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208-042
• • 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. 90 U - © g-o, Well History File Identifier Organizing (done) ❑ Two -sided 111 I 11111 ❑ Rescan Needed II1IIIIIII I1III RE AN DIGITAL DATA OVERSIZED (Scannable) Color 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: 1 /s/ Yi iE Project Proofing 111111111111111111 BY: Maria Date: 3111 i 1/ /s/ Ii\lf Scanning Preparation a x 30 = 6 0 + 3 = TOTAL PAGES e' (Count does not include cover sheet) BY: a Date: 3 /s/ u Production Scanning 1111 IIIII II I I Stage 1 Page Count from Scanned File: —(P--4-- (Count does include coy sheet) Page Count Matches Number in Scanning Preparation: _ YES NO BY: Date: 31 1 ( i 1 ( /s/ VII t 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. 111 111111 11111 11 III ReScanned 111 I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 111111111111 ll 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3/8/2011 Permit to Drill 2080420 Well Name /No. GRANITE PT ST 18742 32RD2 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20298 -02 -00 MD 15378 TVD 10215 Completion Date 10/5/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION • Types Electric or Other Logs Run: Gamma, Resistivity, NMR, Formation Pressure, Neutron Density (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments D C Las 17184Gfnduction /Resistivity 9093 15381 Open 11/7/2008 Res, Dip, Neutron, and Composite in PDS, PDF, CGM, PPT, LAS, and DLIS formats i,L Induction /Resistivity 2 Col 9106 15381 Open 11/7/2008 MPR, GR, Bulk Dens, NP, Acoustic Caliper 21- Sep - 1 2008 '' / `Log Induction /Resistivity 2 Col 9106 15381 Open 11/7/2008 MPR, GR, MR 21- Sep -2008 g Induction /Resistivity 2 Col 9106 15381 Open 11/7/2008 MPR, GR, Azimuthal Gamma Image 21-Sep- 2008 I Log Density 2 Col 9106 15381 Open 11/7/2008 Azimuthal Dens, GR, Bulk • Dens, NP, Acoustic Caliper 21- Sep -2008 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/8/2011 Permit to Drill 2080420 Well Name /No. GRANITE PT ST 18742 32RD2 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20298 -02 -00 MD 15378 TVD 10215 Completion Date 10/5/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION ^\ Well Cored? ' Daily History Received? N Chips Received? �X.l -Al Formation Tops y' N Analysis` • Received? Comments: Compliance Reviewed By: Date: S j Z.15 f ) • RE: 401 issues Page 1 of Fleckenstein, Robert J (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Tuesday, December 16, 2008 10:25 AM To: Fleckenstein, Robert J (DOA) Subject: RE: 401 issues Attachments: 407 GP ST 19742 32RD2 Update.pdf Bob Attached is the updated 407 for GP ST 18742 32RD2 I apologize for the delay. «407 GP ST 19742 32RD2 Update.pdf» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 -263 -7824 phone 907 -317 -5504 cell From: Flynn, Tim [ASRC] Sent: Monday, December 15, 2008 10:57 AM To: 'bob.fleckenstein @alaska.gov' Subject: 401 issues Bob I downloaded the 401 from the website and I could not check "Development Gas" box in section 1 b. of the form. Just wanted to let you know. I used a form from a well I drilled this summer and worked around it. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 12/16/2008 III STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil S Gas El Plugged LI Abandoned 0 Suspended 0 lb. Well Class: 20AAC 25 105 20AAC 25 110 Development Ell Exploratoryr] GINJO WINJ D WDSPL D WAG 0 Othern No. of Completions: Service Ei Stratigraphic TestO 2, Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Abend.: 10/5/2008 208-042 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 7/22/2008 50-733-20298-02 4a. Location of Well (Governmental Section): 7, Date TD Reached: 14. Well Name and Number: Surface: Leg 2, Slot 1, 785'FNL, 601' FEL, Sec 12, T1ON, R12W, S.M. 9/20/2008 GP ST 18742 32RD2 (AN-32RD2) Top of Productive Horizon: 8. KB (ft above MSL): 105' 15, Field/Pool(s): 1186"FNL, 1512' FEL, Sec 6, T10N 11W, S.M. Ground (ft MSL): 65' Granite Point Field Total Depth: 1V/4/ '9, Plug Back Depth(MD+TVD): 794F L, 114 Sec 31, Ti 1N, R11W, S.M. N/A Middle Kenai Oil Pool 4b. Location of Well (St.te Base Plane Coordinates, NAD 27): . 10. Total Depth (MD + TVD): 16, Property Designation: Surface: x- 266849.8 y- 2551356.4 Zone- 4 15,378' (10,215' TVD) AOL0018742 [Anna Platform) TPI: x- 271146.8 y- 2556151.5 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Perrnit: Total Depth: x- 271497.4 y- 2558125.2 Zone- 4 N/A N/A 18. Directional Survey: Yes El No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 124' (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gamma. Resistivity. NMR, Forrnation Pressure, Neutron Density ..,_ 22. CASING, LINER AND CEMENTING RECORD WT GRADE . PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 20" 94# X-52 Surface 600' Surface 599' 26" 547 sxs cement to surface 13-3/8" i 61/68172# Surface 4,020' Surface 3,978' 17-1/2" 1850 sxs cement 9-5/8" 43.5/47# S-95 Surface 9,089 Surface 7,640' 12-1/4" 1620 sxs cement 7" 29# P-110 8,891' 13,074' 7,476' 10,194' 8-1/2" 459 sxs cement 4.5" 12.6# 1-80 12,850' 15,381' 10,162' 10,215' 6" none 23. Open to production or injection? Yes S No0 If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) C-70 13,307' - 13,355' (10,225-10,229' TVD), 6spf 2-7/8", 6.4# (Long) 11,564' NIA C-7D 13,393' - 13,477' (10,230'-10,231' TVD), 6spf 2-7/8", 6.4# (Short) 8,800 N/A C-70 13,556' - 13,640' (10,231'-10,231' TVD), 6spf 2-3/8", 4.6# (Short) 11,562' N/A C-7C 13,827' - 13,916' (10,225'-10,220' TVD), 6spf C-7C 14,069 - 14,286' (10,215'-10,209' TVD), 6spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC, C-7C 14,365' - 14,692' (10,209'-10,210' TVD), 6spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED C-70 14,859' - 14,932' (10,21V-10,212' TVD), 6spf NIA N/A C-7D 14,966' - 14,997' (10,212'-10,212' TVD), 6spf C-7D 15,010' - 15,062' (10,212'-10,212' TVD), 6spf C-7D 15,171' - 15,290' (10,213-10,214' TVD), 6spf 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A (See cover letter) Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period m.gi. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (Gorr): Press, 24-Hour Rate --(s- 27, CORE DATA Conventional Core(s) Acquired? Yes 0 No El Sidewall Cores Acquired? Yes 0 No 151 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE eile0MS BR I;P: 1 6 2008 6 g • s Chevron Timothy C Brandenburg Union OiI Company of California %11011 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 1%101 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com November 07, 2008 k k Commissioner Alaska 00 & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: GP ST 19742 32RD2 Dear Commissioner, Enclosed for review is the 407 Well Completion Report for GP ST 18742 32RD2. Initial attempts to produce GP ST 18742 were met with failure. The well was brought on and produced 200 b/d of water. Water break through has occurred and further intervention to the well is required in - order to understand the failure mechanism. Consequently, no production testing was performed on • GP ST 18742. The well is currently shut in pending further diagnostics. If you have any questions, please don't hesitate to contact myself or Tim Flynn at 907 - 263 -7824. Sincerely, Timothy .: randenburg Drilling Manager .- Attachments: AN -32RD2 Completion Schematic AN -32RD2 Daily Operations Summary AN -32RD2 Final Well Surveys Cc: File Union OiI Company of California / A Chevron Company Page 1 of 1 8�� �: ��^�-8���~ | 4 � � � �A �~ ��� STATE OF ALASKA ALASKA `m� OIL AND GAS (��]N8ERVAJ'|��N(�{}K8yW| • N � nv � m ,0g: ~~ WELL COMPLETION OR RECOMPLETION ��������� ��� mmm~m~u~ ~���nmn. m~m~nn~�n� ��n� o�m~����o�nv m~m~xx��n� n�m�n ��n��w»n�v���������� _ la. Well Status: Oi| Gasp Plugged Abandoned �� Suspended E 1u. Well Class: � `^'',°' ' ^'�r;|��/��/,� ^� ^� ��«� �,^^ 20Am«:5 110 Development El Exploratory0 GINJ 0 WIwx0 »VDSPL 0 WAG 0ho,0 No. of Completions: Service 0 StraUgrapmoTest0 2. Operator Name: a. Date cnmp..Sul:A:It � 1u.Pnnn�ovom|mumuoc Union Oil Company u[Ca|nhmia Aband.: A = 208'042 3. Address: 6. Date Spudded: AP ft t 13. API Number: PO Box 1g6o47. Anchorage, AmVVo19 7/22/2008 oou � 50-733-20298-02 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Number: Name Leg u.Slot 9/20/2008 �.78s'pNL.sO1'FE�.8001o.T�Vm.m1om�S��� 9/20/2008 . GP ST 18742 32RD2 (AN-32RD2 Top of Productive Horizon: 8. KB (ft above MSL): 105' • 15.riemx=vo|$V: 4.oea'rwL.o.seg.5'FsL. Sec 1o.T1om.R12vV G.M. Ground (ft MSL): 65' • Granite Point Field Total Depth: 9. Plug Back oupth(No+7no): V.u7o.5'FNL.u.o1o.6'FEL. Sec 1o.T1nm.m1oW S.M. N/A Middle Kenai OiI P001 • 4b. Location ofWeII (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 2668*9.8 y- 2551356.4 Zone- 4 '15.378' (10,215'lVo) AoLOV Vr*o[Amnu Platform] TPI: x- 271146.8 y- 2556151.5 Zone- 4 n.GSSv Depth (MD +Tvo): 17. Land Use Permit: Total Depth: x- 271*97.4 y- 2558125.2 Zone- 4 N/A N/A 18. Directional Survey: Yes 5 No E 19. Water Depth, if Offshore: 20. Thickness of Permafros (TVD): (Submit electronic and printed information per 20 AAC 25.050) 12* , (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): _774440 91, ' Gamma. Resistivity. NMR. Formation Pressure, Neutron Density 75��'7 � -� 22. CASING, LINER AND CEMENTING RECORD �~- WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING � GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 20^ 94# X-52 Surface uon Surface 59e' 26^ s47mm cement mnunaua 13-3/8" 61/68/72# K Surface 4,020' ' Surface 3.978' 17-1/2" 1850 sxs cement 9'5/8' 43.5w7# S-95 Surface 9.089 Surface 7.640' 1o'1^*" 1620 sxs cement 7" 29# p'110 8.8e1' 13.07*' 7,476' 10.1** 8'1m^ useoxocement 4.5r 12.6# L-80 12.850 15.381' 10.162' 10.215' 6" none 23. Open to production or injection? Yes El No El n Yes, list each 24. TUBING RECORD interval open (MD�TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) [-7o13.307''13.3e5'(10.225''10.229'Tvo).6opr 2-7/8", 6.4# (Long) 11.504' N/A C-7o13.3e3'13.*77' (10.230'-10,231'Tvo).6op 2-7/8", 6.4# (Short) 8.800 N/A C-7o13,556''13,640(10,23 `-10,231' TVD), 6sp 2-3m",*.6#(S»ort) 11.562 N/A C-7C13.827'15.916'(10,225-10.220Tvo).6mpr C-7 25. . xC|o ' FRACTURE, CEMENT SQUEEZE ' ETC. C-7C14.365'14,6e2(10,20e'-10.210' Tvo).6opf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED C-7o1*.858'1*.932(10.211'-10.212' TVD), 6spf N/A N/A C-7o1*,966'1*,997 (10,212'-10,212' TVD), 6spf C-7o15,010' '15.062(10.212'-10,212'TVo).6op C-7o15,171''15.290(10,21T40.214'lVo).eup 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas Iift, etc.): N/A (See cover letter) Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ■:I. Flow Tubing Casing Press: Calculated Oil-am: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate -{■ 27. CORE DATA Conventional Core(s) Acquired? Y No 5 - Sidewall Cores Acquired? Yes �] moiS . If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. �� �°*°"V� � D / � ���8 _--~ /' o ' ^ ED '� ' Form 1n�nrnewonda�onr � ] �t� ` ^ 1 i � ] �p ^� �u ' - 28. GEOLOGIC MARKERS (List all formations anrkers encountered): 29. •ORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 • No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Tyonek C -1T 10,286' 8,708' Tyonek C -1 B 10,320' 8,739' Tyonek C -2T 10,566' 8,969' Tyonek C -2B 10,580' 8,982' Tyonek C -3T 10,639' 9,037' Tyonek C -3B 10,779' 9,166' Tyonek C-4T 10,799' 9,184' Tyonek C-4B 10,856' 9,236' Tyonek C -5AT 10,938' 9,308' Tyonek C -5BB 11,198' 9,520' Tyonek C -7AT 11,700' 9,856' Tyonek C -7AB 11,779' 9,897' Tyonek C -7CT 12,131' 10,033' Tyonek C -7DT 12,772' 10,152' Tyonek C -7CB 12,452' 10,105 Tyonek C- 7DT(inverted) 13,630' 10,230' Tyonek C- 7CB(inverted) 13,828' 10,225' Tyonek C- 7CB(repeat) 14,713' 10,210' Tyonek C- 7DT(repeat) 14,864' 10,211' Tyonek C- 7DB(repeat) 15,365' 10,215' • Formation at total depth: 30. List of Attachments: Daily Operations Summary, Well Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Flynn 263 -7824 Printed Name: Timothy C. Brandenburg Title: Drilling Manager Signature: -- --- `/, Phone: 907 - 276 -7600 Date: 11/7/2008 ( �° 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 / njection, 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 listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 Chevron • ft11001 na Platform Well No. An -32RD2 %O. Final Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 60' 30" 320# Structural - - Surface 276' 85' BML 1 A 20" 94# X -52 19.124" Surface 600' 13 -3/8" 61, 68, K -55 & N -80 BUTT 12.347" Surface 4,020' 1 72# 9 -5/8" 43.5, 47# S -95 BUTT 8.681" Surface 9,089' 7" Liner 29# P -110 Hyd 563 6.625" 8,891' 13,074' 4.5" Liner 12.6# L -80 Hyd 563 3.958 12850 15,381' Tubing Long String 2 7/8" 6.4# P -110 Hyd 503 2.441 0' 11,564' Short String 2 7/8" 6.4# P -110 Hyd 503 2.441 0' 8,800' L. 2 3/8" 4.6# P -110 Hyd 511 8,601' 11,562' JEWELRY DETAIL NO. Depth ID OD Item 52' Tubing Hanger, Cameron, 2 7/8" X 2 7/8 11" DCB B 1 53' 2.441 2.875 4' pup 2 7/8" EUE x 2 7/8 Hyd 503 404' 2 7/8" Hyd 503 tubing 11525' RA marker 2 11556' 2.144 2.875 10' pup 2 7/8" 503 Hyd x 2 7/8" Buttress 3 11,564' 2.250 5.800 Oilwell Hydraulics Type "A" Single Parallel Cavity 11574 2.630 2.875 Pup 2 7/8" EUE 8rd box x 2 3/8" Buttress pin 4 11579 2.000 3.625 1 jt 2 3/8" tubing (2 3/8" But box x 2 3/8" But pin 11610 1.995 2.88 10' Pup 2 3/8 But box x 2 3/8" EUE 8RD (HALCO) ∎1 0 5 11617 1.875 3.25 2 3/8" Sliding sleeve (1.875 profile) 11620 2.000 2.625 Pup 2 3/8" EUE 8rd pin x 2 7/8" Buttress 6 33625 2.441 2.875 38 joints 2 -7/8" Buttress Tubing 11624 1.995 2.875 XO 2 7/8" But x 2 3/8" But liga 1' s 11625 1.995 2.375 12 jts 2 3/8" SCC But Tubing (1 8 13227 1.995 2.700 10' Pup 2 3/8 Buttress x 2 3/8" eue 8 rd (SCC) 2 9 13228 1.56 3.063 2 3 /4' mechanical firing head w/ 1.56 no go 10 13229 2.75 2'/4" safety Spacer 12 13230 2.75 2 3 /4" Vann guns 6 spf 60 deg. HMX 15GR 3 13 15291 2.75 2 3 /4" Bull plug 6 Short String A 53' 3' pup 2 7/8" Mod EUE x 2 7/8 Hyd 503 Wit, B 289' jts 2 7/8" Hyd 503 tubing 7 C 8599' 1.995 2.875 X -over, 2 -7/8" Hyd 503 Box x 2 -3/8" Hyd 511 Pin • 8601' 97 jt 2 3/8" Hyd 511 tubing mo 9 D 11,562' 1.688 2.500 X -over, 2 3/8" Hyd 511.Box x " 1 'h" IJ Pin 0 -PP. ~ 12 - PERFORATION HISTORY -* Interval Pccum. 1- --10. Zone Top Btm Amt spf Comments ♦- -, C-7D 13,307 13,356 48' 6 1- 13 C-7D 13,393' 13,477 84' 6 4-- --0. C-7D 13,556 13,640' 84' 6 C-7C 13,827 13,916 85 6 --10. C-7C 14,069' 14,286 217 6 / C-7C 14,365' 14,692 327 6 C-7D 14,859' 14,937 73 6 i I = 15,381' MD / 10,217, C-7D 14,966' 14,997 31' 6 DRAWN BY: TSF 09/02/08 C-7D 15,010' 15,067 57 6 Updated By: TSF 11/03/08 C-7D 15,171' 15,29G 115 6 Chevron • 1 %0 Chevron - Alaska Daily Operations Summary Y p Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) AN -32RD2 GRANITE PT ST 18742 32RD2 ADL0018742 5073320298 AR4493 105.00 ` is _a ' i t Primary Job Type Job Category Objective Actual Start Date Actual End Date Sidetrack and Complete Sidetrack AN -32RD Phase 11 - Redrill 7/16/2008 Primary Wellbore Affected Wellbore UWI Well Permit Number AN- 32RD2 5073320298 -02 2080420 7 ry �F:. 7/18/200012:00. 7/17/2008 00 :00 Operations Summary Move rig from AN -24Rd to AN- 32RD2, Contacted AOGCC Jim Regg of upcoming BOP test. 7/17/2008 00 :00 - 7/18/2008.00:00 Operations Summary N/U BOP's, Test to 250psi low /3500 psi high. Witness waived by AOGCC Lou Grimaldi. 1401400800:00 - 7/1912000 `00'!00 Operations Summary Finish BOP test, Pull 3 1/2" tubing (kill String) 7/19/2008 00:00 - 7/20/2008 00:00 Operations Summary P/U whipstock, TIH, stuck @ 9145'MD, Free pipe, POOH w/ whipstock. /2i ti 00 :00 - 7/21/2008 00:06 Operations Summary Rig repair, replace IBOP, Set Brdige plug @ 9110'MD 7/21/2008 00:00- 7/2„2/200k00:00 - ... Operations Summary P /U Whipstock, TIH, Set on top of Bridge plug (9,110), Change well over to OBM 7122/2008 00:00 - 7/2312008 00:00 4 41 Operations Summary Mill window from 9,089'- 9,106'MD(9,071'- 9,088' original RKB),Continued to drill into formation, Performed FIT test, pumped6.5bbI @ 1/2 bpm to 1775psi., • drilled to 9151 MD, POOH with mill /220O8a00:o0. - 7/2412008 00 :00 '' , . ' '-` Operations Summary Finish POOH with milling assembly. Rearrange pipe in derrick. PU BHA #3 (8.5" bit, mud motor, MWD, subs) and begin RIH. 7124/2001100:00, Operations Summary TIH w/ drilling BHA, Drill ahead to 9410'MD 7/20/2008 00:0 Operations Summary Drill ahead to 9727'MD 1/2012008 00:00 - 7/27/2008 00 :00 ' v Operations Summary Drill ahead to 9841'MD, Short trip to shoe, Drill ahead to 9940'MD. 7/27/200800:00 - 7/28/2008 00:00 Operations Summary Drill ahead to 10290'MD 7/2012008 00:00 - 7/29/2008 Operations Summary Drill ahead to 10662' MD 7/29/2008 00:00 - 7/3012008 60:00 i"4 . " . Operations Summary Drill ahead to 10750'MD, POOH for BOP test and change bit. Contacted AOGCC Jim Regg of upcoming BOP test, waived witness 7 `!30/2008 :00k - 7131/2000800 :00 m. . 714' ; 14 Operations Summary Test BOP's to 3500/250 psi. Test good, witness waived. P/U drilling BHA, TIH 7/31/2008 00:00 - 8/1/2008 00 :00 ,' Operations Summary TIH, Wash and ream to bottom (10,750' MD) 0€!00 - 8/212008 00:00 Operations Summary Drill ahead to 11068'MD. 8/212008 00:908/312018,00:00 1 Operations Summary Drill ahead to 11,101' MD 8/3/2008 00:00 Operations Summary Drill ahead to 11166 MD, POOH, Change bit and 8/4/2008 00:00 ;81 ; . . } .� k Operations Summary Changed Bit, TIH, Drill ahead to 11,183' MD Chevron • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) AN -32RD2 GRANITE PT ST 18742 32RD2 ADL0018742 5073320298 AR4493 105.00 r DB�Ix Operatlons � � � �� y � � . 8/5/2008 00:00 ` 8/6/2008 00:00 Operations Summary Drill ahead to 11291' MD. .8200800 :00 8/7/2008 00:00 Operations Summary Drill ahead to 11324mMD Short trip to shoe, Drill ahead to 11384'MD 8/7/2008 00:00. -; 8/8/2008 00:00 n Operations Summary Drill ahead to 11157'MD, POOH 8/8/2008 00:004,4"81912008:60:00 ... �, Operations Summary TIH, Drill ahead to 11607'MD 8/9/2008 00 :00 - 8/10/2008 00 :00 ,. Operations Summary Drill ahaead to 11791'MD, POOH 8't,0/2008<O0i00 -: X8/1;112008 00:00 Operations Summary Handle BHA, TIH, Rig Repair, Wash & reamed to bottom (11,1791' MD) 8/11/2008 00:00 - 8/12/2008 00:00 Operations Summary Drill ahead tp 11,946'MD 8/12/2008 00:00.8/14312'008 do :04 :. Operations Summary Drill ahead to 12132'MD. Notified AOGCC Tom Maunder of upcoming BOP test & possible extension. !.50000 -8/14/2008 00:00 Operations Summary Drill ahead to 12290'MD, BOP test extension denied by Tom Maunder, POOH for BOP test. 8/14/2008 00:00 - 8/15/2008 00:00 Operations Summary Trip out of hole, Stand back BHA, Test BOP's 250/3500 psi, Test witnessed by AOGCC Lou Gramaldi. 8/1612008 00 :00' - 8/16/2008 rF ° .r 00 #� Operations Summary P/U drilling BHA, TIH, work tight hole. 4/4612 - 8117/2008 00:00 ; Operations Summary Cont. wash and ream open hole. 8/17/2008 00;:00 : ':*[00:9° ; 'r Operations Summary Cont. wash and ream to bottom (12,290'MD), Drill ahead in 8.5" hole to 12475'MD 8/4812003 :00 - 8/19/2008 00:00 ...,.. Operations Summary Drill ahead to 12,686'MD. u s 8/01208$ 00: 00:00 Operations Summary Drill ahead to 12,945'MD 8/20/2008 00:00 - 8/21/2008 00:00 Operations Summary Drill ahead to 13,076'MD, POOH to run logs 8/21/2008 00:00 - .8/22/2008 00 :00 ':11114,4;,:;;' . k , 14: Operations Summary POOH, UD BHA, P/U clean out BHA, TIH M 8/22/2008 00:90* $/200000 :�� °� �. � ' w, Operations Summary TIH ream tight hole 8/23 /2008.00 :00 - 8/24/2008 00:0(6, . ;. Operations Summary Continue reaming hole, work tight hole, POOH for logging tools, Handle BHA, TIH with logging tools 8/24/2008 00:00 s o : 00:00 z ` , r ., ° Operations Summary POOH for less limber BHA, Drop out Neutron Density tools, TIH and log open hole 8/25/2008:,00:00 - 8/26/2008 60:60 : .. .. 1 ,, . ; ' Operations Summary Log open hole to 12,313'MD 8/28/2008 00x00.8/27/2008 00.00r.t Operations Summary Finish logging open hole, POOH for second logging run, Handle BHA. Contacted AOGCC Jim Regg, waved witness of BOP test Chevron • • 1%0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) AN -32RD2 GRANITE PT ST 18742 32RD2 ADL0018742 5073320298 AR4493 105.00 Daily Qp780.ons 4n, a w 812712008' 00:OOa- ,8/2812008 00 :90 Operations Summary Test BOP to 250/3500 psi. AOGCC witness waived. TIH with drill pipe for second logging run to 9020' MD. 8,26l9608 00:00 - 8/29/2008 00:00 w? Operations Summary Log open hole with Testrak (Formation pressure), POOH 812912008 00:00 - 8/30/2008 00:00 Operations Summary UD BI-IA, Change upper pipe rams to 7" and test, Rig up to run 7" liner 8/30 /2008.00;00 - 8/31/200800:00 Operations Summary Begin running 7" 29# P -110 Hydril 563 casing. 8/31/2008 00:00 - 9/1/2008 00:00 Operations Summary Run 7" liner in hole washing in hole. Land casing @ 13,076'MD, cemented liner w/ 96 bbls (15.8 ppg) bump plug w/ 1,000psi, set liner hanger, mechanicaly set ZXP packer @ 8894'MD. POOH 9/i1$08 00.00` ; - ` 9/212008 00 :0ti" ,, �r� " Operations Summary UD running tools, Change out rams to 5 "x2 7/8" Test BOP's 250/3500 psi 912/2008 00:00 - 9/3/2008 00:00 Operations Summary P/U 6" drilling BHA, TIH, Test casing to 1675 psi, good test, drillout float and 20' of new hole, Perform FIT to 12.8 EMW, 1,675psi. Drill ahead to 130190 9/3/2008 00:00 9/4/2008 00 :00 Operations Summary Drill ahead to 13211'MD, POOH for rotary steerable failure, handle BHA 9/4/2008 00:00 "9/0/2008 00:00 Operations Summary Handle 6" Drilling BHA, TIH, Drill ahead to 13,389'MD 01.4(1'668 00:00 - 9/6/2008 00 :00. ,x Operations Summary Drill ahead to 13,661'MD `9/612008.00:00 917/2008 00:00 ' Operations Summary Drill ahead to 13,682'MD, POOH for bit, handle BHA. 9/7/200 6.00:00 9/8/2008 00:00 Operations Summary Handle BHA, Trip in hole, wash and ream to bottom, Drill ahead to 13,703'MD. Notified AOGCC of upcoming BOP test 9/8/2008 00:00;';9191i008 O0 2` Operations Summary Drill ahead to 13,706'MD, POOH, Test BOP's to 250/3500 psi. AOGCC (Jim Regg) waived witness of test. 9/9/2008 00:00 - 9/10/2008 00:00 . , Operations Summary Finish BOP test, Good test, M/U 6" drilling BHA, TIH, Drill ahead to 13767'MD. 9/10/2004190;00 -9/11/2008 00 :00 Operations Summary Drill ahead to 13977'MD 9/11/2008 00:004942/2006 0 • Operations Summary Drill ahead to 14064'MD POOH 02008 00:00 9/13/2008 00 :00 Operations Summary POOH, Handle BHA, TIH Drill ahead to 14100'MD 9/13/2008,00 :00 01i f10t990 :00 ., ,. mod Operations Summary Continue Drilling ahead trying to hold a 90 -91 deg and working left off of 17, AZ. to get a 0, AZ. Extremely Hard Drilling ( Geologist do say still in good sands though) 944/2008 00;00- 9/15/2008 00:00 Operations Summary Drill ahead to 14442'MD 9/16/200f960:00-,946//066'00:00 r. Operations Summary POOH, Handle BHA, TIH to drill ahead : 6/2008 00:00 - 9/17/2008 00 :00 .t :_ Operations Summary Drill ahead to 14614'MD. Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) AN -32RD2 GRANITE PT ST 18742 32RD2 ADL0018742 5073320298 AR4493 105.00 9117/200800 :O0.9 /1812008 00 :00 . `; , r Operations Summary Drill ahead to 14,735'MD and POOH 911612008 00 Ot'rt'9119/2008 Operations Summary POOH, Change bit, TIH 9/19/2008 00 :00 - 9/20/2008 00:00 Operations Summary Trip in open hole, Drill ahead to 15,148'MD 9/20/2008 00:00 - 9/21/2008 Operations Summary Drill ahead to TD of 6" hole section @ 15,378'MD. Short trip to Shoe • 9121/200800;00 - 9/2212008 00:00 Operations Summary Trip to bottom, Circulate, POOH, Handle BHA. Notified AOGCC of upcoming BOP test. 6 00 :00 Operations Summary Test BOP's 250/3500. P/U 4.5 liner RIH. Lou Gramadli & Chuck Chieve waived witness of BOP test. 9/23/2008 00:00 - 9/24/2008 00 :00 Operations Summary Land 4.5" liner @ 15,374'MD, TOL: 12,848'MD. Circulate well, displace well to base oil. 9/24/200800:00 - ,9125/4.068!00:00 1' . Operations Summary Monitor well and pull out of hole and lay down drill pipe. 912 i 00:00. 9126/2008 00:00. . Operations Summary UD drillpipe, Notify AGOCC of BOP test, waived witness by Jim Regg 912612008 00:00 - 9/27/2008 00:00 Operations Summary Test BOP's to 250/3500, P/U completion 9/27/2008 00 :00 - 9/28/200800:00 - Operations Summary Run in hole with dual 2 3/8" 4.6# L -80x2 7/8" 6.4# L -80 completion 9/28/2008'00:00 "s.9/ f2008OO 00 Operations Summary Run in hole w/ Dual completion 9/30/200800 :00 Operations Summary Land Dual completion @15.291' D, Circulate through tubing, test tubing to 3500 psi for 30 min, good test. 9/30/2008 00 :00. 101112008 00:00 Operations Summary RIH with wireline to coorelate guns on depth, UD wireline, clean stack in preparation to nipple down. 1.01118008 00:00 - 10/212008 00:00` Operations Summary Nipple down BOP's Nipple up Tree test to 5000 psi, Test good. 1012/2008 00:00 - 1`0/3/2008 00:00 Operations Summary Tie production lines to wellhead 10/3/200800 :00 - 10/4/2008 00:00 . . Operations Summary Tie production lines to production, rig down Rig 428 :1I41 . 0 8 10/6/2008 00:00 .: Operations Summary Pull standing valve from well, shift sliding sleeve closed, pressure up tubing to 2200psi, fire pert guns @ 6spf at 13,307'- 13,355', 13,393'- 13,477', 13,556'- 13,640', 13,827- 13,916', 14,069'- 14,286', 14,365- 14,692', 14,859'- 14,932', 14,966'- 14,997', 15,010'- 15,062', 15,171'- 15,290' 10/5/2008 00:00 - � � ��. � �, , � . �r. � ���fF ; ��; . Operations Summary Produce well, continue demobe of rig 428 7 r 101012. r t COQ °. = : 10/712008 00:00 Operations Summary Rig down 10/7/2008 00 :00 - 10/8/205800:00 ' ..,' Operations Summary Rig down Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) AN -32RD2 GRANITE PT ST 18742 32RD2 ADL0018742 5073320298 AR4493 105.00 DailykQperatlonS •�� , 10/8/2008 00 :00 - 101912008:00 :0Q Operations Summary Rig Down 10/9/2008 00:00 - 10/10/2008 00:00 ° } ~` Operations Summary Waiting on production for further operations. 10/10/2008 00:00 - 10/1112008 00 :00 Operations Summary Waiting on production for further operations. 10/11i2008 '00:00- ` 10/12/2008 00:00 Operations Summary Waiting on production for further operations. 10/12/2008 00:00 x 10/1 00 :00 Operations Summary Waiting on production for further operations. 10/13/2008 00:00 -1011 4/2008 00:06 w. Operations Summary Waiting on production for further operations. 0 .. " , :00 .10/1 5 /2008 00:00 Operations Summary Waiting on production for further operations. 10/1512008 00:00;- 10110/200890:00 Operations Summary Waiting on production for further operations. 1011612008`00 :00 10/17/200600i60 Operations Summary Waiting on production for further operations. Demobe rig. �s -� iffi' 0 o0:oo - 10/1812008 00:00 Operations Summary Waiting on production for further operations. Demobe rig. 10/1812008 06:00 10/19/2008:00:00 Operations Summary Waiting on production for further operations. Demobe rig. 1.01: 19120,08,00 :00 .10120 /200800:00. °` Operations Summary Demobe complete. Actual Wellpath Geo • raphic Report Report Generated 10/17/2008 at 12:40:49 PM Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Operator Chevron North Reference True Area Cook Inlet, Alaska (Offshore) Scale 0.999962 Field Granite Point Field Horizontal Reference Point Slot Facility ANNA Platform Vertical Reference Point Rig 428 (RKB) Slot slot #2 -1 MD Reference Point Rig 428 (RKB) Well AN- 32RD #2 Field Vertical Reference mean sea level Wellbore An -32RD #2 Rig 428 (RKB) to Facility Vertical Datum 124.00 ft Wellpath OnTrakMWD <9110- 15381'> Rig 428 (RKB) to mean sea level 124.00 ft Wellbore Last Revised 09/25/2008 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from AN -32 PB at 9089.00 MD Section Origin X E 0.00 ft User Ulricard Section Origin Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 33.33° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft] [USft] Slot Location - 785.01 -601.01 266849.80 2551356.43 60 °58'37.008 "N 151 °18'45.292 "W Facility Reference Pt 267466.35 2552129.24 60 °58'44.738 "N 151 °1633.113 "W Field Reference Pt 267571.89 2557407.98 60 °5936.731 "N 151 98'33.112"W TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [°j [°] [ft] [ft] [ft] [ft] [sry ft] [sry ft] [° /100ft] [°] [° /100ft] [° /100ft] [ft] 0.00 0.00 119.11 0.00 - 124.00 0.00 0.00 266849.80 2551356.43 60 °5637.008 "N 151 18'45.292M 0.00 0.00 0.00 0.00 0.00 19.00 0.00 119.11 19.00 - 105.00 0.00 0.00 266849.80 2551356.43 60 °58'37.008 "N 151 9645.292'W 0.00 119.11 0.00 0.00 0.00 119.00 0.53 119.11 119.00 -5.00 -0.23 0.40 266850.20 2551356.20 60 °58'37.006 "N 151 98'45.284M 0.53 115.15 0.53 0.00 0.03 219.00 0.50 127.90 218.99 94.99 -0.72 1.15 266850.94 2551355.69 60 °5637.001 "N 151 9645.269"W 0.08 98.23 -0.03 8.79 0.03 319.00 0.53 157.11 318.99 194.99 -1.41 1.68 266851.45 2551354.98 60 °5836.994 "N 151 98'45.258 "W 0.26 - 102.09 0.03 29.21 -0.26 419.00 0.52 140.31 418.99 294.99 -2.19 2.15 266851.90 2551354.20 60 °5636.986 "N 15198'45.248 "W 0.15 95.77 -0.01 -16.80 -0.65 519.00 0.53 158.61 518.98 394.98 -2.97 2.60 266852.34 2551353.41 60 °5636.979 "N 151 98'45.236W 0.17 - 159.34 0.01 18.30 -1.05 619.00 0.40 151.40 618.98 494.98 -3.70 2.94 266852.67 2551352.67 60 °58'36.971 "N 151 98'45.232 "W 0.14 70.43 -0.13 -7.21 -1.48 719.00 0.62 184.39 718.98 594.98 -4.55 3.07 266852.77 _ 2551351.82 60 °5636.963 "N 151 °1645.230M 0.36 85.75 0.22 32.99 -2.12 819.00 1.50 245.80 818.96 694.96 -5.63 1.83 266851.52 2551350.77 60 °58'36.952 "N 151 °18'45.255"W 1.32 13.03 0.88 61.41 -3.70 919.00 2.65 251.50 918.89 794.89 -6.90 -1.56 266848.11 2551349.57 60 °5636.940 "N 151 9645.323'W 1.17 23.91 1.15 5.70 -6.62 1019.00 3.20 255.80 1018.76 894.76 -8.31 -6.45 266843.18 2551348.25 60 °5836.926 "N 151 °18'45.423M 0.59 22.20 0.55 4.30 -10.49 1119.00 3.27 256.30 1118.60 994.60 -9.67 - 11.93 266837.68 2551347.00 60 °5836.913 "N 151 9845.534'W 0.08 31.33 0.07 0.50 -14.64 1219.00 3.57 259.19 1218.42 1094.42 -10.93 -17.76 266831.83 2551345.85 60 °5836.900 "N 151 9645.652M 0.35 -45.01 0.30 2.89 -18.89 1319.00 3.68 257.50 1318.22 1194.22 -12.21 -23.95 266825.61 2551344.70 60 °5636.888 "N 151 9645.777W 0.15 46.60 0.11 -1.69 -23.36 1419.00 3.95 261.50 1418.00 1294.00 -13.42 -30.49 266819.05 2551343.63 60 °5636.876 "N 151 °18'45.916W 0.38 28.41 0.27 4.00 -27.96 1519.00 4.27 263.80 1517.75 1393.75 -14.33 -37.60 266811.92 2551342.86 60 °5636.867 "N 151 °18'46.054M 0.36 41.87 0.32 2.30 -32.63 1619.00 4.60 267.39 1617.45 1493.45 -14.91 -45.30 266804.21 2551342.43 60 °5636.861 "N 151 °18'46.210"W 0.43 -20.48 0.33 3.59 -37.35 1719.00 4.80 266.50 1717.11 1593.11 -15.35 -53.49 266796.02 2551342.15 60 °5636.857"N 151 9646.376W 0.21 45.13 0.20 -0.89 -42.21 1819.00 4.93 268.00 1816.75 1692.75 -15.76 -61.96 266787.54 2551341.92 60 °58'36.853 "N 15118'46.547 "W 0.18 51.54 0.13 1.50 -47.20 1919.00 5.72 277.11 1916.32 1792.32 -15.29 -71.20 266778.31 2551342.57 60 °5636.857"N 151°1646.735W W 1.15 69.29 0.79 9.11 -51.89 2019.00 7.26 299.00 2015.69 1891.69 -11.61 -81.67 266767.92 2551346.46 60 °58'36.893 "N 15198'46.947M 2.89 125.89 1.54 21.89 -54.57 2119.00 6.30 313.90 2115.00 1991.00 -4.74 -91.15 266758.58 2551353.52 60 °5636.961 "N 151 9647.139 "W 2.00 95.36 -0.96 14.90 -54.04 2219.00 6.52 335.20 2214.39 2090.39 4.22 - 97.49 266752.42 2551362.60 60 °58'37.049 "N 151 98'47.267M 2.37 67.77 0.22 21.30 -50.03 2319.00 7.83 352.61 2313.61 2189.61 16.13 - 100.74 266749.40 2551374.58 60 °5837.167 "N 151 18'47.333 "W 2.52 98.41 1.31 17.41 -41.87 ID 2419.00 8.00 15.69 2412.69 2288.69 29.59 -99.74 266750.68 2551388.01 60 °5637.299"N 151 18'47.313W 3.16 53.81 0.17 23.08 -30.07 2519.00 8.88 22.89 2511.60 2387.60 43.40 -94.85 266755.84 2551401.72 60 °5837.435 "N 151 9647.214M 1.37 -3.27 0.88 7.20 -15.85 2619.00 9.13 22.80 2610.37 2486.37 57.82 -88.78 266762.20 2551416.02 60 °58'37.577 "N 151 °1647.091M 0.25 90.54 0.25 -0.09 -0.46 2719.00 9.13 23.89 2709.10 2585.10 72.39 -82.49 266768.78 2551430.46 60 °5637.721 "N 151 9646.963W 0.17 -60.24 0.00 1.09 15.17 2819.00 9.35 21.60 2807.81 2683.81 87.20 -76.29 266775.28 2551445.14 60 °5837.866 "N 151 98'46.838M 0.43 -76.23 0.22 -2.29 30.95 2919.00 9.45 19.30 2906.47 2782.47 102.50 - 70.58 266781.29 2551460.32 60 °58'38.01 151 °18'46.722M 0.39 -46.23 0.10 - 2.30 46.86 3019.00 9.68 17.89 3005.07 2881.07 118.25 -65.29 266786.90 2551475.96 60 °58'38.172 "N 151°18'46.616W 0.33 -72.59 0.23 -1.41 62.93 3119.00 9.78 16.10 3103.64 2979.64 134.41 -60.35 266792.16 2551492.02 60 °58'38.331 "N 151 98'46.515W 0.32 109.82 0.10 -1.79 79.15 3219.00 9.28 28.39 3202.27 3078.27 149.66 -54.16 266798.65 2551507.14 60 °5838.482 "N 151 98'46.389 "W 2.09 31.97 -0.50 12.29 95.30 3319.00 10.75 33.19 3300.74 3176.74 164.56 -45.22 266807.89 2551521.86 60 °5638.628 "N 151 °1646.208W 1.69 -2.82 1.47 4.80 112.66 3419.00 12.02 32.89 3398.77 3274.77 181.11 -34.46 266818.98 2551538.19 60 °5838.791 "N 151 9645.990 "W 1.27 -17.00 1.27 -0.30 132.40 3519.00 12.97 31.60 3496.40 3372.40 199.41 -22.93 266830.87 2551556.26 60 °58'38.971 "N 151 98'45.756W 0.99 -20.79 0.95 -1.29 154.03 3619.00 14.35 29.50 3593.57 3469.57 219.76 -10.94 266843.26 2551576.36 60 °5839.172 "N 151 9645.514'W 1.47 -3.83 1.38 -2.10 177.61 3719.00 15.13 29.30 3690.28 3566.28 241.93 1.55 266856.19 2551598.27 60 °5639.390 "N 151 9645.261M 0.78 -29.84 0.78 -0.20 202.99 3819.00 16.65 26.30 3786.46 3662.46 266.15 14.28 266869.41 2551622.23 60 °5839.629 "N 151 °18'45.002 "W 1.73 -27.29 1.52 -3.00 230.23 3919.00 17.60 24.69 3882.02 3758.02 292.73 26.95 266882.60 2551648.55 60 °5839.890 "N 151 98'44.746'W 1.06 - 121.39 0.95 -1.61 259.40 4019.00 16.87 20.30 3977.54 3853.54 320.08 38.30 266894.50 2551675.67 60 °58'40.160 "N 151 °1644.516W 1.49 34.61 -0.73 -4.39 288.48 4119.00 18.67 24.10 4072.77 3948.77 348.30 49.87 266906.63 2551703.65 60 °58'40.438 "N 151 9644.281M 2.14 55.12 1.80 3.80 318.42 4219.00 21.00 32.60 4166.85 4042.85 378.02 66.06 266923.42 2551733.03 60 °58'40.730 "N 151 9643.953W 3.70 34.03 2.33 8.50 352.15 4319.00 24.17 37.69 4259.17 4135.17 409.33 88.24 266946.22 2551763.89 60 °5641.038 "N 151 °1643.504M 3.72 -8.99 3.17 5.09 390.49 4419.00 27.05 36.69 4349.34 4225.34 443.77 114.35 266973.01 2551797.80 60 °58'41.378 "N 151 98'42.975W 2.91 -4.37 2.88 -1.00 433.61 4519.00 29.57 36.30 4437.37 4313.37 481.89 142.55 267001.96 2551835.35 60 °5641.753 "N 151 °18'42.403M 2.53 -11.66 2.52 -0.39 480.96 Page 1 of 3 TVD from MD Inclination Azimuth TVD Ad Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [sry ft] [sry ft] [ °/100ft] [°] [ °/100ft] [° /100ft] [ft] 4619.00 32.72 35.10 4522.95 4398.95 523.90 172.70 267032.95 2551876.75 60 °58'42.167 "N 151 °18'41.792'W 3.21 -7.32 3.15 - 1.20 532.63 4719.00 35.97 34.39 4605.50 4481.50 570.26 204.84 267066.01 2551922.45 60 °58'42.623 "N 151 °18'41.141'W 3.27 -9.25 3.25 -0.71 589.02 4819.00 39.03 33.60 4684.83 4560.83 620.73 238.86 267101.04 2551972.23 60 °58'43.120 "N 151 98'40.451'W 3.10 -6.09 3.06 -0.79 649.89 4919.00 40.87 33.30 4761.49 4637.49 674.31 274.25 267137.49 2552025.08 60 °58'43.648 "N 151 °1539.734'W 1.85 90.84 1.84 -0.30 714.10 5019.00 40.88 36.30 4837.11 4713.11 728.03 311.59 267175.90 2552078.05 60 °58'44.177 "N 151 °1538.977'W 1.96 109.43 0.01 3.00 779.50 5119.00 39.55 43.10 4913.51 4789.51 777.68 352.74 267218.03 2552126.86 60 °58'44.666 "N 151 °18'38.143'W 4.59 31.19 -1.33 6.80 843.59 5219.00 40.63 44.10 4990.01 4866.01 824.31 397.15 267263.37 2552172.58 60 °58'45.125 "N 151 1.26 4.13 1.08 1.00 906.95 5319.00 42.50 44.30 5064.83 4940.83 871.87 443.40 267310.56 2552219.21 60 °58'45.593 "N 151 °18'36.306'W 1.87 2.81 1.87 0.20 972.10 5419.00 43.77 44.39 5137.80 5013.80 920.76 491.19 267359.32 2552267.13 60 °5546.075 "N 151 °18'35.337'W 1.27 -15.81 1.27 0.09 1039.21 5519.00 45.02 43.89 5209.25 5085.25 970.97 539.91 267409.03 2552316.3560 °58'46.569 "N 151 °18'34.350'W 1.30 -59.34 1.25 -0.50 1107.93 5619.00 45.27 43.30 5279.79 5155.79 1022.31 588.79 267458.93 2552366.70 60 °58'47.074 "N 151 °18'33.359'W 0.49 0.00 0.25 -0.59 1177.68 5719.00 45.77 43.30 5349.85 5225.85 1074.24 637.73 267508.89 2552417.63 60 °58'47.586 "N 151 °1832.368'W 0.50 4.35 0.50 0.00 1247.95 5819.00 46.63 43.39 5419.06 5295.06 1126.73 687.27 267559.47 2552469.12 60 °5548.103"N 151 °1531.364'W 0.86 0.00 0.86 0.09 1319.03 5919.00 46.77 43.39 5487.65 5363.65 1179.61 737.26 267610.51 2552520.99 60 °58'48.623 "N 151 °18'30.350'W 0.14 -5.76 0.14 0.00 1390.69 6019.00 48.25 43.19 5555.19 5431.19 1233.29 787.82 267662.14 2552573.64 60 °58'49.152 "N 151 9829.326'W 1.49 20.77 1.48 -0.20 1463.31 _ 6119.00 49.25 43.69 5621.12 5497.12 1287.87 839.52 267714.91 2552627.18 60 °5549.689 "N 151 9528.278'W 1.07 4.61 1.00 0.50 1537.33 6219.00 50.30 43.80 5685.70 5561.70 1343.03 892.31 267768.80 2552681.26 60 °58'50.232 "N 151 °18'27.208'W 1.05 -8.94 1.05 0.11 1612.42 6319.00 51.80 43.50 5748.57 5624.57 1399.30 945.99 267823.59 2552736.45 60 °58'50.787 "N 151 9826.120'W 1.52 21.79 1.50 -0.30 1688.93 6419.00 53.00 44.10 5809.58 5685.58 1456.48 1000.83 267879.56 2552792.52 60 °58'51.350 "N 151 9525.008'W 1.29 8.61 1.20 0.60 1766.83 6519.00 54.07 44.30 5869.01 5745.01 1514.14 1056.89 267936.77 2552849.03 60 °58'51.917"N 151 °18'23.872'W 1.08 -9.61 1.07 0.20 1845.81 6619.00 56.08 43.89 5926.26 5802.26 1573.02 1113.94 267994.98 2552906.76 60 °58'52.497 "N 151 °18'22.716'W 2.04 -50.38 2.01 -0.41 1926.35 6719.00 56.28 43.60 5981.92 5857.92 1633.04 1171.39 268053.62 2552965.61 60 °5553.088 "N 151 9821.551'W 0.31 -98.35 0.20 -0.29 2008.06 6819.00 56.22 43.10 6037.47 5913.47 1693.50 1228.46 268111.89 2553024.92 60 °58'53.683 "N 151 9820.395'W 0.42 - 141.77 -0.06 -0.50 2089.94 6919.00 55.08 42.00 6093.90 5969.90 1754.32 1284.29 268168.93 2553084.60 60 °58'54.282 "N 151 1519.263'W 1.46 - 132.86 -1.14 -1.10 2171.43 7019.00 54.62 41.39 6151.47 6027.47 1815.37 1338.68 268224.52 2553144.55 60 °58'54.883 "N 151 98'18.160'W 0.68 - 156.70 -0.46 -0.61 2252.32 • 7119.00 53.52 40.80 6210.15 6086.15 1876.39 1391.91 268278.96 _ 2553204.49 60 °58'55.484"N 151 1517.082W 1.20 - 146.09 -1.10 -0.59 2332.55 7219.00 52.45 39.89 6270.35 6146.35 1937.24 1443.60 268331.86 2553264.29 60 °58'56.083 "N 151 9516.034'W 1.29 - 146.81 -1.07 -0.91 2411.80 7319.00 51.85 39.39 6331.71 6207.71 1998.04 1493.98 268383.44 2553324.07 60 °58'56.682 "N 151 18'15.013'W 0.72 177.65 -0.60 -0.50 2490.28 7419.00 49.80 39.50 6394.88 6270.88 2057.91 1543.23 268433.88 2553382.93 60 °5557.271 "N 151 18'14.014'W 2.05 171.33 -2.05 0.11 2567.35 7519.00 48.33 39.80 6460.40 6336.40 2116.07 1591.43 268483.23 2553440.12 60 °58'57.844 "N 151 98'13.03TW 1.49 - 177.81 -1.47 0.30 2642.44 7619.00 46.25 39.69 6528.22 6404.22 2172.57 1638.41 268531.33 2553495.66 60 °58'58.400 "N 151 98'12.085W 2.08 -3.51 -2.08 -0.11 2715.45 7719.00 47.33 39.60 6596.69 6472.69 2228.69 1684.91 268578.95 2553550.83 60 °58'58.953 "N 151 °18'11.142'W 1.08 180.00 1.08 -0.09 2787.89 7819.00 46.37 39.60 6665.08 6541.08 2284.90 1731.41 268626.56 2553606.10 60 °58'59.506 "N 151 18'10.199W 0.96 - 177.40 -0.96 0.00 2860.41 7919.00 44.82 39.50 6735.05 6611.05 2339.99 1776.90 268673.15 2553660.26 60 °59'00.049"N 151 9509.277'W 1.55 145.73 -1.55 -0.10 2931.43 8019.00 44.42 39.89 6806.23 6682.23 2394.03 1821.76 268719.08 2553713.40 60 °59'00.581 "N 151 1508.368'W 0.48 - 144.93 -0.40 0.39 3001.24 8119.00 43.55 39.00 6878.18 6754.18 2447.66 1865.89 268764.27 2553766.12 60 °59'01.109 "N 151 9507.473'W 1.07 154.27 -0.87 -0.89 3070.29 8219.00 42.31 39.89 6951.40 6827.40 2500.26 1909.15 268808.58 2553817.84 60 °59'01.627 "N 151 1506.596'W 1.38 180.00 -1.24 0.89 3138.01 8319.00 41.20 39.89 7026.00 6902.00 2551.35 1951.86 268852.30 2553868.07 60 °59'02.130N 151 9505.730'W 1.11 - 134.97 -1.11 0.00 3204.16 8419.00 40.31 38.50 7101.75 6977.75 2601.94 1993.12 268894.56 2553917.82 60 °5902.628 "N 151 18'04.894W 1.27 - 177.02 -0.89 -1.39 3269.10 8519.00 38.98 38.39 7178.75 7054.75 2651.91 2032.79 268935.22 2553966.98 60 °5903.120N 151 98'04.090'W 1.33 172.04 -1.33 -0.11 3332.65 8619.00 37.67 38.69 7257.20 7133.20 2700.41 2071.43 268974.82 2554014.70 60 °5903.597 "N 151 18'03.306'W 1.32 - 176.13 -1.31 0.30 3394.40 8719.00 36.02 38.50 7337.22 7213.22 2747.28 2108.83 269013.16 2554060.81 60 °59'04.059 "N 151 18'02.548'W 1.65 176.94 -1.65 -0.19 3454.11 8819.00 34.95 38.60 7418.65 7294.65 2792.68 2145.01 269050.23 2554105.47 60 °5904.506 "N 151 98'01.815W 1.07 - 100.03 -1.07 0.10 3511.92 8919.00 34.92 38.30 7500.63 7376.63 2837.52 2180.62 269086.73 2554149.59 60 °5904.947 "N 151 9501.093'W 0.17 158.37 -0.03 -0.30 3568.95 9019.00 33.80 39.10 7583.18 7459.18 2881.57 2215.90 269122.89 2554192.92 60 °59'05.381 "N 151 98'00.377W 1.21 - 174.75 -1.12 0.80 3625.14 9089.00 32.94 38.95 7641.63 7517.63 2911.48 2240.14 269147.72 2554222.34 60 °59'05.675 "N 151 °17'59.886'W 1.24 81.79 -1.23 -0.21 3663.46 9110.00 33.27 42.50 7659.23 7535.23 2920.17 2247.63 269155.38 2554230.87 60 °59'05.761 "N 151 97'59.734'W 9.35 159.53 1.58 16.88 3674.82 Azimuth Assumed 9161.00 31.86 43.50 7702.21 7578.21 2940.25 2266.34 269174.49 2554250.57 60 °5905.959 "N 151 97'59.355'W 2.96 149.16 -2.76 1.96 3701.88 Azimuth Assumed 9256.00 30.59 45.00 7783.45 7659.45 2975.53 2300.70 269209.54 2554285.16 60 °59'06.306 "N 151 °17'58.658'W 1.57 120.17 -1.34 1.58 3750.24 Azimuth Assumed • 9351.00 29.63 48.50 7865.63 7741.63 3008.19 2335.38 269244.87 2554317.11 60 °59'06.628 "N 151 °17'57.955'W 2.11 125.60 -1.01 3.68 3796.58 Azimuth Assumed 9443.00 28.48 52.00 7946.06 7822.06 3036.76 2369.70 269279.76 2554344.99 60 °59'06.909 "N 151 97'57.259'W 2.23 114.52 -1.25 3.80 3839.32 Azimuth Assumed 9537.00 27.35 58.01 8029.14 7905.14 3062.01 2405.69 269316.24 2554369.51 60 °5907.157 "N 151 1756.530'W 3.22 141.97 -1.20 6.39 3880.18 9630.00 26.65 59.24 8112.00 7988.00 3083.99 2441.73 269352.71 2554390.77 60 °59'07.374 "N 151 °17'55.799'W 0.96 130.96 -0.75 1.32 3918.35 9726.00 26.14 60.59 8197.99 8073.99 3105.39 2478.65 269390.06 2554411.42 60 °59'07.584 "N 151 97'55.051'W 0.82 131.96 -0.53 1.41 3956.51 9781.00 25.39 62.57 8247.53 8123.53 3116.77 2499.67 269411.30 2554422.38 60 °59'07.696 "N 151 17'54.625W 2.08 121.43 -1.36 3.60 3977.57 9819.00 25.24 63.15 8281.88 8157.88 3124.18 2514.13 269425.91 2554429.50 60 °59'07.769 "N 151 °17'54.331'W 0.76 103.66 -0.39 1.53 3991.71 9912.00 24.91 66.81 8366.12 8242.12 3140.85 2549.83 269461.93 2554445.45 60 °5907.933 "N 151 °17'53.608'W 1.70 131.50 -0.35 3.94 4025.25 10006.00 23.25 71.79 8451.94 8327.94 3154.45 2585.65 269498.02 2554458.32 60 °5908.067"N 151 97'52.882'W 2.79 164.16 -1.77 5.30 4056.29 10100.00 22.64 72.24 8538.51 8414.51 3165.76 2620.51 269533.09 2554468.94 60 °5908.179 "N 151 °17'52.175'W 0.68 - 119.34 -0.65 0.48 4084.90 10190.00 22.55 71.82 8621.60 8497.60 3176.43 2653.40 269566.19 2554478.95 60 °59'08.284 "N 151 °1 7'51.508'W 0.21 - 168.77 -0.10 -0.47 4111.88 10284.00 22.04 71.55 8708.57 8584.57 3187.64 2687.26 269600.26 2554489.47 60 °59'08.394 "N 151 17'50.822'W 0.55 - 159.52 -0.54 -0.29 4139.85 10380.00 21.94 71.45 8797.59 8673.59 3199.04 2721.34 269634.57 2554500.19 60 °5908.506 "N 151 97'50.131'W 0.11 - 159.73 -0.10 -0.10 4168.10 10472.00 21.34 70.84 8883.10 8759.10 3210.00 2753.45 269666.89 2554510.51 60 °59'08.614 "N 151 17'49.480'W 0.70 177.34 -0.65 -0.66 4194.90 10567.00 20.88 70.90 8971.73 8847.73 3221.22 2785.78 269699.43 2554521.07 60 °59'08.724 "N 151 °1748.825W 0.48 -9.37 -0.48 0.06 4222.03 10661.00 21.64 70.56 9059.33 8935.33 3232.47 2817.95 269731.82 2554531.67 60 °59'08.835 "N 151 97'48.173'W 0.82 - 107.57 0.81 -0.36 4249.11 10690.00 21.56 69.86 9086.29 8962.29 3236.08 2828.00 269741.94 2554535.08 60 °5908.871 "N 151 17'47.969W 0.93 -3.82 -0.28 -2.41 4257.65 10758.00 22.84 69.64 9149.25 9025.25 3244.97 2852.10 269766.21 2554543.49 60 °5908.958 "N 151 9747.480'W 1.89 -16.94 1.88 -0.32 4278.32 10853.00 26.98 66.88 9235.40 9111.40 3259.86 2889.22 269803.62 2554557.63 60 °59'09.105 "N 151 1746.725W 4.53 -24.47 4.36 - 2.91 4311.15 10945.00 30.22 63.98 9316.16 9192.16 3278.22 2929.23 269843.99 2554575.18 60 °5909.285 "N 151 °17'45.917'W 3.83 -27.18 3.52 -3.15 4348.48 11040.00 34.87 59.87 9396.23 9272.23 3302.35 2974.24 269889.47 2554598.41 60 °5909.523 "N 151 17'45.004'W 5.42 -46.93 4.89 -4.33 4393.37 11137.00 37.57 55.29 9474.50 9350.50 3333.12 3022.54 269938.38 _ 2554628.20 60 °59'09.826 "N 151 1744.025W 3.94 -41.71 2.78 -4.72 4445.62 11229.00 39.84 52.19 9546.29 9422.29 3367.16 3068.89 269985.40 2554661.31 60 °59'10.161 "N 151'17'43.085'W 3.24 -16.65 2.47 - 3.37 4499.53 Page 2 of 3 TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [] [°] [ft] [ft] [ft] [ft] [sry ft] [sry ft] [°/100ft) [1 [ [ [ft] 11323.00 43.74 50.51 9616.37 9492.37 3406.31 3117.78 270035.06 2554699.46 60 °59'10.546 "N 151 17'42.094' 4.32 -25.09 4.15 -1.79 4559.09 11417.00 47.06 48.40 9682.36 9558.36 3449.83 3168.61 270086.75 2554741.96 60 °59'10.975 "N 151 97'41.064' 3.88 -12.28 3.53 - 2.24 4623.38 11514.00 49.80 47.62 MEM 9622.72 3498.38 3222.53 270141.63 2554789.42 60 °5911.453 "N 15197'39.970' ' J r c, 4693.58 11608.00 53.28 45.70 9805.18 9681.18 3548.91 3276.03 270196.13 2554838.86 60 °59'11.950 "N 151 °17'38.886' 4.03 -23.41 3.70 -2.04 4765.19 11699.00 56.53 44.02 9857.50 9733.50 3601.69 3328.53 270249.67 2554890.58 60 °59'12.470 "N 151 97'37.821' 3.88 -23.46 3.57 -1.85 4838.13 11795.00 60.71 41.95 9907.48 9783.48 3661.65 3384.36 270306.69 2554949.41 60 °59'13.060 "N 15197'36.689' 4.73 -11.67 4.35 -2.16 4918.91 11887.00 65.11 40.95 9949.36 9825.36 3723.03 3438.56 270362.11 2555009.69 60 °59'13.664 "N 15197'35.590' 4.88 -21.82 4.78 -1.09 4999.97 11985.00 69.33 39.15 9987.30 9863.30 3792.20 3496.67 270421.58 2555077.67 60 °59'14.345 "N 15197'34.412' 4.63 -52.95 4.31 - 1.84 5089.69 12077.00 70.76 37.16 10018.70 9894.70 3860.19 3550.08 270476.35 2555144.58 60 °5915.014 "N 151 17'33.329' 2.56 -36.93 1.55 -2.16 5175.85 12173.00 74.45 34.30 10047.40 9923.40 3934.55 3603.54 270531.29 2555217.85 60 °59'15.746 "N 151 17'32.244' 4.78 -14.74 3.84 -2.98 5267.35 12224.00 76.82 33.66 10060.05 9936.05 3975.52 3631.15 270559.71 2555258.26 60 °59'16.150"N 15197'31.685' 4.80 -44.44 4.65 - 1.25 5316.75 12258.00 MIMIIME101. 10067.45 Maern 4003.34 NE= 270578.35 2555285.71 60 °59'16.424 "N 15197'31.318' 5.14 36.28 3.68 - 3.68 5349.94 12292.00 111=31MMESUMIIII=1 9950.45 4031.42 3667.09 270596.76 2555313.42 60 °5916.700 "N 151 °17'30.956' 0.29 104.37 0.24 0.18 5383.20 12324.00 11111EIMEMEME 10081.05 9957.05 4057.78 3683.99 270614.18 2555339.44 60 °5916.960 'N 151 97'30.613' 1.26 -96.51 -0.31 1.25 5414.51 12351.00 IMMEIMESEMI 10086.65 9962.65 4080.00 3698.27 270628.91 2555361.36 60 °5917.178 "N 151 °17'30.323' 0.98 - 121.04 -0.11 - 1.00 5440.92 12386.00 77.92 32.43 10093.94 9969.94 4108.86 3716.67 270647.88 2555389.85 60 °5917.463 "N 151 9729.950' 0.55 118.45 -0.29 -0.49 5475.15 12418.00 77.83 32.60 10100.66 9976.66 4135.24 3733.49 270665.22 2555415.89 60 °5917.722 'N 151 1729.609' 0.59 -96.87 -0.28 0.53 5506.44 12445.00 77.76 32.00 10106.37 9982.37 4157.55 3747.59 270679.77 2555437.91 60 °59'17.942 "N 151 9729.323' 2.19 33.36 -0.26 -2.22 5532.82 12499.00 78.43 32.45 10117.51 9993.51 4202.25 3775.77 270708.83 2555482.03 60 °59'18.382 "N 151 97'28.752' 1.48 -0 .72 1.24 0.83 5585.65 12540.00 81.60 32.41 10124.62 10000.62 4236.33 3797.42 270731.16 2555515.67 60 °59'18.717 "N 151 9728.312' 7.73 13.50 7.73 -0 .10 5626.02 12576.00 ® 10129.49 10005.49 =MEI 3816.62 270750.96 2555545.34 60 °5919.013 "N 151 1727.923' 3.54 -82.89 3.44 0. 83 5661.68 12608.00 82.97 31.67 10133.44 10009.44 4293.26 3833.53 270768.41 2555571.87 60 °5919.278 "N 151 9727.580' 3.25 0.00 0.41 - 3.25 5693.43 12636.00 83.31 31.67 10136.79 10012.79 4316.92 3848.13 270783.47 2555595.23 60 °59'19.511 "N 151 1727.284' 1.21 61.23 1.21 0.00 5721.22 • 12666.00 83.37 31.78 10140.27 10016.27 4342.27 3863.80 270799.65 2555620.25 60 °5919.760 "N 151 1726.966' 0.42 130.92 0.20 0.37 5751.00 12729.00 82.64 32.63 10147.94 10023.94 4395.18 3897.12 270834.02 2555672.48 60 °59'20.281 "N 151 9726.290' 1.77 165.34 -1.16 1.35 5813.52 12783.00 82.11 32.77 10155.11 10031.11 4440.21 3926.04 270863.83 2555716.93 60 °59'20.725 "N 1519725.704' 1.01 - 103.38 -0 .98 0.26 5867.04 12821.00 82.07 32.60 10160.34 10036.34 4471.89 3946.36 270884.79 2555748.20 60 °59'21.037 "N 151 9725.291' 0.46 - 113.40 -0 .11 -0 .45 5904.68 12856.00 82.04 32.53 10165.17 10041.17 4501.11 3965.02 270904.03 2555777.03 60 °59'21.324 "N 151 97'24.913' 0.22 90.02 -0 .09 -0 .20 5939.34 12889.00 82.04 32.78 10169.74 10045.74 4528.62 3982.65 270922.21 2555804.19 60 °59'21.595 "N 151 9724.555' 0.75 164.63 0.00 0.76 5972.02 12921.00 '® 10050.22 MIZIE3 3999.82 270939.90 2555830.47 60 °59'21.857 "N 151 97'24.207' 0.58 145.29 -0.56 0.16 6003.70 12953.00 MIME 32.90 10178.78 1111=3INEMEI 4017.01 270957.62 2555856.72 60 °59'22.119 "N 151°17'23.859' 0.38 -99.56 -0 .31 0.22 6035.37 12984.00 81.75 32.84 10183.23 10059.23 4607.63 4033.66 270974.78 2555882.15 60 °59'22.373 "N 151 9723.521' 0.19 -4.36 -0 .03 -0.19 6066.05 13017.00 81.88 32.83 10187.93 10063.93 4635.07 4051.37 270993.04 2555909.23 60 °59'22.643 "N 151 1723.162' 0.40 - 117.70 0.39 -0.03 6098.72 13157.00 81.11 31.34 10208.63 10084.63 4752.38 4124.92 271068.92 2556025.04 60 °59'23.798 "N 15197'21.670' 111.13MMECAMEN=01.111.2MMI 13248.00 81.49 30.16 10222.40 10098.40 4829.68 4170.91 271116.45 2556101.40 60 °59'24.559 "N 151 1720.737' 1.35 -2.98 0.42 - 1.30 6327.00 13346.00 88.03 29.82 10231.34 10107.34 4914.16 4219.66 271166.88 2556184.89 60 °59'25.391 "N 15197'19.748' 6.68 -18.53 6.67 -0.35 6424.37 13442.00 89.97 29.17 10233.02 10109.02 4997.70 4266.92 271215.80 2556267.46 60 °59'26.213 "N 151 1718.789' 2.13 -79.69 2.02 -0 .68 6520.14 13535.00 90.09 28.51 10232.97 10108.97 5079.17 4311.78 271262.28 2556348.01 60 °59'27.015 "N 151 97'17.879' 0.72 -76.36 0.13 -0.71 6612.85 13627.00 90.98 24.84 10232.11 10108.11 5161.36 4353.07 271305.21 2556429.35 60 °59'27.825 "N 151 °17'17.042' 4.10 - 104.24 0.97 3.99 6704.21 13663.00 90.50 22.95 10231.65 10107.65 5194.27 4367.65 271320.44 2556461.96 60 °59'28.149 "N 151 1716.746' 5.42 -93.92 -1.33 -5.25 6739.72 13716.00 90.32 20.33 10231.27 10107.27 5243.53 4387.19 271340.97 2556510.82 60 °59'28.634 "N 151 1716.349' 4.95 -1.13 -0 .34 -4.94 6791.62 13809.00 93.86 20.26 10227.88 10103.88 5330.68 4419.42 271374.94 2556597.30 60 °59'29.492 "N 151 °17'15.695' 3.81 - 124.91 3.81 -0.08 6882.15 13905.00 92.96 18.97 10222.17 10098.17 5420.95 4451.59 271408.90 2556686.90 60 °59'30.380 "N 15197'15.042' 1.64 - 133.15 -0 .94 -1.34 6975.24 13998.00 91.91 17.85 10218.21 10094.21 5509.11 4480.93 271440.01 2556774.45 60 °59'31.248 "N 15197'14.447' 1.65 151.44 -1.13 -1.20 7065.02 14093.00 91.12 18.28 10215.70 10091.70 5599.39 4510.38 271471.26 2556864.13 60 °59'32.137 "N 151 9713.849' 0.95 -60.16 -0 .83 0.45 7156.64 14188.00 91.55 17.53 10213.49 10089.49 5689.76 4539.58 271502.26 2556953.89 60 °59'33.027 "N 151 1713.256' 0.91 - 160.20 0.45 -0 .79 7248.19 14282.00 91.05 17.35 10211.36 10087.36 5779.42 4567.75 271532.21 2557042.96 60 °59'33.910 "N 151 9712.684' 0.57 - 108.86 -0.53 -0.19 7338.58 14374.00 89.73 13.49 10210.73 10086.73 5868.09 4592.20 271558.44 2557131.12 60 °59'34.783 "N 15197'12.188' 4.43 -90.49 -1.43 -4.20 7426.10 14469.00 89.70 9.92 10211.20 10087.20 5961.10 4611.47 271579.57 2557223.72 60 °59'35.699 "N 151 9711.797' 3.76 -90.30 -0.03 3.76 7514.40 • 14562.00 89.67 3.81 10211.71 10087.71 6053.38 4622.58 271592.52 2557315.76 60 °59'36.607 "N 151 °17'11.571' 6.57 -90.97 -0 .03 3.57 7597.62 14656.00 89.61 0.21 10212.30 10088.30 6147.31 4625.88 271597.70 2557409.60 60 °59'37.532 "N 151 97'11.503' 3.83 -89.10 -0.06 -3.83 7677.91 14751.00 89.67 356.46 10212.90 10088.90 6242.25 4623.12 271596.84 2557504.57 60 °59'38.467 "N 151 1711.558' 3.95 -90.69 0.06 -3.95 7755.72 14846.00 89.64 353.94 10213.47 10089.47 6336.91 4615.17 271590.79 2557599.37 60 °59'39.399 "N 151 97'11.719' 2.65 -72.18 -0.03 -2.65 7830.44 14941.00 89.73 353.66 10214.00 10090.00 6431.35 4604.91 271582.43 2557693.99 60 °59'40.329 "N 151 97'11.926' 0.31 -91.15 0.09 -0.29 7903.72 15036.00 89.67 350.64 10214.49 10090.49 6525.45 4591.94 271571.34 2557788.33 60 °59'41.256 "N 151 1712.188' 3.18 -93.20 -0.06 -3.18 7975.21 15134.00 89.43 346.32 10215.26 10091.26 6621.45 4572.37 271553.70 2557884.70 60 °59'42.201 "N 15197'12.584' 4.41 -84.20 -0.24 -4.41 8044.68 15228.00 89.61 344.55 10216.05 10092.05 6712.42 4548.73 271531.89 2557976.12 60 °59'43.097 "N 151 17'13.063' 1.89 86.30 0.19 -1.88 8107.70 15321.00 89.70 345.94 10216.61 10092.61 6802.35 4525.05 271510.02 2558066.50 60 °59'43.983 "N 15197'13.542' 1.50 95.00 0.10 1.49 8169.83 15351.00 89.61 346.97 10216.79 10092.79 6831.51 4518.02 271503.58 2558095.80 60 °59'44.270 "N 151 9713.684' 3.45 0.00 -0.30 3.43 8190.34 • 15381.00 89.61 346.97 10217.00 10093.00 6860.74 4511.26 271497.40 2558125.16 60 °59'44.558 "N 151°1713.821' 0.00 0.00 0.00 0.00 8211.04 Projected Data - NO SURVEY Page 3 of 3 S Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE November 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTA SCALE LOG DATE INTE13�fA� NQT €S LAS °PDSt 1 L 1 LpT PE LOGGED`; DL1 giiitUptigtVir; rm6 rB LINE' MULTIPLE PROPAGATION GRANITE PT RESISTIVITY GAMMA ST 18742 RAY AZIMUTHAL GAMMA LAS, CGM, XLS, 32RD2 IMAGE 2" 21- Sep -08 1 9070 -15386 PDF, DLIS AZIMUTHAL DENSITY GAMMA RAY BULK GRANITE PT DENSITY NEUTRON ST 18742 POROSITY ACOUSTIC LAS, CGM, XLS, 32RD2 CALIPER 2" 21- Sep -08 1 13020 -15388 PDF, DLIS MULTIPLE GRANITE PT PROPAGATION ST 18742 RESTIVITY GAMMA RAY LAS, CGM, XLS, 32RD2 MAGNEIC RESONANCE 2" 21- Sep -08 1 10120 -13100 PDF, DLIS MULTIPLE PROPAGATION RESISTIVITY GAMMA GRANITE PT RAY BULK DENSITY ST 18742 NEUTRON POROSITY LAS, CGM, XLS, 32RD2 ACOUSTIC CALIPER 2" 21- Sep -08 1 13030 -15388 PDF, DLIS MULTIPLE PROPAGATION RESISTIVITY GAMMA TBU K -12RD2 RAY 2" 7- Aug -08 10834 -11475 CGM, PDF, LAS .90/S-04/0 /V-/ aoS a Please acknowledge recei•t by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: • 3 RE: AN -32RD2 Update Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 11:44 AM To: 'Tyler, Steve L' Cc: Myers, Chris S; Nienhaus, Doug R; Flynn, Tim [ASRC]; Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Walsh, Chantal [ Petrotechnical] Subject: RE: AN -32RD2 (208 -042) Update Steve, et al, Thanks for the update. Interesting and unfortunate findings. Conducting diagnostic work is appropriate. Based on the discussion with yourself and Nigel, it does not appear that the well has any compromise at shallow depth. Please keep us informed. I will place a copy of this message in the well file. Call or message with any questions. Please include the permit number in the message header. Tom Maunder, PE AOGCC From: Tyler, Steve L [mailto:tylersl @chevron.com] Sent: Wednesday, October 15, 2008 11:34 AM To: Maunder, Thomas E (DOA) Cc: Myers, Chris S; Nienhaus, Doug R; Flynn, Tim [ASRC]; Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C; Walsh, Chantal [Petrotechnical] Subject: RE: AN -32RD2 Update Tom Update on our Anna 32RD well. • Over the past 24 hours the well is at a stabilized flow rate, to production, of 210 BFPD 100% water. FTP on LS = 75 psi; SITP on SS = 40 psi; tbg x csg = 65 psi • The results of the retrieved downhole gauges depict an event that occurred on 10/6/08 Monday noon. Where as the FBHP went from 1100 psi to 4250 psi over an 18 hour period. At the same time, the fluid level went from 8000' to 600'. • Our immediate forward plan is still as Tim Flynn has outlined below. • We will continue our rig demobe from Anna to carry on with our Steelhead gas program - M13 gravel pack recompletion; M32 completion pull; M18 grass roots; etc.; while assessing our remedial work options on Anna 32. From: Flynn, Tim [ASRC] Sent: Tuesday, October 14, 2008 11:23 AM To: Maunder, Thomas E (DOA) Cc: Myers, Chris S; Tyler, Steve L; Nienhaus, Doug R Subject: AN -32RD2 Update Tom 10/15/2008 RE: AN -32RD2 Update • • Page 2 of 2 We have been having some troubles with production of AN -32RD2 over the last 7 days. Over the last 7 days since the well has been perforated, we have been met with the inability to circulate our jet pump down the long string of the completion in order to produce the well. We are currently working on a procedure to bring the well to production. 1.) RU /NU well to take production from Long String to separator 2.) Attempt to flow out of balanced well to separator 3.) After well stabilizes (well killed), shut in well and monitor 4.) RU slickline to short string gauge tubing to 2 7/8 x 2 3/8" crossover 5.) Displace tubing strings to filtered inlet water 6.) RIH in short string w/ dummy pump to 2 7/8 "x 2 3/8" crossover 7.) If pump drifts tubing, RU /RIH with Jet Pump and flow well to production The above activities will allow us to understand the dynamics of the dual 2 7/8" tubing strings and give Insite as to what could be causing the pump to not drift past 7400' MD in the long string. If our assumptions are correct, the completion may need to be lifted off seat, and spaced out higher or have entire completion POOH and re- spaced to minimize buckling. We will continue with our weekly summaries of activities and complete a 407 for AN -32RD2 30 days after well is placed on production unless instructed differently. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907 - 317 -5504 cell 10/15/2008 GP St 18742 32RD2 7" cement rogram Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 28, 2008 8:19 AM To: 'Flynn, Tim [ASRC]' Cc: Nienhaus, Doug R; Bonnett, Nigel ( Nigel.Bonnett) Subject: RE: GP St 18742 32RD2 7" cement program Tim, et al, — 0 The regulatory requirement is to place cement 500' above the top of hydrocarbons. It appears that the revised plan will meet the requirement. Good luck with the operations. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Wednesday, August 27, 2008 4 :27 PM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett) Subject: GP St 18742 32RD2 7" cement program Tom We are currently preparing to log the 8.5" hole section of AN -32RD2 and then run a 4157' MD 7" liner to TD. (TD of well at 13076'MD) Our original cement program was to pump 541 cuft (466 sks) of cement up across the 7" liner hanger and set a ZXP packer. Due to excess coal being reported during drilling and clean out runs, a high risk of packing off could occur if cement is brought up across the liner top that could result in a failed set. (Liner top © 8920'MD). The new updated cement program (version 2) has been modified to bring TOC to 10,080'MD which is 500' above any Hydrocarbon bearing zones in the area. No other changes to the current liner running program have been changed. We will still run the ZXP packer for isolation. Attached is the updated cement program with calculated volumes. TOTAL: 493 + 27= 520 cuft (444 sks) w/ 30% excess Thank you «AN -32RD Liner Cement summary V2.doc» Tim Flynn Operations Drilling Engineer 8/28/2008 • . Chevron Granite Point Field Well AN -32RD2 °MO Cement Program 7" Liner (8 -1/2" Hole from 13076 to TOL @ 8920 "MD: Cement volume based on open hole volume plus 30 %, shoe joints and annulus. This will be a single stage cement job, pumping cement from 13076 "MD' up to 10080' md. Estimated volume is as follows: Mud push: = 30 bbls 13.5 lb /gal @ 80 degF Cement Slurry: Open hole: 3996' X 0.1268 cuft/ft (8 -1/2" x 7 ") X 1.3 = 493cuft = 421 sks (1.17 yield) 125' shoe joint X 0.2148 cuft/ft = 27 cult = 23 sks (1.17 yield) TOTAL: 493 + 27= 520 cuft (444 sks) Chase cement with OBM. Cement Properties Type Class G Density 15.8 lb /gal Yield 1.17 ft3 /sk Cementing Program An -24RD 1 8/28/2008 2 Week BOP Testing. • • Page 1 of 2 Maunder, Thomas E (DOA) From: Nienhaus, Doug R [nienhausd @chevron.com] Sent: Wednesday, July 23, 2008 3:06 PM To: Maunder, Thomas E (DOA) Subject: RE: 2_ Week BOP Testing. Thank you Tom Doug R Nienhaus Drilling Superintendent MidContinent / Alaska Chevron North America Exploration & Production 909 W. 9th Ave Anchorage,Alaska 99501 Office 907 - 263 -7840 Cell 907- 223 -6947 nienhausd@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, July 23, 2008 11:43 AM To: Nienhaus, Doug R Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2_ Week BOP Testing. Doug, Your proposal is acceptable. The "not to exceed" interval of 14 days is for drilling operations, i.e. after milling the window in your case. The test interval for workover /decomplete operations accomplished prior to milling a window is still 7 days. In cases where the window is milled prior to reaching 7 days from your last test, 14 days applies for the next test. Call or message with any questions. Tom Maunder, PE AOGCC From: Nienhaus, Doug R [maiito :nienhausd @chevron.com] Sent: Wednesday, July 23, 2008 11:06 AM To: Maunder, Thomas E (DOA) Subject: 2_ Week BOP Testing. Mr. Maunder 7/23/08 We have just Milled a window on a Anna Platform Developmental well AN- 32RD2. Our last BOP Test was on 7 -18 -08 and Witnessed by Mr. Lou Grimaldi. We have been completing weekly BOP Testing on well work Since March. Which were on work over Anna 37 and Anna Developmental well AN -24RD. The Annular packing unit was recently changed out at the end of project on Anna 37. The IBOP & Manual IBOP on the Top Drive have just been 7/24/2008 2 Week BOP Testing. • Page 2 of 2 changed out due to Failure on the Last Bop Test. I Have become quite comfortable with the Rig & its Surface equipment, and would like to proceed with 2 week Bop testing for Developmental well work with Rig 428 on Anna Platform. This would Make out next Bop testing date 8/01/08. Tom Please Advise on this Plan forward for Rig 428. Thanks Doug R Nienhaus Drilling Superintendent MidContinent / Alaska Chevron North America Exploration & Production 909 W. 9th Ave Anchorage,Alaska 99501 Office 907- 263 -7840 Cell 907 - 223 -6947 nienhausd@chevron.com 7/24/2008 GP 18742 32RD2 KOP Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, July 21, 2008 7:38 AM To: 'Flynn, Tim [ASRC]' Cc: Nienhaus, Doug R; Hurt, Floyd R. (FRHU); Lawrence, Steve C; Brandenburg, Tim C; Buster, Larry W Subject: RE: GP 18742 32RD2 KOP (208 -042) Tim, Thanks for following up with this information. It is not unusual for issues to develop with `old" casing. Moving the whipstock depth shallower does not present any regulatory issues. As discussed, moving the whipstock shallower does not affect the abandonment of the old productive interval. I will place a copy of this message and your attachment in the file. Please remember to include the PTD in your messages. From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Sunday, July 20, 2008 10:09 PM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Hurt, Floyd R. (FRHU); Lawrence, Steve C; Brandenburg, Tim C; Buster, Larry W Subject: GP 18742 32RD2 KOP Tom While tripping in hole with whipstock to set at 9436'MD, an obstruction was met approximately 9140'MD resulting in the whipstock assembly being pulled out of the hole. Based on the age and wear of the casing reported from the USIT, we will be moving our planned kickoff of 9436'MD up the hole to 9067'MD. Our directional targets will remain the same with 369' of hole added to the well. The attached procedure submitted with PTD: 208 -042 will be followed going forward. «AN -32RD2 drill and complete procedure summary.doc» Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907- 263 -7824 phone 907- 317 -5504 cell 7/21/2008 I DRILL AND COMPLETE PROCEDURE SUMMARY Pre -Rig Work: (P &A of AN -32RD) (Procedures are covered under P&A Sundry). Rig Operations: (Sidetrack An- 32RD2) 1. Nipple up BOP's test to 250/3500 psi. 2. RIH with whipstock system set whipstock with MWD and displace well to OBM. 3. Mill window as per recommended practices. 4. Fit test to 14 ppg EMW after 20' MD of new hole is cut. (MASP = 3404 psi,) 5. Directionally drill intermediate section w/ 8.5" Directional Assembly. Wiper trips will be performed as hole dictates. 6. RU Logging tools and RIH for clean out run to TD and POOH. 7. Run and cement the 7 ", 29# P -110 intermediate casing back in excess of 100' inside the 9- 5/8" casing. 8. Test casing to 2000 psi 9. Directionally drill production interval w/ 6" directional Assembly to TD. Wiper trips will be performed as hole dictates. 10. FIT test to 14 EMW after 20' MD of new hole is cut (MASP = 3437 psi) 11. Run 4.5 ", 19# L -80 production liner back in excess of 100' inside the 7" casing. 12. Set and test liner top packer circulate well clean reverse diesel throughout well. 13. Clean out 7" liner if required. 14. Trip in with 2 7/8" by 2 3/8" dual completion assembly with Oilwell Hydraulic Cavity Pump and 2000' of TCP guns. 15. Correlation to place guns on depth. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Circulate pump out, fish standing valve and drop bar to fire perf guns. 18. Trip standing valve on seat, circulate pump in place, flow well. 19. Rig down and move off. • \ [ E [ B] j �)) SARAH PAL/N, 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 Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, GP St 18742 32RD2 UNOCAL Permit No: 208 -042 Surface Location: 785' FNL, 601' FEL, SEC. 12, T1ON, R12W, SM Bottomhole Location: 93' FNL, 733' FEL, SEC. 31, T11N, R11W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to redrill the above referenced development well. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, aniel T. Seamount, Jr. Chair DATED this day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o end. Department of Environmental Conservation w/o end. RECEIVED STATE OF ALASKA MAR 2 0 2008 ALA . OIL AND GAS CONSERVATION COM "ION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: • lb. Current Well Class: Exploratory ❑ Development Oil , El 1 c. Specify if well is proposed for: Drill ❑ Redrill 0 Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM GP St 18742 32RD2 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 196247, Anchorage AK 99519 MD: 14800 TVD: 10217 Granite Point/Middle Kenai Oil Poc . 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Leg 2,SIotl, 785'FNL,601'FEL,Sec 12, T1ON,R12W,SM ' ADL 18742 • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1972' FNL, 2002' FEL, SEC 6, T1 ON, R11W, SM N/A 10- Anr -OR Total Depth: 9. Acres in Property: 14. Distance to Nearest 93' FNL, 733' FEL, SEC 31, T11 N, R11W, SM 5060 Propert y: '. y� '- 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Near st e Surface: x- 266850 • y- 2551356.4 • Zoi 4 (Height above GL): 124 AMSL feet W{hi ze o r y R42 -31 p ' 16. Deviated wells: Kickoff depth: 9414 feet • 17. Maximum Anticipated Pressures in psig (see 20 C 25.035) ..y Z.4•ao f Maximum Hole Angle: 90 degrees Downhole: 4457 psi • Surface: 3434 psi • 3•�T.�$ p 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) 8.5" 7" 29# P -110 Hyd 563 3600 9100 7651 12700 10110 560 sks G single stage 6" 4.5" 19# L -80 Hyd 511 2300 12600 10105 14800 10217 NA (Uncemented TCP) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 609.00 20" 547 sx cement to surface 609 609 Surface 4,020.00 13 3/8" 1850 sx cement 4020 3977 Intermediate 9,436.00 9 5/8" 500 sx 9436 7909 Production Well P&A below CIBP SET at 7909 Liner Perforation Depth MD (ft): P&A Perforation Depth TVD (ft): P&A 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat Q Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements E 21. Verbal Approval: Commission Representative: Date 3/19/2008 22. I hereby certify that the foregoing is true and correct. Contact Tim Flynn 907 263 7824 Printed Name Tim Brandenburg Title Drilling Manager Signature 2 Z............_411 263 -7657 Date 3/19/2008 l Commission Use Only Permit to Drill �7/�� API Number: Permit Approval See cover letter for other Number: �..�` --C �`"' 50- 733 zl✓Z76 °'e% Date: q • 167 • Q g requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, d gas ydrates, or gas contained in shales:[ Other: Samples req'd: Yes❑ o Mud log req'd: Yes Nod 3500 es(, Zd� �- S p`�si H measures: Yes[v]'No❑ Directional svy req'd: Yes[v No 4 )- 1 c i (. I 6 DATE: APPROVED BY THE COMMISSION AL , COMMISSIONER Form 10 -401 Revised 12/2005 i G i 0 ,. u "pliyt.e2.47.cza) • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax mail brandenburgt@chevron.com Email nbur mil bndnburgt @chevron.com March 19, 2008 RECEIVED Commissioner MAR 2 0 2008 Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Alaska Oil & Gas Cons. Commission Anchorage, Alaska 99501 Anchorage Re: Anna AN -32RD2 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill to Anna AN- 32RD2. Rig operations are expected to commence approximately April 10, 2008 depending on the progress of other ongoing projects. The toe of the well is planned to cross a section line. Please advice if a spacing exemption is required to perforate within 500' MD and across the section line. If you have any questions, please don't hesitate to contact myself or Tim Flynn at 907 - 263 -7824. Sincerely, Timothy C. Brandenburg Drilling Manager Attachments: Form 10-401 in Duplicate AN -32RD2 Cementing Calculations AN -32RD2 Well Plan Summary AN -32RD2 Casing Design AN -32RD2 Summary Drilling Procedure AN -32RD2 MASP Calculations AN -32RD2 Summary Mud Program AN -32RD2 FIT / LOT Procedure AN -32RD2 Planned Well Sketch AN -32RD2 Drilling Hazards Notice AN -32RD2 Planned Well Trajectory AN -32RD2 BOP Schematic AN -32RD2 Choke Manifold Schematic Cc: File Union Oil Company of California / A Chevron Company Page 1 of 1 RECEIVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION MAR 2 0 2008 PERMIT TO DRILL Aiaska Oil & Gas Cons. Commission 20 AAC 25.005 1a. Type of Work: lb. Current Well Class: Exploratory ❑ Development Oil 0 1c. Specify if well is proposed for:AnChorage Drill ❑ Redrill 0 Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM GP St 18742 32RD2 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 196247, Anchorage AK 99519 MD: 14800 TVD: 10217 Granite Point/Middle Kenai Oil Po( 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Leg 2,Slotl, 785'FNL,601'FEL,Sec 12, T1ON,R12W,SM ADL 18742 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1972' FNL, 2002' FEL, SEC 6, T10N, R11W, SM N/A 1O - Anr - Total Depth: 9. Acres in Property: 14. Distance to Nearest 93' FNL, 733' FEL, SEC 31, T11N, R11W, SM 5060 Property: 7005' ADL18761 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 266850 y- 2551356.4 Zoi 4 (Height above GL): 124 AMSL feet Within Pool: 1740' BR42 -31 16. Deviated wells: Kickoff depth: 9414 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 4457 psi Surface: 3434 psi 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) 8.5" 7" 29# P -110 Hyd 563 3600 9100 7651 12700 10110 560 sks G single stage 6" 4.5" 19# L -80 Hyd 511 2300 12600 10105 14800 10217 NA (Uncemented TCP) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 609.00 20" 547 sx cement to surface 609 609 Surface 4,020.00 13 3/8" 1850 sx cement 4020 3977 Intermediate 9,436.00 9 5/8" 500 sx 9436 7909 Production Well P&A below CIBP SET at 7909 Liner Perforation Depth MD (ft): PM Perforation Depth TVD (ft): PM 20. Attachments: Filing Fee ❑ BOP Sketch el Drilling Program IN Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 3/19/2008 22. I hereby certify that the foregoing is true and correct. Contact Tim Flynn 907 263 7824 Printed Name Tim Brandenbur• Title Drilling Manager - Signature Phone 263 -7657 Date 3/19/2008 Commission Use Only Permit to Drill API Numbe; Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:❑ Other: Samples req'd: Yes No❑ Mud log req'd: Yes No❑ H measures: Yes❑ No Directional svy req'd: Yes No APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate • Chevron Anna Platform Well AN -32RD2 Well Design Summary AN -32RD2 Well Design Summary Anna AN -32RD2 is a sidetrack out of AN -32RD, that will be drilled in a northeasterly direction from Slot 1 in Leg 2 on the Anna Platform. AN -32RD2 will penetrate multiple Tyonek reservoir units but the primary objective is to test the productivity of a C -7D lateral in coarse sandstones and sandy conglomerates. The well will be steered through 2000 ft of C -7D section, beginning within the C -7D reservoir at 12448' (10099' TVD). AN -32RD2 will be kicked off a whipstock at approximately 9414' MD, 7919' TVD. Plans call for drilling 5550' MD through the Tyonek section, reaching a maximum angle of 87 -90 deg inclination in the C -7D lateral section, with a proposed TD of 14800'MD, 10217' TVD. Basic Well Information Platform: Anna Well Name: AN -32RD2 Rig Name Chevron 428 Estimated Spud Date: 04/10/08 Field: Granite Point Productive Horizon: Tyonek 7D sands PTD: 14800' MD Total Depth: 14800'MD, 10217' TVD Slot: Slot 1, Leg #2 Surface Location: 785' FNL, 601' FEL, Sec 12, T1ON, R12W, SM X= 266849; Y= 2551356; NAD27, ASP, Zone 4 Planned BHL: X= 271968, Y= 2557398 NAD27, ASP, Zone 4 Original KB Elevation: 105' AMSL Current KB to BF: 59' Elevation An -32 to BF: 65' Current RKB (KB +EL): 124' 3/19/2008 Page 1 of 4 Chevron • Anna Platform Well AN -32RD2 °N. Well Design Summary Casing and Tubing Program Current Wellbore (CIBP set @ 9436 ` MD) Hole Tube Top Btm Size O.D. Weight Length MD /TVD MD /TVD (in) (in) (lbs / ft) Grade Conn (ft) (ft) (ft) Driven 20" 94# X -52 Weld 609 BF 609 17 1/2 13 3/8 68/61# K -55 BTC 4020 BF 4020/3977 12 1 /4 9 5/8 40/47# S -95 BTC 10164 BF 10164/8589 Proposed Sidetrack (KOP 9414' MD 7919' TVD) Hole Tube Top Btm Size O.D. Weight Length MD /TVD MD /TVD (in) (in) (lbs / ft) Grade Conn (ft) (ft) (ft) 8 1/2 7" 29 P -110 H563 3600 9100/7651 12700/10110 6" 4.5 19 L -80 H511 2350 12600/10105 14800/10217 Well Control Summary Hole Section Equipment Test Pressure (psi) 13 5/8" 5M Annular " 13 5/8" 5M Double Gate, 8 1 /2" 13 5/8" 5M Mud Cross, 13 5/8" 5M Single gate, 250/3500 3' /s" 5M Choke Manifold* 13 5/8" 5M Annular " 13 5/8" 5M Double Gate, 6 1/8" 13 5/8" 5M Mud Cross, 13 5/8" 5M Single gate, 250/3500 3 %" 5M Choke Manifold* * Schematics of the well control equipment are attached for reference 3/19/2008 Page 2 of 4 • Chevron Anna Platform Well AN -32RD2 Well Design Summary Anti - Collision Evaluation Summary There are no close approaches for AN- 32RD2. Well Control Hazards AN -32RD was drilled in 1987 and required 13.0 ppg mud to drill and set 7 5/8" casing past 10,400' MD 9000' TVD. The increase in pressure was assumed to be from "active" water flood in the area at the time. The well was produced for 10 years then converted to an injector. No abnormal pressure was reported when ✓ the completion was pulled from An -32RD. The assumption is that time has dissipated the water flood pressure and the risk of an abnormal water pressured zone is low. Formation Integrity Testing Test Point, 20' Pr Depth d Test Type Projected Test Below... (TVD) (EMW ppg) 9 5/8" KOP 7935' FIT 14.0 Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) 8 1 /2" Int. 9436 -12600 OBM 9.0 -9.5 55 -80 18 -29 9 -18 <_6 6" Prod 12600 -14800 OBM 8.7 -9.4 55 -80 18 -29 9 -18 <_6 . Cementing Summary See Attachments 3/19/2008 Page 3 of 4 • • Chevron Anna Platform Well AN -32RD2 %. Well Design Summary Formation Markers Target Top TVDSS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V4 (PSI) (RKB) C -2 -8833 23 <2000 4.35 C -3 -8911 122 <2000 4.31 C -4 -9041 44 <2000 4.25 C -5A -9174 78 <2000 4.19 C -5B -9270 122 <2000 4.14 C -7A -9728 50 <2000 3.95 C -7C -9845 114 <2000 3.90 C7D 9913 2200 <2000 3.85 3/19/2008 Page 4 of 4 • DRILL AND COMPLETE PROCEDURE SUMMARY Pre -Rig Work: (P &A of AN -32RD) (Procedures are covered under P &A Sundry). Q� 6 Rig Operations: (Sidetrack An- 32RD2) 1. Nipple up BOP's test to 250/3500 psi. 2. RIH with whipstock system set whipstock with MWD and displace well to OBM. 3. Mill window as per recommended practices. 4. Fit test to 14 ppg EMW after 20' MD of new hole is cut. (MASP = 3404 psi,) 5. Directionally drill intermediate section w/ 8.5" Directional Assembly. Wiper trips will be performed as hole dictates. 6. RU Logging tools and RIH for clean out run to TD and POOH. 7. Run and cement the 7 ", 29# P -110 intermediate casing back in excess of 100' inside the 9- 5/8" casing. 8. Test casing to 2000 psi 9. Directionally drill production interval w/ 6" directional Assembly to TD. Wiper trips will be performed as hole dictates. 10. FIT test to 14 EMW after 20' MD of new hole is cut (MASP = 3437 psi) 11. Run 4.5 ", 19# L -80 production liner back in excess of 100' inside the 7" casing. 12. Set and test liner top packer circulate well clean reverse diesel throughout well. 13. Clean out 7" liner if required. 14. Trip in with 2 7/8" by 2 3/8" dual completion assembly with Oilwell Hydraulic Cavity Pump and 2000' of TCP guns. 15. Correlation to place guns on depth. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Circulate pump out, fish standing valve and drop bar to fire pert guns. 18. Trip standing valve on seat, circulate pump in place, flow well. 19. Rig down and move off. • Halliburton BAROID Chevron Mud Program BAPOIO Chevron AN-32 RD2 Anna Platform Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Higbie Reviewed by Dave Soquet Customer Approval Tim Flynn Version No: Date: 1.0 March 18, 2008 AN -32 RD2 v1.0 1 3/18/08 • • Halliburton BAROID Chevron Mud Program AN -32 RD2 Introduction: The following mud program was prepared for a sidetrack of the AN -32 RD2 well on the Anna platform. The well has already been killed and plugged. The well will kick off out of the 9 -5/8" casing at 9,100' MD (7,651' TVD) and 8 -1/2" hole will be drilled to 12,448' MD (10,099' TVD). A 7" liner will then be run and cemented. A 5" by 3.5" tapered drill string will be made up to drill the 6" hole section. This interval will be drilled to TD at 14,650' (10,206' TVD). A 4.5" liner will be run and the well completed with a dual completion. TCP guns will then be used to perforate the un- cemented liner. Prior to milling the window in the 9 -5/8" casing, the well will be displaced to a 9.0 ppg INVERMUL oil -based system. Recycled OBM from AN -24 will be reconditioned for use on this well. Primary Drilling Objectives: • Zero fluid related HSE incidents • Maintain well control at all times • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation /control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Minimize drilling wastes Critical Fluid Issues: • Maintain well control • Eliminating /controlling losses. • Maintaining a low ECD in the production zone to reduce risk of lost returns. • Maintaining a stable wellbore through coal seams. Well Specifics: Casing Program MD TVD Footage 9 -5/8" casing (KOP @ 9100' MD) 9100' 7651' 9100' 8 -1/2" hole ( 7" liner) 12448' 10,099' 2349' 6" hole (4.5" liner) 14650' 10206' 2202' AN -32 RD2 v1.0 2 3/18/08 • Halliburton BAROID Chevron Mud Program Intermediate Interval: (8 -1/2" hole, 7" Liner) to 12,448' MD Mud Type: Invermul System Mud Properties Density Viscosity PV YP ES H FH P WPS 01W 9100' — 9.0 55 - 80 18 -29 9 — 18* 1000- <6 270 to 80/20 12,448 1100 290K • A 20 -22 YP is desired for milling ops. • Additional mud weight may be required for effective coal or shale stabilization. System Formulation Product Concentration Base Oil 0.696 bbl EZ MUL NT 4 ppb INVERMUL NT 4 ppb GELTONE V 4 ppb Lime 5 ppb DURATONE 4 ppb RM 63 1 ppb Water 0.178 bbl CaCl2 24.6 ppb AK -70 4 ppb BAROID toa9.Oppg Mud Type: INVERMUL System. 1. Mud weight: Begin with an initial mud weight of 9.0 ppg. If abnormal pressures exist or the well bore exhibits instability, increase the mud weight accordingly. Maximize solids control equipment. 2. Rheology: Maintain a YP between 9 and 18. Pump high viscosity or Barolift sweeps throughout the interval as needed. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation. 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Prior to milling the window in the 9 -5/8" casing, the well will be displaced to a 9.0 ppg INVERMUL oil -based system. Approximately 900 -1000 bbl of oil mud will be required to displace the well and fill the pits. Prepare the pit system for the INVERMUL as follows: • Clean pits, solids control equipment, all lines and pumps. • Flush all lines with a small volume of oil and discard. • Disconnect all water lines to the pit area and rig floor. • Check all steam fittings in pit room for leaks and repair as needed. Prior to milling, displace the well to the INVERMUL system designated for this interval of the well. Pump a 25 bbl spacer ahead of the oil mud as follows: Spacer Formulation: • 20 barrels of the OBM treated with GELTONE to a YP > 30 (app. 4 -6 sx). Weight this pill to 2 ppg over the OBM weight. • Follow with INVERMUL mud system. Displacement procedure: • Monitor pump strokes to obtain correct displacement. AN -32 RD2 v1.0 3 3/18/08 • Halliburton BAROID Chevron Mud Program • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one joint every 15 minutes • Rotate the pipe as rapidly as allowed during the actual displacement. • Do not shut down during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system. An ES of 300 -500 should be sufficient to indicate when displacement is complete. A retort should also be run at this time to confirm fluid quality. • Clean possum belly and any troughs which were used. Maintenance: 1. Additions of Geltone V and RM -63 will maintain /modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECD and surge /swab pressures. 2. OMC 2 will be available to condition (thin) the mud as required; however, caution should be used when using oil mud thinners to avoid over - thinning the system. 3. Drill this interval with a tight DURATONE HT / AK -70 filtration mechanism (< 6 cc /30 min @ 200° F). Barablok will also be available to improve the filtration control mechanism. 4. For formation bridging /LCM, graded calcium carbonate (Baracarb(s)), cellulose fiber material (Barofibre) and SteelSeal are available. 5. The electrical stability of the mud should be run in the 1000 -1100 volt range with INVERMUL NT and EZ MUL NT as the primary and secondary emulsifiers. DRILTREAT will be available as an effective wetting agent, if needed. 6. Maintain the water phase salinity between 270,000 — 290,000 mg /I range with sack calcium chloride. This level of salinity will provide an effective mechanism for good wellbore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 300 400 500 60 rpm 57 76 94 80 rpm 86 112 141 100 rpm 109 142 179 Baroid recommends a flowrate in the 400 -450 gpm range to maximize solids - control efficiency while still maintaining good hole cleaning capabilities at elevated penetration rates. Pump rates above 550 gpm cause a sharp increase in ECD and should be avoided. RPM's of 100 are strongly recommended. ROP rates above these levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • wiper trips • back reaming • extended periods of circulation (with maximum pipe rpm, targeting > 80 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection AN -32 RD2 v1.0 4 3/18/08 Halliburton BAROID Chevron Mud Program Production Interval: (6" hole, 4.5" Liner) to 14,650' MD Mud Type: Invermul System Mud Properties Density Viscosity PV YP ES H FH P WPS 01W 12,448 — 8.7 - 9.0 55 - 80 18 -29 9 —18 1000- <6 270 to 80/20 14,650 1100 290K • Additional mud weight may be required for effective coal or shale stabilization. System Formulation Product Concentration Base Oil 0.696 bbl EZMULNT 4ppb INVERMUL NT 4 ppb GELTONE V 4 ppb Lime 5 ppb DURATONE 4 ppb RM 63 1 ppb Water 0.178 bbl CaCl2 24.6 ppb AK -70 4 ppb BAROID to a 9.0 ppg Mud Type: INVERMUL System. 1. Mud weight: Begin with an initial mud weight of 8.7 ppg. If abnormal pressures exist or the well bore exhibits instability, increase the mud weight accordingly. Maximize solids control equipment. 2. Rheology: Maintain a YP between 9 and 18. Pump high viscosity or Barolift sweeps throughout the interval as needed. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this horizontal wellbore. Maximize pipe rotation. 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: 1. Additions of Geltone V and RM -63 will maintain /modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECD and surge /swab pressures. 2. OMC 2 will be available to condition (thin) the mud as required; however, caution should be used when using oil mud thinners to avoid over - thinning the system. 3. Drill this interval with a tight DURATONE HT / AK -70 filtration mechanism (< 6 cc /30 min @ 200° F). Barablok will also be available to improve the filtration control mechanism. 4. For formation bridging /LCM, graded calcium carbonate (Baracarb(s)), cellulose fiber material (Barofibre) and SteelSeal are available. 5. The electrical stability of the mud should be run in the 1000 -1100 volt range with INVERMUL NT and EZ MUL NT as the primary and secondary emulsifiers. DRILTREAT will be available as an effective wetting agent, if needed. 6. Maintain the water phase salinity between 270,000 — 290,000 mg /I range with sack calcium chloride. This level of salinity will provide an effective mechanism for good wellbore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. AN -32 RD2 v1.0 5 3/18/08 Halliburton BAROID Chevron Mud Program Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 200 225 250 40 rpm 81 87 94 60 rpm 85 91 105 Baroid recommends a flowrate in the 225 gpm range to maximize solids - control efficiency while still maintaining good hole cleaning capabilities at elevated penetration rates. Pump rates above 225 gpm cause a 0.1 ppg increase per 25 gpm in ECD and should be avoided. ROP rates above these levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • wiper trips • back reaming • extended periods of circulation (with maximum pipe rpm, targeting > 80 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection Sweeps Two types of hole cleaning sweeps can be used: • Increase the sweep density with barite to 2 ppg over system density. • To reduce the density /viscosity build up in the system, sweeps can be built by adding 0.25 ppb BAROLIFT. The fibrous BAROLIFT will be removed at the shakers. Check with MWD personnel to ensure no plugging of tools will occur. Note: Properly size all sweeps for 300 - 400 ft of annular coverage Supplement the hole cleaning of the drilling fluid as dictated by hole cleaning indications. Monitor all sweeps pumped and report on their effectiveness. Maximize drill pipe rotation at high rates on a frequent basis (particularly during connections) to assist in disturbing any potential cuttings accumulations down -hole. The objective of the sweep is to change the flow characteristics / carrying capacity that are inherent with the mud system. Select sweep type accordingly. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control the running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL /AK 70 pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software). System density increases can also be employed in increments of 0.5 ppg. Solids Control Equipment AN -32 RD2 v1.0 6 3/18/08 Chevron • ! FGit 1 II II 0 Ch BAKER Location: Cook Inlet, Alaska Offshore vron Slot: slot #2 -1 NI�i�NE Field: Granite Point Field Well: AN- 32RD #2 Facility: ANNA Platform Wellbore: AN -32 RD #2 INTEQ Plot reference wellpath is AN- 32RD #2 Version 6 True vertical depths are referenced to Rig 428 (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Rig 428 (RKB) North Reference: True north Rig 428 (RKB) to mean sea level: 124 feet Scale: True distance mean sea level to Mud line (Facility: ANNA Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 3/18/2008 Well Profile Data Design Comment MD (ft) Inc ( °) Az ( °) TVD (ft) Local N (ft) Local E (ft) DLS ( ° /100ft) VS (ft) KOP 9414.00 29.350 37.626 7919.46 3043.41 2345.03 1.42 3840.75 End of 3D Arc 9434.00 31.227 41.154 7936.73 3051.20 2351.44 12.93 3850.83 End of 3D Arc 9861.60 23.599 75.102 8318.31 3157.45 2508.26 4.00 4032.21 End of Tangent 10750.92 23.599 75.102 9133.26 3248.99 2852.32 0.00 4320.31 End of 3D Arc 12508.57 87.226 32.147 10106.39 4205.84 3778.64 4.00 5647.12 End of Tangent 14557.37 87.226 32.147 10205.53 5938.50 4867.52 0.00 7678.39 End of Tangent 14800.00 87.226 32.147 10217.27 6143.69 4996.47 0.00 7918.94 Scale 11.150011 Fasting (I l) 1500 2250 3000 3750 4500 5250 6000 6750 et M ` An32Rd2 C -7D Toe Target 26- Feb - 2008 6000 m- 3 7 co a ..` 6000' if 4500 --- ' 7in Casing Intermediate An32Rd2 C -7D Landing Target 15- Jan -2008 i ' 1 3750 �a° J y� ' 7500 � 2 )) P 9.625in Casing Surface 1 300 0 4 L D_ N 0 Ts 9000 o 6 d`a te a •vo 2 1\ -G H 2o AN -32 RD #2 l 10500 t e t 15 -3a11 Ftd2C 1 C. 2.6..e b2p08 P� P 12000 3000 4500 6000 7500 9000 10500 Vertical Section (ft) Scala 1 inch• 1500" Azimuth 39.12° with reference 0.00 N, 0.00 E • • Chev_ "" Planned Wellpath Report �Gi� p Illaill AN- 32RD #2 Version 6 Y YGH Page 1 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION _ Operator Chevron !Slot ?slot #2 -1 Area Cook Inlet, Alaska (Offshore) =Well '^ AN- 32RD#2 Field Granite Point Field Wellbore ' !AN -32 RD #2 Facility ANNA Platform Sidetrack from LAN-32 PB at 9414.00 MD REPORT SETUP INFORMATION Projection System 1NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System 1 WWellArchitect® 2.0 North Reference !True iUser ,Ulricard Scale 0.999962 Report Generated 13/18/2008 at 4:51:33 PM Convergence at slot11.15° West !Database /Source file IWAAnchorage /AN -32 RD #2.xml WELLPATH LOCATION Local coordinates Grid coordinates 1 Geographic coordinates North[ft] 1 East[ft] Easting[USft] Northing[USft] Latitude Longitude Slot Location 1 - 785.01 601.01 266849.80 2551356.43 60 0 58'37.008 "N 151 °18'45.292 "W Facility Reference Pt ! 267466.35 2552129.24 60 °58'44.738 "N 151 °18'33.113 "W Field Reference Pt j ! 267571.89 2557407.98 60°59'36.731"N 151°18'33.112"W WELLPATH DATUM Calculation method Minimum curvature Rig 428 (RKB) to Facility Vertical Datum 1124.00ft — Horizontal Reference Pt Slot � 'Rig 428 (RKB) to mean sea level 124.00ft ' !Vertical Reference Pt Rig 428 (RKB) _ Facility Vertical Datum to Mud Line (Facility) 0.00ft F ____MD Ref erence Pt Rig 428 (RKB) j Section Origin N 0.00, E 0.00 ft d Vertical Reference mean sea level ; Section Azimuth 139.12° Chevron • fb Planned Well path Report Re ort ri BAKER AN- 32RD #2 Version 6 HUGHES Page 2 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD #2 Field Granite Point Field Wellbore AN -32 RD #2 ANNA Platform Sidetrack from AN -32 PB at 9414.00 MD WELLPATH DATA (155 stations) j' = interpolated /extrapolated station MD Inclination Azimuth ' TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] [ °] [°] [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ ° /100ft] [ft] I 0.001' 0.000 119.110 0.00 - 124.00 0.00 0.00 0.00 266849780 2551356.43 0.00 19.00 0.000 119.110 19.00 - 105.00 0.00 ; 0.00 0.00 266849.80 2551356.43 0.00 119.00 0.530 119.110 119.00 - 5.00 0.08 T - 0.23 0.40 266850.20 2551356.20 0.53 219.00 0.500 127.900 218.99 94.99 0.17 -0.72 1.15 266850.94 2551355.69 0.08 319.00 0.530 157.110 318.99 194.99 -0.04 -1.41 1.68 26685145 . 51 r98 419.00 0.520 140.310 418.99 i 294.99 -0.34 -2.19 2.15 266851.90 2551354.20 0.15 519.00 0.530 158.610 518.98 � 394.98 -0.66 -2.971 2.60 266852.341 2551353.41 0.17 619.00 0.400 151.400 618.98 494.98 -1.02 -3.70 2.94 266852.67 2551352.671 0.14 719.00 0.620 184.390 718.98 594.98 - 1.60 - 4.55 3.07 266852.77 2551351.82 " 0.36 245.800 818.96 694.96 -3.21 -5.63 1.83_' -r' l . 4 ,r;.3/ 919.00 2.650 251.500 918.89 794.89 - 6.33 - 6.90 - 1.56 266848.11 2551349.57 1.17 1019.00 ;� _ 3.200 255.800 1018.76 894.76 - 10.52 -8.31 -6.45 266843.18 2551348.25 0.59 1119.00 3.270 256.300 1118.60 r 994.60 - 15.03 -9.67 -11.93 266837.68 2551347.00 0.08 1219.00 3.570 259.190 1218.42 1094.42 - 19.69 - 10.93 -17.76 266831.83 2551345.85 0.35 -24.59 - 12.211 , -23.95 24 1419.00 3.9 .� 0 261.500 1418.00 1294.00 -29.65 -13.42 T -30.49 266819.05 2551343 63 343.63 0.38 1519.00 4.270 263.800 1517.75 1393.75 - 34.84 -14.33 - 37.60' 266811.92 2551342.86 0.36 1619.00 4.600 267.390 1617.45 1493.45 -40.15 -14.91 - 45.30 266804.21 2551342.43 0.43 1719.00 4.800 266.500 1717.11 1593.11 - 45.66 -15.35 • -53.49 266796.02 2551342.15 0.21 268.000 1816.75 1692.75 -51.32 - 1536 - 61.96 266787 54 ;. 2551 ` t= 1919.00 5.720 277.110 1916.32 1792.32 - 56.78 - 15.29 - 71.20 266778.31 1 2551342.57 1.15 2019.00 7.260 299.0001 2015. 1891.69 -60.54 - 11.61 - 81.67 266767.92 2551346.46 2.89 2119.00 6.300 313.900 2115.00 1991.00 -61.19 - 4.74 - 9115 266758.58 2551353.52 2.00 2219.00 6.520 335.200 2214.39 2090.39 - 58.24 4.22 - 97.491 266752.42 2551362.60 2.37 ? 2319.00 1 ' ' '"'"7.830 352.610 2313.61,„ l r 2189.61 - 51.05 16.13 - 10 1 M 66749.40 2551374.5:' 7 2419.00: 8.000 15.690 2412.69 ` 2288.69 - 39.97 29.59 - 99.74 1 266750.68 2551388.01 3.16 2519.00 8.88 22.890 2511.60 2387.60 - 26.18 43.40 - 94.85 266755.84 2551401.72 1.37 2619.00 9.130' 2610.37 2486.37 -11.15 57.82 -88.78 266762.20 2551416.02 0.25 2719.00 9.130 23.890 2709.10 2585.10 4.12 72.39 -82.49 ' 266768.78 , 2551430.46 0.17 E 2807.81 2683.81 19.52 87.20 -76.29 266775.28 ; 2551445.14 ,r Cher.•on EMI Planned Wellpath Report BAKER ISO AN- 32RD #2 Version 6 HUGHES Page 3 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD#2 Field Granite Point Field Wellbore AN -32 RD #2 Facility ANNA Platform Sidetrack from AN -32 PB at 9414.00 MD WET I PATH DATA (155 stations) MD Inclination Azimuth TVD TVD from Vert Sect North r East Grid East Grid North DLS [ft] [ [°] [ft] Fid Vert Ref [ft] [ft] i [ft] I [sry ft] [sry ft] [MOOR] [ft ' 2919.00 9.450 19.300! 2906.47 2782.47 34.99 102 - 70 . 58 266781.29 2551460.32 0.39 3019.00 9.680 17.890 3005.07 2881.07 50.55 118.25 - 65.29 266786.901 2551475.96 0.33 3119.00 9.780 16.100 - 3103.64 2979.64 66.20 134.41 -60.35 266792.16 2551492.02 0.32 3219.0_0 9.280 28.390 3202.27 3078.27 81.94 149.66 -54.16 266798.65 2551507.14 ' 2.09 3319.00 _ 10.750 33.190 3300.74 3176.74 99.14 164.56 - 45.22 266807.89 2551521.86 ~s' .,; 3419.00 12.020 J2191_ 3398.77 3274.77 118.77 181.11 - 34.46 266818 98 2551538.19 1.27 3519.00 12.970 31.600 3496.40 3372.40 140.25 199.41 - 22.93 266830 87 2551556.26 0.99 3619.00 14.350 29.500 3593.57 3469.57 163.59 219.76 - 10.941 266843.26 2551576.36 1.47 3719.00 15.130 29.300 3690.28 3566.28 188.67 241.93 ' 1.55 266856.19 2551598.27 0.78 3819.00 16.650 26.300 378646 3662.46 215.50 266.15 14.28 266869.41 ' 2551622.22 , 1.73 3919.00 17.600 24.690 3882.02 3758.02 244.11 292.73 26.95 266882.60 2551648.55 1.06 4019.00 ` 16.870 20.300 3977.54 3853.54 272.49 320.08 38.30 266894.50 2551675.67 1.49 4119.00 18.670 24.1001 4072.77 3948.77 301.68 348.30 49.87 266906.63 2551703.65 ' 2.1 4219.00 21.000 32.600 4166.85 4042.85 ! 334.96 378.02 66.06 266923.42 2551733.03 3.70 4319.00 _ 70 4 4 et,x,,,, 4259.17 4135.17 373.24 409.32 _8824. , ,. 66946.22 255174 89 3.72 4419.00 27.050 36.690 4349.341 4225.34 416.43 443.77 114.35 266973.01 2551797.80 2.91 4519.00 29.570 36.300 4437.371 437.37 4313.37 463.80 481.89 142.55 267001.96 2551835.35 2.53 r 4619.00 32.720 35.100 4522.95 4398.95 515.42 523.90 172.70 267032.95 2551876.75 3.21 4719.00 35.970 34.3901 4605.50I 4481.50 571.66 570.26 204.84 267066.01 2551922.45 3.27 4819.00 ., z 39 030 _,_ _3.3„600 4684.83 4560.83 632.29 620.73 238 86 2671 2551972.23 3.10 4919.00 40.870 33.300 4761.49 4637.49 696.18 ' 674.31 274.25 267137.49 ' 2552025.08 1.85 5019.00 40.880, 36.300 4837.11 4713.11 761.42 728.03 311.59 267175.90 • 2552078.05 1.96 5119.00 39.550 43.100 4913.51 4789.51 825.90 777.68 352.74 267218.03 2552126.86 4.59 5219.00 40.630 44.100 4990.01 4866.01 890.10 824.31 397.15 267263.37 2552172.58 1.26 „ . 3 .42.5Q0 44.300 c i 4 a 4940.83 956.18 871.87 443.40 267310.56 2552219.21 1.87 5419.00 43.770 44.390' 5137.80 5013.80 1024.27 920.76 491.19 267359.32 2552267.13, 1.27 5519.00 45.020 43.890 5209.25 5085.25 I 1093.96 970.97 539.91 267409.03 2552316.35 1.30 5619.00 45.270 43.300 5279.79 5155.79 1164.63 1022.31 588.79 267458.93 2552366.70 0.49 5719.00 45.770 43.300' 5349.85 5225.85 1235.79 1074.24 637.73 267508.89 ' 2552417.63 0.50 5819.00 46.630 43.390 5419.06 5295.06 1307.77 1126.73 687.27 267559.47 2552469,12 • 0.86 • • Chevron .- Wellpath Report hr Planned Well p AN- 32RD #2 Version 6 BAKER Page 4 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot !slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD #2 Field Granite Point Field Wellbore 'AN -32 RD#2 Facility ANNA Platform Sidetrack from AN -32 PB at 9414.00 MD 1 WELLPATH DATA (155 stations) MD r Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] 1 [ °] [0] [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ °/1008] _. _�._. ; [ft] 5919.00 ' 46.770 43.390E 5487.65 j 5363.65 ' 1380.35 1179.61 737.26 267610.51 2552520.99 0.14 6019.00 48.250 43.190, 5555.19 5431.19 7 1453.89 1233.29 787.82 267662.14 2552573.64 1.49 6119.00 49.250; 43.690 5621.2. 5497.12 1528.86 1287.87 839.52 267714.91 2552627.18 1.07 6219.00 50.300 43.800 5685.70 5561.70 1604.96 1343.03 892.31 267768.80 2552681.26 1.05 ''' 1x11 51.800 43.500 5748.57 5624.57 1682.48 1399.30 945.99 267823.59 2552736.45 ' 6419.00 r 53.000 44.100 5809.58 5685.58 1761.45 1456.48 1000.83 267879.56 j 2552792.52 1.29 6519.00 F77 54.0701 44.300 5869.01 5745.01 1841.55 1514.14 1056.89 267936.77 r 2552849.03 1.08 6619.00 56.080 43.890 5926.26 5802.26 1923.23 1573.02 1113.94 267994.98i 2552906.76 2.04 6719.00 56.280 43.6001 5981.92 5857.92 2006.04 1633.04 1171.39 268053.62' 2552965.61 0.31 ' : Vi ` l TMs# 7.47 5913.47 : + ° t,° 1693.50 1228.46 268111.89 2553024.92 0.42 6919.00 55.080 42.000 6093.90 5969.90 2171.36 1754.32 1284.29 268168.93 2553084.60 1.46 7019.00 54.620 41.3901 6151.47 i 6027.471 2253.05 1815.37 1338.68 268224.52 2553144.55. 0:68 7119.00 ` 53.520 40.800 6210.15 6086.15 2333.97 1876.39 1391.91 268278.96 i 2553204.49 1.20 7219.00 52.450 39.890' 6270.35 ' 6146.35 2413.80 1937.24 1443.60 268331.86 2553264.29 1.29 ,.,, 7319 = .a. ''r' 1, ,O331.71_ 6207.71 . 2492,75.,.. 1998.04 149 ... 268383.44 ,.. 324.07 0.7 7419.00 49.800 39.500 6394.88 6270.88 2570.27 2057.91 1543.23 268433.88 2553382.93 2.05 7519.00 48.330 39.800 6460.40 6336.40 2645.81 2116.07 1591.43 268483.23 i 2553440.12 1.49 7619.00 46.250 39.690 6528.22 6404.22 ■ 2719.28 2172.57 1638.41 i 268531.33 2553495.66 2.08 7719.00 47.330 39.600 6596.69 6472.691 2792.161 2228.69 1684.91 268578.95 2553550.83 1.08 E 6541.08 2865.12 2284.'1 - .(f41 ' I_ I ___ 7919.00 44.820 39.500 6735.05 6611.05 2936.55 2339.99 1776.90 268673.15 2553660.26 1.55 8019.00 44.420 39.890 6806.23 6682.23 3006.79 2394.03 1821.76 268719.08 2553713.40 0.48 8119.00 43.550 39.000 6878.18 6754.18 3076.23 2447.66 1865.89 268764.27 2553766.12 1.07 8219.00 42.310 39.890 6951.40 6827.40 3144.34 2500.26 1909.15 268808.58 2553817.84 1.38 _ ..__ _ ..._ ,___�____��._ _ .�._ m_. _�__ ___ . .;3210.93 2551.35 1951 ? 6902.00 8419.00 40.310 38.500 7101.75 6977.75 3276.21 2601.94 1993.12 268894.56 2553917.82 1.27 8519.00 38.981 38.390 7178.75 7054.75 3340.00 2651.91 2032.79 268935.22 ` 2553966.98 1.33 8619.00 37.671 38.690 7257.20 7133.20 3402.01 2700.41 2071.43 268974.82 2554014.70 1.32 8719.00 36.020 38.500 7337.22 ' 7213.22 ' 3461.97 ! 2747.28 2108.83 269013.16 2554060.81 1.65 a a r - .a,' k „' e1 !. �, r• X51 ' 1 R. i Chevron Nil ill Planned Well path p ath Re ort BAKER �' AN- 32RD #2 Version 6 HUGHES Page 5 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD #2 'Field Granite Point Field Wellbore A N -32 RD #2 Facility ANNA Platform Sidetrack from j AN -32 PB at 9414.00 MD WELLPATH DATA (155 stations) j - = interpolated /extrapolated station N D Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] [ 0 1 [°] [ft] { Fld Vert Ref [ft] [ft] [ft] [ sry ft] [sry f t] [MOOR] _ I [ft] I 8919.00 34.920 38.300` 7500.63' 7376.63 r 3577.28 2837.52 Im 2180.62 269086.73 2554149.59 0.17 9019.00 33.800 39.100 7583.18 7459.18 3633.71 2881.57 ` 2215.90 = 269122.89 2554192.92 1.21 9119.00 32.570 38.890 7666.86 r 7542.86 3688.45 2924.11 2250.34 269158.17 2554234.76 1.24 9219.00 31.580 38.890 7751.60 7627.60 3741.55 2965.44 2283.68 269192.33 2554275.41 ' 0.99 '' f #, 38.100 7837.20 7713.20 3793.24 3005.90 2315.86 269225.32 „ 2554315.22 0.99 9414.00 29.350 37.626 7919.46 7795.46 3840.75 3043.41 2345.03 269255.23 2554352.14 1.42 9434.00 31.227 41.154 7936.73 1 7812.73 3850.83 3051.20 2351.44 269261 79 ' 2554359.79 12.93 9514.001 29.239 46.138 8005.85 ( 7881.85 3890.96 3080.36 2379.18 269290 11 2554388.39 4.00 9614:001 27.052 53.246 8094.05 7970.05 3937.27 3110.90 2415.02 269326.55 2554418.21 4.00 ' ' 77 ;7 .276 61.384 8183.83 8059.83 3979.10 3134.74 2452.00 269364.00 2554441.30 4.00 9814.00' 24.003 70.491 8274.75 8150.75 4016.24 3151.77 2489.93 269402.26 2554457.57 4.00 9861.60 23.5991 75.102 8318.31 8194.31 4032.21 3157.45 2508.26 269420.70 2554462.88 4,00 9914.001 23.599 75.102 8366.33 8242.33 4049.19 3162.85 2528.53 269441.08 2554467.87 0.00 10014.001: 23.599' 75.102 8457.96 ' 8333.96 ? 4081.58 3173.14 2567. 269479.96 2554477.38 0.00 1 . 10114 00 ` ti 23.599 75.102 , X549.6 .�; �;� $x}2$,60 4113.98 3183.43 2 I ° � .6 0.00 10214.001 23.599 75.102 8641.24 � I 8517.24 4146.37 3193.72 2644.60 269557.73 2554496.41 0.00 10314.00' 23.599 75.102 8732.87 8608.87 4178.77 3204.02 2683.28 269596.62 - 2554505.93 0.00 10414.00'1 23.599 75.102 8824.51 8700.51 4211.16 3214.31 2721.97 269635.50 2554515.44 0.00 10514.001. 23.599 75.102 8916.15 8792.15 4243.56 3224.60 2760.66 269674.39 2554524.96 0.00 14. - 77 10614.001 23.599 75.102 9007.78 77- _ 8883.78 4275.95 3234.89 2799 M 264 c 10714.001 23.599, 75.102 9099.42 8975.42 4308.35 3245.19 2838.04 j 269752.16 255 0.00 10750.92 23.599 75.102 9133.26 9009.26 4320.31 3248.99 2852.32 269766.51 2554547 50 ; 0.00 10814.001 25.404 70.848 9190.66 9066.66 4342.04 3256.67 2877.31 269791.65 2554554.68 4.00 10914.0011 28.476 65.184 9279.81 9155.81 4381.72 3273.721 2919.23 , 269833.90 2554570.89 4.00 } i 31.740 60.567 9366.32 W ' [ 42 7 E32 4427.63 3296. 7-77 [ z ' 11114.001 35.142 56.745 9449.76 9325.76 4479.57 3325.38 3010.79 269926 . 47 1 2554620.70 4.00 11214.001 38.646 53.525 9529.73 f 9405.73 453 3059.98 269976.34 2554654.07 4.00 11314.00'[ 42.224 50.768 9605.84 9481.84 4600.44 3399.57 3111.14 270028.29 . 2554692.87 4.00 11414.00t' 45.861 48.369 9677.71 9553.71 4668.80 3444.68 3164.01 270082.05 ; 2554736.90' 4.00 1 ? 49.5 46.250 9745.00 9621.00 4741.99 3494.85 3218.33 2701371,6w. „° 7 ..„ Chevron • MAU 1%.1 Planned Well path Report P P %NO AN- 32RD #2 Version 6 BAKER Page 6 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well 3AN 32RD #2 Field Granite Point Field Wellbore AN -32 RD #2 Facility ANNA Platform Sidetrack from. AN -32 PB at 9414.00 MD WELLPATH DATA (155 stations) ¶ = interpolated /extrapolated station MD Inclination Azimuth ; TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] [01 [01 [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ ° /100ft] [ ft] 11614.00f 53.257 44.353 9807.39 9683.39 4819.67 3549.83 3273.84 270193.96 2554839.82 4.00 1 11714.00f 56.999 42.631' 9864.55 9740.55 4901.46 3609.35 3330.28 270251.57 2554898.20 4.00 11814.00f 60.764 41.051, 9916.23 9792.23 4986.95 3673.13 3387.35 270309.91 2554960.82 4.00 11914.00f 64.545 39.582 9962.16 9838.16 5075.74 3740.86 3444.80 270368 701 2555027.38 4.00 68.341 38.204111 10002.12 9878.12 5167.39 3812.20 3502. ," 270427.65 C 12114.00f 72.147, 36.8967 10035.91 9911.91 5261.44 3886.80 3559.66 ` 270486.46 2555170.99 4.00 12214.00f 75.961 35.644' 9939.38 5357.46 I 3964.31 3616.53 2555247.35 4.00 12314.00f 79.782' 34.432 10084.39 9960.39 5454.96 4044.35 3672.64 270602.57 2555326.24 4.00 12414.00f 83.607 33.249 10098.83 9974.83 5553.47 4126.53 3727.73 270659.29 2555407.29 4.00 y� � 2,1,42 10106.39 rar _ 9982.39 5647.12 4205.84 3778.64 270711.78 2555 T 12514.00f 87.226 32.147 10106.65 9982.65 5652.51 4210.43 3781.53 270714.75 2555490.10 100 12614.00f 87.226 32.147 10111.49 9987.49 5751.65 4295.00 3834.67 270769.58 2555573.59' 0.00 12714.00f 87.226 32.147 10116.33 9992.33 5850.80 4379.57 3887.82 270824.41 2555657.07 0.00 12814.00f 87.226 32.147 10121.17 9997.17 5949.94 4464.14 3940.97 270879.24 2555740.56 ? 0.00 129] 4 u , 87.226 32.147 10126.01 10002.01 6049.08 4548.71 3994.12 270934.07 2555824.04 Q QQ 13014.00f 87.226 32.147 10130.85 10006.85 6148.23 4633.28 4047.26 270988.90 2555907.53 0.00 13114.00f 87.226 32.147 10135.69 10011.691 6247.37 4717.85 4100.41 271043.72 2555991.01 0.00 13214.00f 87.226, 32.147 10140.53 10016.53 1 6346.52 4802.42 4153.56 271098.55 2556074.49 0.00 13314.00f 87.226E 32.147 10145.36 10021.36 6445.66 4886.99 4206.70 271153.38 2556157.98 0.00 13414.00f 87.226 32.147 10150.20 10026.20 6544.80 4971.56 [ K ' ' M; '. :G 6241.46 0.01 13514.00f 87.226 32.147 10155.04 10031.04 6643.95 5056.13 4313.00 271263.04 2556324.95 0.00_ 13614.00f' 87.226 32.147 10159.88 ' 10035.88 6743.09 5140.70 4366.14 271317.87 2556408.43 0.00 13714.00f 87.226 32.147 10164.72 10040.72 6842.24 5225.27 , 4419.29 271372.69 2556491.92 0.00 13814.00' 87.226 32.147 10169.56 10045.56 6941.38 5309.84 4472.44 271427.521 2556575.40i 0.00 13914.00f 87.226 32.147 10174.40 10050.40 7040.52 5394.40 459 271 ,_ 0.00 14014.00f' 87.226 32.147 10179.24 10055.24 7139.67 5478.97 4578.73 j 271537.18 2556742.37 0.00 14114.00f 87.226 32.147 10184.08 10060.08 7238.81 5563.54 4631.88 271592.01 2556825.85' 0.00 14214.00f 87.226 32.1471 10188.91 10064.91 7337.96 5648.11 4685.03 271646.84 2556909.34 0.00 14314.00f 87.226 32.147 10193.75 10069.75 7437.10 5732.68 4738.17 271701.66 2556992.82 ! 0.00 14414.00f 87.226 32.147 10198.59 10074.59 7536.24 5817.25 4791.32 271756.49 2557076.31 0.00 Chevron Planned Wellpath Report BAKER IWO AN- 32RD #2 Version 6 HUGHES Page 7 of 8 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD#2 Field Granite Point Field Welibore AN -32 RD #2 Facility ANNA Platform Sidetrack from AN -32 PB at 9414.00 MD WELLPATH DATA (155 stations) t = interpolated /extrapolated station MD Inclination Azimuth TVD 1 TVD from Vert Sect North East Grid East Grid North DLS [ft] [ °] [°] [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ °/1008] [ft] 14514.00t 87.226 32.147 10203.43 10079.43 7635.39 5901.82 4844.47 271811.32 2557159.79 0.00 14557.37 87.226 32.147 10205.5 10081.53 7678.39 _ I 0 0.00 14614.00t 87.226 32.147 10208.27 10084.27 7734.53 5986.39 4897.62 271866.15 2557243.28 0.00 14714.00t 87.226 32.147 10213.11 10089.11 7833.68 6070.96 4950.76 271920.98 2557326.76_ 0.00 7.226 32.147 10217.27 - 10093.27 7918.94 614319 4996 271968.13 2557398.56 ' Y 1 11 HOLE & CASING SECTIONS Ref Wellbore: AN -32 RD #2 Ref Wellpath: AN- 32RD #2 Version 6 String/Diameter Start MD End MD Interval Start TVD End TVD ' Start N/S Start E/W End N/S End E/W [ft] IN IN IN IN [ftl [ftl [ft] 30in Casing 19.00 291.00 272.001 19.00 290.99 0.00 0.00 -1.19 1.56 fi 20in Casing 19.00 619.00 600.00 19.00 618.98 0.00 0.00 -3.70 2:94 13.375in Casing 19.00 4019.00 4000.00 19.00 3977.54 0.00 0.00 320.08 38.30 30in Conductor 19.001 295.00 276.00 19.00 294.99 0.00 0.00 -1.22 1.58 `'20in Conductor 19.00 619.00 600.00 19.00 618.98" 0.00 0.00 -3.70 2.94 9.625in Casing Surface 19.00 9414.00E 9395.00 19.00 7919.46 0.00 0.00 3043.41 2345.03 8.5in Open Hole 9414.00 12600.00 3186.00 7919.46 10110.81 3043.41 2345.03 4283.16 3827.23 Tin Casing Intermediate 9300.00 12600.00 3300.00 7820.87 10110.81 299826 2309.86 4283.16 382723 6in Open Hole 12600.00 14800.00 2200.00 10110.81 10217.27 4283.16 3827.23 6143.69 4996.47 C • EI Planned Wellpath Report BAKER AN- 32RD #2 Version 6 HUGHES P age 8 of 8 INTEQ REFERENCE NI ELLPATH IDENTIFICATION Operator Chevron !Slot slot #2 -1 Area Cook Inlet, Alaska (Offshore) Well AN- 32RD#2 Field Granite Point Field Wellbore AN -32 RD#2 Facility ANNA Platform Sidetrack from AN-32 PB at 9414.00 MD TARGETS Name MD TVD I North East Grid East Grid North Latitude Longitude Shape [ft] [ft] [ft] [ft] [sry ft] [sry ft] An32Rd2 C - 7D Landin g Target et 10099.00 4076.61 3697.43 270628.00 2555358.00360 °59'17.145 "N 151 °17'30.340 "W polygon .�_ 15 - Jan - 2008 TV DSS Changed from previous plans 1) An32Rd2 C - 7D Toe Target 14557.37 10205.53 5938.50 4867.52 271835.10 _r '.1' t I� L point 26 - Feb - 2008 2200' Past Landing Point SURVEY PROGRAM Ref Wellbore: AN -32 RD #2 Ref Wellpath: AN- 32RD #2 Version 6 Start MD End MD Positional Uncertainty Model Log Name /Comment Wellbore [ft] [ft] 19.00, 4019.001SRG (Standard) AN -32 4019.00 9414.001SRG (Standard) 1 AN - PB 9414.00 12448.29 OnTrak (Magcorrl) ' - RD #2 12448.29 14800.00 OnTrak (Magcorrl) N -32 RD#2 PA Ie RIG 428 CHOKE MANIFOLD u PS O� 11 0 No C 19 NE VALVE # NATIONAL TYPE NORMALLY TO 0 1I 1 3.25 10K OPEN '-'No 2 2.56 5K OPEN 10 9 3 2.56 5K OPEN / I 14G B No 13N N 4 2.56 5K OPEN C 5 2.56 5K CLOSED • II 8 6 O 6 2.56 5K CLOSED 6 ,„/I0 A O 7 2.56 5K CLOSED 0 8 2.56 5K CLOSED Jr 5 4 3 O I 9 2.56 5K CLOSED 0 o NC 10 2.56 5K CLOSED 11 3.25 10K OPEN II ' 0 l' iS �0 ( 12 2.56 5K CLOSED NO 13 3.25 10K CLOSED G 14 3.25 10K CLOSED 12 N I 15 1.0 5K OPEN 1 Q NO 16 2.56 5K CLOSED 1 A 3 1/16" 10K SWACO AUTO CHOKE O B 3 1/16" 10K SWACO AUTO CHOKE C 3" 5K T3 MANUAL CHOKE 0 l LEGEND CHOKE MANIFOLD CHOkf n SCALE: Nrs LINE Y SENSOR 1 DWG. NUMBER SW REFERENCE DRAWINGS NOTFC REV DAZE REVISED q �,�wo "�."o..."o. ANNA PLATFORM A U/IR/U ISSUED FOR RENEW NM SL IV wo : y MR COOK INLET ALASKA ..o.�c. w „"„.,,,"w ACRFFIIA RIG 428 1 "`...... ^` CHOKE MANIFOLD ISOMETRIC DRAWING wui ROME '07;"Q3- NO . SIT NO . l N� DAIL ....... 3 �/ UOCC M11 001 A Chevron Granite Point Field %10 Well AN -32RD2 Cement Program 7" Liner (8 -1/2" Hole from 12500 to 9100' MD): Cement volume based on open hole volume plus 30 %, shoe joints and annulus. This will be a single stage cement job, pumping cement from 12500' and up to 9100' md. Estimated volume is as follows: Mud push: = 40 bbls 13.5 lb /gal @ 80 degF Cement Slurry: Open hole: 3100' X 0.1268 cuft/ft (8 -1/2" x 7 ") X 1.2 = 471cuft = sks (1.16 yield) Cased hole: 300' X 0.1738 cuft/ft (9.5/8" x 7 ") X 1.2 = 62.6 cuft = sks (1.16 yield) 40' shoe joint X 0.2148 cuft/ft = 8 cuft = 7 sks (1.16 yield) TOTAL: 471 + 62.6 + 8= 541 cuft (466 sks) Chase cement with OBM. Cement Properties Type Class G Density 15.81b /gal Yield 1.16 ft3 /sk Cementing Program An -24RD 1 3/19/2008 • • 4 4 Chevron Maximum Anticipated Surface Pressure Calculation Anna platform Well An -32RD2 Cook Inlet, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.437 psi /ft gradient from surface to planned total depth at 10200' TVD BRT. 2. The M.A.S.P. during drilling operations will be governed by the 9 5/8" KOP and the 7" shoe frac gradient The calculations take into account a gas gradient to surface of .1 psi /ft. The KOP for AN -32RD2 is at 7970' TVD. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. 8.5" Hole Fracture Pressure at KOP (7970' TVD): Max. Est. Frac pressure at KOP = 7970 ft. x 0.866 psi /ft = 6902 psi M.A.S.P. from pore pressure: Max. pore pressure at T.D. = 10,100 ft. x 0.437 psi /ft = 4414 psi M.A.S.P. (tbg leak at surface) = 4414 psi - (0.1 psi /ft * 10100 ft) = = 3404 psi 6" Hole Fracture Pressure at Casing Shoe (10100' TVD) Max. Est. Frac pressure at 7" shoe = 10100 ft. x 0.866 psi /ft = 8747 psi M.A.S.P. from pore pressure: Max. pore pressure at T.D. = 10,200 ft. x 0.437 psi/ft = 4457 psi M.A.S.P. (tbg leak at surface) = 4457 psi - (0.1 psi /ft * 10200 ft) = = 3437 psi • 4"j Calculation & Casing Design Factors 4....a0*, Chevron Anna Platform An - 32RD2 Cook Inlet, Alaska WELL: Anna 32RD2 FIELD: Granite Point DATE: 17- Mar-08 DESIGN BY: Tim Flynn Sect. 1 8 1/2" hole MUD WT. 9.00 PPG MASP= 3404 psi Sect. 2 6" hole MUD WT. 9.00 PPG MASP= 3437 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS © RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI ** PSI SF BURST • 1 9 5/8" 9,436 0 9436 43 N -80 Butt 405,748 405,748 1005 2.48 3,616 3,810 1.05 4,790 6,330 1.32 TVD 8,000 0 2 7" 12,500 9000 3500 29 P -110 Hyd 563 101,500 101,500 929 9.15 4,565 8,510 1.86 3,437 11,220 3.26 TVD 10,100 7200 2 4.5" 14,800 12500 2300 19 L -80 Hyd 511 43,700 43,700 208 4.76 4,610 7,500 1.63 3,437 8,430 2.45 TVD 10,200 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.435 psi/ft) and the casing evacuated for the internal stress (.1 psi/ft) ** See attached sheet for calculation of MASP • to. Chevron Well String Shoe Depth FG EMW (in.) (TVD -ft) (psi /ft) (ppg) GPP 51 9 5/8" 9529 1.05 20.2 GPP50 9 5/8" 9877 0.93 17.9 An -11 RD 9 5/8" 8750 0.92 17.7 AN -3RD 9 5/8" 7839 0.75 14.5 An -51 9 5/8" 9842 0.88 17 AN -7rd2 9 5/8" 4439 0.96 18.5 AN -32RD 9 5/8" 9900 0.92 16 • Granite Point Measured Frac Gradients 0 r t 2000 = 4000 I • HV #1 a 0 6000 ■HV #2 ca ! HV #3 o o 8000 xHV , • xHV #5 10000 - l • HV #6 12000 — 0.6 0.7 0.7 0.8 0.8 0.9 0.9 1.0 1.0 1.1 1.1 Frac Gradient (psi /ft) • • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1 /2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre - determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. • • Chevron IWO An -32RD PTD No. Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) Drilling Hazards 13 3/8 — 9 5/8" annulus pressure • Pressure ( <300 psi) has been recorded between the 13 3/8" and 9 5/8" annulus. Currently it is being monitored on a daily basis but poses no immediate concern. • Daily monitoring of the pressure will continue through the rig operations to ensure the pressure does not build to un acceptable levels ( >500 psi) 8 -1/2" Hole / 7" Casing (Intermediate) Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High Increased mud weight, controlled connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring Lost circulation Low Reduced pump rates, reduced trip speeds, real time ECD monitoring, mud rheology, lost circulation material Hole swabbing on trips Medium Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time ECD monitoring, use weighted sweeps Directional Control Medium BHA Design, Rotary Steerable Abnormal Reservoir Low Well control drills, check Pressure for flow during connections, increased mud weight. Likely be water influx, have emulsifiers available. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Sticking BHA in Coals Moderate Control drill through coals. Frequent reaming and trips through coals until sticking • I I tendency abates. 6" Hole / 4.5" Casing (Production) Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High Increased mud weight, controlled connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring Lost circulation Low Reduced pump rates, reduced trip speeds, real time ECD monitoring, mud rheology, lost circulation material Hole swabbing on trips Medium Reduced trip speeds, mud properties, proper hole out of hole filling, pumping ou g p P g real time ECD monitoring, use weighted sweeps Directional Control Medium BHA Design, Rotary Steerable Abnormal Reservoir Low Well control drills, check Pressure • for flow during connections, increased mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Sticking BHA in Coals Moderate Control drill through coals. 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' ,suf..), .A.A. ti+<�` 3 ■i16 3N Rte Ill R..13 ` /7// ra Am axa c« pat +w +xt SO' 42.0., ')511 WR.1MLY f! .•0..51.1 FLO 1 U l f LC w' FusA \ \ \ rlllr111u J 4 Mg1r711111 ■ J Is.. (M[R;a C!L I /9.w 0,..” x J 4 4/16-5I4 50. -� [_ " 6 F{ PAp° t Wrsmpl[ C" �' "n 011 a POP MAW Pww J I /16 -10Y 8/BXIN I I ro+.r1LE s, s MOTOR m POOL ARCTIC ALASKA 3" Tav�l 4 13'�s . S► p. Sti,aL. 8L0 STK. aS i R " xxx Imw sxrrr <' RC_ raas NIGH PRESSURE MUG AND I Alt ROY ttF WAIVER MGN WELL CONTROL SCHEMATfC NyWRF LaNQi - - ��— i----- 1- �-1AYW KU I'UM1° / MK IXRL MIM Wmo,44. w L t r? .fit � 1 _.1_ 428.5624 I ;j . 90 ..,. . . ..,. ., , ,.... 72800 273200 273600 274000 274400 274800 , /��/ ® ®�, ?swop 26790 zs7zoo z sm .... z $ 269200 xs9sao �0 7 0 � 270400 noeolzoo AN RD2 V P/i 0 9 ? . . ..t .94 I BR4 ° fi II 4 p 052.3 I� 1:. o ' BR42.10 jj o i4 • �� I ii •• �,. li � BR12J1 • _•477.19 Vi• oa h Y ' -88o AN• o 8 92 40 � AN -92 NJ2R �� 9 ,. AN3 D2 Lan Tar o` 411 ,(I • - • 4 2.3 I- 9705.1 ,�. -99134 ,__ 4' . / 32/2 TVS AN• • -8 3. : 11 2 k ?p 1 ' o = A i7RD 1 AN 17 $ c -0 °7 • ,r C -7DT 02.. 0 Flan AN-36 , rid, 3 2 • " % ° C•7 -10 LK Simz ion •del 1 3 ^ /40•00 . irjrarjr -3 - B1 .:: , lor,-.... , ,,40.P.._ ,,,...-- --,.._••Mgllr_ilgWjr a 0 250 -.. 750 1000 266000 266400 266800 287200 267603 268000 268400 268800 269200 269600 270000 270400 270800 271200 271600 272000 272400 272800 273200 273600 274000 274400 274800 $400 4600 0800 5000 525 r 5400 r 5800 500 5200 6400 650 r 650 4200 r 7 7500 785 805 _vs AN- 32RD2_V6 ✓ • TM39 1 •G1T 908 • G1A 45485 • 40A 050261 • M41 • C-3T �G2T 10862..E — __ - - - -_— _ —__ - _ — - 10649. -4B 106]5.]1. •.- _ —_ —.. —_ -._.- 18@55..: • G5AT - -. 11086. -__ — -_ — —_ — 11182.:'- BB _.. _._ 11247 95 • 43 1146162 • 44 11645.71 • 45A 11: 865.70 • 1.145C _ 1 ^•�. 7CT - -- RD2 landing Target • • ]DT Facies MO Coal Q sand 0 15 25 300 400 5008 1400 4600 4800 5000 5200 5400 5500 5800 8000 6200 6400 500 6800 705 7200 7400 7600 7800 8000 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 1P57 /v < 7`2 -32 �- Z— PTD# Za e "'— c) VZ V Develo went Service Sery ce Exploratory Stratigraphic Test Non - Conventional Well / FIELD: Bt.2T POOL: Af le 0o ;/ ��p j 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 (If last two digits in Permit No. , API No. 50- - - 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(0, all records, data and Togs 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 I program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool GRANITE PT, MIDDLE KENAI OIL - 280150 Well Name: GRANITE PT ST 18742 32RD2 Program DEV Well bore seg LI PTD#:2080420 Company UNION OIL CO OF CALIFORNIA Initial Class/Type DEV / PEND Geo Area 820 Unit On/Off Shore Off Annular Disposal [1] Administration 1 _Permit fee attached NA 2 _Lease_number _appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes GRANITE PT, MIDDLE KENAI OIL - 280150 defined in CO 76. 5 _Well_locatecl proper_distance_fro_m_ drilling unit boundary Yes -6,000 to pool boundary (eastern boundary of S. _32, T11N, R11W). 16 _Weillocated properdistance from other wells Yes Nearest well, GP 18742 31, is -1,10_0' away & is suspended (all perfs in that well are ptugged). 1 17 _S_ufficient acreage_ayailsble in_d_ritling unit Yes Conforms to CO 76, Rule 2: only well in quarter section, >500'_from property line, and 1 8 lfdeviated, is wellbore plat_included Yes >1,000' from nearest well. 9 Operator only affected Party Yes 10 Operator has_appropriate_ bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 _Permit can be issued )10/About administrative_approval Yes SFD 3/28/2008 13 an permit be approved before 15-day wait Yes • 14 _Well_located within area and_strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wetls_within_1/4_mile_area_of review identified (For service well only) NA 16 Pre-produced injector; duration_of preproduction less than 3 months_ (Forservice welt only) NA 17 _Nonconven. gas_conforms to Asal .05._0300.1.A),(1.2.A-D) NA Engineering 118 Conductor string_p_rovided NA Conductor set in 18742-32 (An-32) (176-087). 19 _Surfacecasing_protects all_known USOWs NA Alt aquifers exempted 40 CFR 147.102 (b)(2)(i). 20 _C_MT v_ol adequate_ to circ_ulate_o_n_cond_uctor & surf csg NA Surface casing set in An-32. 21 _GMT_ vot adequate_ to tie-inlong string tosurf csg NA Production casing set in An-32. 22 _GMT_ will coverall knowmproductive horizons No Production_ liner n_ot planned to be cemented OW° perforating. 23 Casing designs adequate for C, T, B & permafrost Yes 24 _Adequatetankage_ or reserve pit Yes Offshore platform. Class II disposal was av_aiJable. 25 MA re-drill, has a 10-403 for abandonment bean approved Yes 308-014 26 _Adequate_w_ellbore separation_pro_posed Yes Proximity analysis performed. Nearest segment is P&A portion of An-32RD and paths diverge. 27 ltdiverter require& does _it meet regulations NA BOP stack will already be in place. Appr Date 28 Drilling fluid_ program schematic_& eq_uiplist_adeouate Yes Normal reservoir pressure expected. MW planned 8.7 - 9.4 ppg as ne_eded. TEM 4/16/2008 29 _BOPEs,_ do _they meet regulation Yes • 31V\ 30 _BQPE_press rating appropriate; test to_(put psig in comments) c Yes Yes MASP calculated at 3434 psi. 350_0 psi BOP test_planned. 31 _C_hoke_ manifold omplies w/API_ RP-53 (May $4) 32 Work wiil occur without_operation shutdown Yes 33 is presence_ of H2S gas probable Yes Low H2S is reported on Anna. Mud should preclude H2S on rig. Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen_ sulfide measures No Caution advisible in this mature water-flood reservoir. Monitors, alarms in place. Scavengers available. 36 Data presented on potential overpres_surezonett Yes Expected reServoir_pre_ssure is 8.4 ppg EMW; will_be _drilled with 8.7 - 9.4 ppg oit-base mud. Appr Date 37 _Seismic_analysis_ of shallow gas zones NA SFD 3/28/2008 38 _Seabed _condition survey (if off-shore) NA 39 Contact _name/pho_ne for weekly progress reports_ (exploratory only] NA Geologic . Public Date Date Date Commissioner: Com issioner: Commissioner f , .
