a) s- = a, 01 CL CD ^to 1.r. CO fT3 I .. ocL O Tu !0; 4. 0 2 5 ;CD 2 C 0) • _) O — C;0 • , cy, C C < CIS co t— co m = 4 ea :ii, irr 6. cc •E cn a > u) ■ < o."c3 w „x cn 0 . 0 I: R ii m cf, R 0C u esi ZE 5 - R .., .J- .2- (.) .• - U co .= u — to .r. CD ‘u ,11, <IC • - -= __ 4) 6, := ,L- •, - D. :E r- 0 c c ,- (1) 2, MC cq dc ..,... __ „ ai cu 1.1. Z -C3 0.—I 1E . . wct CA < E Cl a M V 4.a CM .0 CD CD ,• 01 < ...• Cl `c.' W 16' CU z.; CL. < I.— 0 Z 2 i-; la 06 lin icit o 2 fct LO a%) g ox 2 px ut ox .so) 0_ ci: .c = c.) 8 = cm (., •• 0 ,., LU 4: __I 0 M C) 'ig 3: 2 15 T3 W .11? > C co Ji 72 0 3i .2 c < c) te a) es , 0 c o z (9 .c 0 >-• E5 0 u .5 a ,7, == c 1.. 0 0 c ..x , iri 0 1: ,., C.3 t: 5 ri C.) LIJ C (-) ,11 ." CO C.) W0 .17. 00 .c .C: OW I— 0 c O . 0. 0 .0 6 C 0.. 0 co •-• c - I a) 0 , - ..,03 ii-, a (i) O cs, cl: < 0 0 0: 1- I STATE OF ALASKA 4 ALASKA _ AND GAS CONSERVATION COMMISSIUN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r Other r Pre-Prod Inj Alter Casing r Rill Tubing r Perforate New Pool Waiver <30 days r r Tine Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-057 3.Address: `6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21331-60 7.Property Designation\ 8.Well Name and Number: ADL 25635,25640 1 R-06AL1 9.Field/Pool(s): '` Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 11585 feet Plugs(measured) None true vertical 6635 feet Junk(measured) None Effective Depth measured 11585 feet Packer(measured) 8435,8909,8921 true vertical 6635 feet (true vertucal) 6266,6628,6634 Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 9.625 4659 3694 0 0 PRODUCTION 9244 7 9279 6729 0 0 Slotted Liner 1468 2.375 11585 6635 0 0 Perforation depth: Measured depth: Slotted 10126-11583 RECEIVED True Vertical Depth: 6683-6635 1, 1 3 Zulu Tubing(size,grade,MD,and TVD) 3.5,J-55,8931 MD,6640 TVD Alaska MI&r�C5rOlts.Commission Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER @ 8435 MD and 6266 ND PACKER-BAKER'FB-1' PACKER @ 8909 MD and 6628 ND BILLET @ 10117 MD and 6683 ND SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 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 Subsequent to operation 781 3029 760 1267 164 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WAG r GASINJ r VVI0 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 N/A Contact Bob Christensen/Darrell Humphrey Printed Name 7o•e D. Christensen Title Production Engineering Specialist Signature r y ' - ..„1,‘ --........................_ Phone:659-7535 Date .0 zriniA a Form 10-404 Revised 7/2009 J— 9 �' MOMS ww 1 a Submit Original Only 1 R-06AL1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/20/10 MEASURED BHP @ 8500' MD: 3154 PSI. SET CATCHER. PULLED DV @ 8381' RKB, SET 3/16"OV @ SAME. PULLED DVs @ 7615' &6285' RKB, SET GLVs @ SAME. IN PROGRESS 07/21/10 PULLED DVs @ 4326' &2041' RKB. SET GLVs @ SAME. BLED IA TO CONFIRM GLVs SET. PULLED CATCHER. COMPLETE. 07/25/10 OPEN WELL- RETURN TO SERVICE • • KUP 1 R-06AL1 Conoco✓Phillips :ice Alaska.Inc. KB-G ld(It) Rig Release Date ••• Well Conao.-1R-06AL1 7/212 2:01012:444 PM — 37.61 5/15/1985 Schemata-Actual • MANGER,33- -s CONDUCTOR, �� I 38-110 SAFETY VLV. -" 1,908 O. GAS.0 2, 1 041 GAS LIFT. 4.326 SURFACE, 37-4,659 GAS LIFT, 5,631 GAS LIFT, - 6,285 GAS LIFT, 6,762 GAS LIFT, _ t 7,198 GAS LIFT. 7,615 GAS LIFT, 8,061 T GAS LIFT. JJ 9,381 - Y POR,8,421 PACKER,8,435 11.dit aleti1 GAS LIFT, 8,473 MID GAS LIFT, _....8.545 i L WHIPSTOCK, 8,819 WINDOW'A', 8.8208.832 �1 • GAS LIFT HMG,8,890 pi mit LOCATOR, 8,908 1'4 PACKER,8,909 S8E,8,913 CIBP,8,921 NIPPLE,8,924 SOS,8,931 FISH,9,145 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Ste Top(R148) (RKB) (1 Make Model lint Same Type Type (in) (psi) Run Date Coot... PRODUCTION, 11 8,544.5 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 35'9'2 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 9,471-10SLOT,,244 'A'LINER, 9,46010,245 SLOT, 10,12611,563 TO(IR-O6AL1), 10,940 ALl LINER, __J ■ 10,117-11,585 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development NI Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: July 19,2010 • 210-0570/ • 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 23,2010 • 50-029-21331-60 . 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 272'FNL,222'FEL,Sec. 19,T12N, R10E,UM • June 27,2010 1R-O6AL1 . Top of Productive Horizon: 8. KB(ft above MSL): 84'RKB . 15.Field/Pool(s): 69'FSL,825'FWL,Sec. 19,T12N, R10E,UM GL(ft above MSL): AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 422'FNL,2278'FWL,Sec.30,T12N,R10E, UM 11585'MD/6635'TVD Kuparuk River Oil Pool ` 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-539470 • y- 5990930 • Zone-4 • 11585'MD/6635'TVD • ADL 25635,25640 TPI: x-535722 y- 5985973 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-537177 y- 5985488 Zone-4 1908'MD/1850'TVD 2560 18.Directional Survey: Yes il 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) 1550'MD/1527'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/ND GR/Res 9455'MD/6727'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 215 sx CS II 9.625" 36# J-55 Surf. 4659' Surf. 3694' 12.25" 1390 sx Permafrost E,425 sx PF C 7" 26# J-55 Surf. 9278' Surf. 6975' 8.5" 510 sx Class G,250 sx PFC 2.375" 4.7# L-80 10116' 11585' 6682' 6635' 3" slotted liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8932' 8435'MD/6266'ND slotted liner from 10125-11583'MD 6683'-6635'ND 8909'MD/6628'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. } COMPLE71QN DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED iljitki none YI 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) July 25,2010 pre-produced injector-flowback in progress Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/31/2010 16 hours Test Period--> 389 2317 459 209% 5952 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 165 psi 1263 24-Hour Rate-> 584 3476 _ 689 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 . If Yes to either question,list formations and intervals cored(MD+ND 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. RECEIVED NONE /0,1 I; 0 4 2010 Alaska MI&Gas Com Commission Form 10 407 Revised 1FABDmS AUG 0 4 10 Submit CONTINUED ON REVERSE Submit original only 4%`, i(' ( /� w / 6 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1550' 1527' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A Sand 9455' 6727' N/A Formation at total depth: Kuparuk A5 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cary Eller @ 263-4172 Printed Na•e V. , e Title: Alaska Wells Manager Signature Phone 265-6306 Date V Q 1,5/ 0 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 TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23:If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T ' Comment 16:00 17:00 1.00 0 0 PROD1 DRILL PULD P At Surface, PJSM, Flo check well. Lay down BHA#7 Blow down tool, Bit looks good 2 plugged nozzles 17:00 17:15 0.25 0 0 PROD1 DRILL BOPE P Perform Bi-Weekly BOPE function test 17:15 20:40 3.42 0 850 COMPZ CASING PUTB P PJSM-P/U Liner.Crew change,cont to run liner. MU liner run BHA#8.On well surface test. 20:40 23:19 2.66 850 8,647 COMPZ CASING RUNL P Tag up,open EDC. RIH @ 60 fpm. Fluid losses—8 bbl/1000 ft. 23:19 23:58 0.66 8,647 9,900 COMPZ CASING RUNL P RIH to 8647'.EOP correction+9'. Close EDC,circulate aound the back side, RIH. 06/22/2010 RIH"A"liner with billet. Set liner at 9455'TOL, 10240'BOL. POOH laying in 9.4#FloPro. Performed injector head repairs: replaced chains,skates,and skate-bearings. Lined up to pump slack management. 00:00 100:15 0.25 9,900 11,245 COMPZ CASING RUNL P Continue RIH with"A"lateral liner 00:15 00:45 0.50 11,245 10,469 COMPZ CASING RUNL P Liner on depth(9460'to 10245'). Top slip of anchor orientated high side. Set anchor:press up 3600 psi,broke back.WOB went from 1.25K to 6K. CT wt went from 12.9K to 11.6K. 00:45 02:20 1.59 10,469 8,815 COMPZ CASING TRIP P PUH into casing. PUW=29K. Stop at 8815',tie-in Circulate out KWF with 9.4 ppg FloPro. Lost 145 bbl NaBr KWF total. 02:20 02:39 0.33 8,815 8,374 COMPZ CASING DLOG P PUH and RIH to tie,-5ft correction. TOL=9455, BOL=10240 02:39 04:51 2.20 8,374 0 COMPZ CASING TRIP P POOH at 70 fpm,20K.Circ 1.47 bpm w/1.2 bpm returns. 04:51 06:58 2.13 0 0 COMPZ CASING PULD P PJSM,Undeploy BHA#8 Liner running tool 06:58 22:58 16.00 0 0 PROD2 DRILL RGRP T Injector repairs. Unstab pipe. Remove injector chains and inspect skates/bearings. Find two cracked bearings in addition to known crack in chain. Reinstall new skates and new bearings. Re-install chains, gripper blocks,and guards. Install stripper and stab pipe. Holding MPD pressure at surface for 11.8 ppg EMW at window. Losses for entire time while OOH was 2 bbl. NAD Non-Billable Rig Repair time 16-hrs. (0700-2300 hours: 16-hrs cum nbh for 6/22/10) 22:58 23:58 1.00 0 0 PROD2 DRILL SLPC T Line up and begin to pump cable up CT for slack management. 06/23/2010 Completed slack management and pressure deployed BHA#9. Tagged billet at 9455'and sidetracked off billet for AL1 lateral. Drilled ahead AL1 to 9605'. Lost 2 BBL 9.4#Powervis to formation. Page 8 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase` Code Subcode T Comment 00:00 01:00 1.00 0 0 PROD2 DRILL SLPC T Continue slack management and cut 20'pipe to cable. 01:00 03:00 2.00 0 0 PROD2 DRILL RGRP T Re-head, pick up BHA#9 and prep to pressure deploy. NAD Non-Billable Rig Repair time 2-hrs. (0100-0300 hours:2-hrs cum nbh for 6/23/10) 03:00 03:30 0.50 0 0 PROD2 DRILL SLPC T Displace CT to FloPro. 03:30 03:42 0.20 0 0 PROD2 STK SFTY P PJSM for deployment 03:42 05:42 2.00 0 0 PROD2 STK PULD P Deploy BHA#9 05:42 07:42 2.00 0 8,350 PROD2 STK TRIP P RIH 07:42 08:06 0.40 8,350 8,380 PROD2 STK DLOG P tie in,+8' 08:06 08:54 0.80 8,380 9,455 PROD2 STK TRIP P Close EDC and RIH to billet 08:54 10:36 1.70 9,455 9,456 PROD2 STK KOST P Tag top of billet, PU and bring pump online at 1.4 BPM,3500 CTP,4190 BHP. PU and start time drill at 1 FPH from 9454.8'. Note:With EDC open,annular pressure sensor reading 100 psi higher than internal BHA pressure. Also causing dP to read 100 psi lower than normal,and ECD to calculate 0.3 ppg higher than actual. Actual BHP is 4090 psi, 150 WHP, FS dP is 375 psi. 10:36 11:06 0.50 9,456 9,457 PROD2 STK KOST P Time drill at 2 FPH 11:06 11:30 0.40 9,457 9,458 PROD2 STK KOST P Time drill at 3 FPH 11:30 12:00 0.50 9,458 9,463 PROD2 STK KOST P Time drill at 10 FPH 12:00 12:36 0.60 9,463 9,483 PROD2 DRILL DRLG P Drill ahead, 12:36 13:06 0.50 9,483 9,483 PROD2 DRILL WPRT P PU and backream past billet at full pump rate, RBIH with pump down, clean. 28K PUW, 12K RIW 13:06 22:45 9.65 9,483 9,576 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3200 CTP, 150 WHP,4160 BHP.good drilling until encountering ankerite at 9524', ROP down to-5 FPH 22:45 23:20 0.59 9,576 9,605 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3400 CTP, 100 WHP,4175 BHP. ROP increase to-50 FPH. 23:20 23:59 0.66 9,605 9,605 PROD2 DRILL WPRT P Wiper trip. PUH to 8854(30K#), RBIH(12K#). 06/24/2010 Drilled AL1 lateral 9605'to 10256'. 00:00 00:12 0.20 9,605 9,605 PROD2 DRILL WPRT P Complete wiper trip. Back on bottom. 00:12 03:36 3.40 9,605 9,755 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3420 CTP, 95 WHP,4175 BHP. ROP -44 FPH. 03:36 04:36 1.00 9,755 9,755 PROD2 DRILL WPRT P Wiper trip. PUH to 8847(31K#), RBIH(12K#). Page 9 of 33 Time'Logs .,. Date From To Dur S.Depth E. Depth Phase Code ` Subcode T Comment 04:36 09:12 4.60 9,755 9,905 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3420 CTP, 95 WHP,4175 BHP. ROP -50 FPH. 09:12 09:54 0.70 9,905 8,850 PROD2 DRILL WPRT P Wiper trip to window,30K PUW. Motor work and 3K overpull at 9025' 09:54 10:06 0.20 8,850 8,880 PROD2 DRILL DLOG P Tie in,-2' 10:06 10:36 0.50 8,880 9,905 PROD2 DRILL WPRT P Wiper in hole, 11K RIW,stacked weight at 9058',pumping.5 BPM and saw slight-100 psi motor work. reaminder of trip in hole was clean 10:36 14:24 3.80 9,905 10,055 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM,3600 CTP, 4100 BHP,90 WHP,2-3K WOB, 200-300 motor work 14:24 15:42 1.30 10,055 10,055 PROD2 DRILL WPRT P Wiper trip to window,31K PUW 15:42 20:10 4.48 10,055 10,205 PROD2 DRILL DRLG P Drilling ahead, 1.6 BPM,3800 CTP, 4150 BHP,90 WHP,2-3K WOB, 200-300 motor work. -33 FPH. 20:10 21:49 1.66 10,205 10,205 PROD2 DRILL WPRT P Wiper trip. 30.5K#PUW, 10K#RIW. Saw slight weight bobble pulling up through 9030', and then 1000#WOB and-100-psi motor work running back down throught 9058'. Pumped 1.4 BPM through trip. Remainder of trip was clean. 21:49 23:58 2.16 10,205 10,256 PROD2 DRILL DRLG P Drilling ahead, 1.34 BPM,3350 CTP, 4150 BHP,45 WHP,2-3K WOB, 100-200 motor work. ROP back down to-5 FPH 10215'approaching 'Fault#1'. Total losses to formation for today: 5-BBL Powervis. Current mud system(#2)has 1701'; LSRV 46K;0.6%solids 06/25/2010 Drilled AL1 lateral 10256'to 10655'. Lost 189 BBL 9.4#Powervis to formation over 24-hour period. 00:00 03:00 3.00 10,256 10,355 PROD2 DRILL DRLG P Drilling ahead, 1.38 BPM,3500 CTP, 4172 BHP,68 WHP,2-3K WOB, 100-200 motor work. ROP-10 FPH. Appear to have penetrated fault at 10,300'with ROP increasing to 55-60 FPH. 03:00 04:00 1.00 10,355 10,355 PROD2 DRILL WPRT P Wiper trip to 8845';31.5K#PUW. 04:00 04:15 0.25 10,355 10,355 PROD2 DRILL DLOG P Log down 2.5-fpm for tie in. Determine correction of-6.5'. 04:15 05:00 0.75 10,355 10,355 PROD2 DRILL WPRT P Wiper in hole, 8K RIW. Stacked 8K#at 9058', pumping 0.5 BPM with no WOB nor motor work. Remainder of trip in'hole was clean. 05:00 08:48 3.80 10,355 10,505 PROD2 DRILL DRLG P Drilling ahead, 1.42 BPM,3600 CTP, 4195 BHP,30 WHP,2-3K WOB, 100-200 motor work. ROP-50 FPH. Start Mud swap 08:48 10:12 1.40 10,505 10,505 PROD2 DRILL WPRT P New mud around bit,Wiper to 9150', 32K PUW, clean trip both ways Page 10 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:12 22:30 12.30 10,505 10,632 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM,3600 CTP, 4200 BHP,250 WHP,2-3K WOB with 5-6K Surface weight, 100-200 motor work. 22:30 00:00 1.50 10,632 10,644 PROD2 DRILL DRLG P Appear to have broached thief zone at 10632'as returns fall to 0.3-0.4 BPM. ROP stays 4-7 FPH until seeing 40-50 FPH again around 10644'. All other parameters same. Lost 189 BBL 9.4#Powervis to formation over 24-hour period. 06/26/2010 Drilled AL1 lateral 10655'to 11255'. Lost 411 BBL 9.4#Powervis to formation over 24-hour period. Losses now down to 7-bbl/hr. 00:00 00:50 0.84 10,644 10,644 PROD2 DRILL DRLG P Drilling ahead 1.34 BPM(-0.5 BPM returns),3300 CTP,4255 BHP,300 WHP,2-3K WOB,6-7K#Surface weight. Drilling 40-50 FPH. 00:50 02:44 1.91 10,644 10,644 PROD2 DRILL WPRT P Wiper trip 10655-9142'. 28.7K# PUW, 9.5K#RIW. Clean through 9455'. 02:44 08:05 5.35 10,644 10,805 PROD2 DRILL DRLG P Drilling ahead 1.3 BPM(-0.6 BPM returns),3200 CTP,4250 BHP,330 WHP,3-4K WOB,Saw 70 FPH for brief interval then back down to drilling 4 FPH. Out of ankerite at 10670,drill ahead with improving return rate. Dropped BHP to 4100 psi, losing<0.1 BPM 08:05 09:29 1.40 10,805 8,845 PROD2 DRILL WPRT P Wiper to window,29K PUW,losing 0.1 BPM 09:29 09:41 0.20 8,845 8,870 PROD2 DRILL DLOG P Tie in,-6' 09:41 10:41 1.00 8,870 10,805 PROD2 DRILL WPRT P Wiper back in hole,9K RIW. Stacked weight at 9058', 10:41 13:29 2.80 10,805 10,955 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM, 1.3 returns, zero WHP,4100 BHP,3850 CTP. 2 -3K WOB with 3K Surface weight. 13:29 15:35 2.10 10,955 10,955 PROD2 DRILL WPRT P Wiper trip,29K PUW, 15:35 18:24 2.83 10,955 11,105 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM, 1.3 returns, zero WHP,4140 BHP,3850 CTP. 2 -3K WOB with 3K Surface weight. 18:24 20:48 2.41 11,105 11,105 PROD2 DRILL WPRT P Wiper trip to 9142'. 29K PUW. 20:48 23:33 2.75 11,105 11,255 PROD2 DRILL DRLG P Drilling ahead, 1.42 BPM, 1.2 returns,zero WHP,4160 BHP, 4190CTP. 2-3K WOB with-1K Surface weight. 23:33 23:57 0.41 11,255 11,255 PROD2 DRILL WPRT P Begin wiper to window,29K PUW, losing 0.2 BPM. Lost 411 BBL 9.4# Powervis to formation over 24-hour period. 06/27/2010 Drilled AL1 lateral to TD at 11585'. Displaced well to beaded liner running pill and 11.8#KWF. Prepared for BOPE testing. Lost 161 BBL 9.4#Powervis to formation over 24-hr period. 00:00 01:15 1.25 11,255 11,255 PROD2 DRILL WPRT P Continue wiper trip to window;29K PUW, losing 0.2 BPM. 01:15 01:30 0.25 11,255 11,255 PROD2 DRILL DLOG P Tie in:-7 Page 11 of 33 Time Logs Date" From ' To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:30 02:36 1.10 11,255 11,255 PROD2 DRILL WPRT P Wiper in hole. Stacked about 4K# surface weight down through 9058'. 02:36 06:54 4.30 11,255 11,405 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 1.2 returns, 22 WHP,4165 BHP,3900CTP. 2-3K WOB with-10K Surface weight. 06:54 09:42 2.80 11,405 11,405 PROD2 DRILL WPRT P Wiper trip,31K PUW, 11K RIW. Clean trip 09:42 11:06 1.40 11,405 11,472 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 1.2 returns, 22 WHP,4200 BHP,3800 CTP. 2-3K WOB 11:06 11:42 0.60 11,472 11,472 PROD2 DRILL WPRT T Stacking weight, PUH and become differentially stuck,After attempting to pull free at up to 60K,shut down pump and pulled once more to 60K, no movement. RBIH to 10K surface, 1K WOB and started pumping again. Had 75 PSI motor work,pulled up to 35K then continued PUH at 32K, PUH while circulating in high vis pill. 11:42 14:36 2.90 11,472 11,585 PROD2 DRILL DRLG P High vis pill at bit drilling ahead at 1.4 BPM, 1.2 BPM returns,3800 CTP, WOChoke and 4215 BHP,-6K to -10K surface weight for 2-3K WOB 14:36 15:18 0.70 11,585 11,585 PROD2 DRILL CIRC P Called TD at 11585'after coming out of the top of the formation. Pump low/high vis sweeps Notified AOGCC of 10PM BOP test time Witness waived by Bob Noble (14:45-hrs). 15:18 17:06 1.80 11,585 8,845 PROD2 DRILL WPRT P Wiper to window, 17:06 18:35 1.49 8,845 9,100 PROD2 DRILL DLOG P Tie in,-6'. RBIH 18:35 19:53 1.30 9,100 11,585 PROD2 DRILL WPRT P RBIH pumping beads at 10325'1.2 BPM, 35 FPM. Tag TD at 11585'. 19:53 21:59 2.11 11,585 0 PROD2 DRILL DISP P POOH laying in beaded liner pill 45 FPM, 0.4 BPM,WHP 350. Beads out of BIT at 8850'. Swap to KWF and time out KWF to be at window. Stop at 8798'. Pump 10 BBL beads above BHA. POOH pumping KWF window to surface. Stay on KWF to surface and decrease pulling speeds due to intermitent losses of returns. 21:59 22:24 0.42 0 0 PROD2 DRILL TRIP P At surface. Flow check well. Conduct PJSM regarding move off well, lay down of BHA. 22:24 22:54 0.50 0 0 PROD2 DRILL PULD P Lay down Drilling Assembly#2 (BHA#9). Bit grade out: 1/2/bt/n/x/i/wt/td. 22:54 23:58 1.08 0 0 PROD2 DRILL CIRC P Flush rig lines. Grease crew on location;grease tree valves. Prep for BOPE testing. 06/28/2010 Set AL1 liner at TD 11585';TOL is at 10116'. POOH and layed down liner running tools. P/U drilling assembly#3(BHA#11). Page 12 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase 1 Code Subcode T Comment 00:00 01:30 1.50 0 0 PROD2 DRILL CIRC P Circulate CT from KWF to water. BOPE test PJSM. 01:30 11:00 9.50 0 0 PROD2 DRILL BOPE P Perform BOPE test. Replace actuator on B5. 11:00 12:18 1.30 0 0 PROD2 DRILL DISP P Displace FW from coil with KWF, install checks in UQC, RU floor for liner ops,confirm hole is full,2.3 Bbls to fill 12:18 12:42 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations,discuss safety joint drill 12:42 15:00 2.30 0 1,468 COMPZ CASING PULD P Start running liner,safety joint drill after first joint in hole. Total of 45 joints slotted liner 15:00 16:00 1.00 1,468 1,513 COMPZ CASING PULD P MU aluminum billet,GS and Inteq liner running BHA,MU injector 16:00 17:42 1.70 1,513 8,713 COMPZ CASING RUNL P RIH 17:42 18:24 0.70 8,713 10,744 COMPZ CASING RUNL P Correct depth at flag,+14'. Wt. check,29K PUW, 13KRIW. Run through window and continue in open hole at 50 FPM. 18:24 19:18 0.90 10,744 11,033 COMPZ CASING RUNL P 10742'Stack weight to-12K, PU 3 times to get by,40K PUW 11031', PU 3 times 11062', PU 1 time 19:18 20:03 0.75 11,033 11,590 COMPZ CASING RUNL P Tag TD. Pump at 1.3 BPM,4000 psi to release liner. PUH pumping down backside. 20:03 20:33 0.50 11,590 10,297 COMPZ CASING DLOG P Tie in:-5'correction. Correction places TOL at 10116'; BOL 11585'. 20:33 22:30 1.95 10,297 0 COMPZ CASING TRIP P POOH pumping KWF 0.72 BPM,0.2 BPM returns. 22:30 23:00 0.50 0 0 COMPZ CASING PULD P At surface. Flow check well. Conduct PJSM regarding lay down and P/U tools. 23:00 23:15 0.25 0 0 COMPZ CASING PULD P Lay down liner running tools. 23:15 00:00 0.75 0 0 PROD3 STK PULD T P/U drilling assembly#3(BHA#11). 06/29/2010 Losses for 24 hours 208 bbls. KOB from 10116',drilling ahead-tagged Ankerite @ 10278'.Slow ROP until 10,321' 00:00 00:30 0.50 0 0 PROD3 STK PULD T Complete injector and packoff maintenance that was being performed concurrently with P/U tools. Stab on well and line up to run in hole. 00:30 03:15 2.75 0 8,870 PROD3 STK TRIP T RIH pumping 0.2 BPM KWF followed by 9.4#Powervis,timing out mud to reach BHA with BHA at stop above window. 03:15 04:45 1.50 8,870 8,870 PROD3 STK CIRC T Stop at 8780'and swap hole to 9.4# Powervis. Pumpin 1.0 BPM,initially 0.3 BPM returns gradually increasing to 0.7 BPM. Close ECD in BHA. Page 13 of 33 .- KU P 1 R-06AL1 C�r1 illipsi 'a Well Attributes Max Angle_&MD TD�tl`.31(&(n, ,. W Ilbore APUUWI Field Name (Well Status Intl(°) IMD(ftKB) Act Btm(ftKB) tsrzlcraMn9ips l; 500292133160 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation [End Date 1(B-Card(R) Rig Release Date SSSV'TRDP I ILast WO [ 37.61 5/15/1985 c.+.tmOlir.AAKI Annotation Depth(ftKB) jEnd Date Annotation Last Mod...End Dab Last Tag' - I. Rev Reason-SIDETRACKS,GLV C/O - Imosbor 7/21/2010 %. ' Casing Strings HANGER,33— Casing Description String 0... !String ID...To (ftKB) Set Depth L_.Set Depth(TVD)...String Wt...String g ption 9 9 P 1 ) P ( 9 9- String Top Thrd 2 3/8 1 1.995 10,116 fi 11,555.0 4.43 L-80 STL Liner Details CONDUCTOR,_ Top Depth 38-110 (TVD) Top Intl Nomi... Top(ftKB) (ftKB) (1 Item Description Comment ID(in) 10,116.6 BILLET Aluminum Liner Top Billet 1.000 SAFETYVLV. I —s Perforations&Slots 1,908 Shot GAS LIFT, Top(TVD) Btm(TVD) Dens 2,041 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (Oh- Type Comment ty I 10,126 11,583 6/27/2010 32.0 SLOT Alternating solid/slotted pipe- GAS LIFT.. 4 3z6 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non slotted ends SURFACE,37-4,659 GASUFT, _- Notes:Geneeral&Safety: _ 5,631 End Dab Annotation 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED GAS LIFT, .i... —. 6,285 7/21/2010 NOTE:VieW Schematicw/Alaska Schematic9.0 GAS LIFT, 6,762 GAS LIFT, 7,198 GAS LIFT. 7,615 GAS LIFT,- - 8,061 GAS LIFT,_ ft, T 8,381 PBR.8,421- PACKER,6,435 ''2-- GAS LIFT, f 8,473 GAS LIFT, 8,545 -:IU It Mlir WHIPSTOCK, 8,819 WINDOW W,_ 8,820-8,832 k GAS LIFT 'e.2, MUG,8,890-_-. ' LOCATOR, 8,908 PACKER,8,93 - SBE,8,9113-- •!1� '� CIaP,8,921 NIPPLE,8,924 SOS,8.931 FISH,9,145 ! — -- - - --- - Mandrel Details --- ., Top Depth Top Pod (TVD) Intl OD Valve Latch Size TRO Run Stn Top(RKB) (ftKB) C) Make Model (in) Sery Type TYpe ON (psi) Run Dab Cam... PRObucraN, 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/212010 35-9.279 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7212010 sLOr. 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,471-10,244 -- 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7212010 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 •A•LINER, 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 9,460-10,245 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 SLOT, 10,12411.583 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10.940 i 9 8,381..1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7212010 AL7 LINER, ■ II 10 8,473.5`--- CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 10,117-11,5115 KUP 1 R-06AL1 ConocoPhillips ° AB,he F h 7I14 KB-Grd(1Q Rig Release Date 37.61 5/15/1985 —- wm c nfig 1R:041,7/21/251 12.4244.0M__m -- —- -— -- — SfhB(nAi G_/WA AL HANGER,33--- CONDUCTOR, 38-110 ( SAFELY VLV, 1,908 GAS LIFT, -_ 2,061 GAS LIFT,_...._ 4,326 SUACE„ 3RF7-4,659 GAS LIFT, 5,631 .._ el GAS LIFT, 6.285 GAS LIFT, 6,762 GAS LIFT._ 7,198 GAS LIFT, 7,615 8 GAS LIFT, ,061 GAS LIFT._. lira', 8,381 PER.8,421 PACKER,8,435— --- GAS IFT, 8,473 GAS IFT, 8L,545 a: WHIPSTOCK,__ 8,819 `' WINDOW'A'. 8,820 8,832 GAS LIFT _ MMG,8,890 LOCATOR, 8,908 PACKER,8,909 SEE,8,913----'--. IMF CIBP,8,921 NIPPLE,8,924 Pill I SOS,8,931 _- FISH,9,145— ...M„_ k" p ,rx., f Mandrel Details iTop Depth Top Port (WO) Inc! OD Valve Latch Size TRO Run Stn Top(68KB) (6KB) (°) Make Model (in) Sere Type Type (!n) (poi) Run Date Com... PRODUCTION, 11 8,544.5 CAMCO MMG-2 1 12 PROD DMY RK 0.000 0.0 5/21/2010 35-9.279 —..-..12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 SLOT, 9,471-10,244 '6'LINER,5 9,iG0-SLOT, SLOT, 10,126-11,583 i 1 10,940 —II AL1 LINER,_ 10,117-11,585 r i a o N 7 m O O O � 1 NOai 7.O'iG O gb y m V - O CO b n c W r--,N z.-.42•4 O C- O .- 9 N N W t O - W i N N O O W W m- y m m r _ J - N m`o- d y m N °-' m 3 gm W,° :< c o a - E U Ncomco O� Jip baDL m E `y C 6p N M °<•1 N E <7 C M VC CO ..- 0 a N a a c44 m a N J a N a a N�Y cirod acv m' J rn In m .6.v M pop Y �V A 0 N o v ao 2 4 D m b p O m -0 �m vS c m r FN-- - ' 4 .4 P. N^ Q1 Ny ro m U c n W N p p dp N C OI V 4 (7 ! p� / W K m 2 0 r N V �� 1- p ° Y n N m t `m -5?0' ado. O N d N N Elf A E''g -IN.-1 $ w E. U , ai Uri ;u=. U mN U N N 2.,f,,, g Y0 l'1 N NNcvN W e A N M M M O m m M m co M M i/ I • _ I \III irl ... .. „all ,., , .._... ,,g I' -- '1 CO CI III III I o m 2 1�� O d m n v N Ct @m a m v m o° m ap s o _ r M N • _ mU t$viD L u u 01 01 O °= 28 co pNn Ce a? P c?°awrno U 2'63 m YOO co Y Y m j~ U ..y N mOj CO' a Si r.0 p5 a a McgZ Mime 414Z go V a 4-1 �� L cCS 0 Q ... ...,... o. (7) MEM Nemo V O > a r i •- 1y,n/ ■— r C L L Q C7 W(13 CD 0 YY , n N Z (AD a k ° m I i N co m o ° to oOD O O (O cl Z N t )'•• r ri N N N`. (O O i N m co to 1 LL 0) Z 0 e 0 c L m >.RI ° ° •E_.... M m 0 O N N • N 7 a CO N W co (D to m J 7 D TV... w C r m 7 m C O` m J J 0 0) to a. n 0 0 ° o FL' r _ _ co _ 7 7 O E O O a �' O c m C co m C�° o o E v m � O m m j F W N a( n N a m (..) 7 0 0 a v- a) d C O HF Q L m m p a 7 A v A m rn O C O C 0 N 7 U) ....L O co C V a a_ m G ; m m U '= A Z L m D j 0 cn p o o R °' O 9 DO Z M J 2 ZNO = p ' F ? ° O 0 LLI (o C_ o) m H U e 't 0m z° w � ; Cl) R O 0 m a. cs.i m N C i (A to { O J J 7 { Q 0 p Q H < O y (,) Q m O th p ° cc N Z O Li ' • O O O i y — cis T ' Q C O to to Z O O O O C O O O L O O O U N D a 0 ¢ 0 co - d' Q (6 C CD v Q D a > m Z a°i 0 rn m n y - cC o. c m O J > =G w N J O �j> Z O O co CO e�< O y y O. Q) Y ' O -I ' to 'm0 0 O O N 2 3 CO CO CO rq Q m Z W a o C7 °• Fo- co v u? O 7 7 O O o Y Z Q + + m !'-' r- O rn CN 0 w c w m !^ T .. 0 m 7 m 7 m V O N d O O O C c `o a +. �.m o o « `pm e Z c To �, E ° o ,°r; ° n o- m _ a rn m CO O N _ a a c a> « m m LL o m a ° UO w m m m �p y �p m m p m 16 0 7 m m 7 CO a) N V t� a` v, 3 3 c a M 0 E 3 3 a 3 2 0 a > > m I lr a El -■-• ea o m - - co g c• ooI 0 CO CO N O ~ a D CO•C d 0_ G) a 0 U 0 E R Z O 0 F- A N M M M M M M M M M M M M M M M M M M M M M M M M M M M M M U)• 2 2 2 2 2 2 5 2 2 2 2 2 2 2 2 2 2 2 2 2 5 5 5 5 5 2 2 5 5 2 a CD M CO CO CD D) O U) M M CO 0 N- CO N 41 M N U) 01 N O CO M CO CD N- CO M 0 N N M D) CO CD 01 O) 11 N O e' a N N c- a V 1- N c- M N N e• a CD O N- R 0 OD n r UC) N a a0 a A N h M m a O M (C) O CO U) a N D v CO O CO O O V Q u-D) e- a n DD O N a0 O M N O O ) O O N a (D O O a- M a CD n O CD O D O CD CD CD N- N- r N- 00 CO CO O O) D) 0) O 0 O O 0 O e- e- .- e- e- .- e- W 9 CO 0 0) N N N N N N N N N N N N N CD N N N CO- (D CO CO. CD (O 6 CD CD CO' Co. O CD D) > CO 7 _ _ 0 CC O ► N O M 0 CD CO CD N N O M CO CO M N 03 a N M CO 0 a CO CD O O R a N N N CO W N e- n O M M h to N-- e- co N ,- N e- N O M D) co a N N r r O 0 jO O co t` N CO N M a O) M M e- N co a N N O M M ,- .- M M M N O a , Y G N O▪ O U a E N _ CO co 0 W Q N- M O N N- CD N (D N- M N M CD N CO N M N N CO N N O M O a M e' 0 ` . 0 0 O N- M N at T O co M 00 O e- D) N CO n a Ol OI N. O N- co a op. O co 0 C_ Q al M CO O N a ,- M O Ni M O Ni a CO M e- N D 0 M CO V N Ni M D O C r co Co N co N v V Y) co co N- CO 00 CO Q) O N M a CD n 0) e- M N n CD N e- F- c W 0 w CD CO (O CO CD CO CO_ CD CD CD CO CD CD CO CD CD N- N N- N- N- N- N- N. co co co co 00 D) •■ R$V) N N N Y N C ( h N U U) N N U N N N N N N N N N N (D N Y N 010.) M010) R M M M M M M M M M M M M M M M M M M M M M M M M M w to (D to co N N v) tD co N N N N N N N co (D N (D (D N co N CO (D N N (D N O CO d mC 0 C. CND G ' co co co CO co co N co 0) N CO N- 0) O N- N a M N a N Co 00 .70 M N a■ LL m e- r N h Of ,- CD I� M I- N O N 0) M CO 0) CD O .- tD e- )- 0) O 0 e- Cr) N CD • 0) N CD r O a 0 Di D) O N M N M a a N N- O M O O a 0 D N O O O O0) C tD M O h N- 00 CD M 0 N- a e- CO N N CD 1- a CD CO M Dl N- a N L' (1) re e Q L V V a co M let co N N N N e- e- e- O O 0 D) W O D) co co co co N- N- N. h. N- ILZ 0 C R tt=O CD Co O O O CD O O CO O N co- CD (D CD CD V) tD N N N N N co. N N in- V) C LOi C • u Ti 2 O m co m CO m co co co m co co m co co co co co m DC co co co co co co 0) co co CO 0) • V) 0 •CCD C ; Z N N N N N N N N N N N to N Cn N (D N N N U) N V1 N (D N N N N O i co O N v to cD 7 L° g to io CD O w 0 0 CD O O N 00 Cr) a CD D) co O O 0 Cr N CD N U) a a N- N N r a CD DI D) O c c_ 0 0)• 0 T R N N h 00 N D) N O V N N a a D) N CO M V. n O CO M N r M a 0) .0 O (C) M CO O) N N CO N N CO M O h a s M O CD N O Ni a U) N M N- U w Q �' �+ Z N N M M M a a a M M N O O D) CD n CO a M O 00 CD a N O > co CO co co O co co DO O co co co CO co O co N- N. N. N- N- N- N- N` CO co co co Co N ❑ O M h M NM CM M 7 M M M M M M M M CM M M M M M M M M M M M F r Z c/ O N a M O M a D) N M M N N CD N N N N (O CD M N CD N O a s CO a N- D) n N M co 0- 0 M M U) Co Co M co co co N- a D) D) N M <! a ( N O (D CO N CO O O O O) CO N- CO O O N a M O N- a O O N O O) Ni Ni (D h O M M CO O) N N N- O M CD D) N MOON- VW D) N a N D) s- .. . co . E a a N N N N N CD co. Co N- N- F- N� DD CO CD Of D7 O) D) O O O O 7 7 7 7 N + - CD . a a a 1" CD ? V a a s V a s a s a s CC 't u) u) N N () (D u) U) N ' co M O M C 0) D) N a a CM N N N N CD N M N N CD C N N O O o U) s- s- D) Cr)D) O C M N 00 O a O) h - CO M I,- a 0 M 0 N a n CD N M 01 N CO O N N. M e- O CD M O O O O ) N O M (o O O O O 0 O ` N a a M M M CONN .- v.- O O O O O CD 0) D) W O CD on CDCDCD O O 01 0) 01 1 0= co CO CD CO CO CO CD CO CO O CO CO CO CO CD CO O N (D N N tD N N N Co co N N N t (D (D CO (O CO (O (0 CD CO co- (D CD co. CO (0 co- O CD co Co CO Co CO CD co' CDCDCDCDCD M_ D) O M CD 0) 0) N a a N N N- N N a a N M N CD 0) N N O CO o O 0) 0 (O M NJ O 0 a 0) N- N- O N ') N- C`l a O M 0 N a r CO OI r M M h a Of N r N N CA N- N y a N O O a N N- O Ni a a M Ni Ni C Cl N N N n O O O D) CT 0) CO CO CD CO O CO N- N. N N- t` C0 CO CO O OD CO CO= n r- n N• r n r- r- co CO CO (O a O CD CO (o 0 (D CO O (O CD CD CD CD CD CD CD CO Co D CD o o (D D CD CD D D m D D o co m co (D m co co (D CD m m (D (D (D CD Y co R 2 C r O N N a N a CD N N O CD CO CD CD N O7 CD N N N CD N N N N N CO a CO Q D -0 h M O M N CD N N N N CO O O O N O O N N N O D) a CD N O CO 0 ..-.. - N N D CO M D N N a CO N O - M 0 N M Ni Q D D D Ni O N O. . D) 01 0) O 00 00 N- N- I` CO CO CD n n N- CO CD N N N N N a a a M M M M N ce L Q' - •ttr• Q d Y Y MO" 0 ` ` •t•r U O CD CD ,tN. O C0 N CD M (O N s N- M CO 0) CO CM a CD O CO N. CO It M M N OD a N CO /i O O O M N N N CO(ID DI O a co (O M CO N N- O M a O O O O a M CO CO M CO N o m cc cc cc li 0 Y Y j C°••� 0 Da) 00) 0 00) 0) m m rn 0) rn rn m ..:r rn m rn m CO rn CO CO CO CO CO O) DC CD CD Q I N. V O ) D) ? CD N 0) N CO 00 N CO 00 0) (O N N M N CO OD D) O 0) a M + ► N- O M 0 O N •- M N r- N010- N .- r- r- r- N N N N N N O O M a N N D N N N N N N N N N o N U N N N N N N N CD N N N D N N N C R V. C C M N 0 N a r C M O 0) N N O a N O M CO CDN 0001- a N- O 001C0 ss- a a ? 0 N N C CD CO CO CO r r co co co 0) O) 0) O O O e' e- N N N CD d d 0) 0 DI D) O 0) O 0) 0 D) OC 0 W m D) co o W CC co 01 W 0) o O o 0 0 0 o O O 0 U _ — 0() a ( O 1. N NI a lii a Nil m n M C O O_' N ctS CO C CL Q O 0 m E R Z O O I- >. co co M M co M M M M M M M M M M M M M M M M M M M M M M M M M co, m ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ CO CD CD 17 N CO CO CD CO N N O) CD N CO V CO CD CO CO N (D N U O V U) O) N- T, C O) N O. V V N N N CO D N O 1N U 0 m 0 0 N N V M M M V N M O N 7 U 0 M N CO 00 N 0 a co co co CO O CO N 0 co M N M t0 m N CO N CO V O) N O p V .-D) O) O) D) D) O) m N (D 0 V CO N O O) N co V co N 0 0 0 CO O O) O O 0 0 N Y 0 — . . . . . — — — — -_ — -_ - 0 0 0 0 0 0 0 0 00 0 0 0 0 O O m O"o D CD 0 N CD C CD O (D D (o CO CO- (D D CD CD CD O CD O CD i N U) CD (D CD O D O c.k etc >v) m a _ _ _ _ 0 0 0 .... N N CD CO 0 CO N N N N CO M CD N- N 03 V N CO N U) O) M N 0 0 2 D y O N co O) m N O O) V N U) V 7 co 7 N N CO D) N CD 0 O - r N co N V N V CO O O 7 Y D O N 0 N N N M V M O 7 7 V N CO O O (V V co o U) N 7 N N 6 M tO CA M O CO (_) Y r r r @) () E m 1, G CO CO W E Q U) M O) CO N CO M 0 (O M N CD `Cr O) CO 00 N M O) CD N 0 N 0 V 0 V N CA OD O O N M 0 0 CO CO V N O (D V V CD co 7 co V co V V Na) a) V co co CD .- N 0) r C_ 0 CO N CC) N 4 C ) N M N 0 0 0 0 O O m D N N N O M D M O) 1 C V - CD N U co 7 V N- O V CO O) N CO V N O co N co V N a) N V N O) 7. a- H W a«s O) O O 0 0 0 7 7 N N N N M M M C() N UD CD D D D N- N N N to U U U co O CD D D O CO CO O CD CD CO D CD CO CD CO CD CD CO O CD D D O CO CD co i A M M co e l m M M M M M M M M M M co M M M M M M M M M M M M M M CO W 0 tD U) U) tD N tD U) N U) tD U) 0 U) N LO N U) U) V) N U) tO N tO tO N U) N N N 0 O 0 O (/) 0 O a. NN� V L Cf) 0 N N CD co CD co a) N CO CO 0 N N U) Na) V 0O CD tD U) N 0 N CO CO CO O■ LL . U) 0 CO fD CO CO N N 0) .- CD CO M CO CO N- CO V .- CO W .- M tO N O) 0 CO N .- V • > m CO V 0 D V D W V O N N D O a0 O V 0) M CD N CO r; O N M N O) N O tO O C O) 00 (D N V C O C I C I N N N N N M M co V V V V V co M N O) a0 CO tO M N1 N 1:e C O.t co CD CO CO O CO CD CO O CD CO CD CD CD CO co co co CD CO CO CD CD CD co U) N U) U) U) CD I a. 0 O N.` N N U) N N N N U) N N ll) tl) U) N U) U) U) U) U) VI N N to N LOU) tO U) tD N i O CD O m m 00 CD a0 Cb Cb O O CD a0 m a0 m CO CO W 0D Cb CD CD CD aD O CD O CD O i t0 O u a - 0 0 W Of 0f 0) 0) CO 0) 0) D) m m m m m a) 0) 0 a) m co m m m m m m m a) m 0), C v 0 0 Z V U D N N N N U) co- N U N o N N ) N N N N U) U U U U U o U N U U a E ° e E u C N rn � 2 . No m a. 0 N MCOC 0 0 T Q V N co M O V) 0 co co t CO M a N- O V In V co CD co O V co CD V M O CO 0 V V N . ° VN a) OM O r- ! N 0U) CO p n N N G 'L 1� N O N vOO t( co .- N M 0 aN N Cn W 01 U V V V V M M M N N N N 0 0 0 O) CO CO O) CO CO CO N N N N CD•3 1-F2 Z N 0 M N? M M N C? N) M 1 M C) M M N P M (.) Ci C) N N N N N N N N N N N N + O CO CD 0 CO N CO V N V V 0 CO N CO 0 (A CO 0 CO M 0 tD W 0 V N tD N 0 V CO N O) CO CO N N 0) O) co N 00 N (O N CD CO N 0 0) 0 0 00 0 N N N O D O N OD N D O D D D M O 0 0 O N D 7 CO co N N CO 7 N D O N 704- 6 co N N CD CD CO CC 00 CO a0 N N N (D (D CO N N C0 O) 0 a') V (O 00 CO N N N N N N N N N N N N N N N N N N N N N N N N CO co M co co co co Z N N U) LOU) LOU) N V N LOU) LOU) N to N U) u U U U U N U U o U o U N M M V 0 V 00 0 CO V 00 0 V U) co 0 aD co V 7 a) U) V N CO N CO CO■ N N O U) O N V N M N N O r CD V a) CD tO O) N CD 0 6 N m co co N O) N- (D N Ol O O O CD N V O N O 0 CO O O N M M N N M D N N V N O 0 N N 6 -- O) o O O) O) T O) O) OD C N N N CCD aD CO CD CO a0 W 00 O CO O 0O N N N N Q U] O (D CO 6 N co N co co LO co U) U) co UC N U) U) N N U) (D co U) U) co U) N co U), co- CD (D CO CO CO CO CD (O (D co- CO CO CD O CO CD CD CD O CD O O CO CD co' CO 0 O CD (O co co V N V CO •- 0 CO V 03 0 V N CD 0 CO CD V O) U) V N M 0 •' CD 00 CD aO U) CD N V U) M UI N or- co V O CD tD D) N CD O U) N o Cd M N O) N CO N Ch V V M N U) C) N M U) O n N (D CD N O) O Oi CD CD to V N CD N U > a0 a0 a0 aO a0 071C1&3: 17-1: (73i fD CD CD CD (D CD CO (D (D CD (O fD CD (O (D (O CD CD (O (D (D CD C �E co fD fD f0 O (0- O CD O xt. O co (O f0 O w (O co. fD N O (D, O co. O O O [D W- tD fD CO CD CD CD CO CD CO CD CO CO co O co CO CO co co co CD co co co CO CO co CD CO CO (0 CO CO CO Y CO CO r...4 _ _ _ _ CD CD 0 CO 0 V N O) 0 N V N V N N CO N O) N CD N CO CO 0 CD N Q 5 -p co O co V co O O) N co O O N N N V CD O V 0 O) 7 N. N tD M CO O7 V W N co N CO 0 a0 4 O) N N 0 CD N O (0 V N O M N O N N U) O) M N O M N V1 CG d N 0- .. v N 0 0 0 O) 0 O) O) O co co co m N co co O) a) 0 0 0 0 7 7 N N N N rI atr c� W Y Y MOM U 7 `•C_ N CO CO CO a0 O m N 0100 ,- 0 U) O) a0 N M 0) M M N aO V CD U) V M O M CO -C O N O O O C 0- C CO U? D N N co co O A 7 co A p) p) N N O) U CP co co co co N V co co. 7 CO co ' NCO CO 0 MNm O0m 000O O00Vm m m m O03 {j T- C) Y Y CO CO O) O OI 0) m a0 CO CO 00 0 ) co co C CO co 00 O) o co Q 0. ON \ L N O(Y V U 0 V M V N M CO O 0 0 V V V N N 0 N O) N- O) CO N CD N 0 T 0 V M s M N co N V N 0 O O co co N CO N) CO V 0 V V N (V .- co V V co V r- 6 U N D N tD N co O N 6 U U D U U (D O D N D N o N D D 1D N D D U 5— D_ O) N Ua0 V N O M CO O N U) O V N 0 M O O) N D b V N 0 M O CO. Q C ... 0 C >C .C N. M M M V a V tD N N CO O O 0 N - r R D W CO O) W n O 0 0 _ O© a m . 0) — 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 - 7 7 7 O w 0 m U 0o. co33o Co 7- — — CO W a TWO ZOrMI 4= m ! c 0 O N 0. CO () O 0) C 0_ Q O U m Z 0 0 O O O I-- T co co M M M co M M M M M M 0 0 0 0 0 0 0 0 0 0 0 0 p (n• 2 2 2 2 2 2 2 2 2 2 2 2 0_ co N O N. co N O) h O m N � C CO N. m Of co M co u) m m n (o O V M n M a M O u) O m 1N 61 N N N .- O O) CO N- u) M N 0 O O 7 V 4-O 0 0 0 O O O) co O) co D? O) O) O O O m m m m m m u) N u) u) 1) N N CL C' >to 7 'G D .0 j O M W N CO O N CD V M co 0 0 0 ` d to O o N- 0 0 4 O v 1- r- M co 0 3 J p N N N M u) N M N V N 1` O 000 CCOO 0 co C E w CO 0 CO CD W Q O) N. 0 N 0) CO r a m N O) 1() N O O m 1. N. u) r- co v M N 0 r- CO. O) CL th Z C 0 CO CO y csi 6 0 0 0 0 0 of (u C_N )() CO h o M (D Co ,- N- H lL 6 w co co co co CO O) 0 0 0 0 CN CO CO U) (O CO CD CO N- N- N- r N N N C la v N 11] u) u) u) N) N N u) u) 11) U) N S ,L W m N o- c 'o O Q. O L m CO CO m N- CO m N CO 0 0 n 4.11 M O C u u r u) CO 10 a r u)w ■ >■ CO 2 C azo O O) W N. N. CD CO CD CD t0- r m W ea 0 re C 0.= sv V c v v v c v V v v_ a Z m 0 R s N in 2 vi N u) in vi N (ri N o (ri n. m ��--mmmm mmmmm mmmm 3 A O 0 N 0 co co co co co a) m m m m m co O) o C Z u Y u N u ) N Y u) 0 u u) Y h ✓ a C C ` O) O v CO le CO• N- W I- o N 0 O a V )( V C C 0 m• 0 T A m O) (V CO CO V N r u M f- U (= � .0 CO V u r n m m m m 0 W 0 0 t i 1- V )O N CO CD M 0 1) N'- (O m m N () (f) V V V M co M Cl J F 2 Z N 0 N N N V N N N N N N N N N u) CO N 0 u) N u) V O M CD m CV M 1- u) CD N. 1- 0 O) CO CD 1D m O 0 o m v eo 0 N.: ni r- 0 0 N co co 1. 11' N V u R 0 M el_N a v_ c v a v v v v_ v v v a T. N u) 10 u) N u) N Y') u1 Y') u) u) N + ) m V 0 u) N- 10 N N N- M ,- CO N co t� O N O CO CO N M m ,- ,- O) _ n m m 1D a N 0 cc; to (V O r o N r- n 1- n N N- n co co co co 0 co Q C u) N u) N to u) u) In u) V) N 0 u) m (O m m m co- m co- CO m co. m m m V O 0 1- 11) N N cl. N. CO ,- (D m i- O N 0 CO O) N M m '- `. CO • O O O) m m V N O) co V K 0 co CD CD N u) 111 u u a R a a M U = 6666 m m m m m 6. 666. C o m D m (D m m m m m m m ( -CO Y 0 CO Q C 'V 10 CO CO N- u) N Co N h N `" N"' < 5 a v, co v, co m ry n co m co v n n (D 0 4 0 h M O) N M O) U) - m 1- N.: 0 Qi , n d .7` 7. - 0 0 CD CO T CO CO m t- 1- 1- .)rr a Y 0 O (6 (6 CO CO OD N CO O) CO CO CO N N. " 1- O) O) leC C n Cl_ 0 0 0 (1 V O m M N O co O co N u) N N o O ,- ,- " N O N N N N u) V 1)') O) O) U Y Y C' m o) O) o) CO O) co co o) O) o a) co 0 N O V C N- O ,- m N M N 0 M O O T CO 7 M N N N N M V O O N N 6 N N u) 6 N 6 6 6 6 N • C V. 0 C >. Q N 10 m V' N- O CO m O) N R m 2 N N N N? M M C V O N u) N O 0 a U 0a "m33o = s tur E CIF Alick\ SE6 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 Von Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-06AL1 ConocoPhillips Alaska, Inc. Permit No: 210-057 Surface Location: 272' FNL, 222' FEL, Sec. 19, T12N, R10E, UM Bottomhole Location: 431' FNL, 2380' FWL, Sec. 30, T12N, R10E, 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 1R-06A, Permit No. 210- 056, API 50-029-21331-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ` 7 day of May, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2010 PERMIT TO DRILL �g� •Conuriission 20 AAC 25.005 A la.Type of Work: • lb.Proposed Well Class: Development-Oil ❑ Service-Winj 0 'Single Zone EI • lc.Specify if well is proposed for: Drill ❑ Re-drill El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 1 R-06AL1 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11600' ' ND: 6542' " Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:272'FNL,222'FEL,Sec. 19,T12N,R10E,UM • ADL 25635,25640 ' Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1031'FSL, 1073'FWL,Sec. 19,T12N, R10E,UM 2568,2571 6/5/2010 Total Depth: 9.Acres in Property: 14.Distance to 431'FNL,2380'FWL,Sec.30,T12N,R10E,UM 2560 Nearest Property: 18550' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ' 84 feet 15.Distance to Nearest Well Open Surface:x- 539470 • y- 5990930 • Zone- 4 GL Elevation above MSL: 41 feet to Same Pool: 1G-08,870' 16.Deviated wells: Kickoff depth: 9350 _ ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 105.6° deg Downhole:3115 psig • Surface:2545 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 2786' 8814' 6483' 11600' 6542' 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) 9303' 6998' 9188' 6890' 9145' Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 215 sx CS II 110' 110' Surface 4575' 9.625" 1390 sx PF E,425 sx PF C 4659' 3694' Intermediate Production 9194' 7" 510 sx Class G,250 sx PF C 9278' 6975' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 8582'-8588',8692'-8742',8860'-8867',8976'-8984',8994'-9024',9028'-9038' 6379'-6383',6465'-6505',6801'-6607',6700'-6707',6716-6741',6745'-6754' 20.Attachments: Property Plat❑ BOP Sketch El Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: '5(5)t44 22. I hereby certify that the foregoing is true and correct. Contact J. G.Eller @ 263-4172 "*.% Printed Name ////1111 V. Cawvey Title Alaska Wells Manager Signature 4 Phon 265-6306 Date S( Ito ter 4C�iQy ommission Use Only Permit to Drill API Number: 9 Permit Approval See cover letter Number: oZjdas7C� 50-(7079a/c�Jiee)eo� Date: 5 1i i r 0 for other requirements Conditions of approval: If box is c cke well ymay_not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: L� * 3500 p Si. /b t eI ' Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No 2' Other: ac 2 5� drz 2S measures: Yes ,No ❑ Directional svy req'd: Yes Er No ❑ ! �nnw��► !mss' ,...„) — vLlfi►r.,.&. oper• �a'% 11.3. ac.c_cr,Q tic ZB 0 s. //7 j� APPROVED BY THE COMMISSION DATE: ,COMMISSIONER y I Form 10-401 (Revised 7/2009) This permit is valid for•4 I -..royal(20 AAC 25.005(g)) / Submit in Duplicate KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Summary of Operations: Well 1R-06 is a Kuparuk A-sand and C-sand injection well equipped with 3Y2"tubing x 7"casing.Four proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling,the existing C-sand perfs in 1R-06 will be squeezed with cement and the A-Sand perfs will be plugged with a bridge plug. After squeezing the existing C-sand perfs with cement,a mechanical whipstock will be placed in the 3'/2" tubing at the first kickoff point. The 1R-06A sidetrack will make a 2-string exit through the 31/2"tubing and 7" casing at 8819' MD. It will target the A3 sand south of the existing well with a 2881' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,700' MD with a liner top aluminum billet at 9350' MD. The 1R-06AL1 lateral will kick off from the aluminum billet at 9350" MD and will target the A4 sand south of the existing well with a 2250' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,600'. MD with the final liner top located just inside the 3'h"tubing at 8814' MD. The 1R-06AL2 lateral will make another 2-string exit through the 3%2"tubing and 7"casing at 8791' MD via a second mechanical whipstock placed in the 3'/2"tubing. It will target the A3 sand north of the existing well with a 2259' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,050' MD with a liner top aluminum billet at 9250' MD. The 1R-06AL2-01 lateral will kick off from the aluminum billet at 9250' MD and will target the A4 sand north of the existing well with a 1500' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,750' MD with the final liner top located just inside the 3'h"tubing at 8780' MD. CTD Drill and Complete 1R-06: June 2010 Pre-Rig Work 1. Test packoffs—T&IC. 2. Positive pressure and drawdown tests on master valve& swab valve 3. Load tbg&IA. MIT-IA. MIT-OA. 4. Obtain updated static BHP on A-sand &C-Sand 5. Permanently lock out the SCSSV at 1908' MD 6. Set 3'/2"CIBP at 8920' MD to plug off A-sand perfs 7. Shoot squeeze perfs thru the 3'/2"tubing and 7"casing at 8791' & 8819' ELM 8. Lay in cement on top of CIBP isolating A-sand. Squeeze the C-sand perfs with cement. 9. RU slickline. Tag cement top. Pressure test cement squeeze. 10. Drill out cement from the 3'h"tubing to 8920' using special clearance bi-center bit 11. Run whipstock dummy 12. Run slimhole CBL to evaluate C-sand squeeze 13. Prep site for Nabors CDR2-AC. Page 2 of 5 0 31GINAL May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1 R-06A Lateral (A3 sand, south) a. Mill 2.80"2-string window with high-side orientation at 8819' MD. b. Drill 2.70"x 3"bi-center lateral to TD of 11,700' MD. c. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 9350' 3. 1R-06AL1 Lateral(A4 sand, south) a. Kick off of the aluminum billet at 9350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,600' MD. • 1,r� c. Run 2%"slotted liner from TD up to 8814' MD, up inside the 7"casing (r" 4. 1 K-O6AL2 Lateral (A3 sand,north) a. Set 3'/2"monobore whipstock in 3'/2"tubing at 8791' MD with high-side orientation. b. Mill 2.80"2-string window with high-side orientation at 8791' MD. c. Drill 2.70"x 3"bi-center lateral to TD of 11,050' MD. d. Run 2%" slotted liner with an aluminum liner-top billet from TD up to 9250' 5. 1 R-06AL2-01 Lateral(A4 sand, north) a. Kick off of the aluminum billet at 9250' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,750' MD. c. Run 2%" slotted liner from TD up to 8780' MD,up inside the 3'/2"tubing 6. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to the system for clean up prior to putting on injection 4. Conduct MIT-IA 5. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- • based Flo-Pro mud(8.6 ppg)for drilling operations. Because the SCSSV installed in 1R-06 will be locked out,we will have to kill the well to deploy 2%"slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1R-06A: 2%",4.7#,L-80, ST-L slotted/solid liner from 9350' MD to 11,700' MD • 1R-06AL1: 2%", 4.7 4, L-80, ST-L slotted/solid liner from 8814' MD to 11,600' MD • • 1R-06AL2: 2%",4.7#,L-80, ST-L slotted/solid liner from 9250' MD to 11,050' MD • 1R-06AL2-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 8780' MD to 10,750' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi Production: 7",J-55,26 ppf Burst 4980 psi; Collapse 4320 psi Page 3 of 5 ; � May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Well Control: • Two well bore volumes(-205 bbl)of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure in 1R-06 is 2545 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity,which is 3115 psi at 6490 SSTVD(i.e. 9.3 ppg)from 1R-08 to the . north in September 2009. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1R-06A,plan#4 2. 1 R-06AL 1,plan#3 • 3. 1R-06AL2,plan#2 4. 1R-06AL2-01, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • • 1R-06 CTD southern laterals(A&AL1): —18,550' to property line,—870' to well 1G-08 • 1R-06 CTD northern laterals(AL2 &AL2-01): —19,500' to property line,—1050' from well 1R-08 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 1R-06 was taken April 2010 after several months of shut-in. The measured A-sand reservoir pressure was 2998 psi at 6571' SSTVD, corresponding to 8.7 ppg EMW. . We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Hazards • Lost circulation is usually not particularly troublesome in the A-sand, but it is a possibility in 1R-06 because of the generally low formation pressure in this area. • Shale stability is a potential problem,particularly in the build section where the A6 sand will be • encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle,and by holding a constant pressure on the formation throughout drilling operations. • Well 1R-06 has no measured H2S since it is an injection well. Well 1R-05 is located 60' to the right side and 1R-07 is 60' to the left side of the 1R-06 surface location. Well 1R-05 has 40 ppm H2S and 1R-07 has 25 ppm H2S, both being measured on 8/6/09. The maximum H2S level on the pad is 150 ppm from well 1R-20(8/15/05). All H2S monitoring equipment will be operational. • Page 4 of 5 1 l i IGINAL May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 8.6 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 allow 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 isolation during deployment and not as a stripper. The SSSV in well 1R-06 will be locked out, so the well will have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2933 psi at 8819' MD (6483' SSTVD),or 8.7 ppg EMW. • Expected annular friction losses while circulating: 882 psi(assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 8.6 ppg equates to 2899 psi hydrostatic bottom hole pressure at 6483' SSTVD • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3781 psi or 11.2 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1R-06. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability, but not necessarily for well control. • When circulation is stopped,—880 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Quarter-Mile Injection Review The following wells lie within one-quarter mile of the proposed 1R-06 CTD laterals. • 1R-06 motherbore(injector). This well is a selective completion in the Kuparuk A-sand and C-sand. The A-sand perfs will be isolated with a cast iron bridge plug in the tubing tail and the C-sand perfs will be squeezed with cement. • 1R-06 CTD southern laterals(A&AL1): • 1R-05 (active producer). This wellbore is located—1335' to the northeast of wells 1R-06A and 1R- 06AL1. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. • 1 G-08 (plugged& sidetracked producer)—This abandoned wellbore is located—873' to the southeast of wells 1R-06A and 1R-06AL1. The Kuparuk interval was abandoned in June 2004 with a balanced cement plug placed on top of a 7"retainer prior to being sidetracked. • 1R-06 CTD northern laterals(AL2&AL2-01): • 1R-08 (active injector)—This wellbore is located—1055' to the north of wells 1R-06AL2 and 1R- 06AL2-01. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. Page 5 of 5 '"`} # I May 5,2010, FINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator l Riser r Annular( Blind/Shear 2"Pipe/Slip(CT) Pump into Lubricator ) 4 above BHA rams P "e 1 Choke 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) Kill ►��‹>CJ L� L- 1 r Blind/Shear 2" Pipe/Slip(CT) Choke 2 Swab Valves Wing Valves '∎:∎∎�� 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 L t .• 2 C H O 0 C3 9 gi Q O1 Q G Or Q —O • Y O m O d d N A O N II m _J ., y N.II N N <I-- <F a°0 o m Q I J • • <n ° N • m m@ U O t , v q m c �E o - .0 c: m m m om wa 0 a E Urn w Y N m U rn0 O 0 jI- 0 O U O 8 a l , o W u Em • E aw EE. —2 N m m N U J O U M LL U O.0 U^ Q_ . N N N g - N N m m N N N t N / r t A • �0 W N l0 m co t+f CO M 0 m m A m_m CO A 0... O N O [ A O r o A I1 .11 Y I ii&ii1iI _• i 4 - NIII I I :',f, , ------"- . :4. I 1 '14, , co �n a, 1 0 U ,I� 1 0 W o a m g co 0 d m o °D a a wW m 0 Y.- V. `m 1 O b S Z M t Q iU N. O L N m m rn Cg co •uN tmam as `) c m c_ °m ° m a m ao CO 0 0 Y U w m<m r N Y Y CO Q.m..m 0 re = w mm°m . \ zo 1 1 N. L, KUP 1 R-06 Conocoi ilhips plc ,u. Well Attributes Max Angle&MD TD Alaska-.Inc. , Wellbore APWWI Field Name IWell Status Ind(') MD(ftKB) Act BEn(ftKB) r-lrlacophA6p: 500292133100 KUPARUK RIVER UNIT INJ 60.30 3,100.00 9,303.0 '' Comment H2S(ppm) Date Annotation End Date KB-Grd(B) Rig Release Date well cn ej.18.06,4n7r1g10 e.1639 AM SSSV:TRDP Last WO: 37.61 5/15/1985 59000 10-ACeral Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM _8,986.0 4/22/2010 Rev Reason:Tag,Pull Plug/Gauges/Leak Imosbor 4/27/2010 ...:.1,-,,,,... oc. xCasingStrings CONDUCTOR, String OD String ID Set Depth Set Depth(TVD) String Wt String 110 Casing Description (in) (In) Top(WKB) (MB/ (ftKB) (Ibslft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 110.0 110.0 65.00 H-40 WELDED SAFETY VLV, - SURFACE 95/8 8.765 0.0 4,659.0 3,693.3 36.00 J-55 1,908 PRODUCTION 7 6.151 0.0 9,278.0 69748 26.00 J-55 GAS LIFT, _ Tubing Strings -_ , , 2,041 String ODString ID Set Depth Set Depth(TVD) String Wt String Tubing Description (in) (in) Top(ftKB) (RKB) (BIB) gbs/ft) Grade String Top Thnl TUBING 3 112 2.992 0.0 8,932.0 6,662.6 9.30 J-55 EUE 8RD GAS LIFT. 4,326 - Other In Hole(All Jewelry:Tubing Run&Retrievable,Fish,etc.) Top Depth (TVD) Top Inel SURF4ACE, Top(ftKB) (GKB) C) Description Comment Run Date ID(in) 1,908 1,850.2 29.48 SAFETY VLV Camco'TRDP-IA'(NOT Locked Out) May hang up 5/21/1995 2.812 toolstring if control line pressure bleeds down. GAS LIFT, 5,631 2,041 1,963.4 33.00 GAS LIFT CAMCO/KBUG/1/DMYBK///Comment STA 1 11/9/1987 2.875 'jj. 4,326 3,449.4 43.26 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA2 11/10/1987 2.875 GAS LIFT, .- 5,631 4,355.8 49.37 GAS UFT CAMCO/KBUG/1/DMY/BK///Comment STA 3 11/10/1987 2.875 6,285 6,285 4,787.5 48.27 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 5 6/30/1985 2.875 6,762 5,103.8 48.32 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA5 11/10/1987 2.875 GAS LIFT, 6.762 7,198 5,396.3 47.03 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 6 6/30/1985 2.875 7,615 5,683.6 46.05 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 7 11/10/1987 2.875 GAS LIFT. - 8,061 5,995.8 44.95 GAS UFT CAMCO/KBUG/1IDMYBK///Comment STA8 11/10/1987 2.875 7'198 8,381 6,225.8 42.60 GAS UFT CAMCO/MMG-2/1.5/DMY/RK///Comment STA 9 11/10/1987 2.922 I. 8,421 6,255.8 41.30 PBR Baker PBR 6/30/1985 3.000 GAS LIFT, h 8,435 6,266.1 41.09 PACKER Baker'FHL'PACKER 6/30/1985 3.000 7,615 17 8,473 6,294.6 40.50 PRODUCTION CAMCO/MMG-2/1.5/DMY/RK1//Comment STA 10 11/21/1993 2.992 _ 8,544 6,349.1 39.40 PRODUCTION CAMCO/MMG-2/1.SIDMY/RKI!/Comment STA 11 11/21/1993 2.992 GAS LIFT, -. 8,061 8,890 6,626.0 33.19 PRODUCTION CAMCO/MMG-211.5/DMY/RK/.25//Comment STA 12 4/21/2002 2.992 ir8,909 6,643.9 32.57 PACKER Baker'FB-1'PACKER 6/30/1985 4.000 GAS LIFT, - 8,924 6,656.0 31.85 NIPPLE Camco*1)*Nipple NO GO 6/3W1985 2.750 8,381 8,931 6,661.7 31.51 SOS Camco 6/30/1985 2.992 8,932 6,662.6 31.46 TTL 6/30/1985 2.992 PBR,8,421 9,145 6,852.01 22.94 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 I Perforations&Slots_ 4�y Shot PACKER,8,435 Top(TVD) Btm(TVD) Dens Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh-- Type Comment 8,582 8,588 6,378.5 6,383.1 C-4,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, _ 8,692 8,742 6,465.0 6,505.0 C-1,UNIT B, 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase 8,473 _ 1 R-06 8,860 8,867 6,601.4 6,607.1 UNIT B,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, -- 8,976 8,984 6,699.6 6,706.6 A-4,1R-06 6/30/1985 4.0 IPERF 4"Hi II Csg Gun'90 deg.ph 6' 8,994 9,024 6,715.3 6,741.2 A-3,1R-06 6/30/1985 4.0 IPERF 4"HJ 11 Csg Gun'90 deg.ph 9,028 9,038 6,744.8 6,753.9 A-3,1R-06 6/30/1985 4.0 IPERF 4'Hi II Csg Gun'90 deg.ph IPERF. �L. i �',. 6,582-8,588 r Notes:General&Safety` End Date Annotation 4/23/2010 NOTE:Suspect Tubing leak between 8572'8.8868' IPERF, --'- - 6,692-8,742 :✓, IPERF,_ ,mot `- '::8,860-8,867 PRODUCTION, r.. 8,890 PACKER,8,909 L ,....,2 NIPPLE,8,924 ' IfSOS,8,931 TTL,8,932 . IPERF, � 8,976-8,984 z, . _ IPERF, 8,994-9,024 IPERF. ,. - 9,028-9,038 FISH,9,145 • PRODUCTION, 8,278 TD,9,303 J - 1GNAL - - ConocéPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1R Pad 1R-06 1 R-06AL1 Plan: 1 R-06AL1 wp03 Standard Planning Report 30 April, 2010 rid BAKER HUGHES UJIGINAL ' ConocoPhillips Mal ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1 Design: 1 R-06AL1_wp03 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1R Pad Site Position: Northing: 5,991,050.01ft Latitude: 70°23'11.370 N', From: Map Easting: 539,829.93ft Longitude: 149°40'33.803 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.31 ° Well 1R-06 Well Position +N/-S 0.00 ft Northing: 5,990,930.21 ft Latitude: 70°23'10.210 N +E/-W 0.00 ft Easting: 539,469.74 ft Longitude: 149°40'44.368 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1 R-06AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°1 (°) (nT) BGGM2009 7/1/2010 17.20 79.85 57,390 Design 1 R-06AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,350.00 Vertical Section: Depth From(TVD) +N/S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 124.00 4/30/2010 12:11:06PM Page 2 COMPASS 2003.16 Build 69 L.:. 1 GIN ConocoPhillips ,-- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1 Design: 1 R-06AL1_wp03 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (1 r) (ft) (ft) (ft) (°IlOOft) (°/100ft) (°/100ft) (°) Target 9,350.00 89.61 183.27 6,644.50 -4,371.32 -3,780.49 0.00 0.00 0.00 0.00 9,430.00 101.42 181.16 6,636.83 -4,450.75 -3,783.58 15.00 14.77 -2.64 350.00 9,517.00 105.58 168.44 6,616.44 -4,534.79 -3,776.01 15.00 4.78 -14.63 290.00 9,627.00 90.22 174.54 6,601.34 -4,642.19 -3,760.05 15.00 -13.96 5.55 158.00 9,717.00 90.31 188.04 6,600.92 -4,731.95 -3,762.08 15.00 0.10 15.00 89.60 9,837.00 90.48 170.04 6,600.08 -4,851.44 -3,760.08 15.00 0.14 -15.00 270.60 9,987.00 94.26 147.84 6,593.80 -4,990.42 -3,706.61 15.00 2.52 -14.80 280.00 10,137.00 90.89 125.57 6,586.99 -5,098.75 -3,604.49 15.00 -2.25 -14.85 262.00 10,437.00 90.27 80.57 6,583.79 -5,164.84 -3,319.72 15.00 -0.20 -15.00 269.50 10,562.00 90.26 99.32 6,583.20 -5,164.71 -3,195.28 15.00 -0.01 15.00 90.00 10,642.00 102.26 99.32 6,574.50 -5,177.57 -3,116.95 15.00 15.00 0.00 0.00 10,722.00 101.99 111.59 6,557.64 -5,198.37 -3,041.72 15.00 -0.34 15.34 90.00 1 10,822.00 98.51 126.42 6,539.75 -5,246.00 -2,955.96 15.00 -3.48 14.83 102.00 11,022.00 90.49 97.40 6,523.74 -5,319.28 -2,773.02 15.00 -4.01 -14.51 256.00 11,122.00 90.47 82.40 6,522.89 -5,319.10 -2,673.31 15.00 -0.02 -15.00 270.00 11,297.00 90.42 108.65 6,521.50 -5,335.80 -2,500.65 15.00 -0.03 15.00 90.00 11,397.00 85.09 122.68 6,525.44 -5,378.93 -2,410.83 15.00 -5.33 14.04 111.00 11,600.00 85.77 92.14 6,542.02 -5,438.74 -2,220.05 15.00 0.33 -15.05 270.00 4/30/2010 12:11:06PM Page 3 COMPASS 2003.16 Build 69 ORiGINAL 1 C I I\ I A ! -- ConocoPhillips take ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1 Design: 1R-06AL1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System 4+1/-S +E/_W Section Rate Azimuth Northing Easting (ft) (°) n (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,350.00 89.61 183.27 6,644.50 -4,371.32 -3,780.49 -689.76 0.00 0.00 5,986,539.43 535,712.741 TIP/KOP 9,400.00 96.99 181.96 6,641.63 -4,421.15 -3,782.77 -663.78 15.00 -10.00 5,986,489.59 535,710.72 9,430.00 101.42 181.16 6,636.83 -4,450.75 -3,783.58 -647.91 15.00 -10.08 5,986,460.00 535,710.07 2 9,500.00 104.82 170.96 6,620.90 -4,518.65 -3,778.95 -606.09 15.00 -70.00 5,986,392.12 535,715.06 9,517.00 105.58 168.44 6,616.44 -4,534.79 -3,776.01 -594.63 15.00 -72.32 5,986,376.00 535,718.08 3 9,600.00 94.00 173.08 6,602.34 -4,615.37 -3,762.96 -538.75 15.00 158.00 5,986,295.50 535,731.56 9,627.00 90.22 174.54 6,601.34 -4,642.19 -3,760.05 -521.35 15.00 158.79 5,986,268.70 535,734.61 1 4 9,700.00 90.30 185.49 6,601.01 -4,715.07 -3,760.07 -480.61 15.00 89.60 5,986,195.82 535,734.97 9,717.00 90.31 188.04 6,600.92 -4,731.95 -3,762.08 -472.83 15.00 89.65 5,986,178.93 535,733.05 5 9,800.00 90.43 175.59 6,600.38 -4,814.75 -3,764.71 -428.71 15.00 -89.40 5,986,096.14 535,730.86 9,837.00 90.48 170.04 6,600.08 -4,851.44 -3,760.08 -404.36 15.00 -89.48 5,986,059.47 535,735.68 6 9,900.00 92.11 160.73 6,598.65 -4,912.32 -3,744.21 -357.16 15.00 -80.00 5,985,998.68 535,751.87 9,987.00 94.26 147.84 6,593.80 -4,990.42 -3,706.61 -282.32 15.00 -80.21 5,985,920.79 535,789.88 7 10,000.00 93.98 145.90 6,592.87 -5,001.27 -3,699.53 -270.37 15.00 -98.00 5,985,909.97 535,797.02 10,100.00 91.75 131.05 6,587.84 -5,075.83 -3,633.50 -173.94 15.00 -98.14 5,985,835.78 535,863.43 10,137.00 90.89 125.57 6,586.99 -5,098.75 -3,604.49 -137.07 15.00 -98.89 5,985,813.01 535,892.57 8 10,200.00 90.79 116.12 6,586.06 -5,131.00 -3,550.46 -74.24 15.00 -90.50 5,985,781.04 535,946.75 10,300.00 90.60 101.12 6,584.84 -5,162.83 -3,455.97 21.89 15.00 -90.64 5,985,749.72 536,041.40 10,400.00 90.37 86.12 6,583.99 -5,169.12 -3,356.46 107.91 15.00 -90.82 5,985,743.95 536,140.94 10,437.00 90.27 80.57 6,583.79 -5,164.84 -3,319.72 135.97 15.00 -90.95 5,985,748.43 536,177.64 9 10,500.00 90.27 90.02 6,583.49 -5,159.67 -3,257.01 185.07 15.00 90.00 5,985,753.93 536,240.33 10,562.00 90.26 99.32 6,583.20 -5,164.71 -3,195.28 239.06 15.00 90.04 5,985,749.21 536,302.07 10 10,600.00 95.96 99.32 6,581.14 -5,170.86 -3,157.85 273.53 15.00 0.00 5,985,743.27 536,339.53 10,642.00 102.26 99.32 6,574.50 -5,177.57 -3,116.95 311.19 15.00 0.00 5,985,736.77 536,380.46 11 10,700.00 102.12 108.22 6,562.23 -5,191.05 -3,061.95 364.33 15.00 90.00 5,985,723.59 536,435.53 10,722.00 101.99 111.59 6,557.64 -5,198.37 -3,041.72 385.19 15.00 91.88 5,985,716.37 536,455.79 12 10,800.00 99.33 123.19 6,543.16 -5,233.60 -2,973.80 461.19 15.00 102.00 5,985,681.51 536,523.89 10,822.00 98.51 126.42 6,539.75 -5,246.00 -2,955.96 482.92 15.00 104.15 5,985,669.20 536,541.79 13 10,900.00 95.53 115.02 6,530.19 -5,285.46 -2,889.52 560.07 15.00 -104.00 5,985,630.10 536,608.44 11,000.00 91.41 100.57 6,524.10 -5,315.84 -2,794.74 655.64 15.00 -105.40 5,985,600.21 536,703.36 11,022.00 90.49 97.40 6,523.74 -5,319.28 -2,773.02 675.57 15.00 -106.28 5,985,596.89 536,725.10 14 11,100.00 90.48 85.70 6,523.08 -5,321.38 -2,695.19 741.27 15.00 -90.00 5,985,595.20 536,802.94 11,122.00 90.47 82.40 6,522.89 -5,319.10 -2,673.31 758.13 15.00 -90.10 5,985,597.60 536,824.80 15 11,200.00 90.46 94.10 6,522.26 -5,316.72 -2,595.48 821.32 15.00 90.00 5,985,600.39 536,902.61 11,297.00 90.42 108.65 6,521.50 -5,335.80 -2,500.65 910.61 15.00 90.10 5,985,581.81 536,997.53 16 11,300.00 90.26 109.07 6,521.49 -5,336.77 -2,497.81 913.51 15.00 111.00 5,985,580.86 537,000.38 4/30/2010 12:11:06PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Vaal ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1 Design: 1R-06AL1_wp03 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +WS +E/-W Section Rate Azimuth Northing Fasting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) P) (ft) (ft) 11,397.00 85.09 122.68 6,525.44 -5,378.93 -2,410.83 1,009.19 15.00 111.00 5,985,539.16 537,087.57 17 11,400.00 85.09 122.23 6,525.70 -5,380.54 -2,408.31 1,012.18 15.00 -90.00 5,985,537.57 537,090.10 11,500.00 85.27 107.18 6,534.15 -5,422.06 -2,318.05 1,110.23 15.00 -89.96 5,985,496.52 537,180.57 11,600.00 • 85.77 92.14 6,542.02 • -5,438.74 -2,220.05 1,200.80 15.00 -88.69 5,985,480.36 537,278.64, TD 4/30/2010 12:11:06PM Page 5 COMPASS 2003.16 Build 69 QRGtNAL ConocoPhillips laki ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1 Design: 1 R-06AL1_wp03 Point 3 0.00 -5,342.59 -3,967.93 5,985,567.28 535,530.45 Point 4 0.00 -5,021.03 -3,685.22 5,985,890.30 535,811.43 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ('7 (') 11,600.00 6,542.02 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (ft) (ft) (ft) (ft) Comment 9,350.00 6,644.50 -4,371.32 -3,780.49 TIP/KOP 9,430.00 6,636.83 -4,450.75 -3,783.58 2 9,517.00 6,616.44 -4,534.79 -3,776.01 3 9,627.00 6,601.34 -4,642.19 -3,760.05 4 9,717.00 6,600.92 -4,731.95 -3,762.08 5 9,837.00 6,600.08 -4,851.44 -3,760.08 6 9,987.00 6,593.80 -4,990.42 -3,706.61 7 10,137.00 6,586.99 -5,098.75 -3,604.49 8 10,437.00 6,583.79 -5,164.84 -3,319.72 9 10,562.00 6,583.20 -5,164.71 -3,195.28 10 10,642.00 6,574.50 -5,177.57 -3,116.95 11 10,722.00 6,557.64 -5,198.37 -3,041.72 12 10,822.00 6,539.75 -5,246.00 -2,955.96 13 11,022.00 6,523.74 -5,319.28 -2,773.02 14 11,122.00 6,522.89 -5,319.10 -2,673.31 15 11,297.00 6,521.50 -5,335.80 -2,500.65 16 11,397.00 6,525.44 -5,378.93 -2,410.83 17 11,600.00 6,542.02 -5,438.74 -2,220.05 TD 4/30/2010 12.11:06PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL iA - lam= s 8 . ^ ! O _F... O _O ^ 4 � I ^ O ^ �\Q fR 8 ill aF .Jg*U :;8. v •� o0v, z i I:- p, — S T sacra.€ k-5 ... l'i N111111.0.1W,,- L I III I - II -u` -S M 0 I I J e I r o � :7 .1 Q 858 • NM 4 irl h W v e 0 V (u!/8 OSI)(+)uuoN/(-)4lnoSN o as �JJ�J d _o _N C $ g ep `�$ la 1 ~ Y d l,2 GG O -- Q -N m v LIP up mm O Y-N m v N fO f'•F2 _o 1 ptl m1�vNn `mViC�'•I.-1p(p�`r.4. ).�+8$� R (41A 14/ N.7VM;;; nKm1--D7�N h 7v '- I 3: 1pplLfjipp� ppppp (ppOpO(����pOpppp oo g 'i� �i _IF ".°§E m0 O IRO Omi-0 0 H 871 .._.- -.-. -.... .--... ..........._..... ........ ---_..-_._ry K G.a4° F g$$810 o 000000$$8$$ z z K K i O 0 0 O U,10 10 Ul 10 IA 10 IA In In U,10 In IA In 10 IA __' r' ` ° 'I s^ efflG IS nv�m_m��oZ ,2a - rr $ , •n a. w m Q J 1N� Oga Snrn*° c'6 E° vW 1'T I I i l`•" FV on N _-h pip�y v9 L - I MN{y poppp m Gappp a0 x ri,C w lmlf t<�pp v N O G vQQl CO ODmfO1r 0,4Nm al- - T CL "Hi Z h Cn N,7WRAmSZ,RO k p p � • \ ^ !',CI- p R$$$ O$ 88F1O ,2i88S 8 O S ' O W O O .=- :=',Pi O gf:M N� �Oi§ •+D O D p p G D D 3 D U 2300 T 010 O80000°—'—'" 19n91 9 a$WON 0 © 0-Nm.a.,0l.-m o .-cqm.t.m,m m (u/8 OS)t ldau rzopian anal, V ,,„a .fttgo -8 'Q= N N q -1 �o�m F 22c, / JI z. \ • --. a. 8 qi < 8 • 5 •_ h9Y* z 8 k- \. k x x -& N O F o O w `off § w m o : + m - 8 r 0 —H w a 'Nit . . • . . _§ rg en I qqF iII s x 8 ' h A Q as 8 22 g LI iio d a ' s . . . iw F -w a N s N $ N s g g g 0 s 0 0 S s ft -1 •s s o O o 8 $ R (u?/8 00Z) (+)i11oW(-)tpnos a V 0 ORIGINAL Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 5, 2010 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits permit to drill applications for four lateral sidetracks out of Kuparuk Well 1R-06 (PTD# 185-071) using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 1R-06 in June 2010. The CTD objective is to drill four A-sand lateral sidetracks (1R-06A, 1 R-06AL1, 1 R-06AL2, and 1 R-06AL2-01). The original wellbore perforations will be plugged with cement and a bridge plug prior to CTD operations (Sundry application is attached). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1 R-06A, 1 R-06AL1, 1 R-06AL2, 1 R-06AL2-01 — Proposed &Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Sundry application for plugging the KRU 1R-06 motherbore If you have any questions or require additional information please contact me at my office 907-263-4172. S cerely, Gary Eller ConocoP ' Alaska Coiled Tubing Drilling Engineer 4 ti _- ' _ �- Q Q co � ' �® U O N. ,..,.,,YI t r`s It) Q co on-- ._ I 1 /......i C�J °. , q .,,_ i ,, „...0420)--°---..,._��g r N V V ft t�0 0) 'n al N 1 R r`r r rt O O e; I../- ° O r r 1 M < r G t9 00 c^l N 1 -`� ° G O ° �r CV G G I in r-ti S. Q �1 7i o•rc __c,, G 0 rte`- V ii f .,-, _ o .,,,, \E- ,,,._'_ P>, co ---.;---' , 2 G ' G V G ° 1 eo.- / (...9 --',.. 1 43 G ~1----- .: •.ice r. G ' 1. •J G G r- h c G ill. N C J° • G TY ° °f V G Q O � � 1 ; '1 G 1 in • '- 1�',a r 1 At 1 C\l G? O r o 0 o IN 0 o r 0 1 O -�' r J G r Q T' LC) J 0 Q r �' co _ r �, C0 NI CD 00 4 CD q� U r r r C) _ r r Q -. Q Q k _m-.4, C ° CGm °N O r U N OO N r Q G CO N AG z- O r0 ti - r---- Q r e'a��C` r G, \J r_ r 4 O ti a 00 CO Oj � G t aa) rM r` t °° °oil \s. Id Y 1 ` G c G In r 1 g '.' 0 CO ° o N C ao r 0)ill--W, 0--- .3 7\4 g) 4 6-'m S M r •r i f TRANSMITTAL LETTER CHECKLIST WELL NAME Xiei/ e%'6,4/// PTD# o?JOOcS--" 7 Development Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: ".5 3 'C/' ,//.: ' POOL: .6 7,4 e ■ / • Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well KkI /r7-- 6 (If last two digits in Permit No. Z/v OS(L,API No. 50-G-1- 21 3'3 _0/ 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 ❑ ❑ To N 0, o a, a N O N o `Om a a> c Q a) N 3 N N a N C d .co 7 I O — 7 0 0) N co z 3 _Q O C 0 C a> c L O E C C a a> I CC O - ' 2 Ch O N c) 0 N ° a' °� O o- F- O (Ea o 2 `O m a 7 a> co E Y 2 N N •'L"' a) ° N 2 t .0 2 N a J v 3 _ s a> c m w Q o c 3 3 m a a> . Q a O C z ° Q) c o °, 7 a 0 a O O N •C O 00 O _> CD 0 .5 . C1 I- ti a ° ° co 0 O' 0) c - O N >N m :5 d_ �j L -O N 0 (p co C O) 5 -O O N . f6 N x de o ..0 — 3 a> m (a0 J Z N N a 3 a) P N a) L p O a .0 = N E .o 9 N O C 0 (0 N O 0- (0 E E 7 < c 3 C o N 3 N c Y °° m o co E I- .� O c N ° ° O ) N 0 0> U)) 'c N I d Q■ Z Z .0 N O) a) a Ca in' N a o (0 07 a s co co a3 p a) 2502 C 9 J 3 Z a co C • O c c U n 3 aa) o° L . O Oi 1 a o ° 00 co a a) 0 N C U O . -p m .N >, m N 3 'a 0 CO CO C LL 1 D a O) C T N Y a 0 -p a E a> (O N w N N N N C Ci)Q O y 0 O Z a) Z 0 00 - c U) N P = CO "O = a> a a O> -O O .0 °- CO 0 c a) N C a) N co N O> (0 N °_ c CO C a a> O a E N a C II O co Y a3 = -O C a a a) N U .(.7.,c a _c N T N N . a' :Ti O a> °03 C O 2 g O -o C C 3 E ° Cr) a> .3 >, m 7 2 o- -0-o a• CO c 'o Q :.7:.0 > C N N O p O C)), C C U C -o (0 2 N a co co N a N 0 0 E ° o a `o v o a°i n a a 0 N X00 m Z O a) j Z .(`0 C .0 C = U N a> .0 0 '7 V CO E ° II c O 0 0 7 m m co c m @ o 3 •o m ca ' N a> E t a Q O O 0 N ° 0 CD Z = 0- o 0 0 C7 ° o = D ° = 4) ° o a) m 00 < N O a> xa = w CO Y U a ,_ < U (n co a O E c� Q 2 2 1 < w -`o a w (n < aa)) a> a) (1) a) a`>> a> aa>> aa>> a) a> a> a) aa)) o < < < < < 0 a) a) CN> a> < aa>> aa> aa>> a> aa)) CI) aa>> o a) < < < , az >- >- >- >- >- >- >- >- >- >- >- >- >- >- z z z z z z z >- >- >- >- z >- >- >- >- >- >- >- z >- z z z T H a> N O (0 U w o To c E E 3 o — E a) O U 0 C a) a) N C izt O O 0 p U N O t�> LL _ o N c �,a C w o - ° o '->-; v J a`) u> E _ 3 O ° 3 as N a) T O U_ C N o O E O Z N E a> 2 (6 0 N N Q 0) O O E N 0 a' -0 > -C o a) N 0 O_ (0 a) Q C O V _' `t 7 C LL 7 x .9 �\- a 30 >, c 7 O) Ti;NO O o- 0 N N N Q > a)Y a N _° (D a O O Q N U a) a) O O w O a) a N a >, c N o as y N .- -0 j Q ? C a N N 7 @ c ; E O CC o > (� •o o ° o N c> N o ° c o — a M �> N 0 CC c In 0 7 o (0 (° T L a p -7° O 0 az, E N (0 '5' O r> -o O 7 (3/) N N CC U ,_ -C O E L .V' a, 7 3 O CO C co L c U) LC> 3 < N N a) a> O) Z -`O 0 .E -O 0 a> C _0 N a> a D O ` a) CO O O 0, a) o CI- L C C N C O 8 4. D Q E E _ -°o c c E CO a>`) o M c C in > H o us �_ a> N = a c)c U c N O QY o o `o (7> -0 o 0 5 o o Q o ° °, 7 U a ° a> o a °- a 3 ° > m Y a> .N a Q 0 a) a> C >, 0 3 ° -O 0 .(0 ° Y N O 0 ,O a> 0> O (0 (6 (0 Q (0 Z (n "T O 0) 0 a) c .N D U U 0 a 0 0 U C — Z o E 3 3 a) o a> L m 3 = 0 'E - Y Q m "o m m m n oa L L m m �. E ca a�i m a> N M (° 'N L o N a a 3 0 � o T 3 c E Z (n a> v) o — 0 .3 3 a> a 0 •• o ° N .� 3 c ° c °> w ° '� 3 m o 3 r °> ° w U o a o c° c a - .> °`o a°, .Q a -o o m E o C .o 0 o o 0 Q o v c a) ' a o o> c -o n N o 0 0 (O a V 0 0 a) ° _ a> o E E E C .O a> N c a J a) 0_ 'O N N _ 3 7 d C V' U 0- y, y, "O a) (` E O) O �. 7 O ° C L 2 U 0 5 (0 O O 0 @ d .N N N L - c N m °- CO (0 N (6 (0 a0 `' o >, 'C 3 2 0 N N O a Cl a E 3 m m rn N a> m > jL O (0 0 c 0 0 0 0 N c (6 .0 0 .0 -0 L N °> N ,- a°, a) > rn 0 L a> a O- w N E 0 ° O a c m E U Y> a) (6 o L C C ... a 0 . 0) -O -O O 'N - 3 -0- 0 N .0 O N (0 c a) C a) E a> -a 3 ca) 0 0 U 0 — -o 2 m — ° U N m 0 c F'' OZ - C 0 Ti* 0 N N 0 O 0 0 N U co 0 C O Cl) O O - (0 "O (a N O- E 33 C .'C 0 N ° -O U CO O = a> 7 O O O .0 .5 (0 (0 a O a> a U° "O (°0 > > 3 0 0• N 0. a) C) w w ) Y N CO O- E 0 00 a) 'J U 'a-) ooi .0-E ° ° a> = -0 n n a`> 5 m ° 3 2 o o 0 2 2 2 m -0 0 -0 ' c O O r >° °- a°) a`> m 'a ai o �0 a J > > > > (n —� O O a Cl_ U > Q a z U co U U U U < —� < w o co co U > �' 2 a O CO (n c_) ° • a — ,- N C') V ((> (O N- CO 0) O — N CO '1' u (O I. CO CA 0 N CO V (O (0 (- co 0> EO N CO r) V (f) (D N- CO Cr)O - - N N N N N N N N N N Cr) CO Cr) Cr) Cr) 0) CO CO CO CO •. U 0 a) w O O 0 w C O C N N U O N% O 0 - - O O R ( 0 (n O 'E- a. O J N N a> c O O C O- O tFO E a ° c a _j 0 Qp U I- MS a < < w a 0 a
