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208-152
DATA SUBMITTAL COMPLIANCE REPORT 4/19/2011 Permit to Drill 2081520 Well Name /No. SWANSON RIV UNIT 211 -33 Operator UNION OIL CO OF CALIFORNIA API No. 50- 133 - 20581 -00 -00 MD 4760 TVD 3956 Completion Date 12/8/2008 Completion Status SUSP Current Status P &A UIC N REQUIRED INFORMATION — Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Too lengthy for data block see 10-407 (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Ty Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Li,..____ Rpt Report: Final Well R Open 1/14/2008 Final Well Report, Table of Cont, Eqip & Crew, Well Data, Geo Data, Drill Data, Daily Rep .4 17422 "Report: Final Well R 2120 4760 Open 1/14/2008 Final Well Report, Table of Cont, Eqip & Crew, Well Data, Geo Data, Drill Data, Daily Rep w /3D Mud Log Graphics in PDS, EMF and CGM as well as Word for Report. �g Mud Log 2 Col 2120 4760 Open 1/14/2009 MD Formation log CL-dg Mud Log 2 Col 2120 4760 Open 1/14/2009 TVD Formation log -Co Mud Log 2 Col 2120 4760 Open 1/14/2009 MD LWD Combo Log Xog Mud Log 2 Col 2120 4760 Open 1/14/2009 TVD LWD Combo Log .og Mud Log 2 Col 2120 4760 Open 1/14/2009 MD Gas Ratio 40 Mud Log 2 Col 2120 4760 Open 1/14/2009 TVD Gas Ratio Mud Log 2 Col 2120 4760 Open 1/14/2009 MD Drilling Dynamics og Mud Log 2 Col 2120 4760 Open 1/14/2009 TVD Drilling Dynamics BEY" C Las 17423-ma Ray 2062 4757 Open 1/14/2009 GR, ROP 1_503-- yg- Gamma Ray 2 Btu 102 4760 Open 1/14/2009 GR 1- Dec -2008 C Las 17424 'induction /Resistivity 2066 4776 Open 1/14/2009 Formation Eval, DENS, Temp, Mud, RMS, GR, NPHI, CNT Formats: PDS, LAS, DLIS ...- Induction /Resistivity 5 Col 2122 4763 Open 1/14/2009 TVD FME, FMI, GR DATA SUBMITTAL COMPLIANCE REPORT 4/19/2011 Permit to Drill 2081520 Well Name/No. SWANSON RIV UNIT 21133 Operator UNION OIL CO OF CALIFORNIA API No. 50-133-20581-00-00 MD 4760 TVD 3956 Completion Date 12/8/2008 Completion Status SUSP Current Status P&A UIC N ED --- 17425 ISEluction/Resistivity 208 2413 Open 1/14/2009 FMI, CNT, ECGR, GR, 1 HTNP, NPHI, Dens, 1 HMNO Formats: PDS, 1 --- LAS, DLIS 1 --- I-14 Formation Micro ha 5 BIu 208 4742 Open 1/14/2009 TVD FE, Plat Form I Express, GR Well Cores/Samples Information: Sample Interval Set • Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Daily History Received? 9.-1-N Chips Received? Y / N Formation Tops 6 N Analysis jj,„/4- Rec,eived? Comments: ) k Compliance Reviewed By: ------------------- Date: 01:1 1 _ 110 STATE OF ALASKA � f ■‘ v?-49 ALAS IP IL AND GAS CONSERVATION COMMISS N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 4 1a. Well Status: Oil ❑ Gas ❑ Plugged ❑ Abandoned Ell Suspended ❑ lb. Well Class: 20MAC 25.105 20AAC 25.110 Development El Exploratory I=1 GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other El No. of Completions: Service ❑ Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., or Atli 12. Permit to Drill Number: Site 6Ave 22 Union Oil Company of California Aband.: 6/3/2009 208 -152 .3cis7 -.S l 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 11/22/2008 50- 133 - 20581 -00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 468' FNL, 2107' FWL, Sec 33, T8N, R9W, SM 12/1/2008 SRU 211 -33 Top of Productive Horizon: 8. KB (ft above MSL): 20.5 15. Field /Pool(s): N/A Ground (ft MSL): 186' Swanson River Unit Total Depth: 9. Plug Back Depth(MD +TVD): 982' FNL, 127' FWL, Sec 33, T8N, R9W, SM Surface Sterling /Upper Beluga 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 344513.23 y- 2466008.4 Zone- 4 4,760'MD (3,956'TVD) A- 028399 [Swanson River Unit] TPI: x- N/A y- N/A Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 342525.83 y- 2465520.72 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No IN 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): N/A 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109# X -56 Surface 102' Surface 102' Driven N/A 9 -5/8" 40# L -80 Surface -tip Surface 1,746' 12 -1/4" 153 bbl Litecrete & 91 bbl Class G cement 23. Open to production or injection? Yes❑ No 0 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) N/A N/A N/A RECEIVED 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED .JUN 0 9 2009 N/A N/A iaska Oil & Gas Cons, Commission Anchorage 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Abandoned well N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period -► Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate -► 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. VC'S © A 5. ‘\'< ‘s k 0,) 5 0A.«ir.��.\-..lextes.,cQ--.yc1r, , _.,„ x1_,:014 a � EIFIL 2.,in 2 2 2000 - ` -.. Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE 6 • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El 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 STERLING A6ST 2,739 2,124 STERLING A7ST 2,856 2,188 STERLING A8 3,010 2,302 STERLING A9 3,109 2,378 STERLING Al0 3,298 2,533 STERLING BO 3,464 2,680 STERLING B2 3,600 2,800 STERLING B3 3,696 2,893 STERLING B5 3,903 3,091 STERLING B6 4,096 3,292 BELUGA 36 -9AST 4,344 3,533 BELUGA 36 -9ST 4,381 3,580 BELUGA 38 -4ST 4,580 3,776 BELUGA 39 -1ST 4,622 3,818 Formation at total depth: BELUGA 4,760 3,956 30. List of Attachments: Directional Survey, Current Schematic, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Newell 263 -7832 Printed Nam Timothy C. Brandenburg Title: Drilling Manager Signature: Phone: 276 -7600 Date: 6/5/2009 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 1 a: 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 • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 211 -33 SWANSON RIVER UNIT 211 -33 5013320581 LK4511 20.65 Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 11/12/2008 12/19/2008 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 211 -33 5013320581 -00 2081520 5/6/2009 00 :00- 5/7/2009 00:00 Operations Summary Shoot natural pad grade at 29" below cellar grating and clean location. 5171 009 00100 - 5/8/2009 00:00 Operations Summary Attempt to clean cellar but failed due to vac truck not operable. Replace cellar grating and secure location. 2:I 2009 ' �_�'; ># '- TY���glT! � t �®f.s•a. �r � � �� r � �' *� a Operations Summary » Clean cement and drilling mud from cellar. Cut casing stump c/w previous marker plate 6' below average natural pad grade. No top job required. Weld on new well marker plate witnessed by Lou Grimaldi of AOGCC. Clean and secure location. 5/1i`Lill, 0:00- 5/1 : ''° 1:00 �� -� "`�' Operations Summary Cut cellar box from casing stump and prepare for removal. Secure well and location while waiting on road restrictions to allow crane travel to location for cellar lift. 5/28 /2009'01:00.5/29 /2 � �. 00:00 7 u x , Operations Summary Remove cellar and back fill in hole. 6/3/2009 00:00 - 6/4/2008 00:00 _ : _ Operations Summary Excavate well stump and change marker plate, back filled hole. Last Report . a.. ..«w y . < ^«w « § y, > : y . x : :� . > . � \y a : y ®» < . � ° m � » 4 Y � . » ., , :� ° :� : � \ � »» §� � � \ . . . ^� : . v« . - ? > � y << «: „ ^ 2 : «\ + °\ < \§ y / \ y v . < \ y < I / I \ . t, , , ~� . . . . . \ .: / \ \ \% ? `ƒ \ i .. ,.,...,,, 1 i \. . 6 1 ,P ' ie 'N., , , - ' d. . Y ' ',.., " - ,, 4: , t ri,,,,,, , , r_',,. ,',,,,,„. ' ' ' , -413/4.4‘ , .....,-,-.. , .. .. ... _..... lirt ' . ' w °. kk #r ,. I. t 3 v . t ! A N .w4x „ .�w rrr " - , ice. ''' * j , s., -- . Y ✓' 4 fi Y . . S , k i ° ra, - . , AI • f R 4. • • 0 Chevron Well Name: SRU 211 -33 I Field: Swanson River Completion: As Built ABN 12/17/2008 RKB: 206.5' GL: 186.0' Driven I J _ 180' CMT I _ L Conductor. 16 ", 109 ppf, X -56 to 102' MD Fresh Water 12 -1/4" Hole 2106' MD / 1752' TVD 7 185' CMT L Surface Casing: 9%", 40 ppf, L -80, BTC t 2095' MD / 1746' TVD 9.7 ppg " WBM Plug 5 25 bbl 15.8 ppg Class G Plug 4 26.5 bbl 15.8 ppg Class G Disposal Zones used in Offset wells: Plug 3 Zone 1: 2753' MD / 2120' TVD 42 bbl Zone 2: 3186' MD / 2438' TVD 15.8 ppg 8 -1/2" Hole Class G Geologic Tops: 4760' MD / 3956' TVD Sterling A -10: 3298' MD / 2532 TVD ., Plug 2 Sterling B -2: 3600' MD / 2809' TVD 42 bbl Sterling B -3: 3696' MD / 2895' TVD 12.5 Sterling B -5: 3903' MD / 3107' TVD ppg Sterling B -6: 4096' MD / 3286' TVD LiteCrete Beluga 36 -9A: 4344' MD / 3536' TVD Beluga 36-9 4381' MD / 3578' TVD Plug 1 Beluga 38 -4: 4580' MD / 3776' TVD 42 bbl Beluga 39 -1: 4622' MD / 3822' ND 12.5 ppg MD (ft) MD (ft) LiteCrete PBTD = 4760' MD Bottom Top TD = 4760' MD Plug 1 4760 4160 Plug 2 4160 3560 Plug 3 3560 2960 Plug 4 2960 2746 Tagged Plug 5 2746 2430 Tagged Retainer 2000 Plug 6 Retainer Top -1915 Plug 7 -180 30 Tagged from GL Top Job 30 GL 5 Tagged from GL WBD SRU 211 -33 ABN.xIs December 17, 2008 Drawn by: RMS ��� P«�*lofl ~ • �� Regg, James �������^�� " y � �� � (DOA) L/� '/�,—� ' From: Regg, James B (DOA) Z/ f / Sm nt: K8ondey.JuneO1.2OOS4:D1PWY <�( 1/7o)1 Tm: �v|er8L@:hevnon.00nn' / Smbject: Swanson P&As Attachments: Surf Abandonment SRF KGSF-3 Plate 05-08-09 LG.jpg; SRU 211-33 Plate 05-08-09 LG.jpg There is wrong info on both marker plates (photos attached) KGSF #3 - Chevron is not a designated operator in Alaska; should be either Union or Union Oil Company of California - wrong API #; should be 50-133-20523-00 - wrong distances from lease lines; should be 1754 ft FNL, 4030 ft FEL SRU 211-33 - Chevron should be Union Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907'793'1236 6/1/2009 a . • IP Incorrect Info on Abandonment Marker Plates Swanson River Unit Photos by AOGCC Inspector L. Grimaldi 5/8/2009 SRU 211 -33 (PTD 208 -152) �. r > ° . f Should be Union (or S t.. !` 2 w- t :� p Union Oil Company of California) Chevron is i i , - not designated operator y 3e :.'" �.; th - . j^ ' � a' • �.t � r • '" !:;,•;•' "'' g v ,'' '«.. -.- , .- . 4L • 1 7.� i � . ; w . y fit 4 — ..' '..-' '' -,...:-.%:.-c -- ; ,, ..,,a.....atiolimiii,46.-. ,...., . , , , . • SRU KGSF #3 PTD 203 -074) Should be Union (or 1 , A, Union Oil Company of 4, I) ) -- California); Chevron is • ' s I not designated operator � t � 1 ; --- Should be: r 0. --, . 4f: ' ' I API # 55-133-20523-00 i ,. " 1 1 .,,,, It 1 i \ ( , . - -- r ""�+t # d ' o `t f _ ' Should be: „' 1754 ft FNL 4030 ft FEL , Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU� 33, SRU211... Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 21, 2009 8:18 AM To: 'Newell, Jack R [FEP]' Cc: Harness, Evan; Kanyer, Christopher V; Santos, Ronilo; Grimaldi, Louis R (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA) Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Jack, Thanks for the update. Contact the Inspectors as necessary to finalize the work out. Call or message with any questions. Tom Maunder, PE AOGCC From: Newell, Jack R [FEP] [mailto:JNewell @chevron.com] Sent: Thursday, May 21, 2009 8:14 AM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Kanyer, Christopher V; Santos, Ronilo Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Mr. Tom Maunder, Swanson River Unit KGSF 3 PTD: 203 -074 Approved Sundry #308 -438 Activities were witnessed by Lou Grimaldi. Cut -off casings 66" below natural ground level. Used Class G cement to have cement to surface. Welded marker plate on to cut casings. We have prepped cellar for removal. Roads in the SRU are improving for mobilization of equipment to remove and bury marker plate. Swanson River Unit SRU 41 -33 PTD: 161 -003 Approved Sundry #308 -312 We have prepared location, shot for natural grade level. Pad and roads were soft to this location. Have not mobilized dirt equipment to cut -off casing, remove, and bury cellar. Swanson River Unit SRU 211 -33 PTD: 208 -152 Approved Sundry 308 -439 Activities were witnessed by Lou Grimaldi. Cut casings off 6' below natural ground level, Natural grade 29" below cellar grating. Cement to surface from drilling activities, no top fill. Welded marker plate. Prepped cellar, roads soft for crane movement. Waiting on road limitations, should be finished with activities within 30 days. Jack R. Newell •• Chevron North America Exploration and Production 5/21/2009 L Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 33, SRU211... Page 2 of 3 Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, May 21, 2009 7:46 AM To: Newell, Jack R [FEP] Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Jack, Just a follow -up; was the work able to be accomplished? Tom From: Newell, Jack R [FEP] [mailto:JNewell @chevron.com] Sent: Friday, May 01, 2009 9:04 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Thomas_Zelenka @blm.gov; Tim.Lawlor @ak.blm.gov; greg_noble@ak.blm.gov Cc: Harness, Evan; Menapace, Michael Sam; Tyler, Steve L; Kanyer, Christopher V; Santos, Ronilo Subject: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Gentlemen, Follow up on phone voice messages to Tom Maunder, Jim Regg, Tim Lawlor: E -mail notification of proceeding: Swanson River Unit Well Abandonment: Continuation of surface clearance; We will be commencing as early as Monday May 4, 2009 to continue operations that were deferred due to ground freezing Fall 2008 on the below listed wells: The wells have previously been cemented to surface per approved sundry and other filings. Swanson River Unit KGSF 3 PTD: 203 -074 Approved Sundry #308 -438 Continue with approved operational goals. Swanson River Unit SRU 41 -33 PTD: 161 -003 Approved Sundry #308 -312 Continue with approved operational goals. Swanson River Unit SRU 211 -33 PTD: 208 -152 Approved Sundry 308 -439 Continue with approved operational goals. 5/21 /2009 Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211... Page 3 of 3 if there are questions please call me, there is no particular order implied Thank you, Jack R Newell • • jneweil @Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel 1 907 263 -7832 Fax 1 866 401 0624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7832. 5/21/2009 Chevron Olacisco Castro Chevron North Aica Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 :;it•) • • • Anchorage, AK 99503 440 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE January 9, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL lAtagot ; lo ctd ks 10 A' A4tE*Atli6:degbV%YSrk,Ma0RP FORMATION SRU 211-33 EVALUATION FMI GR TVD 5" 3-Dec-08 1 1 2122-4763 LAS, PDS, DLIS PLATFORM EXPRESS GR SRU 211-33 TVD 5" 2-Dec-08 1 1 208-4742 LAS, PDS, DLIS FINAL WELL REPORT DML, PDF, LAS, SRU 211-33 MUD LOGGING DATA 2" 04-Dec-08 1 1 2120-4760 TIFF GAMMA RAY MEMORY 23-Nov-08 SRU 211-33 LOG 2" 01-Dec-08 1 1 2062-4757 LAS /03 / Cf9 )( C ))1 / \-/°`)/ (2.) lt j\J e „„,„, . .. Please acknowledge receipt by signing and returning one copy of 907 263 7828. Received By: ) D.; Date: - AWAk,:fiVa / 1 \� ' STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS N JAN 0 7 2009 COMPLETION OR RECOMPLETION REPO WELL O �+a�h2��s @�. C�mfn sslol� la. Well Status: Oil ❑ Gas ❑ Plugged la Abandoned ❑ Suspended ID 1 b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 Development ga Expl atory❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Aband.: 12/8/2008 208 -152 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 11/22/2008 50 -133- 20581 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 468 FNL, 2107' FWL, Sec 33, T8N, R9W, SM 12/1/2008 SRU 211 -33 Top of Productive Horizon: 8. KB (ft above MSL): 20.5 15. Field /Pool(s): N/A Ground (ft MSL): 186' Swanson River Unit Total Depth: 9. Plug Back Depth(MD +TVD): 982 FNL, 127' FWL, Sec 33, T8N, R9W, SM Surface Sterling /Upper Beluga 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 344513.23 y- 2466008.4 Zone- 4 4,760'MD (3,956'TVD) A- 028399 [Swanson River Unit] TPI: x- N/A y- N/A Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 342525.83 y- 2465520.72 Zone- 4 N/A N/A 18. Directional Survey: Yes ell No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD Gamma Ray, Quad Combo (GR, Res, Density, Neutron, Sonic), FMI, Mudlogs (Formation Log LWD /Combo Log, Gas Ratio Log, Drilling Dynamics) 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109# X -56 Surface 102' Surface 102' Driven N/A 9 -5/8" 40# L -80 Surface ,1•4tf Surface 1,746' 12 -1/4" 153 bbl Litecrete & 91 XFS' bbl Class G cement 23. Open to production o r injection? Yes ❑ No 0 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) N/A N/A N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Abandoned well Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period •■;* Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No IO 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 25.07 5% sue ' t a 0 bk h t a-s . W c> 1 •)• 5 �\ et S �� E �Sctc os.c.c>, PP cv cov * - o ROMS L JUN 2 2 2009 Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE G. • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, 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 STERLING A6ST 2,739 2,124 STERLING A7ST 2,856 2,188 STERLING A8 3,010 2,302 STERLING A9 3,109 2,378 STERLING A10 3,298 2,533 STERLING BO 3,464 2,680 STERLING B2 3,600 2,800 STERLING B3 3,696 2,893 STERLING B5 3,903 3,091 STERLING B6 4,096 3,292 BELUGA 36 -9AST 4,344 3,533 BELUGA 36 -9ST 4,381 3,580 BELUGA 38 -4ST 4,580 3,776 BELUGA 39 -1ST 4,622 3,818 Formation at total depth: BELUGA 4,760 3,956 30. List of Attachments: Directional Survey, Current Schematic, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ronnie Santos 263 -7978 Printed Name: Timothy C. Brandenburg Title: Drilling Manager Signature:: , Phone: 276 -7600 Date: 1/7/2009 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 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 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 Well Name: SRU 211 -33 A O . Field: Swanson River 1%0 Completion: As Built ABN 12/17/2008 RKB: 206.5' GL: 186.0' Driven I j — 180' CMT _ L Conductor: 16 ", 109 ppf, X -56 to 102' MD Fresh Water 12 -1/4" Hole 2106' MD /1752'TVD 185' CMT I Surface Casing: 9 % ", 40 ppf, L -80, BTC to 2095' MD / 1746' TVD 9.7 ppg WBM Plug 5 25 bbl 15.8 ppg Class G Plug 4 26.5 bbl 15.8 ppg Class G Disposal Zones used in Offset wells: Plug 3 Zone 1: 2753' MD / 2120' TVD 42 bbl Zone 2: 3186' MD / 2438' TVD 15.8 ppg 8 -1/2" Hole Class G Geologic Tops: 4760' MD / 3956' TVD Sterling A -10: 3298' MD / 2532' TVD Plug 2 Sterling B -2: 3600' MD / 2809' TVD 42 bbl Sterling B -3: 3696' MD / 2895' TVD 12.5 Sterling B -5: 3903' MD / 3107' TVD ppg Sterling B -6: 4096' MD / 3286' TVD LiteCrete Beluga 36 -9A: 4344' MD / 3536' TVD Beluga 36 -9: 4381' MD / 3578' TVD Plug 1 Beluga 38 -4: 4580' MD / 3776' TVD 42 bbl Beluga 39 -1: 4622' MD / 3822' TVD 12.5 ppg MD (ft) MD (ft) LiteCrete PBTD = 4760' MD Bottom Top TD = 4760' MD Plug 1 4760 4160 Plug 2 4160 3560 Plug 3 3560 2960 Plug 4 2960 2746 Tagged Plug 5 2746 2430 Tagged Retainer 2000 Plug 6 Retainer Top -1915 Plug 7 -180 30 Tagged from GL Top Job 30 GL 5 Tagged from GL WBD SRU 211 -33 ABN.xls December 17, 2008 Drawn by: RMS • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 211 -33 SWANSON RIVER UNIT 211 -33 5013320581 LK4511 20.65 nu . s , », k (..#r .tg,� a'c : V , „r .;rt r� r,, Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 11/12/2008 12/19/2008 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 211 -33 5013320581 -00 2081520 V .. TC g +' +3.'' 5 x r.. b� 77.7 . • 5 : $ il„ 3 4 1' if 121 008 00:00 - '.11113/2008 00:00 Operations Summary Mobilizing rig from SCU 312 -09. '1111312008 00:00 - 11/1412008 00:00 , ` ,.l.f, ab, Operations Summary Mobiliziing rig on SCU 211 -33 £1/1412008 00:0' = e B , ' 00`4 i 3 V ';: 'r` te Operations Summary Mobiliziing rig on SCU 211 -33 11/15/ 2008 00t00104/16/2008 F111612008 00 :00 Operations Summary Mobiliziing rig on SCU 211 -33 : o a- 11/1712008 >... = , Operations Summary Mobiliziing rig on SCU 211 -33 11/17/2008 00:00 -11/1812008 00:00 „."'S-"?..' Operations Summary Mobiliziing rig on SCU 211 - 33 11/18/2008 00:00 - 110,19/2008 0':00 ; t ; Operations Summary Mobilizing rig on SCU 211 -33 11/101 00 0'''Aro Operations Summary Continue rigging up. NU BOP /Diverter. o I - i ;. 11 20 ? t�tt 08 00.00w �.;' rr�� Operations Summary Finish NU and function test diverter system and accumulator to 3,000 psi. Veri functions and alarms of all .as detectors, PVT and flow. Mix spud mud. Operations Summary PU and rack back DP and BHA components while working on genset #2. Test mud pumps and lines. 11/22/ 2008 00 :00. 11/2312008 00.110.. <. rr Operations Summary PU 12 -1/4" bit and DC. RIH drill vertical hole from 102' to 257' with 8.7 -8.8 ppg WBM. Circulate /condition hole and POH for directional BHA. Started weighting up mud to 9.6 ppg. LD excess BHA components. _w.: > 00:00 - X 11/24/2008 00:00 ' e ` ' .. . r., , Operations Summary Finished LD excess BHA components. Weight up mud to 9.6 ppg while servicing rig and TDS. PU directional BHA and drill directional hole building inclination to 1418'MD. 111124/2008 00:00. 11/25/2008 00:00: ,,.' - Operations Summary Drill directional hole buildin. inclination to 56 deg to 2106'MD/1750'TVD. Circulate hole clean and POH backreaming tight spots. LD motor and MWD. 1112 008w4 e c ' ! �' .; ".. k , >3 Operations Summary Finish LD motor and bit. LD jar and PU new. MU and RIH with 12 -1/4" hole opener to TD. RIH reaming tight spots. Circulate hole clean. POH working on tight spots. Prepare to run casing. rl 00 . - 11/271200800:00 p Operations Summary Finish LD BHA. RU casing running gears. Run 9 -5/8" 40 ppf L -80 BTC casing. Land casing on WH hanger with EOC at 2095'. Circulate while preparing to cement casing. 11/27/200800 :00 .� ' n Operations Summary Circulate and condition hole prior to cementing. Pressure test lines to 5000 psi. Cement casing with 153 bbls of 12.5 ppg LiteCrete lead cement slurry. Had mixer problems while pumping tail. Pumped 91 bbls of 13.5 ppg- 15.8 ppg Class G tail cement. Did not bump plugs. Cement returns to surface. R/D cement gear. Installed and tested WH packoff to 5000 psi. Test BOP and gas detection system to 250/3000 psi. AOGCC (Lou Grimaldi) waived witness 17:00 11/27/2008. BLM notified without response on 11/26/2008. i ° Wi rt r i 1W00:01} Operations Summary Continue BOP test. Repair and retest blind rams. All tests 250 psi /10min and 3000 psi/10min. Test accumalator. Build PHPA mud volume to 528 bbl in pits. • • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 211 -33 SWANSON RIVER UNIT 211 -33 5013320581 LK4511 20.65 'pax LLLL 11/29/2008 00:00 - ;11/30/2008 00:00 Operations Summary Blind rams test good after replacing seal elements. Pull test plug and install wear bushing. Test casing against blind rams. Stage pressure to 2000 psi /30min, good test. PU directional BHA and RIH with 8 -1/2" PDC bit. Tag at 1996'. Conduct man down drill and post meeting. Displace spud mud in casing with PHPA mud. Tag hard cement at 2011'. Drillout plug, float equipment, shoe, and 20' of new formation to 2125'. Conduct FIT w/ 9.2 ppg mud to 12.5 ppg EMW at 2125'MD/1763'TVq. Drill 8 -1/2" tangent hole to 2638'MD. 11/30/20.080000 " " - ' 12/1/20080000. ..,. A �;.. Vii" ", Operations Summary Drill directional hole sliding as needed to drop inclination to 2875'MD. Circulate and condition hole while rig service TDS. Drill directional hole sliding as needed to 3408'MD. Circulate hivis sweep. Drill directional hole sliding as needed to 3662'MD. Coal stingers at 3509' - 3566'. Drill slide from 3662' to 3816'MD. Had difficulty sliding, work through tight spot. Circulate hivis sweep and condition hole. r Operations Summary Directional drill slide as needed to 4015'MD. Work and backream tight spot at 4015'. Directional drill slide as needed to 4191'MD. Circulate hivis sweep and condition hole. Directional drill slide as needed to 4760'MD TD. Circulate and condition hole. Geologist extended bottom (Beluga) target boundary 75' to the west. Intersects ottom target away rom onglna target boundary. POH through tight spots between 4215' to 4675'. Normal drag rest of the trip to 3408'. ' ' .1100 Operations Summary Short trip to shoe from 3408' to 2065'. Overpull 1 OK into shoe. Circulate hole and recovered some fine sand chunks of clay accross the shaker. Trip in the hole and wash ream last 64' to bottom. Work high torque bottom 25'. Circulate and condition hole for logging. Pump hivis sweep. Recovered a lot of fine sand on the shaker. Service rig and TDS. POH and LD directional BHA. RU Schlumberger Loggers. WL log with Quad Combo. No problem getting to bottom. Tag bottom no fill. Log up to casing shoe. POH and LD tools. 12/0/2008 00:00 -12/ 008 00:00 ' x * 1 ` Operations Summary Finish logging with FMI tools. Log up to casing shoe. Lay down pipe while waiting on office (WOO). MU ABN mule shoe & RIH to shoe. WOO. 12/4/2008 00 :00 - 12/512000 "00:00 _ . Operations Summary Rcvd verbal aooroval from BLM and AOGCC t Droceed with ABN. P/U mule shoe and TIH to 4760'. Pressure test lines to 4000 psi. Mix and pump 42 bbls of 12.5 ppg LiteCrete and spot plug from 4760'- 4160'. 12/5/200800:004 12/8/2008 00:00 Operations Summary Pull out of plug and circulate at 4146'. Pump plug #2 from 4160' -3560' with 42 bbls of 12.5 ppg LiteCrete. Pull out of plug and circulate clean. Pump plug #3 from 3560 -2960' with 42 bbls of 15.8 ppg Class G cement. Pull out of plug and circulate. Pump plug #4 from 2960' -2600' with 26.5 bbls of 15.8 ppg Class G cement. Pull out of plug and circulate. Pull out of hole laying down pipe. 42/6/2008.00:00/:f2/7/200808400W9' tr x Operations Summary Trip in hole to 2028' WOC. TIH and tag plug at 2746' MD with 15K (witnessed by L. Grimaldi of AOGCC). Mix and pump plug #5 with 25 bbls of 15.8 ppg Class G cement from 2746' - 2430'. Pull out of hole and circulate clean. WOC. 12/7 i I IL!, r 1172g/742008 t ir ' Operations Summary WOC. TIH and tag cement at 2430' MD with 15K dawn ( WitnessAd by L. Grimaldi of AOGCQ). POOH and UD Mule shoe. Pick up CIBP and trip in hole to 2000' MD. Set retainer and pull 15K over. PSI test casing to 1100 psi for 30 minutes (Test witnessed by L. Grimaldi of AOGCC). Mix and pump 6 bbls of 15.8 ppg Class G cement on top of retainer. Pull out of hole and lay down drill pipe. TIH with 3 stands and displace well to freshwater. M/U Cement head. 12/8/2008 00.00 = a ' 08 00: t 0 „ , }, Operations Summary Test cement lines to 1000 psi. Mix and pump 15 bbls of 15.8 ppq Class G cement and set surface plug from 192' -5', POOH. M/U wash down joint and circulate to 2ti' from RKB. Begin cleaning for rig down. Nipple down BOP's. Tagged cement at 30' (remedial cementing will be performed during rig down to get to surface Clean pits and cellar. 1 /2008`00:00 - 12/10/2008 00:00 Operations Summary Preparing area to repair DW. To. 'ob surface plug in 9 -5/8" casing to 5' below ground level. 211012008 00:00.12111 008 00:00 � • . ; , "• f x li . x ,t4 Operations Summary Continue Repairing DRWKS and Rigging down Rig. n . 12/11/2008 00 :00 - 12/12/200800:00 x ,; " ; . 1 Operations Summary Continue Repairing DRWKS and Rigging down Rig. 1 a 2/2 1 ° ; 1 00' 3/1008 00 4 r fir. 4, .4-411m: Operations Summary Continue Repairing DRWKS and Rigging down Rig. 1 - 2008 00:00 - 12114/200800:00, a r = Operations Summary Rigging down pipe skate, wind walls and topdrive. • • Chevron C hevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 211 -33 SWANSON RIVER UNIT 211 -33 5013320581 LK4511 20.65 12/14/ 2008 00:00. 12/15/2008 00:00 ,, Operations Summary Continue rigging down Rig and stagging equipment on Tyler pad to be transported. 12/15/2008 00:00 - 12/16/2008 00 :00 Operations Summary Continue rigging down Rig and stagging equipment on Tyler pad to be transported. 12/113/2008 00:00.12/17/2008 00:00 Operations Summary j .T A f Continue rigging down and stagging equipment on Tyler pad to be transported. 12/17 /2008 00:00 - 12/18/2008 00 :00 Operations Summary Continued stagging equipment and moving out on trucks. Cut off wellhead and weld P &A "cao onto the 16" casing of SRU 211 -33 below grade. Surface cement plug, casing cut elevation, and weld cap inspected and accepted by Jeff Jones of AOGCQ. 12/18/2008 00:00 12/19/200800:00 Operations Summary Continued Stagging equipment and moving out on trucks. Rounding up all misc equipment and loading in mud boxes. Actual Wellpath Geographic Report Report Generated 12/3/2008 at 9:45:05 AM Projection System >. s_., NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Operator Chevron North Reference True Area Cook Inlet, Alaska (Kenai Penninsula) Scale 0.999928 Field Swanson River Unit Horizontal Reference Point Slot Facility SRU 211-33 Vertical Reference Point N -106E (RKB) Slot 211-33 MD Reference Point N -106E (RKB) Well 211-33 Field Vertical Reference mean sea level Wellbore 211 -33 N -106E (RKB) to Facility Vertical Datum 206.50 ft Wellpath NaviTrak MWD <191 - 4760'> N -106E (RKB) to mean sea level 206.50 ft Wellbore Last Revised 11/24/2008 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from (none) Section Origin X E 0.00 ft User Ulricard - Section Ori • in Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 255.45° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft] [USft] Slot Location -467.74 2108.06 344513.23 2466008.40 60 °44'49.339 "N 150 °52'08.627 "W Facility Reference Pt 342411.79 2466504.34 60 °44'53.947 "N 150 °52'51.039 "W Field Reference Pt 347751.98 2471720.97 60°45'46.011"N 150°51'04.957'W N • D from MD Inclination Azimuth ND 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) (I1 00ft] [ °] [° /100ft] (I1 00ft] [ft] 0.00 0.00 210.64 0.00 - 206.50 0.00 0.00 344513.23 2466008.40 60 °44'49.339 "N 150 °52'08.627' 0.00 - 149.36 0.00 0.00 0.00 191.00 0.31 210.64 191.00 -15.50 -0.44 -0.26 344512.96 2466007.96 60 °44'49.335 "N 150 °52'08.633' W 0.16 43.36 0.16 0.00 0.37 233.00 0.56 231.66 233.00 26.50 -0.67 -0.48 344512.74 2466007.74 60 °44'49.333 "N 150°52'08.637'W 0.70 12.28 0.60 50.05 0.63 294.00 2.14 240.75 293.98 87.48 -1.41 - 1.71 344511.50 2466007.01 60°44'49.325 "N 150 °52'08.662'W 2.61 11.00 2.59 14.90 2.01 356.00 5.33 247.36 355.84 149.34 -3.09 -5.38 344507.81 2466005.39 60 °44'49.309 "N 150°52'08.736'W 5.18 2.32 5.15 10.66 5.98 417.00 7.77 248.09 416.44 209.94 -5.72 - 11.82 344501.34 2466002.84 60 °44'49.283 "N 150 °52'08.865' W 4.00 5.84 4.00 1.20 12.88 478.00 9.93 249.37 476.71 270.21 -9.11 - 20.57 344492.54 2465999.57 60 °44'49.249"N 150°52'09.041'W 3.56 3.46 3.54 2.10 22.20 540.00 11.67 249.89 537.61 331.11 -13.15 -31.46 344481.60 2465995.67 60 °44'49.210 "N 150°52'09.260'W 2.81 2.38 2.81 0.84 33.75 600.00 13.73 250.25 596.14 389.64 -17.64 -43.86 344469.14 2465991.34 60 °44'49.165 "N 150 °52'09.510 "W 3.44 11.08 3.43 0.60 46.89 662.00 16.12 251.93 656.04 449.54 -22.80 -58.97 344453.97 2465986.39 60 °44'49.115 "N 150°52'09.814'W 3.92 17.66 3.85 2.71 62.81 723.00 18.59 254.38 714.26 507.76 -28.04 - 76.39 344436.48 2465981.37 60 °44'49.063 "N 150°52'10.164'W 4.22 0.18 4.05 4.02 80.98 784.00 20.87 254.40 771.67 565.17 -33.58 - 96.22 344416.58 2465976.10 60 °44'49.008 "N 150°52'10.563'W 3.74 -1.13 3.74 0.03 101.57 845.00 23.06 254.29 828.24 621.74 -39.74 - 118.19 344394.53 2465970.23 60 °44'48.948 "N 150°52'11.005'W 3.59 10.20 3.59 -0.18 124.38 910.00 25.27 255.22 887.54 681.04 -46.73 - 143.86 344368.77 2465963.58 60 °44'48.879 "N 150 °5211.522W 3.45 -14.75 3.40 1.43 150.99 973.00 27.39 254.01 944.00 737.50 -54.15 - 170.80 344341.74 2465956.52 60 °44'48.806 "N 150 °52'12.064"W 3.47 -8.09 3.37 -1.92 178.92 1038.00 30.70 253.09 1000.82 794.32 -63.10 - 201.06 344311.37 2465947.97 60 °44'48.718 "N 150 °52'12.672'9 5.14 6.11 5.09 -1.42 210.46 1102.00 32.99 253.54 1055.19 848.69 -72.79 - 233.40 344278.90 2465938.71 60 °4448.622 "N 150°52'13.323'W 3.60 24.42 3.58 0.70 244.20 1166.00 34.65 254.86 1108.36 901.86 -82.48 - 267.68 344244.51 2465929.48 60 °44'48.527 "N 150 °52'14.013' W 2.84 4.70 2.59 2.06 279.81 1230.00 36.61 255.13 1160.37 953.87 -92.13 -303.69 344208.37 2465920.30 60 °44'48.437N 150 °52'14.737' W 3.07 9.46 3.06 0.42 317.09 1294.00 38.44 255.62 1211.13 1004.63 - 101.97 -341.41 344170.53 2465910.97 60 °44'48.335 "N 150 °52'15.496M 2.90 -15.06 2.86 0.77 356.07 1358.00 39.97 254.98 1260.72 1054.22 - 112.24 -380.53 344131.27 2465901.22 60 °44'48.234 "N 150°52'16.283'W 2.47 -31.22 2.39 -1.00 396.52 1423.00 41.67 253.44 1309.91 1103.41 - 123.81 - 421.41 344090.25 2465890.19 60 °44'48.120 "N 150 °52'17.106' W 3.04 15.10 2.62 -2.37 439.00 • 1487.00 43.22 254.05 1357.13 1150.63 - 135.89 -462.88 344048.63 2465878.65 60 °44'48.001 "N 150°52'17.940'W 2.51 46.45 2.42 0.95 482.17 1550.00 44.53 255.99 1402.55 1196.05 - 147.17 -505.05 344006.31 2465867.94 60 °44'47.890 "N 150°52'18.788'W 2.98 20.40 2.08 3.08 525.83 1615.00 45.49 256.49 1448.50 1242.00 - 158.10 -549.71 343961.52 2465857.60 60 °44'47.787N 150 °52'19.687M 1.57 37.09 1.48 0.77 571.79 1677.00 46.98 258.02 1491.39 1284.89 - 167.97 -593.38 343917.73 2465848.31 60 °44'47.685 "N 150°52'20.565'W 2.99 -2.57 2.40 2.47 616.54 1743.00 48.31 257.94 1535.85 1329.35 - 178.13 - 641.08 343869.90 2465838.78 60 °44'47.585 "N 150 "52'21.525"9 2.02 16.38 2.02 -0.12 665.27 1805.00 50.14 258.64 1576.34 1369.84 - 187.65 -687.05 343823.81 2465829.87 60 °44'47.491 "N 150°52'22.450'W 3.07 -27.62 2.95 1.13 712.16 1871.00 52.14 257.32 1617.75 1411.25 - 198.36 - 737.31 343773.41 2465819.82 60 °44'47.386 "N 150°52'23.461'W 3.41 3.46 3.03 -2.00 763.50 1935.00 54.43 257.49 1656.01 1449.51 - 209.55 - 787.38 343723.21 2465809.30 60 °44'47.275 "N 150°52'24.468'W 3.58 -10.58 3.58 0.27 814.77 2000.00 56.03 257.13 1693.08 1486.58 - 221.28 - 839.46 343670.97 2465798.26 60 °44'47.160 "N 150 °52'25.51619 2.50 -76.18 2.46 -0.55 868.13 2046.00 56.23 256.17 1718.71 1512.21 - 230.10 - 876.62 343633.70 2465789.94 60 °44'47.073 "N 150 °5226.264W 1.79 150.95 0.43 - 2.09 906.32 2095.00 55.72 256.51 1746.13 1539.63 - 239.69 -916.09 343594.12 2465780.87 60 °44'46.978 "N 150°52'27.058'W 1.18 150.76 -1.03 0.70 946.92 Interpolated Point 2106.00 55.61 256.59 1752.34 1545.84 - 241.80 - 924.92 343585.26 2465778.88 60 °44'46.958 "N 150 °5227.235W 1.18 150.71 -1.03 0.70 956.01 Interpoated Point 2139.00 55.27 256.82 1771.06 1564.56 - 248.05 - 951.37 343558.73 2465772.98 60 °44'46.896 "N 150°52'27.768'W 1.18 30.99 -1.03 0.70 983.18 2203.00 55.60 257.06 1807.37 1600.87 - 259.96 - 1002.71 343507.24 2465761.75 60 °44'46.779 "N 150°52'28.800'W 0.60 0.00 0.52 0.37 1035.86 2268.00 55.78 257.06 1844.00 1637.50 - 271.99 - 1055.04 343454.77 2465750.42 60 °44'46.660"N 150 °52'29.853' W 0.28 -87.26 0.28 0.00 1089.53 2332.00 55.83 255.93 1879.97 1673.47 - 284.35 - 1106.51 343403.14 2465738.74 60 °44'46.539 "N 150 W 1.46 - 113.31 0.08 -1.77 1142.46 2396.00 55.72 255.62 1915.97 1709.47 - 297.35 - 1157.80 343351.68 2465726.42 60 °44'46.410 "N 150°5231.921'W 0.44 -17.66 -0.17 -0.48 1195.37 2460.00 55.85 255.57 1951.96 1745.46 -310.52 - 1209.06 343300.26 2465713.93 60 °44'46.281 "N 150 °52'32.952'W 0.21 -95.20 0.20 -0.08 1248.30 2524.00 55.72 253.64 1987.95 1781.45 -324.56 - 1260.08 343249.06 2465700.56 60 °44'46.142 "N 150°52'33.978'W 2.50 146.15 -0.20 -3.02 1301.21 2588.00 55.17 254.09 2024.25 1817.75 -339.21 - 1310.72 343198.24 2465686.59 60 °44'45.998 "N 150°52'34.997'W 1.04 169.83 -0.86 0.70 1353.90 2652.00 53.38 254.49 2061.61 1855.11 -353.28 - 1360.73 343148.05 2465673.18 60 °44'45.859 "N 150°52'36.003'W 2.84 - 137.13 -2.80 0.63 1405.84 Page 1 of 2 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] El [° /100ft] [0/100ft] [ft] 2715.00 52.79 253.80 2099.45 1892.95 - 367.04 - 1409.18 343099.42 2465660.06 60 °44'45.724 "N 150 °52'36.978'W 1.28 - 176.25 -0.94 -1.10 1456.20 2778.00 50.10 253.57 2138.72 1932.22 -380.88 - 1456.46 343051.96 2465646.85 60 °44'45.588"N 150 °52'37.929'W 4.28 176.18 -4.27 -0.37 1505.44 2843.00 47.56 253.80 2181.50 1975.00 -394.63 - 1503.42 343004.84 2465633.73 60 °44'45.452N 150 °52'38.874W 3.92 166.63 -3.91 0.35 1554.34 2906.00 45.09 254.63 2225.01 2018.51 -407.03 - 1547.26 342960.84 2465621.91 60 °44'45.330 "N 150'5739.756'W 4.03 177.37 -3.92 1.32 1599.89 2972.00 42.73 254.79 2272.55 2066.05 - 419.10 - 1591.41 342916.54 2465610.43 60 °4445.211 "N 150 °52'40.644W 3.58 - 174.73 -3.58 0.24 1645.66 3036.00 40.01 254.40 2320.58 2114.08 -430.33 - 1632.18 342875.62 2465599.74 60 °44'45.100"N 150'52'41.464W 4.27 162.38 -4.25 -0.61 1687.95 3100.00 38.39 255.23 2370.17 2163.67 -440.93 - 1671.22 342836.45 2465589.66 60 °44'44.996"N 150 °52'42.2451N 2.66 - 172.31 -2.53 1.30 1728.39 3163.00 36.37 254.77 2420.23 2213.73 -450.82 - 1708.16 342799.38 2465580.25 60 °44'44.898"N 150 °52'42.993'W 3.24 - 161.46 -3.21 -0.73 1766.63 3231.00 33.44 252.98 2475.99 2269.49 -461.61 - 1745.54 342761.87 2465569.97 60 °44'44.792"N 150 °52'43.744'W 4.56 162.00 -4.31 -2.63 1805.52 3295.00 31.11 254.45 2530.10 2323.60 -471.20 - 1778.33 342728.95 2465560.81 60 °4444.698 "N 150 °52'44.404'W 3.84 - 175.59 -3.64 2.30 1839.68 3360.00 28.57 254.04 2586.48 2379.98 -479.98 - 1809.46 342697.71 2465552.44 60 °4444.611 "N 150 °52'45.030 "W 3.92 - 173.31 -3.91 -0.63 1872.01 3424.00 26.13 253.39 2643.32 2436.82 -488.22 - 1837.68 342669.38 2465544.58 60 °44'44.530"N 150 °52'45.598'W 3.84 168.93 -3.81 -1.02 1901.40 3487.00 23.16 254.87 2700.58 2494.08 -495.42 - 1862.94 342644.03 2465537.71 60 °44'44.459 "N 150 °52'46.106'W 4.81 164.25 -4.71 2.35 1927.66 3552.00 20.87 256.69 2760.83 2554.33 -501.42 - 1886.55 342620.35 2465532.02 60 °44'44.400"N 150°52'46.581"W 3.68 168.42 -3.52 2.80 1952.02 3616.00 18.13 258.50 2821.16 2614.66 -506.03 - 1907.41 342599.44 2465527.69 60 °4444.354 "N 150 °5247.001'W 4.38 168.73 -4.28 2.83 1973.36 3680.00 16.09 259.97 2882.32 2675.82 -509.56 - 1925.90 342580.90 2465524.41 60 °4444.320"N 150 °52'47.375W 3.26 171.60 -3.19 2.30 1992.15 3745.00 13.87 261.34 2945.11 2738.61 -512.30 - 1942.47 342564.29 2465521.88 60 °4444.293"N 150 °52'47.706'W 3.46 - 172.25 -3.42 2.11 2008.88 3809.00 11.60 259.80 3007.53 2801.03 -514.60 - 1956.39 342550.35 2465519.77 60 °4444.270"N 150 °52'47.986'W 3.59 - 164.97 -3.55 -2.41 2022.93 3873.00 8.87 254.99 3070.51 2864.01 -517.02 - 1967.49 342539.21 2465517.50 60 °4444.246"N 150 °52'48.210'W 4.47 - 165.04 -4.27 -7.52 2034.28 3937.00 6.74 250.08 3133.91 2927.41 -519.57 - 1975.79 342530.88 2465515.06 60 °44'44.221 "N 150 °52'48.377'W 3.48 - 162.68 -3.33 -7.67 2042.95 4002.00 5.45 245.79 3198.54 2992.04 -522.14 - 1982.19 342524.45 2465512.57 60 °4444.196"N 150 °52'48.505W 2.10 - 171.29 -1.98 -6.60 2049.79 4067.00 3.99 242.56 3263.32 3056.82 -524.45 - 1987.02 342519.60 2465510.33 60 °4444.173"N 150 °52'48.602 "W 2.28 172.15 -2.25 4.97 2055.04 • 4131.00 0.94 270.13 3327.25 3120.75 -525.47 - 1989.52 342517.08 2465509.34 60 °44'44.163 "N 150 °5248.653'W 4.98 153.13 -4.77 43.08 2057.72 4196.00 1.09 40.32 3392.25 3185.75 -525.00 - 1989.65 342516.96 2465509.81 60 °4444.168"N 150 °52'48.655 "W 2.83 -51.44 0.23 200.29 2057.73 4260.00 1.17 35.64 3456.24 3249.74 -524.00 - 1988.88 342517.74 2465510.80 60 °4444.177 "N 150 °52'48.640 "W 0.19 54.60 0.13 -7.31 2056.73 4324.00 1.30 43.05 3520.22 3313.72 -522.94 - 1988.00 342518.63 2465511.85 60 °4444.188 "N 150 °5248.622'W 0.32 -20.23 0.20 11.58 2055.62 4389.00 1.44 41.01 3585.20 3378.70 -521.79 - 1986.96 342519.69 2465512.99 60 °44'44.199 "N 150 °5248.601'W 0.23 14.40 0.22 -3.14 2054.32 4453.00 1.47 41.31 3649.18 3442.68 -520.56 - 1985.89 342520.77 2465514.20 60 °4444.211 "N 150 °52'48.580'W 0.05 -41.19 0.05 0.47 2052.98 4517.00 1.55 38.77 3713.16 3506.66 -519.27 - 1984.81 342521.87 2465515.48 60 °4444.224"N 150 °52'48.558'W 0.16 -50.22 0.13 -3.97 2051.60 4582.00 1.61 36.27 3778.14 3571.64 -517.85 - 1983.72 342522.98 2465516.88 60 °4444.238"N 150 °52'48.536'W 0.14 177.76 0.09 -3.85 2050.19 4646.00 1.46 36.50 3842.11 3635.61 -516.47 - 1982.70 342524.02 2465518.25 60 °4444.257'N 150 °52'48.516'W 0.23 -20.45 -0.23 0.36 2048.86 4707.00 1.57 35.01 3903.09 3696.59 -515.16 - 1981.76 342524.98 2465519.55 60 °44'44.264 "N 150 °5248.497'W 0.19 0.00 0.18 -2.44 2047.62 4760.00 1.57 35.01 3956.07 3749.57 -513.97 - 1980.92 342525.83 2465520.72 60 °44'44.276 "N 150 °5248.480W 0.00 0.00 0.00 0.00 2046.52 Projected Data - NO SURVEY • Page 2 of 2 1 1 r � } y SARAN PAULA, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COM tHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 Timothy Brandenburg FAx (907) 276 -7542 Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Swanson River Unit, Sterling /Upper Beluga Oil Pool, SRU 211 -33 Sundry Number: 308 -439 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this I day of December, 2008 Encl. • STATE OF ALASKA 1 '' ? " `� (" `L�t� ALASKA OIL AND GAS CONSERVATION COMMISSION ()A - APPLICATION FOR SUNDRY APPROVAL - X 10 1 20 AAC 25.280 1. Type of Request: Abandon El Suspend ❑ Operational shutdown Ell Perforate 1=1 Waiver ❑ Other ❑ Alter casing Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ A Change approved program Pull Tubing Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 , Exploratory ❑ 208 -152 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 133 - 20581 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Swanson River Unit (SRU) 211 -33 , 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): Q k ".∎ % y � � A- 028399 [Swanson River Unit] 20.5' Swanson River Unit / Upper Beluga (tz 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4,760' 3,956' 4,760' 3,956' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 16" 102' 102' Surface 2,095' 9 -5/8" 2,095' 1,746' 5,750 psi 3,090 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 15. Estimated Date for 12/4/2008 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ Plugged El - Abandoned 0 17. Verbal Approval: Date: % ( RA' ' 12/4/2008 WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: `,Crst'C. tic - (rte 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ronnie Santos 263 -7978 Printed Name Timothy C. Brandenburg Title Drilling Manager Phon 276 -7600 Date 12/5/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: W r- aq Plug Integrity V BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance K. Other: cerN � e `` ��C -- v.;c \HISS SJ S \ V k O Cc��F O t,. C`VCG'rGY Lz S o rA' s— v M. C! -- 005 Subsequent Form Required: }„1 i \V . f ' pj APPROVED BY Approved by: Nr COMMISSIONER THE COMMISSION Date: 1 21 1 l ) gr Form 10 -403 Revised 06/2006 F' P AM Ft E'," L 5 700i1 Submit in Duplicate . ..v i 4 Si r t '., .. • S Chevron Well Name: SRU 211 -33 Field: Swanson River Completion: Curent 12/4/2008 RKB: 206.5' GL: 186.0' — Driven I J Conductor: 16 ", 109 ppf, X -56 to 102' MD 12 -1/4" Hole 2106' MD / 1752' TVD Surface Casing: 9 % ", 40 ppf, L -80, BTC to 2095' MD / 1746' TVD Disposal Zones used in Offset wells: Zone 1: 2753' MD / 2120' TVD Zone 2: 3186' MD / 2438' TVD 8 -1/2" Hole Geologic Tops: 4760' MD / 3956' TVD Sterling A -10: 3298' MD / 2532' TVD Sterling B -2: 3600' MD / 2809' TVD Sterling B -3: 3696' MD / 2895' TVD Sterling B -5: 3903' MD / 3107' TVD Sterling B -6: 4096' MD / 3286' TVD Beluga 36 -9A: 4344' MD / 3536' TVD Beluga 36 -9: 4381' MD / 3578' TVD Beluga 38 -4: 4580' MD / 3776' TVD Beluga 39 -1: 4622' MD / 3822' TVD MD PBTD = 4760' MD Bottom Top TD = 4760' MD Plug 1 4760 4160 Plug 2 4160 3560 Plug 3 3560 2960 Plug 4 2960 2600 Will tag with 10K Retainer 2000 100' squeeze below shoe Cement below 2195 2000 WBD SRU 211 -33 As Built v0.xls December 4, 2008 Drawn by: RSN • Chevron Well Name: SRU 211 -33 Field: Swanson River Completion: Proposed ABN 12/4/2008 RKB: 206.5' GL: 186.0' Driven I 150' CMI� Conductor: 16 ", 109 ppf, X -56 to 102' MD 12 -1/4" Hole 2106' MD /1752'TVD 1 _150' CMT 9 Surface % "40 ppf, Casing: , L -80, BTC to 2095' MD / 1746' TVD Disposal Zones used in Offset wells: Zone 1: 2753' MD / 2120' TVD Zone 2: 3186' MD / 2438' TVD 8 -1/2" Hole Geologic Tops: 4760' MD / 3956' TVD Sterling A -10: 3298' MD / 2532' TVD Sterling B -2: 3600' MD / 2809' TVD Sterling B -3: 3696' MD / 2895' TVD Sterling B -5: 3903' MD / 3107' TVD Sterling B -6: 4096' MD / 3286' TVD Beluga 36 -9A: 4344' MD / 3536' TVD Beluga 36 -9: 4381' MD / 3578' TVD Beluga 38 -4: 4580' MD / 3776' TVD Beluga 39 -1: 4622' MD / 3822' TVD MD PBTD = 4760' MD Bottom Top TD = 4760' MD Plug 1 4760 4160 Plug 2 4160 3560 Plug 3 3560 2960 Plug 4 2960 2600 Will tag with 10K Retainer 2000 WBD SRU 211 -33 ABN.xls December 4, 2008 Drawn by: RSN • • Operations Summary Prior to drilling operations commencing, 16" 109 ppf, X -56 grade conductor was installed on location. 121/4" hole to a depth of 2106' MD / 1752' TVD. 9%" 40 ppf, L -80 BTC was run to a depth of 2095' MD / 1746' TVD and cemented with cement returns to surface. A pressure tested was performed on the 9 casing to 2000 psi. Picked up 8'/2" BHA and drilled out shoe and rat hole. Drilled to a depth of 2125' MD / 1763' TVD and performed a FIT to 12.5 ppg EMW. The well was drilled to a total depth of 4760' MD / 3956' TVD. Logs were run and the well was deemed uneconomical for completion. Objectives ➢ Abandon current well with cement plugs across porous intervals. ➢ Set cement retainer and dump cement on top. ➢ Set surface plug. Procedure for Abandonment 1. Trip in the hole to 4760' with 4" XT -39 Drill Pipe w/ Mule Shoe on bottom. Circulate and condition mud to prepare for cement job. 2. Hold PJSM w /Schlumberger and rig crews. Rig up cement equipment. Mix and pump balanced plug from 4760' to 4160'. 3. Slowly pull out of plug to approx 4150' standing back drill pipe. 4. Circulate the long way to clean the hole and drill pipe of excess cement. Take cement returns to a cutting tank. Be prepared to retard cement at surface. 5. Hold PJSM w /Schlumberger and rig crews. Rig up cement equipment. Mix and pump balanced plug from 4150' to 3550'. 6. Slowly pull out of plug to approx 3540' standing back drill pipe. 7. Circulate the long way to clean the hole and drill pipe of excess cement. Take cement returns to a cutting tank. Be prepared to retard cement at surface. 8. Hold PJSM w /Schlumberger and rig crews. Rig up cement equipment. Mix and pump balanced plug from 3540' to 2940'. 9. Slowly pull out of plug to approx 2930' standing back drill pipe. 10. Circulate the long way to clean the hole and drill pipe of excess cement. Take cement returns to a cutting tank. Be prepared to retard cement at surface. 11. Hold PJSM w /Schlumberger and rig crews. Rig up cement equipment. Mix and pump balanced plug from 2930' to 2570'. 12. Slowly pull out of plug to approx 2550' standing back drill pipe. 13. Circulate the long way to clean the hole and drill pipe of excess cement. Take cement returns to a cutting tank. Be prepared to retard cement at surface. 14. Begin laying down drill pipe while waiting on cement. WOC time will be determined by lab results from SLB. 15. Trip in the hole 2500' MD. Wash in hole to top of cement. Tag cement plug @2570' with 10K down. Pull out of hole and lay down mule shoe. Note: Contact AOGCC and BLM inspectors to witness cement plug test. 16. Trip out of the hole lay down Mule Shoe. 17. Hold PJSM w/Halliburton, Schlumberger and Nabors. Pick up 9%" 40# cement retainer. Run in hole as per Halliburton and set @2000' MD. The retainer must be set between 50' - 100' from the shoe. • • 18. Set Cement retainer @2000' MD and test retainer and casing to 1000 psi for 30 minutes and chart as per Halliburton recommendations. Note: Contact AOGCC and BLM inspectors to witness casing and retainer test. 19. Hold PJSM w /Schlumberger, Halliburton and Nabors. Unsting from retainer and spot 50' of cement on top of retainer. 20. Pull out of cement and circulate the long way to clean the casing and drill pipe of excess cement. Take cement returns to a cutting tank. Be prepared to retard cement at surface. 21. Pull out of hole laying down drill pipe to surface plug setting depth. 22. Hold PJSM w /Schlumberger and rig crews. Rig up cement equipment. Mix and pump balanced plug from 155' to 5'. The plug must be no more than 5' below original ground level. 23. Slowly pull out of plug to surface. Wash through BOP stack and wellhead to clear any residual cement from equipment. Lay down BHA. 24. Nipple down BOP stack. 25. Nipple down wellhead system. Install well abandonment marker as per 20 AAC 25.120. The marker should extend 4' -6' above ground level. Note: Contact AOGCC and BLM inspectors to witness abandonment marker. Full abandonment will be performed in the spring as per AOGCC and BLM guidelines. • Chevron %O. Chevron-Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UINI ChevNo Original RKB (ft) Water Depth (ft) SRU 211-33 SWANSON RIVER UNIT 211-33 5013320581 LK4511 206.50 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 11/12/2008 Complete Primary Welibore Affected Wellbore UVVI Well Permit Number 5013320581-00 2081520 D 11/12/2008 00:00 - 11/13/2008 00:00 Operations Summary Mobilizing rig from SCU 312-09. 11/13/2008 00:00 - 11/14/2008 00:00 Operations Summary Mobiliziing rig on SCU 211-33 11/14/2008 00:00 - 11/15/2008 00:00 Operations Summary Mobiliziing rig on SCU 211-33 11/45/2008 00:00 - 11/16/2008 00:00 Operations Summary Mobiliziing rig on SCU 211-33 11116/2008 00:00 - 11/17/2008 00:00 Operations Summary Mobiliziing rig on SCU 211-33 11/1712008 00:00 - 11/18/2008 00:00 Operations Summary Mobiliziing rig on SCU 211-33 11#0400810:00 - 1'1/19/2008 00:00 Operations Summary Mobilizing rig on SCU 211-33 ,1414912668100:00"- 11/20/2008 00:00 Operations Summary Continue rigging up. NU BOP/Diverter. 11120/200000:00- 1112112008 00:00 irc Operations Summary Finish NU and function test diverter system and accumulator to 3,000 psi. Verify functions and alarms of all gas detectors, PVT and flow. Mix spud mud. 11/2112008 00:00 - 11/22/2008 00:00 Operations Summary PU and rack back DP and BHA components while working on genset #2. Test mud pumps and lines. 4112212008 00:00 - 11123/2008 00:00 Operations Summary PU 12-1/4" bit and DC. RIH drill vertical hole from 102 to 257 with 8.7-8.8 ppg WBM. Circulate/condition hole and POH for directional BHA. Started weighting up mud to 9.6 ppg. LD excess BHA components. 11/23/2008 00:00 - 11/24/2008 00:00 Operations Summary Finished LD excess BHA components. Weight up mud to 9.6 ppg while servicing rig and TDS. PU directional BHA and drill directional hole building inclination to 1418'MD. . „ 11/24/2008 00:00 - 11/26/200600:06 Operations Summary Drill directional hole building inclination to 56 deg to 2106'MD/1750'TVD. Circulate hole clean and POH backreaming tight spots. LD motor and MWD. 11/26/2008 00:00 - 11126/2000 00:00 Operations Summary Finish LD motor and bit. LD jar and PU new. MU and RIH with 12-1/4" hole opener to TD. RIH reaming tight spots. Circulate hole clean. POH working on tight spots. Prepare to run casing. 11/26/2008 00:00 - 11/27/2008 00:00 Operations Summary Finish LD BHA. RU casing running gears. Run 9-5/8" 40 ppf L-80 BTC casing. Land casing on WH hanger with EOC at 2095. Circulate while preparing to cement casing. 11127/2008 00:00 - 11/2812008 00:00 Operations Summary Circulate and condition hole prior to cementing. Pressure test lines to 5000 psi. Cement casing with 153 bbls of 12.5 ppg LiteCrete lead cement slurry. Had mixer problems while pumping tail. Pumped 91 bbls of 13.5 ppg- 15.8 ppg Class G tail cement. Did not bump plugs. Cement returns to surface. R/D cement gear. Installed and tested WH packoff to 5000 psi. Test BOP and gas detection system to 250/3000 psi. AOGCC (Lou Grimaldi) waived witness 17:00 11/27/2008. BLM notified without response on 11/26/2008. 41/2812008 00:00,7,11/29/2008 00:00 Operations Summary Continue BOP test. Repair and retest blind rams. All tests 250 psi/10min and 3000 psi/10min. Test accumalator. Build PHPA mud volume to 528 bbl in pits. • • Chevron %. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 211 -33 SWANSON RIVER UNIT 211 -33 5013320581 LK4511 206.50 11/29 /2008 00:00 - 11/30/2008 00:00 Operations Summary Blind rams test good after replacing seal elements. Pull test plug and install wear bushing. Test casing against blind rams. Stage pressure to 2000 psi /30min, good test. PU directional BHA and RIH with 8 -1/2" PDC bit. Tag at 1996'. Conduct man down drill and post meeting. Displace spud mud in casing with PHPA mud. Tag hard cement at 2011'. Drillout plug, float equipment, shoe, and 20' of new formation to 2125'. Conduct FIT w/ 9.2 ppg mud to 12.5 ppg EMW at 2125'MD/1763'TVD. Drill 8 -1/2" tangent hole to 2638'MD. 41/30/2008 00:00 - 12/1/2008 00:00 'Operations Summary Drill directional hole sliding as needed to drop inclination to 2875'MD. Circulate and condition hole while rig service TDS. Drill directional hole sliding as needed to 3408'MD. Circulate hivis sweep. Drill directional hole sliding as needed to 3662'MD. Coal stingers at 3509' - 3566'. Drill slide from 3662' to 3816'MD. Had difficulty sliding, work through tight spot. Circulate hivis sweep and condition hole. 1211/2008 00:00 - 12/2/2008 00:00 Operations Summary Directional drill slide as needed to 4015'MD. Work and backream tight spot at 4015'. Directional drill slide as needed to 4191'MD. Circulate hivis sweep and condition hole. Directional drill slide as needed to 4760'MD TD. Circulate and condition hole. Geologist extended bottom (Beluga) target boundary 75' to the west. Intersected bottom target 15' away from original target boundary. POH through tight spots between 4215' to 4675'. Normal drag rest of the trip to 3408'. 12/2/200800:00 - 42/3/2008 00:00 Operations Summary Short trip to shoe from 3408' to 2065'. Overpull 10K into shoe. Circulate hole and recovered some fine sand chunks of clay accross the shaker. Trip in the hole and wash ream last 64' to bottom. Work high torque bottom 25'. Circulate and condition hole for logging. Pump hivis sweep. Recovered a lot of fine sand on the shaker. Service rig and TDS. POH and LD directional BHA. RU Schlumberger Loggers. WL log with Quad Combo. No problem getting to bottom. Tag bottom no fill. Log up to casing shoe. POH and LD tools. 12/3/2008 00:00 - 12/4/2008 00:00 Operations Summary Finish logging with FMI tools. Log up to casing shoe. Lay down pipe while waiting on office (WOO). MU ABN mule shoe & RIH to shoe. WOO. Page 1 of 2 • Maunder, Thomas E (DOA) From: Santos, Ronilo [ronnie.santos @chevron.com] Sent: Tuesday, December 09, 2008 5:11 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SRU 211 -33 (208 -152) Mr. Maunder, The step 27 of the P &A procedure mentioned well abandonment marker as per 20 AAC 25.120 but also mentioned a marker that should extend above ground level. We had earlier caught that somehow conflicting statement and clarified the procedure with our superintendent. The intent of the above ground marker is for the interim time until spring. We no longer plan to install any other marker unless you will require something between now and the final abandonment of the surface structure this coming spring. Thanks, Ronnie From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, December 09, 2008 4:26 PM To: Santos, Ronilo Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SRU 211 -33 (208 -152) Ronnie, I wasn't sure there since an above ground marker was mentioned. Your explanation helps clear the issue. Tom Maunder, PE AOGCC From: Santos, Ronilo [ mailto :ronnie.santos @chevron.com] Sent: Tuesday, December 09, 2008 4:21 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SRU 211 -33 (208 -152) Mr. Maunder, The step for surface P&A is to ensure cement is as close to 5' below ground as possible. Our plan is to cut wellhead off and contact the AOGCC and BLM to witness cement top. We will weld a below ground P &A plate with the legal information in place. This coming spring we will have to shoot actual ground level in with a transit and GPS the wellhead. We will remove cellar box and then backfill the cellar box. Thanks, Ronnie From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Tuesday, December 09, 2008 2:40 PM To: Santos, Ronilo 12/10/2008 • Page 2 of 2 • Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: SRU 211 -33 (208 -152) Ronilo and Nigel, I am working on the sundry notice for the P &A of 211 -33. I am curious regarding the instruction at step 25 regarding the installation of an above ground abandonment marker. The requirement at 120 (a) is for a below grade marker plate, however it appears that Chevron does not intend to complete the P&A until next spring at the earliest. Will the wellhead remain in place until the final P &A? I look forward to your reply. Tom Maunder, PE AOGCC 12/10/2008 FW: Schematic as requested Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 03, 2008 6:15 PM To: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Schematic as requested Nigel, I have spoken with Commissioner Foerster and apprised her of youstequest. She has given her oral approval for you to proceed. I will look for the sundry tomorrow. Cali or message with any questions. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [ mailto :Nigel.Bonnett@chevron.com] Sent: Wed 12/3/2008 4:48 PM To: Maunder, Thomas E (DOA) Subject: FW: Schematic as requested Tom, Please refer to attached P &A schematic for SRU well 211 -33. , oc - 1S What we propose to do is set 4 cement plugs on top of each other from TD (4760' MD) to 4160 'MD. This will isolate all permeable porous zones in the well. The 4th plug will be weight tagged with 10K Ibs Then we plan to set a retainer, with 100 ft squeeze below the retainer & 50' of cement on top of it. Finally we will set a 500 ft surface plug. I will phone to discuss to get initial concurrence. We will submit full sundry tomorrow. Rgds, Nigel From: Nash, R Scott Sent: Wednesday, December 03, 2008 4:41 PM To: Bonnett, Nigel (Nigel.Bonnett) Subject: Schematic as requested «WBD SRU 211 -33 As Built v0.xls» Scott Nash • Advisor Drilling Engineer snas @chevron.com 12/4/2008 . i Chevron Well Name: SRU 211 -33 Field: Swanson River 1100 Completion: As Built 20081203 RKB:206.5' GL: 186.0' Driven J __ L Conductor: 16 ", 109 ppf, X -56 to 102' MD 12 -1/4" Hole 2106' MD / 1752' TVD Surface Casing: 8-1/2" Hole I I 9 % ", 40 ppf, L -80, BTC to 2095' MD / 1746' TVD 4760' MD / 3956' TVD Disposal Zones used in Offset wells: Zone 1: 2750' MD / 2120' TVD Zone 2: 3170' MD / 2438' TVD -4 -iA L--k Geologic Tops: Sterling A -10: 3298' MD / 2532' TVD Sterling B -2: 3600' MD / 2809' TVD Sterling B -3: 3696' MD / 2895' TVD Sterling B -5: 3903' MD / 3107' TVD y,S Sterling B -6: 4096' MD / 3286' TVD Beluga 36 -9A: 4344' MD / 3536' TVD Beluga 36 -9: 4381' MD / 3578' TVD Beluga 38-4: 4580' MD / 3776' TVD Beluga 39 -1: 4622' MD / 3822' TVD N IA- IL MD Bottom Top Plug 1 4760 4160 - Plug 2 4160 3560 PB1 D = 4760' MD Plug 3 3560 2960 TD = 4760' MD Plug 4 2960 2600 Will tag with '10K Retainer 2000 100' squeeze below retainer Cement 2000 1950 WBD SRU 211 -33 As Built v0.xls October 23, 2008 Drawn by: STP FW: Schematic as requested Page 1 of 3 A • • `� Maunder, Thomas E (DOA) From: Grimaldi, Louis R (DOA) Sent: Tuesday, December 09, 2008 6:04 PM To: Maunder, Thomas E (DOA) Subject: RE: 211 -33 (208 -152) P&A - Verbal Approval Tom, I was not concerned, other than I warned them if it was not as they said they may have to drill up the plugs. I still (personally) think they should have spotted a plug across the shoe. 1 dont understand their reluctance to do that. A plug up inside the casing does nothing to protect the shoe and any aquifers above. I realize 1 may not know everything involved here so feel free to school me. Lou From: Matins Thomas E (DOA) Sent: Mon 12/8 408 10:27 AM To: Bonnett, Nigel O'•el.Bonnett) Cc: Nash, R Scott; Ham • ns, Darrell; Grimaldi, Louis R (DOA) Subject: RE: 211 -33 (208 - ) P&A - Verbal Approval Nigel, My lapse for not following up with an e - it documenting our • •-cussion last Thursday. Our discussion was prompted by Mr. Grimaldi's call to me reg. •ing maintainin• he integrity of the surface casing shoe. Sounds like all work went well. Call or messa. - with an • uestions. Tom Maunder, PE AOGCC From: Bonnett, Nigel ( Nigel.Bonnett) [mail .:Nigel.Bonnett@ch-. ron.com] Sent: Monday, December 08, 2008 10: AM To: Maunder, Thomas E (DOA) Cc: Nash, R Scott; Hammons, Dar : Subject: 211 -33 P&A - Verbal A 'royal Morning Tom, Just to confirm, we ga the Drill Site Manager at Rig 106, instructions to set the Bridge Plug • ide the 9 -5/8" casing and then sp. 50 ft of cement on top, based on our discussions and your verbal approval • • Thursday 4th December. As w- discussed Thursday, we did not break down the 9 -5/8" shoe to squeeze cement. On location r Grimaldi (AOGGC witness) expressed some concerns that we did not have an email from y• • to docume his change - though we did document it internally with email to Rig 106, which Mr Grimaldi was sho • . Th- &A sundry for well 211 -33 was submitted Friday 5th December. Apologies if there was any confusion over the P &A plan. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, December 03, 2008 6:15 PM To: Bonnett, Nigel (Nigel.Bonnett) 6/16/2009 Page 1 of 1 . • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 09, 2008 2:40 PM To: Santos, Ronilo Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: SRU 211 -33 (208 -152) Ronilo and Nigel, I am working on the sundry notice for the P&A of 211 -33. I am curious regarding the instruction at step 25 regarding the installation of an above ground abandonment marker. The requirement at 120 (a) is for a below grade marker plate, however it appears that Chevron does not intend to complete the P&A until next spring at the earliest. Will the wellhead remain in place until the final P &A? I look forward to your reply. Tom Maunder, PE AOGCC 6/16/2009 FW: Schematic as requested Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 08, 2008 10:27 AM To: 'Bonnett, Nigel (Nigel.Bonnett)' Cc: Nash, R Scott; Hammons, Darrell; Grimaldi, Louis R (DOA) Subject: RE: 211 -33 (208 -152) P &A - Verbal Approval Nigel, My lapse for not following up with an email documenting our discussion last Thursday. Our discussion was prompted by Mr. Grimaldi's call to me regarding maintaining the integrity of the surface casing shoe. Sounds like all work went well. Call or message with any questions. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [ mailto :Nigel.Bonnett @chevron.com) Sent: Monday, December 08, 2008 10:23 AM To: Maunder, Thomas E (DOA) Cc: Nash, R Scott; Hammons, Darrell Subject: 211 -33 P&A - Verbal Approval Morning Tom, Just to confirm, we gave the Drill Site Manager at Rig 106, instructions to set the Bridge Plug inside the 9 -5/8" casing and then spot 50 ft of cement on top, based on our discussions and your verbal approval on Thursday 4th December. As we discussed Thursday, we did not break down the 9 -5/8" shoe to squeeze cement. On location, Mr Grimaldi (AOGGC witness) expressed some concerns that we did not have an email from you to document this change - though we did document it internally with email to Rig 106, which Mr Grimaldi was shown. The P &A sundry for well 211 -33 was submitted Friday 5th December. Apologies if there was any confusion over the P &A plan. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, December 03, 2008 6:15 PM To: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Schematic as requested Nigel, I have spoken with Commissioner Foerster and apprised her of you request. She has given her oral approval for you to proceed. t will look for the sundry tomorrow. Call or message with any questions. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [mailto:Nigel.Bonnett@chevron.com] Sent: Wed 12/3/2008 4:48 PM To: Maunder, Thomas E (DOA) 12/8/2008 FW: Schematic as requested • Page 2 of 2 • Subject: FW: Schematic as requested Tom, Please refer to attached P &A schematic for SRU well 211 -33. What we propose to do is set 4 cement plugs on top of each other from TD (4760' MD) to 4160 'MD. This will isolate all permeable porous zones in the well. The 4th plug will be weight tagged with 10K lbs Then we plan to set a retainer, with 100 ft squeeze below the retainer & 50' of cement on top of it. Finally we will set a 500 ft surface plug. I will phone to discuss to get initial concurrence. We will submit full sundry tomorrow. Rgds, Nigel From: Nash, R Scott Sent~ Wednesday, December 03, 2008 4:41 PM To: Bonnett, Nigel (Nigel.Bonnett) Subject Schematic as requested «WBD SRU 211 -33 As Built v0.xls» Scott Nash • Advisor Drilling Engineer snas @chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 - 263 -7997 Fax 907 - 263 -7884 12/8/2008 . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: December 7, 2008 P.I. Supervisor ke7 i 2 SUBJECT: Plug & Abandonement THRU: SRU 211 -33 Unocal Swanson River Field FROM: Lou Grimaldi Swanson River Unit Petroleum Inspector PTD #208 -152 NON- CONFIDENTIAL Section: 33 Township: 8N Range: 9W Meridian: Seward Lease No.: A- 028399 Drilling Rig: NAD 106E Rig Elevation: 20.5 Total Depth: 4760' Operator Rep.: Floyd Hurt Casing/Tubing Data: Casing Removal: Conductor: 16" O.D. Shoe@ 82' Casing Cut@ Feet Surface: 9 5/8 O.D. Shoe@ 2095 Casing Cut@ Feet Intermediate: None O.D. Shoe@ Casing Cut@ Feet Production: None O.D. Shoe@ Casing Cut@ Feet Liner: None O.D. Shoe@ Casing Cut@ Feet Tubing: None O.D. Tail@ Casing Cut@ Feet Plugging Data: Type Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom up) of Cement Depth Verified? above plug Test Applied Zonal Isolation I Bottom 4760 1 1 2430.58 I Tagged (LG) 9.8 No Shoe C.I.B.P. 2000 1915 No 9.8 CIBP 1000psi I I I Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface Original tag of Zonal 'so plug too deep at 2746' (RKB), top of injection interval @ 2750'. Pumped additional 25 bbl's cement and tagged 14 hours later. Tag w /4" DP at 2430.58' (RKB), set 15K down while circulating. Good plug, POOH. PU HES C.I.B.P. and set at 2000 (Float Collar @ 2010). Pressure test to 1100 psi for thirty minutes, OK. Tag C.I.B.P. again at 2000 feet for verification. Attachments: none Distribution: Well File (original) Read File DNR /DOG Rev.:5 /28/00 by L.R.G. 2008 - 1207_ P &A_SRU_211- 33_plug_test_Ig.xls 1 SARAH PALIN, GOVERNOR �7 ALASKA OIL I AND S 333 W 7th AVENUE, SUITE 100 CONSERVATION C®m� 1` LSSI ® ANCHORAGE, ALASKA 99501 -3539 ►7iJ PHONE (907) 279 -1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage AK 99519 Re: Swanson River Field, Sterling Upper Beluga Gas, SRU 211 -33 UNOCAL Permit No: 208 -152 Surface Location: 468' FNL, 2107' FWL, SEC. 33, T8N, R9W, SM Bottomhole Location: 977' FNL, 171' FWL, SEC. 33, T8N, R9W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill 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, Daniel T. Seamount, Jr. Chair DATED this day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVED `e ALA* OIL AND GAS CONSERVATION COMSION n 4 : , 3 PERMIT TO DRILL to( ' " 20 AAC 25.005 , h' ka Oil & Gas (t�r� . L:;t�i ril a,,,,�, Ji 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development 00 ❑ 1 c. Speci i e is proposk fig. � Drill El Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas El Coalbed Methane ❑ ' & a3 lydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone El Shale Gas ❑ 2. Operator Name: 5. Bon £ Blanket 0 Single Well El 11. Well Name and Number: Union Oil Company of California) Bond N BCM . i t „J SRU 211 -33 3. Address: 6. Proposed Depth:J MY ` 12. Field /Pool(s): PO Box 196247, Anchorage, Alaska, 99519 MD: 4652 TVD: 3833 Swanson River Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Sterling /Upper Beluga Surface: 468 FNL, 2107' FWL, Sec 33, T8N, R9W, SM A- 028399 (Outside Unit and PA Boundary) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 952 FNL, 265' FWL, Sec 33, T8N, R9W, SM N/A 10/23/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 977 FNL, 171' FWL, Sec 33, T8N, R9W, SM 1760 Property: 171 feet 4b. Location of Well (State Base Plane Coordinates):^/�Q O ✓ 3 - 10. KB Elevation 15. Distance to Nearest Well Surface: x- 1 484,53 y-7„(3,25}170)74$ ) Zone- ASP 4 (Height above GL): 20.5 feet Within Pool: 1856 16. Deviated ti�s " ' ' vkic�COf � �/ 300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: 1687 Surface: 1303 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) Driven 16 109 X -56 Weld 102 0 0 102 102 Driven (not cemented) 12 -1/4 9 -5/8 40 L -80 BTC 2200 0 0 2200 1745 252 bbls (100% excess) 8 -1/2 7 26 L -80 BTC -Mod 4652 0 0 4652 3833 86 bbls (50% excess) 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 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch el Drilling Program 0 Time v. Depth Plot 0 Shallow Hazard Analysis ❑ Property Plat el Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program MI 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Stan Porhola Printed Name Tim Brandenburg Title Drilling Manager Signature C Phone 263 -7640 Date 10/14/2008 ✓' Commission Use Only Permit to Drill API Numb= . Permit Approva' See cover letter for other Number: ���' � � . 50- ,33 - . )►5 t - 0 7 Date: 10 dC) Cgg requirements. If box is checked, well may not be used to explore for, test, or produce coalbed methane, ga hydrates, or gas contained in shales: Conditions of approval : Samples req'd: Yes❑ No Mud log req'd: Yes No' H measures: Yes❑ No ler Directional svy req'd: YesW No❑ Other: r , APPROVED BY THE COMMISSION i� ? Or r DATE' , COMMISSIONER s l p orm 10-401 Revised 12/2005 , Submit in D u licate • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel m a it 7657 E b r and Email bandenburgt @chevron.com October 14, 2008 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 RECE VED Re: Permit to Drill 10 -401 revised 1 Swanson River Unit, SRU 211 -33 Gas Development Well OCT 1 4 2008 Mr. Maunder: Alaska (ail & _p mrr�isslor t � ' unit SR Enclosed for your approval is a revised Permit to Drill (form 10 -401) for the Swanson River nrt U 211 -33 Gas Development Well. Per AOGCC's review of the initial Permit to Drill package, we are revising the following: 1.) Surface Casing set depth moved from 2000' MD / 1643' TVD to 2200' MD / 1745' TVD. 2.) BOP Test pressures of 3000/250 psi. The change to the Surface Casing set depth is based on Area Injection Order #13 which exempts fresh water aquifers below 1700' TVD in the Swanson River Field. The Surface Casing set depth is being revised to isolate the non- exempt fresh water aquifers above 1700' TVD. No changes will be made to the directional plan. These revisions have been made to the permit form (10 -401), procedure, well schematic, depth vs. time curve, casing design, MASP, cement program and mud program. We are still targeting a spud date of October 23 Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Mr. Stan Porhola at 263- 7640. Sincerely, Timothy : randenburg Drilling Manager TCB: stp Attachments: PTD Package revised Cc: Well File Engineer File — Stan Porhola Environmental — Rich Vicente Union Oil Company of California / A Chevron Company http: / /www.chevron.com Chevron • • 111110 Swanson River Unit SRU 211 -33 Gas Well Drilling Procedure Summary 1. Prepare location. Drill and drive 16" conductor casing to +/- 102' MD w/ Kraxberger truck rig. Set cellar. Install multi -bowl wellhead. 2. MIRU Nabors #106E drilling rig. 3. NU and function test Diverter. 4. PU drillpipe and 12 -1/4" bit and directional BHA. 5. RIH and clean -out 16" conductor. 6. Drill 12 -1/4" hole with 8.6 -9.2 ppg water -based spud mud to casing point at +/- 2200'. Utilize BHA w/ MWD only. 7. Condition hole and POOH. Laydown bit and BHA. 8. RU and run 9 -5/8" casing. 9. MU and test cement lines. Circulate and cement casing bringing cement to surface. Bump top plug and test casing to 2000 psi. 10. Deactivate diverter system and activate BOPE equipment. Test BOPE to 3000 psi /250 psi. 11. MU 8 -1/2" directional BHA and RIH. Drill out float equipment, and 20' of new formation. Pull back into the casing and conduct a leak - off test or FIT test to 13.0 ppg EMW. 12. Directionally drill 8 -1/2" hole to TD at +/- 4,652' MD / 3,833' TVD with 9.0 -9.5 ppg water -based mud. Utilize BHA w/ MWD and GR. 13. Condition hole and POOH. Laydown bit and BHA. 14. RU and run open hole logging suite (Quad Combo: GR -Res, Den, Neu, Son) from TD to 7" shoe. Run FMI (Formation Micro Imager) from TD to 7" shoe. 15. RU and run 7" casing. 16. MU and test cement lines. Circulate and cement casing bringing cement to previous shoe. Bump plug and test casing to 2000 psi. 17. RIH w/ cleanout assembly and displace mud to 6% KCI brine. POOH. 18. If cement coverage is questionable, a USIT (Ultra Sonic Imaging Tool) will be run to evaluate cement coverage and bond. 19. Set sump packer on E -line at 3870' MD. RIH w/ TCP guns. Perforate Sterling B -5 (3840' -3850' MD). POOH. 20. RIH w/ Gravel Pack running tool and screen assembly. Gravel Pack Sterling B -5 sand w/ 20/40 Ottawa sand. POOH w/ running tool. 21. Repeat TCP and Gravel Pack procedure for Sterling B -3 sand (3635' -3645' MD) and Sterling B -2 sand (3531' -3541' MD). 22. RIH w/ 2 -7/8" tubing. Circ packer fluid. Space out and land tubing. 3 Drilling Procedure Summary SRU 211- 33.doc 1 10/14/2008 Chevron • • IWO Swanson River Unit %10. SRU 211 -33 Gas Well Drilling Procedure Summary 23. Test tubing to 2000 psi and tubing x casing annulus to 1500 psi. 24. ND BOPE. NU and test tree to 5000 psi. Release Rig. 25. RU slickline. RIH w/ weight bar and break KOIVs (Knock out isolation valves). Turn well over to production for testing. Flowline will connect well from 211 -33 to TS 1 -33 production facilities. 3 Drilling Procedure Summary SRU 211- 33.doc 2 10/14/2008 • • Chevron Well Name: SRU 211 -33 %/1111 Field: Swanson River 1%01 Completion: Proposed v2.9 RKB: 206.5' GL: 186.0' Driven ( J Conductor: 16 ", 109 ppf, X -56 to 102' MD 112-1/4" Hole' Surface Casing: 9 % ", 40 ppf, L -80, BTC to 2200' MD 8 -1/2" Hole I Production Tubing: 2 % ", 6.4 ppf, L -80, TC -II to 3488' Completion: - Chemical injection sidepocket mandrel at 2000' Isolations String: - Baker SC -1 packer at 3488' 2 % ", 6.5 ppf, L -80, Hydril 503 3507-3558' MD - Excluder 2000 (Med) Screen 3517' -3555' 2%", 6.5 ppf, L -80, Hydril 503 3614' -3665' MD - Baker SLCMD sliding sleeve at 3517' (Closed) 2 % ", 6.5 ppf, L -80, Hydril 503 3819' -3870' MD 2.313" X- profile - S -22 Seal assembly at 3558' - Baker SC -1 packer at 3558' � �� Geologic Tops: - Excluder 2000 (Med) Screen 3624' -3662' ;t « . Sterling B -2: 3531' MD / 2721' TVD Baker SLCMD sliding sleeve at 3624' (Closed) Sterling B -3: 3635' MD / 2821' TVD 2.313" X- profile Vii; 000 j•'- 8-2 Sterling B -5: 3840' MD / 3022' TVD - S -22 Seal assembly at 3665' Beluga 39_1ST: 4523' MD / 3703' TVD Zak - Baker SC -1 packer at 3665' . ?Al TD: 4652' MD / 3833' TVD - Excluder 2000 (Med) Screen 3829' -3867' ;hi i, - Baker SLCMD sliding sleeve at 3829' (Closed) Fife. 2.313" X- profile •: ∎ 000'® j B -3 i i. r Geologic Pressures - S -22 Seal assembly at 3870' Sterling A: 8.5 ppg EMW - Baker FS sump packer at 3870' ;; $�;i; Sterling B -2: 7.8 - 8.1 ppg EMW •r•r r•r•. Sterling B -3: 7.8 - 8.1 ppg EMW '''r" Sterling B -5: 7.8 - 8.1 ppg EMW ..... y }M1r1: Proposed Perforations: D00 is Sterling 8-2: 3531' - 3541' MD= B -5 Sterling B -3: 3635' - 3645' MD � � Bottom Hole Temperatures Sterling B -5: 3840' - 3850' MD Sterling B -2: 73 °F Sterling B -3: 74 °F Sterling B -5: 76 °F Production Casing: PBTD = 4567' MD 7 ", 26 ppf, L -80, BTC -Mod to 4652' MD TD = 4652' MD 4.xls October 14, 2008 Drawn by: STP r SRU 211 -33 Chevron Depth vs. Time -- Drilling Time MIRU Nabors 1000 106E • 12 -1/4" Hole 2000 9 - 5/8" Casing 3000 8 - 1/2" Hole 4000 i 5000 / P Open Hole Logs 7" Casing Gravel Pack DeMobe Completion Nabors 106E 6000 0 5 10 15 20 25 30 35 Time (Days) • m eg Chevron Maximum Anticipated Surface Pressure Calculation Swanson River SRU 211 -33 Kenai Peninsula, Alaska Assumptions: 1. Based on offset drilling & production data, the pore pressure gradient is predicted to be 0.404 to 0.440 psi /ft in the Sterling A & B sands with a 0.440 psi /ft gradient in the Beluga at a total depth of 3,833' TVD RKB. 2. The M.A.S.P. during drilling operations will be governed by the 9 -5/8" shoe frac gradient, and is calculated based on a full column of gas between the 9 -5/8" shoe and the surface. The shoe f or SRU 211 -33 at 1745' TVD will be above the shoe depths of recent offset wells in Swanson River, ranging from 1950' to 2023' TVD. Leak -off or formation integrity tests ranged from 14.3 ppg to 21.1 ppg (0.744 psi /ft and 1.100 psi /ft). This offset LOT /FIT data from nearby wells useful for relatively accurate kick tolerance & MASP calculations. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Life: Max. pore pressure at T.D. = 3,833 ft. x 0.440 psi /ft = 1687 psi M.A.S.P. (tbg leak at surface) = 1687 psi - (0.1 psi /ft * 3,833 ft) = = 1303 psi M.A.S.P. While Drilling 8 -1/2" hole at 3,833' TVD: Max. Est. Frac pressure at 9 -5/8" shoe = 1745 ft. x 0.68 psi /ft = 1187 psi M.A.S.P. during drilling = 1187 psi - (0.1 psi /ft x 1745 ft.) = = 1012 psi Calculation & Casing Design Factors 1 Chevron Swanson River SRU 211-33 Kenai Peninsula, Alaska WELL: SRU 211 -33 FIELD: Swanson River DATE: 14-Oct-08 DESIGN BY: Stan Porhola Sect. 1 12 1/4" hole MUD WT. 9.0 PPG MASP =1012 psi " Sect. 2 8 1/2" hole MUD WT. 9.3 PPG MASP= 1,303psi 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 P51' PSI SF COLL. PSI** P I SF BURST 1 9-5/8" 2,200 0 2200 40 L -80 BTC 88,000 88,000 916 10.41 789 3,090 3.92 1,012 5,750 6.68 TVD 1,745 0 2 7" 4,652 0 4652 26 L -80 BTC 120,952 120,952 604 4.99 1,733 5,410 3.12 1,303 7,240 6.66 TVD 3,833 0 • Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.440 psi/ft) and the casing evacuated for the intemal stress (0 psi/ft) • See attached sheet for calculation of MASP 0 Chevron • 11.01 Swanson River Unit SRU 211 -33 Gas Well Cement Program 16" Casing (Driven to +/ -102') Note: This string is only for structural support of the wellhead and diverter system. 9 -5/8" Casino (12 -1/4" Hole to 2,200' MD): Cement volume based on annular volume plus 100% open hole excess and shoe joint(s). The job will consist of a lead and tail and cement will be brought to surface. The estimated total volume is as follows: Lead: 1700' X 0.3132 cuft/ft (12 -1/4" x 9 -5/8 ") X 2.0 = 1065 cuft = 459 sxs (2.32 yield) Tail: 500' X 0.3132 cuft/ft (12 -1/4" x 9 -5/8 ") X 2.0 = 313 cuft = 263 sxs (1.19 yield) 80' shoe joint X 0.4257cuft/ft = 34 cuft = 29 sxs (1.19 yield) TOTAL: 1065 + 313 + 34 = 1412 cuft or 751 sxs 7" Casing (8 -1/2" Hole to 4,652' MD): Cement volume based on annular volume plus 50% open hole excess and shoe joint(s). The job will consist of a lead only and cement will be brought to 2,200' MD (Previous shoe). The estimated total volume is as follows: Lead: 2,452' X 0.1268 cuft/ft (8 -1/2" x 7 ") X 1.5 = 466 cuft = 307 sxs (1.52 yield) 80' shoe joint X 0.2148 cuft/ft = 17 cuft = 11 sxs (1.52 yield) TOTAL: 466 + 17 = 483 cuft or 318 sxs 9 Cement Program 211- 33.doc 1 10/14/2008 Chevron Swanson River Unit %10 SRU 211 -33 Gas Well Cement Program Cement Type and Design: Surface Casing, 9 -5/8 ", Lead Cement Type: Class G Density: 12.2 ppg Cement: 459 sx Yield: 2.32 ft /sx Mix Water: 13.52 gal /sx Slurry Volume: 190 bbl Additives: 0046 0.200% BWOC Antifoam S002 2.000% BWOC Accelerator D079 3.000% BWOC Extender Surface Casing, 9 -5/8 ", Tail Cement Type: Class G Density: 15.8 ppg Cement: 292 sx Yield: 1.19 ft /sx Mix Water: 5.18 gal /sx Slurry Volume: 62 bbl Additives: D046 0.200% BWOC Antifoam S002 1.000% BWOC Accelerator D153 2.000% BWOC Anti - settling Production Casing, 7 ", Lead Cement (Schlumberper LiteCRETE) Type: Class G Density: 12.5 ppg Cement: 318 sx Yield: 1.52 ft /sx Mix Water: 4.87 gal /sx Slurry Volume: 86 bbl Additives: D174 0.100% BWOC Expanding Agent D046 0.600% BWOC Antifoam D065 0.400% BWOC Dispersant D500 0.745 gal /sx GasBLOK LT D135 0.106 gal /sx GasBLOK Stabilizer 9 Cement Program 211- 33.doc 2 10/14/2008 c • Chevron %101 Swanson River Unit IMO SRU 211 -33 Gas Well Mud Program Surface Hole Recommendations Mud Type: Spud Mud (Water - based) Properties: Depth Density Viscosi Plastic Viscosity Yield Point API FL QH 0 - 2200' 8.6 -9.2 70 - 250 10 - 30 25 - 40 < 6 8.5 -9.0 System Formulation: Spud Mud (Water- based) Product Concentration Water 0.95 bbl Aquagel 25 ppb (35 - 40 YP) X -Tend II 0.10 ppb Caustic soda 0.20 ppb (9.0 pH) Soda Ash 0.20 ppb Production Hole Recommendations Mud Type: 6% KCI, EZ Mud (Water- based) Properties: Depth Density Viscosity PV YP API FL pH 2200' — TD 9.0 — 9.5 40 - 50 6 -15 18 -25 <5 8.5 — 9.5 System Formulation: 6% KCI, EZ Mud (Water- based) Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) PAC L 1 ppb Dextrid 1 ppb EZ Mud DP 0.75 ppb (.15 initially) Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb (maintain per dilution rate) Baroid As required* *There will be an adequate stock of Barite on location to increase mud weight by 1.5 ppg for entire mud system Monitoring Equipment to be used on the circulating system: • Flow Show — Gauge for returns • Pit Volume Totalizer System • Mud /Gas Detection System for Methane and H 10 Mud Program 211- 33.doc 1 10/14/2008 Page 1 of 3 • 4110 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 07, 2008 8:29 PM To: PORHOLA, STAN T Subject: RE: SRU 211 -33 = Again OS- ^ .5 Stan, It is my understanding that the surface casing needs to be set below the exemption depth. Let's talk tomorrow. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [ mailto :stan.porhola @chevron.com] Sent: Tue 10/7/2008 4:36 PM To: Maunder, Thomas E (DOA) Subject: RE: SRU 211 -33 - Again Tom, In my review I did notice that the AEO for Swanson was down to 1700' TVD. How does this affect the surface casing shoe depth? For Chevron's Ivan River Unit, the AEO is down to 2500' TVD. I'm currently planning a grass roots well but the surface shoe will be about 1785' TVD. The intermediate shoe will be at 4933' TVD. How would this impact the casing and cement design depths? Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 -3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 sta n. porhola@chevron. com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 07, 2008 4:06 PM To: PORHOLA, STAN T 12/9/2008 Page 2 of 3 • Subject: FW: SRU 211 -33 - Again Sorry Stan, 1 misfired. Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, October 07, 2008 4:05 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SRU 211 -33 - Again Stan, As I was finishing my review, 1 looked at the aquifer exemption for Swanson River Field. According to 40 CFR 147.102(b)(1)(i), all aquifers are exempted below 1700' tvd. You plan to set the surface casing at - 1643' tvd. It appears that the planned surface casing depth is insufficient. Please get back to me with a revised surface casing depth. At a minimum, it would appear that the surface casing shoe depth should be increased by 100' tvd. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, October 07, 2008 10:44 AM To: 'PORHOLA, STAN T Subject: RE: SRU 211 -33 Stan, Thanks for the reply. I will hand correct the md. With regard to MASP and BOP rating, I think we are fortunate that the available equipment is generally 5K. In the case of 105E, the 5 K rated equipment give you significantly more options than just a 2 K system. Please note, the 3000 psi value is only with regard to the BOP test. The 2000 psi test planned for the tubing and casing appears to be more than adequate. Thanks as well for the schedule. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Tuesday, October 07, 2008 10:12 AM To: Maunder, Thomas E (DOA) Subject: RE: SRU 211 - 33 Tom, 1.) The MD should be 4652'. That 5500 is an erroneous error. 2.) The cement will enter the 9 -5/8" shoe. We will not pump down the 9 -5/8" x 7" with mud to clear. 3.) The 3000 psi would not exceed any design limits. I was under the impression that if you were under 2000 psi MASP, then you would only be required to have a 2M BOPE. All the BOPE equipment for 106E will be 5M. The BLM has BOPE requirements for 2M, 3M, 5M, etc. These may not all have a correlation to AOGCC regs. If 3000 psi is required, we won't have any issues with testing the BOPE and Casing to this pressure. 4.) Nabors 106E is currently moving to SCU 312 -09. Following this workover, the rig will move to SRU 211 -33. The workover is scheduled for 2 weeks. If there is a minimal of downtime, the rig should be available to move to SRU 211 -33 around Oct 21st, with spud to follow around Oct 28th. I've previously submitted an NOS (Notice of Staking) to the BLM so their 30 day minimum requirement for review has been met. Greg Noble (while Tom Zelenka is on vacation) received the APD the same date as the AOGCC. 12/9/2008 Page 3 of 3 • Thanks for the quick response. Let me know if you need any additional information. Stan Porhala Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 -3322 Tel 907 263 7640 Fax 907 263 7884 CeII 907 229 1769 stan.porhola @chevron.com !Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 07, 2008 9:26 AM To: PORHOLA, STAN T Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett) Subject: SRU 211 - 33 Stan, 1 am beginning review of the permit application for this well and have some comments/questions. 1. The and given for the 8 -1/2" hole is given as 5500' on the 401 sheet, however wherever else the 8- 1/2 "/7" casing TD is listed it is 4652'. So far as I can tell, the tvd given is always 3833'. What is the correct planned and for the 8 -1/2" section? 2. You state that it is planned to raise the 7" cement to the surface casing shoe. Is it intended to cement into the 9 -5/8" shoe or will the "shoe be cleared" by pumping some mud? 3. You indicate a planned BOP test pressure of 2000 psi which is in excess of MASP. I am reluctant to endorse this test pressure. As ! remember 3000 is generally the minimum test pressure required. This should not affect your planned casing or tubing tests. 4. How real is the October 23 spud date? I may have other comments; however I wanted to get these to you. Tom Maunder, PE AOGCC 12/9/2008 i r Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, , AK AK 99519 -6247 Tel m a it 7657 E b r and Email bandenburgt @chevron.com October 1, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: Permit to Drill 10 -401 Swanson River Unit, SRU 211 -33 Gas Development Well Dear Commissioner: Enclosed for your approval is a completed Permit to Drill (form 10 -401) for the Swanson River Unit SRU 211 -33 Gas Development Well. Subject to AOGCC approval, it is our intention to utilize Nabors 106E, which is currently active in Swanson River. We plan to drill a directional well to +/- 4,652'/3,833' MD /TVD, run and cement a 7" production casing string, perforate and run a multi -zone gravel pack completion in the Sterling B- sands. We would like to request a variance from requirements of 20 AAC 25.035, to utilize a diverter vent line diameter of 12" which will be smaller than our surface hole of 12 -1/4" we plan to drill out of the 16" conductor. A similar request was submitted in the permit to drill for SCU 42 -05Y in June 2007. In order to clarify the BOP testing requirements, we are requesting that the AOGCC BOP testing requirements (test durations, high and low pressure requirements, etc.) are included in the Conditions of Approval (COA). We are assuming a BHP of 1,687 psi. Utilizing a 0.10 psi/ft gradient (per 20 AAC 25.035) from a TVD of 3,833', the maximum surface pressure would be 1,303 psi. Therefore, we will be planning to utilize 2000 psi for the approved stack working pressure. Per BLM regulations, a 0.22 psi/ft gradient gives a maximum surface pressure of 843 psi. Therefore, an approved stack working pressure of 2,000 psi is applicable for both the AOGCC and BLM. to your office requesting the ability to produce the well within 1500' of both a lease and unit boundary. We are targeting a spud date of October 23 Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Mr. Stan Porhola at 263 -7640. Sincerely, i oty Timothy C. Brandenburg Drilling Manager TCB: stp Attachments: PTD Package Cc: Well File Engineer File — Stan Porhola Environmental — Rich Vicente Union Oil Company of California / A Chevron Company http: / /www.chevronom JO 1t/ i STATE OF ALASKA A9-6-41 ,_;'' ALA OIL AND GAS CONSERVATION COM ION PERMIT TO DRILL V.) [ 20 AAC 25.005 1 a. Type of Work: 1 b. rrent Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill 151 Redrill ❑ Strati. : phic Test ❑ Service ❑ Development Gas 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone 0 Shale Gas ❑ 2. Operator Name: / , 5. Bond: Blanket MI Single Well ❑ 11. Well Name and Number: CI..„0en (Union Oil Company of Cali. nia) Bond No. 61S103671687BCM SRU 211 -33 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, Alaska, 99 ' MD: 4652 TVD: .33 Swanson River Unit 4a. Location of Well (Governmental Sectio • 7. Property Designation: 40f Sterling /Upper Beluga Surface: 468 FNL, 2107' FWL, Sec 33, T: R9W, SM fab A- 028399 (Outside Unit and PA Boundary) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 952 FNL, 265' FWL, Sec 33, T8N, R- , SM N/A 10/23/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 977 FNL, 171' FWL, Sec 33, T8N, R9 , -11A 1760 Property: 171 feet 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 1,484,536 y- 2,465,770 e- ASP 4 (Height above GL): 0.5 feet Within Pool: 1856 16. Deviated wells: Kickoff depth: '0 feet 17. Maximum Anticipated Pr- -sures in psig (see 20 AAC 25.035) Maximum Hole Angle: • degrees Downhole: 1687 Surface: 1303 18. Casing Program: Specifications Top - Setting i - pth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling ength MD TVD MD TVD (including stage data) Driven 16 109 X -56 Weld 102 0 0 102 102 Driven (not cemented) 12 -1/4 9 -5/8 40 L -80 BTC •000 0 0 2000 1643 230 bbls (100% excess) 8 -1/2 7 26 L -80 BTC -Mod , 2 0 0 ayeQ 3833 93 bbls (50% excess) 19. PRESENT WELL CONDITION SUMMARY (To be pleted 'Jr Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): E -ct. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): 3531 -3541, 3635 -3645, 3840 -38 d Perforation Depth • (ft): 2721 -2731, 2821 -2831, 3022 -3032 20. Attachments: Filing Fee ❑ BOP Sketch IN Drilling Program el e v. Depth Plot IN Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch r Seabed Report ❑ Drilli Fluid Program El 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: up Date 22. I hereby certify that the foregoing is true and correct. Contact Stan Porhola Printed Name ja . Tim Brandenburg " °" T1tle —° Signature If ✓. _ Fr Phone 263 -7640 Date 10/1/2008 Commission Use Only Permit to Drill / API Number Permit Approval See cover letter for other Number: �, ff— /S� 50 33aee'677000'D Date: requirements. If box is checked, well ay not be used to explore for, test, or produce coalbed methane, gas hy• -tes, or gas contained in shales:[ Conditions of approval : Samples req'd: Yes No [✓], Mud log req'd: Yes❑ NoV H measures: Yes No Dire '•nal svy req'd: Yes[ No 000�;t, %O \ e `7V Other: APPROVED :Y THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate .1 i `‘ i ‘. / i 1 \l t " i L.... Chevron • • Swanson River Unit SRU 211 -33 Gas Well Drilling Procedure Summary 1. Pr- 'are location. Drill and drive 16" conductor casing to +/- 102' MD Kraxberger truck rig. Set cellar. Install multi -bo wellhead. 2. MIRU abors #106E drilling rig. 3. NU and nction test Diverter. 4. PU drillpi•- and 12 -1/4" bit and directional BHA. 5. RIH and cl= : n -out 16" conductor. 6. Drill 12-1/4" ole with 8.6 -9.2 ppg water-base spud mud to casing point at +/- 20‘ C. Utilize BHA w/ MWD only. SUPERSEDED 7. Condition hole - d POOH. Laydown bit a • BHA. '° X 9 8. RU and run 9 -5/8 casing. ` 9. MU and test cem= t lines. Circulate d cement casing bringing cement to surface. : mp top plug an. test casing to 2000 psi. 10. Deactivate diverter s' -tem and a. ivate BOPE equipment. Test BOPE to 2000 psi /250 • . i. 11. MU 8 -1/2" directional B and ' H. Drill out float equipment, and 20' of new formation. Pull • -ck nto the casing and conduct a leak - off test or FIT test to 13.0 pp MW. 12. Directionally drill 8 -1/2" hol= TD at +/- 4,652' MD / 3,833' TVD with 9.0 -9.5 ppg water -bas-d m, d. Utilize BHA w/ MWD and GR. 13. Condition hole and POO Layd • , n bit and BHA. 14. RU and run open hole egging sui - (Quad Combo: GR -Res, Den, Neu, Son) from TD to " shoe. Run MI (Formation Micro Imager) from TD to 7" shoe. 15. RU andrun7 "casi . 16. MU and test ce -nt lines. Circulate an cement casing bringing cement to previ• s shoe. Bump plug and t =-t casing to 2000 psi. 17. RIH w/ clean • t assembly and displace ud to 6% KCI brine. POOH. 18. If cement c erage is questionable, a USIT Itra Sonic Imaging Tool) will • - run to evaluate cement coverage an • bond. 19. Set su packer on E -line at 3870' MD. RI w/ TCP guns. Perfor- Sterling B -5 (3840' -3850' MD). POOH. 20. RIH / Gravel Pack running tool and screen ass- bly. Gravel Pac Sterling B -5 sand w/ 20/40 Ottawa sand. POO w/ running to• . 21. ' -peat TCP and Gravel Pack procedure for Sterling 3 sand 3635' -3645' MD) and Sterling B -2 sand (3531' -3541' MD). 22. RIH w/ 2 -7/8" tubing. Circ packer fluid. Space out and land tub' g. 3 Drilling Procedure Summary SRU 211- 33.doc 1 9/24/2008 Chevron • 1111011 Swanson River Unit SRU 211 -33 Gas Well Drilling Procedure Summary 23. Te. tubing to 2000 psi and tubing x casing annulus to 1500 psi. 24. ND : • PE. NU and test tree to 5000 psi. Release Rig. 25. RU s kline. RIH w/ weight bar and break KOI s (Knock out isolation valves). Turn well over to production for -sting. Flowline will conne t well from 211 -33 to TS 1 -33 productio facilities. 3 Drilling Procedure Summary SRU 211- 33.doc 2 9/24/2008 1 ,SOP-14 gf4' C - vron Well Name: SRU 211 -33 , Field: Swanson River Completion: Proposed v2.8 RKB: 206.5' GL: 186.0' Driven 'co .uctor: 16 ", 109 ppf, X -56 to 102' MD 112-1/4" Hole Surface Casing: 9 % ", 40 ppf, L -80, BTC to 2000' MD 8 -1/2" Hole Production Tubing: 2 % ", 6.4 ppf, L -80, TC-Il to 3488' Completion: - Chemical injection sidepocket mandrel at 2000' Isolationg String: - Baker SC -1 packer at 3488' 2W, 6.5 ppf, L -80, Hydril 503 3507' -3558' MD - Excluder 2000 (Med) Screen 3517' -3555' 2W, 6.5 ppf, L -80, Hydril 503 3614' -3665' MD - Baker SLCMD sliding sleeve at 3517' (Closed) 2W, 6.5 ppf, L -80, Hydril 503 3819' -3870' MD 2.313" X- profile - S -22 Seal assembly at 3558' - Baker SC -1 packer at 3558' �_ Geologic Tops: - Excluder 2000 (Med) Screen 3624' -3662' ;1 Sterling B -2: 3531' MD / 2721' TVD - Baker SLCMD sliding sleeve at 3624' (Closed) t;:, " . Sterling B -3: 3635' MD / 2821' TVD 2.313" X- profile -: j 000 r B -2 Sterling B -5: 3840' MD / 3022' TVD - S -22 Seal assembly at 3665' eluga 39_1 ST: 4523' MD / 3703' TVD - Baker SC -1 packer at 3665' T1 4652' MD / 3833' TVD - Excluder 2000 (Med) Screen 3829' -3867' al ae: - Baker SLCMD sliding sleeve at 3829' (Close. \± 2.313" X- profile ; 000 B -3 Geolo• i, • ressures: S-22 Seal assembly at 3870' �� Sterling A. :.5 ppg EMW - Baker FS sump packer at 3870' •,;I• , ?,;• Sterling B- .8 - 8.1 ppg EMW kAx r . ^.,h Sterling B -3: - 8.1 ppg EMW : Ot t ;P : 5 t :;; Sterling B -5: 7.: - 8.1 ppg EMW Proposed Perforations : x`000 B -5 Sterling B -2: 3531' - 3541' MD Sterling B -3: 3635' - 3645' MD Bottom Hole Tem.er- ures Sterling B -5: 3840' - 3850' MD Sterling B -2: 73 °F Sterling B -3: 74 °F Sterling B -5: 76 °F — Production Casing: PBTD = 4567' MD 7 ", 26 ppf, L -80, BTC -Mod to 4652' D TD = 4652' MD 4.xls September 5, 2008 Drawn by: STP 0 C SRU 211 -33 Chevron c Depth vs. Time 1 —Drilling Time MIRU O! Nabors 1000 106E 12 -1/4" Hole 2000 9 -5/8" Casing ;3000 o. d A 8 -1/2" Hole 4000 5001 Open Hole Logs 7" Casing Gravel Pack DeMobe Completion Nabors 106E 6000 -r 0 5 10 15 20 25 30 35 Time (Days) 1 1 Chevron FARO Planned Wellpath Report BAKER IWII 211- 33_Version #7 NUGH Page 1 of 3 INTEQ REFERENCE WELLPATH IDENTIFICATION [Operator Chevron Slot 211 -33 Area Cook Inlet, Alaska (Kenai Penninsula) Well 211 -33 'Field Swanson River Unit Wellbore 211 -33 Facility 21133 REPORT SETUP INFORMATION [Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System RWellArchitect ®2 0 North Reference d True User Ulricard Scale 10.999928 !Report Generated 19/25/2008 at 4:14:17 PM ■ Convergence a slot €0.76° West 'Database /Source file IWA Anchorage /211 33 xml i WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[USft] Northing[USft] I Latitude Longitude 'S1ot Location - 467.74 1 2108.06 344513.23 2466008.40 60°44'49.339"N 150°52'08.627"W Facility Reference Pt 342411.79 2466504.34 60 °44'53.947 "N 1 150 °5 2'51 039 "W ¢3 Field Reference Pt F 347751.98 2471720 97 60°45'46.011"N 150 °51'04.957 "W .,... w..,a _ ,.t..., �, -. �.. v.. ,.�— ..............�..R.:.�.... w. +«,. .._ .,.tea«,... ,.. ... ,.no.,..,,�. a.,. ,.....,�.. WELLPATH DATUM Calculation method Minimum curvature N -106E (RT) to Facility Vertical Datum 206.50ft 1Horizontal Reference Pt Slot N -106E (RT) to mean sea level 206.50ft Vertical Reference Pt N -106E (RT) Facility Vertical Datum to Mud Line (Facility) "O.00ft =' MD Reference Pt [N -106E (RT) Section Origin N 0.00, E 0.00 ft Field Vertical Reference ,mean sea level Section Azimuth 90.00° I Chevron 1 00 100 Pla Wellpath Report BAKER 211- 33_Version #7 HUGHES Page 2 of3 INTEQ REFERENCE WELLPATH IDENTIFICATION [ Operator Chevron ISlot [ 211 -33 Area Cook Inlet, Alaska (Kenai Penninsula) Well 211 -33 Meld ]Swanson River Unit (Wellbore 211 -33 ]Facility 211 -33 ■ ( WELLPATH DATA (54 stations) 1' = 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] 0.00t 0.000r 255.283 0.00 - 206.50 0.00 0.00 0.00 344513.23 2466008.40 0.00 20.50 0.000' 255.283 20.50 - 186.00 0.00 0.00 0.00 344513.23 2466008.401 0.00 120.501 0.000 255.283 120.50 -86.00 0.00 0.00 0.00 344513 23 2466008.401 0.00 220.50t 0.000; 255.283 220.50 14.00 0.00 0.00 0.00 I 344513.23 r 2466008.40 0.00 00.00 0.000 55.283 300.00 93.50 0.00 0.00 0.00 344513.23 2466008 40, • _' 0.00 • 320.50t 0.820; 255.283 320.50 114.00 -0.14 -0.04 -0.14 344513.09 j 2466008.36 4.00 420.501 4.820; 255.283 420.36 213.86 4.90 -1.29 4.90 344508.31 2466007.18 F 4.00 520.50t 8.820 2 55.283 519.63 313.13 -16.38 4.30 -16.38 344496.79 2466004.31 � 4.00 620.50t 12.820 255.283 617.83 411.33 -34.54 -9.07 -34.54 344478.58 2465999.79 4.00 720.501 16.820 255.283 714.49 507.99 -59.27 -15.57 -59.27 344453.76 2465993.62 4.00 820.50t 20.820 255.283 809.12 602.62 -90.46 -23.76 -90.46 344422.47 2465985.84 4.00 920.50t 24.820 255.283 901.27 694.77 - 127.97 -33.61 - 127.97 344384.84 ! 2465976.49 4.00 1020.50t 28.820 255.2831 990.50 784.00 - 171.60 -45.07 - 171.60 344341.06 I 2465965.61 4.00 1120.501 32.820 255.283 1076.36 869.86 - 221.14 -58.09 i - 221.14 344291.36 ! 2465953.25 4.00 1220.501 36.820 255283 1158.44 951.94 - 276.36 -72.59 - 276.36 344235.96 2465939 48 mow. 4.00 1320.501; 40.820; 255.283 1236.33 1029.83 - 336.98 -88.51 - 336.98 344175.14 • 2465924 36 4.00 [ '__._. -_ 402.70 344109.19 ' 2465907 97 r 4.00 1420.501'1 44.820 2 55.283 1309.67 1103.17 - 402.70 _ - 105.77 1520.501' 48.820 255.283 1378.08 1171.58 473.22 r - 124.30 473.22 344038.45 2465890 39 f 4.00 1620.50t 52.820 € 255.283 1441.25 1234.75 - 548.17 - 143.98 - 548.17 343963.24 2465871 69 j 4.00 1720.501 56.826., ,= 255.283 1498.85 1292.35 - 627.21 - 164.74 - 627.21 343883.94, 2465851.98" 4.00 1780.95 59.238; 255.283 1530.86 1324.36 - 676.81 - 177.77 - 676.81 343834.18 2465839.61 4.00 1820.501 59.2381 255.283 1551.08 1344.58 - 709.68 - 186.41 - 709.68 343801.20 2465831.42 0.00 1920.50t 59.2381 255.283 1602.23 1395.73 - 792.79 - 208.24 - 792.79 343717.82 2465810.69 0.00 2020.50t 59.238' 2 55.283 1653.38 1446.88 - 875.90 - 230.07 - 875.90 343634.43 2465789.96 0.00 2120.501 59238 255283 1704.53 1498.03 - 959.01 - 251.90 - 959.01 343551.04 2465769.24 0.00 2220.501` 59.238 255.283 1755.67 1549.17 - 1042.12 - 273.73 - 1042.12 343467.66 2465748.51 0.00 2320.501 59.238 255.283 1806.82 1600.32 - 1125.23 - 295.56 - 1125.23 343384.27 , 2465727 78 1 0.00 1 2420.501 59.238 255.283 1857.97 1651.47 - 1208.34 - 317.39 - 1208.34 343300.89 2465707 06 n 0.00 2425.21 59.238 255.283 1860.38 1653.88 - 1212.26 - 318.41 - 1212.26 343296.96 2465706.08 0.00 2520.501 55.426 255283 1911.80 1705.30 - 1289.83 - 338.79 - 1289.83 343219.13 . 2465686.731 4.00 2620.50t 51.426 255.283 1971.38 1764.88 - 1367.48 - 359.19 - 1367.48 343141.21 2465667 37 a 4.00 r 2720.501 47.426 255.283 2036.40 1829.90 } - 1440.93 - 378.48 - 1440.93 343067.52 2465649.05 4.00 2820.501 43.426 255.283 2106.57 1900.071 - 1509.82 - 396.57 - 1509.82 j 342998.41 2465631 87 4.00 2920.501 39.426 255.283 2181.54 1975.04 - 1573.80 413.38 - 1573.801 342934.21 2465615 91 4.00 3020.501 35.426 255.283 2260.94 2054.44 - 1632.57 428.81 - 1632.57 34287525 _2465601.26 *: 4 0 3120.501 31.426 255.283 2344.38 2137.88 - 1685.84 442.81 - 1685.84 342821.81 , 2465587.97 I 4.00 r 3220.501' 27.426 255.283 2431.46 2224.96 - 1733.35 455.28 - 1733.35 342774.14 2465576.13 4.00 3320.501 23.426 255.283 2521.75 2315.25 - 1774.86 466.19 - 1774.86 342732.48 1 2465565.77 r 4.00 3420.50t 19.426• 255.283 2614.82 2408.32 - 1810.19 - 475.47 - 1810.19 342697.04 2465556.96 4.00 20.501 15.420` ° 55.283 271022 2503.72 - 1839.15 483.08 - 1839.15 342667.99 ' 2465549.74 4.00' 3531.16 15.000.255.283' 2720.50 2514.00 - 1841.85 - 483.79 - 1841.85 342665.27 2465549.07 4.00 3620.501 13.213255.283 2807.14 2600.64 - 1862.91 - 489.32 - 1862.91 342644.14 2465543 81 1 2.00 3720.501 11.2131 255.283 2904.88 2698.38 - 1883.37 - 494.69 - 1883.37 342623 62 2465538 71 2.00 - 1900.52 - 499.20 - 1900.52 342606.41 2465534.43 3820.501' 9.213 255.283] 3003.29 2796.79 j 2.00 3920.51 02,26 2895.76 -.1414.34 -502.82 1914.34 342 2465530. , ,. • • • Chevron HMO Planned Wellpath Report BAKER IN. 211- 33_Version #7 HUGHES Page 3 of 3 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator !Chevro rSlot 211 -33 A rea Cook Inlet, Alaska (Kenai Penninsula) Well [ 211 - 33 Field !Swanson River Unit Wellbore 211 -33 Facility 211-33 WELLPATH DATA (54 stations) j' = interpolated /extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS I [ft] 1 0 1 1 1 I [ft] Fid Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ ° /l00ft] I [ft] E 4020.50f! 5.213 255.283" 3201.66 2995.16 - 1924.81 - 505.57 - 1924.81 342582.05 2465528.38 2.00 4120.50t 3.213 255.283 3301.39 3094.89 - 1931.91 - 507.44 - 1931.91 342574.921 2465526.61 2.00 4220.50t 1.213, 255.283 3401.31 3194.81 - 1935.65 - 508.42 - 1935.65 342571.17 2465525.67 2.00 - 1936.27 - 508.58 - 1936.27 342570.55 1 2465525 52 2.00 4281.16 : 0. 000 ' 255.283 3461.96 3255.46 4320 _' 0.000 255.283 3501.30 3294.80 - 1936.27 - 508.58 - 1936.27 342570.55 2465525 52 tt t 4420.50f f 0.000 255.283 3601.30 3394.80 - 1936.27 - 508.58 - 1936.27 342570.55 , 2465525.52 0.00 4520.5011 0.000 255.283 3701.30 3494.80 - 1936.27 - 508.58 - 1936.27 342570.55 7 2465525.521 0.00 4620.50 f C 0.000 255.283' 3801.30 3594.80 - 1936.27 - 508.58 - 1936.27 342570.55 2465525.52 r 0.00 4651.70 0.000 255.283 3832.50 3626.00 - 1936.27 - 508.58 - 1936.27 342570.55 1 2465525 52 0.00 HOLE & CASING SECTIONS Ref Wellbore: 211 -33 Ref Wellpath: 211-33_Version#7 _ String/Diameter Start Ml) End MD Interval Start TVD End TVD Start N/S Start E/W End N/S I End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] s [ft] 16in Conductor 20.50 102.00 81.50 20.50 102.00 0.00 0.00 0.00 0.00 `12.25in Open Hole � 20.50 2000.00 1979.50 20.50 1642.89; 0.00 0.00 - 225.59 - 858.86 19.625in Casing Surface 20.50 2000.00 1979.50 20.50 1642.89 0.00 0.00 - 225.59 - 858.86 875in Open Hole 2000.00 4651.70 2651.70 1642.89 3832.50 - 225.591 - 858.86 - 508.58 - 1936.27 Tin Liner r-- 2000.00 4651.70 2651.70 1642.89 3832.50 - 225.59 - 858.86 - 508.58 - 1936.27 TARGETS Name MD TVD North ; East Grid East I Grid North Latitude Longitude Shape [ft] [ft] [ft] I [ft] [sry ft] [sry ft] 1 2720.50 - 483.85 - 1842.13 342665.00 2465549.0060 °44'44.573 "N 150 °52'45.688 "W circle 211 -33 Target#1 (22-Sep-08) 211 -33 TD Target (22- Sep -08) - 3832.501 - 483.85 - 1842.13 342665.00 2465549.001 60 °44'44.573 "N 150°52'45.688"W circle SURVEY PROGRAM Ref Wellbore: 211 -33 Ref Wellpath: 211- 33_Version #7 Start MD I End MD Positional Uncertainty Model Log Name /Comment 1 Wellbore [ft] s [ft] 20.50! 4651.70NaviTrak (Magcorrl) 11 -33 • 1 Chevron Clearance Report riti 211-33 Version#7 BAKER %NO Closest Approach UGN ES Page 1 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION 1 'Operator Chevron Slot 1211-33 Area :Cook Inlet, Alaska (Kenai Penninsula) Well 1211-33 :Field Swanson River Unit Wellbore 211-33 7 Facility .211 REPORT SETUP INFORMATION i Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System WellArchitect® 2.0 North Reference [True User Ulricard - , [Scale 0.999928 Report Generated 9/25/2008 at 4:16:31 PM Convergence at slot ,0.76° West 'Database/Sourcefile 1WAAnchorage/211-33.xml_ i ... WELLPATH LOCATION Local coordinates Grid coordinates 1 Geographic coordinates Northift] EastIft] : Easting[USft] Northing[USft] —r- Latitude Longitude "I Slot Location -467.74 2108.06 ' 344513.23 2466008.40 60°4449.339"N 150°5208.627"W Facility Reference Pt ' 342411.79 2466504.34 60°4453.947"N 1 150°5251.039"W [Field Reference Pt 347751.98 2471720.97 60°45'46.011N 150°51'04.957"W , WELLPATH DATUM Calculation method ,Minimum Curvature N-106E (RT) to Facility Vertical Datum 1 206.50ft !Horizontal Reference Pt Slot N-106E (RT) to mean sea level 1206.50ft Vertical Reference Pt N-106E (RT) Facility Vertical Datum to Mud Line (Facility) 10.00ft MD Reference Pt N-106E (RT) Field Vertical Reference mean sea level POSITIONAL UNCERTAINTY CALCULATION SETTINGS , 1 'Ellipse Confidence Limit 13.00 Std Dev 'Ellipse Start Depth 0.00ft 1Surface Position Uncertainty 'included r - I Declination 118.94° East of TN Dip Angle 73.66° 'Magnetic Field Strength 1 r55566 nT 66° ---- ' _ ANTI-COLLISION RULE Rule Name E-type Closest Approach w/Hole&Csg Limit:0 StdDev:3.00 .Rule Based On Ellipsoid Separation , i lw/Surface Uncert F Plane of Rule i Closest Approach 1Threshold Value 10.00ft Subtract Casing & Hole Size i yes Apply Cone of Safety no ----1 • • Chevron Clearance Report a ' BAKER re NINO 211 -33 Version #7 N�Q►NES Closest Approach Page 2 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION [Operator Chevron Slot x211 -33 Area Cook Inlet, Alaska (Kenai Penninsula) Well 211 -33 Field ISwanson River Unit 1Wellbore 211 -33 Facility 211 -33 HOLE & CASING SECTIONS Ref Wellbore: 211 -33 Ref Wellpath: 211 -33 Version #7 I String/Diameter Start MD End MD Interval ; Start TVD End TVD ' Start N/S Start E/W End N/S End E/W , [ft] [ft] [ft] I [ft] [ft] I [ft] [ft] i [ft] I [ft] 16in Conductor 20.50 102.00 I 8 20.50 , 102.00 0.00 0.00' 0.00' 0.00 ! 12.25in Open Hole 20.50' 2000.00 1979.50' 20.50 1642 89, 0.00, 0.001 225.59 -858.861 t 9 625in Casing Surface 20.50 2000.00 1979.50' 20.50 1642.89 i _mm 0.001 0.00' 225.59 E -858 86 8 5in Open Hole 2000.00 4651.70 2651.70' 1642.89 3832.501 832 50 [ 225.59 -858.86 508.58 [ -1936.27 Tin Liner 2000.00 4651.703 2651.70 1642.89 3832.50' - 225.59; - 858. 508.58 -1936 27 SURVEY PROGRA M Ref Wellbore: 211 -33 Ref Wellpath: 211 -33 Version #7 Start MD End MD 1 Positional Uncertainty Model I Log Name /Comment F Wellbore l [ft] [ft] 20.50 4651.70 NaviTrak (Magcorrl) 211-33 �.. -,. aa... .,., <.... ..�,. .m ..�. s..a...� ._.. «..,.-...... ..�..,,.... -.«., ...w.. »a- ,.,�.,u,w. ._. a.,.,........ u-..., ..-.�.._,,,......- .,.�.o...�... - .em....,..,,...w..._..-.,xK. ..,:.,........._-,...... CALCULATION RANGE & CUTOFF From. 20.50ft MD To: 4651.70ft MD [C - C Cutoff. (none) OFFSET WELL CLEARANCE SUMMARY (1 Offset Wellpath selected) Offset Offset Offset Offset Offset Ref Min C -C Diverging Ref MD of Min C -C Min C -C ACR Facility Slot Well Wellbore Wellpath MD Clear Dist from MD Min C -C Ell Sep Ell Sep Status [ft] [ft] [ft] Ell Sep [ft] Dvrg from [ill [ft] 211-33 121 -33WD 21 -33WD 21 -33WD Inc Only <0 3805> 300 00 52 92 302 26 3 3 1 7 6 1 3 6 1 5 1 4 6 2 0 1 0 2PASS I • • Chevron Clearance Report VAIN W . 211- 33_Version #7 BAKER ONO Closest Approach HUGHES Page 3 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot 211 - Area Cook Inlet, Alaska (Kenai Penninsula) Well 211 -33 Field Swanson River Unit Wellbore 211 -33 Facility 211 -33 CLEARANCE DATA - Offset Wellbore: 21 -33WD Offset Wellpath: Inc Only<0 -3805> Facility: 211 - Slot: 21 -33WD Well: 21 -33WD Threshold Value =0.00 ft t = interpolated /extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C -C Ellipse ACR ACR [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] Bearing Clear Dist Sep MASD Status [ [ft] [ft] [ft] 20.50t 20.50 0.00 0.00 20.00 20.50 -33.43 41.23 129.04r 53.08[_ 39.68 13.401 PASS 120.50t 120.50 0.00 0.00 120.02 120.52 -33.39 41.23 129.00 53.05 38.53 14.523 PASS 220.50t 220.50' 0.00 0.00 220.04 220.54 -33.29 41.23 128.92r 52.99 37.34 15.65 PASS 300.00t 300.00 0.00 0.00 299.56 300.06 -33.17 41.23 128.82 52.92 36.35 16.57 PASS 30226t 302.26 0.00 0.00 301.81 302.31 -33.16 41.23 128.81' 52.91 3632 16.59 PASS 320.501 320.50 -0.04 -0.14 320.06 320.56 -33.13 41.23 128.66 52.98 36.18' 16.80 PASS H r. 331.76t 331.76 -0.09 0.34 331.31 331.81 -33.11 41.23 128.46 53.09 36.15 16.94 PASS 420.501! 420.36 -1.29 -4.90 419.94 420.44 -32.92 41.23 124.44 55.931_ 37.86 18.07 PASS 520.501 519.63 -4.30 -16.38 519.22 519.72 -32.65 41.23 116.201- 64.21 44.40 19.81 PASS 620.50t 617.83 -9.07 -34.54 617.42 617.92 -32.32 41.23 107.06 79.25 57.50 21.75 PASS 720.50t 714.49 -15.57 -59.27 714.06 714.56 -31.95 41.23 99.26 101.82 78.09 23.73 PASS 820.50t 809.12 -23.76 -90.46 808.66 809.15 -31.53 41.23 93.38 131.92 106.291 25.63 PASS 920.501 901.27 -33.61 - 127.97 900.76 901.26 -31.07 41.23 89.14 169.22 141.80' 27.42 PASS 1020.50t 990.50 - 45.07 - 171.60 989.92 990.42 -30.58 41.23 86.10 213.32 184.221 29.10 PASS 1120.50t 1076.36 -58.09 - 221.14 1075.69 1076.18 -30.06 41.23 83.90 263.86 233.17 30.69 PASS 1220.50t 1158.44 -72.59 - 276.36 1157.66 1158.15 -29.53 41.23 82.28 320.49 288.30 32.19 PASS 1320.50t 1236.33 -88.51 - 336.98 1235.42 1235.91 -28.99 41.23 81.06 382.86 349.26 33.60, PASS 1420.50t 1309.67 - 105.77 402.70 1308.59 1309.08 -28.45 41.23 80.12 450.62 415.69 34.93' PASS 1520.50t 1378.08 - 124.30 - 473.22 1376.83 1377.31 -27.92 41.23 79.39 523.40 487.23 36.17 PASS 1620.50t 1441.25 - 143.98 - 548.17 1439.79 1440.26 -27.40 41.23 78.81 600.82 563.51 37.32 PASS 1720.501 1498.85 - 164.74 - 627.21 1497.17 1497.61 -26.91 41.23 78.35 682.50 644.14 38.37 PASS 1780.95t 1530.86 - 177.77 - 676.81 1529.04 1529.52 -26.63 41.23 78.11 733.77 694.28 39.49' PASS 1820.50t 1551.08 - 186.41 - 709.68 1549.19 1549.66 -26.45 41.23 77.98 767.75 727.54 40.211 PASS 1920.50t 1602.23 - 208.24 - 792.79 1600.11 1600.58 -26.00 41.23 77.67 853.70 811.69 42.00 PASS 2020.501 1653.38 - 230.07 - 875.90 1651.02 1651.50 -25.53 4123 77.43' 939.66 896.01 43.65 PASS 2120.501 1704.53 - 251.90 - 959.01 1701.93 1702.40 -25.06 41.23 77.22 1025.64 980.18' 45.46 PASS 2220.501 1755.67 - 273.73 - 1042.12 1752.83 1753.31 -24.58 41.23 77.05 1111.63 1064.35' 47.28 PASS 2320.50t 1806.82 - 295.56 - 1125.23 1803.73 1804.20 -24.09 41.23 76.90 1197.63 1148.51 49.12 PASS 2420.50t 1857.97 - 317.39 - 1208.34 1854.62 1855.09 -23.60 41.23 76.77 1283.65' 1232.68 50.97 PASS 2425.21t 1860.38 - 318.41 - 1212.26 1857.01 1857.48 - 23.57 41.23 76.76 1287.70 1236.64 51.05 PASS 2520.501 1911.80 - 338.79 - 1289.83 1908.18 1908.65 - 23.06 41.23 76.66 1367.99 1315.06 52.93 PASS 2620.50t 1971.38 - 359.19 - 1367.48 1967.49 1967.95 -22.47 41.23 76.56 1448.40 1393.231 55.17 PASS 2720.501 2036.40 - 378.48 - 1440.93 2032.251 2032.71 -21.80 41.23 76.47 1524.48r 57.63 PASS 2820.50t 2106.57 - 396.57 - 1509.82 2102.14[ 2102.60 -21.07 41.23 76.39 1595.86P1535.58 60.28 PASS 2920.50t 2181.54 413.38 - 1573.80 2176.83 2177.29 -20.27 41.23 76.32 1662.19 1599.09 63.10 PASS 3020.50t 2260.941 428.81 - 1632.57 2255.96 2256.40: -19.40 41.23 76.26 1723.15 1657.071 66.08 PASS 3120.50t 2344.38; 442.81 - 1685.84 2339.13 2339.571 , -18.47 41.23 76.201 1778.44 170925; 69.19 PASS 3220.501 2431.46 455.28 - 1733.35 2425.95 2426.38 -17.48 41.23 76.14 1827.79 1755.38[ 72.41 PASS 3320.501 2521.75 - 466.19 - 1774.86 2515.99 2516.41 -16.42 41.23 76.09 1870.97E 1795.24 75.73 PASS 3420.501 2614.82 475.47- - 1810.19 2608.81 260922 -15.30 41.23 76.04 1907.76 1828.65 79.11 PASS 3520.501 2710.22 483.08 - 1839.15 2703.96 2704.37 -14.13 41.23 76.00 1937.98 1855.45 82.53 PASS 3531.16t1 2720.50 483.79' - 1841.85 2714.22 2714.631 -14.00 41.23 75.99 1940.81; 1857.931 82.88 PASS L 3620.50T 2807.14 489.32' - 1862.91 2800.66 2801.07 -12.91 41.2 75.95 1962.81877.091 85.75 PASS 1 3720.5011 2904.88 - 494.691 - 1883.37 2898.17 2898.55 -11.66 41.23 75.91 1984.307 1895.30 89.01` PASS 3820.501, 3003.29 - 499.20 - 1900.52 2996.71 2997.10 -10.38 41.23 75.87 2002.4 1910.02 92.32` PASS 0 0 Chevron Clearance Report BIM 211- 33_Version #7 BAKER 010 Closest Approach HUGHES Page 4 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot 211 -33 Area Cook Inlet, Alaska (Kenai Penninsula) Well 211 -33 Field Swanson River Unit Wellbore f 11 -33 Facility 211 -33 1 CLEARANCE DATA - Offset Wellbore: 21 -33W0 Offset Wellpath: Inc Only <0 -3805> Facility: 211 -33 Slot: 21 -33WD Well: 21 -33WD Threshold Value =0.00 ft to = interpolated /extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C -C Ellipse ACR ACR g [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] Bearing Clear Dist Sep MASD Status 2 [ [ft] [ft] [ft] - 3920.50t 3102.26 - 502.82 - 1914.34 3095.86 3096.25 -9.157 41.23 75.83 2016.93 1921.29 95.64 PASS 4020.50t 3201.66 - 505.57 - 1924.81 3195.47 3195.85 - 7.96` 41.23 75.80 2028.04 1929.09 98.95; PASS 20.50 t 3301.39 - 507.44 - 1931.91 3295.41 3295.78 -6.82 41.23 75.76 2035.67 1933.42 102.25 PASS 1 4220.501 3401.31 - 508.42 - 1935.65 3395.56 3395.92 -5.72 41.23 75.73 2039.80 1934.26 105.53 PASS Y 4281.16t 3461.96 - 508.58 - 1936.27 3456.36 3456.71 -5.08 41.23 75.72 2040.60 1933.11 107.49 PASS 4320.501 3501.301 - 508.58 - 1936.27 3495.79 3496.15 4.67 41.23 75.70 2040.70, 1931.96 108.73 PASS 4420.501 3601.30 - 508.58 - 1936.27 3596.03 3596.38 -3.67 41.23 75.68 2040.94r 1929.05 111.90 PASS 4520.501, 3701.30 - 508.58 - 1936.27 3696.28 3696.62 -2.72 41.23 75.65 2041.181926.11 115.07 PASS 4620.50t 3801.30 -508.58 - 1936.27 3796.52 3796.85 -1.82 41.23 75.63 2041.40 1923.16 118.24 PASS 4651.701 3832.50 -508.58 -1936 27 3805.00 3805.34 1.74 4113 75.62 2041.60_ 1923,24 118.36 PASS HOLE & CASING SECTIONS Offset Wellbore: 21 -33WD Offset Wellpath: Inc Only <0 -3805> String/Diameter Start MD ` End MI) Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W ' I [ft] [ft] [ft] [ft] [ft] i [ft] 3 [ft] [ft] [ft] 16in Casing 0.00 10000.001 10000.00 . - 20.00 NA[' - 20.38 1 25.13 NA NA WELLPATH COMPOSITION Offset Wellbore: 21 -33WD Offset Wellpath: Inc Only <0 -3805> Start MD 1 End MD Positional Uncertainty Model Log Name /Comment Wellbore [ft] 1 [ft] 0.00 3805.00 ' Drift Indicator (Standard) Inc Only <0 - 3805> 21 - 33WD OFFSET WELLPATH MD REFERENCE - Offset Wellbore: 21 - 33WD Offset Wellpath: Inc Only <0 - 3805> ;MD Reference: Rig on 21 - 33WD (RT) Offset TVD & local coordinates use Reference Wellpath settings i (See WELLPATH DATUM on page 1 of this report) • • Chevron EMS Chevron `ER %Oil L ocation: Cook Het, Alaska (Kenai Penninsula) Slot: 211 -33 INTEQ Field: Swanson River Unit Well: 211 -33 Facility: 211 -33 Wellbore: 211 -33 Plot reference wellpath is 211- 33_Version #7 True vertical depths are referenced to N -106E (RT) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to N -106E (RT) North Reference: True north N -106E (RT) to mean sea level: 206.5 feet Scale: True distance mean sea level to Mud line (Facility: 211 -33): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 9/25/2008 Hole and Casing Sections Start End Start End Start Start End End Name MD (ft) MD (ft) Interval (ft) TVD (ft) TVD (ft) Local N (ft) Local E (ft) Local N (ft) Local E (ft) Wellbore 16in Conductor 20.50 102.00 81.50 20.50 102.00 0.00 0.00 0.00 0.00 211 -33 12.25in Open Hole 20.50 2000.00 1979.50 20.50 1642.89 0.00 0.00 - 225.59 - 858.86 211 -33 9.625in Casing Surface 20.50 2000.00 1979.50 20.50 1642.89 0.00 0.00 - 225.59 - 858.86 211 -33 8.5in Open Hole 2000.00 4651.70 2651.70 1642.89 3832.50 - 225.59 - 858.86 - 508.58 - 1936.27 211 -33 7in Liner 2000.00 4651.70 2651.70 1642.89 3832.50 - 225.59 - 858.86 - 508.58 - 1936.27 211 -33 Well Profile Data Design Comment MD (ft) Inc (°) Az (°) TVD (ft) Local N (ft) Local E (ft) DLS (° /10oft) VS (ft) Tie On 20.50 0.000 255.283 20.50 0.00 0.00 0.00 0.00 End of Tangent 300.00 0.000 255.283 300.00 0.00 0.00 0.00 0.00 End of Build 1780.95 59.238 255.283 1530.86 - 177.77 -676.81 4.00 - 676.81 End of Tangent 2425.21 59.238 255.283 1860.38 - 318.41 - 1212.26 0.00 - 1212.26 End of Drop 3531.16 15.000 255.283 2720.50 - 483.79 - 1841.85 4.00 - 1841.85 End of Drop 4281.16 0.000 255.283 3461.96 - 508.58 - 1936.27 2.00 - 1936.27 End of Tangent 4651.70 0.000 255.283 3832.50 - 508.58 - 1936.27 0.00 - 1936.27 0 MI N 0 I LI L 16in Cmdudor End of Tangent 375 750 4.007100ft N 1125 W E 1500 nd of Buld 60GM (1945.0 to 20100) Dip: 73.66° Field: 55565.5 nT 8 g d Magnetic North is 1894 degrees East of True North (at 101252008) w 9.625n Casing Surface gn O. To correct azimuth from Magnetic to True add 1890 de grees 0) 0 1875 nd of Tangent 0) 2250 4.00°/100ft I- Easting (ft) Scale 111011.6005 -2100 -1800 -1500 -1200 - 900 -600 -300 0 i 28 25 1 '.-- , End of Drop 16in Cmdudor 211-33 Target#1 (22- Sep -08) 0 211 -33 3000 Z 9.6251n Casing Surface b.- o 2.00 71008 P. -300 5 (] 3375 7in Liner End of Crop 21133 T (22- Sep -0B) 21133 TD D Target (22-Sep-08) -600 3750 I 7in Liner -car End of Tangent 211-33 TD Target (22-Sep-08) 4125 -2250 -1875 -1500 -1125 - 750 -375 0 Vertical Section (ft) Scale 1 inch = "9 n Azimuth 90.00 °with reference 0.00 N, 0.00 E • • tri Chevron Ma , um Anticipated Surface Pressure Calculation Swanson River SRU 211 -33 Kenai Peninsula_ Al U 1 RSE E Assumptions: ' 1� " .l 1. Based on offset drilling & production d- -, the pore l _ be,A4 t• 4.440 psi /ft in the Sterling A & B sands with a 0.440 psi /ft gra.'ent in the Beluga at a total depth of 3,833' TVD RKB 2. The M.A.S.P. during drilling operations will - governed by the 9 -5/8" shoe frac gradient, - d is calculated based on a full column of gas between the 9 -5/8" shoe a ' the surface. The shoe f or SRU 211 -33 , 1643' TVD will be above the shoe depths of recent offset wells in Swanson RI r, ranging from 1950' to 2023' TVD. - k -off or formation integrity tests ranged from 14.3 ppg to 21.1 ppg (0.744 psi ' and 1.100 psi /ft). This offset LOU, data from nearby wells useful for relatively accurate kick tolerance & MASP calcu tions. 3. The M.A.S.P. during production operations will be t - estimated SIBHP minu e gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Life: Max. pore pressure at T.D. = 3,833 ft. 0.440 psi /ft = 1687 psi M.A.S.P. (tbg leak at surface) = 1687 • .1 - (0. psi /ft * 3,833 ft) = = 1303 psi M.A.S.P. While Drilling 8 -1/2" hole at 3,833' TVD: Max. Est. Frac pressure at 9 -5/8" shoe = 1643 ft. x 0.. psi /ft = 1117 psi M.A.S.P. during drilling = 1117 psi - (0.1 psi /ft x •43 ft.) _ = 953 psi -jam - -- 41° Calculation & Casing Design Factors Chevron Swanson River SRU 211 -33 Kenai Peninsula, Alaska WELL: - U 211-33 FIELD: Swanson River DATE: 24-Sep -08 DESIGN BY: Stan Porhola Sect, 1 12 1/4" hoi= ■ UD WT. 9.0 PPG MASP= 953 psi ** Sect. 2 8 1/2" hole • ' 9.3 PPG MASP. 1,303psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM wio TENSION WO' CASE MASP YIELD WORST CASE • SECTION CASING BOTTOM TOP LENGTH WT. RADE THREAD LBS LBS 1000 LBS SF TENSION PSI *, PSI F COLL. PSI ** PSI SF BURST 1 9-5/8" 2,000 0 2000 40 :0 BTC 80,000 80,000 916 11.45 743 3,0'. 4.16 999 5,750 5.76 TVD 1,643 0 2 7" 4,652 0 4652 26 L -80 BTC 120,952 120,952 604 4.99 1,733 5,410 3.12 1,374 7,240 5.27 ND 3,833 0 EE * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.440 psi/ft - • • the casing evacuated fo internal stress (0 psi/ft) t *._.ti r ** See attached sheet for calculation of MASP . p aai o Fn • • Chevron Swanson River Unit SRU 211 -33 Gas Well Cement Program 16" Casino (► iven to +/ -102') Note: This strin• 's only for structural support of the wellhead and diverter system. 9 -5/8" Casin • 12 -1 " Hole to 2 000' MD : Cement volume based • annular volume plus 100% open hole excess - d shoe joint(s). The job will consist of a 1 =-d and tail and cement will be brought to surf- e. The estimated total volume is as follows: Lead: 1500' X 0.3132 c ft (12 -1/4" x 9 -5/8 ") X 2.0 = 940 c = 405 sxs (2.32 yield) Tail: 500' X 0.3132 cuft/ft ' 2 -1/4" x 9 -5/8 ") X 2.0 = 313 , ft = 263 sxs (1.19 yield) 80' shoe joint X 0.4257cuft/ft = cuft = 29 sxs (1.19 yield) TOTAL: 940 + 313 + 34 = 12: • cuft or 697 .xs SUPERSEDEC 7" Casing (8 -1/2" Hole to 4,652' MD): Cement volume based on annular volume p •% open hole excess and shoe joint(s). The job will consist of a lead only and cemer will • brought to 2,000' MD (Previous shoe). The estimated total volume is as follows: Lead: 2,652' X 0.1268 cuft/ft (8- " x 7 ") X 1.5 = 04 cuft = 332 sxs (1.52 yield) 80' shoe joint X 0.2148 cuft/ = cuft = 11 sxs (1.52 yield) TOTAL: 504 + 1 = 521 cuft or 343 sxs 9 Cement Program 211- 33.doc 1 9/24/2008 • • Chevron %101 Swanson River Unit SRU 211 -33 Gas Well Cement Program Cement pe and Design: Surface Casi ' , 9 -5/8 ", Lead Cement Type: Class G Density: 12.2 pp• Cement: 405 sx UP'ERED Yield: 2.32 ft3 /sx /(0(ti—k Mix Water: 13.52 gal Slurry Volume: 168 bb Additives: D046 0.200% BWOC A 'foam S002 2.000% BWOC Acc. erator D079 3.000% BWOC Exte • er Surface Casing, 9 -5/8 ", Tail ment Type: Class G Density: 15.8 ppg Cement: 292 sx Yield: 1.19 ft /sx Mix Water: 5.18 gal /sx Slurry Volume: 62 bbl Additives: 0046 0.200% BWOC Antifoam S002 1.000% BWOC Accelerator D153 2.000% BWOC Anti - settling Production Casing, 7 ", Lead Cemen chlu •erger LiteCRETE) Type: Class G Density: 12.5 ppg Cement: 343 sx Yield: 1.52 ft /sx Mix Water: 4.87 gal /sx Slurry Volume: 93 bbl Additives: D174 0.100% BWOC E sanding Agent 0046 0.600% BWOC ' ntifoam D065 0.400% BWO ' ' ispersant D500 0.745 gal /sx GasBLOK LT D135 0.106 gal/ GasBLOK Stabilizer 9 Cement Program 211- 33.doc 2 9 24/2008 • • Chevron Swanson River Unit 10 10 SRU 211 -33 Gas Well Mud Program Surface Hol Recommendations Mud Type: S • d Mud (Water- based) Properties: Depth Densi Viscosi Plastic Viscosity Yield Point API F �H 0 -2000' 8.6 -9.2 70 -250 10 -30 25 -40 • 8.5 -9.0 System Formulation: Sp • Mud (Water- based) Product Concentration Water 0.95 bbl Aquagel 25 ppb (35 - 40 YP) X -Tend II 0.10 ppb Caustic soda 0.20 ppb (9.0 pH) Soda Ash 0.20 ppb Production Hole Recommendation Mud Type: 6% KCI, EZ Mud (Water -base. Properties: Depth Density Viscosity PV YP API FL pH 2000' — TD 9.0 — 9.5 40 - 50 6 -15 -25 <5 8.5 — 9.5 System Formulation: 6% KCI, EZ M (Water -base Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlori• - ) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 3 P) PAC L 1 ppb Dextrid 1 ppb EZ Mud DP 0.75 ppb (.15 initially) Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb (maintain per dilution rate Baroid As required* *There will be an ade ate stock of Barite on location to increase mud weight by 1.5 p, for entire mud system Monitoring uipment to be used on the circulating system: • Flo how — Gauge for returns • P' olume Totalizer System • ud /Gas Detection System for Methane and H 10 Mud Program 211- 33.doc 1 9/24/2008 • • Chevron Swanson River Unit SRU 211 -33 Gas Well Drilling Waste Plan Drilling Waste Plan The water -base mud cuttings will be hauled by Super Sucker from the SRU 211 -33 well location to the newly constructed Solid Waste Processing Facility (SWPF), located on the same pad as well SCU 243B -4 (PTD No. 199 -055). The solids will be stored until a grind & inject unit is mobilized to dispose of other Class II waste from future remediation projects within Swanson River. Liquids and used mud will be hauled by vacuum truck and injected in SCU 43 -04WD (a.k.a. SCU 243 -4MD) (PTD No. 161 -029) Class II disposal well located on the adjacent pad to the SWPF. A portable injection skid and tanks will be utililzed for injection of Class II liquids and used mud, including liquids that accumulate in the SWPF. The contingency plan in case the SWPF would become inoperable for any reason is twofold. First, the cuttings may be loaded into tanks for storage until the SWPF is operational. Second, the cuttings may be hauled to an offshore location on the Bruce Platform for injection in the Class II disposal well Br -3 -87 (PTD No. 166 -052). If SCU 43 -04WD were to become inoperable for any reason, fluids would be stored in portable tanks until a time that well intervention by slickline, a -line, and /or coil tubing were able to bring the service well back online. 11 Drilling Waste Plan.doc 1 9/24/2008 • Chevron Swanson River Unit SRU 211 -33 Gas Well Log /Core /Test Programs LOGGING Surface Hole, 12 -1/4" 0' - 2,000' MD: MWD: Directional LWD: None Open Hole: None Cased Hole: None Production Hole, 8 -1/2" 2,000' - 4,652' MD: MWD: Directional LWD: Gamma Ray Open Hole: Gamma Ray, Resistivity, Density, Neutron, Sonic, FMI (resisitivity) Cased Hole: USIT (If cement coverage is questionable) CORING None Planned TESTING Following rig demobilization, flowing testing of the well will be thru buried flowline from the well location to the TS 1 -33 (Tank Setting) production facilities. All fluid volumes will be metered. 12 Log- Core -Test Programs 211- 33.doc 1 9/24/2008 • • %. Ch evron ESTIMATED GEOLOGIC TOPS AND CORRELATIONS SRU 211 -33 Elevation 186.0 RKB 206.5 Zone / Pore Depths ( +/- 50') Marker Lithology Fluid Target* Press (ppg) MD TVD TVDSS Shallow Aquifers Cong /Sand Water N/A 8.5 0 -2112 0 - 1700 0 - 1493 Sterling -A6ST Sand Water Offset Disposal 8.5 2779 2077 1870 Sterling -A9 Sand Water Offset Disposal 8.5 3078 2309 2102 Sterling -B2 Sand Gas/Water Primary 7.8 - 8.1 3531 2721 2514 Sterling -B3 Sand Gas/Water Primary 7.8 - 8.1 3635 2821 2614 Sterling -B5 Sand Gas/Water Primary 7.8 - 8.1 3840 3022 2815 Beluga 36 -9AST Sand Gas/Water Secondary 8.5 4301 3482 3275 Beluga 39 -1ST Sand Gas/Water Secondary 8.5 4522 3703 3496 TD Silt/Sand Gas/Water Well TD 8.5 4652 3833 3626 *Current Cement Design will isolate all fresh water and hydrocarbon zones. 9 -5/8" Casing Cement to Surface 7" Casing Cement to 9 -5/8" shoe @ 2000' MD / 1643' TVD • Chevron LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drilipipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. A non - permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure -vs- cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of Teak -off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drilipipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The Teak -off pressure is calculated as follows: Leak -off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. B' p SURFACE PRESS. TYPICAL PIT PLOT (psi) A VOLUME PUMPED SHUT -IN -TIME (BBLS) (MIN] NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. • • 29 28 32 33 SECTION LINE N 2466265.726 % %ss,ikAi'% E 1482434.646 41.4 .... OF A� gfl, *14 A % 0 j ..M. SCOTT McLANE. i IA - AS- STAKED WELLI b 49288—S Zir SRU 211-33 � "'9 � � , N:2465769.782 1 N % � `' E: \ \ �� LATITUDE: 60 °44'47.313 "N W Z LONGITUDE: 150 °52'16.619"W W Q LL ASP ZONE 4 NAD83 Z U c FWL = 210T J ` FNL =468' Z o ELEV = 186.0' (NAVD88) U SECTION 33, TOWNSHIP 8N, W O RANGE 9W, SM, AK (A Z / 2107' FWL s ��� I N 2 05a�� 46251 S 221 -33 PAD CC ESS ROW E 1484576 937 P �. ABANDONED j \ 3 � �, EDGE OF PAD ___ �� � J+"' TO OF BERM _______ SEC 33 _ NOTES 1) BASIS OF COORDINATES: NGS OPUS SOLUTION FROM DORS NORTH "ZAN1 ", 'TBON" AND "TSEA" ALASKA STATE PLANE ZONE 4 NAD83 .►: �' EPOCH 2003. --[� 2)BASIS OF ELEVATION: NGS BM Q79 RESET 1991 NAVD88. 3) SECTION LINE OFFSETS COMPUTED FROM BLM CORNERS SCALE FOUND AT Y4 S32 S33, NW Ye S33 3 N Ye S32 S33 AND USED TO 0 100 200 COMPUTE NW CORNER S33 COORDINATES SHOWN . / I , 1 , I ■ SRU 211-33 Chevron AS- STAKED SURFACE LOCATION p�� SWANSON RIVER FIELD LOCATION: SECTION 33, TOWNSHIP 8 NORTH, /11 ENGINEERING - TESTING RANGE 9 WEST, SEWARD MERIDIAN ALASKA SURVEYING - MAPPING P.O. BOX 468 00 SOLDOTNA, AK. 99669 JOB NO 083077 VOICE: (907) 283 -4218 FAX: (907) 283 -3265 DWG. Consiaing Inc WWW.MCLANECG.COM 083077 SRU211- 33REV2 Date: 8/11/08 FIGURE: 1 • • 4 3 2 1 6 r---.1 i -- -! t - -, A028405 3 9 - - ---° 10 1 - - -- i _- 1 2 7 r•• -• t j 1 . j A028077 ! 13 17 ! ! 1 15 14 13 18 i6 r r 1 I i 1 i . r'•- i A028384 8N1OW 8N9 `.._ 1 �� 24 19 20 i21 23 .c 24 �._.._.. 22 i 8N8W i i • 8 _•• -: A028406 rr I • 25 30 29 A028399.--i ___ PROPOSED LOCATIO�J # 7 j 2 5 3 C SRU 21 ! r i 1 ,-F# F 1 , 1 ~ w i A028990 A028396 1 -. - - -; 33 34 ! 3 5 - 31 3,2._! t • y 4v i 3 0 i 1 I • y t I 6 i_.._.._..5 t 4# 3 i 2 1 1 . • - -1 6 A028996 ' tU -r A028997 7N1 OW r.• - -.! � 7N9W 1 7N8W 12 8 -—� 9.+s 10 11 12 7 r 1 , 4.) I 4% A029002 -� � - - ..I \�``, 1 , 7/ 2' 13 10 j(il 1 1 6 A0 14 13 18 1 ._----- _.._..1 15 ``„ - CIRI 5809 Chevron o 0.5 1 lipal Union Oil Company SWANSON RIVER FIELD miles " ` 4 1 of California Proposed Location SRU 211 -33 Alaska State Plane Zone 4, NAD27 July 9, 2008 . • 29 r i ! 28 27 SRU 34 -28 SRU 21 33WD 81N9W i SRU 41 -33WD SRU 41 -33 SRU 31 -33WD SRU 32- 33WD Av. SRU 32 -33 SRU 32A -33 34 - ` 5 4 7N9W 3 Chevron SWANSON RIVER FIELD 0 250 500 1,000 IWO Union Oil Company IWO ofCalifomia y Proposed Location SRU 211 -33 Alaska State Plane Zone 4, NAD27 3000 ft Radius July 9, 2008 • 0 Chevron DIVERTER STACK -UP Date - September 24, 2008 Location - SRU 211 -33 %Oil Rig - Nabors 106E Mil W �� Stack: Size - 13 5/8" Pressure Rating - 3000 PSI Nace Trim - Yes Iel lel MI ISO IMO MO 101 Annular: Make - Hydril Pressure Rating - 5000 L - _ _, 1 Nace Trim - Yes 181 PSI1l1 IeIIeIIRI - :P 1. ow Imo �0 . - ' Knife Valve: Make - FNW ' Model - 61 B MI : 35 WI ' Tee: Make - VG Model - S137 : it :: im.. Closing Unit 181/01101 1011o11at Matting ; 0.50' I ill Make - Academy O =M li k Model Number H180T (�1: Designed Pressure Rating - 3000 sal 1 N1_INI— IIII.INI INI 'uX zFi:ia Accumulator: Number of Bottles - 12 IaIIacw 1Y11M11Y1 - Gallons /Bottle - 15 Ir.? . All ( I � '( i ► E1 Total Volume - 180 Iaeeulsl- 1su1sn61 Pre- Charge Pressure - 1000 '' Outlets: Size - 4" Valve Ball I! NABORS 106E • BOP DATA Chevron Date - September 24, 2008 Location - SRU 211 -33 Rig - Nabors #106E Depth - 102' MD • 12.30' Stack: Size 13 -5/8 in Pressure Rating 5000 psi 20.03' Nace Trim Yes 15.58' I Annular: Make /Model Hydril : - - Pressure Rating 5000 psi 3.45' - rtn rrn rt=n r•T ii Or • - _ Ram: Make /Model Shaffer SL VBR II. Pressure Rating 5000 psi 12.16' ■ 0 ■ OBI 161161 161 181101 KILL LINE CHOKE LINE �� _ Ram: Make /Model Shaffer SL Blind II. l ' = � �� Pressure Rating 5000 psi 2.86' Ma SIN 111112 Ram: Make /Model Shaffer SL Pipe gp Pressure Rating 5000 psi Li ih.. „, I. Epp , , Kill line: Line size 2 inch Valve (1st) Manual Valve (2nd) HCR 3.33' Chock line: Line size 3 inch Valve (1st) Manual Valve (2nd) HCR • 0.35' _0" so ilo_i elmo Sal JI atting I $ 0.50' III rJ (I' {* 1 Total Volume = 101 1s1- 101 - 101.101 101 6c :0 :I. ■ Casing Make /Model VG MB -242 m or ms sor 161161 Bowl: Pressure Rating 5000 psi __ Well ° Il III { 'I Closing Unit Is1./01 -101- 101 -101 101 Make Academy Model Number H180T Oa, 1 � Designed Pressure Rating 3000 19.68 Rig KB Heights Top of Multibowl r" <. Accumulator: Number of Bottles 12 Gallons /Bottle 15 20.35 Upper Load Shoulder Total Volume 180 (upper test plug) Pre- Charge Pressure 1000 (Intermediate casing hanger) Percent Useable Fluid 67 Useable Volume 121 24.04 Lower Load Shoulder (lower test plug) Nitrogen: Number of Bottles 4 (Surface casing hanger) Bottle Height 15 Average Pressure 2600 Equivalent Gallons of Useable Fluid /Bottle 10 Form DRI G -01. Mav /2001 Useable Capacity 40 I Materials List I Item Description Nabors Alaska Drilling Rig - 106E 1 2- 1/16" 5M Manual Valve 2 -14 3 -1/8" 5M Manual Valves A 3- 1/16" 5M Hydraulic Choke B 3 -1/8" 5M Manual Choke To Gas 1 - — . Buster From VIEW BOP's �- j__ VIEW .i !l � CC - / BB I___ jr__ .0.---- ' " 1-44.*". Y1 (*.. 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DD1111 } } 5,23 - 11 027 0 ES 01 iii r ......_. ■id RIG 106 _ ENCLOSED ME SHED te MODULES} 80 TROMPSON METAL FAR # i Shannon W. Martin Chevron North America Chevron Land Representative Exploration and Production 1411011 MidContinent/Alaska 909 West 9 Avenue P.O. Box 196247 %10 Anchorage, AK 99519 -6247 Tel 907 263 7872 Fax 907 263 7898 Email smartin @chevron.com October 1, 2008 Chair Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 PERMIT TO DRILL Swanson River Unit (SRU) 211 -33 well Federal Lease No. A- 028399 Dear Chair Seamount: Union Oil Company of California's (Union) is planning to drill its Swanson River Unit (SRU) 211 -33 well in the Swanson River Field with an anticipated spud date of October 23, 2008. In accordance with 20 AAC 25.005 (a), a Permit to Drill and associated filing fees are being filed contemporaneously herewith. A spacing exception is not required for the reasons set forth be- low. The Anticipated Productive Interval for the SRU 211 -33 well is the Sterling B -sands, and a dis- covery would establish a firm geologic basis for expanding the Sterling/Upper Beluga Participat- ing Area and SRU boundaries. The legal description of the SRU 211 -33 well is as follows: Surface Location 468 FNL 2107 FWL Sec 33 T8N R9W S.M. Top of Productive Interval Location 952 FNL 265 FWL Sec 33 T8N R9W S.M. Projected Bottom Hole Location 977 FNL 171 FWL Sec 33 T8N R9W S.M. 20 AAC 25.055 provides in pertinent part: (a) The commission will, in its discretion, establish drilling units to govern well spacing and prescribe a spacing pattern by pool rules adopted in accordance with 20 AAC 25.520. In the absence of an order by the commission establishing drilling units or pre- scribing a spacing pattern for a pool, the following statewide spacing requirements ap- ply: MidContinent /Alaska /Chevron North America Exploration and Production www.chevron.com I • Chair Dan Seamount Alaska Oil and Gas Conservation Commission October 1, 2008 Page 2 (2) for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (4) if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in that pool on any governmen- tal section; a well may not be drilled or completed closer than 3,000 feet to any well - drilling to or capable of producing from the same pool. As depicted on the attached plat, the 211 -33 wellbore will be open to test production within 1,500 feet of the lease line between A- 028399 and A- 028396. However, Union is the sole work- ing interest owner of such leases, and the landowner /royalty owner is the same on both sides of the lease line (i.e., CIRI and the Bureau of Land Management), and therefore, a spacing excep- tion is not required under 20 AAC 25.055 (a)(2). Also, as depicted on the attached plat, the drilling of well SRU 211 -33 will not cause more than one well to be drilled to or completed in the same pool (i.e., Sterling B- sands) within Section 33 T8N R9W. Moreover, even if gas is discovered, SRU 211 -33 will not be drilled to or completed closer than 3,000 feet to any other well drilling to or capable of producing from the Sterling B- sands. For these reasons, a spacing exception is not required under 20 AAC 25.055 (a)(4). If you require additional information regarding Union's Permit to Drill, please contact Stan Por- hola, drilling engineer at 263 -7640, or the undersigned at 907 - 263 -7872. Very truly yours, t.✓.A Shannon W. Martin cc: Kim Cunningham, CIRI Greg Noble, BLM MidContinent /Alaska /Chevron North America Exploration and Production www.chevron.com • • ATTACHMENT 1 29 3000 ft I Lease No. A028399 SRU 34 -28 1500 ft ! PROPOSED SURFACE LOCATION SRU -33 PROPOSED TOP TARGET LOCATION ! 1 SRU 211 -33 SRU 21 -33WD SRU 41 -33WD SRU 41 SRU 31 -33WD PROPOSED BOTTOM SRU 32- 33WD SRU 32 -33 HOLE LOCATION SRU 211 -33 SRU 32A -33 Lea e No. A0, 2.8,396 ..ix /33 i._.._.._.._.._.._..i L e a s e No. A 0 2 8 9 9 0 8N9W liease No. A028996 7N9W Lease No. A028997 Chevron SWANSON RIVER FIELD 0 250 500 1,000 Union Oil Company F�_ . 14. Of California Proposed Location SRU 211 -33 Alaska State Plane Zone 4, NAD 83 1500 ft and 3000 ft Radius September 23, 2008 lmnbaa. l:. l.at.,WOk_ tieWaps,DEavinroI.SRF -Proposed- aoaoocn+.aus_wz mxa Page 1 of 2 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 07, 2008 4:05 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SRU 211 -33 -Again Stan, As I was finishing my review, I looked at the aquifer exemption for Swanson River Field. According to 40 CFR 147.102(b)(1)(i), all aquifers are exempted below 1700' tvd. You plan to set the surface casing at - 1643' tvd. It appears that the planned surface casing depth is insufficient. Please get back to me with a revised surface casing depth. At a minimum, it would appear that the surface casing shoe depth should be increased by 100' tvd. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, October 07, 2008 10:44 AM To: 'PORHOLA, STAN T Subject: RE: SRU 211-33 Stan, Thanks for the reply. I will hand correct the md. With regard to MASP and BOP rating, I think we are fortunate that the available equipment is generally 5K. In the case of 105E, the 5 K rated equipment give you significantly more options than just a 2 K system. Please note, the 3000 psi value is only with regard to the BOP test. The 2000 psi test planned for the tubing and casing appears to be more than adequate. Thanks as well for the schedule. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [ mailto :stan.porhola @chevron.com] Sent: Tuesday, October 07, 2008 10:12 AM To: Maunder, Thomas E (DOA) Subject: RE: SRU 211 -33 Tom, 1.) The MD should be 4652'. That 5500 is an erroneous error. 2.) The cement will enter the 9 -5/8" shoe. We will not pump down the 9 -5/8" x 7" with mud to clear. 3.) The 3000 psi would not exceed any design limits. I was under the impression that if you were under 2000 psi MASP, then you would only be required to have a 2M BOPE. All the BOPE equipment for 106E will be 5M. The BLM has BOPE requirements for 2M, 3M, 5M, etc. These may not all have a correlation to AOGCC regs. If 3000 psi is required, we won't have any issues with testing the BOPE and Casing to this pressure. 4.) Nabors 106E is currently moving to SCU 312 -09. Following this workover, the rig will move to SRU 211 -33. The workover is scheduled for 2 weeks. If there is a minimal of downtime, the rig should be available to move to SRU 211 -33 around Oct 21st, with spud to follow around Oct 28th. I've previously submitted an NOS (Notice of Staking) to the BLM so their 30 day minimum requirement for review has been met. Greg Noble (while Tom Zelenka is on vacation) received the APD the same date as the AOGCC. Thanks for the quick response. Let me know if you need any additional information. 10/7/2008 Page 2 of 2 • • Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 -3322 Tel 907 263 7640 Fax 907 263 7884 CeII 907 229 1769 stan. porhola©chevron. com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 07, 2008 9:26 AM To: PORHOLA, STAN T Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett) Subject: SRU 211 -33 Stan, I am beginning review of the permit application for this well and have some comments /questions. 1. The and given for the 8 -1/2" hole is given as 5500' on the 401 sheet, however wherever else the 8- 1/2 "/7" casing TD is listed it is 4652'. So far as I can tell, the tvd given is always 3833'. What is the correct planned and for the 8 -1/2" section? 2. You state that it is planned to raise the 7" cement to the surface casing shoe. Is it intended to cement into the 9 -5/8" shoe or will the "shoe be cleared" by pumping some mud? 3. You indicate a planned BOP test pressure of 2000 psi which is in excess of MASP. I am reluctant to endorse this test pressure. As I remember 3000 is generally the minimum test pressure required. This should not affect your planned casing or tubing tests. 4. How real is the October 23 spud date? I may have other comments; however I wanted to get these to you. Tom Maunder, PE AOGCC 10/7/2008 • • TRANSMITTAL LETTER CHECKLIST WELL NAME a// �3 PTD# 2Of /5 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: �Sh/R4 S WY E/ POOL: � 'UHG /C/��e2' . eZuos9 C--) 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(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/112008 WELL PERMIT CHECKLIST Field & Pool STERLING, UP BELUGA UNDEF GAS - 768530 Well Name: SWANSON RIV UNIT 211-33 Program DEV Well bore seg El 1 PTD#: 2081520 Company _UNION OIL CO OF CALIFORNIA Initial Class/Type DEV / PEND Geo Area 820 Unit 51994 On/Off Shore On Annular Disposal L] Administration 11 Permit fee attached NA 2 ,Lease number _appropriate Yes 3 Unique well n_ame_and number Yes 4 Welllocatecl in a defined pool Yes Sterling / Upper Beluga 5 _Well_locatecl proper_distance from drilling u nit boundary Yes 6 _Well_located properdistance from other wells Yes 7 Sufficient acreage_ayailable in drilling unit Yes 8 ifdeviated, is wellbore plat inclu_ded Yes 9 Operator only affected party Yes 10 _Operator has_appropriate_ bond in_force Yes e1 sio3 671687Bcm. 11 Permit Gan be issued without conservation order Yes Appr Date 12 _Permit can be issued without administrative_approval Yes ACS 10/6/2008 13 Can permit be approved before 15-day wait Yes • 14 Welllocatecl within area and_strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells_within 1/4 mile area of review identified (For ser vice well only) NA 16 Pre-produced injector; duration_of pre-_production less than 3 months (For service well only) NA_ 17 Nonco_nven. gas_conforms to AS31 .05,0304, tA).4. 2.A-D) NA Engineering 18 Conductor string_provided Yes 19 _S_utface_casing_ protects all known USDWS Yes Surface casing planned a 1745' tvd. All aquifers exempted > 1700' tvd. 20 _C_MT_v_ol_ adequate_ to circ_ulate_o_n_conductor& surf csg Yes 21 _CMT voi adequate_ to tie-in_long _string to surf csg Yes 22 _C_MT_will coverall known productive horizons Yes 23 Casing designs adequate for 0, T, B & permafrost Yes 24 Adequate_tankage_ or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 _Ifs_ re-drili, has_a 1.0-403 for abandonment been approved NA 26 _Adequate_wellbore separationproposed Yes There are no proximate wells. 27 if_diverterrequired does it meet regulations Yes Requesting to drili 12-1/4" hole w/ 12" diverter line. This has been approved _previously. Appr Date 28 _Drilling fluid program schematic_& equiptistadequate Yes Maximum expected formation pressure 8.5 EMW. MW planned up to 9.5 p_pg. TEM 10/15/2008 29 _B_OPEs,_cto they meet regulation Yes III 30 _B_OPE_press rating appropriate; _test to_(put psig in comments) Yes MASP calculated at 1303 psi. 3000 psi BOP test adequate. N 31 _C_hoke_ manifold complies w/API RP-53 (May 84) Yes 32 _Work will occur without_operation shutdown Yes 33 is presence of 1-128 gas probable No H2S is not reported in CI gas production. 34 Mechanical condition of wells within AOR verified (Fo service well ortlY) NA Geology 35 _Permit can be issued vo/o hydrogen_ sulfide me asures Yes 36 _Data presented on potential overpressure zones NA Appr Date 37 _Selsrnic_a_nalysts of shallow gas zones NA ACS 10/6/2008 38 Seabed condition survey (if off-shore) NA 39 Contact _name/phone for weekly_progress reports [exploratory only] No Geologic Date: Engineering Public Date Union is the sole working interest owner of both leases A-028396 and A-028399 and the landowner/royalty owner is the same Date Commissioner: Commissioner: Commissioner on both sides of the lease line. 0 4 2, ,y1 7GL- 21. , . • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0 FINAL WELL REPORT MUDLOGGING DATA Swanson River Unit SRU 211 - 33 id -r It', , ,' • l s 4 = - : , , ..' --." " *,- . .,, - , i:: cgs `'-- ` - ` 4,,.t... x . ..�.. .. Provided by: El EPO Approved by: Kevin Eastham Compiled by: Larry Resch Tollef Winslow Date: 12/04/2008 • Distribution: 12/08/2008 _ 1 -L/ ,D Chevron SRU 211 -33 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 3 1.1 Equipment Summary 3 1.2 Crew 3 2 WELL DETAILS 4 2.1 Well Summary 4 2.2 Hole Data 4 3 GEOLOGICAL DATA 5 3.1 Mud Log Summary 5 3.2 Connection Gas Summary 10 3.3 Trip/Wiper Gas Summary 10 3.4 Sampling Program / Sample Dispatch 10 4 DRILLING DATA 11 4.1 Daily Activity Summary 11 4.2 Survey Data 12 4.3 Bit Record 14 4.4 Mud Record 15 5 MORNING REPORTS 16 Enclosures 2 "/100' Formation Log (MD and ND) 2 "/100' Gas Ratio Log (MD and TVD) 2 "/100' LWD / Lithology Log (MD and ND) 2 "/100' Drilling Dynamics Log (MD and ND) • El EPOCH 2 Chevron I MO SRU 211 -33 • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer — Drill Floor Monitor Azonics 0 Computer — Pit Monitor Azonics 0 Computer for Company Man Rigwatch Remote (HP Compaq) 0 Computer for Mud Engineer Rigwatch Remote (HP Compaq) 0 Computer for Toolpusher Rigwatch Remote (HP Compaq) 0 Computers for Mudloggers (3) Data editing, Rigwatch Master, and 0 R Remote (all HP Compaq) QGM Agitator (Mounted in possum Ditch gas belly) 0 Flame ionization total gas & chromatography. Hook Load / Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes /Minute and 0 Pump Output Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain /Loss 8 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters (2) 2 proximity sensors 0 III Rate of penetration RPM Crown Sheave proximity sensor 0 PLC feed 0 Torque PLC feed 0 1.2 Crew Unit Type : Arctic Unit Number : ML030 Mudloggers Years Days Sample Catchers Years Days Technician Days Larry Resch 5.5 9/9 Justin VanderBerg .5 7/9 Tollef Winslow 1 9/9 Jeff McBeth .5 7/9 *' Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. • PI EPOCH 3 Chevron SRU 211 -33 . 2 WELL DETAILS 2.1 Well Summary Well: SRU 211 -33 API Index #: 50- 133 - 2058 -00 -00 Field: Swanson River Unit Surface Co- Ordinates: 468' FNL, 2107' FWL Sec. 33 T8N R9W S.M. Borough: Kenai Borough Primary Targets: Beluga Sands State: Alaska Primary Target Depth: 4641'MD/3833'TVD Rig Name / Type: NAD 106E /Arctic TD Depth: 4760'MD/3956'TVD Spud Date: 11/20/2008 Ground Elevation: PAD 186.0' MSL TD Date: 12/02/2008 KB Elevation: RKB 206.5' MSL Days Drilling: 27 TD Formation: Tertiary- Beluga Completion Status: P & A Days Evaluating: 1 Classification: Gas Exploration III 2.2 — Hole Data Hole Maximum Depth TD Mud Dev. Casing/ Shoe Depth FIT MD TVD Weight o. MD TVD Section (ft) (ft) Formation (ppg) (ft) (ft) (ppg) Conductor 102 102 Unknown -- -- -- 102 102 -- 12-1/4" 2106 1762 Sterling 9.2 56.10 9 -5/8" 2097 1762 12.5 8 -1/2" 4760 3956 Beluga 9.2 _ 1.57 none • PI EPOCH 4 Chevron I WO SRU 211 -33 • 3 GEOLOGICAL DATA 3.1 Mud Log Summary 2106' to 4760' MD (1762' to 3956' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 259.3 5.2 163.5 55 0 12.9 TUFFACEOUS CLAYSTONE (2106' — 2200') = light to medium Tight gray; very soft to slightly firm; poorly indurated with poor cohesion and moderate adhesion; mushy to curdy in part; amorphous fracture when wet; very hydrophilic; air dried samples readily hydrate, swell and crumble apart; hydrofissle in part; lumpy to slimy cuttings habit when firm; generally shaped by vibrating action of shaker; soluble, readily washes out when processing samples; dull to rarely earthy; generally smooth, clayey texture often gritty with extremely fine grain clasts; noncalcareous; occasionally interbeds with and grades towards a tuffaceous sandstone. SAND (2200' TO 2280') = unconsolidated; fine to medium grain; angular to rarely subangular with moderate to poor sphericity in part; fairly well sorted; very immature; predominately frosted, glass- like transparent and translucent quartz grains with abundant medium to medium dark gray mafics; transparent glass shards common; abundant secondary grains include shades of bluish green and greenish gray, reddish orange, translucent yellowish brown, individual grains often contain 411 secondary minerals, occasional biotite; interval interpreted to contain interbedded tuff and tuffaceous sands, material of which may be lost over shakers. no hydro- carbon indications. SAND AND TUFFACEOUS SAND (2280 - 2400) = very light gray to Tight gray with occasional light brownish shades; extremely fine to lower very fine grain when tuffaceous; often matrix supported occasionally grain supported with significant tuffaceous matrix; no visible porosity; noncalcareous; very hydrophilic; occasionally contains well entrained and poorly indurated carbonaceous material; interval contains significant unconsolidated fine to medium grain sand; angular to rarely subangular with moderate to good sorting and poor to moderate sphericity in part; generally appears salt and pepper in samples with frosted, transparent and translucent quart and abundant medium and dark gray mafic grains; reddish orange, pale yellow green, blue green translucent amber grains common; trace book -type biotite; extremely fine angular glass shards common; interval contains significant smooth to gritty tuffaceous clay, often with abundant disseminated quartz grains well entrained. TUFFACEOUS CLAYSTONE (2400' - 2520') = light to medium light gray, occasionally with light brownish shades, pale yellowish brown to light brown; very soft to soft, becoming more firm than previously seen; fair to moderate inundation with good adhesion and fair to moderate cohesion; lumpy to curdy in part; crumbly to often pulverulent; amorphous fracture, hydrofissle in part; generally nodular, rarely sub platy cuttings habit when carbonaceous material is present; samples vary from dull to sub waxy in part when smooth and primarily exists as tuff; generally dull to occasionally sparkly with increasing quartz grains and transparent glass shards; occasionally earthy with poorly indurated, bedded carbonaceous material; noncalcareous; generally hydrophilic; often very sandy; grades from a sandy claystone to a tuffaceous sandstone; unconsolidated sand continues to be significant. • El EPOCH 5 Chevron SRU 211 -33 SAND (2520' - 2640') = unconsolidated; fine to medium grain, angular to rarely sub angular with moderate to poor sphericity; moderate to well sorted; rarely poorly consolidated with abundant tuffaceous matrix, occasionally appears as tuffaceous claystone with abundant quartz content; generally appears salt and pepper with frosted translucent and transparent quartz, dark gray to medium gray mafics; secondary clasts vary throughout section with significant yellowish green and greenish gray, reddish orange, book- like micas, translucent yellowish brown to amber; occasional extremely fine glass shards but very localized and associated with more tuffaceous samples. no hydrocarbon indications. TUFFACEOUS CLAYSTONE /CARBONACEOUS SHALE (2650' - 2790') = very light to light medium gray, often with brownish shades; also pale yellowish brown to pale brown; firm; moderate to well indurated with good cohesion; crumbly to malleable in part; irregular to blocky, often sub platy; massive in part with significant tuff content; becoming dominantly sub platy with increasing poorly to often well indurated carbonaceous material; often contains detrital carbonaceous fragments, occasional microlaminae; grades from a carbonaceous claystone /shale to an earthy, dirty coal; woody carbonaceous detritus common; luster varies from dull to sub waxy when tuffaceous, dull to sparkly with increasing sand content, dull to earthy with significant organic content; noncalcareous; very to slightly hydrophilic; hydrofissle in part; fine to occasionally medium grain unconsolidated sands continue, occasionally consolidated and cemented with tuffaceous clay matrix. SAND AND TUFFACEOUS SAND (2790' - 2970') = light gray to grayish white, generally with pale yellowish brown shades; extremely fine to very fine angular grains with poor sphericity; noncalcareous; friable to brittle, often crumbly; varies from grain supported to matrix supported; generally transparent and translucent quartz with abundant medium and dark gray mafic grains; • reddish orange clasts, extremely thin glass shards and micas common; interval continues to contain significant unconsolidated sand = very fine to fine, Tess commonly medium grained; angular to rarely sub angular with poor to occasionally moderate sphericity and poor sorting; slightly conglomeratic in part with fragments of medium sized irregular but well rounded grains; samples appear salt and pepper with approximately evenly represented translucent, transparent and frosted quartz versus dark and medium gray mafics; greenish blue and pale green, reddish orange and translucent amber grains common; quartz grains containing book -like biotite rare but noteworthy; no hydrocarbon indicators. TUFFACEOUS AND CARBONACEOUS CLAYSTONE (2970' - 3090') = light to medium light gray with definite brownish shades, pale yellowish brown to moderate dark brown; firm; moderate induration with good cohesion and adhesion; samples vary from smooth clay /tuff, often with significant glass -like shards and trans- parent to translucent quartz grains; grades to a tuffaceous /argillaceous sandstone in part; slightly silty in part; significant amounts of earthy to argillaceous carbonaceous material closely resembling a carbonaceous shale; carbonaceous materials appear as poorly indurated, immature coal and scale -like to sub platy detrital fragments; occasionally seen as streaks in smoother clay samples; 3030' -3060' interval contains pale yellowish to slightly brownish yellow clays with well entrained carbonaceous clasts, frosted quartz and reddish orange fragments; interval also contains some very coarse well rounded grains with fair to occasionally good sphericity. SAND (3060' - 3120') = unconsolidated; very fine to medium grain, occasionally to upper coarse grain; dominantly angular with poor sphericity; occasional well rounded pebbles with fair to good sphericity; poorly sorted; salt and pepper appearance with frosted to translucent and transparent quartz; abundant dark and medium gray mafics; a variety of grayish green, pale yellow green, bluish green, amber to translucent yellowish brown, reddish orange and smoky gray grains; disseminated El EPOCH 6 Chevron SRU 211 -33 • book -like biotite common; extremely fine grain quartz consolidated sand with tuffaceous matrix thinly interbeds with arenaceous clays /tuffs. CLAYSTONE (3120' - 3270') = dominantly as previously described with the appearance of pale yellowish green to grayish green; soft to firm with good adhesion and moderate cohesion; fair to moderate induration; lumpy to curdy in part; pulverulent; noncalcareous; slightly hydrophilic; amorphous to rarely blocky fracture in part; nodular to sub tabular cuttings habit; dull to sparkly in part with abundant extremely fine transparent quartz; arguably slightly silty in part based on component grain size; grades to an argillaceous sandstone with increasing depth; interval continues to exhibit earthy carbonaceous claystone and unconsolidated sands as seen above. SAND (3270' - 3390') = unconsolidated gray; lower coarse to lower medium grains with an occasional very coarse grain; subangular grains with low sphericity; translucent and clear quartz grains mixed with dark lithics; as the interval increases, green lithics and volcanic material increase. CONGLOMERATIC SAND (3360' - 3480) = grayish white; upper coarse to lower coarse grains; sub rounded to sub angular with moderate sorting; very poorly consolidated; grain supported matrix; cement is volcanic in origin; immature texture; matrix is composed mostly of quartz with accessory lithics including carbonaceous material and fine grained sandstone. CLAYSTONE (3420' - 3480') = light gray to gray; poor induration; crumbly to crunchy tenacity; cuttings habit is massive with an earthy luster; gritty texture and massive structures with encased organic material without any visible structure CONGLOMERATE SAND /CARBONACEOUS SHALE CONTACT NOTED IN 3450' - 3480' • SAMPLE = light gray to grayish white coarse grains angular in nature; poorly sorted; matrix is volcanic glass supporting quartz grains; 75% volcanic glass, 25% clear quartz; this conglomerate sand is in contact with carbonaceous shale which is predominately black with thin brown beds; well indurated; planar fracture; platy habit; matte luster and thin structure. TUFFACEOUS CLAYSTONE (3480' - 3570') = gray to light gray with some green tinting; soft and poorly indurated; crumbly to crunchy tenacity; hackly texture; massive cuttings; dull luster; clayey texture and massive structure. CARBONACEOUS SHALE (3560' - 3570') = dark brown; moderately indurated; crumbly tenacity; platy habit; earthy luster; matte texture; thin structure; no accessory elements; noncalcareous. with coal (3560' - 3570') = black; firm; tough tenacity and planar to irregular fracture; massive cuttings habit; thinly laminated beds; no fossils or accessory minerals. TUFFACEOUS CLAYSTONE (3365' - 3660') = light to medium gray; mushy to curdy in consistency; crunch to crumbly tenacity; massive cuttings habit; dull luster with clayey texture and massive structure. SAND (3640' - 3660') = unconsolidated; translucent to clear grains; lower medium to course; well sorted; subangular to angular; moderate sphericity; predominately quartz with small amounts of green grain volcanic lithics also present. TUFFACEOUS CLAYSTONE (3360' - 3700') = light gray to gray; crumbly with poor to moderate induration; cuttings are massive with dull luster and clayey texture; there is no observable structure, • however carbonaceous material is present in some cuttings. EPOCH 7 Chevron SRU 211 -33 SAND (3700' - 3800') = unconsolidated; fine to medium grain, often upper medium to lower course, occasionally very fine grain; angular to rarely sub angular, occasionally well rounded when very coarse, possibly as pebble fragments; predominately poor sphericity, poor sorting; locally fine grain and matrix supported with tuffaceous /argillaceous matrix; noncalcareous and very hydrophilic, more an arenaceous claystone in part; salt and pepper appearance with frosted to translucent, often glass -like transparent quartz; abundant dark gray and medium to dark gray mafics; secondary components include abundant green, yellowish and bluish green, reddish orange, pale yellowish brown and translucent amber; multi - mineral clasts common; biotite often appears as disaggregated individual and book -like flakes, occasionally part of clasts; traces of thinly interbedded earthy claystone, often with carbonaceous material and very immature coal. CLAYSTONE, SILTSTONE AND CARBONACEOUS MATERIAL (3800' - 4000') = colors vary throughout interval: light gray to light medium gray with slight greenish shades, light gray with brownish tones, pale yellowish brown; firm to soft with good adhesion and good cohesion; fair to moderate induration in part; varies from clean, smooth, massive to earthy, gritty, silty to sandy in part; generally dull, sub waxy when tuffaceous, sparkly to subsucrosicwith increasing sand content; earthy samples generally contain carbonaceous detritus as flakes, sub platy fragments and occasional microlaminae; commonly associated with poorly developed woody /pulpy coal. with localized interbedded sandstone = gray with brownish shades; very fine to lower medium grain, angular with little to poor sphericity; slightly calcareous; varies from grain supported to matrix supported; argillaceous with apparent clay infill; no visible porosity; a variety of components including milky white and transparent quartz, medium and dark gray mafics, Tight to dark green, yellowish green, reddish orange and amber clasts; biotite common. CLAYSTONE & SILTSTONE (4000' - 4080') = light to medium light gray, often with yellowish brown • shades and bluish green tones, pale yellowish brown to yellowish brown; firm to occasionally crumbly with increasing silt/sand content; moderate induration with cohesion and adhesion; non- ; some cuttings hydrophilic and hydrofissle when tuffaceous; gross samples generally non - reactive; blocky, hackly to earthy in part; often smooth, massive consistency, generally gritty with varying degrees of entrained quartz silt and sand; carbonaceous present but significantly less so than seen above; often with thin interbeds of argillaceous sandstone, siltstone and unconsolidated sand as seen above. SAND (4100' - 4200') = unconsolidated; translucent to white grains; medium to lower coarse grained; well sorted; angular to subangular with moderate sphericity; formation is predominately quartz but does contain dark Iithics as well as volcanic material. TUFFACEOUS CLAYSTONE (4180' - 4320') = light gray with some green sub tones; poorly indurated; crumbly tenacity; earthy fracture; massive cuttings habit; dull luster; clayey texture with massive structure; clumpy consistency; no inclusions or organic material. SAND (4260' TO 4300') = unconsolidated; translucent to white grains; upper coarse to upper medium grains; moderately sorted; angular to subangular, moderate sphericity; sample interval is composed of predominately of quartz but also contains dark and green Iithics. TUFFACEOUS CLAYSTONE (4180' - 4320') = light gray to gray; poorly indurated crumbly tenacity; earthy fracture; massive cuttings habit; dull luster and clayey texture with massive structure. SAND (4300' - 4340') = unconsolidated; translucent to clear quartz grains; upper coarse to medium S grains; well sorted; angular to sub - angular; moderate sphericity; samples also contain black and green Iithics. El EPOCH 8 Chevron IWO SRU 211 -33 • CARBONACEOUS SHALE (4340' - 4360') = dark brown; well indurated with brittle tenacity; blocky fracture; cuttings habit is massive; luster is greasy; smooth texture; thinly bedded; no accessory organics present. TUFFACEOUS CLAYSTONE (4360' - 4420') = gray to Tight gray; poorly indurated; crumbly tenacity; earthy fracture, massive cuttings habit; dull luster with a clayey texture; massive structure. TUFFACEOUS CLAYSTONE (4360' - 4420') = gray to light gray; poorly indurated; crumbly tenacity; earthy fracture; massive cuttings habit; dull luster with a clayey texture; massive structure. SAND (4460' - 4520') = unconsolidated; medium coarse grained with a range from lower coarse to upper fine; poorly sorted; subangular; moderate sphericity sand is texturally immature; composition is mostly translucent and clear quartz with few dark lithics. SAND (4520' - 4600') = unconsolidated; very coarse to lower medium grained; poorly sorted; subangular; low sphericity; composed of translucent and white quartz; many dark lithics present as well as volcanic lithics giving the sand a salt and pepper appearance; some quartz grains are impacted while others are polished; as the interval increases, quartz decreases from 75% to 25 %. TUFFACEOUS CLAYSTONE (4420' TO 4580') = light gray; clumpy consistency; crumbly tenacity; cuttings are massive; dull luster; clayey texture and massive structure. SAND (4600 4720') = unconsolidated; upper medium to upper fine grained; poorly sorted; angular with low sphericity; quartz is translucent to white in color; quartz grains are frosted; sample contains dark lithics. TUFFACEOUS CLAYSTONE (4580' - 4640') = light gray to gray; moderately indurated; crumbly tenacity; cuttings habit is massive; dull luster; lithics adhere to the formation easily; clumpy consistency and lack of any discernable bedding; no accessory items or included carbonaceous material. SAND (4720' - 4760') = unconsolidated; lower very coarse to lower coarse grained; moderate sphericity; angular to subangular; moderately sorted; matrix is composed of translucent and clear quartz in equal mix with dark lithics. TUFFACEOUS CLAYSTONE (4640' - 4760') = light gray to gray; moderately homogenous and lacking fossils or cuttings habit; clayey texture; dull luster; sample is adhesive and expansive in water; lumpy consistency massive bedding; tuffaceous claystone is homogeneous and lacking fossils or carbonaceous material; the formation is noncalcareous. El EPOCH 9 Chevron IWO SRU 211 -33 • 3.2 Connection Gas Summary 1unit = 0.05% Methane Equivalent Note: No connection gasses were observed Depth (ft) Background Units MD/TVD Gas Above C -1 C -2 C -3 C-4 C -5 (Units) Background N/A N/A N/A N/A N/A N/A N/A N/A 3.3 Trip/Wiper Gas Summary 1 Unit = 0.05% Methane Equivalent Depth (ft) Trip to (ft) Maximum Gas Downtime MD/TVD MD/TVD (Units) (hours) 4760/3956 Shoe: 2000/1693 33 11.4 3.4 Sampling Program / Sample Dispatch 0 Set Sample Type Frequency Interval Dispatched To: Processed: Chevron, USA 1 and 2 Washed and 30' 2100' - 3500' 3800 Centerpoint Drive, Suite #100 Dried 20' 3500 - 4760' Anchorage, Alaska 99503 Attn: Debra Oudean Processed: AOGCC 30' 2100' - 3500' Howard Okland 3 Washed and Dried 20' 3500 - 4760' 333 West 7 Avenue, Suite # 100 Anchorage, Alaska 99501 BJ Services Unprocessed: Ed Post 4 Directly off 20" *3500' — 4760'* Mile Marker22.5 Shaker North Kenai Spur Highway Kenai, Alaska 99611 * Sample frequency was altered according to on -site geologist. • El EPOCH 10 Chevron SRU 211 -33 • 4 DRILLING DATA 4.1 Daily Activity Summary: 11/29/2008 Completed BOP tests. Pick up and make up new BHA. Run in hole with 8 -1/2" PDC bit. Displace drilling mud in hole with fresh KCI Polymer mud. Tag cement at 2012 ft. Drill cement, float equipment, shoe and 20 ft of new formation. Conduct FIT to 12.5 ppg EMW at 2125 ft. Epoch Well Services commences full mud logging operations at 1725 hours. Drill ahead with no problems. 11/30/2008 Continue drilling ahead from 2631 ft to 3618 ft. with no problems. 12/01/2008 Drill ahead from 3816 ft to TD 4760 ft at 1530 hours. Circulate bottoms up. Carbide lag indicates in gage hole. Condition hole. Short trip to shoe for rig service and wiper trip. 12/02/2008 Complete wiper trip from shoe to TD at 4760 ft. Epoch records 33 units maximum wiper trip gas at 11.4 hours down time. Circulate 20 bbl high vis sweep to condition hole. Observe few cuttings but lots of sand at bottoms up. Pull out of hole: Service top drive at shoe; lay down MWD tools. Rig up Schlumberger wire line. Run SWS Quad Combo logs. Currently changing out tools at report time. 12/03/2008 Complete second suite of wire line tools. Rig down Schlumberger. Wait on orders. Epoch Well Services released from responsibilities at 1830 hours. Running in hole to shoe at (2359 hrs) report time. S El EPOCH 11 Chevron W SRU 211 -33 4.2 Survey Data Measured Incl. Azim. True Vertical Northings Eastings Vertical Dogleg Depth Section Rate (ft) (deg) (deg) Depth (ft) (ft) { +N / -S} (ft) { +E / -W} (ft) 0100ft) 20.50 0.00 255.28 20.50 0.00 0.00 0.00 0.00 191.00 0.31 210.64 191.00 -0.40 -0.23 0.33 0.18 233.00 0.56 231.66 233.00 -0.62 -0.45 0.60 0.69 294.00 2.14 240.75 293.98 -1.36 -1.68 1.97 2.61 356.00 5.33 247.36 355.84 -3.03 -5.34 5.94 5.18 417.00 7.77 248.09 416.44 -5.66 -11.78 12.84 4.01 478.00 9.93 249.37 476.71 -9.05 -20.53 22.16 3.55 540.00 11.67 249.89 537.61 -13.09 -31.42 33.72 2.82 600.00 13.73 250.25 596.14 -17.59 -43.82 46.85 3.43 662.00 16.12 251.93 656.04 -22.74 -58.93 62.78 3.91 723.00 18.59 254.38 714.26 -27.99 -76.35 80.95 4.23 784.00 20.87 254.40 771.68 -33.53 -96.18 101.54 3.74 845.00 23.06 254.29 828.25 -39.69 - 118.15 124.35 3.59 910.00 25.27 255.22 887.55 -46.67 - 143.82 150.96 3.46 973.00 27.39 254.01 944.01 -54.10 - 170.76 178.90 3.46 1038.00 30.70 253.09 1000.83 -63.05 - 201.01 210.43 5.14 1102.00 32.99 253.54 1055.19 -72.74 - 233.36 244.18 3.60 110 1166.00 34.65 254.86 1108.35 -82.43 - 267.64 279.80 2.84 1230.00 36.61 255.13 1160.37 -92.08 - 303.65 317.08 3.07 1294.00 38.44 255.62 1211.12 - 101.91 - 341.37 356.06 2.88 1358.00 39.97 254.98 1260.71 - 112.18 - 380.50 396.52 2.48 1423.00 41.67 253.44 1309.90 - 123.75 - 421.38 439.00 3.03 1487.00 43.22 254.05 1357.13 - 135.84 - 462.85 482.17 2.50 1550.00 44.53 255.99 1402.55 - 147.12 - 505.02 525.83 2.98 1615.00 45.49 256.49 1448.50 - 158.05 - 549.67 571.79 1.57 1677.00 46.98 258.02 1491.39 - 167.92 - 593.34 616.53 3.00 1743.00 48.31 257.94 1535.85 - 178.08 - 641.04 665.25 2.02 1805.00 50.14 258.64 1576.34 - 187.60 - 687.01 712.13 3.06 1871.00 52.14 257.32 1617.75 - 198.32 - 737.27 763.46 3.42 1935.00 54.43 257.49 1656.01 - 209.50 - 787.34 814.73 3.57 2000.00 56.03 257.13 1693.08 - 221.23 - 839.42 868.09 2.51 2046.00 56.23 256.17 1718.72 - 230.05 - 876.58 906.27 1.79 2139.00 55.27 256.82 1771.06 - 248.00 - 951.33 983.12 1.18 2203.00 55.60 257.06 1807.37 - 259.91 - 1002.67 1035.80 0.60 2268.00 55.78 257.06 1844.01 - 271.93 - 1054.99 1089.46 0.28 2332.00 55.83 255.93 1879.98 - 284.30 - 1106.46 1142.39 1.46 2396.00 55.72 255.62 1915.98 - 297.30 - 1157.76 1195.30 0.43 2460.00 55.85 255.57 1951.97 - 310.46 - 1209.02 1248.22 0.21 2524.00 55.72 253.64 1987.96 - 324.51 - 1260.04 1301.14 2.51 2588.00 55.17 254.09 2024.25 - 339.16 - 1310.67 1353.84 1.04 S El EPOCH 12 Chevron I MO SRU 211 -33 410 Measured Incl. Azim. True Vertical Northings Eastings Vertical Dogleg Depth (deg) (deg) Depth (ft) (ft) { +N / -S} (ft) { +E / -W} ft ) ( Section Rate () ( ) 2652.00 53.38 254.49 2061.62 - 353.23 - 1360.69 1405.78 2.85 2715.00 52.79 253.80 2099.46 - 366.99 - 1409.14 1456.14 1.27 2778.00 50.10 253.57 2138.72 - 380.83 - 1456.42 1505.39 4.28 2843.00 47.56 253.80 2181.51 - 394.58 - 1503.37 1554.29 3.93 2906.00 45.09 254.63 2225.01 - 406.98 - 1547.22 1599.85 4.03 2972.00 42.73 254.79 2272.55 - 419.05 - 1591.37 1645.62 3.58 3036.00 40.01 254.40 2320.58 - 430.28 - 1632.14 1687.91 4.28 3100.00 38.39 255.23 2370.18 - 440.88 - 1671.17 1728.35 2.66 3163.00 36.37 254.77 2420.23 - 450.77 - 1708.12 1766.59 3.23 3231.00 33.44 252.98 2476.00 - 461.56 - 1745.50 1805.49 4.57 3295.00 31.11 254.45 2530.11 - 471.15 - 1778.29 1839.64 3.84 3360.00 28.57 254.04 2586.48 - 479.93 - 1809.42 1871.98 3.92 3424.00 26.13 253.39 2643.32 - 488.17 - 1837.64 1901.37 3.84 3487.00 23.16 254.87 2700.58 - 495.37 - 1862.90 1927.63 4.82 3552.00 20.87 256.69 2760.84 - 501.37 - 1886.51 1951.98 3.68 3616.00 18.13 258.50 2821.16 - 505.98 - 1907.36 1973.33 4.38 3680.00 16.09 259.97 2882.33 - 509.51 - 1925.85 1992.11 3.26 3745.00 13.87 261.34 2945.12 - 512.25 - 1942.42 2008.83 3.46 3809.00 11.60 259.80 3007.54 - 514.55 - 1956.34 2022.87 3.57 3873.00 8.87 254.99 3070.51 - 516.96 - 1967.44 2034.22 4.47 3937.00 6.74 250.08 3133.92 - 519.52 - 1975.74 2042.90 3.49 4002.00 5.45 245.79 3198.55 - 522.09 - 1982.14 2049.74 2.10 4067.00 3.99 242.56 3263.33 - 524.40 - 1986.96 2054.99 2.29 4131.00 0.94 270.13 3327.26 - 525.42 - 1989.46 2057.67 4.98 4196.00 1.09 40.32 3392.26 - 524.95 - 1989.60 2057.68 2.84 4260.00 1.17 35.64 3456.25 - 523.95 - 1988.82 2056.68 0.19 4324.00 1.30 43.05 3520.23 - 522.89 - 1987.94 2055.56 0.32 4389.00 1.44 41.01 3585.21 - 521.73 - 1986.90 2054.26 0.23 4453.00 1.47 41.31 3649.19 - 520.50 - 1985.83 2052.91 0.05 4517.00 1.55 38.77 3713.17 - 519.21 - 1984.74 2051.53 0.16 4582.00 1.61 36.27 3778.14 - 517.79 - 1983.65 2050.12 0.14 4646.00 1.46 36.50 3842.12 - 516.41 - 1982.64 2048.78 0.23 4707.00 1.57 35.01 3903.10 - 515.10 - 1981.69 2047.54 0.19 4760.00 1.57 35.01 3956.08 - 513.91 - 1980.86 2046.43 0.00 • til EPOCH 13 Chevron V OW SRU 211 -33 4.3 Bit Record Bit Size Type Ser. No. JetsITFA In Out Ftg. Hrs. Wear Reason 1 -1 -WT- 4 8 -1/2" HCM 06Z 7118694 0 5568 2601' 4760' 2654' 22.4 A -0 -I- TD NO -TD • S CI EPOCH 14 on SR U 211 -33 4.4 Mud Record Contractor: BAROID Date Depth MW FLT VIS PV YP Gels FL FC So Is NAP/W Sd MBT pH CI- Ca+ (ppg) (F) (s /qt) ( %) Ratio ( %) (mI /I) (mI /I) 11/28/08 2094' 9.20 -- 51 13 17 6/8/9 6.0 1 2.8 -/95.0 -- 2.0 8.0 26.0k 80 2106' 9.20 -- 51 12 18 7/8/9 6.5 1 2.7 -/95.0 -- 2.0 8.0 28.0k 60 11/29/08 2125' 9.20 60 51 14 21 7/30/35 6.6 1 2.9 -/95.0 -- 2.5 11.4 25.0k 160 2550' 9.35 69 50 14 19 6/9/11 6.0 1 4.0 -/93.8 1.50 2.5 10.9 27.0k 360 11/30/08 3466' 9.20 72 51 10 19 5/7/9 6.5 1 3.3 -/94.5 0.75 2.5 8.9 27.0k 160 3816' 9.20 86 53 16 25 8/10/13 5.2 1 3.6 -/94.0 0.50 2.5 8.8 29.0k 200 12/01/08 4099' 9.20 85 54 14 21 7/11/14 5.4 1 3.1 0.1/94.5 0.50 5.0 8.5 28.5k 280 4760' 9.20 88 57 20 29 8/1/13 5.0 1 3.2 _ -/94.5 1.25 5.0 8.9 28.0k 200 12/02/08 4760' 9.50 72 28 16 24 7/13/18 4.7 1 4.5 0.3/93.0 0.80 5.0 8.9 27.5k 160 Abbreviations MW = Mud Weight Gels = Gel Strength Sand = Sand content ECD = Effective Circulating Density FL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity SoIs = Solids NAP/W = Oil to Water ratio YP = Yield Point FLT = Flow Line Temp El EPOCH 15 5 MORNING REPORTS • El EPOCH 16 Chevron USA 4. Swanson River Unit DAILY WELLSITE REPORT El EPOCH SRU 211 -33 REPORT FOR Floyd Hurt, Lindsay Hubbard DATE Nov 29, 2008 DEPTH 2631' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 2106' 24 HOUR FOOTAGE 525' CASING INFORMATION 9 -5/8" @ 2097' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2046' 56.23 256.17 1718.71' 2203' 55.60 257.06 1807.37' SURVEY DATA 2332' 55.83 255.93 1879.97' 2460' 55.85 255.57 1951.96' 2588' 55.17 254.09 2024.25' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8 -1/2" HCC HCM506Z 7118694 6 X 11/0.5568 2106' 525' 3.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 340.7 @ 2135 21.5 @ 2556 184.7 196.5 FT /HR SURFACE TORQUE 9000 @ 2322 37 @ 2386 2739.3 3899 AMPS WEIGHT ON BIT 9 @ 2204 1 @ 2383 0.7 0.00000 KLBS ROTARY RPM 81 @ 2595 36 @ 2120 50.3 80.0 RPM PUMP PRESSURE 1326 @ 2138 774 @ 2110 1102.8 1072 PSI 0 DRILLING MUD REPORT DEPTH 2550' MW 9.35 VIS 50 PV 14 YP 19 FL 6.0 Gels 6/9/11 CL- 27k FC 1 SOL 4.0 SD 1.5 OIL MBL 2.5 pH 10.9 Ca+ 360 CCI MWD SUMMARY INTERVAL 2106' TO Current TOOLS PDC bit with Mud Motor and MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 50 @ 2401 0 @ 2570 8.5 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 7888 @ 2401 69 @ 2284 1380.1 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ @ AVG PROPANE (C -3) 0 @ @ CURRENT BUTANE (C -4) 0 @ @ CURRENT BACKGROUND /AVG < 10 U PENTANE (C -5) 0 @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 24 Hours: Dominately unconsolidated sands; Tuffaceous claystone decreasing. PRESENT LITHOLOGY 2630 ft: 80% unconsolidated sand; 20 % tuffaceous clays DAILY ACTIVITY Completed testing BOP's. Pick up and make up new BHA. Run in hole with 8 -1/2" PDC bit. Displace drilling mud in SUMMARY hole with fresh KCI Polymer mud. Tag cement at 2012 ft. Drill cement, float equipment, shoe and 20 ft of new formation. Conduct FIT to 12.5 ppg EMW at 2125 ft. Drill ahead with no problems. • EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC___ DAILY COST REPORT BY Larry Resch Chevron USA • Swanson River DAILY WELLSITE REPORT El EPOCH SRU 211 -33 REPORT FOR DATE Nov 30, 2008 DEPTH 3816' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 2631' 24 HOUR FOOTAGE 1185' CASING INFORMATION 9 -5/8" @ 2097' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2652' 53.38 254.49 2061.62' 2906' 45.09 254.63 2225.01' SURVEY DATA 3163' 36.37 254.77 2420.23' 3424' 26.13 253.39 2643.32' 3745' 13.87 261.34 2945.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8 -1/2" HCC HCM506Z 7118694 6 X 11/0.5568 2106' 1185' 13.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 346.4 @ 3057 5.2 @ 3348 159.9 9.1 FT /HR SURFACE TORQUE 8301 @ 3477 25 @ 3814 2562.9 699 AMPS WEIGHT ON BIT 18 @ 3812 1 @ 2861 2.0 3.6 KLBS ROTARY RPM 86 @ 3186 50 @ 3449 43.4 0.0 RPM PUMP PRESSURE 1687 @ 3768 1008 @ 2638 1209.1 1263 PSI 40 DRILLING MUD REPORT DEPTH 3816' MW 9.2 VIS 53 PV 16 YP 25 FL 5.2 Gels 8/10/13 CL- 29k FC 1 SOL 3.6 SD 0.5 OIL MBL 2.5 pH 8.8 Ca+ 200 CCI MWD SUMMARY INTERVAL 2106' TO Current TOOLS PDC bit with mud motor and MWD; gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 55 @ 3587.00000 0 @ 2707 17.5 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 12401 @ 3452 2 @ 2707 2823.4 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ @ AVG PROPANE (C -3) 0 © @ CURRENT BUTANE (C -4) 0 @ @ CURRENT BACKGROUND /AVG < 20U PENTANE (C -5) 0 @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 24 Hr: Dominately sand and claystone with occasional poorly developed coal PRESENT LITHOLOGY 3800 ft: 60% sand, 30 % claystone, 10% coal DAILY ACTIVITY SUMMARY Continue drilling ahead from 2631 ft to 3618 ft. with no problems. 0 EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC___ DAILY COST $5170 REPORT BY Larry Resch Chevron, USA 0 Swanson River Unit SRU 211 -33 DAILY WELLSITE REPORT EPOCIE[ REPORT FOR Floyd Hurt, Lindsay Hubbard DATE 12/1/2008 DEPTH 4760' PRESENT OPERATION Wiper Trip at TD TIME 2359 hrs YESTERDAY 3816' 24 HOUR FOOTAGE 944' CASING INFORMATION 9 -5/8" 2097' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9737' 6.74 250.08 3133.91' 3131' 0.94 270.13 3327.25' SURVEY DATA 4324' 1.30 43.05 3520.22' 4582' 1.61 36.27 3778.14' 4760' 1.57 35.07 3956.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8 -1/2" HCC HCM506Z 7118694 6 x 11/0.5568 2106' 4760 2654' 2.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 344.2 @ 3947 6.4 @ 4100 156.4 FT /HR SURFACE TORQUE 9859 @ 4645 37 @ 4116 5360.8 AMPS WEIGHT ON BIT 19 @ 4012 0 @ 4157 1.4 KLBS ROTARY RPM 86 @ 4573 35 @ 4013 57.4 RPM PUMP PRESSURE 1847 @ 4758 1162 © 3823 1467.9 PSI O DRILLING MUD REPORT DEPTH 4760 MW 9.2 VIS 57 PV 20 YP 29 FL 5.0 Gels 8/10/13 CL- 28k FC 1 SOL 3.2 SD 1.25 OIL MBL 5.0 pH 8.9 Ca+ 200 CCI MWD SUMMARY INTERVAL 2106 TO Current TOOLS PDC bit with mud motor and MWD; Gamma GAS SUMMARY HIGH LOW AVERAGE (units) DITCH GAS ( t e st ) © 4099 0 @ 9.7 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C -1) 45884 @ 4560.00000 2 @ 4094.00000 2548.8 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ @ AVG PROPANE (C -3) 0 @ @ CURRENT BUTANE (C 4) 0 @ @ CURRENT < 5 Units while BACKGROUND /AVG drilling PENTANE (C -5) 0 @ @ HYDROCARBON SHOWS none INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 24 Hour: Dominately unconsolidated sand and claystone PRESENT LITHOLOGY At TD: 70 % Claystone, 30 % Sand DAILY ACTIVITY Drill ahead from 3816 ft to TD 4760 ft at 1530 hours. Circulate bottoms up. Carbide lag indicates in gage hole. 0 SUMMARY Condition hole. Short trip to shoe for rig service and wiper trip. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC__ DAILY COST $5170 Chevron, USA • Swanson River Unit DAILY WELLSITE REPORT tif EPOCH SRU 211 -33 REPORT FOR Floyd Hurt, Lindsay Hubbard DATE Dec 2, 2008 DEPTH 4760' PRESENT OPERATION Wire Line Logging TIME 2359 hrs YESTERDAY 4760' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 -5/8" @ 2097' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8 -1/2" HCC HCM506Z 7118694 6 X 11/0.5568 2106' 4760' 2654' 22.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI 40 MWD SUMMARY INTERVAL Current TO TOOLS No tools in hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS 33 U, 11.4 hrs CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) @ @ CONNECTION GAS HIGH 0 ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG < 5 u when circulating PENTANE (C -5) @ @ HYDROCARBON SHOWS No new footage drilled this period INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled this period PRESENT LITHOLOGY DAILY Complete wiper trip from shoe to TD at 4760 ft. Epoch records 33 units maximum wiper trip gas at 11.4 hours down ACTIVITY time. Circulate 20 bbl high vis sweep to condition hole. Observe few cuttings but lots of sand at bottoms up. Pull out SUMMARY of hole: Service top drive at shoe; lay down MWD tools. Rig up Schlumberger wire line. Run SWS Quad Combo logs. Currently changing out tools at report time. EPOCH PERSONNEL ON Resch, Windslow + 2 DAILY $4970 NOTE: Daily cost for 11/30, 12/1, 12/2 should be $4970, NOT BOARD SC__ COST $5170. (operator error while computing) . REPORT BY Larry Resch Chevron, USA Swanson River Unit DAILY WELLSITE REPORT Itt EPOCIE[ SRU 211 -33 REPORT FOR Floyd Hurt, Lindsay Hubbard DATE Dec 03, 2008 DEPTH 4760' PRESENT OPERATION Wait on orders; RIH to shoe TIME 2359 hrs YESTERDAY 4760' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 -5/8" @ 2097 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 8 -1/2" HCC HCM506Z 7118694 6 X 11/0.5568 2106' 4760' 2654' 22.4 1- 1- WT- A- 0- I -NO -TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI ir MWD SUMMARY lir INTERVAL TO TOOLS No tools in hole this period GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS No new footage drilled this period INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled this period PRESENT LITHOLOGY DAILY ACTIVITY Complete second suite of wire line tools. Rig down Schlumberger. Wait on orders. Epoch Well Services SUMMARY released from responsabilities at 1830 hours. Running in hole to shoe at (2359 hrs) report time. EPOCH PERSONNEL ON BOARD Resch, Winslow__ DAILY COST $4145 REPORT BY Larry Resch •
