The URL can be used to link to this page

Home My WebLink About211-036 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. 4_ I I- - 03 f7 Well History File Identifier Organizing (done) ❑ Two-sided II 1111 Ill II III ❑ Rescan Needed 1 11111111 IIIIIII RES N DIGITAL DATA OVERSIZED (Scannable) of Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 7149„fiti. isiPIP Project Proofing I IIIIIIIIIII I I III! BY: dialifbDate: _ _ /s/ (1/JfD Scanning Preparation x 30 = + = TOTAL PAGES caa (Count does not include cover sheet) BY: 421° Date: 7/ /s/ Ir/V1►{}� Production Scanning I 1111111111111111 Stage 1 Page Count from Scanned File: cg3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: 41112Date: 7/ ffLj.. isi Mf)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. III II IiIlII II 11111 ReScanned I lIlIlIlIHI 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111111111111111 a 1 c 0 m m w co as o• Z N c, Ua) c o c• 5 }aNil a, °? E 1 N T a) E O o z O irj F. �'c 1 U Ta 1 o o Q o o > o d o 0 c ) z 12 m d U 0 0 o re Z c - Cl) E o a 2 2 a cE m N� Q . OU O 0 Li. Q c - 0 m 0. 0 aN. '5' co .�. .. a z z O ." ' to— ,EE0E >- } w = °' u) Z U I , V) cs' w Z m V c°, i d Z 1 cre • a 'CC 11 co a) 7 co- O J ° to .2 I O � o,m c TE CL csi zI o _I2 m • 5 C o ' y 0 N ai a, 1 D)To O co X o E 1 J N 000 N U a, 1 I Q T I— I- p �.. I N I- H Z z 1 y CE1 re > D a, I ' I cn a 11 U a c i i i Q Y o Q o 21 .) - --J., z 0 o a, U cn Z c CD c E Ec a Z w R Z CCD O J _ar. w H Z Z Z m 01 eri 3. c >- >- >-< Z W 0 Z arp Oo y O a)N H CO r d y LL �. > E F. Z V C .� lL a, co J a) j O ce « c a, N Z Q c. a) v C 0 OLL aa) c 0 d aNi Z ami c c cc Z W CO c 0 o v, y m E 5 a y J U H U n76 _ -T.a) 1 E a a cz) Cr W Q a o co TTD 0 U <a I C) i U l et O H 0. J 0 1- Colombie, Jody J (DOA) 241 03 0,0 From: Schwartz, Guy L (DOA) Sent: Thursday, May 12, 2011 4:45 PM To: Allsup-Drake, Sharon K Cc: Eller, J Gary; Colombie, Jody J (DOA) Subject: RE: cancel permit to drill for 2K-19AL2 This email will suffice... we will withdraw PTD 211-036 for 2K-19AL2 CTD sidetrack lateral. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Allsup-Drake, Sharon K Jmailto:Sharon.K.Allsup-Drake(aconocophillips.coml Sent: Thursday, May 12, 2011 2:57 PM To: Schwartz, Guy L(DOA) Cc: Eller, J Gary Subject: cancel permit to drill for 2K-19AL2 Guy— What is the best way to inform AOGCC that we want to cancel a permit to drill? Should I send a paper version of a letter or is an email just as good? We would like to can the permit for 2K-19AL2, permit#211-036. Thank you, Sharon 263-4612 1 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, March 09, 2011 4:36 PM To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA) Subject: RE: Correction on KRU 2K-19 CTD PTDs (PTD 211-036) Gary, The permits have already been circulated here... I will add your statement to the well files. Thanks for updating us with the most current information. Hopefully, if the MI injection has truly been that recent(first gas injection in pattern) you will not see MI gas that quickly in the tighter A sand target zone wellbore. Of course , if MI has been injected for quite awhile all bets are off!!! Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, 3 Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, March 09, 2011 4:23 PM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Ohlinger, James J Subject: Correction on KRU 2K-19 CTD PTDs Guy— I wanted to make you aware of an error that I made in the paperwork accompanying the drilling permits for the proposed KRU 2K-19 CTD laterals. In the Hazards section on page 4 of the summary document dated February 28, 2011 that accompanied the drilling permits, I stated that"there has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas". That statement was incorrect. Well 2K-13, immediately to the north of 2K-19, has recently been on MI gas injection, and therefore it is likely that any influx taken during the drilling of the 2K-19 CTD laterals would contain significant quantities of gas. I have already made the correction on my own written drilling procedure. Please contact me if you have any questions. 7. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 3/9/2011 SlfTJLi1J ElF0 AIR\ SEA /SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS333 W.7th AVENUE,SUITE 100 COMMISSIONCONSERVATION COMSSIONANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-19AL2 ConocoPhillips Alaska, Inc. Permit No: 211-036 Surface Location: 219' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 1693' FSL, 1840' FWL, SEC. 10, T1ON, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 2K-19A, Permit No 211- 034, API 50-103-20118-01. 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, 0 Daniel T. .-amount, Jr. Chair DATED this/v day of March, 2011. cc: Department of Fish & 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 OR 9 2 Mil PERMIT TO DRILL 20 AAC 25.005 AlaRka Oil&Gas Cons.Commission la.Type of Work: . 1 b.Proposed Well Class: Development-Oil a • Service-Winj ❑ Single Zone a• lc.Specify if well ir.",pf9lye Drill ❑ Re-drilla Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2K-19AL2 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 12450' , TVD: 6126' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:219'FNL,94'FEL,Sec. 11,T1ON,R8E, UM ' ADL 25588,25589 ° Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1572'FSL,2627'FEL,Sec. 10,T1ON,R8E,UM 2674,2675 4/15/2011 Total Depth: 9.Acres in Property: 14.Distance to 1693'FSL, 1840'FWL,Sec. 10,T1ON,R8E,UM 2560 / Nearest Property: 11400 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:/5-t/meet 15.Distance to Nearest Well Open Surface:x- 498310 y- 5938085 Zone- 4 GL Elevation above MSL:�1�(d / eta ,to Same Pool: 2K-27,2100' .aj-,/ 16.Deviated wells: Kickoff depth: 11600 •ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 97° deg, Downhole:4078 psig • Surface:3512 psig • 18.Casing Procram: 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 2390' 10060' 6210' 12450' 6126' slotted liner .,"" 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 10659' 6576' 10500' 6474' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx AS II 115' 115' Surface 3754' 9.625" 1200 sx AS Ill,450 sx Class G 3789' 2898' Intermediate Production 10524' 7" 450 sx Class G 10557' 6508' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 10169'-10189', 10210'-10250' 6259'-6271',6285'-6309' 20.Attachments: Property Plat❑ BOP Sketch a Drilling Programa Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements ❑I 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 t ,3i tIlk Printed Name V. Cawvey Title Alaska Wells Manager Signature Phon 265-6306 Date 5/2,.../ /Z4)1 f Commission Use Only Permit to Drill ,, ,___, API Number: Permit Appro al See cover letter rl Number: C. ( ', =; 50-/C13� ' t%=(/ j��/-61-1 Date: l ( ( Ifor other requirements Conditions of approval: If box is checked,well not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: 2/ *X 500 psc; !30P ies 1L Samples req'd: Yes ❑ No Mud log req'd: Yes El No [' Other: . Z 6-00 S` A nnw[ 4H2S measures: Yes L Er No ❑ t-- ) -' APPROVED BY THE COMMISSION /� / DATE: j A ,COMMISSIONER Form 10-401 evised 7/2009) This permit is valid 1 $4 •n(h (r f pproval(20 C 25.005(g)) Submit in Duplicate . i ConocoPhillips RE EIV EL Alaska P.O. BOX 100360 !1/�A�t3 ANCHORAGE,ALASKA 99510-0360 N3Ska Oil&Gas Cons.Cce(emission ssion February 28, 2011 4fChocags 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 three coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-19 (PTD# 189-109) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill three producing A-sand laterals: 2K-19A, 2K-19AL1, and 2K-19AL2. Work is scheduled to begin in April 2011. Also included is the sundry for plugging the existing 2K-19 perfs with cement in order to perform these CTD sidetracks. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2K-19A, 2K-19AL1, 2K-19AL2 — Proposed & Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — 10-403 for plugging the existing 2K-19 wellbore with cement If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, Gary Eller Conoco fillips Alaska Coiled Tubing Drilling Engineer KRU 2K-19A, AL1, AL2 —Coiled Tubing Drilling Summary of Operations: Well 2K-19 is a Kuparuk A-sand production well equipped with 31/2"tubing and 7"production casing. Three proposed A-sand CTD laterals will increase reservoir exposure and offset the planned 2K-13 CTD injection laterals. Prior to drilling,the existing A-Sand perfs in 2K-19 will be squeezed with cement to provide a means to kick out of the 7"casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 10,220' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K-19A sidetrack will exit the 7"casing at 10,170' MD and will target the A4 sand west of the existing well with a 3030' lateral. The hole will be completed with a 2%"slotted liner to the TD of 13,200' MD with an aluminum billet at 12,350' MD. The 2K-19AL1 lateral will kick off from the aluminum billet at 12,350' MD and will target the A4 sand west of the existing well with a 750' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,100' MD with an aluminum billet at 11,600' MD. The 2K-19AL2 lateral will kick off from the aluminum billet at 11,600' MD and will target the A4 sand west of the existing well with an 850' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,450' MD with the final liner top located just inside the 31/2"tubing at 10,060' MD. CTD Drill and Complete 2K-19 Laterals: April 2011 Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU slickline. Obtain updated static BHP on A-sand. Dummy off all GLMs. RD slickline. 3. RU e-line. Perf holes in 3'/2"tubing tail at 10,070' MD. RD e-line. 4. RU coil. Mill out XN-nipple in tubing tail to 2.80"ID. Plug the A-sand perfs with cement up to 10,070' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2-AC, including setting BPV WE Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-19A Sidetrack(A4 sand,west) a. Drill 2.80"high-side pilot hole through cement to 10,220 MD'. b. Drift pilot hole with whipstock dummy c. Set whipstock at 10,170' MD with high-side orientation. d. Mill 2.80"window with high-side orientation at 10,170' MD. e. Drill 2.70"x 3"bi-center lateral to TD of 13,200' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 12,350' 3. 2K-19AL 1 Lateral (A4 sand,west) a. Kick off of the aluminum billet at 12,350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 13,100' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 11,600' 4. 2K-19AL2 Lateral(A4 sand,west) a. Kick off of the aluminum billet at 11,600' MD b. Drill 2.70"x 3"bi-center lateral to TD of 12,450' MD 11t;5 c. Run 2%" slotted liner from TD up to 10,060' MD,up inside the 31/2"tubing tail Fri) - 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 2 of 4 February 28,2011, FINAL ORIGINAL KRU 2K-19A, AL1, AL2 — Coiled Tubing Drilling Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%"slotted liner in the three laterals. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2K-19A: 2%",4.7#,L-80, ST-L slotted/solid liner from 12,350' MD to 13,200' MD • 2K-19AL1: 2%", 4.7#, L-80, ST-L slotted/solid liner from 11,600' MD to 13,100' MD • 2K-19AL2: 2%",4.7#, L-80, ST-L slotted/solid linpr from 10,060' MD to 12,450' MD ✓ a... 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 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 2K-19 was taken November 2010. The A-sand reservoir pressure was measured at 2355 psi at 10,050' MD, 6050' SSTVD, corresponding to 7.3 ppg EMW. We generally expect to encounter increasing pressure as laterals are drilled away from the mother well. Well Control: • Two well bore volumes(-230 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 4500 psi. Maximum potential surface pressure in 2K-19 is 3512 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4078 psi at 6122' TVD taken in offset injection well 2K-13 in January 2011, corresponding to 12.8 ppg formation pressure. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 4 February 28,2011, FINAL KRU 2K-19A, AL1, AL2 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 2K-19A,plan#3 2. 2K-19AL1, plan#2 3. 2K-19AL2, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-19 CTD laterals(A, AL1 &AL2): 11,400' to property line,—2100' to well 2K-27 Hazards • Shale stability is the most significant problem expected due to somewhat low reservoir pressure and the significant number of fault crossings expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas. • Well 2K-19 has 90 ppm measured H2S as of January 2010. Well 2K-18 is located 25' to the right side and 2K-20 is 25' to the left side of the 2K-19 surface location. Neither well has any measured H2S since they are both injectors. The maximum H25 level on the pad is 400 ppm from well 2K-27(1/13/09). All H2S monitoring equipment will be operational. 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 used to reduce pressure fluctuations to help with hole stability. 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 23/8"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-19 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2382 psi at 10,170' MD(6275' TVD), or 7.3 ppg EMW. • Expected annular friction losses while circulating: 1017 psi(assuming annular friction of 100 psi/1000 ft due to the 3Y2"tubing) • Planned mud density of 8.6 ppg equates to 2806 psi hydrostatic bottom hole pressure at 6275' TVD. Mud hydrostatic pressure alone is expected to be sufficient to overbalance formation pressure. • While circulating 8.6 ppg mud, bottom hole circulating pressure is estimated to be 3823 psi or 11.7 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-19. 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,—1000 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Page 4 of 4 q to 1 February 28,2011, FINAL I KUP 2K-19 Conoc P fillips l a Well Attributes Max_Angle-&MD TD Alaska,Inc. --,,,,n .ems t hm-. Wellbore APWWI Field NWell Status Incl(') MD(ftKB) A.Ban(RKB) -T ' 501032011800 KUPARUK RIVER UNIT _ PROD 60.35 3,700.00 10,659.0 ca:nmiTM _ _ Comment H2S(ppm) Date Annotation End Data KB-God(ft) Rig RNase Dale "' SSSV:TRDP 200 1/13r2009 Last WOOL` 39.99 11/14/1989 w n Cones_zK,l9 3D „1.1p;3).,36-6ht �_._ -_ --'- .. Stltema0c Actual- �-Annotation 'Depth(flK6) End Date Annotation Last Mod By End Dab Last Tag:SLM 10,346.0 2/14/2010 Rev Reason:PERFORATIONSImosbor 3/2/2010 Casing Strings ..:.:.M _. .-. .. ;: _...F .;. .. - String OD String ID Set Depth Bat Depth(TVD) String Wt String --"^""a"WtlV1.'OL:�It�PL _ Casing-D _ ton (in) ( ) Top(fIKB) (ftKBL_ (RKB) (lbs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 CONDUCTOR '"i' 115 -r.-...'„fr.. SURFACE 95/8 8.765 0.0 3,789.0 2,897.5 36.00 J-55 PRODUCTION 7 6.151 0.0 10,557.0 6,508.0 26.00 J-55 Tubing Strings 4l �..._ �_., - �- ;..ti 4. Y i SakryvaNe, String OD:.String ID .::Set Depth Set Depth(TVD) String Wt String... 1,798 Tubing Description (in) (eel Tay(RKB) (8KB) (eKB) (tbnlft) Grade String Topmed TUBING 3 1/2 2.992 0.0 10,084.0 6,209.0 9.30 J-55 EUE8rdABMOD Other In HQ1jAil JewelryTubing Run$Retrievable;Fish etc_ Top Depth (TVD) Top Incl GAS UFT, -_ Top(RKB) IRKS) Cl Despiption Comment Run Data ID(in) 2,675 1,798 1,721.8 33.62 Safety Valve Camco TRDP-1ASSA 5/3/1990 2.812 2,675 2,317.5 56.05 GAS UFT MERLA/TMPD/1/GLVBK/.125/1350/Comment STA 1 9/21/2003 2.875 5,5303,784.8 58.98 GAS UFT MERLA/TMPD/1/GLVBK/.156/1363/Comment.STA 2 9/21/2003 2.875 SURFACE,09 ',,1 sr 7,062 4,598.8 57.84 GAS UFT MERLA/TMPD/1/GLVBK/.156/1341/Comment STA3 9/21/2003 2.875 7,833 5,007.4 57.73 GAS UFT MERLARMPD/1/DMY/BW//Comment.STA 4 5/3/1990 2.875 8,577 5,397.1 58.70 GAS UFT MERLA/TMPD/1/GLV/BK/.188/1355/Comment STA 5 9212003 2.875 GAS LIFT, - Y/ 9,298 5,7732 57.98 GAS UFT CAMCO/MMG-2/1.5/DMRK///Comment STA 6 9/24/2003 2.921 :;.1:', 5,530 - e 9,959 6,136.9 55.24 GAS UFT CAMCO/MMG-2/1.5/OV/RK/.25//Comment STA7 5/14/2009 2.921 = 10,003 6,163.4 55.48 PBR Baker'80-4 w/10'Stroke PBR 5/3/1990 3.000 _ 10,016 6,170.5 55.28 PACKER Baker HB'RETRIEVABLE PACKER 5/3/1990 2.890 GAS UFT, -_ 10,052 6,190.6 54.76 NIPPLE Otis'IN'Nipple NO GO w2.81"POUSHED BORE 5/3/1990 2.750 7,062 77 10,083 6,208.4 54.30 SOS Baker 5/3/1990 2.992 10,084 6,209.0 54.29 TTL 5/3/1990 2.992 Perforations&::Slots ?-- . GAS LIFT. Shot 7,833 Min(TVD) (TVD) Dens Top(ftKB) Blrn(RKB) (RKB) (ftKB) Zone Date (sh-• Type Comment 10,169 10,189 6,259.4 6,271.4 A-4,2K-19 3/1/2010 6.0 APERF 2.5"Millenium HMX charges,60 y, degree phase 10,210 10,250 6,285.3 6,309.1 A-5,2K-19 ---5/1/1990 4.0(PERF 180 deg.Phasing;4.5"HLS Casing GAS LIFT. Guns e.sn ---- , L - Notes:General&Safety ":._ s _- ;, _ -;-t End Data _ _.-," Annotation 10/24/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION s 9242009 NOTE Repair SURF CSG of 9 5/8"hanger,weld 38"sleeve W/10".500 wall API SL-X65 pipe GAS LIFT, 9,298 GAS LIFT, 9,959 -- PER,10,003 _-H. -... PACKER, 10,016 NIPPLE,10,052 E:, 11 SOS,10,083 -_ ' TO,,10,081 - ai, APERF, • 10,169-10,189 (PERF, 10210-10,250 PRODUCTION. 10,557N _ TO,10,659 w - Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing < , Lubricator k .v{-1 Riser r 7 Annular/ Blind%Shear 2" Pipe/Slip (CT) Pump into Lubricator � /\J L �< above BHA rams ► >< 1 r Choke 1 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip (BHA) DL Kill `\4<l>"11J L><Il<_J ► i 1;' r Blind/Shear 2" Pipe/Slip (CT) r. Choke 2 Swab Valves MIL Wing Valves lb,..41:41 Tree Flow Cross 0 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 I ORIGINAL E LL 2 0 OS o 0 N o •- N :105 r (-)"O N: q Da) ;,n' o. v_` JN Y NY LDN Icom - h —= en • Do chm IQ�UI o r p • a�QO10 @ OO up E @ C V. O mcn , = m m p a mCL ,)-N N`r)N Y113 2 m mQ a .%;:'; "E.. 1 o' E o ! –___--7.---- __,– ' – . 5517:‘I Eil � lNOL 1141 ii 11 ti o U IVV10 i tW Ll @ a E O S` faca LO O mco `p. ap cb ao #u c cni c%n Q c;2 °2 c,co c- me r ? C N ON O. tO N 1,C q` N v M O cn t 0 'C O Q 4 d N m M a o a_o Q t Q a ORIGiNAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL2 Plan: 2K-19AL2_wp02 Standard Planning Report 25 February, 2011 BAKER HUGHES ORIGINAL vs ConocoPhillips Ira' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19(4154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL2 Design: 2K-19AL2_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-19 Well Position +N/-S 0.00 ft Northing: 5,938,085.20 ft Latitude: 70°14'31.454 N +EI-W 0.00 ft Easting: 498,310.27 ft Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: f 118.50ft t Wellbore 2K-19AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/15/2011 16.64 79.76 57,334 Design 2K-19AL2_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,600.00 Vertical Section: Depth From(ND) +N/-S +EJ-W Direction (ft) (ft) (ft) (°) ! -118.50 0.00 0.00 277.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 11,600.00 87.36 257.94 6,135.19 -3,485.71 -7,809.78 0.00 0.00 0.00 0.00 11,630.00 87.37 262.45 6,136.57 -3,490.81 -7,839.30 15.00 0.03 15.02 90.00 11,705.00 88.98 273.59 6,138.96 -3,493.40 -7,914.10 15.00 2.14 14.85 82.00 11,925.00 88.71 306.60 6,143.53 -3,418.88 -8,117.82 15.00 -0.12 15.00 90.80 I 11,995.00 90.00 296.18 6,144.32 -3,382.47 -8,177.49 15.00 1.85 -14.89 277.00 12,215.00 96.72 263.79 6,131.09 -3,344.72 -8,390.74 15.00 3.05 -14.72 282.40 12,285.00 90.21 255.53 6,126.86 -3,357.26 -8,459.38 15.00 -9.30 -11.79 232.00 12,450.00 90.19 280.28 6,126.28 -3,363.23 -8,622.99 15.00 -0.01 15.00 90.00 2/26'2011 11:42:42AMp i + COMPASS 2003.16 Build 69 1.-' ConocoPhillips (/"R ConocoPhilhps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL2 Design: 2K-19AL2_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-w Section Rate Azimuth Northing Easting (ft) (o) (o) (ft) (ft) (ft) (ft) 0100ft) (°) (ft) (ft) 11,600.00 87.36 257.94 6,135.19 -3,485.71 -7,809.78 7,326.76 0.00 0.00 5,934,601.59 490,500.49 TIP/KOP 11,630.00 87.37 262.45 6,136.57 -3,490.81 -7,839.30 7,355.45 15.00 90.00 5,934,596.49 490,470.97 2 11,700.00 88.87 272.85 6,138.87 -3,493.68 -7,909.11 7,424.38 15.00 82.00 5,934,593.64 490,401.17 11,705.00 88.98 273.59 6,138.96 -3,493.40 -7,914.10 7,429.37 15.00 81.66 5,934,593.93 490,396.18 3 11,800.00 88.81 287.84 6,140.80 -3,475.78 -8,007.18 7,523.91 15.00 90.80 5,934,611.56 490,303.11 11,900.00 88.72 302.85 6,142.97 -3,433.11 -8,097.28 7,618.53 15.00 90.52 5,934,654.25 490,213.03 11,925.00 88.71 306.60 6,143.53 -3,418.88 -8,117.82 7,640.65 15.00 90.20 5,934,668.49 490,192.50 1 4 111,995.00 90.00 296.18 6,144.32 -3,382.47 -8,177.49 7,704.32 15.00 -83.00 5,934,704.90 490,132.84 5 12,000.00 90.16 295.44 6,144.32 -3,380.30 -8,181.99 7,709.05 15.00 -77.60 5,934,707.07 490,128.34 12,100.00 93.34 280.78 6,141.24 -3,349.31 -8,276.72 7,806.85 15.00 -77.60 5,934,738.08 490,033.63 12,200.00 96.30 266.02 6,132.79 -3,343.40 -8,375.90 7,906.01 15.00 -78.05 5,934,744.02 489,934.46 , 12,215.00 96.72 263.79 6,131.09 -3,344.72 -8,390.74 7,920.58 15.00 -79.30 5,934,742.70 489,919.62 6 12,285.00 90.21 255.53 6,126.86 -3,357.26 -8,459.38 7,987.18 15.00 -128.00 5,934,730.17 489,850.98 7 12,300.00 90.21 257.78 6,126.80 -3,360.72 -8,473.97 8,001.24 15.00 90.00 5,934,726.72 489,836.39 12,400.00 90.20 272.78 6,126.45 -3,368.92 -8,573.35 8,098.88 15.00 90.01 5,934,718.54 489,737.02 12,450.00 90.19 280.28 6,126.28 -3,363.23 -8,622.99 8,148.84 15.00 90.06 5,934,724.24 489,687.39 TD 2125/2011 11:42:42AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL2 Design: 2K-19AL2_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-19AL2 t4 0.00 0.00 6,126.00 -3,362.30 -8,623.43 5,934,725.17 489,686.95 70° 13'58.337 N 150°4'59.707 W -plan misses target center by 1.07ft at 12450.00ft MD(6126.28 TVD,-3363.23 N,-8622.99 E) -Point 2K-19A,AL2 Fault#2 0.00 0.00 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 70°14'8.038 N 150°4'30.709 W -plan misses target center by 6237.32ft at 11600.00ft MD(6135.19 TVD,-3485.71 N,-7809.78 E) -Polygon Point 1 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 Point 2 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 Point 3 0.00 -3,853.22 -7,867.13 5,934,234.13 490,443.06 Point 4 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 2K-19AL2 Polygon 0.00 0.00 0.00 -3,363.10 -7,676.31 5,934,724.16 490,633.97 70°13'58.339 N 150°4'32.185 W -plan misses target center by 6137.87ft at 11600.00ft MD(6135.19 TVD,-3485.71 N,-7809.78 E) -Polygon Point 1 0.00 -3,363.10 -7,676.31 5,934,724.16 490,633.97 Point 2 0.00 -3,590.14 -7,736.25 5,934,497.15 490,573.99 Point 3 0.00 -3,516.27 -8,253.33 5,934,571.13 490,056.98 Point 4 0.00 -3,457.42 -8,816.40 5,934,630.10 489,493.98 Point 5 0.00 -3,156.36 -8,687.47 5,934,931.10 489,622.96 Point 6 0.00 -3,363.10 -7,676.31 5,934,724.16 490,633.97 2K-19AL2 t1 0.00 0.00 6,140.00 -3,489.17 -7,949.32 5,934,598.17 490,360.97 70°13'57.097 N 150°4'40.114 W -plan hits target center -Point 2K-19AL2 t3 0.00 0.00 6,127.00 -3,354.26 -8,450.41 5,934,733.17 489,859.95 70°13'58.418 N 150°4'54.679 W -plan hits target center -Point 2K-19AL2 t2 0.00 0.00 6,144.00 -3,364.21 -8,219.38 5,934,723.17 490,090.96 70°13'58.323 N 150°4'47.966 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (••) ('•) 3,789.00 2,758.29 9 5/8" 9-5/8 12-1/4 12,450.00 6,126.28 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (ft) (ft) (ft) (ft) Comment 11,600.00 6,135.19 -3,485.71 -7,809.78 TIP/KOP 11,630.00 6,136.57 -3,490.81 -7,839.30 2 11,705.00 6,138.96 -3,493.40 -7,914.10 3 11,925.00 6,143.53 -3,418.88 -8,117.82 4 11,995.00 6,144.32 -3,382.47 -8,177.49 5 12,215.00 6,131.09 -3,344.72 -8,390.74 6 12,285.00 6,126.86 -3,357.26 -8,459.38 7 12,450.00 6,126.28 -3,363.23 -8,622.99 TD 2/25%2011 11:42:42AM Page 4 COMPASS 2003.16 Build 69 QRJGJNIL x w m Y z gwe 'd d C z __.�. 1 1 6'2941eel i -a e e .— 1 g g g g o M add I f I coo, $> a- 1 333 3 l'4.-- 1 1 -8 i o 'O ti e- Q 1 ••O • CAO .— L6.. r, _.. I...__. 1p-- S _. -.-......_.. _.__'".' 0 N Y � 1 .1a a Q rB o S , ... _. { -_ .` cid J 8 M to M 8 O ? .._.... N oILI = M (��/)!OOT)(+)4o1�I%C�4�noS ' .> Ill � 8 8 8 8 8 8 8 8 8 8 1 _e- o CO 01 8 I I - w a I Cip e j .* U s s= =o- iI o a) 10 u po a _ _. N,..... I.._. I O n a . 3 F1 o+ Vn.tM( mmgy�pp M 4] .4 I 1 r- p Mr--rte-. otitis i -R I N o J 1 _ O Q :EnIS 088 8 828288ppp _ : . -O daOf JN .1.,7:5 6.1 co r`NNpp ▪Y OomOfrmMo, WN H 04c,404 NN _p I a• am" 8'88888888 O Y Y N N NO •C' ap p p ^y m 0;1 L` 3m OONC+RMO� I ___._. L._. — _.D PN�aJ rn 0 m0 co LEER i V n.e� 2�(0 _.... N owr� I-- a -� C I- m W '- 28 v P.'ciM9 a o 2 E Zn- :RiRiF2 GJWNU) . . 8. WMMM <t MNN r<omeo eommeo eo NN � '0-'""1 , b.., $ .b. '1"'-'1-"'1.' ro $ V e ' oea2 n 12n*3n N st, FR' ,7:; f8*8 38 N N M N N N N Z m M M a, 8 (u�/k) OL) adaQ tEatan aru swim 1.5 8 °888888 888 W WO 8884W0Ca sEEY O OfNNN y �.-.- -' a (V C 10 (n.�NM'f�.nm Ism ORIGINAL Ail VA +. \ ,kkg* ,,„„, J 4i • „2,„0 „a, , c., .• 8 ` Oa O �s 6 wg8a x0o p E SiYV rh l ! 8 ffi iiiit \ 1 1 ;,w ,,, 1 1 a• p $ N p rn Y`' 1 '. S S O g 0 w �o W CO 3a 1 ....1 III C : S2., = il lagl \\\ Y : N j ' p N.,/ Q a ,N I ga Y.Y LI{ I 1 Y YN(NI 3 i 1 0 �rn32Q m I a` 3Y j $ A : AUG I I I.. ” 1 0 1 7. 1 'r4- o 8 $ a ? (u1/1J 00Z) (+)111 -10N/( Z A o0 { flRIGINAL N V ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL2 2K-19AL2_wp02 Travelling Cylinder Report 28 February, 2011 Irani BAKER HUGHES ORIGINAL ConocoPhillips //.._ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL2 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL2_wp02 Offset TVD Reference: Offset Datum Reference 2K-19AL2_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer(WARNING:There is hidden tight data in this project Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,600.00 to 12,450.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,441.45ft Error Surface: Elliptical Conic Survey Tool Program Date 2/24/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 10,160.00 2K-19 GyroData(2K-19) GYD-CT-CMS Gyrodata cont.casing m/s 10,160.00 11,600.00 2K-19A_wp03(2K-19A) MWD MWD-Standard 11,600.00 12,450.00 2K-19AL2_wp02(2K-19AL2) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (") 3,789.00 2,912.29 9 5/8" 9-5/8 12-1/4 12,450.00 6,280.28 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-19-2K-19A-2K-19A wp03 11,600.00 11,600.00 0.00 0.35 -0.22 FAIL-No Errors 2K-19-2K-19AL1 -2K-19AL1_wp02 11,600.00 11,600.00 0.00 0.22 -0.22 FAIL-No Errors 2K-27-2K-27-2K-27 Out of range 2K-27-2K-27-2K-27(wp02) Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2./28/2011 1:15:13PM Page 2 of 5 COMPASS 2003.16 Build 69 (-) r`1 Jai TRANSMITTAL LETTER CHECKLIST WELL NAME 021:( 24 - /911 PTD# Z l 1 6 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: t ,✓'Gtk/JG4-E'er POOL: k" -(72-/ ni . 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 Ki2 b/ (If last two digits in Permit No. 7!/e API No. 50-/OS-?--CV/A5 -t/ . b 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 E Co W ° O a) O lcc c 0 , E 3. J c C. O' 3, Ed m 4a co, : O W (I) o, O 0, c �, Y O %,, o, , E' _ v, 15 E O ,. . , , , n v c ur o, o: °_ 3, 00 (0o L y > Zg, y, -,7,, 4 r 3 _c O, C C C' y, O, N C 0) N, DD O, C, �: �: l6 •�: as = N 'C O. C f0. 0 C: Co , S2: c g �, O, 0: ay a , , o • a m o v > >' o, 'I, 2. H CO C O: O: 0 , O, _, 7' C C M. f6 a) C, f0 N� C N, O.. a0 Ty E 0, O a c n w 3, o, , V a. v, �. 0 o, c' 0' > O N t, 0, O Y, o, N. Z' O W a' 2 T �� 0 , O' ' �' E U U: U: �,0, N, C. m, N, O, 0 o m' d Y Q. >> M, crc CO,N' .c , T C Y, ' CO' g' V' co a m O WI E W' 0' . D , c, , O) v. a, "Zr. 3' N d, a, , p. r)' y 0' a a �' -' 3' Q c' , �, , 0, Z. Z. Z. c. i' C ar C' lo: 0: U) . - N o N: CO, CO, 0 Ci- a, , Y, E. f/J a 0,' a �' v, �' 5 a) g' a)' N to. D , ot), �, .0, O' ,, N, a) a)' o) v, ' 6 0. aY `) C C d O: ,-, H ay , a,, , d a C' ul O, C: : w• C •y, O, 0'. 0, .7, 0, C' w O) Q , cu, , w Oc, Oc, Oc, a , , , , , , ai 0, _.. a •c, �, m o n aii �. c to, 4 N, •$, 7, F. EO C, O O. O, N, d, N, C 'O .0-1 ° �: C: 'f0 0 M' Y P c f6' 0' 0 (a l0: 0 d d U' d 0 CO > V' a) M' N l`' a), ai E c9 0, , Y: z, Z, Z, E. HH ! flH,ft) 't x 000o 0COv) aO ch n. 2 2 . 2 ' 2 Q N a` i W ' O , Q; Q; a), aa)i, CO m, a), a), a); a), a); m m a) Q, Q Q Q Q Q Q o. a), a) a), a), < a) acsCO), CD aa): ac CO m, Q: o a) Q Q Q p. Z, Z, }, }, } }, }, }, } > }, } } } Z, Z, Z Z Z z Z Z, }, }, }, >- Z. } >, }, } }, }, Z, 1 Z >- z z z • `o co v oC , a) a) c : , E > 00 : , > tis 0 c o _TD .Li' rn•cr . , , . , , , , , c t, . . o a E -_Id. a,. E. 3, 0 O , , , . v 3. M, a): > > Q c, 0, o, Z, �, �: a) m a0 : ` o. ; c. t' of ay a), d jL aca a w `a4, 1,ce a' C, y, > 0 N,w rn , ° c oca m o 2. o �: 7, y, > O, 0' 5' 0' f0 > 0: ' 0 •0' O' o,es; E. G): 7 � w0,, c•,: •O, O: ,. g, y0 E2 U O ., O) N' 0' 0 3' ' co C. 0) L C' o. j 9, 0. ' Q' w N 0' 171)^ 0) V, la, a), • Z •O' O. C 5, O' ay 'C, 0, 0 O, C. ay m: O, O, 0) ' a: L, C, 0, COi'2; �, EE. _ 'O C. co, •E� llj� @ �, p1 C 'N� > �, C, �, �: �', C ' G a), w 0 e' N, L O- C C c cry 2' o V o v' c 3 o °' 2' ° c o >' v, r c o Q Q' ' it. ' w w: c c, ° m' 0, 0- p: O: c 0 c 'D� U: a 0� c 0 o: �, d: a� �� 0.. • o' a' O a)' 0 C O' O a) O' len, -(o' ay Q, 0, a' ,, 'C O, 0) O'0 i. N y D n E o ° °, ° �: o. o �. a, Y a E o. E' E •c 3' a,' c' a,'Y 0, 2, 0, 4 C C, �. a) 0 t, t, a, ca. O, Huiith° ffltfl ! U it ._ c0) D. V, a0. 3'o 0 m, , E, N, 13, 3, a a m '3. 3. ate). w a). v,, 0,, (0m,, 4 m, o, N' o. 11111 a ° c. wc-. 0 �: . > O uJa D3, f0'O C' O, °O, °O, > 0 0, O, co o' 9, 0,, a), 0, 0, C,d J -o0a) a) a5, O, E O E a) EE O , J a) a V' 0' 0' _ 7' 7' d C' 0. d .0-r 0 - .0 0 N 0) 8, co,, O C O O 02) °, t, a N, a a 0 0 a O, CO a L. �, CC, O , 0 E, C '� ;�, y O' 0, C, t, p _, 0 0,, a3, E 0, O, O, 0) a) 4 N, 0,, 0, , t-: C, au a co co, co, co, CO0, O >r I, 0,, .O, •y, O, a a', rn r, 0 c, a a a), 3' co' co a), 0, 0, 3. c, 0, c? o. 0. y, c. Y, y a_', •g a) m, 0,, 4E pcp' Oi 0 C t/, �` y a, a, a, t, a) > .� C L, 0, a Y y, w O U, .0 o' >, ;C N, LL la' a, '0 •0' •O0 °, - C. C -0 a) u,' '7 wa' 0 C' C C' E. UO �, 0, E, �, �, �, a) M -6 o t c C, a;, •3' �' o, 0 m „„ �' „„ �, , �' `' _ �° m, 60, o, 0. CO c, y, C 0, CO F Zi >, ", c'' 3, 0 0, 0, a, o o `u `u E, -, o. •o, a, E - c, cu 0, c, (0 p' c, ; 0 O' O' o' o, m 0, o' y, , s, co° >>, >, 3, o co, v, co2., t, o, vi, 4 ;, y, c �: >, o m. a), c a) a) 0' a. m 4 4 a€) a€i o a' 3, o, 7 2 2', 2', co, -o ° -00, > c, a, a' O o, a o. €, N. a, c 0 cz; a, J, D, 5.', 5., 5.; cn, � O, 0, a, a; c.) 5 da; 0,, coUU, 0,, Ua � Q, �' o, m' m; v, 5,, 2 a, 0, w,, 0, c), ✓ ° I E r ' D f� aQ, 0 - N M v uo �D O�7 O N N NM v N ON n N m MO M M M Mt o M M a,M 0,M O 6. G p C 0 pcu (N 0 p 27 p ° C Ix p O 0 co 0 co O M O O W c, R M C co M O-E CL _ Tz in 0 T J N •E c O O o W aIE a p c a � 0 a LL 0 • CL. Q Q W < 0 Q