Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
207-176
~~ ~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 5/27/2010 Permit to Drill 2071760 Well Name/No. GUBIK 3 Operator ANADARKO PETROLEUM CORPORA API No. 50-287-20017-00-00 MD 3950 TVD 3949 Completion Date 4/14/2008 Completion Status P&A Current Status P&A UIC N __ REQUIRED INFORMATION Mud Log Yes Samples No DATAINFORMATgN Types Electric or Other Logs Run: Mud Log, MWD Directional, LWD: GR/Res/Dens/Neutron/Sonic, WL: Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Directional Survey (No ~ ~ l (data taken from Logs Portion of Master Well Data Maint Interval OH / Hype rvieairrrni ~~uuiuC~ ~ya~pg aca~C ~~iewa rvo ~[ar[ a[op ~.n rcecervea ~.ornrnenw ED C 16073 See NotNotes Open 4/1/2008 Multiple Meta Data i graphics in MD og Induction/Resistivity 5 Col 1008 2621 Open 4/1/2008 High Def Induction Log, Comp Z-Densilog, Neutron, GR, Caliper 20- ~ Feb-2008 ~LOg Cement Evaluation 5 Col 1008 2621 Case 4/1/2008 Cement Volume Log 20- Feb-2008 Log See Notes 5 Col 1008 2621 Open 4/1/2008 Spectalog 20-Feb-2008 og Induction/Resistivity 5 Col 1008 3948 Open 4/1/2008 High Def Induction Log,Multipole Array AcoustiLog, GR, Cali 07 Mar, 2008 og Induction/Resistivity 5 Col 1008 2621 Open 4/1/2008 High Def Induction Log, Multipole Array AcoustiLog GR, Caliper 20-Feb-2008 !I 'Log See Notes 5 Col 1119 1905 Open 4/1/2008 Res. Characterization 20- ', Feb-2008 og Gamma Ray 5 Col 0 7626 Open 4/1/2008 High Def Induction Log, RT & RXO 1 D-Inversion, 12 Mar, 2008 Log Gamma Ray Col 1143 3790 Open 4/11/2008 PB 1 Reser. Characteristion, Instrument, GR •I •I DATA SUBMITTAL COMPLIANCE REPORT 5/27/2010 Permit to Drill 2071760 Well Name/No. GUBIK 3 Operator ANADARKO PETROLEUM CORPORA API No. 50-287-20017-00-00 MD 3950 ND 3949 Completion Date 4/14/2008 Completion Status P&A Current Status P&A UIC N Log See Notes Col 1008 3940 Open 4/10/2008 Borehole profile, for 8 3/4' Bit and T casing .{~ Log Induction/Resistivity 2 Col 1008 3941 Open 4/10/2008 High Def Induct, GR, Caliper og Induction/Resistivity 2 Col 1008 3941 Open 4/10/2008 PB 1 High Def Induct, GR, Caliper Log Induction/Resistivity 5 Col 1008 3941 Open 4/10/2008 PB 1 High Def Induct, Comp Z-Densi, CNL, GR, Caliper og See Notes 5 860 2590 Open 4/10/2008 Multipole Accoustic Log, 22 Feb, 2008 Log See Notes 5 1040 3906 Open 4/10/2008 PB 1 Multipole Acoustic Logs, Azimuthal Anisotrophy Analysis og See Notes 5 1250 3900 Open 4/10/2008 PB 1 Array Accoustic Logs, Stoneley Perm ~ D C 16116 ~~ Notes 0 0 Open RCI, HDIL, GR, CAL, XMAC, BHP in Meta, LAS graphics pt Report: Final Well R 0 0 Open 4/24/2008 Final Well Report: Gen Info, Daily Summ, Daily Ops, Well Diagram, Lith Summ, Hydro notes, Show Reports, Show Reports P61, Bit Record, Survey Report, Mud Record. ~~ D C 16145 Report: Final Well R 0 0 Open 4/24/2008 Final Well Report: Gen Info, Daily Summ, Daily Ops, Well Diagram, Lith Summ, Hydro notes, Show Reports, Show Reports PB1, Bit Record, Survey Report, Mud Record. og Mud Log 2 Col 105 4285 Open 4/24/2008 Combo Mud log 26-Feb- 2008 Log Mud Log 5 Col 105 4285 Open 4/24/2008 Combo Mud log 26-Feb- 2008 • DATA SUBMITTAL COMPLIANCE REPORT 5/27/2010 Permit to Drill 2071760 Well Name/No. GUBIK 3 Operator ANADARKO PETROLEUM CORPORA API No. 50-287-20017-00-00 u sy5u i vu 3y4y compieuon uate 4/14%NU25 uompietwn status rc`kH t;urrent status rts~ uic rv Log Mud Log 5 Col 105 4285 Open 4!2412008 Gas Ratio tog 26-Feb-2008 ', Log Mud Log 2 Col 105 4285 Open 4/24/2008 Drilling Dynamics log 26- Feb-2008 '~ Log Mud Log 2 Cof 105 3950 Open 4/24/2008 P61 Combo Mud log 03- ', Mar-2008 Log Mud Log 5 Col 105 3950 Open 4/24/2008 PB1 Combo Mud log 03- ', Mar-2008 Log Mud Log 5 Col 105 3950 Open 4124!2008 PB1 Gas Ratiolog 03-Mar- 2008 Log Mud Log 2 Col 105 3950 Open 4/24/2008 P61 Drilling Dynamics log 03-Mar-2008 D C 16146 See Notes 0 0 Open 4/24/2008 ASCII, Core Sample ', Pictures in PDF and other '~ graphics ', og Induction/Resistivity 2 Col 105 4285 Open 5/14/2008 MD Triple Combo, BAT Comp Data, ROP, DGR, EWR, CTN, SLD, BAT Bi- Model Log Induction/Resistivity 5 Col 105 4285 Open 5/14/2008 MD Triple Combo, BAT Comp Data, ROP, DGR, EWR, CTN, SLD, BAT Bi- Model Log Induction/Resistivity 5 Col 105 4285 Open 5/14/2008 MD ROP, DGR, EWR, GOM og Induction/Resistivity 5 Col 105 3950 Open 5/14/2008 PB1 MD ROP, DGR, /~ EWR,GOM ILog Induction/Resistivity 5 Col 105 3950 Open 5/14/2008 P61 MD ROP, DGR, EWR o Induction/Resistivity 2 Col 105 3950 Open 5/14/2008 PB1 MD ROP, DGR, EWR ED C Pds 16250 See Notes 0 0 Open 5/14/2008 MD EWR, ROP, DGR and other logs in PDS format ~ with PB1 logs ~ ~ See Notes 2 840 3910 Open 4/10/2008 PB 1 Multipole Array Accoustic Logs, Poisson's Ratio • DATA SUBMITTAL COMPLIANCE REPORT 5127/2010 Permit to Drill 2071760 Well Name/No. GUBIK 3 Operator ANADARKO PETROLEUM CORPORA API No. 50-287-20017-00-00 MD 3950 TVD 3949 Completion Date 4/14/2008 Completion Status P&A Current Status P&A UIC N o~ See Notes 5 2850 3850 Open 4/1012008 PB 1 Multipole Accoustic Log, 09 Mar, 2008 '-Cog See Notes 5 890 3914 Open 4/10/2008 PB 1 Multipole Accoustic Log, 12 Mar, 2008 Log See Notes 5 Col 1008 3948 Open 4/1/2008 PB 1 Digital Spectalog 07- Mar-2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ Cores and/or Samples are required to be submitted. This record automatically created ~ _ from Permit to Drill Module on: 1/28/2008. ~ ADDITIONAL INFORMATION Well Cored? Y ,~ Daily History Received? Y N Chips Received? , Y~ Formation Tops Y N Analysis Y_L.1~I-- Received? Comments: ~~ Compliance Reviewed By: Date: C7 MEMORANDUM TO: Jim Regg P. I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: August 15, 2008 Location Inspection Gubik #3 - Anadarko PTD 2071760 Sunday, August 15, 2008: 1 performed a Location Clearance inspection of Anadarko's exploratory well Gubik #3. 1 was accompanied by Federico Lier (Anadarko) and Gerald Nayakic (N. Slope Borough). This exploration location was clean with no evidence of past drilling activity other than the cellar area, which was mounded nicely to prevent ponding. I recommend this location be approved "final location cleared". Attachments: Photo 2008-0815_Location_Clear _Gubik-3_cs.docx Page 1 of 2 Location Inspection — Gubik #3 (PTD 2071760) Photos by AOGCC Inspector C. Scheve 8/15/2008 2008-0815_Location_Clear_Gubik-3_cs.docx Page 2 of 2 Maunder, Thomas E (DOA) From: Bill Penrose [bill@fairweather.com] Sent: Saturday, July 05, 2008 7:43 AM To: Maunder, Thomas E (DOA) Cc: Alaska.DrillingOpsMgr Subject: RE: Gubik #3 (207-176 -AGAIN Tom, • Page 1 of 1 In answer to your first question, there were a total of three flow periods conducted in testing the Gubik well: one for cleanup of the well, one to test the Nanushuk interval and one to test the Tulavak interval. The rate and cumulative volume reported for the Nanushuk interval reflect only that test and not the cleanup beforehand. For your second question, I agree the perfing and re-perfing could have been reported more clearly. Here's how it went: The original perfs were shot with tubing-conveyed guns over the interval 3,542' - 3,612' and the expended guns dropped. Later, two intervals were perforated with wireline-conveyed guns: 3,542' - 3,582' and 3,612' - 3,652'. Therefore, the WL-perFd interval 3,542' - 3,582' was a re-perf'd interval and the interval 3,612' - 3,652' contained new perfs. Let me know if this is clear as mud. Regards, ~~ ~~~ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 01, 2008 9:49 AM To: Fred McDougal; Chuck Rowe; Bill Penrose Subject: RE: Gubik #3 (207-176) -AGAIN As I have continued to review, I find a discrepancy in the re-perforating detail of April 1 and April 2. Were the first set of wireline perfs a new interval? That is what it reads based on the information given on the face of the 407. Thanks in advance, Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, July O1, 2008 9:13 AM To: 'Fred McDougal'; 'Chuck Rowe'; 'Bill Penrose' Subject: Gubik #3 (207-176) All, I am reviewing the 407 submitted for this well. It appears there were 2 flow periods for the Nanushuk interval. Is the flow rate and cumulative volume information reported for both periods or only for the 2nd Thanks in advance, Tom Maunder, PE AOGCC 7/7/2008 ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 ~nada~~ Petroleum Corporation May 8, 2008 Mr. Dan Seamount, Chair R ~ ~' ~ ~ VE Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 MAY 1 4 2008 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage RE: Well Completion Report Anadarko Petroleum Corporation: Gubik #3 (PTD 207-176) Dear Mr. Seamount, Anadarko Petroleum Corporation hereby submits its Well Completion Report for the work performed in drilling its Gubik #3 exploration well on the North Slope. Please find enclosed the following information for your files: 1) Form 10-407 Well Completion or Re-completion Report and Log 2) Well As-Built Survey 3) Wellbore Schematic 4) Well Operations Summary 5) Directional Survey 6) Detailed Well Testing Data Anadarko requests the AOGCC keep this well's testing data confidential to the extent allowed under the regulations. If you have any questions or require additional information, please contact me at (907) 273-6302 or Bill Penrose at (907) 258-3446. Sincerely, AN ROLEUM CORPORATION Fred McDougal Drilling Operations Manager enclosures cc: Bill Penrose -Fairweather 1 MAY ~ 4 200$ `~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSj~a 011 & Gas Cons. Comfnlssion WELL COMPLETION OR RECOMPLETION REPORT A~i~dola~G 1a. Well Status: Oil^ Gas^ Plugged ^ Abandoned Q ,Suspended ^ 2oaac2s.~oe zoaACZS.~~o GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1b. Well Class: Development ^ Exploratory^~ Service ^ Stratigraphic Test^ 2. Operator Name: Anadarko Petroleum Corporation 5. D Comp., Susp., or Aband.: 4/14/2008 • 12. Permit to Drill Num_ ber: PTD 207-176 /Sundry 308-067 3. Address: 3201 C Street, Suite 603, Anchorage, AK, 99503 6. a e pudded: 1/31/2008 13. API Number: ~~ ,. - l~ 50-287-20017-00 4a. Location of Well (Governmental Section): Surface: 1767' FEL 2411' FSL, S17 T01-R03E 7. Date TD Reached: 3/6/2008 - 14. Well Name and Number: Gubik #3 - Top of Productive Horizon: 1767' FEL 2411' FSL, S17 T01-R03E 8. KB (ft above MSL): 217 Ground (ft MSL): 195 15. Field/Pool(s): Total Depth: 1789' FEL 2365' FSL, S17 T01-R03E 9. Plug Back Depth(MD+TVD): Surface Exploratory - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 314531.00 ` y- 5647250.00 Zone- 4 10. Total Depth (MD + TVD): "3,950' MD, 3,949' TVD ' 16. Property Designation: ASRC Lease CA003 TPI: x- 314531.00 y- 5647250.00 Zone- 4 Total Depth: x- 314508.00 y- 5647204.00 Zone- 4 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: ASRC • 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): -810' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Mud Log, MWD Directional, LWD: GR/Res/Dens/Neutron/Sonic, WL: HDIUXMAX/CAL/CN/ZDL/GR/RCI/USIT 22. CASING, LI NER AND CEMENTING RECORD GASING WT. PER GRADE SETTING DEPTH MD SETTING D EPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM y PULLED 16" N/A N/A Surface 105' Surface 105' 20" grouted to surface ISL.- None 9-5/8" 40 # L-80 Surface 1007 Surface 1007 12-1/4" cmtd to surface w/ bbls None 7" 26# L-80 Surface 3935 Surface 3935 8-3/4" Cmtd to Surf w/158 bbls None 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) Nanushuk Formation 3542'-3612' MD/TVD w/ 4-5/8" TCP guns, 3-1/2" 1,254' 1,517' 3,612'-3,652' w/ 2-112" hollow carrier at 6 spf. Tuluvak Formation 1590' ' 3-1/2" 1,717' 1,701' -1640 MD/TVD w/ Powerjet Omega HC gun at 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production: See attached testing summaries for two zones Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate --- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q Sidewall Cores Acquired? Yes ^ No ^~ - 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 AA//C 25.071. ~AT/~. ~ O ~~: tt`~~ ~ ~ Z~~S V;FtIF -G ~~ .~~ Form 10-407 Revised 2/2007 ~ ~` ~ ~ ~ {\ j /, 'CONTINUED ON REVERSE SIDE _ ~ ~ ~p• o~ y.. - 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD SS Well tested? Yes Q .. No ~ If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to Permafrost -top Surface Surface this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 972' 972' Intervals Tested: Tuluvak 1,079' 1,079' Nanushuk Formation 3542'-3652' MDITVD Nanushuk 2,860' 2,860' Tuluvak Formation 1590'-1640' MDITVD Grandstand 3,330' 3,330' Top Torok (original hole) 4,135' 4,135' Both intervals tested gas. See attachments for a TD (Sidetrack hole) 3,950' 3,949' summary and detailed testing results. 30. List of Attachments: Wellbore schem, location as-built, operation summary, directional survey, testing data. Logs submitted separately. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bill Penrose 258-3446 - Printed Name: all Title: Alaska Drilling Operations Manager Signatur . M~Phone: 273-6302 Date: S Z-~ D~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for 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 iri this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 212007 ~nada~~ Petroleum Corporation Operations Summary Anadarko Petroleum Corporation Gubik #3 January 31, 2008 278' MW 9.8 ppg Vis 67 sec M/LT 12-1/4" bit, RIH, tag bottom at 85'. Build mud volume, test surface lines, wash from 85' to 105'. Drill from 105' to 278' w/packing off problems. February 1, 2008 494' MW 9.8 ppg Vis 77 sec Incl 0.71 deg POOH, clean and inspect bit, RIH. Drill f/ 278' to 494'. POOH. M/U BHA with MWD and LWD components. February 2, 2008 1;027' MW 10.6 ppg Vis 83 sec Incl 0.70 deg Finish M/U BHA, RIH. Ream to bottom (5' of fill). Drill 12-1/4" hole f/ 494' to 849'. Charge pump motor failed. Repair motor, drill f/ 849' to 1,027'. C&C hole and POOH slowly for MAD pass. February 3, 2008 1,027' MW 10.6 ppg Vis 78 sec Inc10.70 deg MAD pass f/ 428' to 248'. RIH to 1,027' - no fill. C&C hole for casing and POH. Download LWD and R/U to run 9-5/8" casing. February 4, 2008 1,027' MW 10.7 ppg Vis 76 sec Inc10.70 deg Run 9-5/8" casing to 1,007'. Circ 2 casing volumes. R/D casing running equip. RIH w/ 4" DP and screw-in sub. Space out and screw into float collar. Circ w/ rig pump. Hanger bypass ports plugged, lost circ. Rig hoses to take returns from conductor outlets. C&C well w/ full returns. Pump 38 bbls spacer, 127 bbls permafrost cement and 23 bbls Class G cement. Displace w/ mud using rig pumps. Full circulation throughout job. CIP at 2020 hrs. Back out screw-in sub and circ out. R/D lines. February 5, 2008 1,027' MW 10.7 ppg Vis 66 sec Incl 0.70 deg POOH, S/B DP, L/D screw-in sub. L/D landing jt, N/D diverter line and riser. N/LT wellhead and test to 4,800 psi -good test. N/LT BOPE while cleaning pits. ~adarl~~ Petroleum Corporation February 6, 2008 1,027' MW 10.7 ppg Vis 64 sec Incl 0.70 deg Land annular preventer and measure for bell nipple. Install kill line, HCR and manual valves. Install bell nipple and turnbuckle. Install accumulator lines to BOPS, install choke line and hammer up all BOP bolts. Found shear ram blocks not fully retracting into bonnets. Remove ram blocks, set wear bushing. February 7, 2008 1,027' MW 10.7 ppg Vis 52 sec Inc10.70 deg L/D DCs f/ derrick. Load pipe shed w/ 8-3/4" BHA. P/iJ and RIH on 4" DP to 800'. Circ hole and POOH. Open blind/shear doors, take measurements and re-tighten bolts. Remove manual locks f/ blind/shears, install rams and function -functioned properly. P/LT 4" DP f/ pipe shed and stand back in derrick (SLM). February 8, 2008 1,027' MW 10.7 ppg Vis 54 sec Incl 0.70 deg P/LT 21 stands DP, S/B in derrick. Center up BOPs, pull wear bushing, perform full-body test on BOPs and choke manifold. R/U test pump, AOGCC inspector Bob Noble on location. Test top VBRs, choke hose, HCR to 250/5000 psi. Leak on check valve. Tighten up on check valve and wellhead adapter flange. Re-test to 250/5000 -good test. Test btm VBRs, choke and kill HCR, manual choke and kill valves, valves 1 - 6 on choke manifold to 250/5000. Test annular preventer to 250/3000. February 9, 2008 1,027' MW 11.7 ppg Vis 58 sec Inc10.70 deg Continue to work on choke. Test choke valves to 250/5,000. Install spacers on blind rams. Test blinds and check valve. Pull test plug, set wear bushing, test-run manual locks on blinds. RIH w/ 5" HWDP and test VBRs against it. RIH to 742'. Test cs~ to 3,000 psi. RIH to 917'. Change top drive saver sub and grabber dies. February 10, 2008 1,047' MW 11.7 ppg Vis 53 sec Incl 0.70 deg Tag FC at 926'. Drill FC and cement to 998'. Circ 2 hi-vis sweeps .and POH. M/iJ smart BHA, test MWD, RIH. Drill float shoe, rat hole and 20' of new hole to 1,047'. C&C for LOT, pull back into shoe. February 11, 2008 1,285' MW 13.6 ppg Vis 56 sec Incl 1.12 deg Perform LOT to 21.3 ppg EMW. Build mud weight to 13.6 ppg. Control drill 8-3/4" hole from 1,047' to 1,285' with background gas ranging from 1,047 units to 9,000 units. February 12, 2008 1,706' MW 13.6 ppg Vis 52 sec Incl 0.92 deg Dri118-3/4" hole f/ 1,285' to 1,343' w/background gas 400 - 1,300 units. Drill and slide f/1,343' to 1,497' w/ connection gas 400 -8,600 units. Drill and slide f/ 1,497' to 1,706'. ~adarM~~ Petroleum Corporation :7 February 13, 2008 2,149' MW 14.0 ppg Vis 49 sec Inc10.38 deg Drill 1,706' to 1,800', stopping to circulate out gas every 4' - 10'. BGG 400-600 units. Max cnxn gas 9,977 units. Drill and slide 1,800' to 2,000', circulating out gas every 10' to 50'. Max cnxn gas 4,000 units. C&C hole for wiper trip. Pump out of hole 2 stands. BGG at 3,900 units, circ back to btm. Raise MW f/ 13.6 to 13.8 ppg and S/D pumps for 20 min. Start pumps up, BU gas 5,000 units. S/D pumps again for 20 min. Start up pumps, BU gas 4,800 units. Raise MW f/ 13.8 to 14.0 ppg. S/D pumps for 30 min. Start up pumps, BU gas 4,500 units. Control dri112,000' to 2,149' w/ avg BGG of 475 units, cnxn gas 1,200 - 2,500 units. February 14, 2008 2,628' MW 14.2 ppg Vis 53 sec Inc10.17 deg Drill 2,149' to 2,628'. BGG 450 - 600 units, cnxn gas 2,900 units. CBU and POH 5 stands. Last stand pulled tight. RIH to btm and CBU - circa up 7,500 units gas. Raise MW to 14.2 ppg. S/D and monitor well for 20 minutes - no flow, circ up 4,200 units gas. POH 7 stands. Line up trip tank and monitor on way back in. Proper hole fill and no tight spots. CBU on btm -BGG 360 - 400, cnxn gas 3,865 units. Februar~l5, 2008 2,628' MW 14.6 ppg Vis 57 sec Inc10.70 deg C&C mud, observe well -slight flow due to gas breaking out of mud. Incr mud weight from 14.2 to 14.4 ppg. Observe well, POH 17 stds into shoe at 1,000'. Minor tight spots at 1,599', 1,250', 1,205' and 1,170'. Observe well while performing rig maint. RIH to 2,535', M/LT top drive. Wash to btm, circulated up 10,035 units gas w/ MW cut to 13.7 ppg. Incr mud weight from 14.4 to 14.6 ppg while repairing mud pump. Monitor well and POH. February 16, 2008 2,628' MW 15.2 ppg Vis 60 sec Inc10.70 deg POH into shoe, monitor well -gas bubbles visible. RIH to btm, CBU -trip gas 7,168 units. Increase mud weight 14.6 to 15.0 ppg. S/D pumps for 20 min, observe well. CBU -max gas 330 units, BGG 60 units. POH into shoe, monitor well for 2 hrs. RIH to btm, CBU -trip gas 4,400 units, BGG 98 units. Raise mud weight from 15.0 to 15.4 ppg. February 17, 2008 2,628' MW 15.8 ppg Vis 61 sec Inc10.70 deg Increase mud weight from 15.0 to 15.4 ppg. S/D pumps, observe well. POH into casing shoe -hole in good condition. Observe well for 2 hrs. RIH to TD and CBU -max trip gas 4,050 units, mud wt cut to 14.7 ppg. Commence increasing mud wt from 15.4 to 16.2 Ppg• ~nadarl~~ Petroleum Corporation • February 18, 2008 2,628' MW 16.6 ppg. Vis 63 sec Inc10.70 deg Weight up mud to 16.2 ppg. Check well for flow and POH into casing shoe at 1,007'. Hole in good condition and took correct amount of fill. Monitor well for 2 hrs -static. RIH to TD and circulate around. Max trip gas 7,000 units, mud wt cut to 15.2 ppg. Commence increasing mud wt from 16.2 to 16.6 ppg. February 19, 2008 2,628' MW 16.6 ppg Vis 61 sec Inc10.70 deg Weigh up mud to 16.6 ppg. Check well for flow and POH into casing shoe at 1,007'. Hole in good condition. Monitor well for 2 hrs -static. RIH to TD and circulate around. Max trip gas 7,428 units. POH to shoe, change elevators while observing well -static. POH, SB BHA. _Test BOPS to 250/3.000 bsi. Test witness waived by AOGCC. Download MWD and L/D same. L/D stab and float sub. February_20, 2008 2,628' MW 16.6 ppg Vis 63 sec Inc10.70 deg Handle BHA, RIH. CBU at shoe -max gas 8,200 units, mud cut to 14.7 ppg at max gas. RIH to btm, CBU. Max gas 2,610 units, mud cut to 15.7 ppg at max gas. C&C for logs. POH for logs -hole in good condition. M/U lubricator on shooting flange on annular preventer. Make up logging Run #1 (CH Tension -Temp - GR - CN - Zdens -Caliper - XMAC Acoustic) and RIH. February 21, 2008 2,628' MW 16.6 ppg Vis 62 sec Inc10.70 deg Continue OH logging Run #l. R/D WL and lub, R/U bell nipple. M/U 8.75" cleanout BHA and RIH to btm. Hole in good shape. Circulate up copious large cuttings, 2' fill on btm. POH for logs. R/D riser, R/U Lub and WL. RIH w/ logging Run #2 (RCI). February 22, 2008 2,628' MW 16.6 ppg Vis 70 sec Inc10.70 deg Finish logging with RCI tools. POH and R/D WL and lubricator, R/U bell nipple. M/LJ bit and BHA, RIH to 1,290'. Attempt CBU, found top drive to be frozen up. POH to shoe. Thaw top drive, standpipe and kelly hose. February 23, 2008 2,829' MW 16.2 ppg Vis 63 sec Inc10.69 deg Thaw standpipe and kelly hose. Pump through mud lines and top drive, CBU at shoe - gas peak at 885 units. RIH to 1,480'. Grabber on top drive not functioning, bring top drive to floor and warm up. RIH to btm at 2,628', CBU -max gas 220 units. Drill 8- 3/4" hole 2,628' to 2,829'. • ~nadarl~~ Petroleum Corporation February 24, 2008 3,788' MW 15.4 ppg Vis 52 sec Incl 1.30 deg Drill 8-3/4" hole 2,829' to 3,176'. Make correction slide 3,176' to 3,206'. Drill 3,206' to 3,788'. February 25, 2008 4,173' MW 15.4 ppg Vis 52 sec Incl 1.31 deg Drill 8-3/4" hole 3,788' to 3,900'. IBOP failed to open after cnxn and top drive, kelly hose and standpipe froze. Thaw same. Dri113,900' to 4,130'. Begin losing mud at 2 - 6 bph. Pump LCM pill. Check well - no static losses. Dri114,130' to 4,173'. February 26, 2008 4,285" MW 14.6 ppg Vis 63 sec Incl 2.31 deg Drill 8-3/4" hole 4,173' to 4,285' TD. C&C mud and POH. Pull tight at 4,145', commence backreaming. Pipe stuck w/ bit at 3,737'. Jar down and circ at 30 spm, los~ t circ. Pump LCM pill. Cut MW to 14.6 ppg and continue jarring down. Static fluid loss 1-3 bbl/hr. Make blind backoff 143' below rotary table and replace one jt DP w/ pup to bring top of DP down to 3' above RT. February 27, 2008 4,285' MW 14.6 ppg Vis 63 sec Incl 2.31 deg Hang sheaves, R/U freepoint tools. Conduct freepoint investigation -found freepoint at 3,464'. POH and R/D freepoint tools. M/U string shot and RIH to 3,464'. Put left-hand torque into DP and fire string shot. Back off and pick up. Start pumping at 30 spm w/ partial returns at first then complete lost returns.. Slow pumping to 15 spm and mix and pump 50 bbl LCM pill. Static losses reduced from 10 bph to 2 bph. February 28, 2008 4,285' MW 14.4 ppg Vis 64 sec Incl 2.31 deg Blow do top drive, fill hole, monitor well -static. POH, checking torque on each cnxn. Back-off of fish occurred at service break in drilling jars. M/iJ fishing BHA and RIH to 3,161' -took weight. Ream and wash down toward top offish. (TOF at 3,457'.) February 29, 2008 4,285' MW 14.3 ppg Vis 55 sec Inc12.31 deg Wash down from 3,262' to 3,454', partial returns at first, then full returns. Attempt to engage top of fish at 3,457' without success. POH, checking well for proper fill. L/D fishing BHA, M/iJ mule shoe on DP for cementing, RIH. March 1, 2008 2,950' MW 13.7 ppg Vis 70 sec Inc10.84 deg RIH, tag TOF at 3,454'. Circ while R/U cementers. Test lines to 3,000 psi then pump 44 bbls weighted spacer, 49 bbls 17.0 ppg cement, 5 bbls spacer and 23 bbls mud. CIP at 0700 hrs. R/D cementers, POH to 2,503'. .Circ out DP and POH. Pull wear ring, test BOPE to 250/3,000 psi. ~ r ~nada~~ Petroleum Corporation March 2, 2008 3,045' MW 13.6 ppg Vis 70 sec Incl 0.84 deg Finish testing BOPE. M/U BHA and RIH. Tag cement at 2,970'. Dress cement to 3,045'. Cement held 24K lbs weight w/ pumps on. POH. M/U kickoff/directional drilling BHA and RIH. March 3, 2008 3,105' MW 13.3 ppg Vis 56 sec Inc10.84 deg RIH to 3,015', orient tool face. Time drill, attempting to kick off cmt plug, 3,015' to 3,038'. Bit broke through hard cmt into soft cmt. Hard cmt re-encountered at 3,096'. Time drill, attempting to kick off, 3,096' to 3,105'. March 4, 2008 3,330' MW 13.3 ppg Vis 56 sec Inc14.82 deg Time drill (sliding w/ occasional rotation when stabilizer hung up) from 3,105' to 3,330' -kicked off cmt plug and built angle for separation from original wellbore. March 5, 2008 3,861' MW 13.3 ppg Vis 52 sec Inc14.65 deg Drill and slide 3,330' to 3,527'. Make wiper trip to 2,952' -hole in good condition. Dri113,527' to 3,861'. March 6, 2008 3,950' MW 13.5 ppg Vis 51 sec Inc14.65 deg Drill 8-3/4" hole 3,861' to 3,950' TD. CBU, trip to csg shoe and back to TD - 8' fill. ,/ CBU, POH. Pulled tight at 3,633'. Raise MW 2 points while circ. POH w/ no further problems. S/B HWDP and jars, L/D BHA, download LWD tools. March 7, 2008 3,950' MW 13.6 ppg Vis 51 sec Inc14.65 deg Finish L/D MWD tools. R/U WL, N/D bell nipple, N/U lubricator. P/U logging tools: HDIL-XMAX-Cal-CN-ZDL-GR. RIH to TD, log out. POH and change tools to RCI. RIH w/ RCI and take 15 pressure sets. March 8, 2008 3,950' MW 13.6 ppg Vis 51 sec Inc14.65 deg Finish running RCI log, POH, R/D WL. M/U clean-out BHA, RIH. Hole tight at 3,112'. Wash through w/o rotation. RIH to TD w/ no addn'1 hole probs. CBU x 2. POH, L/D HWDP and BHA. • • ~adarll~ii~ Petroleum Corporation March 9, 2008 3,950' MW 13.6 ppg Vis 51 sec Incl 4.65 deg Clear floor. C/O top rams to 7". R/U to run casing. Set test joint of 7" csg in rams to test 7" rams -egged collar on test jt. P/iJ new test jt and test rams to 3,000 psi - OK. Csg tongs failed, R/U new set. Run 7" csg. March 10, 2008 3,950' MW 13.6 ppg Vis 51 sec Inc14.65 deg Run 7" csg to 3,935', washing thru tight spot at 1,604' and working thru KOP. R/D csg running tools, R/U cementers. Circ hole while batching up. Pump 1St stage consisting of 115 bbls of 18 ppg cement, displace w/ mud. Bump plug, pressure up and open stage tool (at 1,300') w/ 3,100 psi. Circ above stage tool, received 1 bbl good cement back. Pump 2"d stage consisting of 43 bbls of 14.5 ppg gas-block cement, displace w/ mud. Land top plug in stage tool and shift tool closed w/ 1,900 psi. Received 1 bbl 14.5 ppg cmt back at surface. Verify stage tool closed and R/D cementers. Test BOPE. March 11, 2008 3,950' MW 13.5 ppg Vis 53 sec Inc14.65 deg Test floor valves and accumulator. Change 7" rams to 3-1/2" X 5" VBRs. Repair BOPS while cleaning pits and organizing completion in pipe shed. Finish testing BOPE. M/U clean-out BHA and RIH. Drill up stage tool closing plug. Test casing to 500 psi. RIH to 3,759' March 12, 2008 3,950' MW 13.5 ppg Vis 56 sec Inc14.65 deg RIH, tag up at 3,807'. CBU X 2 and POH. R/U SLB WL. RIH w/ gauge ring, tag up at 3,773', POH. WL Run #2 - GR/CCL log to 3,773'. WL Run #3 - USIT/CBL. R/D WL equipment. Pressure test casing to 5,000 psi for 30 minutes - food test. M/iJ casing scraping BHA. March 13, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg Finish M/LT csg scraper BHA and RIH to shut-off baffle. Drill rubber plug on baffle 3,807' to 3,808'. Circ well while cleaning pits and mixing weighted pill and surfactant. Displace well w/ 2% KCl brine. POH, S/B 20 stands DP. POH, L/D remainder of DP. L/D DCs. March 14, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg L/D BHA. Perform 5,000 psi test on casing. R/U WL, run correlation GR/CCL log to TD and out. R/D WL. M/U 4-5/8" TCP guns, firing head, auto release, tubing and packer and RIH. Tag btm, pull up to pkr setting depth. Pump 64 bbls diesel, displace w/ 17 bbls brine. Drop ball and set pkr. Shear off of pkr, test pkr/annulus to 500 psi., POH, L/D DP. ~nada~~ Petroleum Corporation March 15, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg Finish L/D DP and setting tools. R/U to run tbg. M/U and RIH w/ pkr, 2 chemical injection mandrels and two 1/a" CI control lines on tubing. Land tbg hgr in wellhead, lock down, drop ball and set pkr. B/O landing jt, set BPV, clear floor. March 16, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Blow down all lines, hoses and mud manifold. R/D all BOPE and related valves and hoses. N/D 11" SM X 11" lOM adapter spool, N/U 3-1/8" SM production tree and test. Perform injection test down CI lines. Release rig at 22:30, 3/16/2008. March 17, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Well testers rigging up while rig demobs. Prepare base for flare stack, hang floats in separator. Cold weather hampering operations. March 18, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg R/U as possible during rig demob which is in turn hampered by cold wx (-SOF). Arrange equip on ground, but cannot erect due to cranes being shut down by wx. March 19, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg R/U of testing equipment mostly shut down due to weather (-53F). Prep to change out broken line heater, prepare flare stack for assembly and raising. March 20, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Send out non-functioning line heater, receive new one. Spot and prepare to raise flare mast. Spot and commission office unit. Waiting for rig components to get out of the way. March 21, 2008 Continue limited work while drilling rig rigs down. Lay out equipment as possible, wire up electrical and corns. March 22, 2008 Assemble, raise and secure flare stack. Receive and spot cherry picker, additional heaters, pickup truck. Office unit warmed up and corns being installed. ~adarl~~ Petroleum Corporation March 23.2008 M/LJ line to flare stack. Install line heater in berm, fill w/ glycol and fuel and put heat on it. M/U lines to line heater, choke, separator and metering skid. Plug power into add'1 office skid and warm up. Prep area around wellhead for mats and scaffolding. March 24, 2008 Set mats and plywood across cellar. Spot testing SSV. R/U scaffolding around well and test scrubber and tent same. Install and insulate hoses to manifolds and tanks. M/U lines to test equipment. Warm line heater in preparation for test firing. Warm up data- gathering office. March 25, 2008 R/U scan equip on separator and methanol injection pump. R/U crossover, safety valve and short section of line to wing valve on tree. Fire line heater and bring glycol up to operating temp. Insulate pipes and hoses, grease valves in choke manifold. Wire line heater and office shacks. GCI work on comets. March 26, 2008 Continue rigging up lines. Air test lines w/ 130 psi for several hours. Receive and spot gen set, re-spot office skids, continue comet work. March 27, 2008 Continue rigging and insulating lines and instrumentation. Insulate ice pad around flare stack. Fire up and spot slickline unit and hot oil pumper. March 28, 2008 Continue R/U test equipment and instrumentation. M/U insulated line f/ wellhead to choke manifold. Take on diesel for hot oiler. Set warning delineators. Pressure test annulus valves, pull BPV. R/U slickline unit, RIH, pull ball and rod from RHC plug then pull RHC plug. R/U sensors on data header, re-spot heater and power cables. Fill lines w/ warm diesel and pressure test all. March 29, 2008 ~~`~ ~~ ` ~'~ ` ~ ~~~ Finish preparing for test. Apply pressure to well, fire guns. Open well for 1-1/2 hrs, shut in well for 3 hrs. R/U slickline, RIH w/ 2.7" GR. No obstructions found and verified that guns had dropped. Conduct swabbing operations using slickline unit. ~adarl~~ Petroleum Corporation March 30, 2008 Continue swabbing until well came in. Flow well. R/U slickline and install downhole gauges. Continue to flow well for duration of planned flow period. Shut in well for pressure build-up. March 31, 2008 Well shut in for pressure build-up. April 1, 2008 Continue pressure build-up. R/LJ slickline, retrieve downhole gauges, run GR to top of dropped guns at 3,681' SLM. R/D slickline, R/U e-line. RIH,_,re-perforate interval 3,612' - 3,652' w/ 2 gun runs, 2-1/2" hollow carriers at 6 spf. April 2, 2008 Continue re-perforating 3,542' - 3,582' w/ 2 gun runs, 2-1/2" hollow carriers at 6 spf. R/D e-line, open well to flow. Service tree valves while flowing. R/U e-line and run production log across perforated interval. R/D e-line, continue to flow well. Apri13, 2008 Continue flowing well. Obtain downhole water sample via slickline sample bailer. Run GR, tag up on and break through ice plug at tbg tail. Run sample bailer, got stuck at tbg tail, pull out of rope socket. Recover fish after several attempts. Spot methanol on ice plug at tbg tail. RIH w/ GR, tag up on ice plug. Chip through ice, broke through and tools got blown up hole, stuck at 3,469' SLM. Hold 500 lbs overpull on line while arranging fishing tools from Deadhorse. Apri14, 2008 Continue flowing well while waiting for fishing tools from Deadhorse. Well choked itself off while R/U Kinley cutter. Shut in well at choke and drop cutter. Cut wire, recovered same and Kinley cutter. RIH w/ LIB, found fish at 3,244', POH. Stop downhole methanol injection, secure well and monitor SITP. Apri15, 2008 R/U WL unit, lubricator and BOP's. RIH w/ 3-1/2" EZSV bridge plug, log on depth and set at 3,185' (in middle of a .joint). Release running tool and tag EZSV to confirm placement. POH. SITP 1,300 psi. Bleed down to 140 psi for drawdown test on EZSV - ~ood test. R/U 2-1/8" x 32' dump bailer. Mix cement and fill bailer. RIH w/ bailer, tag EZSV, P/LT 15' and dump 12.5' cement on retainer.. POH, re-dress bailer. ~ ~ ~adarl~~ Petroleum Corporation Apri16, 2008 RIH w/ cement-filled dump bailer. Bailer failed, POH. Re-dress and re-load bailer, RIH. Dump 12.5' of cement on top of previous 12.5' cement, POH. Load hole w/ 35 bbls diesel. Perform 20-minutepressure tests of CIBP/cement at 650 pair 1,045_psi and 2,050 -psi• M/U CIBP on WL, RIH. Set CIBP at 1,750'. POH Pressure test CIBP to 960 psi for 20 minutes. P/U 25' of 2-1/2" HC perforating guns, RIH. Perforate 1,615' to 1,640' w/ 6 spf. POH and P/LT another 25' length of 2-1/2" HC guns, RIH. ,~'erforate 1,590' - 1,615' w/ 6 spf. POH, R/D WL. Open well for cleanup through testing facilities. April 7, 2008 Flow well through production testing facility at various choke settings. Shut well in for pressure build-up. Apri18, 2008 Continue recording SITP. Apri19, 2008 Continue recording SITP. Commence rigging down tank farm and flare boom. April 11, 2008 Continue R/D test equipment. Inject 186 bbls produced fluids into perfs. R/U lubricator and perf tubing 1,498' - 1,506' w/ 17 holes. R/D lubricator. R/U to cement down tubing w/ return line on annulus going through choke. Pump 22 bbls cmt down tbg then open choke sufficiently to maintain backpressure and pump additional 35 bbls cmt. Result: 5 bbls went into perfs, 17.7 bbls in tbg and 39.5 bbls in annulus4 Good cmt returns to surface. Shut well in to WOC. April 12, 2008 Continue R/D test equipment. Clear area around wellhead to provide access. N/D csg valve and tree. Tag TOC w/ T-bar, TOC at 7' below tbg hgr. R/U heaters and hoses to btm of cellar to melt and remove ice. April 13, 2008 Clean water and debris from cellar. Cut off all casing strings below 9-5/8" hanger and remove all wellhead equipment. Tag cement in tubing and all annuli. Notify AOGCC inspector and prep to make final casing cutoff at +5' below tundra level. ~ ~ ~nada~~ Petroleum Corporation April 14, 2008 Make final cut at 6' below tundra level Cement at surface in tubing and all annuli. ,Got okay from AOGCC to weld marker plate on. Weld on marker plate. Attempt to remove ~ cellar w/ forks on loader - no good. Order out backhoe -will be on location in 2-3 days. April 15, 2008 Demob fluids and equipment. April 16, 2008 Demob fluids and equipment. April 17, 2008 Demob fluids and equipment. r~ REV DATE BY CK APP RIP110N R DATE BY APP DESCRIPTION NOTES ~ to `" iz I. COORDINATES SHOWN ARE NAD27, ALASKA STATE PLANE ZONE 4. ~ 2. GEODETIC COORDINATES ARE NAD 27. 7 16 i5 14 I3 3. ALL DISTANCES ARE TRUE. 4. PAD IS ROTATED 70' WEST FROM TRUE NORTH. 5. APPROXIMATE ELEVATION OF WELL CELLAR IS 515.2 FEET. N zo zl z2 23 24 CHANDLER I • LOCATED WITHIN PROTRACTED SEC. 15, T1 S,&R2E, • UMIAT MERIDIAN. 2364' F.S.L, 928' F.W.L. z9 za 27 Zs z~• LAT = 69'21'16.99" N LONG = 151'37'58.94" W Y = 5,616,141 N~- X = 289,128 ~ SCALE: I"=200' 3 ~ /34 35 36 X35' T 1 S ~~/ ~ S ~ . VICINITY MAP ~£ SQi7 1 " = 1 MILE / \ ~ AS BUILT CONDUCTOR LOCATION N ~ ~ \ ~ 4 / o / _~ ry N ~~~~ J ~ ~~ ~ 2 L /~ ```~~~~~~~~~~itt' ` `~ .. I ~~j~~ ., ~ G pqO \ ~ Kenneth W. A LS-8535 i~ •' I S~0'~ Q OW-~J.~~- ~~ I !CE PAD LIMITS ` ~ ~ 1~~~„"""~~~ W V SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LANG SURVEYING IN THE STATE OF LOUNSBURY ALASKA AND THAT THIS REPRESENTS A SURVEY DONE BY ME & A330CIATE3, INC. OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS sosvsxo>RS nton+>E~ ~ ~~ ~'a~1 AND OTHER DETAILS ARE CORRECT AS OF MARCH I8, 2008. Anadarko CHANDLER I EXPLORATORY WELL WELL CON DUCTOR AS BUILT Petroleum Corporation CADD FlLE DATE. DRAWING N0: SHEET: REV: 3/18/08 CHANDLER ASBUILT I ~ I O Sperry Drilling Services "; INSITE - DIRECTIONAL SURVEY REPORT Anadarko Petroleum Corporation Gubik 3 BP01 Gubik North Slope Borough Alaska USA AK-MW-000555116 n__ Measud Vertical ~~`erficat `~~ Dept lnclinafion ~,~~ ~t:~„~,; Depth Latitude, : Departure ~ectior~' dogleg (feet'} (d~r~es) ~~°~f (feet) (feet) {feet) , (fees) , (degl100tt) 0.00 0.00 0.00 0.00 0.00 N 0.00E 0.00 TIE-IN 143.77 0.06 265.00 143.77 0.01 S 0.07 W -0.01 0.04 230.63 0.48 151.18 230.63 0.33 S 0.06 E -0.33 0.58 325.99 0.54 179.13 325.99 1.13 S 0.26 E -1.13 0.27 410.41 0.71 185.58 410.40 2.05 S 0.22 E -2.05 0.22 499.61 0.57 2D3.28. 499.59.. 3.01 S 0.01 W -3.01 0.27 588.49 0.56 189;.33 588.47 3.85 S 0.26 W -3.85 0.15 676.96 0.53 184.99 676.94 4.68 S 0.37 W -4.68 0.06 _~ _ 860.00 0.68 178.32 859.97 6.61 S . 0.41 W, -6.6`I 0.09 919.68 0.70 '~ ~ `' 186.79 919.64 7;32 S ~ 0.44 'U~f -7:32 w;~ .^ 0.17 1007.00 0.86 208.33 1006.95 8.42 S 0.81 W -8.42 0.38 1027.53 0.91 212.13 1027.48 8.70 S 0.97 W -8.70 0.38 1121.96 1.11 215.23 1121.90 10.08 S 1.90 W -10.08 0.22 1214.77 1.12 211.41 1214.69 11.59 S 2.89 W -11.59 0.08 1313.69 1,19 212.13 1313.59 13.29 S 3.94 W -13.29 0.08 1411.53 1.23 217.57 1411.41 14,9$ S ' 5,12 W -14.98 0.12 1456.64. 0.98 216.84 1458.51 15.70 S " 5.67 W -15.70 ' 0.53 1508:40 0.99 204,57 1508.26 16.43 S 6.10 W -16.43 a' 0.42 1604.56 0.92 222.35 1604.41 17.75 S 6.97 W ®17.75 0.32 1698.49 1.11 219.67 1698,32 19.01 S . 8.06 W -19.01 4.21 1796.23 1.33 231.76 1796.04 20.44 S 9.55 W -20.44 0.34 1892.38 0.66 229.23 1892.18 21.49 S 10.85 W -21.49 0.69 1937.19 0.31 217.09 1936.98 21.76 S 11.12 W -21.76 0.82 1989.71 0.25 221.86 1989.50 21.96 S 11.28 W -21.96 0.11 2086.04 0.38 225.91 2085.83 22.34 S 11.65 W -22.34 0.13 2180;27 0.14 342:24 2180.06 22.44 S '"~` 11.91 W -22.44 0.48 ~' 2276.13 '0;14. 135.43 2275.92 22.45 S 11.97 W -22.45 0:28 2372.55 0.22 272.46 2372.34 22.55 S 12:19: W -22.55 0.24 ,`' 2470.75 0.14 182.08 2470.54 22.66 S 12.38 W -22.66 0.27 ~;' 2566:29- 0.28 216.38 2566.08 22.96 S 12.52 W -22.96 _ 0.19 2667.32 0.56 206.55 2667.11 23.60 S 12.89 W -23.60 0.29 2762.38 0.67 197.72 2762.16 24.54 S 13.26 W -24.54 0.15 2857.21 0.69 189.01 2856.99 25.62 S 13.52 W -25.62 0.11 2952.31 0.84 193.18 2952.08 26.87 S 13.77 W -26.87 0.17 3082.95 1.22 198.46 3082.70 29.11 S 14.43 W -29.11 0.30 3116.00. 2.12 208.05 3115.73 29.99 S - 14.83 W -29.99 y 2.85 3129.45 2.49 209.95 3129.`i7 30.46 S 15.09 W -30.46. 2.78 3145.36 2.94 219.15 3145:06 31.07 S 15.52 W -31,07 3.92 3179.27 3.50 221:89 3178.92 32.52 S 16.76 W -32.52 1.72 3224.62 3.63 223.32 3224.18 34.59 S 18.66 W -34:59 0.34 3275.34 3.91 229.37 3274.79 36.88 S 21.08 W -36.88 0.96 3325.51 4.59 235.06 3324.82 39.14 S 24.02 W -39.14 1.60 3373.61 4.82 242.35 3372.76 41.18 S 27.39 W -41.18 1.33 3469.44 4.65 238.64 3468.27 45.07 S 34.27 W -45.07 0.37 3562.69 4.57 241.53 3561.22 48.81 S 40.76 W -48.81 0.26 r'° 3660.36 4.47 239.70 3658.58 52.58 S 47.46 -52:58. 0.18 ' 3756.49 4.27 240.88 3754.43 56.21 S 53.82 `~' -56.21 0.22 ~N 3853.75 4.23 240.95 3851.42 59.72 S 60.12 W ' -59.72 0.04 3887.20 4.1$ 242.73 3884.78 60.88 S 62.29 W -60.88 0.42 3950.00 4.1'>3 242.73 3947.42 62.98 8 66.35 W -62.98 0.00. ___ 3.~ 1 ~, s ~ ~. ~~x ~r~~,~~, ~. ~a ~v~~w~ Date Printed:06 March 2008 Nanushuk Test 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 3/30/2008 Flow Date of Test: Hours Production for Oil-Bbl: Gas-MCF: Water- Choke Gas-Oil Ratio: Tested: Bbl: Size: Test ~ ~ 4/4/2008 59 1/2 Period 0 2187 0 64/64 N/A Flow Tubing Casing Calculated Oil-Bbl: Gas-MCF: Water- Oil Gravity -API Press: Bbl: (corr): Press. 24-Hour ~ 24 273 Rate 0 882 0 N/A Tuluvak Test 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 4/6/2008 Flow Date of Test: Hours Production for Oil-Bbl: Gas-MCF: Water- Choke Gas-Oil Ratio: Tested: Bbl: Size: Test 4/7/2008 16 Period "'~ 0 9568 0 62/64 N/A Flow Tubing Casing Calculated Oil-Bbl: Gas-MCF: Water- Oil Gravity -API Press: Bbl: (corr): Press 24-Hour / . 655 238 Rate ~ 0 14352 0 N/A WELL TEST REPORT CUSTOMER : Anadarko WELL NAME : Gubik #3 ® EXPRO DATE : 30-Mar-08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Petroleum Corporation CHOKE SEPARATOR F LOW RATES C UMULATIV E FLUID P ROPERTIE S DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d OIL stb/d WATER stb/d GAS MMsc OIL stb WATER stb OIL API 60° GAS Air-1 BS&W % COZ % HZS m CHLORIDES m 30-Mar-08 00:00 64 6 35 87 0 75 0.000 0.00 0.00 0.000 4.58 0.00 0.00 30-Mar-OS 00:15 64 0 34 93 0 74 0.000 0.000 30-Mar-08 00:30 64 0 32 84 1 73 0.000 0.00 0.00 0.000 4.58 0.00 0.00 30-Mar-08 00:45 64 0 32 96 0 73 0.000 0.000 30-Mar-08 01:00 64 0 32 83 0 72 0.000 0.00 0.00 0.000 4.58 0.00 0.00 30-Mar-08 01:15 64 0 32 99 0 72 0.000 0.000 30-Mar-08 01:30 64 48 32 99 0 71 0.000 400.08 0.00 0.000 12.92 0.00 0.00 30-Mar-08 01:45 64 0 32 101 0 70 0.000 0.000 30-Mar-08 02:00 64 8 32 106 0 70 0.000 80.02 0.00 0.000 14.59 0.00 0.00 30-Mar-08 02:15 64 1 33 108 0 69 0.000 480.10 0.00 0.000 19.59 30-Mar-08 02:30 64 39 42 141 0 69 0.000 2641.00 0.00 0.000 37.92 0.00 0.00 30-Mar-08 02:45 36 296 48 178 22 81 0.000 0.000 30-Mar-08 03:00 36 285 45 166 54 100 0.642 940.00 0.00 0.007 51.93 0.00 0.00 30-Mar-08 03:15 36 239 44 154 62 102 0.940 0.016 0.592 0.15 0.00 30-Mar-08 03:30 40 189 43 156 57 105 1.094 558.00 0.00 0.028 71.52 0.00 0.00 30-Mar-08 03:45 40 225 42 163 53 110 0.977 0.038 30-Mar-08 04:00 40 136 41 150 60 118 1.412 18.40 0.00 0.053 83.54 0.00 8.25 30-Mar-08 04:15 48 82 40 136 50 121 1.132 0.065 30-Mar-08 04:30 48 67 39 128 46 125 1.007 0.00 0.00 0.075 83.54 0.00 8.25 30-Mar-08 04:45 48 65 38 122 41 124 0.939 0.085 30-Mar-08 05:00 48 64 36 116 22 128 0.863 20.00 0.00 0.094 83.54 0.00 42.6 0.00 30-Mar-08 05:15 48 62 37 123 27 128 1.016 0.104 30-Mar-O8 05:30 48 56 37 115 22 125 0.904 0.00 0.00 0.114 83.54 0.00 0.00 0.65 0.00 30-Mar-08 05:45 48 55 37 121 23 122 0.874 0.123 30-Mar-08 06:00 48 44 36 113 21 93 0.863 0.00 0.00 0.132 83.96 0.03 0.00 30-Mar-08 06:15 48 42 37 110 21 82 0.836 0.141 30-Mar-08 06:30 48 43 37 111 21 75 0.832 0.00 0.00 0.149 83.96 0.03 0.00 30-Mar-08 06:45 48 49 37 117 21 71 0.840 0.158 30-Mar-08 07:00 48 58 36 110 22 93 0.845 20.00 0.00 0.167 83.96 0.03 0.00 30-Mar-08 07:15 48 63 36 122 23 101 0.907 0.176 30-Mar-08 07:30 48 59 36 111 21 77 0.887 0.00 0.00 0.186 83.96 0.03 43.1 12.80 30-Mar-08 07:45 48 55 37 117 21 69 0.865 0.195 30-Mar-08 08:00 48 56 37 110 20 65 0.863 34.89 4.80 0.204 84.41 0.13 0.596 12.80 30-Mar-08 08:15 48 56 37 111 19 62 0.858 0.212 30-Mar-08 08:30 48 55 37 112 20 61 0.866 34.89 4.80 0.221 85.11 0.23 12.80 30-Mar-08 08:45 48 52 37 112 19 59 0.855 0.230 30-Mar-08 09:00 48 59 37 110 20 58 0.858 5.96 14.00 0.239 85.95 0.53 70.20 30-Mar-08 09:15 64 83 38 111 22 60 0.912 0.249 30-Mar-08 09:30 64 33 38 113 21 59 0.883 5.96 14.00 0.258 86.08 0.82 70.20 30-Mar-08 09:45 64 29 38 110 21 59 0.886 0.267 30-Mar-0810:00 64 39 39 119 21 59 0.881 2.00 18.00 0.276 86.12 1.19 90.00 30-Mar-0810:15 64 30 39 113 21 59 0.879 0.286 Expro Well Testing 1 of 3 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO WELL DATE : 30 Ma~08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park leum CorPOratio~ CHOKE SEPARATOR FLOW RATE S CUMULATIV E FLUID P ROPERTIE S DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d OIL stb/d WATER stb/d GAS MMsc OIL stb WATER stb OIL API 60° GAS Air-1 BS&W % COZ % HZS m CHLORIDES m 30-Mar-0810:30 64 39 40 113 21 59 0.887 2.00 18.00 0.295 86.14 1.57 90.00 30-Mar-0810:45 64 35 40 108 21 58 0.890 0.304 30-Mar-0811:00 64 28 41 113 22 58 0.892 1.20 18.80 0.313 86.19 1.96 94.00 65,000 30-Mar-0811:15 64 29 41 110 22 57 0.899 0.323 30-Mar-0811:30 64 43 41 113 23 57 0.898 1.20 18.80 0.332 86.21 2.35 94.00 30-Mar-0811:45 64 30 42 114 23 57 0.903 0.342 30-Mar-0812:00 64 30 42 114 20 58 0.908 1.20 18.80 0.351 86.24 2.74 0.596 94.00 0.80 0.00 70,000 30-Mar-0812:15 64 30 42 114 21 57 0.950 0.361 30-Mar-0812:30 64 30 42 119 21 57 0.950 0.60 19.20 0.371 86.24 3.14 94.00 30-Mar-0812:45 64 40 42 113 23 58 0.920 0.380 30-Mar-0813:00 64 32 43 117 24 58 0.919 0.00 0.00 0.390 86.25 3.14 94.00 30-Mar-0813:15 64 43 44 121 25 57 0.919 0.399 30-Mar-0813:30 64 44 44 109 25 57 0.922 0.00 0.00 0.409 86.25 3.14 94.00 30-Mar-0813:45 64 43 44 118 25 57 0.925 0.419 30-Mar-0814:00 64 43 44 107 26 57 0.926 0.80 19.20 0.428 86.26 3.54 96.00 30-Mar-0814:15 64 46 44 108 25 58 0.933 0.438 30-Mar-0814:30 64 34 44 121 25 58 0.930 0.80 19.20 0.448 86.28 3.94 96.00 30-Mar-0814:45 64 43 45 118 25 58 0.930 0.457 30-Mar-0815:00 64 38 45 121 26 57 0.935 1.00 19.00 0.467 86.30 4.34 95.00 30-Mar-0815:15 64 42 45 109 26 58 0.943 0.477 30-Mar-0815:30 64 39 45 122 25 57 0.937 1.00 19.00 0.487 86.30 4.34 95.00 30-Mar-0815:45 64 35 45 116 25 57 0.926 0.496 30-Mar-0816:00 64 40 45 113 25 56 0.927 0.00 0.00 0.506 86.30 4.34 0.595 100.00 0.65 0.00 30-Mar-0816:15 64 41 45 115 24 56 0.929 0.516 30-Mar-0816:30 64 31 44 125 24 56 0.910 0.00 0.00 0.525 86.30 4.34 100.00 30-Mar-0816:45 64 44 44 128 23 55 0.919 0.535 30-Mar-0817:00 64 42 44 119 22 56 0.914 0.00 39.00 0.544 86.30 5.16 100.00 30-Mar-0817:15 64 38 44 118 23 56 0.901 0.554 30-Mar-0817:30 64 32 45 125 23 57 0.887 0.00 39.40 0.563 86.30 5.16 100.00 30-Mar-0817:45 64 35 44 122 24 56 0.889 0.572 30-Mar-0818:00 64 32 43 123 24 56 0.881 0.00 19.70 0.581 86.30 5.57 100.00 30-Mar-0818:15 64 45 43 137 24 56 0.884 0.591 30-Mar-0818:30 64 30 42 128 23 55 0.902 0.00 0.00 0.600 86.30 5.57 100.00 30-Mar-0818:45 64 35 42 140 21 55 0.900 0.609 30-Mar-0819:00 64 37 42 127 21 54 0.898 0.00 0.00 0.619 86.30 5.57 100.00 30-Mar-0819:15 64 22 41 137 20 54 0.895 0.628 30-Mar-0819:30 64 27 42 143 19 54 0.895 0.00 0.00 0.637 86.30 5.57 0.595 100.00 0.70 0.00 30-Mar-0819:45 64 22 42 143 18 54 0.876 0.646 30-Mar-O8 20:00 64 31 42 146 18 54 0.897 0.00 19.80 0.656 86.30 5.98 100.00 30-Mar-OS 20:15 64 29 42 150 19 59 0.907 0.665 30-Mar-08 20:30 64 36 43 149 19 57 0.881 0.00 79.22 0.674 86.30 7.63 100.00 30-Mar-08 20:45 64 39 42 140 19 56 0.874 0.684 Expro Well Testing 2 of 3 5/1/2008 WELL TEST REPORT Cam/ CUSTOMER: Anadarko O G./\~~® WELL D~E : 30-Ma~08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~~a~l~w ~ Petroleum Corporation CHOKE SEPARATOR F LOW RATES CUMULATIV E FLUID P ROPERTIES DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d OIL stb/d WATER stb/d GAS MMsc OIL stb WATER stb OIL API 60° GAS Air-1 BS&W % COz % HZS m CHLORIDES m 30-Mar-08 21:00 64 39 42 140 19 55 0.863 0.00 39.61 0.693 86.30 8.46 0.590 100.00 30-Mar-08 21:15 64 25 42 148 20 55 0.882 0.702 30-Mar-08 21:30 64 35 41 141 22 57 0.926 0.00 80.02 0.711 86.30 10.12 100.00 • Expro Well Testing 3 of 3 5/1/2008 GAS FLOW REPORT ® CUSTOMER : Anadarko O EXPRO WELL NAME : Gubik #3 DATE : 30-Mar-08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m CorPOratio~ SEPA RATOR GAS FA CTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) ~ (psia) DIFF. PRESS (inches Hz0) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 30-Mar-08 00:00 64 14.73 0.56 74.55 0.00 1.000 2.872 0.00 1.0000 1.0000 1.0000 0.9863 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 00:15 64 15.21 0.66 73.96 0.00 1.000 3.168 0.00 1.0000 1.0000 1.0000 0.9868 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 00:30 64 15.31 0.70 73.43 0.00 1.000 3.274 0.00 1.0000 1.0000 1.0000 0.9873 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-OS 00:45 64 15.18 0.70 72.94 0.00 1.000 3.260 0.00 1.0000 1.0000 1.0000 0.9878 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 01:00 64 15.12 0.64 71.95 0.00 1.000 3.111 0.00 1.0000 1.0000 1.0000 0.9887 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 01:15 64 14.96 0.65 71.65 0.00 1.000 3.118 0.00 1.0000 1.0000 1.0000 0.9890 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-OS 01:30 64 15.03 0.60 71.21 0.00 1.000 3.003 0.00 1.0000 1.0000 1.0000 0.9894 1.0000 1.0003 1.0000 0.00 0.000 0.00 30-Mar-0B 01:45 64 15.05 0.69 70.41 0.00 1.000 3.222 0.00 1.0000 1.0000 1.0000 0.9901 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-OS 02:00 64 14.94 0.66 70.34 0.00 1.000 3.140 0.00 1.0000 1.0000 1.0000 0.9902 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 02:15 64 14.96 0.68 69.48 0.00 1.000 3.189 0.00 1.0000 1.0000 1.0000 0.9910 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-OS 02:30 64 15.11 0.66 69.20 0.00 1.000 3.158 0.00 1.0000 1.0000 1.0000 0.9913 1.0000 1.0003 1.0000 0.00 0.000 0.000 30-Mar-08 02:45 36 37.11 0.67 81.45 0.00 1.000 4.986 0.00 1.0000 1.0000 1.0000 0.9800 1.0000 1.0001 1.0030 0.00 0.000 0.000 30-Mar-08 03:00 36 68.98 3.00 99.77 3.00 1.000 14.385 1907.81 1.0000 1.0000 1.0000 0.9638 1.0029 1.0003 1.0070 1858.28 0.642 0.007 30-Mar-08 03:15 36 77.04 5.79 101.62 3.00 1.000 21.120 1907.81 1.0000 1.0000 1.0000 0.9622 1.0019 1.0004 1.0090 1855.76 0.940 0.016 30-Mar-08 03:30 40 71.91 5.05 105.44 3.00 0.592 19.056 1907.81 1.0000 1.0000 1.3000 0.9590 1.0022 1.0004 1.0040 2392.49 1.094 0.028 30-Mar-08 03:45 40 67.94 4.29 109.65 3.00 0.592 17.072 1907.81 1.0000 1.0000 1.3000 0.9554 1.0024 1.0004 1.0030 2383.39 0.977 0.038 30-Mar-OS 04:00 40 74.29 8.32 117.63 3.00 0.592 24.861 1907.81 1.0000 1.0000 1.3000 0.9488 1.0016 1.0007 1.0030 2366.27 1.412 0.053 30-Mar-08 04:15 48 64.89 6.16 121.38 3.00 0.592 19.993 1907.81 1.0000 1.0000 1.3000 0.9457 1.0021 1.0006 1.0030 2357.96 1.132 0.065 30-Mar-08 04:30 48 61.04 5.21 124.84 3.00 0.592 17.833 1907.81 1.0000 1.0000 1.3000 0.9429 1.0024 1.0005 1.0030 2350.85 1.007 0.075 30-Mar-OS 04:45 48 55.92 4.95 123.93 3.00 0.592 16.637 1907.81 1.0000 1.0000 1.3000 0.9437 1.0026 1.0005 1.0020 2352.55 0.939 0.085 30-Mar-08 05:00 48 36.69 109.12 128.04 1.50 0.592 63.274 455.03 1.0000 1.0000 1.3000 0.9404 1.0008 1.0200 1.0010 568.38 0.863 0.094 30-Mar-08 05:15 48 41.50 133.09 127.63 1.50 0.592 74.318 455.03 1.0000 1.0000 1.3000 0.9407 1.0006 1.0216 1.0010 569.54 1.016 0.104 30-Mar-08 05:30 48 37.21 117.23 124.93 1.50 0.592 66.046 455.03 1.0000 1.0000 1.3000 0.9429 1.0007 1.0212 1.0010 570.56 0.904 0.114 30-Mar-08 05:45 48 37.28 109.00 122.02 1.50 0.592 63.746 455.03 1.0000 1.0000 1.3000 0.9452 1.0007 1.0197 1.0010 571.15 0.874 0.123 30-Mar-08 06:00 48 36.19 104.24 93.40 1.50 0.592 61.420 455.03 1.0000 1.0000 1.3000 0.9694 1.0008 1.0194 1.0010 585.68 0.863 0.132 30-Mar-08 06:15 48 35.69 97.41 82.28 1.50 0.592 58.962 455.03 1.0000 1.0000 1.3000 0.9792 1.0008 1.0183 1.0020 591.11 0.836 0.14 30-Mar-08 06:30 48 35.66 95.30 74.86 1.50 0.592 58.296 455.03 1.0000 1.0000 1.3000 0.9860 1.0008 1.0180 1.0020 595.02 0.832 0.149 30-Mar-OS 06:45 48 35.91 95.59 70.99 1.50 0.592 58.589 455.03 1.0000 1.0000 1.3000 0.9896 1.0008 1.0179 1.0020 597.17 0.840 0.158 30-Mar-08 07:00 48 36.74 98.48 92.58 1.50 0.592 60.151 455.03 1.0000 1.0000 1.3000 0.9701 1.0008 1.0180 1.0010 585.37 0.845 0.167 30-Mar-08 07:15 48 38.14 110.57 100.54 1.50 0.592 64.940 455.03 1.0000 1.0000 1.3000 0.9632 1.0007 1.0195 1.0020 582.02 0.907 0.176 30-Mar-OS 07:30 48 35.84 107.73 77.48 1.50 0.592 62.137 455.03 1.0000 1.0000 1.3000 0.9836 1.0008 1.0202 1.0020 594.85 0.887 0.186 30-Mar-08 07:45 48 35.34 102.21 68.78 1.50 0.592 60.101 455.03 1.0000 1.0000 1.3000 0.9917 1.0008 1.0195 1.0020 599.32 0.865 0.195 30-Mar-08 08:00 48 34.64 103.03 64.81 1.50 0.592 59.741 455.03 1.0000 1.0000 1.3000 0.9954 1.0008 1.0200 1.0020 601.90 0.863 0.204 30-Mar-08 08:15 48 34.16 102.64 62.17 1.50 0.592 59.213 455.03 1.0000 1.0000 1.3000 0.9979 1.0008 1.0202 1.0020 603.55 0.858 0.212 30-Mar-08 08:30 48 34.55 103.19 60.57 1.50 0.592 59.709 455.03 1.0000 1.0000 1.3000 0.9995 1.0008 1.0201 1.0020 604.42 0.866 0.221 30-Mar-08 08:45 48 34.13 102.20 59.40 1.50 0.596 59.060 455.03 1.0000 1.0000 1.2950 1.0006 1.0008 1.0202 1.0020 603.10 0.855 0.230 30-Mar-OS 09:00 48 34.38 101.96 58.32 1.50 0.596 59.206 455.03 1.0000 1.0000 1.2950 1.0016 1.0008 1.0200 1.0020 603.63 0.858 0.239 30-Mar-08 09:15 64 36.63 108.47 59.57 1.50 0.596 63.034 455.03 1.0000 1.0000 1.2950 1.0004 1.0008 1.0199 1.0020 602.95 0.912 0.249 30-Mar-08 09:30 64 35.41 105.23 59.40 1.50 0.596 61.043 455.03 1.0000 1.0000 1.2950 1.0006 1.0008 1.0200 1.0020 603.05 0.883 0.258 30-Mar-OS 09:45 64 35.74 104.84 58.87 1.50 0.596 61.213 455.03 1.0000 1.0000 1.2950 1.0011 1.0008 1.0197 1.0020 603.23 0.886 0.267 30-Mar-0810:00 64 35.25 104.97 59.06 1.50 0.596 60.829 455.03 1.0000 1.0000 1.2950 1.0009 1.0008 1.0200 1.0020 603.27 0.881 0.276 Expro Well Testing 1 of 3 5/1/2008 GAS FLOW REPORT ® CUSTOMER : Anadarko O EXPRO WELL DAITE : 30 Ma~08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~troleum CorPOrat SEPAR ATOR GAS FA CTORS DATE 8 TIME (dd-mmm- hh:mm) CHOKE SIZE (64ths) ~ (psia) DIFF. PRESS (inches H2O) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 30-Mar-0810:15 64 35.70 103.38 59.08 1.50 0.596 60.751 455.03 1.0000 1.0000 1.2950 1.0009 1.0008 1.0195 1.0020 602.95 0.879 0.286 30-Mar-0810:30 64 35.87 104.59 58.85 1.50 0.596 61.251 455.03 1.0000 1.0000 1.2950 1.0011 1.0008 1.0196 1.0020 603.17 0.887 0.295 30-Mar-0810:45 64 36.10 104.64 58.16 1.50 0.596 61.461 455.03 1.0000 1.0000 1.2950 1.0018 1.0008 1.0195 1.0020 603.52 0.890 0.304 30-Mar-0811:00 64 36.64 103.53 57.74 1.50 0.596 61.590 455.03 1.0000 1.0000 1.2950 1.0022 1.0008 1.0190 1.0020 603.50 0.892 0.313 30-Mar-0811:15 64 37.09 103.89 57.41 1.50 0.596 62.075 455.03 1.0000 1.0000 1.2950 1.0025 1.0008 1.0188 1.0020 603.60 0.899 0.323 30-Mar-0811:30 64 37.56 102.34 56.80 1.50 0.596 61.999 455.03 1.0000 1.0000 1.2950 1.0031 1.0008 1.0183 1.0020 603.68 0.898 0.332 30-Mar-0811:45 64 37.96 102.30 56.50 1.50 0.596 62.316 455.03 1.0000 1.0000 1.2950 1.0034 1.0008 1.0181 1.0020 603.75 0.903 0.34 30-Mar-0812:00 64 34.37 110.00 56.77 1.50 0.596 61.487 455.03 1.0000 1.0000 1.2950 1.0031 1.0009 1.0382 1.0016 615.21 0.908 0.35 30-Mar-0812:15 64 35.73 116.00 57.00 1.50 0.596 64.379 455.03 1.0000 1.0000 1.2950 1.0029 1.0009 1.0377 1.0017 614.83 0.950 0.361 30-Mar-0812:30 64 35.73 116.00 57.49 1.50 0.596 64.379 455.03 1.0000 1.0000 1.2950 1.0024 1.0013 1.0377 1.0017 614.78 0.950 0.371 30-Mar-0812:45 64 37.76 106.85 57.55 1.50 0.596 63.519 455.03 1.0000 1.0000 1.2950 1.0024 1.0007 1.0190 1.0020 603.66 0.920 0.380 30-Mar-0813:00 64 38.83 103.74 57.52 1.50 0.596 63.468 455.03 1.0000 1.0000 1.2950 1.0024 1.0007 1.0180 1.0020 603.09 0.919 0.390 30-Mar-0813:15 64 39.31 102.56 57.42 1.50 0.596 63.495 455.03 1.0000 1.0000 1.2950 1.0025 1.0007 1.0175 1.0020 602.92 0.919 0.399 30-Mar-0813:30 64 39.56 102.47 56.92 1.50 0.596 63.669 455.03 1.0000 1.0000 1.2950 1.0030 1.0007 1.0174 1.0020 603.15 0.922 0:409 30-Mar-0813:45 64 40.12 101.83 57.35 1.50 0.596 63.917 455.03 1.0000 1.0000 1.2950 1.0026 1.0007 1.0170 1.0020 602.71 0.925 0.419 30-Mar-0814:00 64 40.34 101.61 57.13 1.50 0.596 64.023 455.03 1.0000 1.0000 1.2950 1.0028 1.0007 1.0169 1.0020 602.77 0.926 0.428 30-Mar-0814:15 64 40.12 103.57 57.53 1.50 0.596 64.461 455.03 1.0000 1.0000 1.2950 1.0024 1.0007 1.0173 1.0020 602.77 0.933 0.438 30-Mar-0814:30 64 39.95 103.48 57.73 1.50 0.596 64.296 455.03 1.0000 1.0000 1.2950 1.0022 1.0007 1.0174 1.0020 602.69 0.930 0.448 30-Mar-0814:45 64 40.30 102.73 57.91 1.50 0.596 64.343 455.03 1.0000 1.0000 1.2950 1.0020 1.0007 1.0171 1.0020 602.43 0.930 0.457 30-Mar-0815:00 64 40.52 102.99 56.99 1.50 0.596 64.600 455.03 1.0000 1.0000 1.2950 1.0029 1.0007 1.0171 1.0020 602.95 0.935 0.467 30-Mar-0815:15 64 39.90 106.36 57.63 1.50 0.596 65.144 455.03 1.0000 1.0000 1.2950 1.0023 1.0007 1.0179 1.0020 603.04 0.943 0.477 30-Mar-0815:30 64 40.00 104.83 57.74 1.50 0.596 64.755 455.03 1.0000 1.0000 1.2950 1.0022 1.0007 1.0176 1.0020 602.80 0.937 0.487 30-Mar-0815:45 64 39.77 102.92 57.08 1.50 0.596 63.978 455.03 1.0000 1.0000 1.2950 1.0028 1.0007 1.0174 1.0020 603.06 0.926 0.496 30-Mar-0816:00 64 39.75 102.91 55.91 1.50 0.596 63.958 455.03 1.0000 1.0000 1.2950 1.0040 1.0007 1.0174 1.0020 603.75 0.927 0.506 30-Mar-0816:15 64 38.71 105.88 55.75 1.50 0.595 64.020 455.03 1.0000 1.0000 1.2960 1.0041 1.0007 1.0184 1.0020 604.89 0.929 0.516 30-Mar-0816:30 64 38.81 101.34 55.90 1.50 0.595 62.714 455.03 1.0000 1.0000 1.2960 1.0040 1.0008 1.0175 1.0020 604.31 0.910 0.52 30-Mar-0816:45 64 38.44 104.09 54.96 1.50 0.595 63.255 455.03 1.0000 1.0000 1.2960 1.0049 1.0007 1.0182 1.0020 605.24 0.919 0.53 30-Mar-0817:00 64 37.12 106.58 55.75 1.50 0.595 62.899 455.03 1.0000 1.0000 1.2960 1.0041 1.0008 1.0193 1.0020 605.37 0.914 0.544 30-Mar-0817:15 64 37.24 103.33 55.94 1.50 0.595 62.032 455.03 1.0000 1.0000 1.2960 1.0039 1.0008 1.0186 1.0020 604.88 0.901 0.554 30-Mar-0817:30 64 37.63 99.51 56.78 1.50 0.595 61.193 455.03 1.0000 1.0000 1.2960 1.0031 1.0008 1.0178 1.0020 603.88 0.887 0.563 30-Mar-0817:45 64 38.35 98.23 56.38 1.50 0.595 61.377 455.03 1.0000 1.0000 1.2960 1.0035 1.0008 1.0172 1.0020 603.82 0.889 0.572 30-Mar-0818:00 64 38.43 96.29 56.15 1.50 0.595 60.831 455.03 1.0000 1.0000 1.2960 1.0037 1.0008 1.0168 1.0020 603.74 0.881 0.581 30-Mar-0818:15 64 38.52 96.53 55.69 1.50 0.595 60.978 455.03 1.0000 1.0000 1.2960 1.0042 1.0008 1.0168 1.0020 604.02 0.884 0.591 30-Mar-OS 18:30 64 38.16 101.09 54.81 1.50 0.595 62.110 455.03 1.0000 1.0000 1.2960 1.0050 1.0008 1.0178 1.0020 605.09 0.902 0.600 30-Mar-0818:45 64 36.20 105.87 54.96 1.50 0.595 61.907 455.03 1.0000 1.0000 1.2960 1.0049 1.0008 1.0197 1.0020 606.02 0.900 0.609 30-Mar-OS 19:00 64 35.25 107.79 54.46 1.50 0.595 61.641 455.03 1.0000 1.0000 1.2960 1.0054 1.0008 1.0206 1.0020 606.82 0.898 0.619 30-Mar-0819:15 64 34.68 108.81 53.98 1.50 0.595 61.429 455.03 1.0000 1.0000 1.2960 1.0058 1.0008 1.0211 1.0020 607.40 0.895 0.628 30-Mar-0819:30 64 34.19 110.22 53.94 1.50 0.595 61.387 455.03 1.0000 1.0000 1.2960 1.0059 1.0008 1.0217 1.0020 607.75 0.895 0.637 30-Mar-0819:45 64 32.95 109.21 53.55 1.50 0.595 59.987 455.03 1.0000 1.0000 1.2960 1.0063 1.0008 1.0223 1.0020 608.31 0.876 0.646 30-Mar-08 20:00 64 32.72 115.15 53.64 1.50 0.595 61.382 455.03 1.0000 1.0000 1.2960 1.0062 1.0008 1.0237 1.0020 609.07 0.897 0.656 30-Mar-08 20:15 64 33.93 114.91 58.69 1.50 0.595 62.441 455.03 1.0000 1.0000 1.2860 1.0013 1.0008 1.0228 1.0020 605.58 0.907 0.665 Expro Well Testing 2 of 3 5/1/2008 GAS FLOW REPORT CUSTOMER :Anadarko O EXPRO WELL DArE : 30 Ma~08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~d ~ -'~ t l m Corporat SEPARATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) ~ (psia) DIFF. PRESS (inches H2O) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 30-Mar-08 20:30 64 33.38 109.87 56.71 1.50 0.595 60.560 455.03 1.0000 1.0000 1.2960 1.0032 1.0008 1.0222 1.0020 606.35 0.881 0.674 30-Mar-0B 20:45 64 33.65 107.20 55.52 1.50 0.595 60.061 455.03 1.0000 1.0000 1.2960 1.0043 1.0008 1.0215 1.0020 606.64 0.874 0.684 30-Mar-0B 21:00 64 33.83 104.03 55.28 1.50 0.595 59.324 455.03 1.0000 1.0000 1.2960 1.0046 1.0008 1.0207 1.0020 606.35 0.863 0.693 30-Mar-OS 21:15 64 34.93 105.07 54.74 1.50 0.595 60.581 455.03 1.0000 1.0000 1.2960 1.0051 1.0008 1.0202 1.0020 606.44 0.882 0.702 30-Mar-08 21:30 64 36.82 110.40 56.82 1.50 0.595 63.757 455.03 1.0000 1.0000 1.2960 1.0031 1.0008 1.0202 1.0020 605.23 0.926 0.711 Expro Well Testing 3 of 3 5/1/2008 PRODUCTION TANK DATA SHEET EXPRO Customer: Anadarko Well: Gubik #3 Start Date: 29-Mar-08 End Date: 30-Mar-08 Flow Period: Flow #1 -Clean-up Total Fluid Production: 96.42 bbls Total Oil Production: 86.30 bbls Total Water Production: 10.12 bbls Petroleum Corporation Start End Tank Previous Strap Curren t Strap Fluid Inc. BS 8~W H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date 8~ Time Date 8 Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 29-Mar-08 03:00 29-Mar-08 03:10 1 1.00 5.25 1.00 5.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 29-Mar-08 03:10 29-Mar-08 06:00 1 1.00 5.25 1.00 5.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 29-Mar-08 10:55 29-Mar-OS 11:30 1 1.00 5.25 1.00 6.00 1.25 0.00% 0.00% 0.00 0.00 0.00 1.25 1.25 51.44 29-Mar-08 11:30 29-Mar-08 11:50 1 1.00 6.00 1.00 6.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 1.25 0.00 29-Mar-08 11:50 29-Mar-08 12:00 1 1.00 6.00 1.00 6.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 1.25 0.00 29-Mar-08 12:00 29-Mar-08 12:30 1 1.00 6.00 1.00 6.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 1.25 0.00 29-Mar-08 12:30 29-Mar-08 13:00 1 1.00 6.00 1.00 6.50 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 2.08 40.01 29-Mar-08 13:00 29-Mar-08 13:30 1 1.00 6.50 1.00 7.00 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 2.92 40.01 29-Mar-O8 13:30 29-Mar-08 14:00 1 1.00 7.00 1.00 7.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 2.92 0.00 29-Mar-08 14:00 29-Mar-08 14:30 1 1.00 7.00 1.00 7.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 2.92 0.00 29-Mar-08 14:30 29-Mar-08 15:00 1 1.00 7.00 1.00 7.25 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 3.33 20.00 29-Mar-08 15:00 29-Mar-08 15:30 1 1.00 7.25 1.00 7.50 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 3.75 20.00 29-Mar-08 15:30 29-Mar-08 16:00 1 1.00 7.50 1.00 7.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 3.75 0.00 29-Mar-08 16:00 29-Mar-08 16:30 1 1.00 7.50 1.00 7.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 3.75 0.00 29-Mar-08 16:30 29-Mar-08 22:00 1 1.00 7.50 1.00 7.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 3.75 0.00 29-Mar-08 22:00 29-Mar-08 22:30 1 1.00 7.50 1.00 7.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 3.75 0.00 29-Mar-08 22:30 29-Mar-08 23:00 1 1.00 7.50 1.00 8.00 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 4.58 40.01 29-Mar-08 23:00 29-Mar-08 23:30 1 1.00 8.00 1.00 8.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 4.58 0.00 29-Mar-08 23:30 30-Mar-08 00:00 1 1.00 8.00 1.00 8.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 4.58 0.00 30-Mar-08 00:00 30-Mar-08 00:30 1 1.00 8.00 1.00 8.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 4.58 0.00 30-Mar-08 00:30 30-Mar-08 01:00 1 1.00 8.00 1.00 8.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 4.58 0.00 30-Mar-08 01:00 30-Mar-08 01:30 1 1.00 8.00 2.00 1.00 8.34 0.00% 0.00% 0.00 0.00 0.00 8.34 12.92 400.08 30-Mar-08 01:30 30-Mar-08 02:00 1 2.00 1.00 2.00 2.00 1.67 0.00% 0.00% 0.00 0.00 0.00 1.67 14.59 80.02 30-Mar-08 02:00 30-Mar-08 02:10 1 2.00 2.00 2.00 4.00 3.33 0.00% 0.00% 0.00 0.00 0.00 3.33 17.92 480.1 30-Mar-08 02:10 30-Mar-08 02:20 1 2.00 4.00 2.00 5.00 1.67 0.00% 0.00% 0.00 0.00 0.00 1.67 19.59 240.05 30-Mar-08 02:20 30-Mar-08 02:30 1 2.00 5.00 3.00 4.00 18.34 0.00% 0.00% 0.00 0.00 0.00 18.34 37.92 2640.53 30-Mar-08 02:30 30-Mar-O8 03:00 2 0.00 1.50 1.00 2.50 14.01 0.00% 0.00% 0.00 0.00 0.00 14.01 51.93 672.48 30-Mar-08 03:00 30-Mar-08 03:30 1 3.00 4.00 4.00 3.75 19.59 0.00% 0.00% 0.00 0.00 0.00 19.59 71.52 940.19 30-Mar-08 03:30 30-Mar-08 04:00 2 1.00 2.50 1.00 9.50 11.64 0.00% 0.00% 0.00 0.00 0.00 11.64 83.16 558.55 30-Mar-08 04:00 30-Mar-08 04:30 1 4.00 3.75 4.00 4.00 0.42 0.00% 8.00% 0.03 0.03 1.60 0.38 83.54 18.40 30-Mar-08 04:30 30-Mar-08 05:00 2 1.00 9.50 1.00 9.50 0.00 0.00% 0.75% 0.00 0.03 0.00 0.00 83.54 0.00 30-Mar-08 05:00 30-Mar-08 05:30 1 4.00 4.00 4.00 4.25 0.42 0.00% 0.00% 0.00 0.03 0.00 0.42 83.96 20.00 30-Mar-08 05:30 30-Mar-08 06:00 2 1.00 9.50 1.00 9.50 0.00 0.00% 0.00% 0.00 0.03 0.00 0.00 83.96 0.00 30-Mar-O8 06:00 30-Mar-08 06:30 1 4.00 4.25 4.00 4.25 0.00 0.00% 0.00% 0.00 0.03 0.00 0.00 83.96 0.00 30-Mar-08 06:30 30-Mar-08 07:00 2 1.00 9.50 1.00 9.75 0.42 0.00% 0.00% 0.00 0.03 0.00 0.42 84.37 20.00 30-Mar-08 07:00 30-Mar-08 07:30 1 1.00 4.25 1.00 4.25 0.00 0.00% 0.00% 0.00 0.03 0.00 0.00 84.37 0.00 30-Mar-08 07:30 30-Mar-08 08:00 2 1.00 9.50 1.00 10.00 0.83 0.80% 12.00% 0.10 0.13 4.80 0.73 85.10 34.89 Expro Well Testing 1 of 2 5/1/2008 PRODUCTION TANK DATA SHEET EXPRO Customer: Anadarko Well: Gubik #3 Start Date: 29-Mar-08 End Date: 30-Mar-08 Flow Period: Flow #1 -Clean-up Total Fluid Production: 96.42 bbls Total Oil Production: 86.30 bbls Total Water Production: 10.12 bbls ~,a,~a,,l~ ~ Petroleum Corporation Start End Tank Previous Strap Current Strap Fluid Inc. BS &W H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date & Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 30-Mar-08 08:00 30-Mar-08 08:30 1 4.00 4.25 4.00 4.75 0.83 0.80% 12.00% 0.10 0.23 4.80 0.73 85.$3 34.89 30-Mar-08 08:30 30-Mar-08 09:00 2 1.00 10.00 1.00 10.25 0.42 0.20% 70.00% 0.29 0.53 14.00 0.12 85.95 5.96 30-Mar-08 09:00 30-Mar-08 09:30 1 4.00 4.75 4.00 5.00 0.42 0.20% 70.00% 0.29 0.82 14.00 0.12 86.08 5.96 30-Mar-08 09:30 30-Mar-08 10:00 2 1.00 10.25 1.00 10.50 0.42 0.00% 90.00% 0.38 1.19 18.00 0.04 86.12 2.00 30-Mar-08 10:00 30-Mar-08 10:30 1 4.00 5.00 4.00 5.25 0.42 0.00% 90.00% 0.38 1.57 18.00 0.04 86.16 2.00 30-Mar-08 10:30 30-Mar-08 11:00 2 1.00 10.50 1.00 10.75 0.42 0.00% 94.00% 0.39 1.96 18.80 0.03 86.19 1.20 30-Mar-08 11:00 30-Mar-08 11:30 1 1.00 5.25 1.00 5.50 0.42 0.00% 94.00% 0.39 2.35 18.80 0.03 86.21 1.20 30-Mar-08 11:30 30-Mar-08 12:00 2 1.00 10.75 1.00 11.00 0.42 0.00% 94.00% 0.39 2.74 18.80 0.03 86.24 1.20 30-Mar-08 12:00 30-Mar-08 12:30 1 4.00 5.50 4.00 5.75 0.42 1.00% 96.00% 0.40 3.14 19.20 0.01 86.25 0.60 30-Mar-08 12:30 30-Mar-08 13:00 2 1.00 11.00 1.00 11.00 0.00 0.00% 94.00% 0.00 3.14 0.00 0.00 86.25 0.00 30-Mar-08 13:00 30-Mar-08 13:30 1 4.00 5.75 4.00 5.75 0.00 0.00% 94.00% 0.00 3.14 0.00 0.00 86.25 0.00 30-Mar-08 13:30 30-Mar-08 14:00 2 1.00 11.00 1.00 11.25 0.42 0.00% 96.00% 0.40 3.54 19.20 0.02 86.26 0.80 30-Mar-08 14:00 30-Mar-08 14:30 1 4.00 5.75 4.00 6.00 0.42 0.00% 96.00% 0.40 3.94 19.20 0.02 86.28 0.80 30-Mar-08 14:30 30-Mar-08 15:00 2 1.00 11.25 1.00 11.50 0.42 0.00% 95.00% 0.40 4.34 19.00 0.02 86.30 1.00 30-Mar-08 15:00 30-Mar-08 15:30 1 4.00 6.00 4.00 6.00 0.00 0.00% 95.00% 0.00 4.34 0.00 0.00 86.30 0.00 30-Mar-08 15:30 30-Mar-08 16:00 2 1.00 11.50 1.00 11.50 0.00 3.00% 97.00% 0.00 4.34 0.00 0.00 86.30 0.00 30-Mar-08 16:00 30-Mar-08 16:30 1 4.00 6.00 4.00 6.00 0.00 3.00% 97.00% 0.00 4.34 0.00 0.00 86.30 0.00 30-Mar-08 16:30 30-Mar-08 17:00 2 1.00 11.50 2.00 0.00 0.83 1.60% 98.40% 0.82 5.16 39.37 0.00 86.30 0.00 30-Mar-O8 17:00 30-Mar-08 17:30 1 4.00 6.00 4.00 6.25 0.42 1.60% 98.40% 0.41 5.57 19.68 0.00 86.30 0.00 30-Mar-08 17:30 30-Mar-08 18:00 2 2.00 0.00 2.00 0.00 0.00 1.60% 98.40% 0.00 5.57 0.00 0.00 86.30 0.00 30-Mar-08 18:00 30-Mar-08 18:30 1 4.00 6.25 4.00 6.25 0.00 1.60% 98.40% 0.00 5.57 0.00 0.00 86.30 0.00 30-Mar-08 18:30 30-Mar-08 19:00 2 2.00 0.00 2.00 0.00 0.00 1.50% 98.50% 0.00 5.57 0.00 0.00 86.30 0.00 30-Mar-08 19:00 30-Mar-08 19:30 1 4.00 6.25 4.00 6.50 0.42 1.00% 99.00% 0.41 5.98 19.80 0.00 86.30 0.00 30-Mar-08 19:30 30-Mar-08 20:00 2 2.00 0.00 2.00 1.00 1.67 1.00% 99.00% 1.65 7.63 79.22 0.00 86.30 0.00 30-Mar-08 20:00 30-Mar-08 20:30 1 4.00 6.50 4.00 7.00 0.83 1.00% 99.00% 0.83 8.46 39.61 0.00 86.30 0.00 30-Mar-08 20:30 30-Mar-08 21:00 2 2.00 1.00 2.00 2.00 1.67 0.00% 100.00% 1.67 10.12 80.02 0.00 86.30 0.00 30-Mar-08 21:00 30-Mar-08 21:30 1 4.00 7.00 4.00 7.00 0.00 0.00% 100.00% 0.00 10.12 0.00 0.00 86.30 0.00 Expro Well Testing 2 of 2 5/1/2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 DATE : 28-Mar-08 r~ U TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 28-Mar-08 10:52 Started air test of flow line from wellhead to separator. 11:07 Found leak and fixed. 14:28 Bled down air from flowline -good air test. 15:58 Shut down power to DAS system -moving generator to clean mud from pad. 17:30 Shift handover with day crew. 18:00 Wrapped flowline with blankets. 18:30 Continued to prepare for pressure testing. 20:00 Conducted Safety meeting prior to pressure testing flowline and separator (Expro and Little Red). 20:20 Expro choke opened both ways and separator on bypass. 21:00 Little Red started pumping hot diesel to fill lines. 21:05 Lower and upper master valves closed; swab valve and wing valve opened. 21:10 Little Red pumped at 0.5 bbl/min. 21:17 Returns at Tank #1; switched to Tank #2. 21:18 Returns at Tank #2; switched to Tank #3. 21:19 Returns at Tank #3; switched to Tank #4. 21:20 Returns at Tank #4; shut in tank farm manifold. 21:21 Lined up to pump through heater. 21:22 Little Red continued to pump hot diesel; 6 bbl pumped. 21:30 Little Red continued to pressure up to 100 psi. 21:33 Little Red pressured up to 250 psi. 21:40 Little Red pressured up to 500 psi. 21:42 Little Red pressured up to 1000 psi. 21:43 Bled pressure to 0 psi; leak in flowline. 21:46 Little Red pressured up to 250 psi. 21:50 Bled pressure to 0 psi; leak in flowline. 22:00 Little Red pressured up to 100 psi. 22:02 Little Red pressured up to 250 psi. 22:05 Little Red pressured up to 1000 psi. 22:10 Good pressure test on flowline. 22:11 Applied nitrogen to separator. 22:15 Lined up to pressure test separator. 22:16 Little Red started pumping to fill separator. 22:37 Little Red pumped 20 bbls. 22:54 Fluid at Daniels meter and fluid at high point of line. 23:00 Little Red pressured up to 100 psi. 23:02 Little Red pressured up to 250 psi. 23:04 Little Red pressured up to 500 psi. 23:06 Little Red pressured up to 1000 psi. 23:10 Good pressure test on separator. 23:15 Line heater shut in. 23:18 Bled separator to 0 psi. 23:20 Lined up to pressure test flowline to 5000 psi. 23:22 Little Red pressured up to 2500 psi. 23:25 Bled pressure to 0 psi; leak in flowline. 23:32 Little Red pressured up to 1000 psi. 23:33 Little Red pressured up to 2500 psi. 23:35 Little Red pressured up to 5000 psi. 23:37 Good pressure test on flowline. Expro Well Testing 1 of 7 5/1/2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 DATE : 28-Mar-08 C~ TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 28-Mar-08 23:42 Dumped fluid from separator to Tank #1. 23:50 Pressure tested Methanol injection lines. 29-Mar-08 0:00 Installed 3:0" orifice plate (out of service). 0:30 Continued to pressure test Methanol lines. 1:00 Leaks in Methanol hoses; trouble shooting problems. 2:00 Good test on Methanol lines to 3500 psi. 2:30 Conducted Safety meeting prior to pressuring up to 5000 psi to fire TCP guns. 3:10 Initial tank straps; Tank #1= 1' 5 1/4", Tank #2= 1 1/2", Tank #3= 0, Tank #4= 5 1/2". Initial Methanol readings; AC 10029= 2' 11 "=267.8 gal, AC 10053= 3' 1 "=283.1 gal. 3:12 Little Red started pressuring up to 5000 psi. 3:17 Opened choke; bled pressure to 0 psi. 3:18 Closed choke. 3:19 Monitor WHP for 5 to 10 minutes for TCP firing indication. 3:22 Indication that guns fired; 200 psi on wellhead; instantly dropped to 0 psi. 3:27 Started pumping Methanol. 3:29 Started opening choke manifold 48/64ths adjustable. 3:33 Little Red rigged down. 3:35 WHP= 0 psi. 3:42 Monitored WHP. 3:45 Stopped Methanol injection; AC 10029= 2' 10 1/2"= 264.0 gal, AC 10053= 3'1"=283.1 gal Methanol injected was 3.8 gal. 3:46 Continued to monitor pressure. 4:44 Closed choke; monitored pressure. 5:30 Completed hand over with night crew. 10:55 Opened well at wellhead to commence swabbing well. 10:55 Choke manifold opened on a 64/64ths adjustable to Tank #1. 11:17 Slickline at 200 ft. 11:30 Tk #1 = 1' 6" 11:50 Tk #1 = 1' 6" 12:00 Tk #1 = 1' 6" 12:30 Tk #1 = 1' 6" 13:00 Tk #1 = 1' 6.5" 13:00 BS&W = 100% diesel 13:30 Tk #1 = 1' 7" 14:00 Tk #1 = 1' 7" 14:30 Tk #1 = 1' 7" 15:00 Tk #1 = 1' 7.25" 15:30 Tk #1 = 1' 7.5" 15:47 Shut-in at choke manifold. SSV shut-in due to air compressor shutting down. 15:50 SSV opened and choke opened on a 64/64ths. Slickline commenced swabbing. 16:00 Slickline commenced swabbing at 200 ft -seeing fluid (diesel) at surface. 16:00 Tk #1 = 1' 7.5" 16:30 Tk #1 = 1' 7.5" 16:21 Slickline out of hole. Commenced changing out line to heavier grade for swabbing operations. 16:30 Decision made to leave well open at the choke to monitor for fluid and pressure. 18:00 Shift handover with day crew. 18:00 Monitored tank #1 every 30 minutes for volumes changes. Expro Well Testing 2 of 7 5/1/2008 ~~ Job Log CUSTOMER :Anadarko EXPRO WELL NAME : Gubik #3 DATE : 28-Mar-08 a TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 29-Mar-08 18:15 Installed pressure sensor on compressor air line (low level set at iu psis. 18:30 Cleaned up around well test area and pad. 20:00 Wrapped tank farm manifold with plastic. 20:30 Standby for swabbing operations. 22:00 Tk #1 = 1' 7.50" 22:50 Diesel at choke and separator inlet. 23:00 Tk #1= 1' 8.00' ; 0.50 bbl increase. 23:10 Fuel truck filled equipment. 23:12 BS&W = 100% diesel. 23:25 BS&W = 100% diesel. 23:30 Tk #1= 1' 8.00' ; 0.00 bbl increase. 30-Mar-08 0:00 Tk #1= 1' 8.00' ; 0.00 bbl increase. HAL Slickline started to rig up a-line to swab well. 0:30 Tk #1= 1' 8.00' ; 0.00 bbl increase. 1:00 Tk #1= 1' 8.00' ; 0.00 bbl increase. 1:20 HAL Slickline started to RIH; swabbing at 400 ft and tagged at 495 ft. 1:30 TK #1= 2' 1.00' ; 8.34 bbl increase. BS&W= 100% Diesel. 2:00 Tk #1= 2' 2.00' ; 1.67 bbl increase. 2:10 BS&W=Trace solids Tk #1= 2' 4.00' ; 3.33 bbl increase. 2:20 TK #1= 2' 5.00"; 1.67 bbl increase. 2:30 Gas SG = 1.000 2:35 Switched from Tk #1 to Tk #2 (Initial strap= 1.500"). 2:36 Started Methanol injection both downhole and at the choke manifold. 2:37 Choke size = 36/64ths adjustable. 2:38 Well flow diverted through the separator. 2:44 Gas to surface -flare started. 2:50 3-inch orifice plate in service on the separator. 2:50 H2S = 0 ppm. 3:00 3-inch orifice plate out of service on the separator. Increased choke to a 40/64ths adjustable. 3:01 3-inch orifice plate in service on the separator. 3:15 Tk #2= 1' 2.50' ; 3:15 COZ = 0.15%; Gas Gravity = 0.592 3:20 BS&W =Trace. 3:30 Switched from Tk #2 to Tk #1. 3:39 Stopped methanol injection at the choke manifold; downhole injection continued. 3:45 BS&W = 8% water and 0.25% emulsion. 3:45 Hydrocarbons to surface. 4:00 Increased choke to a 48/64ths adjustable. Switched from Tk #2 to Tk #1. Tk #2 = 1' 9.50' ; 4:30 Switched from Tk #1 to Tk #2. 4:40 Tk#1 =4'4" 4:44 3-inch orifice plate out of service on the separator. 4:47 1.5-inch orifice plate in service on the separator. Expro Well Test ing 3 of 7 5/1 /2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 DATE : 28-Mar-08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 30-Mar-08 5:00 Oil API = 44.3 @ 80.24 F = 42.6 @ 60 F Switched from Tk #2 to Tk #1. Tank #2 = 1' 9.50" 5:30 Switched from Tk #1 to Tk #2. Tk#1 =4'4.25" COZ = 0.65%; H2S = 0 ppm Methanol Totes: AC 10029 = 30" = 229.5 gal; AC 10053 = 35" = 267.8 gal Total Methanol Injected since 02:36 = 49.73 gallons 5:44 By-passed heater to drop gas temperature down to prevent carry over to the gas flare. 6:00 Switched from Tk #1 to Tk #2. Tk #2 = 1' 9.50" 6:30 Switched from Tk #1 to Tk #2. Tk#1 =4'4.25" 6:53 Flow diverted through the heater. 7:00 Switched from Tk #2 to Tk #1. Tk #2 = 1' 9.75 7:17 By-passed heater to drop gas temperature down to prevent carry over to the gas flare. 7:30 Switched from Tk #1 to Tk #2. Tk#1 =4'4.25" BS&W = 12% water; 0.8% solids OiIAPl=44.5@76.82F=43.1 @60F 8:00 Switched from Tk #2 to Tk #1. Tk #2 = 1' 10" Gas Gravity = 0.596 8:26 Methanol Totes: AC 10029 = 27" = 206.6 gal; AC 10053 = 35" = 267.8 gal Total Methanol Injected since 02:36 = 95.63 gallons 8:30 Switched from Tk #1 to Tk #2. Tk #1 = 4' 4.75" 9:00 Switched from Tk #2 to Tk #1. Tk #2 = BS&W = 70% water, 0.2% solids Water Density = 0.954 g/cc @ 15.4 C Water pH = 7 9:01 Commenced to increase choke to a 64/64ths adjustable. 9:06 Choke size = 64/64ths adjustable. 9:15 Methanol Totes: AC 10029 = 24" = 183.6 gal Total Methanol Injected since 02:36 = 118.58 gallons 9:30 Switched from Tk #1 to Tk #2. Tk#1 =4'5" 10:00 Switched Tk #2 to Tk #1. Tk#2=1'10.5" BS&W = 90% water Water Density = 0.967 g/cc @ 13.9 C 10:30 Switched from Tk #1 to Tk #2. Tk #1 = 4' 5.25" BW&W = 90% water Expro Well Testing 4 of 7 5/1/2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 DATE : 28-Mar-08 TEST No. :Flow #1 -Clean-up CUSTOMER REP. :Dennis MacDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 30-Mar-08 11:00 Switched from Tk #2 to Tk #1. Tk #2 = 1' 10.75" BS&W = 94% water Water Density = 0.957 @ 17.2 C pH=7 Salinity = 65,000 11:15 McOH Tank #1 (AC 10029) = 20" = 153.0 gal. Total McOH injected since 02:36 = 126.23 gallons 11:30 Switched from Tk #1 to Tk #2. Tk #1 = BS&W = 94% water 11:55 DAS logger offline. 11:58 DAS logger online. 12:00 DAS logger offline. Switched from Tk #2 to Tk #1. Tk#2=1'11" BS&W = 94% water Gas Gravity = 0.596 COZ = 0.8%; HZS = 0 ppm pH=7 Salinity = 70,000 Water density = 0.951 g/cc @ 16 C 12:24 DAS logger online. 12:30 Switched from Tk #1 to Tk #2. Tk #1 BS&W = 96% water, 1 % sediment 13:00 Switched from Tk #2 to Tk #1. BS&W = 94% water Tk#2=1'11" 13:30 Switched from Tk #1 to Tk #2. Tk #1 = 4' 5.75" BS&W = 94% water 14:00 Switched from Tk #2 to Tk #1. Tk #2 = 1' 11.25" BS&W = 96% water 14:30 Switched from Tk #1 to Tk #2. Tk#1 =4'6" BS&W = 96% water McOH Tank #1 (AC 10029) = 13" = 99.50 gal. Total McOH injected since 02:36 = 179.78 gallons 15:00 Switched from Tk #2 to Tk #1. Tk#2=1'11.5" BS&W = 95% water 15:30 Switched from Tk #1 to Tk #2. Tk #1 = BS&W = 95% water McOH Tank #1 (AC 10029) = 12" = 91.8 gal. Only pumping from one pump. Total McOH injected since 02:36 = 187.43 gallons Expro Well Testi ng 5 of 7 5/1 /2008 Job Log EXPRO CUSTOMER WELL NAME DATE Anadarko TEST No. :Flow #1 -Clean-up Gubik #3 CUSTOMER REP. :Dennis MacDaniel 28-Mar-08 EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 30-Mar-08 16:00 Switched from Tk #2 to Tk #1. Tk #2 = 1' 11.5" BS&W = 97% water, 2% emulsion, 1 % sediment COZ = 0.65%; H2S = 0 ppm Gas Gravity = 0.595 Salinity = 65,000 ppm Water density = 0.967 g/cc @ 19.9 C 16:30 Switched from Tk #1 to Tk #2. Tk#1 =4'6" BS&W = 97% water, 2% emulsion, 1 % sediment McOH Tank #1 (AC 10029) = 11.5" = 87.98 gal. Total McOH injected since 02:36 = 191.25 gallons 17:00 Switched from Tk #2 to Tk #1. Tk#2=2' Checked McOH density = 0.803 g/cc @ 14.4 C Checked McOH pump rate = 220 ml/min = 0.058 gal/min McOH Tank #1 (AC 10029) = 10" = 76.5 gal. Total McOH injected since 02:36 = 202.73 gallons BS&W = 98.4% water, 0.2% sediment, 1.4% emulsion Water density = 0.968 g/cc @ 15.6 C 17:30 Switched from Tk #1 to Tk #2. Tk #1 = 4' 6.25" BS&W = 98.4% water, 0.2% sediment, 1.4% emulsion 18:00 Switched from Tk #2 to Tk #1. BS&W = 98.4% water, 0.2% sediment, 1.4% emulsion Tk#2=2'0" 18:05 Collected fluid sample for Anadarko. 18:30 Switched from Tk #1 to Tk #2. McOH Tank #1 (AC 10029) = 8.5" = 65.03 gal. Total McOH injected since 02:36 = 214.20 gallons Water density = 0.972 g/cc @ 14.9 C BS&W = 98.4% water, 0.2% sediment, 1.4% emulsion 19:00 Switched from Tk #2 to Tk #1. BS&W = 98.4% water, 1.4% emulsion Tk#2=2'0" 19:30 Switched from Tk #1 to Tk #2. McOH Tank #1 (AC 10029) = 7.5" = 57.38 gal. Total McOH injected since 02:36 = 221.85 gallons BS&W = 99% water, 1.0% emulsion/sediment. Gas Gravity = 0.595 COZ = 0.70%; H2S = 0 ppm Tk#1=4'6.50" HAL Slickline RIH. 20:00 Switched from Tk #2 to Tk #1. BS&W = 99% water, 1.0% emulsion/sediment. Tk #2= 2' 1" 20:10 HAL Slickline POOH; gauges did not lock. 20:30 Switched from Tk #1 to Tk #2. Expro Well Testing 6 of 7 5/1/2008 Job Log CUSTOMER :Anadarko TEST No. :Flow #1 -Clean-up EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis MacDaniel DATE : 28-Mar-08 EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 30-Mar-08 20:30 McOH Tank #1 (AC 10029) = 6.5" = 49.73 gal. Total McOH injected since 02:36 = 229.50 gallons 21:00 Switched Tk #2 to Tk #1. Tk#2=2'2" Gas Gravity = 0.590 BS&W = 100% water 21:15 Switched log data to 1 sec intervals. 21:30 Switched from Tk #1 to Tk #2. Shut in well; choke manifold double blocked. Methanol injection stopped. SSV capped. McOH Tank #1 (AC 10029) = 5.5" = 42.08 gal. Total McOH injected since 02:36 = 237 gallons Tk#1=4'7.0" Methanol left on location = 1174 gal Monitored wellhead pressure for build-up. 21:35 Evacuated flowline downstream of choke to tank farm. 23:00 Wrapped flowline with plastic and connected Tioga heater. 31-Mar-08 0:00 Replaced custom oil leg spool. 2:30 Installed new check valves on Methanol pump. 4:00 Checked flare line; no residual fluid. 4:30 Final Tank straps on TK #1 & #2; Tk #1= 4' 7.25" = 82.30 bbls Tk #2 = 2' 7.25"= 42.29 bbls 6:00 Shit hand with night crew. Continued to monitor surface pressure for build-up period.. Expro Well Testing 7 of 7 5/1/2008 EXPRO 70 Wellhead Plot Wellhead Plot Anadarko Gubik #3 Petroleum Corporation 60 50 .-. N ~ .-. 40 ~ ~ ~V d ~ N = ~~ m o °~ 30 t U 20 10 0 350 300 250 200 ~ a . y ~ U ~. ... o!S 150 = 100 50 0 0:00 1:15 2:30 3:45 5:00 6:15 7:30 8:45 10:00 11:15 12:30 13:45 15:00 16:15 17:30 18:45 20:00 21:15 30-Mar-08 Date & Time 31-Mar-08 ~W HT -~ Choke Size --~- W HP t CSG~ Expro Well Testing Page 1 5/1/2008 EXPRO 70 Separator Plot Separator Plot Anadarko Gubik #3 Petroleum Corporation 60 50 d L N 40 m a` a~ o a ~+ v R L a 30 m 20 10 0 140 120 100 m L ~+ 80 ~ a I~ o L _~ ~.+ 60 L ca a m rn 40 20 0 0:00 1:15 2:30 3:45 5:00 6:15 7:30 8:45 10:00 11:15 12:30 13:45 15:00 16:15 17:30 18:45 20:00 21:15 30-Mar-08 Date & Time 31-Mar-08 Pressure -Temperature Expro Well Testing Page 1 5/1/2008 EXPRO 3000 2500 2000 m r N~ I.L 3 0 1500 O 1000 500 0 Production Plot Wellhead Plot Anadarko Gubik #3 Petroleum Corporation ^ -- ^ - - -- - -- ^ ^ • • 1.60 1.40 1.20 • 1.00 r ~ 0.80 N ~ ~ ~. 0.60 0.40 0.20 0.00 i i 0:00 1:15 2:30 3:45 5:00 6:15 7:30 8:45 10:00 11:15 12:30 13:45 15:00 16:15 17:30 18:45 20:00 21:15 30-Mar-08 Date & Time 31-Mar-08 ^ Oil Rate -~ Water Rate ~ Gas Rate II Expro Well Testing Page 1 5/1/2008 ~, i WELL TEST REPORT CUSTOMER :Anadarko O EXPRO START DAME : 2 Aprk-08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park I~m CorPO tl CHOKE EPARATOR FLOW RATES McOH CUMU LATNE McOH FLUI D PROPER TIES DATE 8~ TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMscf FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BS&W % C02 % HZS m SALINITY m 02-A r-08 03:00 0 1 42 172 14 74 0.000 0.00 0.000 0.00 02-A r-08 03:15 0 1 44 171 13 73 0.000 0.000 02-A r-08 03:30 0 0 44 171 13 71 0.000 0.00 10.93 0.000 0.00 0.00 02-A r-08 03:45 36 969 40 172 31 49 0.000 0.000 02-A r-08 04:00 48 371 36 172 81 75 2.499 0.00 0.026 0.00 0.599 0.60 0 02-A r-08 04:15 64 84 36 159 58 54 2.756 0.055 02-A r-08 04:30 64 66 36 168 42 55 1.601 0.00 10.93 0.071 0.00 0.46 02-A r-08 04:45 64 48 37 162 37 55 1.531 0.087 02-A r-08 05:00 64 54 38 161 36 54 1.427 0.00 0.102 0.00 0.599 0.75 0 02-A r-08 05:15 64 51 38 16 34 55 1.322 0.116 02-A r-08 05:30 64 47 38 167 33 54 1.299 0.00 10.93 0.130 0.00 0.91 02-A r-08 05:45 64 42 37 169 33 54 1.257 0.143 02-A r-O8 06:00 64 40 37 161 32 54 1.228 0.00 17.49 0.155 0.00 1.28 02-A r-08 06:15 64 39 37 174 32 54 1.202 0.168 02-A r-08 06:30 64 48 37 168 32 54 1.207 0.00 0.181 0.00 02-A r-08 06:45 64 31 37 165 30 53 1.188 0.193 02-A r-08 07:00 64 38 38 169 30 53 1.161 0.00 8.20 0.205 0.00 1.62 02-A rA8 07:15 64 32 38 180 31 53 1.141 0.217 02-A r-08 07:30 64 39 38 172 32 54 1.132 0.00 0.229 0.00 02-A r-08 07:45 64 35 38 182 32 55 1.116 0.240 02-A r-08 08:00 64 38 38 174 32 54 1.109 0.00 7.13 0.252 0.00 1.91 02-A r-08 08:15 64 43 37 184 32 54 1.096 0.263 02-A r-08 08:30 64 43 37 174 31 54 1.074 0.00 0.274 0.00 42.0 02-A r-08 08:45 64 28 37 178 31 54 1.058 0.285 02-A r-08 09:00 64 38 38 189 30 54 1.025 0.00 12.02 0.296 0.00 2.41 0.600 0.77 0 02-A r-08 09:15 64 29 38 192 29 49 1.028 0.307 02-A r-08 09:30 64 28 39 187 29 48 0.973 0.00 0.317 0.00 02-A r-OS 09:45 64 28 39 187 29 47 0.994 0.327 02-A r-08 10:00 64 28 39 188 29 51 0.995 0.00 8.70 0.338 0.00 2.78 02-A r-08 10:15 64 40 39 191 28 53 0.978 0.348 02-A r-08 10:30 64 30 39 203 29 53 0.977 0.00 0.358 0.00 02-A r-08 10:45 64 28 39 195 28 54 0.970 0.368 02-A r-08 11:00 64 35 39 201 28 54 0.959 0.00 10.93 0.378 0.00 3.23 02-A r-08 11:15 64 28 41 204 28 53 0.963 0.388 02-A r-08 11:30 64 31 41 211 27 54 0.960 0.00 0.398 0.00 02-A r-08 11:45 64 42 40 201 27 53 0.953 0.408 02-A r-08 12:00 64 27 41 205 26 53 0.952 0.00 12.57 0.418 0.00 3.76 0.598 7.62 100.00 70,000 02-A r-08 12:15 64 43 41 205 25 54 0.934 0.428 02-A r-08 12:30 64 30 40 209 27 54 0.927 20.00 0.437 0.42 02-A r-08 12:45 64 27 41 204 28 54 0.938 0.447 02-A r-08 13:00 64 35 41 203 28 54 0.942 20.00 8.20 0.457 0.83 4.10 02-A r-OS 13:15 64 41 40 212 27 54 0.942 0.467 02-A r-08 13:30 64 40 40 207 27 54 0.937 40.00 0.477 1.67 0.598 7.49 100.00 60,000 02-A r-08 13:45 64 40 40 219 26 55 0.925 0.486 02-A r-08 14:00 64 38 40 220 27 55 0.914 0.00 9.84 0.496 1.67 4.51 02-A r-08 14:15 64 27 41 214 28 54 0.926 0.505 02-A r-08 14:30 64 39 41 219 27 54 0.926 0.00 0.515 1.67 Expro Well Testing 1 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO START DATE : 2 Aprv08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park u~atio~ CHOKE SEPAR ATOR FLOW RATES McOH CUMUL ATNE McOH FLUI D PROPER TIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMscf FLUID sib INJ stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % HzS m SALINITY m 02-A r-08 14:45 64 40 41 221 27 54 0.924 0.525 02-A r-08 15:00 64 28 41 219 27 55 0.908 38.81 12.02 0.534 2.48 5.01 7.54 100.00 64,000 02-A r-08 15:15 64 28 41 212 28 54 0.919 0.544 02-A r-08 15:30 64 25 40 211 26 54 0.928 0.00 0.553 2.48 02-A r-08 15:45 64 30 41 212 24 57 0.897 0.563 02-A r-08 16:00 64 28 41 212 26 56 0.925 38.81 10.93 0.572 3.28 5.46 02-A r-08 16:15 64 26 41 222 26 55 0.913 0.582 02-A r-08 16:30 64 41 40 211 26 56 0.911 19.40 0.591 3.69 02-A r-08 16:45 64 39 40 210 26 56 0.907 0.601 02-A r-08 17:00 64 26 40 220 27 56 0.909 0.00 9.84 0.610 3.69 5.87 100.00 70,000 02-A r-08 17:15 64 25 39 216 27 55 0.905 0.620 02-A r-08 17:30 64 41 39 209 27 55 0.895 0.00 6.56 0.629 3.69 6.01 02-A r-08 17:45 64 27 40 212 28 54 0.905 0.638 02-A r-08 18:00 64 38 40 206 27 55 0.902 0.00 0.648 3.69 100.00 0.77 70,000 02-A r-08 18:15 64 30 40 206 27 55 0.897 0.657 02-A r-08 18:30 64 37 39 208 29 56 0.896 19.40 10.93 0.667 4.09 6.47 7.65 100.00 02-A r--08 18:45 64 41 39 210 31 54 0.907 0.676 02-A r-08 19:00 64 34 39 208 28 55 0.918 20.00 0.686 4.51 100.00 02-A r-08 19:15 64 23 40 209 27 55 0.914 0.695 02-A r-08 19:30 64 23 41 213 25 54 0.909 20.00 10.93 0.704 4.93 6.92 100.00 02-A r-08 19:45 64 37 41 218 24 54 0.900 0.714 02-A r-08 20:00 64 36 41 214 26 54 0.889 20.00 0.00 0.723 5.34 0.597 02-A r-08 20:15 64 38 40 215 25 53 0.880 0.732 02-A r-08 20:30 64 29 40 222 25 54 0.872 0.00 0.00 0.741 5.34 6.92 02-A r-OS 20:45 64 42 41 216 26 55 0.858 0.750 02-A r-08 21:00 64 49 40 229 29 57 0.881 0.00 0.00 0.759 5.34 7.72 100.00 02-A r-08 21:15 64 31 39 232 29 58 0.909 0.769 02-A r-08 21:30 64 30 39 229 28 57 0.892 40.00 10.93 0.778 6.18 7.38 100.00 02-A r-08 21:45 64 29 38 215 30 58 0.895 0.788 02-A r-08 22:00 64 41 39 222 30 57 0.887 20.00 0.797 6.59 100.00 02-A r-08 22:15 64 25 39 211 31 57 0.893 0.806 02-A r-08 22:30 64 33 38 208 31 56 0.889 0.00 13.11 0.815 6.59 7.92 100.00 02-A r-08 22:45 64 24 39 209 31 56 0.891 0.825 02-A r-08 23:00 64 36 39 218 31 56 0.886 20.00 0.834 7.01 100.00 1.00 02-A r-08 23:15 64 42 38 219 30 55 0.885 0.843 02-A r-08 23:30 64 38 39 219 31 56 0.881 0.00 8.74 0.852 7.01 8.29 0.598 7.30 100.00 1.00 0 02-A r-08 23:45 64 33 39 212 31 56 0.861 0.861 03-A r-08 00:00 64 28 39 218 31 56 0.865 19.60 0.870 7.42 100.00 03-A r-08 00:15 64 42 38 219 31 55 0.865 0.879 03-A r-08 00:30 64 36 38 214 31 56 0.857 20.00 13.11 0.888 7.83 8.88 100.00 03-A r-08 00:45 64 28 39 216 32 56 0.863 0.897 03-A r-08 01:00 64 37 38 205 32 55 0.863 0.00 0.906 7.83 03-A r-08 01:15 64 39 38 218 31 55 0.857 0.915 03-A r-08 01:30 64 42 38 224 34 56 0.895 20.00 8.74 0.924 8.25 9.20 100.00 03-A r-08 01:45 64 40 39 216 31 57 0.855 0.933 03-A r-08 02:00 64 42 38 224 31 57 0.857 0.00 0.942 8.25 7.17 03-A r-08 02:15 64 31 38 221 33 56 0.866 0.951 • u Expro Well Testing 2 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO START DATE : 2-Apr-08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~„ada,'1~, a Petroleum CorOOration CHOKE SEPARATOR FLOW RATES McOH CUMUL ATIVE McOH FLUID PROPER TIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMscf FLUID sib INJ stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % HZS m SALINITY m 03-A r-08 02:30 64 29 38 214 32 56 0.854 20.00 12.02 0.960 8.67 9.70 100.00 03-A r-08 02:45 64 27 38 218 32 56 0.859 0.969 03-A r-08 03:00 64 30 39 208 33 56 0.861 0.00 0.978 8.67 0.599 0.90 0 03-A r-08 03:15 64 27 39 203 33 56 0.862 0.987 03-A r-08 03:30 64 30 39 219 32 56 0.866 20.00 10.93 0.996 9.09 10.15 100.00 03-A r-08 03:45 64 34 38 219 29 57 0.871 1.005 03-A r-OS 04:00 64 27 38 211 29 56 0.855 0.00 1.014 9.09 03-A r-OS 04:15 64 25 38 209 30 56 0.859 1.023 03-A r-08 04:30 64 21 37 212 30 55 0.859 20.00 6.56 1.032 9.50 10.43 7.37 100.00 46,000 03-A r-08 04:45 64 25 38 209 29 54 0.842 1.041 03-A r-OS 05:00 64 37 38 213 29 54 0.846 20.00 1.050 9.92 100.00 03-A r-OS 05:15 64 35 38 211 30 56 0.858 1.058 03-A r-08 05:30 64 26 37 214 28 56 0.815 0.00 6.56 1.067 9.92 10.70 0.598 03-A r-08 05:45 64 39 37 221 30 56 0.834 1.076 03-A r-08 06:00 64 40 36 208 31 55 0.834 0.00 1.084 9.92 03-A r-08 06:15 64 22 36 206 31 56 0.826 1.093 03-A r-08 06:30 64 38 36 205 31 55 0.821 0.00 6.56 1.101 9.92 10.97 03-A r-OS 06:45 64 38 36 206 31 54 0.820 1.110 03-A r-08 07:00 64 20 35 208 31 55 0.834 1.119 0.599 0.90 0 03-A r-08 07:15 64 27 35 209 30 54 0.826 1.127 03-A r-08 07:30 64 32 35 211 32 54 0.849 0.00 6.56 1.136 9.92 11.25 100.00 03-A r-08 07:45 64 41 34 215 32 55 0.862 1.145 03-A r-08 08:00 64 42 34 214 32 55 0.851 1.154 03-A r-08 08:15 64 22 35 222 31 57 0.863 1.163 03-A r-08 08:30 64 28 36 225 31 56 0.851 19.60 8.74 1.172 10.74 11.61 03-A r-08 08:45 64 29 34 215 29 56 0.891 1.181 03-A r-08 09:00 64 27 34 211 27 55 0.851 1.190 03-A r-08 09:15 64 28 35 217 28 56 0.831 1.199 03-A r-08 09:30 64 39 34 226 29 56 0.815 0.00 4.37 1.207 10.74 11.79 03-A r-08 09:45 64 37 36 214 31 55 0.839 1.216 03-A r-08 10:00 64 39 36 226 32 55 0.845 1.225 03-A r-08 10:15 64 39 36 218 32 56 0.837 1.233 03-A r-08 10:30 64 32 36 214 33 55 0.839 0.00 7.10 1.242 10.74 12.09 03-A r-08 10:45 64 31 35 220 32 55 0.814 1.251 03-A r-08 11:00 64 39 36 215 33 53 0.856 1.260 03-A r-08 11:15 64 35 36 226 31 53 0.884 1.269 03-A r-08 11:30 64 18 35 218 28 53 0.866 0.00 7.10 1.278 10.74 12.38 03-A r-08 11:45 64 15 36 228 24 53 0.832 1.286 03-A r-OS 12:00 64 34 36 219 23 53 0.768 1.294 03-A r-OS 12:15 64 30 36 215 24 55 0.754 1.302 03-A r-OS 12:30 64 45 36 218 28 55 0.767 0.00 9.84 1.310 10.74 12.79 0.600 100.00 0.90 0 10,000 03-A r-08 12:45 64 35 36 228 32 56 0.832 1.319 03- r-08 13:00 64 20 36 232 31 55 0.817 1.327 03-A r-08 13:15 64 41 36 235 30 56 0.796 1.336 03-A r-08 13:30 64 39 37 236 35 56 0.880 0.00 8.74 1.345 10.74 13.16 03-A r-08 13:45 64 43 36 231 35 56 0.876 1.354 03-A r-08 14:00 64 32 37 229 41 57 1.011 1.365 Expro Well Testing 3 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO STARTDnTE:2-Apk08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m~atio~ CHOKE SEPARATOR FLOW RATES McOH CUMU LATNE McOH FLUID PROPER TIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMscf FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BSBW % COZ % HZS m SALINITY m 03-A r-OS 14:15 64 35 37 242 35 57 0.858 1.373 03-A r-08 14:30 64 26 38 231 31 56 0.936 29.86 8.74 1.383 11.98 13.52 100.00 03-A r-08 14:45 64 28 39 229 25 55 0.882 1.392 03-A r-08 15:00 64 44 39 231 25 56 0.796 1.401 03-A r-08 15:15 64 32 38 234 30 58 0.844 1.409 03-A r-08 15:30 64 29 38 246 32 58 0.816 9.95 6.56 1.418 12.39 13.80 03-A r-08 15:45 64 39 38 236 34 58 0.833 1.427 03-A r-08 16:00 64 30 38 241 35 57 0.840 1.435 100.00 1.00 0 03-A r-08 16:15 64 30 37 242 33 58 0.813 1.444 03-A r-08 16:30 64 29 37 239 33 58 0.817 9.95 7.65 1.452 12.81 14.12 03-A r-08 16:45 64 37 36 247 35 59 0.863 1.461 03-A r-08 17:00 64 29 37 242 27 56 0.871 1.470 03-A r-08 17:15 64 36 37 235 26 57 0.817 1.479 03-A r-08 17:30 64 29 36 234 26 57 0.731 9.95 8.74 1.487 13.22 14.48 03-A r-08 17:45 64 26 36 241 29 57 0.740 1.494 03-A r-08 18:00 64 7 37 243 28 55 0.712 1.502 6.93 100.00 03-A r-08 18:15 64 23 36 229 19 56 0.541 1.507 03-A r-08 18:30 64 16 36 239 16 55 0.495 9.93 7.65 1.512 13.64 14.80 03-A r-08 18:45 64 0 36 243 7 55 0.326 1.516 03-A r-08 19:00 64 0 38 230 1 55 0.185 1.518 03-A r-08 19:15 64 1 38 241 1 55 0.000 1.518 03-A r-08 19:30 64 4 38 232 4 55 0.202 0.00 9.84 1.520 13.64 15.21 03-A r-08 19:45 64 1 36 242 1 56 0.180 1.522 03-A r-08 20:00 64 0 35 246 0 58 0.168 1.524 03-A r-08 20:15 64 0 34 236 0 62 0.162 1.525 03-A r-08 20:30 64 1 33 242 1 64 0.168 0.00 5.46 1.527 13.64 15.43 7.42 100.00 1.00 0 52,000 03-A r-OS 20:45 64 1 32 248 1 64 0.195 1.529 03-A r-OS 21:00 64 0 32 238 0 66 0.166 1.531 03-A r-08 21:15 64 0 32 236 0 66 0.220 1.533 03-A r-08 21:30 64 0 32 240 0 66 0.240 10.00 9.84 1.536 14.05 15.85 03-A r-08 21:45 64 0 32 235 0 67 0.223 1.538 03-A r-08 22:00 64 101 35 253 24 65 0.845 1.547 03-A r-08 22:15 64 59 36 263 48 60 1.333 1.561 03-A r-08 22:30 64 32 36 263 38 58 1.177 10.00 8.74 1.573 14.47 16.03 7.37 03-A r-08 22:45 64 29 36 252 24 56 1.112 1.584 03-A r-08 23:00 64 30 35 259 23 55 1.074 1.596 03-A r-08 23:15 64 44 35 249 22 56 1.051 1.607 03-A r-08 23:30 64 43 35 245 23 57 1.020 9.75 6.56 1.617 14.88 16.48 03-A r-08 23:45 64 40 35 246 24 57 1.011 1.628 04-A r-08 00:00 64 44 35 260 25 56 0.996 10.93 1.638 16.71 7.15 04-A r-08 00:15 64 25 35 256 26 55 1.003 1.649 04-A r-08 00`30 64 25 35 246 24 54 0.999 0.00 6.56 1.659 14.88 16.85 0.600 100.00 0.90 0 28,000 04-A r-08 00:45 64 34 34 248 21 54 0.979 1.669 04-A r-08 01:00 64 34 34 253 22 55 0.960 1.679 04-A r-08 01:15 64 38 34 242 23 55 0.953 1.689 04-A r-08 01:30 64 21 34 243 23 55 0.940 10.00 7.65 1.699 15.29 17.17 04-A r-08 01:45 64 34 34 253 23 55 0.937 1.709 • Expro Well Testing 4 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO START DATE : 2-Apr-OS END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park leu~atio~ lel CHOKE SEPAR ATOR FLOW RATES McOH CUMU LATNE McOH FLUID PROPER TIES DATE 8: TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMscf FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BSBW % COZ % HZS m SALINrfY m 04-A r-OS 02:00 64 36 33 246 23 55 0.928 1.718 04-A r-OS 02:15 64 39 34 250 23 56 0.928 1.728 04-A r-08 02:30 64 29 33 257 23 56 0.926 0.00 8.74 1.738 15.29 17.53 7.45 100.00 04-A r-08 02:45 64 37 34 246 22 56 0.908 1.747 04-A r-08 03:00 64 39 34 259 23 56 0.914 1.757 04-A r-08 03:15 64 22 34 249 23 56 0.912 1.766 04-A r-08 03:30 64 37 34 250 22 57 0.904 10.00 6.56 1.775 15.71 17.80 0.599 100.00 04-A r-08 03:45 64 20 34 254 22 56 0.896 1.785 04-A r-08 04:00 64 25 34 263 21 57 0.881 1.794 04-A r-08 04:15 64 37 34 252 23 57 0.891 1.803 04-A r-08 04:30 64 23 34 263 23 56 0.889 9.90 7.65 1.813 16.12 18.12 04-A r-08 04:45 64 35 34 264 24 22 0.904 1.822 04-A r-08 05:00 64 36 35 264 22 57 0.882 1.831 04-A r-08 05:15 64 30 35 254 23 57 0.891 1.840 04-A r-08 05:30 64 29 35 263 23 56 0.889 9.90 9.84 1.850 16.54 18.53 0.599 7.65 100.00 0.92 0 56,000 04-A r-OS 05:45 64 28 35 260 23 56 0.890 1.859 04-A r-08 06:00 64 36 35 260 22 56 0.877 0.00 8.74 1.868 16.54 18.71 04-A r-08 06:15 64 33 35 256 20 56 0.825 1.877 04-A r-08 06:30 64 21 35 255 20 55 0.842 1.885 04- rA8 06:45 64 78 35 255 21 55 0.858 7.894 04-A r-08 06:46 64 27 35 265 20 55 0.817 1.895 04-A r-08 06:47 64 15 35 255 18 55 0.785 1.895 04-A r-08 06:48 64 32 35 255 18 55 0.784 1.896 04-A r-08 06:49 64 23 35 257 19 55 0.804 1.897 04-A r-08 06:50 64 17 35 256 18 55 0.792 1.897 04-A r-08 06:51 64 26 35 259 19 55 0.777 1.898 04-A r-08 06:52 64 20 35 256 13 54 0.661 1.898 04-A r-08 06:53 64 17 36 254 10 54 0.587 1.899 04-A r-08 06:54 64 0 35 261 8 54 0.504 1.899 04-A r-08 06:55 64 20 35 252 10 54 0.560 1.899 04-A r-08 06:56 64 52 36 254 23 57 0.914 1.900 04-A r-08 06:57 64 39 35 254 28 56 1.061 1.901 04-A r-08 06:58 64 46 35 263 26 55 1.038 1.901 04-A r-08 06:59 64 47 35 260 25 55 1.028 1.902 04-A r-08 07:00 64 32 36 258 26 55 1.032 9.80 6.56 1.903 17.35 18.99 04-A r-08 07:15 64 23 37 263 22 56 0.922 1.912 04-A r-08 07:30 64 25 39 269 21 57 0.880 1.922 04-A r-08 07:45 64 23 41 269 22 57 0.879 1.931 04-A r-08 08:00 64 22 40 269 21 55 0.862 9.80 7.65 1.940 17.76 19.31 7.66 100.00 04-A r-OS 08:15 64 21 41 257 20 55 0.818 1.948 04-A r-08 08:30 64 39 41 264 21 56 0.845 1.957 04-A r-08 08:45 64 21 41 256 20 57 0.835 1.966 04-A r-08 09:00 64 37 41 262 21 57 0.830 9.80 7.65 1.974 18.17 19.62 0.598 100.00 0.90 0 04-A r-08 09:15 64 32 43 266 23 57 0.857 1.983 04-A r-08 09:30 64 40 43 264 23 58 0.865 1.992 04-A r-08 09:45 64 25 42 273 23 58 0.848 2.001 04-A r-08 10:00 64 27 44 273 24 57 0.857 19.70 6.56 2.010 18.99 19.90 100.00 • Expro Well Testing 5 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko EXPRO START DATE : 2-Apr 08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park leu~atio~ CHOKE SEPAR ATOR FLOW RATES McOH C MU LATIVE McOH FLUID PROPERTIES DATE $ TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscF/d FLUID stb/d INJ stb/d GAS MMscf FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BS$W % COZ % HZS m SALINITY m 04-A r-08 10:15 64 32 45 273 25 57 0.863 2.019 04-A r-OS 10:30 64 25 45 275 25 57 0.856 2.028 04-A r-OS 10:45 64 37 45 270 23 58 0.841 2.037 04-A r-08 11:00 64 41 45 263 24 58 0.856 0.00 8.74 2.046 18.99 20.26 7.48 100.00 04-A r-08 11:15 64 22 44 263 25 58 0.859 2.055 04-A r-08 11:30 64 36 45 266 23 58 0.853 2.063 04-A r-08 11:45 64 40 46 271 23 58 0.845 2.072 04-A r-OS 12:00 64 31 46 261 22 59 0.833 0.00 8.74 2.081 18.99 20.63 100.00 04-A r-OS 12:15 64 29 45 262 22 58 0.837 2.090 04-A r-OS 12:30 64 33 46 260 22 59 0.821 2.098 04-A r-08 12:45 64 40 45 270 23 59 0.846 2.107 04-A r-08 13:00 64 26 46 262 23 59 0.851 9.95 8.74 2.116 19.40 20.99 100.00 04-A r-08 13:15 64 23 46 267 21 58 0.868 2.125 04-A r-08 13:30 64 24 46 274 18 58 0.851 2.134 04-A r-08 13:31 64 10 46 274 9 57 0.578 2.134 04-A r-OS 13:32 64 0 46 263 6 56 0.453 2.135 04-A r-OS 13:33 64 4 47 272 5 57 0.400 2.135 04-A r-OS 13:34 64 1 47 273 6 57 0.419 2.135 04-A r-08 13:35 64 14 47 263 6 57 0.437 2.135 04-A r-08 13:36 64 3 47 265 7 58 0.483 2.136 04-A r-08 13:37 64 3 47 272 9 58 0.520 2.136 04-A r-08 13:38 64 20 47 270 10 58 0.554 2.136 04-A r-08 13:39 64 5 47 264 10 58 0.547 2.137 04-A r-08 13:40 64 19 48 273 10 58 0.549 2.137 04-A r-08 13:41 64 9 48 264 11 58 0.567 2.138 04-A r-08 13:42 64 84 47 273 26 61 1.084 2.138 04-A r-08 13:43 64 93 47 268 36 61 1.589 2.140 04-A r-08 13:44 64 75 46 271 35 60 1.570 2.141 04-A r-08 13:45 64 68 46 278 32 60 1.475 2.142 04-A r-08 13:46 64 69 46 282 29 60 1.385 2.143 04-A r-08 13:47 64 64 46 273 26 60 1.287 2.143 04-A r-OS 13:48 64 44 46 281 24 60 1.211 2.144 04-A r-08 13:49 64 53 45 281 22 60 1.127 2.145 04-A r-OS 13:50 64 44 46 282 21 60 1.075 2.146 04-A r-08 13:51 64 36 45 275 20 60 1.043 2.147 04-A r-08 13:52 64 33 45 282 20 60 0.990 2.147 04-A r-08 13:53 64 34 45 280 19 60 0.957 2.148 04-A r-08 13:54 64 44 46 281 19 60 0.944 2.149 04-A r-08 13:55 64 27 45 281 17 60 0.891 2.149 04-A r-08 13:56 64 39 46 273 17 60 0.869 2.150 04-A r-08 13:57 64 30 45 271 17 60 0.861 2.150 04-A r-08 13:58 64 24 46 281 17 60 0.851 2.151 04-A r-08 13:59 64 23 46 275 16 60 0.838 2.152 04-A r-08 14:00 64 31 45 273 17 59 0.844 9.85 8.74 2.152 19.82 21.36 0.594 100.00 30,000 04-A r-08 14:15 64 38 46 279 17 60 0.851 2.161 04-A r-08 14:30 64 32 45 272 17 61 0.868 2.170 04-A r-08 14:45 64 36 47 275 18 59 0.843 2.179 • Expro Well Testing 6 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO START DATE : 2-Apr-08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m CorPO CHOKE SEPAR ATOR FLOW RATES McOH CUMU LATIVE McOH FLUI D PROPERTIES DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscF/d FLUID stb/d INJ stb/d GAS MMscf FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BS&W % C02 % HZS m SALINITY m 04- r-08 15:00 64 19 48 260 18 58 0.780 0.00 8.56 2.187 19.82 21.63 04-A r-08 15:01 64 9 48 258 8 58 0.520 2.187 04-A r-08 15:02 64 15 48 259 8 58 0.499 2.188 04-A r-08 15:03 64 20 48 269 8 58 0.494 2.188 04-A r-08 15:04 64 8 48 265 7 58 0.470 2.188 04-A r-08 15:05 64 21 48 260 6 59 0.452 2.189 04-A r-08 15:06 64 3 48 269 6 59 0.444 2.189 04-A r-08 15:07 64 4 48 270 6 59 0.427 2.189 04-A r-08 15:08 64 3 48 262 5 59 0.421 2.190 04-A r-08 15:09 64 15 48 258 5 59 0.410 2.190 04-A r-08 15:10 64 1 48 262 5 59 0.408 2.190 04-A r-08 15:11 64 12 48 266 5 59 0.403 2.190 04-A r-08 15:12 64 4 48 264 5 59 0.399 2.191 04-A r-08 15:13 64 0 48 261 5 59 0.390 2.191 04-A r-08 15:14 64 7 48 270 5 59 0.394 2.191 04-A r-08 15:15 64 13 48 270 5 59 0.394 2.192 04-A r-08 15:16 64 2 48 259 6 60 0.411 2.192 04-A r-08 15:17 64 4 48 268 6 60 0.390 2.192 04-A r-08 15:18 64 2 49 260 6 60 0.386 2.192 04-A r-08 15:19 64 7 49 267 6 60 0.399 2.193 04-A r-08 15:20 64 0 50 257 6 60 0.401 2.193 04-A r-08 15:21 64 14 50 269 6 60 0.397 2.193 04-A r-08 15:22 64 0 51 267 5 60 0.378 2.193 04-A r-08 75:23 0 11 51 256 2 59 0.000 2.193 04-A r-08 15:24 0 23 53 264 04-A r-08 15:25 0 35 54 267 04-A r-OS 15:26 0 25 54 262 04-A r-08 15:27 0 38 55 270 04-A r-08 15:28 0 31 56 258 04-A r-08 15:29 0 44 56 266 04-A r-08 15:30 0 42 57 261 04-A r-08 15:31 0 37 57 268 04-A r-08 15:32 0 27 57 258 04-A r-08 15:33 0 39 58 265 04-A r-08 15:34 0 43 59 267 04-A r-08 15:35 0 28 60 267 04-A r-08 15:36 0 32 60 264 04-A r-08 15:37 0 31 60 259 04-A r-OS 15:38 0 43 61 263 04-A r-08 15:39 0 40 61 259 04-A r-OS 15:40 0 34 61 257 04-A r-OS 15:41 0 36 61 265 04-A r-08 15:42 0 47 62 268 04-A r-08 15:43 0 45 62 260 04-A r-08 15:44 0 45 62 261 04-A r-08 15:45 0 46 63 257 04-A r-08 15:46 0 46 64 269 r~ ~~ i Expro Well Testing 7 of 8 5/1/2008 WELL TEST REPORT CUSTOMER : Anadarko O EXPRO START DATE : 2-Apr-08 END DATE: 4-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~troleu~atio~ CHOKE SEPAR ATOR FLOW RATES McOH CUMU LATNE McOH FLUI D PROPERTIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ stb/d GAS MMs FLUID stb INJ stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % HZS m SALINITY m 04-A r-08 15:47 0 47 64 270 04-A r-08 15:48 0 52 65 269 04-A r-08 15:49 0 51 66 267 04-A r-08 15:50 0 54 66 261 04-A r-08 15:51 0 48 67 260 04-A r-08 15:52 0 52 67 259 04-A r-08 15:53 0 56 68 269 04-A r-08 15:54 0 58 68 258 04-A r-08 15:55 0 57 68 259 04-A r-OS 15:56 0 46 69 260 04-A r-OS 15:57 0 44 69 260 04-A r-08 15:58 0 55 69 259 04-A r-08 15:59 0 48 70 259 04-A r-OS 16:00 0 45 70 270 Expro Well Testing 8 of 8 5/1/2008 GAS FLOW REPORT ® CUSTOMER :Anadarko O EXPRO START I~ E: 2-Apr 08 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis MaDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m Corooratio~ SEPA RATOR GAS FA CTORS DATE 8 TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) ~ (psis) DIFF. PRESS (inches H2O) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 02-Apr-08 04:00 48 95.96 27.37 74.81 2.75 0.600 51.249 1582.05 1.0000 1.0000 1.2910 0.9861 1.0007 1.0018 1.0060 2031.47 2.499 0.026 02-Apr-08 04:15 64 72.90 42.00 53.78 2.75 0.599 55.334 1582.05 1.0000 1.0000 1.2920 1.0060 1.0007 1.0036 1.0050 2075.60 2.756 0.055 02-Apr-08 04:30 64 56.45 18.42 54.63 2.75 0.599 32.246 1582.05 1.0000 1.0000 1.2920 1.0052 1.0012 1.0020 1.0040 2068.73 1.601 0.071 02-Apr-08 04:45 64 54.06 17.61 54.69 2.75 0.599 30.854 1582.05 1.0000 1.0000 1.2920 1.0051 1.0012 1.0020 1.0030 2068.30 1.531 0.087 02-Apr-08 05:00 64 50.72 16.29 54.18 2.75 0.599 28.744 1582.05 1.0000 1.0000 1.2920 1.0056 1.0013 1.0020 1.0030 2068.91 1.427 0.102 02-Apr-08 05:15 64 48.86 14.52 54.56 2.75 0.599 26.635 1582.05 1.0000 1.0000 1.2920 1.0053 1.0015 1.0018 1.0030 2067.74 1.322 0.116 02-Apr-08 05:30 64 48.12 14.22 53.79 2.75 0.599 26.158 1582.05 1.0000 1.0000 1.2920 1.0060 1.0015 1.0018 1.0030 2069.24 1.299 0.13 02-Apr-08 05:45 64 47.59 13.47 53.94 2.75 0.599 25.319 1582.05 1.0000 1.0000 1.2920 1.0059 1.0015 1.0017 1.0030 2068.77 1.257 0.14 02-Apr-08 06:00 64 47.18 12.97 53.88 2.75 0.599 24.737 1582.05 1.0000 1.0000 1.2920 1.0059 1.0016 1.0017 1.0030 2068.81 1.228 0.155 02-Apr-08 06:15 64 46.54 12.58 53.54 2.75 0.599 24.197 1582.05 1.0000 1.0000 1.2920 1.0063 1.0016 1.0017 1.0030 2069.41 1.202 0.168 02-Apr-08 06:30 64 45.50 12.97 53.42 2.75 0.599 24.293 1582.05 1.0000 1.0000 1.2920 1.0064 1.0016 1.0018 1.0030 2069.67 1.207 0.181 02-Apr-08 06:45 64 45.00 12.70 52.82 2.75 0.599 23.906 1582.05 1.0000 1.0000 1.2920 1.0070 1.0017 1.0017 1.0030 2070.83 1.188 0.193 02-Apr-08 07:00 64 44.89 12.16 53.29 2.75 0.599 23.364 1582.05 1.0000 1.0000 1.2920 1.0065 1.0017 1.0017 1.0030 2069.78 1.161 0.205 02-Apr-08 07:15 64 45.73 11.53 53.44 2.75 0.599 22.962 1582.05 1.0000 1.0000 1.2920 1.0064 1.0017 1.0016 1.0030 2069.42 1.141 0.217 02-Apr-08 07:30 64 46.55 11.17 53.87 2.75 0.599 22.803 1582.05 1.0000 1.0000 1.2920 1.0059 1.0017 1.0015 1.0030 2068.55 1.132 0.229 02-Apr-08 07:45 64 46.92 10.79 54.78 2.75 0.599 22.500 1582.05 1.0000 1.0000 1.2920 1.0051 1.0017 1.0014 1.0030 2066.67 1.116 0.240 02-Apr-OS 08:00 64 47.15 10.59 54.38 2.75 0.599 22.345 1582.05 1.0000 1.0000 1.2920 1.0055 1.0018 1.0014 1.0030 2067.49 1.109 0.252 02-Apr-08 08:15 64 46.87 10.41 54.41 2.75 0.599 22.089 1582.05 1.0000 1.0000 1.2920 1.0054 1.0018 1.0014 1.0030 2067.38 1.096 0.263 02-Apr-08 08:30 64 45.88 10.21 54.48 2.75 0.599 21.643 1582.05 1.0000 1.0000 1.2920 1.0054 1.0018 1.0014 1.0030 2067.16 1.074 0.274 02-Apr-08 08:45 64 45.35 10.02 53.81 2.75 0.599 21.317 1582.05 1.0000 1.0000 1.2920 1.0060 1.0019 1.0014 1.0030 2068.49 1.058 0.285 02-Apr-08 09:00 64 44.38 9.61 54.07 2.75 0.599 20.652 1582.05 1.0000 1.0000 1.2920 1.0057 1.0019 1.0013 1.0030 2067.86 1.025 0.296 02-Apr-08 09:15 64 44.00 9.64 48.75 2.75 0.599 20.595 1582.05 1.0000 1.0000 1.2920 1.0110 1.0019 1.0014 1.0030 2078.80 1.028 0.307 02-Apr-08 09:30 64 43.49 8.73 47.93 2.75 0.599 19.485 1582.05 1.0000 1.0000 1.2920 1.0118 1.0020 1.0012 1.0030 2080.43 0.973 0.317 02-Apr-08 09:45 64 43.60 9.09 46.50 2.75 0.600 19.908 1582.05 1.0000 1.0000 1.2910 1.0132 1.0020 1.0013 1.0030 2081.72 0.994 0.327 02-Apr-0810:00 64 43.30 9.25 51.40 2.75 0.600 20.013 1582.05 1.0000 1.0000 1.2910 1.0084 1.0020 1.0013 1.0030 2071.55 0.995 0.338 02-Apr-0810:15 64 43.18 9.00 53.29 2.75 0.600 19.713 1582.05 1.0000 1.0000 1.2910 1.0065 1.0020 1.0013 1.0020 2067.66 0.978 0.34 02-Apr-0810:30 64 43.88 8.83 53.37 2.75 0.600 19.684 1582.05 1.0000 1.0000 1.2910 1.0064 1.0020 1.0012 1.0030. 2067.51 0.977 0.358 02-Apr-0810:45 64 42.65 8.97 53.87 2.75 0.600 19.559 1582.05 1.0000 1.0000 1.2910 1.0059 1.0020 1.0013 1.0020 2066.44 0.970 0.368 02-Apr-0811:00 64 42.75 8.74 53.81 2.75 0.600 19.330 1582.05 1.0000 1.0000 1.2910 1.0060 1.0021 1.0013 1.0020 2066.54 0.959 0.378 02-Apr-0811:15 64 42.82 8.80 53.40 2.75 0.600 19.412 1582.05 1.0000 1.0000 1.2910 1.0064 1.0021 1.0013 1.0020 2067.39 0.963 0.388 02-Apr-0811:30 64 41.39 9.05 53.53 2.75 0.600 19.354 1582.05 1.0000 1.0000 1.2910 1.0063 1.0021 1.0013 1.0020 2067.09 0.960 0.398 02-Apr-0811:45 64 41.28 8.93 53.09 2.75 0.600 19.200 1582.05 1.0000 1.0000 1.2910 1.0067 1.0021 1.0013 1.0020 2067.99 0.953 0.408 02-Apr-0812:00 64 40.86 9.01 53.14 2.75 0.600 19.187 1582.05 1.0000 1.0000 1.2910 1.0067 1.0021 1.0014 1.0020 2067.87 0.952 0.418 02-Apr-0812:15 64 40.04 8.85 53.70 2.75 0.600 18.824 1582.05 1.0000 1.0000 1.2910 1.0061 1.0022 1.0014 1.0020 2066.69 0.934 0.428 02-Apr-0812:30 64 41.65 8.38 53.97 2.75 0.600 18.682 1582.05 1.0000 1.0000 1.2910 1.0058 1.0022 1.0012 1.0020 2066.16 0.927 0.437 02-Apr-0812:45 64 42.71 8.38. 54.36 2.75 0.600 18.919 1582.05 1.0000 1.0000 1.2910 1.0055 1.0021 1.0012 1.0020 2065.42 0.938 0.447 02-Apr-0813:00 64 42.58 8.49 54.37 2.75 0.600 19.013 1582.05 1.0000 1.0000 1.2910 1.0055 1.0021 1.0012 1.0020 2065.39 0.942 0.457 02-Apr-0813:15 64 41.88 8.63 54.09 2.75 0.600 19.011 1582.05 1.0000 1.0000 1.2910 1.0057 1.0021 1.0013 1.0020 2065.93 0.942 0.467 02-Apr-0813:30 64 41.24 8.63 53.78 2.75 0.598 18.865 1582.05 1.0000 1.0000 1.2930 1.0060 1.0021 1.0013 1.0020 2069.98 0.937 0.477 02-Apr-0813:45 64 40.48 8.57 54.74 2.75 0.598 18.626 1582.05 1.0000 1.0000 1.2930 1.0051 1.0022 1.0013 1.0020 2068.00 0.925 0.486 02-Apr-0814:00 64 41.55 8.16 54.59 2.75 0.598 18.413 1582.05 1.0000 1.0000 1.2930 1.0052 1.0022 1.0012 1.0020 2068.32 0.914 0.496 Expro Well Testing 1 of 8 5/1/2008 GAS FLOW REPORT CUSTOMER : Anadarko WELL NAME : Gubik #3 ® EXPRO START DATE: 2-Apr-08 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis MaDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m Corporation SEPA RATOR GAS FA CTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) ~ (psia) DIFF. PRESS (inches Hz0) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 02-Apr-0814:15 64 42.63 8.16 54.30 2.75 0.598 18.651 1582.05 1.0000 1.0000 1.2930 1.0055 1.0021 1.0012 1.0020 2068.95 0.926 0.505 02-Apr-0814:30 64 42.09 8.25 53.81 2.75 0.598 18.634 1582.05 1.0000 1.0000 1.2930 1.0060 1.0022 1.0012 1.0020 2069.92 0.926 0.515 02-Apr-0814:45 64 41.50 8.34 54.04 2.75 0.598 18.604 1582.05 1.0000 1.0000 1.2930 1.0058 1.0022 1.0012 1.0020 2069.44 0.924 0.525 02-Apr-0815:00 64 41.52 8.06 54.55 2.75 0.598 18.293 1582.05 1.0000 1.0000 1.2930 1.0053 1.0022 1.0012 1.0020 2068.39 0.908 0.534 02-Apr-0815:15 64 42.33 8.09 54.00 2.75 0.598 18.505 1582.05 1.0000 1.0000 1.2930 1.0058 1.0022 1.0012 1.0020 2069.55 0.919 0.544 02-Apr-08 15:30 64 41.19 8.49 54.45 2.75 0.598 18.700 1582.05 1.0000 1.0000 1.2930 1.0054 1.0022 ' 1.0013 1.0020 2068.60 0.928 0.553 02-Apr-0815:45 64 38.96 8.42 56.69 2.75 0.598 18.112 1582.05 1.0000 1.0000 1.2930 1.0032 1.0023 1.0013 1.0020 2064.00 0.897 0.56 02-Apr-0816:00 64 40.52 8.60 55.73 2.75 0.598 18.667 1582.05 1.0000 1.0000 1.2930 1.0041 1.0022 1.0013 1.0020 2065.99 0.925 0.572 02-Apr-0816:15 64 40.64 8.33 55.19 2.75 0.598 18.399 1582.05 1.0000 1.0000 1.2930 1.0047 1.0022 1.0013 1.0020 2067.08 0.913 0.582 02-Apr-0816:30 64 40.97 8.24 55.69 2.75 0.598 18.374 1582.05 1.0000 1.0000 1.2930 1.0042 1.0022 1.0012 1.0020 2066.07 0.911 0.591 02-Apr-0816:45 64 40.90 8.18 55.58 2.75 0.598 18.291 1582.05 1.0000 1.0000 1.2930 1.0043 1.0022 1.0012 1.0020 2066.28 0.907 0.601 02-Apr-0817:00 64 41.90 8.03 55.80 2.75 0.598 18.343 1582.05 1.0000 1.0000 1.2930 1.0041 1.0022 1.0012 1.0020 2065.86 0.909 0.610 02-Apr-0817:15 64 41.76 7.97 54.60 2.75 0.598 18.244 1582.05 1.0000 1.0000 1.2930 1.0052 1.0022 1.0012 1.0020 2068.31 0.905 0.620 02-Apr-0817:30 64 41.46 7.85 54.54 2.75 0.598 18.041 1582.05 1.0000 1.0000 1.2930 1.0053 1.0022 1.0012 1.0020 2068.41 0.895 0.629 02-Apr-0817:45 64 42.37 7.84 53.89 2.75 0.598 18.226 1582.05 1.0000 1.0000 1.2930 1.0059 1.0022 1.0011 1.0020 2069.77 0.905 0.638 02-Apr-0818:00 64 41.76 7.91 55.01 2.75 0.598 18.175 1582.05 1.0000 1.0000 1.2930 1.0048 1.0022 1.0012 1.0020 2067.47 0.902 0.648 02-Apr-0818:15 64 41.90 7.79 54.53 2.75 0.598 18.067 1582.05 1.0000 1.0000 1.2930 1.0053 1.0022 1.0011 1.0020 2068.45 0.897 0.657 02-Apr-0818:30 64 43.56 7.49 56.10 2.75 0.598 18.063 1582.05 1.0000 1.0000 1.2930 1.0038 1.0022 1.0011 1.0020 2065:32 0.896 0.667 02-Apr-0818:45 64 45.78 7.29 54.96 2.75 0.598 18.268 1582.05 1.0000 1.0000 1.2930 1.0049 1.0022 1.0010 1.0030 2067.77 0.907 0.676 02-Apr-0819:00 64 42.59 8.03 54.81 2.75 0.598 18.493 1582.05 1.0000 1.0000 1.2930 1.0050 1.0022 1.0012 1.0020 2067.91 0.918 0.686 02-Apr-0819:15 64 41.24 8.21 54.61 2.75 0.598 18.401 1582.05 1.0000 1.0000 1.2930 1.0052 1.0022 1.0012 1.0020 2068.27 0.914 0.695 02-Apr-0819:30 64 39.82 8.42 54.29 2.75 0.598 18.311 1582.05 1.0000 1.0000 1.2930 1.0055 1.0022 1.0013 1.0020 2068.89 0.909 0.704 02-Apr-0819:45 64 38.86 8.45 54.20 2.75 0.598 18.121 1582.05 1.0000 1.0000 1.2930 1.0056 1.0023 1.0013 1.0020 2069.07 0.900 0.714 02-Apr-OS 20:00 64 40.46 7.91 54.17 2.75 0.597 17.890 1582.05 1.0000 1.0000 1.2940 1.0057 1.0023 1.0012 1.0020 2070.86 0.889 0.723 02-Apr-08 20:15 64 40.01 7.81 53.16 2.75 0.597 17.677 1582.05 1.0000 1.0000 1.2940 1.0066 1.0023 1.0012 1.0020 2072.92 0.880 0.732 02-Apr-08 20:30 64 39.87 7.72 53.65 2.75 0.597 17.544 1582.05 1.0000 1.0000 1.2940 1.0062 1.0023 1.0012 1.0020 2071.90 0.872 0.741 02-Apr-08 20:45 64 40.52 7.36 54.77 2.75 0.597 17.269 1582.05 1.0000 1.0000 1.2940 1.0051 1.0024 1.0011 1.0020 2069.62 0.858 0.750 02-Apr-08 21:00 64 44.13 7.16 57.04 2.75 0.597 17.776 1582.05 1.0000 1.0000 1.2940 1.0029 1.0022 1.0010 1.0020 2065.17 0.881 0.759 02-Apr-08 21:15 64 43.53 7.73 57.67 2.75 0.597 18.344 1582.05 1.0000 1.0000 1.2940 1.0022 1.0022 1.0011 1.0020 2063.84 0.909 0.769 02-Apr-08 21:30 64 42.77 7.57 57.18 2.75 0.597 17.994 1582.05 1.0000 1.0000 1.2940 1.0027 1.0022 1.0011 1.0020 2064.81 0.892 0.778 02-Apr-08 21:45 64 44.74 7.29 57.59 2.75 0.597 18.060 1582.05 1.0000 1.0000 1.2940 1.0023 1.0022 1.0010 1.0030 2064.08 0.895 0.788 02-Apr-08 22:00 64 44.60 7.17 56.54 2.75 0.597 17.882 1582.05 1.0000 1.0000 1.2940 1.0033 1.0022 1.0010 1.0030 2066.19 0.887 0.797 02-Apr-08 22:15 64 45.37 7.16 57.22 2.75 0.597 18.024 1582.05 1.0000 1.0000 1.2940 1.0027 1.0022 1.0010 1.0030 2064.86 0.893 0.806 02-Apr-08 22:30 64 45.53 7.06 56.07 2.75 0.597 17.929 1582.05 1.0000 1.0000 1.2940 1.0038 1.0022 1.0010 1.0030 2067.21 0.889 0.815 02-Apr-08 22:45 64 45.62 7.07 56.02 2.75 0.597 17.959 1582.05 1.0000 1.0000 1.2940 1.0038 1.0022 1.0010 1.0030 2067.32 0.891 0.825 02-Apr-08 23:00 64 45.47 7.02 55.71 2.75 0.597 17.866 1582.05 1.0000 1.0000 1.2940 1.0041 1.0022 1.0010 1.0030 2067.94 0.886 0.834 02-Apr-08 23:15 64 45.17 7.04 55.49 2.75 0.597 17.832 1582.05 1.0000 1.0000 1.2940 1.0044 1.0022 1.0010 1.0030 2068.37 0.885 0.843 02-Apr-08 23:30 64 45.63 6.92 55.87 2.75 0.598 17.770 1582.05 1.0000 1.0000 1.2930 1.0040 1.0022 1.0009 1.0030 2065.91 0.881 0.852 02-Apr-08 23:45 64 45.69 6.59 55.56 2.75 0.598 17.352 1582.05 1.0000 1.0000 1.2930 1.0043 1.0023 1.0009 1.0030 2066.57 0.861 0.861 03-Apr-08 00:00 64 45.83 6.64 55.79 2.75 0.598 17.445 1582.05 1.0000 1.0000 1.2930 1.0041 1.0023 1.0009 1.0030 2066.11 0.865 0.870 03-Apr-08 00:15 64 45.79 6.64 55.45 2.75 0.598 17.437 1582.05 1.0000 1.0000 1.2930 1.0044 1.0023 1.0009 1.0030 2066.81 0.865 0.879 Expro Well Testing 2 of 8 5/1/2008 GAS FLOW REPORT ® CUSTOMER : Anadarko WELL NAME : Gubik #3 EXPRO START DATE: 2-Apr-08 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis MaDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~d ~ ~m CorPOrat SEPAR ATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) ~ (psia) DIFF. PRESS (inches HZO) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 03-Apr-08 00:30 64 45.64 6.55 55.80 2.75 0.598 17.290 1582.05 1.0000 1.0000 1.2930 1.0041 1.0023 1.0009 1.0030 2066.08 0.857 0.888 03-Apr-08 00:45 64 46.39 6.53 55.97 2.75 0.598 17.405 1582.05 1.0000 1.0000 1.2930 1.0039 1.0023 1.0009 1.0030 2065.79 0.863 0.897 03-Apr-08 01:00 64 46.34 6.54 55.31 2.75 0.598 17.409 1582.05 1.0000 1.0000 1.2930 1.0045 1.0023 1.0009 1.0030 2067.13 0.863 0.906 03-Apr-08 01:15 64 45.93 6.49 55.27 2.75 0.598 17.265 1582.05 1.0000 1.0000 1.2930 1.0046 1.0023 1.0009 1.0030 2067.18 0.857 0.915 03-Apr-08 01:30 64 48.36 6.74 56.43 2.75 0.598 18.054 1582.05 1.0000 1.0000 1.2930 1.0034 1.0022 1.0009 1.0030 2064.96 0.895 0.924 03-Apr-08 01:45 64 45.31 6.58 57.47 2.75 0.598 17.267 1582.05 1.0000 1.0000 1.2930 1.0024 1.0023 1.0009 1.0030 2062.67 0.855 0.933 03-Apr-08 02:00 64 46.12 6.48 56.66 2.75 0.598 17.287 1582.05 1.0000 1.0000 1.2930 1.0032 1.0023 1.0009 1.0030 2064.37 0.857 0.94 03-Apr-08 02:15 64 47.41 6.44 56.46 2.75 0.598 17.473 1582.05 1.0000 1.0000 1.2930 1.0034 1.0022 1.0008 1.0030 2064.86 0.866 0.95 03-Apr-08 02:30 64 46.55 6.38 56.37 2.75 0.598 17.233 1582.05 1.0000 1.0000 1.2930 1.0035 1.0023 1.0008 1.0030 2064.99 0.854 0.960 03-Apr-08 02:45 64 47.10 6.38 56.19 2.75 0.598 17.335 1582.05 1.0000 1.0000 1.2930 1.0037 1.0023 1.0008 1.0030 2065.39 0.859 0.969 03-Apr-08 03:00 64 47.33 6.37 55.93 2.75 0.598 17.364 1582.05 1.0000 1.0000 1.2930 1.0039 1.0022 1.0008 1.0030 2065.94 0.861 0.978 03-Apr-08 03:15 64 47.34 6.38 55.60 2.75 0.598 17.379 1582.05 1.0000 1.0000 1.2930 1.0043 1.0022 1.0008 1.0030 2066.61 0.862 0.987 03-Apr-OS 03:30 64 46.31 6.59 55.83 2.75 0.598 17.469 1582.05 1.0000 1.0000 1.2930 1.0040 1.0022 1.0009 1.0030 2066.06 0.866 0.996 03-Apr-08 03:45 64 44.12 7.00 57.02 2.75 0.598 17.574 1582.05 1.0000 1.0000 1.2930 1.0029 1.0023 1.0010 1.0020 2063.50 0.871 1.005 03-Apr-08 04:00 64 43.72 6.81 56.45 2.75 0.598 17.255 1582.05 1.0000 1.0000 1.2930 1.0034 1.0023 1.0010 1.0020 2064.64 0.855 1.014 03-Apr-08 04:15 64 44.44 6.75 55.91 2.75 0.598 17.320 1582.05 1.0000 1.0000 1.2930 1.0040 1.0023 1.0009 1.0030 2065.77 0.859 1.023 03-Apr-08 04:30 64 44.48 6.73 54.99 2.75 0.598 17.302 1582.05 1.0000 1.0000 1.2930 1.0049 1.0023 1.0009 1.0030 2067.66 0.859 1.032 03-Apr-08 04:45 64 43.47 6.62 54.40 2.75 0.598 16.964 1582.05 1.0000 1.0000 1.2930 1.0054 1.0024 1.0009 1.0020 2068.80 0.842 1.041 03-Apr-08 05:00 64 43.68 6.64 53.69 2.75 0.598 17.030 1582.05 1.0000 1.0000 1.2930 1.0061 1.0023 1.0009 1.0030 2070.27 0.846 1.050 03-Apr-08 05:15 64 44.40 6.74 56.07 2.75 0.598 17.299 1582.05 1.0000 1.0000 1.2930 1.0038 1.0023 1.0009 1.0030 2065.45 0.858 1.058 03-Apr-08 05:30 64 42.76 6.32 55.93 2.75 0.598 16.439 1582.05 1.0000 1.0000 1.2930 1.0039 1.0024 1.0009 1.0020 2065.68 0.815 1.067 03-Apr-08 05:45 64 44.74 6.33 55.87 2.75 0.598 16.829 1582.05 1.0000 1.0000 1.2930 1.0040 1.0024 1.0009 1.0030 2065.90 0.834 1.076 03-Apr-08 06:00 64 45.47 6.22 55.48 2.75 0.598 16.817 1582.05 1.0000 1.0000 1.2930 1.0044 1.0023 1.0008 1.0030 2066.75 0.834 1.084 03-Apr-08 06:15 64 45.65 6.07 55.56 2.75 0.598 16.646 1582.05 1.0000 1.0000 1.2930 1.0043 1.0024 1.0008 1.0030 2066.61 0.826 1.093 03-Apr-08 06:30 64 45.86 5.96 55.01 2.75 0.598 16.533 1582.05 1:0000 1.0000 1.2930 1.0048 1.0024 1.0008 1.0030 2067.77 0.821 1.101 03-Apr-08 06:45 64 45.88 5.95 54.24 2.75 0.598 16.522 1582.05 1.0000 1.0000 1.2930 1.0056 1.0024 1.0008 1.0030 2069.35 0.820 1.11 03-Apr-08 07:00 64 45.71 6.18 55.01 2.75 0.598 16.807 1582.05 1.0000 1.0000 1.2930 1.0048 1.0023 1.0008 1.0030 2067.74 0.834 1.11 03-Apr-08 07:15 64 45.03 6.15 54.26 2.75 0.599 16.641 1582.05 1.0000 1.0000 1.2920 1.0056 1.0024 1.0008 1.0030 2067.51 0.826 1.127 03-Apr-08 07:30 64 46.23 6.34 54.44 2.75 0.599 17.120 1582.05 1.0000 1.0000 1.2920 1.0054 1.0023 1.0008 1.0030 2067.20 0.849 1.136 03-Apr-08 07:45 64 46.78 6.46 55.05 2.75 0.599 17.384 1582.05 1.0000 1.0000 1.2920 1.0048 1.0023 1.0009 1.0030 2065.98 0.862 1.145 03-Apr-08 08:00 64 46.60 6.31 55.01 2.75 0.599 17.148 1582.05 1.0000 1.0000 1.2920 1.0048 1.0023 1.0008 1.0030 2066.05 0.851 1.154 03-Apr-08 08:15 64 46.03 6.60 56.77 2.75 0.599 17.430 1582.05 1.0000 1.0000 1.2920 1.0031 1.0023 1.0009 1.0030 2062.42 0.863 1.163 03-Apr-08 08:30 64 45.28 6.52 56.46 2.75 0.599 17.182 1582.05 1.0000 1.0000 1.2920 1.0034 1.0023 1.0009 1.0030 2063.01 0.851 1.172 03-Apr-08 08:45 64 43.50 7.44 56.16 2.75 0.599 17.990 1582.05 1.0000 1.0000 1.2920 1.0037 1.0022 1.0011 1.0020 2063.48 0.891 1.181 03-Apr-08 09:00 64 41.95 7.01 54.53 2.75 0.599 17.148 1582.05 1.0000 1.0000 1.2920 1.0053 1.0023 1.0010 1.0020 2066.75 0.851 1.190 03-Apr-08 09:15 64 43.18 6.51 55.98 2.75 0.599 16.766 1582.05 1.0000 1.0000 1.2920 1.0039 1.0024 1.0009 1.0020 2063.87 0.831 1.199 03-Apr-08 09:30 64 43.33 6.24 55.73 2.75 0.599 16.443 1582.05 1.0000 1.0000 1.2920 1.0041 1.0024 1.0009 1.0020 2064.41 0.815 1.207 03-Apr-08 09:45 64 45.72 6.26 55.49 2.75 0.599 16.918 1582.05 1.0000 1.0000 1.2920 1.0044 1.0023 1.0008 1.0030 2065.02 0.839 1.216 03-Apr-0810:00 64 46.57 6.23 55.19 2.75 0.599 17.033 1582.05 1.0000 1.0000 1.2920 1.0047 1.0023 1.0008 1.0030 2065.70 0.845 1.225 03-Apr-0810:15 64 46.51 6.13 55.55 2.75 0.599 16.885 1582.05 1.0000 1.0000 1.2920 1.0043 1.0023 1.0008 1.0030 2064.98 0.837 1.233 03-Apr-0810:30 64 47.64 6.01 55.29 2.75 0.599 16.921 1582.05 1.0000 1.0000 1.2920 1.0046 1.0023 1.0008 1.0030 2065.60 0.839 1.242 Expro Well Testing 3 of 8 5/1/2008 GAS FLOW REPORT ® CUSTOMER :Anadarko O EXPRO START DATE: 2 Apk08 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m CorPOrat~ SEPAR ATOR GAS FA CTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches HZO) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscHd) GAS CUMM (MMscf) 03-Apr-0810:45 64 46.41 5.80 54.57 2.75 0.599 16.407 1582.05 1.0000 1.0000 1.2920 1.0053 1.0024 1.0008 1.0030 2067.00 0.814 1.251 03-Apr-0811:00 64 47.67 6.23 53.45 2.75 0.599 17.233 1582.05 1.0000 1.0000 1.2920 1.0064 1.0023 1.0008 1.0030 2069.34 0.856 1.260 03-Apr-0811:15 64 45.24 7.00 53.34 2.75 0.599 17.796 1582.05 1.0000 1.0000 1.2920 1.0065 1.0022 1.0010 1.0030 2069.34 0.884 1.269 03-Apr-0811:30 64 43.20 7.03 52.91 2.75 0.599 17.427 1582.05 1.0000 1.0000 1.2920 1.0069 1.0023 1.0010 1.0020 2070.10 0.866 1.278 03-Apr-0811:45 64 39.11 7.16 52.79 2.75 0.599 16.734 1582.05 1.0000 1.0000 1.2920 1.0070 1.0025 1.0011 1.0020 2070.20 0.832 1.286 03-Apr-0812:00 64 37.89 6.32 53.44 2.75 0.599 15.475 1582.05 1.0000 1.0000 1.2920 1.0064 1.0027 1.0010 1.0020 2068.92 0.768 1.294 03-Apr-0812:15 64 39.18 5.90 55.27 2.75 0.599 15.204 1582.05 1.0000 1.0000 1.2920 1.0046 1.0027 1.0009 1.0020 2065.26 0.754 1.30 03-Apr-0812:30 64 42.92 5.59 55.36 2.75 0.600 15.489 1582.05 1.0000 1.0000 1.2910 1.0045 1.0026 1.0008 1.0020 2063.52 0.767 1.31 03-Apr-0812:45 64 46.54 6.06 55.69 2.75 0.600 16.794 1582.05 1.0000 1.0000 1.2910 1.0042 1.0023 1.0008 1.0030 2063.00 0.832 1.319 03-Apr-0813:00 64 45.42 5.99 55.35 2.75 0.600 16.494 1582.05 1.0000 1.0000 1.2910 1.0045 1.0024 1.0008 1.0030 2063.62 0.817 1.327 03-Apr-0813:15 64 45.16 5.73 56.12 2.75 0.600 16.086 1582.05 1.0000 1.0000 1.2910 1.0038 1.0025 1.0008 1.0030 2062.08 0.796 1.336 03-Apr-0813:30 64 50.16 6.29 55.69 2.75 0.600 17.762 1582.05 1.0000 1.0000 1.2910 1.0042 1.0022 1.0008 1.0030 2063.24 0.880 1.345 03-Apr-0813:45 64 49.95 6.26 55.59 2.75 0.600 17.683 1582.05 1.0000 1.0000 1.2910 1.0043 1.0022 1.0008 1.0030 2063.43 0.876 1.354 03-Apr-0814:00 64 56.04 7.44 56.84 2.75 0.600 20.419 1582.05 1.0000 1.0000 1.2910 1.0031 1.0018 1.0008 1.0040 2061.37 1.011 1.365 03-Apr-0814:15 64 49.63 6.06 56.78 2.75 0.600 17.342 1582.05 1.0000 1.0000 1.2910 1.0031 1.0022 1.0008 1.0030 2061.01 0.858 1.373 03-Apr-0814:30 64 45.45 7.87 55.70 2.75 0.600 18.913 1582.05 1.0000 1.0000 1.2910 1.0042 1.0021 1.0011 1.0030 2062.81 0.936 1.383 03-Apr-0814:45 64 39.63 7.99 55.27 2.75 0.600 17.794 1582.05 1.0000 1.0000 1.2910 1.0046 1.0023 1.0012 1.0020 2063.44 0.882 1.392 03-Apr-0815:00 64 39.82 6.49 56.07 2.75 0.600 16.076 1582.05 1.0000 1.0000 1.2910 1.0038 1.0025 1.0010 1.0020 2061.87 0.796 1.401 03-Apr-0815:15 64 45.09 6.47 58.24 2.75 0.600 17.080 1582.05 1.0000 1.0000 1.2910 1.0017 1.0023 1.0009 1.0030 2057.68 0.844 1.409 03-Apr-0815:30 64 46.72 5.84 58.48 2.75 0.600 16.518 1582.05 1.0000 1.0000 1.2910 1.0015 1.0024 1.0008 1.0030 2057.38 0.816 1.418 03-Apr-0815:45 64 48.69 5.83 57.72 2.75 0.600 16.848 1582.05 1.0000 1.0000 1.2910 1.0022 1.0023 1.0007 1.0030 2059.05 0.833 1.427 03-Apr-0816:00 64 49.36 5.85 57.35 2.75 0.600 16.993 1582.05 1.0000 1.0000 1.2910 1.0026 1.0023 1.0007 1.0030 2059.86 0.840 1.435 03-Apr-0816:15 64 47.86 5.64 58.33 2.75 0.598 16.430 1582.05 1.0000 1.0000 1.2930 1.0016 1.0024 1.0007 1.0030 2061.21 0.813 1.444 03-Apr-0816:30 64 47.83 5.70 57.95 2.75 0.598 16.512 1582.05 1.0000 1.0000 1.2930 1.0020 1.0024 1.0007 1.0030 2061.96 0.817 1.452 03-Apr-0816:45 64 50.12 6.05 56.59 2.75 0.598 17.413 1582.05 1.0000 1.0000 1.2930 1.0033 1.0022 1.0007 1.0030 2064.84 0.863 1.461 03-Apr-0817:00 64 41.75 7.40 56.07 2.75 0.598 17.577 1582.05 1.0000 1.0000 1.2930 1.0038 1.0023 1.0011 1.0020 2065.31 0.871 1.47 03-Apr-0817:15 64 40.80 6.66 56.50 2.75 0.598 16.484 1582.05 1.0000 1.0000 1.2930 1.0034 1.0025 1.0010 1.0020 2064.44 0.817 1.47 03-Apr-0817:30 64 41.16 5.30 56.68 2.75 0.598 14.770 1582.05 1.0000 1.0000 1.2930 1.0032 1.0027 1.0008 1.0020 2064.26 0.731 1.487 03-Apr-0817:45 64 43.61 5.12 56.51 2.75 0.598 14.943 1582.05 1.0000 1.0000 1.2930 1.0034 1.0027 1.0007 1.0020 2064.75 0.740 1.494 03-Apr-0818:00 64 42.50 4.85 55.29 2.75 0.598 14.357 1582.05 1.0000 1.0000 1.2930 1.0046 1.0028 1.0007 1.0020 2067.25 0.712 1.502 03-Apr-0818:15 64 33.33 3.58 55.84 2.75 0.598 10.923 1582.05 1.0000 1.0000 1.2930 1.0040 1.0040 1.0007 1.0020 2066.84 0.541 1.507 03-Apr-0818:30 64 30.73 3.24 55.04 2.75 0.598 9.978 1582.05 1.0000 1.0000 1.2930 1.0048 1.0045 1.0006 1.0010 2069.06 0.495 1.512 03-Apr-0818:45 120 21.92 1.96 55.12 2.75 0.598 6.555 1582.05 1.0000 1.0000 1.2930 1.0047 1.0086 1.0006 1.0010 2075.56 0.326 1.516 03-Apr-0819:00 64 15.58 0.84 55.17 2.75 0.598 3.618 1582.05 1.0000 1.0000 1.2930 1.0047 1.0372 1.0003 1.0000 2132.76 0.185 1.518 03-Apr-0819:15 64 15.43 0.74 54.59 2.75 0.000 3.379 1582.05 1.0000 1.0000 1.#10 1.0052 1.0431 1.0003 1.0000 1.#J 0.000 1.518 03-Apr-0819:30 64 19.08 0.85 54.68 2.75 0.598 4.027 1582.05 1.0000 1.0000 1.2930 1.0052 1.0166 1.0003 1.0000 2091.92 0.202 1.520 03-Apr-0819:45 64 15.04 0.79 55.99 2.75 0.598 3.447 1582.05 1.0000 1.0000 1.2930 1.0039 1.0616 1.0003 1.0000 2180.94 0.180 1.522 03-Apr-08 20:00 64 14.73 0.79 58.00 2.75 0.598 3.411 1582.05 1.0000 1.0000 1.2930 1.0019 1.0000 1.0003 1.0000 2050.44 0.168 1.524 03-Apr-08 20:15 64 14.73 0.74 61.91 2.75 0.598 3.302 1582.05 1.0000 1.0000 1.2930 0.9982 1.0000 1.0003 1.0000 2042.72 0.162 1.525 03-Apr-08 20:30 64 14.73 0.80 63.83 2.75 0.598 3.433 1582.05 1.0000 1.0000 1.2930 0.9963 1.0000 1.0003 1.0000 2039.01 0.168 1.527 03-Apr-OS 20:45 64 14.75 0.75 64.82 2.75 0.598 3.326 1582.05 1.0000 1.0000 1.2930 0.9954 1.2007 1.0003 1.0000 2445.82 0.195 1.529 Expro Well Testing 4 of 8 5/1/2008 GAS FLOW REPORT CUSTOMER : Anadarko WELL NAME : Gubik #3 ® EXPRO START DATE: 2-Apr-08 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~troleum CorPOratio~ SEPA RATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pt (psia) DIFF. PRESS (inches H2O) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 03-Apr-08 21:00 64 14.73 0.78 66.15 2.75 0.598 3.390 1582.05 1.0000 1.0000 1.2930 0.9941 1.0000 1.0003 1.0000 2034.51 0.166 1.531 03-Apr-08 21:15 64 14.74 0.76 65.99. 2.75 0.598 3.347 1582.05 1.0000 1.0000 1.2930 0.9943 1.3461 1.0003 1.0000 2738.96 0.220 1.533 03-Apr-08 21:30 64 14.73 0.73 65.60 2.75 0.598 3.279 1582.05 1.0000 1.0000 1.2930 0.9947 1.5013 1.0003 1.0000 3055.86 0.240 1.536 03-Apr-08 21:45 64 14.74 0.79 66.98 2.75 0.598 3.412 1582.05 1.0000 1.0000 1.2930 0.9934 1.3413 1.0003 1.0000 2726.65 0.223 1.538 03-Apr-08 22:00 64 38.32 7.72 65.34 2.75 0.598 17.200 1582.05 1.0000 1.0000 1.2930 0.9949 1.0024 1.0012 1.0020 2046.70 0.845 1.547 03-Apr-08 22:15 64 62.41 11.65 60.05 2.75 0.598 26.964 1582.05 1.0000 1.0000 1.2930 0.9999 1.0014 1.0012 1.0040 2059.05 1.333 1.561 03-Apr-08 22:30 64 52.75 10.73 58.46 2.75 0.598 23.791 1582.05 1.0000 1.0000 1.2930 1.0015 1.0016 1.0013 1.0030 2061.30 1.177 1.57 03-Apr-08 22:45 64 38.76 12.99 56.30 2.75 0.598 22.439 1582.05 1.0000 1.0000 1.2930 1.0036 1.0018 1.0021 1.0020 2065.39 1.112 1.58 03-Apr-OS 23:00 64 37.54 12.48 55.19 2.75 0.598 21.645 1582.05 1.0000 1.0000 1.2930 1.0047 1.0019 1.0021 1.0020 2067.56 1.074 1.596 03-Apr-08 23:15 64 37.06 12.15 56.45 2.75 0.598 21.220 1582.05 1.0000 1.0000 1.2930 1.0034 1.0020 1.0020 1.0020 2064.95 1.051 1.607 03-Apr-08 23:30 64 37.47 11.30 56.63 2.75 0.598 20.577 1582.05 1.0000 1.0000 1.2930 1.0033 1.0020 1.0019 1.0020 2064.46 1.020 1.617 03-Apr-08 23:45 64 38.71 10.76 56.60 2.75 0.598 20.409 1582.05 1.0000 1.0000 1.2930 1.0033 1.0020 1.0017 1.0020 2064.42 1.011 1.628 04-Apr-08 00:00 64 39.27 10.28 56.11 2.75 0.598 20.092 1582.05 1.0000 1.0000 1.2930 1.0038 1.0020 1.0016 1.0020 2065.35 0.996 1.638 04-Apr-08 00:15 64 40.38 10.13 55.21 2.75 0.598 20.225 1582.05 1.0000 1.0000 1.2930 1.0046 1.0020 1.0015 1.0020 2067.17 1.003 1.649 04-Apr-08 00:30 64 38.87 10.45 54.27 2.75 0.600 20.154 1582.05 1.0000 1.0000 1.2910 1.0056 1.0020 1.0017 1.0020 2065.67 0.999 1.659 04-Apr-08 00:45 64 36.09 10.80 54.27 2.75 0.600 19.743 1582.05 1.0000 1.0000 1.2910 1.0056 1.0021 1.0018 1.0020 2065.75 0.979 1.669 04-Apr-OS 01:00 64 36.32 10.33 54.84 2.75 0.600 19.370 1582.05 1.0000 1.0000 1.2910 1.0050 1.0022 1.0018 1.0020 2064.54 0.960 1.679 04-Apr-08 01:15 64 37.33 9.91 55.27 2.75 0.600 19.234 1582.05 1.0000 1.0000 1.2910 1.0046 1.0022 1.0016 1.0020 2063.59 0.953 1.689 04-Apr-08 01:30 64 37.52 9.60 55.41 2.75 0.600 18.979 1582.05 1.0000 1.0000 1.2910 1.0044 1.0022 1.0016 1.0020 2063.26 0.940 1.699 04-Apr-08 01:45 64 38.10 9.38 54.77 2.75 0.600 18.904 1582.05 1.0000 1.0000 1.2910 1.0051 1.0022 1.0015 1.0020 2064.55 0.937 1.709 04-Apr-08 02:00 64 38.04 9.22 54.54 2.75 0.600 18.728 1582.05 1.0000 1.0000 1.2910 1.0053 1.0022 1.0015 1.0020 2064.99 0.928 1.718 04-Apr-08 02:15 64 38.17 9.21 55.63 2.75 0.600 18.750 1582.05 1.0000 1.0000 1.2910 1.0042 1.0022 1.0015 1.0020 2062.78 0.928 1.728 04-Apr-08 02:30 64 38.13 9.17 55.67 2.75 0.600 18.699 1582.05 1.0000 1.0000 1.2910 1.0042 1.0022 1.0015 1.0020 2062.70 0.926 1.738 04-Apr-08 02:45 64 37.08 9.07 55.86 2.75 0.600 18.339 1582.05 1.0000 1.0000 1.2910 1.0040 1.0023 1.0015 1.0020 2062.30 0.908 1.747 04-Apr-08 03:00 64 37.77 9.04 55.99 2.75 0.600 18.478 1582.05 1.0000 1.0000 1.2910 1.0039 1.0022 1.0015 1.0020 2062.03 0.914 1.757 04-Apr-08 03:15 64 37.80 8.98 55.64 2.75 0.600 18.424 1582.05 1.0000 1.0000 1.2910 1.0042 1.0023 1.0015 1.0020 2062.73 0.912 1.76 04-Apr-08 03:30 64 36.54 9.14 56.50 2.75 0.600 18.275 1582.05 1.0000 1.0000 1.2910 1.0034 1.0023 1.0015 1.0020 2061.04 0.904 1.77 04-Apr-08 03:45 64 36.31 9.03 56.28 2.75 0.600 18.107 1582.05 1.0000 1.0000 1.2910 1.0036 1.0023 1.0015 1.0020 2061.48 0.896 1.785 04-Apr-08 04:00 64 36.19 8.77 56.62 2.75 0.600 17.815 1582.05 1.0000 1.0000 1.2910 1.0033 1.0024 1.0015 1.0020 2060.77 0.881 1.794 04-Apr-08 04:15 64 37.25 8.71 57.00 2.75 0.599 18.012 1582.05 1.0000 1.0000 1.2920 1.0029 1.0023 1.0014 1.0020 2061.69 0.891 1.803 04-Apr-08 04:30 64 38.22 8.44 56.20 2.75 0.599 17.960 1582.05 1.0000 1.0000 1.2920 1.0037 1.0023 1.0014 1.0020 2063.28 0.889 1.813 04-Apr-08 04:45 64 38.89 8.56 55.62 2.75 0.599 18.246 1582.05 1.0000 1.0000 1.2920 1.0042 1.0023 1.0014 1.0020 2064.46 0.904 1.822 04-Apr-08 05:00 64 37.03 8.59 57.41 2.75 0.599 17.835 1582.05 1.0000 1.0000 1.2920 1.0025 1.0023 1.0014 1.0020 2060.84 0.882 1.831 04-Apr-OS 05:15 64 37.37 8.67 56.51 2.75 0.599 18.000 1582.05 1.0000 1.0000 1.2920 1.0034 1.0023 1.0014 1.0020 2062.67 0.891 1.840 04-Apr-08 05:30 64 37.65 8.57 56.11 2.75 0.599 17.963 1582.05 1.0000 1.0000 1.2920 1.0038 1.0023 1.0014 1.0020 2063.47 0.889 1.850 04-Apr-08 05:45 64 37.27 8.66 55.79 2.75 0.599 17.965 1582.05 1.0000 1.0000 1.2920 1.0041 1.0023 1.0014 1.0020 2064.13 0.890 1.859 04-Apr-08 06:00 64 36.65 8.56 56.10 2.75 0.599 17.712 1582.05 1.0000 1.0000 1.2920 1.0038 1.0024 1.0014 1.0020 2063.49 0.877 1.868 04-Apr-08 06:15 64 34.36 8.08 55.77 2.75 0.599 16.662 1582.05 1.0000 1.0000 1.2920 1.0041 1.0026 1.0015 1.0020 2064.21 0.825 1.877 04-Apr-08 06:30 64 35.00 8.24 55.40 2.75 0.599 16.982 1582.05 1.0000 1.0000 1.2920 1.0044 1.0025 1.0015 1.0020 2064.93 0.842 1.885 04-Apr-08 06:45 64 35.96 8.32 55.12 2.75 0.599 17.297 1582.05 1.0000 1.0000 1.2920 1.0047 1.0024 1.0014 1.0020 2065.49 0.858 1.894 04-Apr-08 06:46 64 34.82 7.80 55.12 2.75 0.599 16.480 1582.05 1.0000 1.0000 1.2920 1.0047 1.0026 1.0014 1.0020 2065.49 0.817 1.895 Expro Well Testing 5 of 8 5/1/2008 GAS FLOW REPORT CUSTOMER :Anadarko EXPRO START ATE: 2-Apk08 END DATE: 4-Apr-OS TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park ~m CorPOratio~ SEPA RATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches HZO) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 04-Apr-08 06:47 64 32.86 7.62 54.93 2.75 0.599 15.824 1582.05 1.0000 1.0000 1.2920 1.0049 1.0028 1.0014 1.0020 2065.98 0.785 1.895 04-Apr-08 06:48 64 33.00 7.58 54.95 2.75 0.599 15.816 1582.05 1.0000 1.0000 1.2920 1.0049 1.0028 1.0014 1.0020 2065.94 0.784 1.896 04-Apr-08 06:49 64 33.46 7.85 55.13 2.75 0.599 16.207 1582.05 1.0000 1.0000 1.2920 1.0047 1.0027 1.0014 1.0020 2065.54 0.804 1.897 04-Apr-08 06:50 64 33.15 7.69 54.84 2.75 0.599 15.966 1582.05 1.0000 1.0000 1.2920 1.0050 1.0027 1.0014 1.0020 2066.16 0.792 1.897 04-Apr-08 06:51 64 33.32 7.36 54.82 2.75 0.599 15.660 1582.05 1.0000 1.0000 1.2920 1.0050 1.0028 1.0014 1.0020 2066.17 0.777 1.898 04-Apr-08 06:52 64 27.88 6.37 54.40 2.75 0.599 13.326 1582.05 1.0000 1.0000 1.2920 1.0054 1.0035 1.0014 1.0010 2067.73 0.661 1.898 04-Apr-08 06:53 64 24.85 5.63 54.06 2.75 0.599 11.828 1582.05 1.0000 1.0000 1.2920 1.0058 1.0043 1.0014 1.0010 2069.40 0.587 1.89 04-Apr-08 06:54 64 22.51 4.57 53.73 2.75 0.599 10.143 1582.05 1.0000 1.0000 1.2920 1.0061 1.0054 1.0013 1.0010 2071.68 0.504 1.89 04-Apr-08 06:55 64 24.62 5.17 54.45 2.75 0.599 11.282 1582.05 1.0000 1.0000 1.2920 1.0054 1.0045 1.0013 1.0010 2068.85 0.560 1.899 04-Apr-08 06:56 64 37.33 9.14 56.66 2.75 0.599 18.471 1582.05 1.0000 1.0000 1.2920 1.0032 1.0023 1.0015 1.0020 2062.40 0.914 1.900 04-Apr-08 06:57 64 42.25 10.87 56.39 2.75 0.599 21.430 1582.05 1.0000 1.0000 1.2920 1.0035 1.0019 1.0016 1.0020 2063.20 1.061 1.901 04-Apr-08 06:58 64 41.14 10.66 55.38 2.75 0.599 20.942 1582.05 1.0000 1.0000 1.2920 1.0045 1.0019 1.0016 1.0020 2065.19 1.038 1.901 04-Apr-OS 06:59 64 40.18 10.71 55.25 2.75 0.599 20.744 1582.05 1.0000 1.0000 1.2920 1.0046 1.0020 1.0016 1.0020 2065.45 1.028 1.902 04-Apr-08 07:00 64 41.20 10.53 55.36 2.75 0.599 20.829 1582.05 1.0000 1.0000 1.2920 1.0045 1.0019 1.0016 1.0020 2065.22 1.032 1.903 04-Apr-08 07:15 64 36.48 9.51 56.10 2.75 0.599 18.626 1582.05 1.0000 1.0000 1.2920 1.0038 1.0023 1.0016 1.0020 2063.58 0.922 1.912 04-Apr-08 07:30 64 35.56 8.88 56.50 2.75 0.599 17.770 1582.05 1.0000 1.0000 1.2920 1.0034 1.0024 1.0015 1.0020 2062.75 0.880 1.922 04-Apr-08 07:45 64 36.65 8.61 56.58 2.75 0.599 17.764 1582.05 1.0000 1.0000 1.2920 1.0033 1.0024 1.0015 1.0020 2062.54 0.879 1.931 04-Apr-08 08:00 64 36.20 8.34 54.73 2.75 0.599 17.375 1582.05 1.0000 1.0000 1.2920 1.0051 1.0024 1.0014 1.0020 2066.28 0.862 1.940 04-Apr-08 08:15 64 34.48 7.89 55.24 2.75 0.599 16.494 1582.05 1.0000 1.0000 1.2920 1.0046 1.0026 1.0014 1.0020 2065.27 0.818 1.948 04-Apr-08 08:30 64 35.65 8.16 55.53 2.75 0.599 17.056 1582.05 1.0000 1.0000 1.2920 1.0043 1.0025 1.0014 1.0020 2064.64 0.845 1.957 04-Apr-08 08:45 64 34.57 8.23 56.85 2.75 0.599 16.867 1582.05 1.0000 1.0000 1.2920 1.0030 1.0025 1.0015 1.0020 2062.02 0.835 1.966 04-Apr-08 09:00 64 35.33 7.97 57.28 2.75 0.599 16.780 1582.05 1.0000 1.0000 1.2920 1.0026 1.0025 1.0014 1.0020 2061.11 0.830 1.974 04-Apr-08 09:15 64 37.53 7.99 57.22 2.75 0.598 17.317 1582.05 1.0000 1.0000 1.2930 1.0027 1.0024 1.0013 1.0020 2062.91 0:857 1.983 04-Apr-08 09:30 64 38.14 8.01 57.87 2.75 0.598 17.479 1582.05 1.0000 1.0000 1.2930 1.0021 1.0024 1.0013 1.0020 2061.61 0.865 1.992 04-Apr-08 09:45 64 37.79 7.77 57.71 2.75 0.598 17.136 1582.05 1.0000 1.0000 1.2930 1.0022 1.0024 1.0013 1.0020 2061.92 0.848 2.001 04-Apr-0810:00 64 38.51 7.78 57.04 2.75 0.598 17.309 1582.05 1.0000 1.0000 1.2930 1.0029 1.0024 1.0012 1.0020 2063.27 0.857 2.01 04-Apr-0810:15 64 39.55 7.68 56.78 2.75 0.598 17.428 1582.05 1.0000 1.0000 1.2930 1.0031 1.0023 1.0012 1.0020 2063.80 0.863 2.01 04-Apr-0810:30 64 39.30 7.61 57.23 2.75 0.598 17.294 1582.05 1.0000 1.0000 1.2930 1.0027 1.0024 1.0012 1.0020 2062.90 0.856 2.028 04-Apr-0810:45 64 37.92 7.61 57.68 2.75 0.598 16.987 1582.05 1.0000 1.0000 1.2930 1.0022 1.0024 1.0012 1.0020 2061.98 0.841 2.037 04-Apr-0811:00 64 39.00 7.68 58.37 2.75 0.598 17.307 1582.05 1.0000 1.0000 1.2930 1.0016 1.0024 1.0012 1.0020 2060.60 0.856 2.046 04-Apr-0811:15 64 39.41 7.64 57.68 2.75 0.598 17.352 1582.05 1.0000 1.0000 1.2930 1.0022 1.0024 1.0012 1.0020 2061.98 0.859 2.055 04-Apr-0811:30 64 37.74 7.89 58.24 2.75 0.598 17.256 1582.05 1.0000 1.0000 1.2930 1.0017 1.0024 1.0013 1.0020 2060.85 0.853 2.063 04-Apr-0811:45 64 37.44 7.79 58.33 2.75 0.598 17.078 1582.05 1.0000 1.0000 1.2930 1.0016 1.0024 1.0013 1.0020 2060.68 0.845 2.072 04-Apr-0812:00 64 37.00 7.67 58.77 2.75 0.598 16.846 1582.05 1.0000 1.0000 1.2930 1.0012 1.0025 1.0013 1.0020 2059.79 0.833 2.081 04-Apr-0812:15 64 37.01 7.73 58.40 2.75 0.598 16.914 1582.05 1.0000 1.0000 1.2930 1.0015 1.0025 1.0013 1.0020 2060.55 0.837 2.090 04-Apr-0812:30 64 36.29 7.60 59.07 2.75 0.598 16.607 1582.05 1.0000 1.0000 1.2930 1.0009 1.0025 1.0013 1.0020 2059.19 0.821 2.098 04-Apr-0812:45 64 37.30 7.85 58.77 2.75 0.598 17.112 1582.05 1.0000 1.0000 1.2930 1.0012 1.0024 1.0013 1.0020 2059.80 0.846 2.107 04-Apr-0813:00 64 37.32 7.95 58.71 2.75 0.598 17.225 1582.05 1.0000 1.0000 1.2930 1.0012 1.0024 1.0013 1.0020 2059.91 0.851 2.116 04-Apr-0813:15 64 35.62 8.65 58.36 2.75 0.598 17.553 1582.05 1.0000 1.0000 1.2930 1.0016 1.0024 1.0015 1.0020 2060.69 0.868 2.125 04-Apr-0813:30 64 33.69 8.76 57.57 2.75 0.598 17.179 1582.05 1.0000 1.0000 1.2930 1.0023 1.0025 1.0016 1.0020 2062.37 0.851 2.134 04-Apr-0813:31 64 23.66 5.74 56.60 2.75 0.598 11.654 1582.05 1.0000 1.0000 1.2930 1.0033 1.0045 1.0015 1.0010 2066.46 0.578 2.134 Expro Well Testing 6 of 8 5/1/2008 GAS FLOW REPORT CUSTOMER : Anadarko TEST No. :Flow #2 - Nanushuk RePerf ® WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel EXPRO START DATE: 2-Apr-08 EXPRO SUPERVISOR : T. Stone / T. Park END DATE: 4-Apr-08 Petroleum Corporation SEPAR ATOR GAS FA CTORS DATE & TIME dd-mmm- hh:mm ( YY ) CHOKE SIZE 64ths ( ) Pf sic (P ) DIFF. PRESS (inches H O z ) GAS TEMP F (°) ORIFICE SIZE inches (~ ) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 04-Apr-0813:32 64 20.67 4.02 56.39 2.75 0.598 9.116 1582.05 1.0000 1.0000 1.2930 1.0035 1.0066 1.0012 1.0010 2070.05 0.453 2.135 04-Apr-0813:33 64 19.43 3.33 56.57 2.75 0.598 8.044 1582.05 1.0000 1.0000 1.2930 1.0033 1.0081 1.0011 1.0000 2072.35 0.400. 2.135 04-Apr-0813:34 64 20.86 3.42 56.91 2.75 0.598 8.446 1582.05 1.0000 1.0000 1.2930 1.0030 1.0070 1.0010 1.0010 2069.56 0.419 2.135 04-Apr-0813:35 64 21.13 3.67 57.24 2.75 0.598 8.806 1582.05 1.0000 1.0000 1.2930 1.0027 1.0067 1.0011 1.0010 2068.26 0.437 2.135 04-Apr-0813:36 64 21.71 4.38 57.87 2.75 0.598 9.751 1582.05 1.0000 1.0000 1.2930 1.0021 1.0058 1.0012 1.0010 2065.78 0.483 2.136 04-Apr-0813:37 64 24.22 4.56 58.10 2.75 0.598 10.509 1582.05 1.0000 1.0000 1.2930 1.0018 1.0049 1.0012 1.0010 2063.69 0.520 2.136 04-Apr-0813:38 64 25.20 4.98 57.93 2.75 0.598 11.202 1582.05 1.0000 1.0000 1.2930 1.0020 1.0045 1.0012 1.0010 2063.43 0.554 2.13 04-Apr-0813:39 64 24.52 4.97 57.91 2.75 0.598 11.039 1582.05 1.0000 1.0000 1.2930 1.0020 1.0046 1.0013 1.0010 2063.72 0.547 2.13 04-Apr-0813:40 64 25.16 4.88 57.71 2.75 0.598 11.081 1582.05 1.0000 1.0000 1.2930 1.0022 1.0045 1.0012 1.0010 2063.92 0.549 2.137 04-Apr-0813:41 64 25.46 5.15 57.98 2.75 0.598 11.451 1582.05 1.0000 1.0000 1.2930 1.0019 1.0044 1.0012 1.0010 2063.15 0.567 2.138 04-Apr-0813:42 64 40.66 11.85 60.56 2.75 0.598 21.950 1582.05 1.0000 1.0000 1.2930 0.9995 1.0019 1.0018 1.0020 2056.62 1.084 2.138 04-Apr-0813:43 64 50.67 20.41 60.74 2.75 0.598 32.159 1582.05 1.0000 1.0000 1.2930 0.9993 1.0012 1.0025 1.0030 2058.03 1.589 2.140 04-Apr-0813:44 64 49.94 20.20 60.21 2.75 0.598 31.761 1582.05 1.0000 1.0000 1.2930 0.9998 1.0012 1.0025 1.0030 2059.03 1.570 2.141 04-Apr-0813:45 64 46.28 19.26 60.05 2.75 0.598 29.856 1582.05 1.0000 1.0000 1.2930 0.9999 1.0013 1.0026 1.0030 2059.07 1.475 2.142 04-Apr-0813:46 64 43.67 17.98 59.88 2.75 0.598 28.021 1582.05 1.0000 1.0000 1.2930 1.0001 1.0014 1.0025 1.0020 2059.13 1.385 2.143 04-Apr-0813:47 64 40.97 16.54 59.51 2.75 0.598 26.032 1582.05 1.0000 1.0000 1.2930 1.0005 1.0016 1.0025 1.0020 2059.59 1.287 2.143 04-Apr-0813:48 64 38.50 15.61 59.79 2.75 0.598 24.515 1582.05 1.0000 1.0000 1.2930 1.0002 1.0017 1.0025 1.0020 2058.88 1.211 2.144 04-Apr-0813:49 64 36.79 14.16 60.03 2.75 0.598 22.824 1582.05 1.0000 1.0000 1.2930 1.0000 1.0018 1.0024 1.0020 2058.15 1.127 2.145 04-Apr-0813:50 64 35.33 13.41 59.92 2.75 0.598 21.766 1582.05 1.0000 1.0000 1.2930 1.0001 1.0020 1.0023 1.0020 2058.31 1.075 2.146 04-Apr-0813:51 64 35.10 12.70 59.85 2.75 0.598 21.113 1582.05 1.0000 1.0000 1.2930 1.0001 1.0020 1.0022 1.0020 2058.31 1.043 2.147 04-Apr-0813:52 64 34.66 11.59 60.03 2.75 0.598 20.043 1582.05 1.0000 1.0000 1.2930 1.0000 1.0021 1.0021 1.0020 2057.77 0.990 2.147 04-Apr-0813:53 64 33.67 11.16 60.21 2.75 0.598 19.384 1582.05 1.0000 1.0000 1.2930 0.9998 1.0022 1.0020 1.0020 2057.40 0.957 2.148 04-Apr-0813:54 64 33.72 10.84 60.05 2.75 0.598 19.119 1582.05 1.0000 1.0000 1.2930 1.0000 1.0023 1.0020 1.0020 2057.67 0.944 2.149 04-Apr-0813:55 64 32.02 10.16 59.93 2.75 0.598 18.037 1582.05 1.0000 1.0000 1.2930 1.0001 1.0024 1.0020 1.0010 2057.94 0.891 2.149 04-Apr-0813:56 64 31.35 9.88 60.24 2.75 0.598 17.599 1582.05 1.0000 1.0000 1.2930 0.9998 1.0025 1.0019 1.0010 2057.35 0.869 2.150 04-Apr-0813:57 64 31.44 9.68 60.27 2.75 0.598 17.445 1582.05 1.0000 1.0000 1.2930 0.9997 1.0025 1.0019 1.0010 2057.25 0.861 2.15 04-Apr-0813:58 64 31.33 9.49 59.98 2.75 0.598 17.243 1582.05 1.0000 1.0000 1.2930 1.0000 1.0026 1.0019 1.0010 2057.82 0.851 2.15 04-Apr-0813:59 64 30.31 9.50 59.94 2.75 0.598 16.969 1582.05 1.0000 1.0000 1.2930 1.0001 1.0027 1.0019 1.0010 2058.03 0.838 2.152 04-Apr-0814:00 64 31.33 9.31 59.41 2.75 0.598 17.079 1582.05 1.0000 1.0000 1.2930 1.0006 1.0026 1.0018 1.0010 2058.94 0.844 2.152 04-Apr-0814:15 64 31.23 9.44 59.91 2.75 0.594 17.170 1582.05 1.0000 1.0000 1.2970 1.0001 1.0026 1.0019 1.0010 2064.86 0.851 2.161 04-Apr-0814:30 64 31.99 9.60 60.61 2.75 0.594 17.524 1582.05 1.0000 1.0000 1.2970 0.9994 1.0025 1.0019 1.0010 2063.40 0.868 2.170 04-Apr-0814:45 64 32.82 8.80 58.70 2.75 0.594 16.995 1582.05 1.0000 1.0000 1.2970 1.0012 1.0026 1.0017 1.0020 2067.06 0.843 2.179 04-Apr-0815:00 64 31.15 7.94 58.27 2.75 0.594 15.727 1582.05 1.0000 1.0000 1.2970 1.0017 1.0028 1.0016 1.0010 2068.02 0.780 2.187 04-Apr-0815:01 64 22.68 4.82 58.02 2.75 0.594 10.456 1582.05 1.0000 1.0000 1.2970 1.0019 1.0052 1.0013 1.0010 2071.43 0.520 2.187 04-Apr-0815:02 64 22.74 4.43 58.37 2.75 0.594 10.037 1582.05 1.0000 1.0000 1.2970 1.0016 1.0054 1.0012 1.0010 2070.95 0.499 2.188 04-Apr-0815:03 64 23.03 4.29 58.31 2.75 0.594 9.940 1582.05 1.0000 1.0000 1.2970 1.0016 1.0054 1.0011 1.0010 2070.98 0.494 2.188 04-Apr-0815:04 64 21.76 4.10 58.39 2.75 0.594 9.445 1582.05 1.0000 1.0000 1.2970 1.0016 1.0060 1.0012 1.0010 2071.87 0.470 2.188 04-Apr-0815:05 64 20.96 3.94 58.80 2.75 0.594 9.087 1582.05 1.0000 1.0000 1.2970 1.0012 1.0065 1.0012 1.0010 2071.94 0.452 2.189 04-Apr-0815:06 64 20.52 3.89 58.99 2.75 0.594 8.934 1582.05 1.0000 1.0000 1.2970 1.0010 1.0068 1.0012 1.0000 2072.08 0.444 2.189 04-Apr-0815:07 64 20.31 3.62 58.63 2.75 0.594 8.575 1582.05 1.0000 1.0000 1.2970 1.0013 1.0072 1.0011 1.0000 2073.41 0.427 2.189 04-Apr-0815:08 64 20.02 3.57 58.87 2.75 0.594 8.454 1582.05 1.0000 1.0000 1.2970 1.0011 1.0074 1.0011 1.0000 2073.38 0.421 2.190 Expro Well Testing 7 of 8 5/1/2008 GAS FLOW REPORT ® CUSTOMER :Anadarko O EXPRO START DATE: 2-Apr O8 END DATE: 4-Apr-08 TEST No. :Flow #2 - Nanushuk RePerf CUSTOMER REP. :Dennis McDaniel ~~ EXPRO SUPERVISOR : T. Stone / T. Park Petroleum Corporation SEPA RATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches HZO) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg FtF Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 04-Apr-0815:09 64 19.39 3.50 58.82 2.75 0.594 8.238 1582.05 1.0000 1.0000 1.2970 1.0011 1.0080 1.0011 1.0000 2074.56 0.410 2.190 04-Apr-0815:10 64 19.56 3.44 58.91 2.75 0.594 8.203 1582.05 1.0000 1.0000 1.2970 1.0011 1.0079 1.0011 1.0000 2074.19 0.408 2.190 04-Apr-0815:11 64 19.73 3.32 59.38 2.75 0.594 8.093 1582.05 1.0000 1.0000 1.2970 1.0006 1.0079 1.0010 1.0000 2073.19 0.403 2.190 04-Apr-0815:12 64 19.33 3.33 59.16 2.75 0.594 8.023 1582.05 1.0000 1.0000 1.2970 1.0008 1.0082 1.0011 1.0000 2074.26 0.399 2.191 04-Apr-0815:13 64 19.39 3.17 59.27 2.75 0.594 7.840 1582.05 1.0000 1.0000 1.2970 1.0007 1.0084 1.0010 1.0000 2074.26 0.390 2.191 04-Apr-0815:14 64 19.41 3.23 59.36 2.75 0.594 7.918 1582.05 1.0000 1.0000 1.2970 1.0006 1.0083 1.0010 1.0000 2073.93 0.394 2.191 04-Apr-0815:15 64 20.04 3.13 59.45 2.75 0.594 7.920 1582.05 1.0000 1.0000 1.2970 1.0005 1.0079 1.0010 1.0000 2072.94 0.394 2.19 04-Apr-0815:16 64 20.94 3.26 59.56 2.75 0.594 8.262 1582.05 1.0000 1.0000 1.2970 1.0004 1.0072 1.0010 1.0010 2071.34 0.411 2.19 04-Apr-0815:17 64 20.58 3.00 59.54 2.75 0.594 7.857 1582.05 1.0000 1.0000 1.2970 1.0004 1.0077 1.0009 1.0000 2072.29 0.390 2.192 04-Apr-0815:18 64 20.60 2.93 59.69 2.75 0.594 7.769 1582.05 1.0000 1.0000 1.2970 1.0003 1.0078 1.0009 1.0000 2072.11 0.386 2.192 04-Apr-0815:19 64 21.06 3.06 59.64 2.75 0.594 8.028 1582.05 1.0000 1.0000 1.2970 1.0003 1.0073 1.0009 1.0010 2071.42 0.399 2.193 04-Apr-0815:20 64 20.27 3.20 59.75 2.75 0.594 8.054 1582.05 1.0000 1.0000 1.2970 1.0002 1.0077 1.0010 1.0000 2071.89 0.401 2.193 04-Apr-0815:21 64 20.33 3.13 59.75 2.75 0.594 7.977 1582.05 1.0000 1.0000 1.2970 1.0002 1.0077 1.0010 1.0000 2071.92 0.397 2.193 04-Apr-0815:22 64 19.45 2.97 60.05 2.75 0.594 7.600 1582.05 1.0000 1.0000 1.2970 1.0000 1.0086 1.0009 1.0000 2073.04 0.378 2.193 Expro Well Testing 8 of 8 5/1/2008 PRODUCTION TANK DATA SHEET CUSTOMER : Anadarko WELL NAME : Gubik #3 Total Fluid Production: 19.82 bbls Total Oil Production: 0.00 bbls START DATE: 02-Apr-08 Total Water Production: 19.82 bbls END DATE: 04-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf Petroleum Corporation Start End Tank Previous Strap Current Strap Fluid Inc. BS BW H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date 8~ Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 02-Apr-08 03:00 02-Apr-08 03:30 1 4.00 7.25 4.00 7.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 03:30 02-Apr-08 04:00 1 4.00 7.25 4.00 7.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 04:00 02-Apr-08 04:30 2 2.00 1.25 2.00 1.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 04:30 02-Apr-08 05:00 1 4.00 7.25 4.00 7.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 05:00 02-Apr-08 05:30 2 2.00 1.25 2.00 1.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 05:30 02-Apr-08 06:00 1 4.00 7.25 4.00 7.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 06:00 02-Apr-08 11:30 1 4.00 7.25 4.00 7.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 11:30 02-Apr-08 12:00 2 2.00 1.25 2.00 1.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 0.00 0.00 02-Apr-08 12:00 02-Apr-08 12:30 1 4.00 7.25 4.00 7.50 0.42 0.00% 100.00% 0.42 0.42 20.00 0.00 0.00 0.00 02-Apr-08 12:30 02-Apr-08 13:00 2 2.00 1.25 2.00 1.50 0.42 0.00% 100.00% 0.42 0.83 20.00 0.00 0.00 0.00 02-Apr-08 13:00 02-Apr-08 13:30 1 4.00 7.50 4.00 8.00 0.83 0.00% 100.00% 0.83 1.67 40.01 0.00 0.00 0.00 02-Apr-08 13:30 02-Apr-08 14:00 2 2.00 1.50 2.00 1.50 0.00 3.00% 97.00% 0.00 1.67 0.00 0.00 0.00 0.00 02-Apr-08 14:00 02-Apr-08 14:30 1 4.00 8.00 4.00 8.00 0.00 3.00% 97.00% 0.00 1.67 0.00 0.00 0.00 0.00 02-Apr-08 14:30 02-Apr-08 15:00 2 2.00 1.50 2.00 2.00 0.83 3.00% 97.00% 0.81 2.48 38.81 0.00 0.00 0.00 02-Apr-08 15:00 02-Apr-08 15:30 1 4.00 8.00 4.00 8.00 0.00 3.00% 97.00% 0.00 2.48 0.00 0.00 0.00 0.00 02-Apr-08 15:30 02-Apr-08 16:00 2 2.00 2.20 2.00 2.50 0.83 3.00% 97.00% 0.81 3.28 38.81 0.00 0.00 0.00 02-Apr-08 16:00 02-Apr-08 16:30 1 4.00 8.00 4.00 8.25 0.42 3.00% 97.00% 0.40 3.69 19.40 0.00 0.00 0.00 02-Apr-08 16:30 02-Apr-08 17:00 2 2.00 2.50 2.00 2.50 0.00 3.00% 97.00% 0.00 3.69 0.00 0.00 0.00 0.00 02-Apr-08 17:00 02-Apr-08 17:30 1 4.00 8.25 4.00 8.25 0.00 3.00% 97.00% 0.00 3.69 0.00 0.00 0.00 0.00 02-Apr-08 17:30 02-Apr-08 18:00 2 2.00 2.50 2.00 2.75 0.42 3.00% 97.00% 0.40 4.09 19.40 0.00 0.00 0.00 02-Apr-08 18:00 02-Apr-08 18:30 1 4.00 8.25 4.00 8.50 0.42 0.00% 100.00% 0.42 4.51 20.00 0.00 0.00 0.00 02-Apr-08 18:30 02-Apr-08 19:00 2 2.00 2.75 2.00 3.00 0.42 0.00% 100.00% 0.42 4.93 20.00 0.00 0.00 0.00 02-Apr-08 19:00 02-Apr-08 19:30 1 4.00 8.50 4.00 8.75 0.42 0.00% 100.00% 0.42 5.34 20.00 0.00 0.00 0.00 02-Apr-08 19:30 02-Apr-08 20:00 2 2.00 3.00 2.00 3.00 0.00 0.00% 0.00% 0.00 5.34 0.00 0.00 0.00 0.00 02-Apr-08 20:00 02-Apr-08 20:30 1 4.00 8.75 4.00 8.75 0.00 0.00% 0.00% 0.00 5.34 0.00 0.00 0.00 0.00 02-Apr-08 20:30 02-Apr-08 21:00 2 2.00 3.00 2.00 3.50 0.83 0.00% 100.00% 0.83 6.18 40.01 0.00 0.00 0.00 02-Apr-08 21:00 02-Apr-08 21:30 1 4.00 8.75 4.00 9.00 0.42 0.00% 100.00% 0.42 6.59 20.00 0.00 0.00 0.00 02-Apr-08 21:30 02-Apr-08 22:00 2 2.00 3.75 2.00 3.75 0.00 0.00% 0.00% 0.00 6.59 0.00 0.00 0.00 0.00 02-Apr-08 22:00 02-Apr-08 22:30 1 4.00 9.00 4.00 9.25 0.42 0.00% 100.00% 0.42 7.01 20.00 0.00 0.00 0.00 02-Apr-08 22:30 02-Apr-08 23:00 2 2.00 3.75 2.00 3.75 0.00 0.00% 0.00% 0.00 7.01 0.00 0.00 0.00 0.00 02-Apr-08 23:00 02-Apr-08 23:30 1 4.00 9.25 4.00 9.50 0.42 2.00% 98.00% 0.41 7.42 19.60 0.00 0.00 0.00 02-Apr-08 23:30 03-Apr-08 00:00 2 2.00 3.75 2.00 4.00 0.42 0.00% 100.00% 0.42 7.83 20.00 0.00 0.00 0.00 03-Apr-08 00:00 03-Apr-08 00:30 1 4.00 9.50 4.00 9.50 0.00 0.00% 0.00% 0.00 7.83 0.00 0.00 0.00 0.00 03-Apr-08 00:30 03-Apr-08 01:00 2 2.00 4.00 2.00 4.25 0.42 0.00% 100.00% 0.42 8.25 20.00 0.00 0.00 0.00 03-Apr-08 01:00 03-Apr-08 01:30 1 4.00 9.50 4.00 9.50 0.00 0.00% 0.00% 0.00 8.25 0.00 0.00 0.00 0.00 03-Apr-08 01:30 03-Apr-08 02:00 1 4.00 9.50 4.00 9.75 0.42 0.00% 100.00% 0.42 8.67 20.00 0.00 0.00 0.00 r Expro Well Testing 1 of 3 5/1/2008 PRODUCTION TANK DATA SHEET CUSTOMER :Anadarko Total Fluid Production: 19.82 bbls © WELL NAME : Gubik #3 Total Oil Production: 0.00 bbls START DATE: 02-Apr-08 Total Water Production: 19.82 bbls END DATE: 04-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf ~nada~~ ~ Petroleum Corporation Start End Tank Previous Strap Current Strap Fluid Inc. BS &W H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date & Time Date 8~ Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 03-Apr-08 02:00 03-Apr-08 02:30 2 2.00 4.25 2.00 4.25 0.00 0.00% 100.00% 0.00 8.67 0.00 0.00 0.00 0.00 03-Apr-08 02:30 03-Apr-OS 03:00 1 4.00 9.75 4.00 10.00 0.42 0.00% 100.00% 0.42 9.09 20.00 0.00 0.00 0.00 03-Apr-08 03:00 03-Apr-08 03:30 2 2.00 4.25 2.00 4.25 0.00 0.00% 0.00% 0.00 9.09 0.00 0.00 0.00 0.00 03-Apr-08 03:30 03-Apr-08 04:00 1 4.00 10.00 4.00 10.25 0.42 0.00% 100.00% 0.42 9.50 20.00 0.00 0.00 0.00 03-Apr-08 04:00 03-Apr-08 04:30 2 2.00 4.25 2.00 4.50 0.42 0.00% 100.00% 0.42 9.92 20.00 0.00 0.00 0.00 03-Apr-08 04:30 03-Apr-08 05:00 1 4.00 10.25 4.00 10.25 0.00 0.00% 100.00% 0.00 9.92 0.00 0.00 0.00 0.00 03-Apr-08 05:00 03-Apr-08 05:30 2 2.00 4.50 2.00 4.50 0.00 0.00% 100.00% 0.00 9.92 0.00 0.00 0.00 0.00 03-Apr-08 05:30 03-Apr-08 06:00 1 4.00 10.25 4.00 10.25 0.00 0.00% 100.00% 0.00 9.92 0.00 0.00 0.00 0.00 03-Apr-OS 06:00 03-Apr-08 06:30 2 2.00 4.50 2.00 4.50 0.00 0.00% 100.00% 0.00 9.92 0.00 0.00 0.00 0.00 03-Apr-08 06:30 03-Apr-OS 07:30 1 4.00 10.25 4.00 10.25 0.00 0.00% 100.00% 0.00 9.92 0.00 0.00 0.00 0.00 03-Apr-08 07:30 03-Apr-08 08:30 2 2.00 4.50 2.00 5.00 0.83 2.00% 98.00% 0.82 10.74 19.60 0.00 0.00 0.00 03-Apr-08 08:30 03-Apr-08 09:30 1 4.00 10.25 4.00 10.25 0.00 2.00% 98.00% 0.00 10.74 0.00 0.00 0.00 0.00 03-Apr-08 09:30 03-Apr-08 10:30 2 2.00 5.00 2.00 5.00 0.00 2.00% 98.00% 0.00 10.74 0.00 0.00 0.00 0.00 03-Apr-08 10:30 03-Apr-08 11:30 1 4.00 10.25 4.00 10.25 0.00 0.00% 100.00% 0.00 10.74 0.00 0.00 0.00 0.00 03-Apr-08 11:30 03-Apr-08 12:30 2 2.00 5.00 2.00 5.00 0.00 0.00% 100.00% 0.00 10.74 0.00 0.00 0.00 0.00 03-Apr-08 12:30 03-Apr-08 13:30 1 4.00 10.25 4.00 10.25 0.00 0.00% 100.00% 0.00 10.74 0.00 0.00 0.00 0.00 03-Apr-08 13:30 03-Apr-08 14:30 2 2.00 5.00 2.00 5.75 1.25 0.50% 99.50% 1.24 11.98 29.86 0.00 0.00 0.00 03-Apr-08 14:30 03-Apr-08 15:30 1 4.00 10.25 4.00 10.50 0.42 0.50% 99.50% 0.41 12.39 9.95 0.00 0.00 0.00 03-Apr-08 15:30 03-Apr-08 16:30 2 2.00 5.75 2.00 6.00 0.42 0.50% 99.50% 0.41 12.81 9.95 0.00 0.00 0.00 03-Apr-08 16:30 03-Apr-08 17:30 1 4.00 10.50 4.00 10.75 0.42 0.50% 99.50% 0.41 13.22 9.95 0.00 0.00 0.00 03-Apr-08 17:30 03-Apr-08 18:30 2 2.00 6.00 2.00 6.25 0.42 0.75% 99.25% 0.41 13.64 9.93 0.00 0.00 0.00 03-Apr-08 18:30 03-Apr-08 19:30 1 4.00 10.75 4.00 10.75 0.00 0.00% 0.00% 0.00 13.64 0.00 0.00 0.00 0.00 03-Apr-08 19:30 03-Apr-08 20:30 2 2.00 6.25 2.00 6.50 0.42 0.00% 100.00% 0.42 14.05 10.00 0.00 0.00 0.00 03-Apr-08 20:30 03-Apr-08 21:30 1 4.00 10.75 4.00 11.00 0.42 0.00% 100.00% 0.42 14.47 10.00 0.00 0.00 0.00 03-Apr-08 21:30 03-Apr-08 22:30 2 2.00 6.50 2.00 6.75 0.42 2.50% 97.50% 0.41 14.88 9.75 0.00 0.00 0.00 03-Apr-08 22:30 03-Apr-08 23:30 1 4.00 11.00 4.00 11.00 0.00 0.00% 0.00% 0.00 14.88 0.00 0.00 0.00 0.00 03-Apr-08 23:30 04-Apr-09 00:30 2 2.00 6.75 2.00 7.00 0.42 0.00% 100.00% 0.42 15.29 10.00 0.00 0.00 0.00 04-Apr-08 00:30 04-Apr-08 01:30 1 4.00 11.00 4.00 11.00 0.00 0.00% 0.00% 0.00 15.29 0.00 0.00 0.00 0.00 04-Apr-08 01:30 04-Apr-08 02:30 2 2.00 7.00 2.00 7.25 0.42 0.00% 100.00% 0.42 15.71 10.00 0.00 0.00 0.00 04-Apr-08 02:30 04-Apr-08 03:30 1 4.00 11.00 4.00 11.25 0.42 1.00% 99.00% 0.41 16.12 9.90 0.00 0.00 0.00 04-Apr-O8 03:30 04-Apr-08 04:30 2 2.00 7.25 2.00 7.50 0.42 1.00% 99.00% 0.41 16.54 9.90 0.00 0.00 0.00 04-Apr-08 04:30 04-Apr-08 05:30 1 4.00 11.25 4.00 11.50 0.42 2.00% 98.00% 0.41 16.94 9.80 0.00 0.00 0.00 04-Apr-O8 05:30 04-Apr-08 06:00 2 2.00 7.50 2.00 7.50 0.00 2.00% 98.00% 0.00 16.94 0.00 0.00 0.00 0.00 04-Apr-08 06:00 04-Apr-08 07:00 1 4.00 11.50 4.00 11.75 0.42 2.00% 98.00% 0.41 17.35 9.80 0.00 0.00 0.00 04-Apr-08 07:00 04-Apr-08 08:00 2 2.00 7.50 2.00 7.75 0.42 2.00% 98.00% 0.41 17.76 9.80 0.00 0.00 0.00 04-Apr-08 08:00 04-Apr-08 09:00 1 4.00 11.75 5.00 0.00 0.42 2.00% 98.00% 0.41 18.17 9.80 0.00 0.00 0.00 04-Apr-08 09:00 04-Apr-08 10:00 2 2.00 7.50 2.00 8.00 0.83 1.50% 98.50% 0.82 18.99 19.70 0.00 0.00 0.00 1 J Expro Well Testing 2 of 3 5/1/2008 PRODUCTION TANK DATA SHEET CUSTOMER :Anadarko Total Fluid Production: WELL NAME : Gubik #3 Total Oil Production: ® EXPRO START DATE: 02-Apr-08 Total Water Production: END DATE: 04-Apr-08 TEST No.: Flow #2 - Nanushuk RePerf 19.82 bbls 0.00 bbls 19.82 bbls IOlnad~,~, ~ Petroleum Corporation Start End Tank Previous Strap Current Strap Fluid Inc. BS &W H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date 8 Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 04-Apr-08 10:00 04-Apr-08 11:00 1 5.00 0.00 5.00 0.00 0.00 2.00% 98.00% 0.00 18.99 0.00 0.00 0.00 0.00 04-Apr-08 11:00 04-Apr-08 12:00 2 2.00 8.00 2.00 8.00 0.00 2.00% 98.00% 0.00 18.99 0.00 0.00 0.00 0.00 04-Apr-08 12:00 04-Apr-08 13:00 1 5.00 0.00 5.00 0.25 0.42 0.50% 99.50% 0.41 19.40 9.95 0.00 0.00 0.00 04-Apr-08 13:00 04-Apr-08 14:00 2 2.00 8.00 2.00 8.25 0.42 1.50% 98.50% 0.41 19.82 9.85 0.00 0.00 0.00 04-Apr-08 14:00 04-Apr-08 15:00 1 5.00 0.25 5.00 0.25 0.00 1.50% 98.50% 0.00 19.82 0.00 0.00 0.00 0.00 04-Apr-08 15;00 04-Apr-08 15:22 2 2.00 8.50 2.00 8.50 0.00 1.50% 98.50% 0.00 19.82 0.00 0.00 0.00 0.00 1~J Expro Well Testing 3 of 3 5/1/2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 02-Apr-08 END DATE : 04-Apr-08 TEST No. :Flow #2 - Nanushuk CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 2-Apr-08 0:00 WHP= 0 psi; CSG=170 psi. 0:52 Opened Wing valve. Opened well test choke. 0:53 Pressure bled to 0 psi; Tk #1= 4' 7.25". No change in fluid level. 0:54 Closed wing valve. Closed well test choke. 1:00 WHP= 0 psi; CSG=170 psi. 1:45 Schlumberger connected Lubricator to wellhead for final gun run. 1:50 Noticed leak on Otis cap when Schlumberger RIH with guns. Shut down heaters and light towers. 2:00 WHP= 0 psi; CSG=180 psi. 2:02 Schlumberger at surface. 2:03 Opened Wing valve. Opened well test choke. Pressure bled to 0 psi; Tk #1= 4' 7.25". No change in fluid level. 2:04 Closed wing valve. Closed well test choke. 2:15 Schlumberger fixed problem; started RIH. 2:30 Functioned Methanol pumps; 0.5 L/min rate. 3:00 WHP= 0 psi; CSG=180 psi. 3:25 Started Methanol injection. Schlumberger at surface. 3:26 Opened Wing valve. Opened well test choke. 3:27 Pressure bled to 0 psi; Tk #1= 4' 7.25". No change in fluid level. Closed wing valve. 3:28 Closed well test choke. 3:30 Placed 2.75-inch plate in top chamber of Daniels. 3:32 Swab closed; wing, upper master and lower master opened 3:40 Flare lit. 3:42 Opened well on a 24/64ths adjustable choke. 3:43 Increased choke to a 36/64ths adjustable. 3:48 2.75-inch orifice plate in service on the separator. C02 = 0.60%; HzS = 0 ppm 4:00 2.75-inch orifice plate out of service on the separator. Diverted Tk #1 to Tk#2; Tk #1= 4' 7.25". No change in volume. Increased choke to a 48/64ths adjustable. 4:02 2.75-inch orifice plate in service on the separator. 4:03 Gas Gravity = 0.599 4:07 Debris at separator. 4:12 Increased choke to a 64/64ths adjustable. 4:30 Diverted Tk #2 to Tk#1; Tk #2= 2' 1.25". No change in volume. 4:52 C02 = 0.75%; HZS = 0 ppm 5:00 Diverted Tk #1 to Tk#2; Tk #1 = 4' 7.25" Liquid leg of separator to tanks closed - no fluid at separator. 5:20 McOH Tote 10053 = 29" Total methanol injected = 38.25 gallons 6:00 Shift handover with night crew. Expro Well Testing 1 of 9 5/1/2008 • Job Log CUSTOMER :Anadarko TEST No. :Flow #2 - Nanushuk EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel START DATE : 02-Apr-08 EXPRO SUPERVISOR : T. Stone / T. Park END DATE : 04-Apr-08 Date Time dd-mm-yy hh:mm Operations 2-Apr-08 7:00 McOH Tote 10053 = 25 1/8" Total methanol injected = 67.89 gallons 8:00 McOH Tote 10053 = 23.5" Total methanol injected = 80.36 gallons 8:30 Observed small increase in fluid at the separator. Fluid Density = 40.7 API @ 44 F = 42 API @ 60 F 9:00 McOH Tote 10053 = 20.75" Total methanol injected = 101.40 gallons COz = 0.77%; H2S = 0 ppm Gas Gravity = 0.600 10:00 McOH Tote 10053 = 18.75" Total methanol injected = 116.62 gallons 11:00 McOH Tote 10053 = 16.25" Total methanol injected = 135.75 gallons 11:17 Opened oil leg to well test tanks. 11:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 7.25" - no gain 12:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 1.25" BS&W = 99.5% water, 0.5% sediment pH=7 Salinity = 70,000 Water Density = 0.914 g/cc @ 13.6 C = 7.62 ppg McOH Tote 10053 = 13 3/8"" Total methanol injected = 157.74 gallons 12:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'7.5" BS&W = 100% 13:00 Diverted from Tk #2 to Tk #1. Tk#2=2'1.5" 13:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'8" BS&W = 97% water, 3% grease/sediment Gas Gravity = 0.598 pH=7 Salinity = 60,000 Water Density = 0.899 g/cc @ 15.6 C = 7.49 ppg 13:34 Vector servicing upper and lower master valves on wellhead. 14:00 Diverted from Tk #2 to Tk #1. Tk#2=2'1.5" McOH Tote 10053 = 9.25" Total methanol injected = 189 gallons 14:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'8" 15:00 Diverted from Tk #2 to Tk #1. Tk#2= BS&W = 97% water, 3% grease/sediment Water Density = 0.904 g/cc @ 14 C =7.54 ppg Expro Well Testi ng 2 of 9 5/1 /2008 U Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 02-Apr-08 END DATE : 04-Apr-08 TEST No. :Flow #2 - Nanushuk CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 2-Apr-08 15:00 pH = 7 Salinity = 64,000 McOH Tote 10053 = 6.5" Total methanol injected = 210 gallons 15:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'8" BS&W = 100% 15:41 Schlumberger commenced RIH with production log toolstring. 16:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 2.25" McOH Tote 10053 = 4" Total methanol injected = 219.6 gallons 16:30 Diverted from Tk#1 to Tk #2. Tk #1 = 4' 8.25" 17:00 Diverted from Tk #2 to Tk #1. Tk#2=2'2.5" BS&W = 97% water, 3% grease/sediment pH=8 Salinity = 70,000 McOH Tote 10053 = 1.75" Total methanol injected = 233 gallons 17:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 8.25" Switched McOH Totes -Pumping out of 10051 (853.1 gal left on location). 18:00 Diverted from Tk #2 to Tk #1. Tk#2=2'2.75" 18:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 8.50". 18:30 BS&W = 100% water, 0% grease/sediment. Water Density= 0.917 g/cc @ 24.9 C = 7.65 ppg 18:42 Shut-in CSG pressure transducer to change out pressure gauge. 18:53 Opened CSG pressure transducer. 19:00 Diverted from Tk #2 to Tk #1. 19:27 Stopped methanol injection; Schlumberger collected flowing samples. 19:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 8.75" 19:50 Gas Gravity = 0.597 20:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 3" (no change in volume). 20:15 Schlumberger finished collecting pressurized gas sample. 20:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 8.75". 20:35 Started methanol injection. 21:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 3.50" BS&W= 100% Water Density = 0.926 g/cc @ 21 C = 7.72 ppg Expro Well Testi ng 3 of 9 5/1 /2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 02-Apr-08 END DATE : 04-Apr-08 r: TEST No. :Flow #2 - Nanushuk CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 2-Apr-08 21:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'9.0". McOH Tote 10051 = 30" Total methanol injected = 309.8 gallons 22:00 Diverted from Tk #2 to Tk #1. Tk #2= 2' 3.75". 22:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 9.25". McOH Tote 10051 = 27" Total methanol injected = 332.7 gallons 23:00 Diverted from Tk #2 to Tk #1. Tk #2= 2' 3.75". COZ = 1 %; HzS = 0 ppm 23:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 9.50". BS&W= 98% water and 2% sediment. Gas Gravity = 0.598 COZ = 1 %; HZS = 0 ppm Water Density = 0.876 g/cc @ 19.9 C = 7.30 ppg McOH Tote 10051 = 25" Total methanol injected = 348 gallons 3-Apr-08 0:00 Diverted from Tk #2 to Tk #1. 0:30 Diverted from Tk #1 to Tk #2. Tk#1 =4'9.50". McOH Tote 10051 = 22" Total methanol injected = 371 gallons 1:00 Diverted Tk #2 to Tk #1 Tk #2 = 2' 4.25". 1:30 McOH Tote 10051 = 20" Total methanol injected = 386 gallons 2:00 Diverted from Tk #1 to Tk #2. Tk#1 =4'9.75". BS&W = 100% Water Density= 0.860 g/cc @ 17.2 C = 7.17 ppg 2:30 Diverted from Tk #2 to Tank #1. Tk #2 = 2' 4.25". McOH Tote 10051 = 17.25" Total methanol injected = 407 gallons 3:00 Diverted from Tk #1 to Tk #2. Gas Gravity = 0.599 COZ = 0.9%; H2S = 0 ppm 3:30 Diverted from Tk #2 to Tank #1. Tk#2=2'4.25" McOH Tote 10051 = 14.75" Expro Well Testing 4 of 9 5/1/2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 02-Apr-08 END DATE : 04-Apr-08 • TEST No. :Flow #2 - Nanushuk CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 3-Apr-08 3:30 Total methanol injected = 426 gallons 3:40 Shut down one side of Methanol to reduce injection rate. 4:00 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". 4:30 Diverted from Tk #2 to Tk #1. Tk #2= 2' 4.50". BS&W = 100% Water Density = 0.884 g/cc @ 18.4 C = 7.37 ppg Salinity = 46,000 ppm pH=8 McOH Tote 10051 = 13.25" Total methanol injected = 438 gallons 5:00 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". 5:30 Diverted from Tk #2 to Tk #1. Tk #2= 2' 4.75" McOH Tote 10051 = 11.75" Total methanol injected = 449 gallons 6:00 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". 6:30 Diverted from Tk #2 to Tk #1. Tk#2=2'4.5" McOH Tote 10051 = 10.25" Total methanol injected = 461 gallons 7:00 Gas Gravity = 0.599 COZ = 0.9%; H2S = 0 ppm 7:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". BS&W = 98% water, 2% emulsion/sediment 7:30 Fluid wt = 7.0 ppg 7:55 Slickline RIH to set gauges. 8:30 Diverted from Tk #2 to Tk #1. Tk#2=2'4.5" McOH Tote 10051 = 6.75" Total methanol injected = 488 gallons 9:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". McOH Tote 10051 = 5.75" Total methanol injected = 495 gallons 10:30 Diverted from Tk #2 to Tk #1. Tk#2=2'5" McOH Tote 10051 = 4 1/8"' Total methanol injected = 508 gallons 11:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". BS&W = 100% water McOH Tote 10051 = 2.5" Total methanol injected = 520 gallons Expro Well Testing 5 of 9 5/1 /2008 • • Job Log CUSTOMER :Anadarko TEST No. :Flow #2 - Nanushuk EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel START DATE : 02-Apr-08 EXPRO SUPERVISOR : T. Stone / T. Park END DATE : 04-Apr-08 Date Time dd-mm-yy hh:mm Operations 3-Apr-08 12:25 Slickline fishing bailer. BS&W = 99.7% water, 0.3% sediment pH=6 Salinity = 10,000 ppm COZ = 0.9%; H2S = 0 ppm Gas Gravity = 0.600 12:30 Diverted from Tk #2 to Tk #1. Tk#2=2'5" McOH Tote 10051 = 0.25" Total methanol injected = 537 gallons 13:00 BS&W =dry gas - no fluid 13:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.25". McOH Tote 10024 = 36" Total methanol injected = 553 gallons 13:48 Slickline continued to fish bailer. 14:30 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 5.75" BS&W = 99.5% water, 0.5% emulsion McOH Tote 10024 = 34" Total methanol injected = 568 gallons 15:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.5" McOH Tote 10024 = 32.5" Total methanol injected = 579 gallons 16:00 BS&W = 99.5% water, 0.5% emulsion Gas Gravity = 0.598 COZ = 1 %; H2S = 0 ppm 16:30 Diverted from Tk #2 to Tk #1. Tk#2=2'6" McOH Tote 10024 = 30.75" Total methanol injected = 593 gallons 17:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.75". McOH Tote 10024 = 30.75" Total methanol injected = 608 gallons 18:00 BS&W = 99.25% water; 0.75% sediment Water Density = 0.830 g/cc @ 22.1 C = 6.92 ppg 18:30 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 6.25" McOH Tote 10024 = 27.00" = 206.6 gal Total methanol injected = 622 gallons Problems with slickline. 18:40 Increased choke to a 120/64ths adjustable. 18:46 Decreased choke to 64/64ths adjustable. 18:50 Flare went out. 19:00 Lit igniter. 19:10 Stabbed lubricator; wireline RIH. Expro Well Testi ng 6 of 9 5/1 /2008 EXPFtO CUSTOMER WELL NAME START DATE END DATE Job Log C~ Anadarko TEST No. :Flow #2 - Nanushuk Gubik #3 CUSTOMER REP. :Dennis McDaniel 02-Apr-08 EXPRO SUPERVISOR : T. Stone / T. Park 04-Apr-08 Date Time dd-mm-yy hh:mm Operations 3-Apr-08 19:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 10.75". McOH Tote 10024 = 24.75" Total methanol injected = 639 gallons 20:30 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 6.50" McOH Tote 10024 = 23.50" Total methanol injected = 648 gallons BS&W= 100% water; trace sediment Water Density = 0.890 g/cc @ 19.1 C = 7.42 ppg C02 = 1 %; HZS = 0 ppm Salinity = 52,000 ppm pH=8 21:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 11.00". McOH Tote 10024 = 21.25" Total methanol injected = 666 gallons 21:55 WHP increased to 150 psi. Slickline had problems downhole. 22:30 Diverted from Tk #2 to Tk #1. Tk#2=2'6.75" McOH Tote 10024 = 19.25" Total methanol injected = 681 gallons BS&W= 97.5% water; 2.50% sediment Water Density = 0.920 g/cc @ 20.4 C = 7.67 ppg Shut propane off at flare stack. 22:50 Schlumberger sampled separator gas line. 23:30 Diverted from Tk #1 to Tk #2. 23:30 Tk #1 = 4' 11.00". McOH Tote 10024 = 17.75" Total methanol injected = 692 gallons 4-Apr-08 0:00 McOH Tote 10024 = 16.50". Total methanol injected = 702 gallons BS&W = 100% water Water Density = 0.858 g/cc @ 22.2 C = 7.15 ppg COZ = 0.90%; H2S = 0 ppm Salinity = 28,000 ppm pH=7 0:30 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 6.75" McOH Tote 10024 = 15.75" Total methanol injected = 708 gallons 1:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 11.00". McOH Tote 10024 = 14.00" Total methanol injected = 721 gallons 2:30 Diverted from Tk #2 to Tk #1. Expro Well Testi ng 7 of 9 5/1 /2008 i i Job Log CUSTOMER :Anadarko TEST No. :Flow #2 - Nanushuk EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel START DATE : 02-Apr-08 EXPRO SUPERVISOR : T. Stone / T. Park END DATE : 04-Apr-08 Date Time ~ dd-mm-yy hh:mm Operations 4-Apr-08 2:30 Tk #2 = 2' 7.25". McOH Tote 10024 = 12.00" Total methanol injected = 736 gallons BS&W= 100%; 1.0% sediment Water Density = 0.894 g/cc @ 22 C =7.45 ppg 3:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 11.25". McOH Tote 10024 = 10.0". Total methanol injected = 748 gallons 4:30 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 7.50". McOH Tote 10024 = 8.75" Total methanol injected = 761 gallons 5:30 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 11.50". McOH Tote 10024 = 6.50". Total methanol injected = 778 gallons BS&W= 100% water; 2.0% sediment Water Density = 0.918 g/cc @ 15.6 C = 7.65 ppg C02 = 0.92%; HZS = 0 ppm Salinity= 56,000ppm pH=8 6:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 7.50". McOH Tote 10024 = 5.50". Total methanol injected = 786 gallons 6:50 WHP dropped to zero. Gas rate dropped off. 6:55 WHP returned to previous state. Gas rate increased. 7:00 Diverted from Tk #1 to Tk #2. Tk #1 = 4' 11.75" McOH Tote 10024 = 4". Total methanol injected = 797 gallons 8:00 Diverted from Tk #2 to Tk #1. Tk #2 = 2' 7.75" McOH Tote 10024 = 2.25". Total methanol injected = 810 gallons BS&W = 98% water, 2% sediment pH=7 Water Density = 0.919 g/cc @ 15.2 C = 7.66 ppg 9:00 Diverted from Tk #1 to Tk #2. Tk #1 = 5' McOH Tote 10024 = 0.5" Total methanol injected = 824 gallons Switched methanol tote to AC 10053. Initial strap = 37.5" = 287 gallons 10:00 Diverted from Tk #2 to Tk #1. Tk #1 = BS&W = 98.5% water, 1.5% sediment COZ = 0.90%; H2S = 0 ppm Expro Well Testi ng 8 of 9 5/1 /2008 Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 02-Apr-08 END DATE : 04-Apr-08 TEST No. :Flow #2 - Nanushuk CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : T. Stone / T. Park Date Time dd-mm-yy hh:mm Operations 4-Apr-08 10:00 McOH Tote 10053 = 36" Total methanol injected = 836 gallons 11:00 Diverted from Tk #1 to Tk #2. Tk #1 = 5' McOH Tote 10053 = 34" Total methanol injected = 851 gallons BS&W = 98% water, 2% sediment Water Density = 0.897 g/cc @ 28.3 C = 7.48 ppg 12:00 Diverted from Tk #1 to Tk #2. Tk#2=2'8" BS&W = 98% water, 2% sediment McOH Tote 10053 = 32" Total methanol injected = 866 gallons 13:00 Diverted from Tk #1 to Tk #2. Tk #1 = 5' 0.25" McOH Tote 10053 = 30" Total methanol injected = 882 gallons BS&W = 99.5% water, 0.5% sediment 13:30 WHP decreased to zero. 13:43 WHP spiked at 93 psig. 14:00 Diverted from Tk #2 to Tk #1. Tk#2=2'8.25" McOH Tote 10053 = 28" Total methanol injected = 897 gallons Gas Gravity = 0.594 BS&W = 98.5% water, 1.5% sediment pH=7 Salinity = 30,000 ppm 14:00 Water Density = 1.008 g/cc @ 20.3 C = 8.40 ppg 15:00 Diverted from Tk #1 to Tk #2. Tk #1 = 5' 0.25" McOH Tote 10053 = 26.5" Total methanol injected = 908 gallons 15:00 WHP decreased to zero. 15:22 Well shut-in at the choke manifold. 15:26 Reduced McOH injection rate -pumping from one side of pump. 15:28 SSV locked out. 16:30 McOH Tote 10053 = 24.25" Total methanol injected = 926 gallons Expro Well Testing 9 of 9 5/1/2008 Wellhead Plot Wellhead Plot - Nanushuk Flow #2 EXPRO Anadarko Gubik #3 Petroleum Corporation 80 1000 70 60 50 .-. H s ~ ~ ~v N=40 (A m .se o~ 0 t v 30 20 10 0 857 • 714 571 ~ a ~ ~ U a ... ~ 429 = 286 • 143 0 02-Apr-08 02-Apr-08 02-Apr-08 03-Apr-08 03-Apr-08 03-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 03:00 11:30 20:00 04:30 13:00 21:30 06:00 11:00 13:54 15:24 15:58 Date & Time --~ W HT -~ Choke Size -F- W HP --~ CSG Expro Well Testing Page 1 5/1/2008 Separator Plot EXPRO 100 90 80 L H 70 N d a ~ O 60 TN 2 d N ~_ d ~ ~ 50 o!S v ot~ a ~ v~ a 40 L v ~+ L ~ 30 20 10 Separator Plot - Nanushuk Flow #2 Anadarko Gubik #3 Petroleum Corporation 100 90 80 70 60 R 50 m ~ av E m 40 30 20 • 10 I I ~ I I I I ~' ~_ ~ ~ I I i l o 02-Apr-08 02-Apr-08 02-Apr-08 02-Apr-08 03-Apr-08 03-Apr-08 03-Apr-08 03-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 03:00 09:15 15:30 21:45 04:00 10:15 16:30 22:45 05:00 07:45 13:32 13:57 15:18 Date & Time T Pressure -~ Diff Press -~ Temperature Expro Well Testing Page 1 5/1/2008 Production Plot 45 40 35 m c 0 30 m ._ = 25 r ~ m Q- ~ ~ °~ 20 d r ca 3 15 .~ 10 5 EXPRO _ f- - -- - _ - ---_ - _ -- ^ - ~ - - - - -- __ - ~ i •• • • •• • - • • _ • ^ t if _~ t ^ --- Production Plot - Nanushuk Flow #2 Anadarko Gubik #3 Petroleum Corporation - 3.00 - 2.67 - 2.33 2.00 1.67 °' ~ ° w ~ ° ~ N ca ~ - 1.33 ~ ~ - 1.00 0.67 . 0.33 0 0.00 02-Apr-08 02-Apr-08 02-Apr-08 02-Apr-08 03-Apr-08 03-Apr-08 03-Apr-08 03-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 04-Apr-08 03:00 09:15 15:30 21:45 04:00 10:15 16:30 22:45 05:00 07:45 13:32 13:57 15:18 Date & Time --~-Fluid Rate f McOH Inj Rate ~ Gas Rate Expro Well Testing Page 1 5/1/2008 Well Test Report CUSTOMER : Anadarko O EXPRO STEART ~ E: 06-Apr#-08 END DATE: 07-Apr-0B TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park ~troleu~atio~ CHOKE SEPARATOR FLOW RATES McOH CUMMLATNES McOH FLUI D PROPER TIES DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMsd/d FLUID stb/d INJ. stb/d GAS MMs FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % H2S m SALINRY m 06-A r-08 18:00 0 8 90 255 06-A r-08 18:01 0 0 90 263 O6-A r-08 18:02 0 0 90 264 06-A r-08 18:03 0 0 90 264 O6-A r-08 18:04 0 8 90 255 06-A r-08 18:05 0 3 90 255 06-A r-08 18:06 0 5 90 256 06-A r-08 18:07 0 9 90 264 06-A r-08 18:08 0 0 90 264 06-A r-08 18:09 0 7 90 253 O6-A r-08 18:10 0 1 90 252 O6-A r-08 18:11 0 0 90 260 O6-A r-08 18:12 0 0 90 265 06-A r-08 18:13 0 10 90 255 06-A r-08 18:14 0 0 90 265 06-A r-08 18:15 0 8 90 263 06-A r-08 18:16 0 11 90 264 O6-A r-08 18:17 0 3 90 259 06-A r-08 18:18 0 0 90 252 06-A r-08 18:19 0 10 90 260 06-A r-08 18:20 0 10 90 263 06-A r-08 18:21 0 0 90 258 06-A r-08 18:22 0 7 90 260 06-A r-08 18:23 0 11 90 261 O6-A r-08 18:24 0 7 90 253 06-A r-08 18:25 0 10 90 264 06-A r-08 18:26 0 10 90 265 06-A r-08 18:27 0 0 90 259 06-A r-08 18:28 0 5 90 253 06-A r-08 18:29 0 0 90 254 06-A r-08 18:30 0 389 86 253 06-A r-08 18:31 0 385 87 265 06-A r-OS 18:32 0 383 87 257 06-A r-08 18:33 0 404 87 267 06-A r-08 18:34 0 395 87 265 O6-A r-08 18:35 0 394 87 256 06-A r-08 18:36 0 390 86 259 06-A r-08 18:37 0 404 86 262 O6-A r-08 18:38 0 388 86 256 06-A r-08 18:39 0 396 86 268 O6-A r-08 18:40 0 393 86 257 06-A r-08 18:41 0 404 86 267 06-A r-OS 18:42 0 389 86 258 O6-A r-08 18:43 0 399 86 263 06-A r-08 18:44 0 399 85 257 06-A r-08 18:45 0 396 86 270 06-A r-08 18:46 0 394 85 260 L J r Expro Well Testing 1 of 7 5/1/2008 Well Test Report CUSTOMER : Anadarko EXPRO STEART ~ E: 06-Apr-08 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park Petroleum Corporation CHOKE SEPAR ATOR FLOW RATES McOH CUMMLATNES McOH FLUI D PROPER TIES DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ. stb/d GAS MMscf FLUID stb INJ. stb OIL API 60°F GAS Air-1 FLUID BS&W % COZ % HzS m SALINITY m O6-A r-08 18:47 0 390 86 269 O6-A r-08 18:48 0 385 85 258 O6-A r-08 18:49 0 390 85 257 O6-A r-08 18:50 0 395 86 260 O6-A r-08 18:51 0 385 86 268 06-A r-OS 18:52 0 401 86 258 06-A r-08 18:53 0 385 86 269 06-A r-08 18:54 0 391 86 267 06-A r-08 18:55 0 402 86 264 O6-A r-08 18:56 0 387 86 270 O6-A r-08 18:57 0 400 86 259 06-A r-08 18:58 0 390 86 261 O6-A r-08 18:59 0 400 86 271 06-A r-08 19:00 0 395 86 271 06-A r-OS 19:01 0 388 86 261 06-A r-OS 19:02 0 385 86 259 06-A r-08 19:03 0 397 86 268 06-A r-08 19:04 0 394 87 262 06-A r-08 19:05 0 389 87 262 06-A r-08 19:06 0 392 86 259 O6-A r-0819:07 0 386 87 264 O6-A r-0819:08 0 390 87 261 06-A r-0819:09 0 386 87 260 06-A r-0819:10 0 400 87 272 06-A r-08 19:11 0 387 87 268 O6-A r-0819:12 0 400 87 269 O6-A r-0819:13 0 387 87 263 06-A r-0819:14 0 397 87 271 O6-A r-08 19:15 0 402 87 269 O6-A r-08 19:16 0 402 88 260 06-A r-08 19:17 0 401 88 258 06-A r-08 19:18 0 398 88 259 06-A r-0819:19 0 388 87 264 O6-A r-0819:20 0 387 88 264 06-A r-0819:21 0 388 88 259 06-A r-08 19:22 0 389 88 258 06-A r-08 19:23 0 395 88 267 06-A r-0819:24 0 403 88 268 06-A r-0819:25 0 389 88 257 06-A r-0819:26 0 388 88 268 06-A r-OS 19:27 0 390 88 268 06-A r-08 19:28 0 402 88 267 O6-A r-08 19:29 0 395 88 267 06-A r-0819:30 0 388 88 263 06-A r-0819:31 0 404 88 262 06-A r-08 19:32 0 403 88 259 06-A r-OS 19:33 0 396 88 270 Expro Well Testing 2 of 7 5/1/2008 Well Test Report CUSTOMER : Anadarko O EXPRO START DATE: 06-Aprr-08 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park Petroleum CorDOration CHOKE SEPAR ATOR FLOW RATES McOH CUMMLATNES McOH FLUI D PROPER TIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMSCf/d FLUID stb/d INJ. stb/d GAS MMs FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % H2S m SALINITY m O6-A r-0819:34 0 400 88 269 06-A r-0819:35 0 403 88 257 06-A r-0819:36 0 389 88 264 06-A r-0819:37 0 402 88 257 06-A r-0819:38 0 393 88 257 06-A r-0819:39 0 389 88 257 06-A r-08 19:40 0 402 88 261 06-A r-08 19:41 0 397 88 258 06-A r-0819:42 0 395 88 259 06-A r-0819:43 0 401 88 261 O6-A r-0819:44 0 398 88 262 06-A r-0819:45 0 405 88 263 06-A r-0819:46 0 389 88 268 06-A r-0819:47 0 389 88 257 06-A r-0819:48 0 401 88 269 06-A r-08 19:49 0 402 88 256 06-A r-0819:50 0 403 88 267 06-A r-08 19:51 0 398 88 265 06-A r-OS 19:52 0 400 87 259 06-A r-0819:53 0 390 88 259 O6-A r-0819:54 0 404 88 257 O6-A r-0819:55 0 401 87 255 O6-A r-0819:56 0 401 88 260 O6-A r-0819:57 0 406 88 268 06-A r-08 19:58 0 405 87 268 06-A r-0819:59 0 402 87 256 06-A r-08 20:00 0 390 87 269 O6-A r-08 20:01 0 403 87 261 O6-A r-08 20:02 0 404 87 267 06-A r-08 20:03 0 391 88 262 06-A r-08 20:04 0 393 88 259 06-A r-08 20:05 0 393 87 257 06-A r-08 20:06 0 391 87 269 06-A r-08 20:07 0 403 87 269 O6-A r-08 20:08 0 390 88 261 06-A r-08 20:09 0 405 87 266 06-A r-08 20:10 0 389 88 257 06-A r-08 20:11 0 400 87 268 O6-A r-08 20:12 0 393 88 257 06-A r-O8 20:13 0 406 87 256 O6-A r-08 20:14 0 390 87 268 O6-A r-08 20:15 0 404 88 257 O6-A r-08 20:16 0 390 88 261 06-A r-08 20:17 0 392 88 266 06-A r-08 20:18 0 395 88 262 06-A r-08 20:19 0 391 88 256 06-A r-O8 20:20 0 390 88 259 Expro Well Testing 3 of 7 5/1/2008 Well Test Report CUSTOMER :Anadarko O EXPRO STEART DATE: 06 Apr#- 8 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park ~m~atio~ M CHOKE SEPAR ATOR FLOW RATES McOH CUMMLATNES McOH FLUI D PROPER TIES DATE & TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ. stb/d GAS MMscf FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BS&W % COZ % HZS m SALINffY m 06-A r-08 20:21 0 406 88 257 06-A r-08 20:22 0 406 88 260 O6-A r-08 20:23 0 406 88 266 06-A r-08 20:24 0 395 87 269 06-A r-08 20:25 0 405 88 268 06-A r-08 20:26 0 392 87 267 O6-A r-08 20:27 0 399 87 269 06-A r-08 20:28 0 392 87 269 O6-A r-08 20:29 0 407 87 269 06-A r-08 20:30 0 395 87 256 06-A r-08 20:31 0 391 87 259 06-A r-08 20:32 0 391 87 257 06-A r-08 20:33 0 405 87 256 O6-A r-08 20:34 0 406 87 262 06-A r-08 20:35 0 393 87 256 06-A r-08 20:36 0 391 87 266 O6-A r-08 20:37 0 394 87 266 O6-A r-08 20:38 0 381 87 257 O6-A r-08 20:39 0 405 87 258 06-A r-08 20:40 0 410 87 262 06-A r-OS 20:41 0 409 88 258 06-A r-08 20:42 0 413 87 267 06-A r-08 20:43 0 416 87 261 06-A r-08 20:44 0 414 87 270 O6-A r-08 20:45 0 413 88 258 O6-A r-08 20:46 0 416 87 270 06-A r-08 20:47 0 408 88 260 06-A r-08 20:48 0 409 88 259 06-A r-08 20:49 0 423 88 268 06-A r-08 20:50 0 430 88 259 06-A r-08 20:51 0 419 88 267 O6-A r-08 20:52 0 413 88 271 06-A r-08 20:53 0 423 88 258 06-A r-08 20:54 0 425 88 259 06-A r-OS 20:55 0 428 88 258 06-A r-08 20:56 0 427 88 267 06-A r-08 20:57 0 428 88 262 06-A r-08 20:58 0 416 88 266 06-A r-08 20:59 0 416 88 258 06-A r-08 21:00 0 413 88 260 06-A r-08 21:01 0 424 88 265 06-A r-08 21:02 0 415 88 260 06-A r-08 21:03 0 432 88 268 O6-A r-08 21:04 0 430 88 263 O6-A r-08 21:05 0 416 88 258 O6-A r-08 21:06 0 425 88 260 06-A r-08 21:07 0 413 88 269 Expro Well Testing 4 of 7 5/1/2008 Well Test Report CUSTOMER : Anadarko O EXPRO START DATE: O6-Apr#-08 END DATE: 07-Apr-0B TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park ~m~atio~ CHOKE SEPAR ATOR FLOW RATES McOH CUMMLATIVES McOH FLUID PROPER TIES DATE 8a TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ. stb/d GAS MMscf FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BS&W % CO2 % HZS m SALINITY m 06-A r-08 21:08 0 418 88 261 06-A r-08 21:09 0 430 88 269 06-A r-08 21:10 0 425 88 259 06-A r-08 21:11 0 424 88 267 O6-A r-08 21:12 0 423 89 259 O6-A r-08 21:13 0 431 89 264 O6-A r-08 21:14 0 431 89 260 06-A r-08 21:15 0 430 89 270 06-A r-08 21:16 0 429 89 264 06-A r-08 21:17 0 433 89 258 06-A r-08 21:18 0 445 89 264 06-A r-08 21:19 0 432 89 270 06-A r-08 21:20 0 434 89 258 06-A r-08 21:21 0 435 89 266 06-A r-08 21:22 0 447 89 259 06-A r-08 21:23 0 441 89 271 06-A r-08 21:24 0 443 89 269 O6-A r-08 21:25 0 438 89 264 O6-A r-08 21:26 0 446 89 260 O6-A r-08 21:27 0 432 89 262 06-A r-08 21:28 0 446 89 259 06-A r-08 21:29 0 447 89 271 06-A r-08 21:30 0 435 90 271 10.80 0.09 06-A r-08 21:45 0 442 90 271 06-A r-08 22:00 0 443 88 265 06-A r-08 22:15 0 427 90 271 0 62 0.000 0 0.000 0.00 0.6 0 O6-A r-08 22:30 16 583 61 277 0 61 0.000 0 12.00 0.000 0.00 0.59 0 06-A r-08 22:45 24 712 51 276 14 64 0.000 0 0.000 0.00 6.20 0 06-A r-08 23:00 24 780 44 274 20 58 0.828 0 0.009 0.00 0.583 0 06-A r-08 23:15 32 852 41 289 72 36 5.937 480 0.070 14.59 0 O6-A r-08 23:30 32 849 42 302 84 57 4.151 280 10.80 0.114 17.50 1.05 0 06-A r-08 23:45 40 814 43 302 110 51 7.370 0.190 07-A r-08 00:00 40 815 43 301 110 49 7.927 40 0.273 17.92 0.571 0 07-A r-08 00:15 40 810 42 295 112 45 7.894 0.355 07-A r-08 00:30 48 757 42 286 117 49 7.835 0 12.00 0.437 17.92 1.55 0 0.00% 07-A r-08 00:45 48 761 41 283 147 40 9.947 0.541 07-A r-08 01:00 48 767 40 284 150 40 9.990 20 0.645 18.33 0 07-A r-08 01:15 48 779 40 290 148 41 10.025 0.749 07-A r-08 01:30 48 770 40 282 150 43 .9.984 10.80 0.853 2.00 0 07-A r-08 01:45 48 784 40 283 153 38 10.051 0.958 07-A r-08 02:00 48 774 41 288 152 39 10.095 0 1.063 18.33 0 07-A r-08 02:15 48 786 42 277 153 42 10.019 1.167 07-A r-08 02:30 48 780 42 284 153 37 10.099 9.60 1.272 2.41 0 07-A r-08 02:45 48 771 41 287 153 41 10.155 1.378 07-A r-08 03:00 48 793 41 279 154 43 10.080 0 1.483 18.33 0 07-A r-08 03:15 48 752 41 288 141 41 6.697 1.553 07-A r-08 03:30 56 715 42 275 201 32 6.951 4.32 1.625 2.60 Expro Well Testing 5 of 7 5/1/2008 Well Test Report CUSTOMER : Anadarko EXPRO ART ATE: O6-Apr-08 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park ~troleu~atio~ M CHOKE SEPARATOR FLOW RATES McOH CUMMLATNES McOH FLUID PROPERTIES DATEB<TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ. stb/d GAS MMscf FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BSBW % COZ % HZS m SALINITY m 07-A r-08 03:45 56 687 39 278 227 32 13.386 1.765 07-A r-08 04:00 56 701 37 266 226 32 13.148 20 1.902 19.16 0.567 0 07-A r-08 04:15 56 702 37 260 226 32 13.076 2.038 07-A r-08 04:30 56 700 37 265 227 32 13.057 8.64 2.174 2.96 07-A r-08 04:45 56 694 37 265 228 32 13.022 2.310 07-A r-08 05:00 56 686 38 263 229 32 12.962 0 2.445 19.16 07-A r-OS 05:15 56 700 37 252 229 32 12.995 2.580 07-A r-08 05:30 56 686 37 265 228 32 12.970 10.80 2.715 3.42 07-A r-08 05:45 56 702 37 265 228 32 13.012 2.851 07-A r-08 06:00 56 647 36 253 227 19 13.175 0 8.64 2.988 19.16 3.60 07-A r-08 06:15 62 650 36 263 230 19 12.492 3.118 07-A r-08 06:30 62 648 35 258 237 10 14.188 3.266 07-A r-08 06:45 62 667 35 254 237 10 14.353 3.415 07-A r-08 07:00 62 666 35 254 237 10 14.388 40 12.00 3.565 20.83 4.10 07-A r-08 07:15 62 667 35 247 237 4 14.487 3.716 07-A r-08 07:30 62 666 35 240 238 4 14.524 3.867 07-A r-08 07:45 62 652 35 245 238 4 14.515 4.019 07-A r-08 08:00 62 651 35 247 237 4 14.501 20 8.64 4.170 21.66 4.46 07-A r-08 08:15 62 663 34 241 237 3 14.518 4.321 07-A r-08 08:30 62 663 34 245 237 3 14.527 0 4.472 21.66 07-A r-08 08:45 62 653 34 250 237 3 14.502 4.623 07-A r-08 09:00 62 643 34 240 237 3 14.498 20 12.00 4.774 22.08 4.96 07-A r-08 09:15 62 652 34 239 236 3 14.489 4.925 07-A r-08 09:30 62 659 34 251 237 2 14.497 0 5.076 22.08 07-A r-08 09:45 62 664 34 249 237 2 14.522 5.227 07-A r-08 10:00 62 665 34 245 236 7 14.429 0 10.80 5.378 22.08 5.42 7.28 100 07-A r-08 10:15 62 666 34 239 237 6 14.448 5.528 07-A r-08 10:30 62 653 34 242 237 6 14.434 20 5.679 22.50 07-A r-08 10:45 62 653 34 249 236 6 14.426 5.829 07-A r-08 11:00 62 664 34 238 239 6 14.400 0 10.80 5.979 22.50 5.87 0.567 07-A r-08 11:15 62 649 34 248 246 7 14.402 6.129 07-A r-08 11:30 62 656 34 250 248 7 14.450 0 6.279 22.50 07-A r-08 11:45 62 649 34 239 249 7 14.561 6.431 07-A r-08 12:00 62 656 34 238 251 7 14.676 0 10.80 6.584 6.33 0.569 07-A r-08 12:15 62 650 33 238 251 21 14.419 6.734 07-A r-08 12:30 62 663 34 248 250 21 14.428 0 6.884 22.50 07-A r-OS 12:45 62 665 34 247 249 21 14.432 7.035 07-A r-08 13:00 62 665 33 239 249 21 14.437 20 9.60 7.185 6.74 0.569 07-A r-08 13:15 62 654 33 236 249 22 14.417 7.335 07-A r-08 13:30 62 660 34 236 251 22 14.401 0 7.485 23.33 7.10 100 07-A r-OS 13:45 62 648 34 246 252 22 14.380 7.635 07-A r-08 14:00 62 648 34 248 253 22 14.384 0 13.20 7.785 7.28 0.568 07-A r-08 14:15 62 664 34 240 254 23 14.358 7.935 07-A r-08 14:30 62 653 34 240 254 23 14.357 0 8.084 23.33 07-A r-08 14:45 62 662 34 247 254 24 14.364 8.234 07-A r-08 15:00 62 667 33 238 253 24 14.391 20 8.64 8.384 23.75 7.65 0.568 07-A r-08 15:15 62 663 34 236 251 23 14.452 8.534 n Expro Well Testing 6 of 7 5/1/2008 Well Test Resort CUSTOMER : Anadarko O EXPRO STEART DA E: O6 Apr-08 END DATE: 07-Apr-0B TEST No.: Flow #3 - Tuluvak Clean-up CUSTOMER REP.: Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park ~troleu~atiol~ bl CHOKE SEPARATOR FLOW RATES McOH CUMMLATIVES McOH FLUI D PROPERTIES DATE 8 TIME dd-mmm- hh:mm SIZE 64ths WHP si WHT °F CSG si PRES. si TEMP. °F GAS MMscf/d FLUID stb/d INJ. stb/d GAS MMscf FLUID stb INJ. stb OIL API 60°F GAS Air=1 FLUID BSBW % COZ % HZS m SALINITY m 07-A r-08 15:30 62 664 33 246 248 23 14.464 0 8.685 07-A r-08 15:45 62 665 34 238 249 25 14.429 8.835 07-A r-08 16:00 62 651 34 247 250 25 14.413 20 9.84 8.985 24.17 8.06 7.10 100 35,000 07-A r-08 16:15 62 664 33 246 250 26 14.411 9.135 07-A r-08 16:30 62 647 34 245 249 26 14.412 20 9.286 24.58 07-A r-08 16:45 62 662 34 236 246 25 14.423 9.436 07-A r-08 17:00 62 659 34 237 245 25 14.414 0 12.02 9.586 24.58 8.56 07-A r-08 17:15 62 663 34 243 270 25 13.699 9.729 07-A r-08 17:30 62 655 34 235 271 25 14.207 20 9.877 25.00 07-A r-08 17:45 62 665 34 234 271 25 14.198 10.025 07-A r-08 18:00 62 665 34 245 270 25 14.212 0 13.11 10.173 25.00 9.11 0.568 07-A r-08 18:15 62 665 33 237 272 25 14.217 10.321 07-A r-08 18:30 62 649 34 245 276 25 14.173 0 10.468 25.00 07-A r-08 18:45 62 664 34 232 277 27 14.181 10.616 07-A r-08 19:00 62 651 33 239 268 27 14.147 0 10.93 10.763 25.00 9.56 07-A r-OS 19:15 62 657 34 246 269 27 14.697 10.917 07-A r-08 19:30 62 652 33 236 270 27 14.691 11.070 07- r-08 19:45 62 648 33 237 270 27 14.587 11.221 07-A r-08 20:00 62 647 33 237 267 30 14.105 20 10.93 11.368 25.83 10.02 0.567 07-A r-08 20:15 62 650 33 240 267 30 14.220 11.517 07-A r-08 20:30 62 653 33 243 265 30 14.240 11.665 07-A r-08 20:45 62 658 33 234 258 30 14.306 11.814 07-A r-08 21:00 62 652 33 234 250 28 14.325 0 12.02 11.963 25.83 10.52 07-A r-08 21:15 62 648 34 235 246 28 14.282 12.112 07-A r-08 21:30 62 652 33 245 249 28 14.228 12.260 0.568 07-A r-08 21:45 62 661 33 238 252 28 14.195 12.408 07-A r-OS 22:00 62 655 33 233 254 28 14.191 0 10.93 12.556 25.83 10.97 • Expro Well Testing 7 of 7 5/1/2008 GAS FLOW REPORT CUSTOMER : Anadarko O EXPRO START DATE: 06 Ap ~ 8 END DATE: 07-Apr-08 TEST No. :Flow #3 - Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : D.Jones / T. Park Petroleum Corporation SEPAR ATOR GAS FA CTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches HZO) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 06-Apr-OS 22:45 24 28.52 0.71 63.73 0.00 0.600 4.500 0.00 1.0000 1.0000 1.2910 0.9964 1.0000 1.0002 1.0010 0.00 0.000 0.000 06-Apr-08 23:00 24 34.66 29.49 58.44 2.00 0.583 31.971 816.13 1.0000 1.0000 1.3100 1.0015 1.0012 1.0056 1.0020 1079.48 0.828 0.009 O6-Apr-08 23:15 32 86.77 104.74 36.20 3.00 0.583 95.333 1907.81 1.0000 1.0000 1.3100 1.0237 1.0004 1.0073 1.0070 2594.95 5.937 0.070 06-Apr-08 23:30 32 98.47 47.36 56.61 3.00 0.583 68.290 1907.81 1.0000 1.0000 1.3100 1.0033 1.0006 1.0029 1.0070 2532.87 4.151 0.114 O6-Apr-08 23:45 40 124.94 115.26 51.04 3.00 0.583 120.002 1907.81 1.0000 1.0000 1.3100 1.0087 1.0003 1.0055 1.0090 2559.21 7.370 0.190 07-Apr-08 00:00 40 124.64 130.09 48.52 3.00 0.571 127.336 1907.81 1.0000 1.0000 1.3230 1.0112 1.0003 1.0063 1.0090 2593.82 7.927 0.273 07-Apr-08 00:15 40 126.99 125.76 45.17 3.00 0.571 126.374 1907.81 1.0000 1.0000 1.3230 1.0146 1.0003 1.0059 1.0100 2602.66 7.894 0.35 07-Apr-08 00:30 48 131.80 120.29 48.81 3.00 0.571 125.914 1907.81 1.0000 1.0000 1.3230 1.0109 1.0003 1.0055 1.0100 2592.60 7.835 0.43- 07-Apr-OS 00:45 48 161.56 155.78 44.22 3.00 0.571 158.644 1907.81 1.0000 1.0000 1.3230 1.0155 1.0002 1.0058 1.0130 2612.62 9.947 0.541 07-Apr-08 01:00 48 164.94 152.33 39.53 3.00 0.571 158.510 1907.81 1.0000 1.0000 1.3230 1.0203 1.0002 1.0055 1.0140 2626.07 9.990 0.645 07-Apr-08 01:15 48 163.08 155.60 40.85 3.00 0.571 159.296 1907.81 1.0000 1.0000 1.3230 1.0189 1.0002 1.0057 1.0130 2622.34 10.025 0.749 07-Apr-08 01:30 48 164.63 153.52 42.86 3.00 0.571 158.978 1907.81 1.0000 1.0000 1.3230 1.0169 1.0002 1.0056 1.0130 2616.65 9.984 0.853 07-Apr-08 01:45 48 167.37 151.51 38.32 3.00 0.571 159.243 1907.81 1.0000 1.0000 1.3230 1.0215 1.0002 1.0054 1.0140 2629.84 10.051 0.958 07-Apr-08 02:00 48 166.39 154.06 39.32 3.00 0.571 160.106 1907.81 1.0000 1.0000 1.3230 1.0205 1.0002 1.0056 1.0140 2627.05 10.095 1.063 07-Apr-08 02:15 48 167.69 151.38 41.73 3.00 0.571 159.326 1907.81 1.0000 1.0000 1.3230 1.0180 1.0002 1.0054 1.0140 2620.11 10.019 1.167 07-Apr-08 02:30 48 167.48 152.39 36.93 3.00 0.571 159.757 1907.81 1.0000 1.0000 1.3230 1.0230 1.0002 1.0055 1.0140 2633.95 10.099 1.272 07-Apr-08 02:45 48 167.55 155.44 41.25 3.00 0.571 161.381 1907.81 1.0000 1.0000 1.3230 1.0185 1.0002 1.0056 1.0140 2621.82 10.155 1.378 07-Apr-08 03:00 48 168.48 152.73 42.50 3.00 0.571 160.412 1907.81 1.0000 1.0000 1.3230 1.0173 1.0002 1.0054 1.0140 2618.17 10.080 1.483 07-Apr-08 03:15 48 155.94 73.21 41.41 3.00 0.571 106.847 1907.81 1.0000 1.0000 1.3230 1.0184 1.0004 1.0028 1.0130 2611.76 6.697 1.553 07-Apr-08 03:30 56 215.89 55.30 32.00 3.00 0.571 109.264 1907.81 1.0000 1.0000 1.3230 1.0281 1.0003 1.0015 1.0190 2650.66 6.951 1.625 07-Apr-08 03:45 56 241.45 181.45 32.00 3.00 0.571 209.311 1907.81 1.0000 1.0000 1.3230 1.0281 1.0002 1.0045 1.0220 2664.73 13.386 1.765 07-Apr-08 04:00 56 240.85 174.40 32.00 3.00 0.567 204.949 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0043 1.0220 2672.96 13.148 1.902 07-Apr-08 04:15 56 240.95 172.45 32.00 3.00 0.567 203.843 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0043 1.0220 2672.86 13.076 2.038 07-Apr-08 04:30 56 242.18 171.04 32.00 3.00 0.567 203.525 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0042 1.0220 2673.02 13.057 2.174 07-Apr-08 04:45 56 242.40 169.99 32.00 3.00 0.567 202.992 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0042 1.0220 2673.00 13.022 2.310 07-Apr-08 05:00 56 243.29 167.80 32.00 3.00 0.567 202.050 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0041 1.0220 2673.05 12.962 2.44 07-Apr-08 05:15 56 243.55 168.45 32.00 3.00 0.567 202.549 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0041 1.0220 2673.15 12.995 2.58 07-Apr-08 05:30 56 243.07 168.15 32.00 3.00 0.567 202.169 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0041 1.0220 2673.02 12.970 2.715 07-Apr-08 05:45 56 242.86 169.39 32.00 3.00 0.567 202.825 1907.81 1.0000 1.0000 1.3280 1.0281 1.0002 1.0042 1.0220 2673.06 13.012 2.851 07-Apr-08 06:00 56 242.22 168.86 19.00 3.00 0.567 202.241 1907.81 1.0000 1.0000 1.3280 1.0419 1.0002 1.0042 1.0240 2714.41 13.175 2.988 07-Apr-08 06:15 62 244.23 150.63 19.00 3.00 0.567 191.803 1907.81 1.0000 1.0000 1.3280 1.0419 1.0002 1.0037 1.0240 2713.72 12.492 3.118 07-Apr-08 06:30 62 251.35 183.91 9.50 3.00 0.567 215.002 1907.81 1.0000 1.0000 1.3280 1.0524 1.0002 1.0044 1.0270 2749.67 14.188 3.266 07-Apr-08 06:45 62 252.03 187.62 9.50 3.00 0.567 217.453 1907.81 1.0000 1.0000 1.3280 1.0524 1.0002 1.0045 1.0270 2750.09 14.353 3.415 07-Apr-08 07:00 62 252.19 188.41 9.50 3.00 0.567 217.980 1907.81 1.0000 1.0000 1.3280 1.0524 1.0002 1.0045 1.0270 2750.18 14.388 3.565 07-Apr-08 07:15 62 252.08 188.46 4.00 3.00 0.567 217.961 1907.81 1.0000 1.0000 1.3280 1.0586 1.0002 1.0045 1.0280 2769.37 14.487 3.716 07-Apr-08 07:30 62 252.65 188.98 4.00 3.00 0.567 218.508 1907.81 1.0000 1.0000 1.3280 1.0586 1.0002 1.0045 1.0280 2769.56 14.524 3.867 07-Apr-08 07:45 62 252.39 188.95 4.00 3.00 0.567 218.378 1907.81 1.0000 1.0000 1.3280 1.0586 1.0002 1.0045 1.0280 2769.49 14.515 4.019 07-Apr-08 08:00 62 252.00 188.88 4.00 3.00 0.567 218.169 1907.81 1.0000 1.0000 1.3280 1.0586 1.0002 1.0045 1.0280 2769.37 14.501 4.170 07-Apr-08 08:15 62 251.97 188.88 3.00 3.00 0.567 218.156 1907.81 1.0000 1.0000 1.3280 1.0598 1.0002 1.0045 1.0280 2772.91 14.518 4.321 07-Apr-08 08:30 62 251.74 189.27 3.00 3.00 0.567 218.282 1907.81 1.0000 1.0000 1.3280 1.0598 1.0002 1.0045 1.0280 2772.87 14.527 4.472 07-Apr-08 08:45 62 251.38 188.91 3.00 3.00 0.567 217.918 1907.81 1.0000 1.0000 1.3280 1.0598 1.0002 1.0045 1.0280 2772.75 14.502 4.623 Expro Well Testing 1 of 3 5/1/2008 GAS FLOW REPORT CUSTOMER : Anadarko WELL NAME : Gubik #3 ® EXPRO START DATE: 06-Apr-08 END DATE: 07-Apr-08 TEST No. :Flow #3 - Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel d EXPRO SUPERVISOR : D.Jones / T. Park Petroleum Corporat~ SEPA RATOR GAS FA CTORS DATE 8 TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches H2O) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscf/d) GAS CUMM (MMscf) 07-Apr-OS 09:00 62 251.31 188.89 3.00 3.00 0.567 217.876 1907.81 1.0000 1.0000 1.3280 1.0598 1.0002 1.0045 1.0280 2772.72 14.498 4.774 07-Apr-08 09:15 62 251.14 188.77 3.00 3.00 0.567 217.733 1907.81 1.0000 1.0000 1.3280 1.0598 1.0002 1.0045 1.0280 2772.67 14.489 4.925 07-Apr-OS 09:30 62 251.25 188.41 2.00 3.00 0.567 217.573 1907.81 1.0000 1.0000 1.3280 1.0609 1.0002 1.0045 1.0280 2776.24 14.497 5.076 07-Apr-08 09:45 62 251.30 189.01 2.00 3.00 0.567 217.941 1907.81 1.0000 1.0000 1.3280 1.0609 1.0002 1.0045 1.0280 2776.29 14.522 5.227 07-Apr-0810:00 62 251.11 188.97 6.60 3.00 0.567 217.835 1907.81 1.0000 1.0000 1.3280 1.0557 1.0002 1.0045 1.0270 2759.99 14.429 5.378 07-Apr-0810:15 62 251.57 188.99 6.40 3.00 0.567 218.046 1907.81 1.0000 1.0000 1.3280 1.0559 1.0002 1.0045 1.0270 2760.82 14.448 5.528 07-Apr-0810:30 62 251.32 188.84 6.40 3.00 0.567 217.851 1907.81 1.0000 1.0000 1.3280 1.0559 1.0002 1.0045 1.0270 2760.74 14.434 5.67. 07-Apr-0810:45 62 251.18 188.64 6.20 3.00 0.567 217.675 1907.81 1.0000 1.0000 1.3280 1.0561 1.0002 1.0045 1.0270 2761.39 14.426 5.82 07-Apr-0811:00 62 253.81 185.95 6.20 3.00 0.567 217.246 1907.81 1.0000 1.0000 1.3280 1.0561 1.0002 1.0044 1.0270 2761.95 14.400 5.979 07-Apr-0811:15 62 260.64 181.23 6.90 3.00 0.567 217.338 1907.81 1.0000 1.0000 1.3280 1.0553 1.0002 1.0042 1.0280 2761.09 14.402 6.129 07-Apr-0811:30 62 262.25 181.26 6.90 3.00 0.567 218.026 1907.81 1.0000 1.0000 1.3280 1.0553 1.0002 1.0041 1.0280 2761.55 14.450 6.279 07-Apr-0811:45 62 263.78 182.92 6.90 3.00 0.567 219.660 1907.81 1.0000 1.0000 1.3280 1.0553 1.0002 1.0042 1.0290 2762.08 14.561 6.431 07-Apr-0812:00 62 265.55 184.49 6.90 3.00 0.567 221.340 1907.81 1.0000 1.0000 1.3280 1.0553 1.0002 1.0042 1.0290 2762.68 14.676 6.584 07-Apr-0812:15 62 265.55 184.46 21.00 3.00 0.567 221.322 1907.81 1.0000 1.0000 1.3280 1.0398 1.0002 1.0042 1.0260 2714.46 14.419 6.734 07-Apr-0812:30 62 264.60 185.38 21.00 3.00 0.567 221.476 1907.81 1.0000 1.0000 1.3280 1.0398 1.0002 1.0042 1.0260 2714.29 14.428 6.884 07-Apr-0812:45 62 263.31 186.44 21.00 3.00 0.567 221.566 1907.81 1.0000 1.0000 1.3280 1.0398 1.0002 1.0042 1.0260 2714.04 14.432 7.035 07-Apr-0813:00 62 264.18 185.92 21.00 3.00 0.567 221.622 1907.81 1.0000 1.0000 1.3280 1.0398 1.0002 1.0042 1.0260 2714.22 14.437 7.185 07-Apr-0813:15 62 263.45 186.40 22.00 3.00 0.567 221.601 1907.81 1.0000 1.0000 1.3280 1.0387 1.0002 1.0042 1.0260 2710.77 14.417 7.335 07-Apr-0813:30 62 265.91 184.21 22.00 3.00 0.567 221.322 1907.81 1.0000 1.0000 1.3280 1.0387 1.0002 1.0041 1.0260 2711.23 14.401 7.485 07-Apr-0813:45 62 266.90 182.97 22.00 3.00 0.567 220.986 1907.81 1.0000. 1.0000 1.3280 1.0387 1.0002 1.0041 1.0260 2711.39 14.380 7.635 07-Apr-0814:00 62 267.65 182.52 22.00 3.00 0.567 221.024 1907.81 1.0000 1.0000 1.3280 1.0387 1.0002 1.0041 1.0260 2711.55 14.384 7.785 07-Apr-0814:15 62 268.75 181.55 23.00 3.00 0.567 220.888 1907.81 1.0000 1.0000 1.3280 1.0376 1.0002 1.0040 1.0260 2708.46 14.358 7.935 07-Apr-0814:30 62 269.22 181.18 23.00 3.00 0.567 220.856 1907.81 1.0000 1.0000 1.3280 1.0376 1.0002 1.0040 1.0260 2708.55 14.357 8.084 07-Apr-0814:45 62 269.07 181.91 24.00 3.00 0.567 221.239 1907.81 1.0000 1.0000 1.3280 1.0365 1.0002 1.0040 1.0260 2705.27 14.364 8.234 07-Apr-0815:00 62 267.67 183.57 24.00 3.00 0.567 221.667 1907.81 1.0000 1.0000 1.3280 1.0365 1.0002 1.0041 1.0260 2705.04 14.391 8.384 07-Apr-0815:15 62 265.97 186.22 23.00 3.00 0.568 222.551 1907.81 1.0000 1.0000 1.3270 1.0376 1,0002 1.0042 1.0260 2705.86 14.452 8.5 07-Apr-0815:30 62 262.65 188.95 23.00 3.00 0.568 222.773 1907.81 1.0000 1.0000 1.3270 1.0376 1.0002 1.0043 1.0250 2705.23 14.464 8.68 07-Apr-0815:45 62 263.50 188.31 25.00 3.00 0.568 222.755 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0043 1.0250 2698.87 14.429 8.835 07-Apr-0816:00 62 265.13 186.72 25.00 3.00 0.568 222.497 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0042 1.0250 2699.15 14.413 8.985 07-Apr-0816:15 62 265.03 187.19 26.00 3.00 0.568 222.735 1907.81 1.0000 1.0000 1.3270 1.0344 1.0002 1.0042 1.0250 2695.91 14.411 9.135 07-Apr-0816:30 62 264.14 187.85 26.00 3.00 0.568 222.753 1907.81 1.0000 1.0000 1.3270 1.0344 1.0002 1.0043 1.0250 2695.74 14.412 9.286 07-Apr-0816:45 62 261.22 189.87 25.00 3.00 0.568 222.706 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0044 1.0250 2698.43 14.423 9.436 07-Apr-0817:00 62 259.41 191.00 25.00 3.00 0.568 222.592 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0044 1.0250 2698.08 14.414 9.586 07-Apr-0817:15 62 285.16 156.48 25.00 3.00 0.568 211.239 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0033 1.0270 2702.24 13.699 9.729 07-Apr-0817:30 62 286.02 167.68 25.00 3.00 0.568 218.997 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0035 1.0270 2703.07 14.207 9.877 07-Apr-0817:45 62 285.69 167.66 25.00 3.00 0.568 218.858 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0035 1.0270 2702.99 14.198 10.025 07-Apr-0818:00 62 285.55 168.09 25.00 3.00 0.568 219.085 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0035 1.0270 2702.98 14.212 10.173 07-Apr-0818:15 62 286.69 167.50 25.00 3.00 0.568 219.136 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0035 1.0280 2703.22 14.217 10.321 07-Apr-0818:30 62 290.47 164.22 25.00 3.00 0.568 218.406 1907.81 1.0000 1.0000 1.3270 1.0355 1.0002 1.0034 1.0280 2703.98 14.173 10.468 07-Apr-0818:45 62 292.10 164.24 27.00 3.00 0.568 219.031 1907.81 1.0000 1.0000 1.3270 1.0333 1.0002 1.0034 1.0280 2697.78 14.181 10.616 07-Apr-0819:00 62 282.33 169.37 27.00 3.00 0.568 218.674 1907.81 1.0000 1.0000 1.3270 1.0333 1.0002 1.0036 1.0270 2695.70 14.147 10.763 Expro Well Testing 2 of 3 5/1/2008 GAS FLOW REPORT ® CUSTOMER : Anadarko WELL NAME : Gubik #3 EXPRO START DATE: 06-Apr-08 END DATE: 07-Apr-08 TEST No. :Flow #3 - Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel ~ kl EXPRO SUPERVISOR : D.Jones / T. Park Petroleum Corporati~ SEPARATOR GAS FACTORS DATE & TIME (dd-mmm-yy hh:mm) CHOKE SIZE (64ths) Pf (psia) DIFF. PRESS (inches Hz0) GAS TEMP (°F) ORIFICE SIZE (inches) GAS GRAVITY SORT Fb Fpb Ftb Fg Ftf Fr Y Fpv C' GAS RATE (MMscNd) GAS CUMM (MMscf) 07-Apr-0819:15 62 283.92 169.68 0.00 3.00 0.568 219.489 1907.81 1.0000 1.0000 1.3270 1.0632 1.0002 1.0036 1.0330 2789.99 14.697 10.917 07-Apr-0819:30 62 284.53 169.16 0.00 3.00 0.568 219.388 1907.81 1.0000 1.0000 1.3270 1.0632 1.0002 1.0036 1.0330 2790.16 14.691 11.070 07-Apr-0819:45 62 284.93 166.54 0.00 3.00 0.568 217.835 1907.81 1.0000 1.0000 1.3270 1.0632 1.0002 1.0035 1.0330 2790.13 14.587 11.221 07-Apr-08 20:00 62 281.63 169.73 30.00 3.00 0.567 218.635 1907.81 1.0000 1.0000 1.3280 1.0302 1.0002 1.0036 1.0260 2688.02 14.105 11.368 07-Apr-08 20:15 62 282.05 172.22 30.00 3.00 0.567 220.397 1907.81 1.0000 1.0000 1.3280 1.0302 1.0002 1.0037 1.0260 2688.26 14.220 11.517 07-Apr-08 20:30 62 279.85 174.12 30.00 3.00 0.567 220.743 1907.81 1.0000 1.0000 1.3280 1.0302 1.0002 1.0037 1.0260 2687.86 14.240 11.665 07-Apr-08 20:45 62 272.38 180.75 30.00 3.00 0.567 221.884 1907.81 1.0000 1.0000 1.3280 1.0302 1.0002 1.0040 1.0250 2686.53 14.306 11.81 07-Apr-08 21:00 62 264.59 185.86 28.00 3.00 0.567 221.758 1907.81 1.0000 1.0000 1.3280 1.0323 1.0002 1.0042 1.0250 2691.49 14.325 11.9 07-Apr-08 21:15 62 260.83 187.53 28.00 3.00 0.567 221.164 1907.81 1.0000 1.0000 1.3280 1.0323 1.0002 1.0043 1.0240 2690.74 14.282 12.112 07-Apr-08 21:30 62 263.92 183.87 28.00 3.00 0.567 220.288 1907.81 1.0000 1.0000 1.3280 1.0323 1.0002 1.0042 1.0250 2691.22 14.228 12.260 07-Apr-08 21:45 62 266.77 181.28 28.00 3.00 0.568 219.909 1907.81 1.0000 1.0000 1.3270 1.0323 1.0002 1.0041 1.0250 2689.50 14.195 12.408 07-Apr-08 22:00 62 268.27 180.13 28.00 3.00 0.568 219.826 1907.81 1.0000 1.0000 1.3270 1.0323 1.0002 1.0040 1.0250 2689.78 14.191 12.556 Expro Well Testing 3 of 3 5/1/2008 PRODUCTION TANK DATA SHEET CUSTOMER : Anadarko Total Fluid Production: O EXPRO START DATE: 06-Apr# 8 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up 25.83 bbls /Oln~~ ~ Petroleum Corporation Start End Tank Previous Strap Curren t Strap Fluid Inc. BS &W H2O Inc. H2O Cum H2O Rate Fluid Inc. Fluid Cum Fluid Rate Date & Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 06-Apr-08 22:18 06-Apr-08 22:30 1 1.00 5.50 1.00 8.00 4.17 0.00% 0.00% 0.00 0.00 0.00 4.17 4.17 500.10 06-Apr-08 22:30 06-Apr-08 22:45 2 4.00 6.00 4.00 9.25 5.42 0.00% 0.00% 0.00 0.00 0.00 5.42 9.59 520.10 06-Apr-08 22:45 06-Apr-08 23:00 1 1.00 8.00 1.00 11.00 5.00 0.00% 0.00% 0.00 0.00 0.00 5.00 14.59 480.10 06-Apr-08 23:00 06-Apr-08 23:15 2 4.00 9.25 4.00 11.00 2.92 0.00% 0.00% 0.00 0.00 0.00 2.92 17.50 280.06 06-Apr-08 23:15 06-Apr-08 23:30 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 17.50 0.00 06-Apr-08 23:30 06-Apr-08 23:45 2 4.00 11.00 4.00 11.25 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 17.92 40.01 06-Apr-08 23:45 07-Apr-08 00:00 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 17.92 0.00 07-Apr-08 00:00 07-Apr-08 00:30 2 4.00 11.25 4.00 11.50 0.42 1.50% 0.00% 0.00 0.00 0.00 0.41 18.33 19.70 07-Apr-08 00:30 07-Apr-08 01:00 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 18.33 0.00 07-Apr-08 01:00 07-Apr-08 01:30 2 4.00 11.50 4.00 11.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 18.33 0.00 07-Apr-08 01:30 07-Apr-08 02:00 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 18.33 0.00 07-Apr-08 02:00 07-Apr-08 03:00 2 4.00 11.50 5.00 0.00 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 19.16 20.00 07-Apr-08 03:00 07-Apr-08 04:00 2 5.00 0.00 5.00 0.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 19.16 0.00 07-Apr-08 04:00 07-Apr-08 05:00 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 19.16 0.00 07-Apr-08 05:00 07-Apr-08 06:00 1 1.00 11.00 1.00 11.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 19.16 0.00 07-Apr-08 06:00 07-Apr-08 07:00 1 1.00 11.00 2.00 0.00 1.67 0.00% 0.00% 0.00 0.00 0.00 1.67 20.83 40.01 07-Apr-08 07:00 07-Apr-08 08:00 1 2.00 0.00 2.00 0.50 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 21.66 20.00 07-Apr-08 08:00 07-Apr-08 08:30 1 2.00 0.50 2.00 0.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 21.66 0.00 07-Apr-08 08:30 07-Apr-08 09:00 2 5.00 0.00 5.00 0.25 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 22.08 20.00 07-Apr-08 09:00 07-Apr-08 09:30 1 2.00 0.50 2.00 0.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 22.08 0.00 07-Apr-08 09:30 07-Apr-08 10:00 2 5.00 0.25 5.00 0.25 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 22.08 0.00 07-Apr-08 10:00 07-Apr-08 10:30 1 2.00 0.50 2.00 0.75 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 22.50 20.00 07-Apr-08 10:30 07-Apr-08 11:00 2 5.00 0.75 5.00 0.75 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 22.50 0.00 07-Apr-08 11:00 07-Apr-08 11:30 1 2.00 0.75 2.00 1.00 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 22.91 20.00 07-Apr-08 11:30 07-Apr-08 12:00 2 5.00 0.75 5.00 0.75 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 22.91 0.00 07-Apr-08 12:00 07-Apr-08 12:30 1 2.00 1.00 2.00 1.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 22.91 0.00 07-Apr-08 12:30 07-Apr-08 13:00 2 5.00 0.75 5.00 1.00 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 23.33 20.00 07-Apr-08 13:00 07-Apr-08 13:30 1 2.00 1.00 2.00 1.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 23.33 0.00 07-Apr-08 13:30 07-Apr-08 14:00 2 5.00 1.00 5.00 1.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 23.33 0.00 07-Apr-08 14:00 07-Apr-08 14:30 1 2.00 1.00 2.00 1.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 23.33 0.00 07-Apr-08 14:30 07-Apr-08 15:00 2 5.00 1.00 5.00 1.25 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 23.75 20.00 07-Apr-08 15:00 07-Apr-08 15:30 1 2.00 1.00 2.00 1.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 23.75 0.00 07-Apr-O8 15:30 07-Apr-08 16:00 2 5.00 1.25 5.00 1.50 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 24.17 20.00 07-Apr-08 16:00 07-Apr-08 16:30 1 2.00 1.00 2.00 1.25 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 24.58 20.00 07-Apr-08 16:30 07-Apr-08 17:00 2 5.00 1.50 5.00 1.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 24.58 0.00 07-Apr-08 17:00 07-Apr-08 17:30 1 2.00 1.25 2.00 1.50 0.42 0.00% 0.00% 0.00 0.00 0.00 0.42 25.00 20.00 Expro Well Testing 1 of 2 5/1/2008 PRODUCTION TANK DATA SHEET CUSTOMER :Anadarko Total Fluid Production: ~/ WELL NAME : Gubik #3 ® ~XP~ START DATE: 06-Apr-08 END DATE: 07-Apr-08 TEST No.: Flow #3 - Tuluvak Clean-up 25.83 bbls ~„a'd~'I~w ~ Petroleum Corporation Start End Tank Previous Strap Current Strap Fluid Inc. BS &W H2O Inc. H2O Cum H2O Rate Fluid Inc. Fluid Cum Fluid Rate Date & Time Date 8~ Time No. feet in feet in bbl Solids Water bbl bbl bbl/d bbl bbl bbl/d 07-Apr-08 17:30 07-Apr-08 18:00 2 5.00 1.50 5.00 1.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 25.00 0.00 07-Apr-08 18:00 07-Apr-08 18:30 1 2.00 1.50 2.00 1.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 25.00 0.00 07-Apr-08 18:30 07-Apr-08 19:00 2 5.00 1.50 5.00 1.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 25.00 0.00 07-Apr-08 19:00 07-Apr-08 20:00 1 2.00 1.50 2.00 2.00 0.83 0.00% 0.00% 0.00 0.00 0.00 0.83 25.83 20.00 07-Apr-08 20:00 07-Apr-08 21:00 2 5.00 1.50 5.00 1.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 25.83 0.00 07-Apr-08 21:00 07-Apr-08 22:00 1 2.00 2.00 2.00 2.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 25.83 0.00 L Expro Well Testing 2 of 2 5/1/2008 EXPRO Job Log CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 06-Apr-08 END DATE : 07-Apr-08 TEST No. : Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : D. Jones / T. Park Date Time dd-mm-yy hh:mm Operations 6-Apr-08 18:00 Shift handover with day crew. Tk #1= 1' 5.50"= 19.37 bbl Tk #2= 4' 6.00"= 80.21 bbl; total bbl= 99.58 bbl 18:20 Schlumberger prepared to fire guns. 2-inch Orifice plate in the upper chamber of Daniels meter on the separator. McOH SG = 0.802 @ 10 C = 6.69 ppg 18:29 Schlumberger fired guns; 385-400 psi at surface. 18:33 Zeroed adjustable choke. Lined up to Tk #1. 20:35 Schlumberger stabbed lubricator for second gun run. 21:13 Schlumberger fired guns; 430 to 440 psi at surface. 21:17 Started McOH injection. 21:30 McOH= 15.00" McOH injected= 4 bbl 21:56 Schlumberger rigged off wellhead. 22:10 Safety system charged. 22:18 Opened well on 16/64ths adjustable choke. 22:30 Diverted from Tk #1 to Tk #2 Tk #1= 1' 8.00" 22:33 Gas at tanks 22:42 Increased choke to 24/64ths adjustable. Diverted to flare stack. 22:45 Diverted from Tk #2 to Tk #1 Tk #2= 4' 9.25" 2-inch orifice plate in service on the separator. Gas Gravity = 0.583 BS&W= 100% diesel; Fluid wt. = 0.807 @ 20.3 C = 6.70 ppg 23:00 Diverted from Tk #1 to Tk #2 Tk #1= 1' 11" Increased choke to 32/64ths adjustable. 23:10 2-inch orifice plate out of service on the separator. 23:12 3-inch orifice plate in service on the separator. 23:15 Diverted Tk #2 to Tk #1. Tk#2=4'11" Flare platform temp = 30 F 23:25 Diverted to heater coils 23:30 3-inch orifice plate out of service on the separator. Increased choke to a 40/64ths adjustable. Diverted TK #1 to Tk #2 Tk #1= 1' 11" 23:45 Diverted from Tk #2 to Tk #1 Tk #2 = 4' 11.25" Gas Gravity = 0.571 7-Apr-08 0:00 Diverted from Tk #1 to Tk #2 Tk #1= 1' 11" BS&W= 1.5 % sediment Gas Gravity= 0.571 Expro Well Testing 1 of 5 5/1 /2008 • Job Log CUSTOMER :Anadarko TEST No. : Tuluvak Clean-up EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel START DATE : 06-Apr-08 EXPRO SUPERVISOR : D. Jones / T. Park END DATE : 07-Apr-08 Date Time dd-mm-yy hh:mm Operations 7-Apr-08 0:30 Fluid wt.= 6.81 ppg Increased choke to a 48/64ths adjustable. Diverted from Tk #2 to Tk #1 Tk #2= 4' 11.50" H2S = 0 ppm; COZ = 0.00% McOH = 7.00" 1:00 Diverted from Tk #1 to Tk #2 Tk #1= 1' 11" 1:30 Diverted from Tk #2 to Tk #1 Tk #2= 4' 11.50" McOH = 4.50" McOH injected = 84 gal 2:00 Diverted from Tk #1 to Tk #2 (switched to 1 hr tank readings). Tk#1= 1' 11" 2:30 McOH = 2.25" McOH injected = 101 gal Switched McOH tote AC 10052 (2.25") with AC 10029 (39.25") 3:00 Tk #1 = 5' 0.00" 3:05 Observed WHP gradually increasing. 3-inch orifice plate out of service on the separator. Switched from 2" side of choke to 1"side. 3:13 3-inch orifice plate in service on the separator. 3:15 Pulled 2" adjustable choke; found piece of rubber restricting flow. Heater on bypass. 3:17 3-inch orifice plate out of service on the separator. 3:30 3-inch orifice plate in service on the separator. McOH = 38.25" McOH injected = 109 gal 4:00 Gas Gravity = 0.567 Diverted from Tk #2 to Tk #1. Tk #2 = 5' 0.00" 4:06 Switched generators. 4:30 McOH = 36.25" McOH injected = 124 gal 5:00 Tk#1= 1' 11" 5:39 Injected methanol upstream of the gas back pressure valve on the separator. 6:00 Increased choke to a 62/64ths adjustable. Tk #1 = 1' 11" McOH = 32.25" McOH injected = 151 gal 6:01 Decreased choke to a 52/64ths adjustable. 6:11 3-inch orifice plate out of service on the separator. Increased choke to 62/64ths adjustable. 6:13 3-inch orifice plate in service on the separator. 6:15 Started McOH injection at minimum rate upstream of the gas back pressure valve on the separator. 7:00 Tk #1 = 2' McOH = 30" McOH injected = 172 gal Expro Well Testi ng 2 of 5 5/1/2008 u Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 06-Apr-08 END DATE : 07-Apr-08 TEST No. : Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : D. Jones / T. Park -Date Time dd-mm-yy hh:mm Operations 7-Apr-08 8:00 Tk #1 = 2' 0.5" McOH = 28" McOH injected = 187 gal 8:30 Diverted from Tk #1 to Tk #2. Tk#1 =2'0.5" 9:00 Diverted from Tk #2 to Tk #1. Tk#2=5'0.25" McOH = 25.25" McOH injected = 208 gal 9:30 Diverted from Tk #1 to Tk #2. Tk#1 =2'0.5" 10:00 Diverted from Tk #2 to Tk #1. Tk #2 = BS&W= 0.6 % sediment Fluid wt.= 7.28 ppg McOH = 22.75" McOH injected = 228 gal 10:30 Diverted from Tk #2 to Tk #1. Tk#1 =2'0.75" 11:00 Diverted from Tk #1 to Tk #2. Tk#2=5'0.75" McOH = 20.25" McOH injected = 247 gallons Gas Gravity = 0.567 11:30 Diverted from Tk #2 to Tk #1. Tk #1 = 2' 1" 12:00 Diverted from Tk #2 to Tk #1. Tk#2=5'0.75" McOH = 17.75" McOH injected = 266 gallons Gas Gravity = 0.569 12:30 Diverted from Tk #1 to Tk #2. Tk#1 =2'1" 13:00 Diverted from Tk #2 to Tk #1. Tk#2=5'1" McOH = 15.50" McOH injected = 283 gallons Gas Gravity = 0.569 13:30 Diverted from Tk #1 to Tk #2. Tk #1 = 2' 1" Fluid wt = 7.1 ppg BS&W = 1 % sediment, 99% McOH /Diesel mixture 14:00 Diverted Tk #2 to Tk #1. Tk#2=5'1" McOH = 12.50" McOH injected = 306 gallons Gas Gravity = 0.568 14:30 Diverted from Tk #1 to Tk #2. Expro Well Testi ng 3 of 5 5/1 /2008 • Job Log CUSTOMER :Anadarko TEST No. : Tuluvak Clean-up EXPRO WELL NAME : Gubik #3 CUSTOMER REP. :Dennis McDaniel START DATE : 06-Apr-08 EXPRO SUPERVISOR : D. Jones / T. Park END DATE : 07-Apr-08 Date Time dd-mm-yy hh:mm Operations 7-Apr-08 14:30 Tk #1 = 2' 1" 15:00 Diverted Tk #2 to Tk #1. Tk #2 = 5' 1.25" McOH = 10.50" McOH injected = 321 gallons Gas Gravity = 0.568 15:30 Diverted from Tk #1 to Tk #2. Tk #1 = 2' 1" 16:00 Diverted from Tk #2 to Tk #1. Tk#2=5'1.5" McOH = 8.50" McOH injected = 321 gallons Fluid wt = 7.1 ppg pH=7 Salinity = 35,000 BS&W = 1 % sediment, 99% McOH /Diesel mixture 16:30 Diverted from Tk #1 to Tk #2. Tk #1 = 2' 1.25" 17:00 Diverted from Tk #2 to Tk #1. Tk#2=5'1.5" McOH = 5.5" McOH Injected = 359 gallons 17:02 Raised the orifice plate in the separator to raise the static pressure. Orifice plate in service on the separator with the static pressure raised from 243 psig to 273 psig. 17:30 Diverted from Tk #1 to Tk #2. Tk #1 = 2' 1.50" 18:00 Diverted from Tk #2 to Tk #1. Tk #2= 5' 1.50" Switched from McOH tote AC 10029 to AC 10051 AC 10029= 2.50" AC 10051= 38.75" Put remaining McOH from AC 10029 into chemical injection pump on separator. 18:30 Diverted from Tk #1 to Tk #2 Tk #1= 2' 1.50" 19:00 Diverted from Tk #2 to Tk #1 Tk #2= 5' 1.50" McOH= 36.25" Methanol injected= 402 gal 20:00 Diverted from Tk #1 to Tk #2 Tk#1=2'2.00" McOH= 33.75 Methanol injected= 421 gal Gas Gravity = 0.567 21:00 Diverted from Tk #2 to Tk #1 Tk #2= 5' 1.50" McOH= 31.00" McOH injected= 442 gal Gas Gravity = 0.568 Expro Well Testi ng 4 of 5 5/1/2008 • Job Log EXPRO CUSTOMER :Anadarko WELL NAME : Gubik #3 START DATE : 06-Apr-08 END DATE : 07-Apr-08 U TEST No. : Tuluvak Clean-up CUSTOMER REP. :Dennis McDaniel EXPRO SUPERVISOR : D. Jones / T. Park Date Time dd-mm-yy hh:mm Operations 7-Apr-08 21:50 Changed to 1 sec log frequency for build-up. 22:00 Shut in well; choke closed. Tk #1= 2' 2.00" McOH= McOH injected= 442 gal McOH stopped. Lined up to bypass to tanks. Plate in upper chamber. 22:06 Blew down separator. Expro Well Testing 5 of 5 5/1/2008 EXPRO Wellhead Plot Wellhead Plot - Tuluvak Clean-up Anadarko Gubik #3 Petroleum Corporation 1000 100 90 80 70 H 60 t ~ LL ~~ N = 50 y m ~e o~ 0 v 40 30 20 10 0 900 800 700 600 vi w a 500 vii U Q- ~ ... a 400 = 300 200 100 0 06-Apr-08 06-Apr-08 06-Apr-08 06-Apr-08 06-Apr-08 06-Apr-08 06-Apr-08 06-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 18:00 18:30 19:00 19:30 20:00 20:30 21:00 21:30 05:00 12:30 20:00 Date & Time -~ W HT -~ Choke Size --f- W HP -+- CSG Expro Well Testing Page 1 5/1/2008 •I •I EXPRO 300 250 d ~ 200 N fA d a`~ ~_ _ 0 N d ~ ~ 150 ya .~ ~~+ o ~~ Y Q (~ ~/ L m 100 Separator Plot Separator Plot - Tuluvak Clean-up Anadarko Gubik #3 Petroleum Corporation 70 60 50 d 3 40 -- - - - ~ o L _~ ~.+ 30 L a N 20 50 0 10 0 06-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 22:45 01:15 03:45 06:15 08:45 11:15 13:45 16:15 18:45 21:15 Date & Time -~ Static Press ~ Diff Press -~--Temperature Expro Well Testing Page 1 5/1/2008 600 500 400 m w ea c a 300 LL ~ 'D .~ 200 100 0 06-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 07-Apr-08 22:15 00:45 03:15 05:45 08:15 10:45 13:15 15:45 18:15 20:45 Date & Time ^ Fluid Rate -•- Gas Rate Expro Well Testing Page 1 EXPRO Production Plot Production Plot - Tuluvak Clean-up Anadarko Gubik #3 d~-u,l~ ~ Petroleum Corporation ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ 16 14 12 • 10 °r' ~ c~ N 6 4 2 0 5/1 /2008 ~~ Petroburri Corporation c Gubik #3 P&A Well Schematic 30" Auger Hole 12-1/4" Hole TULUVAK FORMATION 1,590'-1,640' (50') Thru-tubing CIBP w/o cement ; 1,740' TVD NANUSHUK FORMATION 3,542'-3,612' (40') 3,612'-3,652' (40') 8-3/4" Hole • 16" 65# H-40 Conductor at 105' TVD 9 5/8" 40# L-80 BTC Casing at 1,014' TVD retrievable Packer at ,517' TVD > BWD Permanent Packer w/ opHead at 1,700' TVD a-tubing CIBP w/ 25' cement op at ±3,500' TVD 3# L-80 BTC-M Casing at 0' TVD Total Depth 3,950' TVD WELL LOG TRANSMITTAL To: Alaska Oil & Gas Conservation Commission 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 Attn: Librarian RE: SDL Formation Evaluation Logs: Gubik 3 &Gubik 3 BPOI ~ U ,} Alaska ~~ -.~... Inc ...,..~~ ~s, ~'" ;, .,,,J;~~t~ horac~~ W Apri123, 2008 AK-AM-5551160 Gubik 3 & Gubik3 BPOl: Final Mudlogs - 8 Logs End of Well Report including CD-ROM with Digital Data & Final Graphic Files 1 Sets 1 Sets PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage,.Alaska, 99518 (907 273 ~SS9 ,~ APR ~~ .r ?O~~f3 Date: ,{ t,,, ;t,4,~ r/ 1 Signed: ,~_ l ~ 1 ~i~ ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 a Petr©I~~.+~~ Corpo~atton April 18, 2008 Mr. Daniel Seamount, Chair ~~~ ~~~~ Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Guh~k,#~ `~?b3> Dear Mr. Seamount, 'This is a report of Anadarko Petroleum Corporation's well operations on the Gubik #3 for the period April 11 through April 17, 2008, inclusive. April 11, 2008 Continue R/D test equipment. Inject 186 bbls produced fluids into perfs. R/t1 lubricator and perf tubing 1,498' -1,506' w/ l 7 holes. R/D lubricator. R/U to cement down tubing w/ return line on annulus going through choke. Pump 22 bbls cmt down tbg then open choke sufficiently to maintain backpressure and pump additional 35 bbls cmt. Result: 5 bbls went into perfs, 17.7 bbls in tbg and 39.5 bbls in annulus. Good cmt returns to surface. Shut well in to WOC. April 12, .2008 Continue R/D test equipment. Cleaz area around wellhead to provide access. N/D csg valve and tree. Tag TOC w/ T-bar, TOC at 7' below tbg hgr. R/U heaters and hoses to btm of cellar to melt and remove ice. April 13, 2008 Clean water and. debris from cellaz. Cut off all casing strings below 9-5/8" hanger and remove all wellhead equipment. Tag cement in tubing and all annuli. Notify AOGCC inspector and prep to make final casing cutoff at +5' below tundra level. April 14, 2008 Make final cut at 6' below tundra level. Cement at surface in tubing and all annuli. Got okay from AOGCC to weld marker plate on. Weld on marker plate. Attempt to remove cellar w/ forks on loader - no good. Order out backhoe -will be on location in 2-3 days. I~ LJ April 15, 2008 Demob fluids and equipment. April 16, 2008 Demob fluids and equipment. April 17, 2008 Demob fluids and equipment. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION b~'` c~ ~e~rno~e Bill Penrose Vice President 1 Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 -_ - _ -__ - ~~r ~~~~ ~~~~~~~~~y Petro-Canada Geological Operations, Room 238 150- 6`h Avenue S.W. Calgary, Alberta T2P 3Y7 Attn: Cathy Vitale BG International Ltd. 500-222-3~d Avenue S.W. Calgary, AB T2P OB4 Attn: Chris Opekar Field Prints Final Prints CDROM Field Prints Final Prints CDROM Alaska Oil 8~ Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian Field Prints Final Prints CDROM Tim Ryherd, Geologist Dept. of Natural Resources -Division of Oil & Gas State of Alaska 550 W. 7`h Avenue, Suite 800 Anchorage, AK 99501-3510 Field Prints Final Prints CDROM 2 Prints 2 Prints 1 (LIS data and Final Print PD Graphics) 2 Prints 2 Prints 1 (LIS data and Final Print PD Graphics) 1 Print 1 Print 1 (LIS data and Final Print PD Graphics) 1 Print 1 Print 1 (LIS data and Final Print PD Graphics) ;;>~~ ~JO?~~ ,~ r, Confidential ao~ -~7~ `~l6 «6 Page 2 of 2 4/9/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 11, 2008 8:13 AM To: 'Bill Penrose' Subject: RE: Gubik #3 (207-176) P8~A Bill, So far as I know, everything deeper than 5' below tundra may be left in place. Tom Maunder, PE AOGCC From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, April 11, 2008 7:27 AM To: Maunder, Thomas. E (DOA) Subject: Gubik P&A Tom, Here's a question from the guys working the P&A at Gubik #3. The well cellar is 12' deep. They have to cut off the well 5' below tundra level and weld on the marker plate. Their question: Do the cellar box and cement floor need to be removed below the 5' level or can they be left in place and buried along with the well stub? Regards, ~~ Vice President /Drilling Manager Fairweather E8~P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 4/11/2008 • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 Pekrale~rr~~ Corparat~on April 11, 2008 Mr. Daniel Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7`i' Ave., Suite 100 Anchorage, Alaska 99501 ~~ "'~ ~ ` ~ RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Seamount, This is a report of Anadarko Petroleum Corporation's well operations on the Gubik #3 for the period April 4 through April 10, 2008, inclusive. April 4, 2008 Continue flowing well while waiting for fishing tools from Deadhorse. Well choked itself off while R/U Kinley cutter. Shut in well at choke and drop cutter. Cut wire, recovered same and Kinley cutter. RIH w/ LIB, found fish at 3,244', POH. Stop downhole methanol injection, secure well and monitor SITP. Apri15, 2008 R/U WL unit, lubricator and BOP's. RIH w/ 3-1I2" EZSV bridge plug, log on depth and set at 3,185' (in middle of a joint). Release running tool and tag EZSV to confirm placement. POH. SITP 1,300 psi. Bleed down to 140 psi for drawdown test on EZSV - good test. R/U 2-1/8" x 32' dump bailer. Mix cement and fill bailer. R.IH w/ bailer, tag EZSV, P/L7 15' and dump 12.5' cement on retainer. POH, re-dress hailer. Apri16, 2008 RIH w/ cement-filled dump bailer. Bailer failed, POH. Re-dress and re-toad bailer, RIH. Dump 12.5' of cement on top of previous 12.5' cement, POH. Load hole w/ 35 bbls diesel. Perform 20-minute pressure tests of CIBP/cement at 650 psi, 1,045 psi and 2,050 psi. MIU CIBP on WL, RIH. Set CIBP at 1,750'. POH. Pressure test CIBP to 960 psi for 20 minutes. P/U 25' of 2-1/2" HC perforating guns, RIH, Perforate 1,615' to 1,640' w/ 6 spf. POH and P/U another 25' length of 2-1/2" HC guns, RIH. Perforate 1,590' - 1,615' w/ 6 spf. POH, RID WL. Open well for cleanup through testing facilities. • April 7, 2008 Flow well through production testing facility at various choke settings. Shut well in for pressure build-up. April 8, 2008 Continue recording SITP. Apri19, 2008 Continue recording SITP. Commence rigging down tank farm and flare boom. April 10, 2008 Continue recording SITP. Continue rigging down testing equipment. MIRU cementing unit, slickline unit, hot oil unit and perf guns for well P&A. Begin heating water for cementing. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~i~ ~e~aro~e Bill Penrose Vice President f Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~ ~~. ~~~,~~~,;, DATE: April 06, 2008 P. I. Supervisor I FROM: Lou Grimaldi SUBJECT: Outer/Inner pressure test Petroleum Inspector Anadarko Gubik #3 PTD #207-176 Exploratory April 06, 2008: I witnessed the pressure test of abandonment plug in the tailpipe of Gubik 3. I arrived to find Little Red services rigged up and ready to pump down the tubing. Two tenths of a barrel was required to pressure up against the tubing plug to ~ 1095 psi. I observed a loss of 40 psi in the first 15 minutes and 10 psi in the second 15 minutes. The test of this down-hole plug was good. Attachments: None Non-Confidential Wellbore-Annulus plug verification Gubik 3 04-06-08 LG.doc Page 1 of 1 Maunder, Thomas E (D4Aj From: Maunder, Thomas E (DOA) Sent: Saturday, Apri105, 2008 12:25 PM To: 'Bill Penrose' Subject: RE: Plan Modification: Anadarko Gubik #3 ~• Bill, Your proposal is as we discussed. No real issue on moving the plug. With regard to the fluids, since they were produced from the well in the course of testing the lower interval you proposal is acceptable. Tom Maunder, PE AOGCC From: Bill Penrose [mailto:bill@fairweather.com] Sent: Saturday, Apri105, 2008 11:05 AM To: Maunder, Thomas E (DOA) Subject: Plan Modification: Anadarko Gubik #3 Tom, Per our discussion earlier, Anadarko has requested modification of its approved testing and P&A plan for Gubik #3 to show: 1. Moving of the bottom bridge plug in the bottom part of the completion uphole approximately 300' because of a fish and hydrate plug lower down, and 2. Use of the surtace fluid from the Nanushuk test (mostly diesel with minor KCI and methanol} as load fluid for the Tuluvak test and subsequent injection of that fluid and any other fluid originating in the Tuluvak test to be injected into the Tuluvak during P&A operations. Please confirm if this is acceptable to the Commission. Thanks and regards, Regards, ~e Pepe Vice President t Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 4/5/2008 • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907} 273-6300 ~nadarl~~ Petroleum Corporation April 4, 2008 Mr. Daniel Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 )/ ~2~hrn Anchorage, Alaska 99501 (~4" Y ~~ RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 2Q7-176) Deaz Mr. Seamount, This is a report of Anadarko Petroleum Corporation's well operations on Gubk #3 for the period Mazch 28 through April 3, 2008, inclusive. Mazch 2$, 2008 Continue R/U test equipment and instrumentation. M/U insulated line f! wellhead to choke manifold. Take on diesel for hot oiler. Set warning delineators. Pressure test annulus valves, pull BPV. R![J slickline unit, R1H, pull ball and rod from RHC plug then pull RHC plug. R/LT sensors on data header, re-spot heater and. power cables. Fill lines w/ warm diesel and pressure test all. Mazch 29, 2008 Finish preparing for test. Apply pressure to well, fire guns. Open well for 1-1 /2 hrs, shut in well for 3 hrs. R/tJ slickiine, RIH w/ 2.7" GR No obstructions found and verified that guns had dropped. Conduct swabbing operations using slickline unit. March 30, 2008 Continue swabbing until well came in. Flow well. R/U slickline and ilistall downhole gauges. Continue to flow well for duration of planned flow period. Shut in well for pressure build-up. March 31, 2008 WeII shut in far pressure build-up. April l , 2008 Continue pressure build-up. R/U slickline, retrieve downhole gauges, run GR to top of dropped guns at 3,681' SLM. R/D slickline, R/U e-line. RTH, re-perforate interval 3,612' - 3,652' w/ 2 gun runs, 2-112" hollow carriers at 6 spf. April 2, 2008 Continue re-perforating 3,542' - 3,582' w/ 2 gun runs, 2-1/2" hollow carriers at 6 spf. R/D a-line, open well to flow. Service tree valves while flowing. R/U a-line and run production Iog across perforated interval. R/D a-line, continue to flow well. Apri13, 2008 Continue flowing well. Obtain downhole water sample via slickline sample bailer. Run GR, tag up on and break through ice plug at tbg tail. Run. sample bailer, got stuck at tbg tail, pull out of rope socket. Recover fish after several attempts. Spot methanol on ice plug at tbg tail. RIH w/ GR, tag up on ice plug. Chip through ice, broke through and tools got blown up hole, stuck at 3,469' SLM. Hold 500 lbs overpull on line while arranging fishing tools from Deadhorse. If you. have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~~ ~ Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 M faker Atlas VUireli ' Gubik #3 AF's U 2~i?-; Petro-Canada Geological Operations, Roorp,~ ~c~,'.:. ~;C~f'il ili~;~lOtt 150- 6th Avenue S.W. ~Of8~0 Calgary, Alberta °' T2P 3Y7 Attn: Cathy Vitale Field Prints 2 Prints Final Prints 2 Prints CDROM 1 (LIS data and Final Print PD Graphics) BG International Ltd. 500-222-3rd Avenue S.W. Calgary, AB T2P 064 Attn: Chris Opekar Field Prints 2 Prints Final Prints 2 Prints CDROM 1 (LIS data and Final Print PD Graphics) Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian Field Prints Final Prints CDROM Tim Ryherd, Geologist Dept. of Natural Resources -Division of Oil & Gas State of Alaska 550 W. 7th Avenue, Suite 800 Anchorage, AK 99501-3510 Field Prints Final Prints CDROM C. ,I;~~ 1 Print 1 Print 1 (LIS data and Final Print PD Graphics) 1 Print 1 Print 1 (LIS data and Final Print PD Graphics) r ~ ~? ~~~~ ~` ~(ov~3 Confidential Page 2 of 2 3/28/2008 ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 ~adarl~~ Petroleum Corporation March 28, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on Gubik #3 for the period March 21 through March 27, 2008, inclusive. March 21, 2008 Continue limited work while drilling rig rigs down. Lay out equipment as possible, wire up electrical and corns. March 22, 2008 Assemble, raise and secure flare stack. Receive and spot cherry picker, additional heaters, pickup truck. Office unit warmed up and toms being installed. March 23, 2008 M/LJ line to flare stack. Install line heater in berm, fill w/ glycol and fuel and put heat on it. M/U lines to line heater, choke, separator and metering skid. Plug power into add'1 office skid and warm up. Prep area around wellhead for mats and scaffolding. March 24, 2008 Set mats and plywood across cellar. Spot testing SSV. R/U scaffolding around well and test scrubber and tent same. Install and insulate hoses to manifolds and tanks. M/U lines to test equipment. Warm line heater in preparation for test firing. Warm up data- gathering office. • March 25, 2008 R/U scan equip on separator and methanol injection pump. R/U crossover, safety valve and short section of line to wing valve on tree. Fire line heater and bring glycol up to operating temp. Insulate pipes and hoses, grease valves in choke manifold. V~ire line heater and office shacks. GCI work on comms. March 26, 2008 Continue rigging up lines. Air test lines w/ 130 psi for several hours. Receive and spot gen set, re-spot office skids, continue comet work. March 27, 2008 Continue rigging and insulating lines and instrumentation. Insulate ice pad around flare stack. Fire up and spot slickline unit and hot oil pumper. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 i • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 ada~ Petroloum Corporation March 21, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on Gubik #3 for the period March 14 through March 20, 2008, inclusive. March 14, 2008 3,950' MW 8.4 ppg Vis 2$ sec Inc14.65 deg L/D BHA. Perform 5,000 psi test on casing. R/U WL, run correlation GR/CCL log to TD and out. R/D WL. M/U 4-5/8" TCP guns, firing head, auto release, tubing and packer and RIH. Tag btm, pull up to pkr setting depth. Pump 64 bbls diesel, displace w/ 17 bbls brine. Drop ball and set pkr. Shear off of pkr, test pkr/annulus to 500 psi., POH, L/D DP. March 15, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Finish L/D DP and setting tools. R/U to run tbg. M/U and RIH w/ pkr, 2 chemical injection mandrels and two '/4" CI control lines on tubing. Land tbg hgr in wellhead, lock down, drop ball and set pkr. B/O landing jt, set BPV, clear floor. March 16, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Blow down all lines, hoses and mud manifold. R/D all BOPE and related valves and hoses. N/D 11" SM X 11" IOM adapter spool, N/tJ 3-1/8" SM production tree and test. Perform injection test down CI lines. Release rig at 22:30, 3/16/2008. March 17, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg Well testers rigging up while rig demobs. Prepare base for flare stack, hang floats in separator. Cold weather hampering operations. ~ i March 18, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg R/U as possible during rig demob which is in turn hampered by cold wx (-SOF). Arrange equip on ground, but cannot erect due to cranes being shut down by wx. March 19, 2008 3,950' MW 8.4 ppg Vis 28 sec Inc14.65 deg R/U of testing equipment mostly shut down due to weather (-53F). Prep to change out broken line heater, prepare flare stack for assembly and raising. March 20, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Send out non-functioning line heater, receive new one. Spot and prepare to raise flare mast. Spot and commission office unit. Waiting for rig components to get out of the way. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~c~ ~eamaae Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 Page 1 of 2 Maunder, Thomas E (DOA) From: Bill Penrose [bill@fairweather.com] Sent: Friday, March 21, 2008 8:39 AM To: Maunder, Thomas E (DOA) Subject: RE: Weekly Drilling Ops Reports -Anadarko Foothills Drilling Tom, In answer to your questions below: ~V~i \~~ 1. The upper packer setting pressure was 3,000 psi. The pressure was held for 15 minutes. 2. The casing was tested to 5,000 psi for 30 minutes on the 13th and charted. The well was later displaced to completion brine and another quick, uncharted 5-minute, 5,000 psi test put on it on the way out of the hole on the 14th to make sure all was still good. 3. After the upper packer was set, a 10-minute, 500 psi test was put on the annulus. Regards, ~~ ~e`vtadQ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 21, 2008 7:48 AM To: Bill Penrose Subject: RE: Weekly Drilling Ops Reports -Anadarko Foothills Drilling Thanks Bill, A couple of questions: 1. What was the setting pressure for the upper packer? Was the pressure held for a time to test the tubing? 2. The casing was tested to 5000 psi on March 14, was it a 30 minute test and charted? 3. Was any pressure test applied to the annulus after the packer was set? Thanks in advance. Tom Maunder, PE AOGCC Prom: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, March 21, 2008 7:03 AM To: Maunder, Thomas E (DOA) Cc: Alaska.DrillingOpsMgr@anadarko.com Subject: Weekly Drilling Ops Reports -Anadarko Foothills Drilling Tom, Please find attached the weekly Drilling Operations Reports for the Anadarko Gubik #3 and Chandler #1 wells. Regards, 3/24/2008 Page 2 of 2 ~c~ t'~e~ode Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 3124/200$ • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 March 14, 2008 ~adarl~~ Petroleum Corporation RECEIVE® Mr. Dan Seamount, Chair MAR 1 4 2008 Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 A{asica 4~ 8~ Gas Cons. COmnliSSiOn Anchorage, Alaska 99501 AttChOrage RE: Application for Sundry Approval: Completion, Testing and P&A Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Seamount, Anadarko Petroleum Corporation hereby applies for approval of the attached plans to complete, test and plug and abandon the Gubik #3. The well will be completed by the drilling rig after which the rig will be moved to the Chandler #1 drilling location and Gubik #3 will be tested and plugged and abandoned without the rig on location. The Gubik #3 wellbore will be used to test first the deeper Nanushuk interval then the shallower Tuluvak interval. Both are gas-bearing zones with no oil logged or expected. At the completion of testing the well will be permanently plugged and abandoned. Please find attached a Form 10-403 for this work and a detailed completion, testing and P&A procedure. If you have any questions or require additional information, please contact me at (907) 273-6302 or Bill Penrose at (907) 258-3446. Sincerely, ANADARKO PETROLEUM CORPORATION Chuck Rowe Drilling Operations Manager enclosures cc: Bill Penrose -Fairweather ORIGINAL 1 ~~ ~ ~ ~ ~ ~ SARAH PALIN, GOVERNOR A~S~A OIIJ ,~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5ERQATIOIQ COMI-IISSIOIYT ANCHORAGE,AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chuck Rowe Alaska Drilling Operations Manger Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 Re: Exploration Well, Gubik #3 Sundry Number: 308-081 Dear Mr. Rowe: 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 ffie 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 day of March, 2008 Encl. '~, ~~ .~~ R~~~~V~ ~ ALA• OIL AND GASTCONSERVAT ON COMM SIO I APPLICATION FOR SUNDRY APPROVALS' MAR 1 4 20 ~ 20 AAC 25 Aso Alaska Oil & Gas Cons. 1. Type of Request: Abandon ^~ Suspend ^ Operational shutdown ^ Perforate Q i ther ^/ . Alter casing^ Repair well ^ Plug Perforations Stimulate^ Time Extension ^ Test Well Change approved prograri^ Pull Tubing^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Anadarko Petroleum Corporation Development ^ Exploratory ^ ` 207-176 3. Address: Stratigraphic ^ Service ^ 6. API Number: 3201 C Street, Suite 603, Anchorage, Alaska 99503 ~ 50-287-20017-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 1,767' Spacing Exception Required? Yes ^ No ^~ ~ Gubik #3 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~' ASRC Lease CA003 ~ 20 Exploratory 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): 3,950' 3,947' 3,827' 3,824' None None Casing Length Size MD TVD Burst Collapse Structural Conductor g5' 16" 105' 105' N/A NIA Surface gg7' 9.518" 1,007' 1,007' 5,750 psi 3,090 psi Intermediate Production 3,912' 7" 3,935' 3,932' 7,240 psi 5,410 psi 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: N/A Packers and SSSV MD (ft): N/A 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^~ Development ^ Service ^ 15. Estimated Date for 3/1212008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged Q Abandoned Q 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 2583446 Printed Name Chuck Rowe Title Alaska Drilling Operations Manager Signature / n Phone Date J E L 2c W ocr H ©v 273-6302 /~ M~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ a~"' (~~ Plug Integrity '~ BOP Test ^ Mechanical Integrity Test ^ Location C l earance ~ `` __ r i Other: ~~~ ~\ ~`~~~~8t~°~ Wc~'~SS iTJ~[.~~DE4C7~-pFZS~jCSC~.-~~ `` ` ~~ Subsequent Form Required: V~ APPROVED BY ~ I ~~ Approved b : OMMISSIONER THE COMMISSION D t y a e: ~: t,,,l ~ I l7 I I V h t_ ~~ ~ ~ ~ ~,1 Form 10-403 Revised 06/2006 l Submit in Duplicate cedar Petroleum Corporation COMPLETION & WELL TESTING PROCEDURE Final Copy GUBIK#3 (ALASKA FOOTHILLS) ANADARKO PETROLEUM CORPORATION AOGCC PERMIT No.: 207-176 API No: 50-287-20017-00 AFE #: 2013211 March 13, 2008 Version 2 *AOGCC Approved P&A Program* Completion Engineers Mark A. Conrad (NXS248) Dennis McDaniel (ZDRM7) .. i ~ Gubik #3 T1 N-R3E-17 ~nadarl~ Alaska Foothills Petroleum Corporation COMPLETION & WELLTESTING PROCEDURE GUBIK #3 ALASKA FOOTHILLS T1 N - R3E SECT 17 2411' FSL 1767' FEL CURRENT STATUS: Final Program v2 AOGCC Approved March 13, 2008 The Gubik #3 was drilled to a TD of 4,285'. However during the wiper trip before running logs, the BHA became stuck. We performed aback-off and left most of the BHA in the hole. Then a ±500' cement plug was set and used to bypass the original hole and drill to a TD of 3,950' md. 7" 26 ppf casing was run and cemented in place (included a stage collar @ 1,300'). The wellbore was left with ±13.6 ppg WBM . OBJECTIVES: To make a mud conditioning trip before running a CBL/USIT log, displace the WBM to a 8.43 ppg KCI completion brine and then run the proposed production equipment. Once the hanger is landed and the tree is nippled up, the rig will be demobilized and moved to the Chandler location. Once we can house the welltesting personnel, we will begin arig-less test of the Nanushuk & the Tuluvak Sands. The overall philosophy of the welltest for both sands will be a cleanup flow period followed by aflow-after-flow test. There will be an onsite reservoir engineer to help facilitate the testing process and analyze the data. AFE & Costs 2010339.DRL 2010339.CMP Total Costs $38,621,000 $2,462,000 $41,083,000 Days 19 42 61 * Costs are not accurately distributed between Drilling & Completion Elevations 195' Ground Elev (AMSL) 3,812' MD /3,810' TVD PBTD 215.5' RKB to MSL (Nabors 105E) 3,935' MD / 3,932' TVD TD 20.5' RKB to GL 95 ° F BH Temperature -1.5' THE to GL Reservoir Data Perfs BHP SIWHP Sand MD (TVD) SPF (psi) EMW BHT (psi) Tuluvak Gas 1,590'-640' MD/TVD 6 977 11.6 75 °F 935 3,542'-82' MD Nanushuk Gas 3,612'_ 52' MD 6 1,500? ±8.0 95 °F 1,450 (3,540 80 TVD) (3, 610 =52' TVD) NOTES: 1) Nanushuk BHP is from RCI data (suspect) 2) Tuluvak BHP is from RCI data 2 ~ ~ Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~~~ AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 TubularS (see attached schematic for detail) Casing -Actual IDmin Drift Burst Collapse Tensile 16" Conductor 65 ppf (0.375" wt) H-40 @105' 15.25 15.062 1,640 630 781,000 9 5/8" _._ Surface .._ 40 ppf (0.395" wt) L-80 BTC @ 1,014' " g.g35 8.679 5,750 3,090 947,000 Casmg_ _ m 12.25 hole 7„ Production 26 ppf (0.362" wt) L-80 BTC-M @ ' " 6.276 6.151 7,240 5,410 641,000 _ Casing____.._..__ in 8.75 hole _ 3,935 Tubing -Proposed IDmin Drift Burst Collapse Tensile 3-1/2" Production 9.2 ppf L-80 IBT-M 2.992 2.867 10,160 10,540 _ 207,220 _ Workstring -Proposed IDmin Drift Burst Collapse Tensile 4" Workstring 15.7 ppf (17.27 ppf adjusted) S-135 2.563 2.438 21,331 18,593 456,900 XT-39 TK341PC Make Up Torque Min Max 12,400 22,200 Wellhead /Tbg Hgr Wellhead 3 1/8" 5M Vetco 5 3/4" Otis on top Tbg Hanger 11" 5M w/ IBT-M Vetco 2 pass throughs "B" Section 11" 5M Vetco Vetco multi-bowl system Fluids Fluid Description Gradient (psi/ft) Drilling Fluid 13 6 ppg MI KCI based mud .___.____ 0,6968_ Completion Fluid 8.43 ppg 2% KCI .___._.__0.4384 ____ _ Backer Fluid_..___.___._.__._._._._...__._~._ arctic grade diesel (freeze protections ._._..___._.__0.3526.__._____ Displacement & Capacities Displacement (bbls/ft) Capacity (bbls/ft) 3'/~" production tubing 0.00320 0.00870_. 4" XT-39 IPC workstring 0.00015 0.00993 __ __ _ _ _ 7"casing_ ______________ 0.00934 _____ 0.03830 _ Correlation Logs Type Date Description Open Hole Mar 3, 2008 Baker Atlas HD Induction Log /CDUCNL Open Hole Mar 7, 2008 Sperry LWD Log _ Cased Hole TBR USIT/CBUGR/CCL __ _ __ _ _ _ ___ _ __ 3 ~ ~ Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~i~d AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 SAFETY & ENVIRONMENTAL COMPLIANCE ARE CORE VALUES ANADARKO IS COMMITTED TO A SAFE 8 ENVIRONMENTAL COMPLIANT WORKING ENVIRONMENT FOR ALL COMPANY AND SERVICE PERSONNEL. Feedback on all issues is considered priority, especially issues involving safety. A safety meeting will be held prior to commencing each critical operation to provide all personnel with a safe working knowledge of the ensuing job particulars and potential hazards. Well control procedures should receive top priority with any concerns addressed immediately to the APC HSE Representative on site. COMPLETION PROCEDURE: 1. MUD CONDITIONING & CASED HOLE LOGGING 1.1. After the 7" 26# L-80 BTC-M casing has been cemented and landed in the casing spool, PU & RIH w/ 6 1/8" bit, DC's, 4" XT-39 DP and drill out stage tool @ 1,277' dpm. 1.2. After drilling through stage collar, perform a quick 500 psi test and then continue to PBTD. Once at PBTD and dress off any cement on top of the landing ring @ 3,812' dpm. Circulate & condition mud. POOH NOTE: While circulating mud, make sure to run over the finest screens available to remove most of the solids in the mud. Ensure mud properties are in good shape with min PV & YP values If possible, start cleaning one or more tanks in order to prepare for displacement. 1.3. RU Schlumberger E-Line services w/ pack-off. RIH w/ 6.05" GR/JB. NOTE: • Use this run to flag or mark the PBTD (DPM-WLM delta) • GR run is primarily for Halliburton's packers (PHL has largest OD 6.0") • SLB has a 6.125", 6.05" and 5.9" OD GR 1.4. RIH w/ USIT/CBL/GR/CCL. Log entire wellbore. Ensure data quality is good. If needed a pressure pass can be made. RDMO E-Line NOTE: • SLB recommends 12hrs min WOC before running USIT/CBL • Note difference between pipe and wireline PBTD depth (from GR run) • Compare proposed packer depths with the CBL/CCL to prevent setting in collar • Send the CBL/USIT pdf via email. • Post to Petrolink (clerk on Nabors 105 to post) 2. WELLBORE CLEANUP 8: DISPLACEMENT 2.1. Close blind rams and perform a 30 min 5,000 psi casing test (±70% of burst) and chart. This will serve as a official casing test. 2.2. PU and RIH w/ 6 1/8" bit and scraper on the 4" XT-39 drill pipe to PBTD. 4 Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~ti~d AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 2.3. Circulate/condition mud until mud properties are optimum to ensure a successful displacement and begin cleaning tanks/lines/valves/ditches in preparation of mixing the completion fluid. NOTE: • Mud properties should have min PV & YP values • Clean tanks & circulate through lines with Safe-Surf W (1-55ga1 drum to 50 bbls water or as per MI Engineer) • Ensure that we have 2 clean tanks for the displacement operations (1 clean and 1 return or dirty tank) 2.4. Pumping down the DP, displace the conditioned KCI mud by pumping the following spacers/fluids at 5 bpm until the Safe Surf W turns the corner, then increase pump to 7 bpm. NOTE: • Do not stop circulating once displacement is started to avoid any density re- distribution from occurring. • Rotate (20-40 rpm's) and reciprocate while pumping • 1St 25 bbl hi-vis spacer weighted ± 1 ppg higher than the final mud w • Calculated Capacities: 37.8 bbls DP / 84 bbls Annulus 0 15 bbls fresh water 0 25 bbls of Duovis (hi-vis spacer) weighted w/ barite 0 37 bbls of Safe Surf W (water based mud surfactant - 10% vol) 0 30 bbls of Duovis (hi-vis spacer) mixed w/ KCI o +/-8.43 ppg (2% KCl) 2.5. POOH laying down all b +/-1,900' of the 4" XT-39 DP. Once out of the hole with the DP, close the blind shears d perform a 5 min 5,000 psi integrity test. NOTE: • Plan to tag bottom with the TCP guns to put us on depth then set BWD @ +/-1,700'. 3. RUN PRODUCTION EQUIPMENT 3.1. MU the following Nanushuk completion equipment consisting of a TCP gun system w/ permanent packer and 3 %" 9.2# L-80 IBT-M tubing. NOTE: • Confirm that wear bushing has been pulled from WH (visually locate wear bushing) • See detailed Halliburton Schematic (attached • Top of packer is to be spaced-out close to the bottom of the proposed Tuluvak perforations • Equipment has been made up into assemblies to aide in field make-up • Sparingly use Best-O-Life 2000 thread compound and follow proper make-up procedures. • Use "mustache" brush to apply modest amount of thread compound • The make up torque for 3 %Z" 9.3# L-80 IBT-M tubing is determined by the knurled bands: o Make up pipe hand tight with 1 thread standoff o Minimum power make up will be to the first knurled band o Maximum power make up will be to the second knurled band (1/8" past 1st band) • Thread on BWD setting tool is 2 7/8" EUE 8rd and a crossover to 4" XT-39 has already been torqued upon the setting tool. Gubik #3 T1 N-R3E-17 ~~~ Alaska Foothills Petroleum Corporation • Final Program v2 AOGCC Approved March 13, 2008 Item Descri tion I.D. O.D. Len th De th 7 7" 26-32# 'BWD' Permanent packer 3 1/2" 9.2# IBT-M Pu Joint 4.000 2.992 5.875 6.00 10.00 1,701.54 1,707.54 3 1/2" 9.2# Tubin used to S ace out 2.992 4.500 1,767.00 1,717.54 6 3 1/2" 9.2# Pup Joint 3 1/2" 9.2# 9cr "X" Nipple (2.813" Pkbore) 3 1/2" 9.2# Pu Joint 2.992 2.813 2.992 4.250 4.250 4.250 8.00 1.50 6.00 3,484.54 3,492.54 3,494.04 3 1/2" 9.2# Tubin 2.992 4.250 31.00 3,500.04 5 3 1/2" Ported Sub 2.992 4.250 2.23 3,531.04 4 3 1/2" Auto Release Sub 2.992 4.250 2.23 3,533.27 Pressure Activated Firin Head N/A 3.780 5.50 3,535.50 4-5/8" S acer Gun N/A 2.875 1.00 3,541.00 4 5/8" 5s f Millennium Guns 4.625 40.00 3,542.00 4-5/8" S acer Gun 30.00 3,582.00 3 4 5/8" 5s f Millennium Guns N/A 40.00 3,612.00 2 Pressure Activated Firin Head N/A 4.625 2.53 3,652.00 1 Bull Nose N/A 3.380 0.55 3,654.53 EOT 3.380 3,655.08 3.2. With BWD permanent packer below the rotary, crossover to the 4 " XT-39 DP (2 7/8" EUE x 4" XT-39 XO already made-up to setting tool of the BWD) and run 1 stand, then a 10' or 15' pup (for correlation purposes) then remaining drillpipe. NOTE: • Record the weight of the BHA as indicated on the rig's weight indicator • Ensure all equipment including XO's can pass a 1 '/2" secondary packer setting ball • Easy on/off slips. Use dog collar or safety clamp until 5,000 Ibs or weight is established. • LIVE TCP GUNS - Minimum activation psi = 3760 psi (100% 2% KCI) 3.3. Continue in the hole and based off cleanout trip, slowly and lightly tag PBTD with TCP Guns. PU and space out guns to perforate the Nanushuk @ 3,542'-582' & 3,612'-652'. NOTE: • Do Not set more than 5K down on TCP Guns • Compare to PBTD dpm depth on cleanout run OPTIONAL: Set DP in slips and RU Schlumberger E-Line. MU & RIH w/ GR/CCL and correlate guns on depth. NOTE: • Use GR and CCL (10' pup 1 stand above packer) and compare to CBL 3.4. Before setting packer circulate 65 bbls of diesel followed by 17 bbls of 2% KCI down the DP taking returns up the casing. NOTE: • Diesel should be balanced in/out below the BWD 6 ~I Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~~~~~ AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 3.5. With guns in position to perforate the Nanushuk @ 3,542'-582' & 3,612'-652', drop 1 '/4" brass ball and allow to fall onto seat. With backside full and the hydril open, screw in the top drive. Once ball is on seat, pressure up to 500 to perform a low psi workstring test and ensure the ball is on seat. Once confirmed good, continue up to 3500 psi to set the packer. With 3500 psi on the DP, PU to neutral weight + the weight of the BHA (as recorded in step 3.2) and hold for 15 mins. Bleed DP to 0 psi. PU until setting tool shears from the packer (±60K shear ring). To confirm packer was set (other than the OP required to shear off the setting tool), sting back into packer and perform a 500 psi backside test. NOTE: • Ensure TIW or any surface equipment can pass a 1 '/2" secondary ball • LIVE TCP GUNS - Minimum activation psi = 3760 psi (100% 2% KCI) • Monitor the backside continuously and make sure hydril is always OPEN during the setting process • Setting tool has been modified to allow us to test the packer after being set and to not have to blow a ball seat in order to pull dry. 3.6. POOH laying down remaining 4" XT-39 DP. 3.7. PU & RIH w/ production packer, X-LN assembly and chemical injection mandrels on 3'/2" 9.2# L-80 IBT-M tubing as listed below. NOTE: • See detailed Halliburton Schematic (attached) Ensure EOT is >40' above top Tuluvak perforation • Equipment has been made up into assemblies to aide in field make-up • Sparingly use Best-O-Life 2000 thread compound and follow proper make-up procedures • Use "mustache" brush to apply modest amount of thread compound • The make up for 3'/2" 9.3# L-80 IBT-M tubing is determined by the knurled bands: o Make up pipe hand tight with 1 thread standoff o Minimum power make up will be to the first knurled band o Maximum power make up will be to the second knurled band (1/8" past 1st band) Item Descri tion I.D. O.D. Len th De th Tubing Hanger (2 - 3/8" ports, 1/4" SS 0.88 0.00 12 C/L) 2.992 3 1/2" 9.2# Pu Joint 2.982 4.250 4.73 0.88 3 1/2" 9.2# Tubin 2.9g2 4.250 1,253.99 5.61 3 1/2" 9.2# Pup Joint 2.992 4.250 8.00 1,259.60 11 3 1/2" Chemical Inject Sub (2.813" XXO) 2.813 3.668 1.50 1,267.60 3 1/2" 9.2# Pu Joint 2,gg2 4.250 6.00 1,269.10 3 1/2" 9.2# Tubin 2.gg2 4.250 31.00 1,275.10 3 1/2" 9.2# Pup Joint 2.992 4.250 8.00 1,306.10 10 3 1/2" Chemical Inject Sub (2.813" XXO) 2.813 4.250 1.50 1,314.10 3 1/2" 9.2# Pu Joint 2.gg2 4.250 6.00 1,315.60 3 1/2" 9.2# Tubin 2.992 4.250 186.00 1,321.60 3 1/2" 9.2# x-over IBT-M Box x EUE Pin 2.992 4.250 10.00 1,507.60 9 7" x 3 1/2" 26-29#'PHL' Hydraulic set Pkr 2.890 6.000 5.40 1,517.60 3 1/2" 9.2# x-over EUE Box xIBT-M Pin 2.992 4.250 10.00 1,523.00 3 1/2" 9.2# Pup Joint 2.992 4.250 8.00 1,533.00 8 3 1/2" 9.2# 9cr "X" Nipple (2.813" PkBore) 2.813 4.250 1.50 1,541.00 7 . ~ ~` Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~i~d AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 3 1/2" 9.2# Pup Joint 2.992 4.250 6.00 1,542.50 3 1/2" 9.2# WLEG 2.gg2 4.250 1.50 1,548.50 EOT 1,550.00 3.8. PU & MU 11" 5M tubing hanger. Terminate'/4" CI control line(s) and feed through 3/8" pass throughs in the TH. Secure CI to landing joint. 3.9. Lower TH into bowl and lockdown TH. Circulate 54.3 bbls of diesel down the tubing while taking returns on the annulus. Once diesel is all the way around, drop ball and rod and allow to gravitate to the RHCM plug. RU surface lines and test to 3,000 psi. Pressure up on the tubing to 500 psi and hold for 3-5 mins. Then increase slowly to 3,000 psi to fully set the PHL packer and hold for 15 mins. Bleed pressure to 0 psi and then perform a 500 psi annulus test while monitoring the tubing side for returns. NOTE: • Diesel will be for underbalance and freeze protection • Monitor backside while setting the packer to ensure RHCM plug is set and holding • slickline will be needed to retrieve the rod/ball and RHCM plug before firing the guns and starting the welltest. • Diesel will be for underbalance and freeze protection 3.10. Install BPV in TH. 4. DEMOB RIG 8~ MOBILIZE WELLTEST EQUIPMENT 4.1. ND BOP. NU Tree. Pull BPV and install 2 way check to test tree to 5,000 psi. Pull 2 way check. Install BPV in TH and leave until rig is demobed. 4.2. Demob rig to Chandler #1 location 4.3. Mobilize welltest package & support equipment. 4.4. RU scaffolding around the wellhead and wrap with visqueen to hold heat in as we perform the rigless operations. 4.5. RU slickline to pull the rod/ball and the RHCM plug in the X-LN. RD slickline. 5. PERFORATE & TEST NANUSHUK FORMATION 5.1. Finish rigging up welltest equipment. Flush lines & equipment with diesel. Test lines & welltest equipment. 5.2. RU pump and pressure up to ±5,000 psig to activate the delayed firing heads on the TCP guns. Bleed pressure off fairly quickly to allow guns to go off with a underbalance. RD Pump. NOTE: • 4 5/8" Millennium TCP: 6 spf, 60°, 32" form pen, 0.35" CsgEHD • Will work up to max rate slowly • w/100% Diesel HH the TCP activation psi = 4,080 min / 4,950 max With a 8.33 ppg reservoir pressure the max UB >200 psi 5.3. Flow well to equipment as described below: NOTE: • Ensure SPIDR surface pressure recorder is hooked up to wellhead • Max Rate & SI time will be determined by how the well behaves and the onsite reservoir engineer • Will work up to max rate slowly 8 Gubik #3 T1 N-R3E-17 ~~~ Alaska Foothills Petroleum Corporation Final Program v2 AOGCC Approved March 13, 2008 • Looking for well to stabilize and clean up so that we can run BHPG in the hole. Stage Target Rate (MMscfd) Interval (hours) Clean Up 0 to Max Rate ? SIBU -- ? 5.4. RU slickline lubricator & test to 500 psig above SITP. MU & RIH w/ tandem DHPG's (3 sec sampling) and set in 2.813" X-LN @ ±3,491'. POOH & RD WL. 5.5. Flow well to equipment as described below: NOTE: • Max Rate will be determined by how the well behaves and the onsite reservoir engineer • Will work up to max rate slowly • Looking to confirm/establish a correlation between Surf & BH pressure Stage Target Rate (MMscfd) interval (hours) Ramp Up 0 to Max Rate ? q~ Max Rate 12 SIBU -- 24 5.6. RU slickline lubricator & test to 500 psig above SITP. MU &RIH to pull the tandem DHPG's (3 sec sampling). POOH NOTE: • Purpose of this is to establish a correlation between surface & downhole data. • Download data from both DHPG & SPIDR and send to Houston via email ASAP 5.7. MU &RIH w/ other set of tandem DHPG's (3 sec sampling) and set back in the 2.813" X-LN @ ±3,491'. POOH & RD WL. 5.8. Perform flowtest and buildups on Nanushuk formation as per reservoir engineer. Stage Target Rate (MMscfd) Interval (hours) q2 25% of Max 6-12 hrs q3 50% of Max 6-12 hrs q4 75% of Max 6-12 hrs q5 Max Rate 6-12 hrs 9 .. Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~ti7d AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 SIBU -- 1.5 * tflow *Confirm with Onsite Reservoir Engineer whether a Production Log and/or downhole samples will be obtained after the conclusion of the SIBU* 6. PLUG & ADBANDON NANUSHUK FORMATION 6.1. After final buildup period, RU slickline lubricator and test to 500 psig over SITP. RIH and retrieve the DHPG's. RD slickline equipment. NOTE: • Gather surface and downhole fluid samples (as required by reservoir engineer) • Run Spinner Log if required by reservoir engineer (requires flowing well) 6.2. RU Little Red to re-inject all fluids produced back into the Nanushuk perforations followed by 2% KCI completion fluid followed by +/-1,500' of diesel. 6.3. RU E-Line. Test lubricator. MU & RIH w/ TTBP and set in the lowest joint of 3'/s" tailpipe below the X-LN. Estimated @ ±3,500'. POOH ~. NOTE: ~~-~~5 • AOGCC rules - CIBP within 50' of perforations 6.4. Pressure test CIBP to 500 psi for 15 mins. 6.5. RIH w/ 2 1/8" thin walled bailer and place 25' of cement on top of the CIBP (±2 runs). POOH 6.6. MU &RIH w/ TTBP and set in first full joint below the BWD packer @ ±1,700'. POOH 6.7. Pressure test CIBP to 500 psi for 15 mins. 7. PERFORATE & TEST TULUVAK FORMATION 7.1. MU &RIH w/ 2.5" PowerJet Omega HC 6 spf guns and perforate the Tuluvak formation @ 1,590' - 1,640'. NOTE: • Ref Log: Baker Atlas HDI Log 2-2-08 • PowerJet Omega HC gun: 6 spf, 60°, 16" form pen, 0.25" CsgEHD / 0.56" FEHD • Will work up to max rate slowly • 971# BHP - 571# HH = 400# UB 7.2. POOH and RD E-Line 7.3. Flow well to equipment as described below: NOTE: • Ensure SPIDR surface pressure recorder is hooked up to wellhead • Max Rate & SI time will be determined by how the well behaves and the onsite reservoir engineer • Will work up to max rate slowly • Looking for well to stabilize and clean up so that we can run BHPG in the hole. Stage. Target Rate (MMscfd) Interval (hours). Clean Up 0 to Max Rate ? 10 . ~,. • Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~~ AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 SIBU -- ? 7.4. RU slickline lubricator & test to 500 psig above SITP. MU & RIH w/ tandem DHPG's (3 sec sampling) and set in 2.813" X-LN @ ±1,541'. POOH & RD WL. 7.5. Flow well to equipment as described below: NOTE: • Max Rate will be determined by how the well behaves and the onsite reservoir engineer • Will work up to max rate slowly • Looking to confirm/establish a correlation between Surf & BH pressure Stage Target Rate (MMscfd) Interval (hours) Ramp Up 0 to Max Rate ? q~ Max Rate 12 SIBU -- 24 7.6. RU slickline lubricator & test to 500 psig above SITP. MU &RIH to pull the tandem DHPG's (3 sec sampling). POOH NOTE: • Purpose of this is to establish a correlation between surface &downhole data. • Download data from both DHPG & SPIDR and send to Houston via email ASAP 7.7. MU &RIH w/ other set of tandem DHPG's (3 sec sampling) and set back in the 2.813" X-LN @ ±1,541'. POOH & RD WL. 7.8. Perform flowtest and buildups on the Tuluvak formation as per reservoir engineer Stage Target Rate (MMscfd) Interval (hours) q2 25% of Max 6-12 hrs q3 50% of Max 6-12 hrs qa 75% of Max 6-12 hrs q5 Max Rate 6-12 hrs SIBU -- 1.5 * tfloW *Confirm with Onsite Reservoir Engineer whether a Production Log and/or downhole samples will be obtained after the conclusion of the SIBU" 8. PLUG & ADBANDON THE TULUVAK FORMATION & WELLBORE 11 • Gubik #3 ~ Final Program v2 T1 N-R3E-17 ~~~~ AOGCC Approved Alaska Foothills Petroleum Corporation March 13, 2008 8.1. After final buildup period, RU slickline lubricator and test to 500 psig over SITP. RIH and retrieve the DHPG's. RD slicklline equipt. NOTE: • Gather surface and downhole fluid samples (as required by reservoir engineer) • Run Spinner Log if required by reservoir engineer (requires flowing well) 8.2. RU pump and re-inject all fluids produced into the Tuluvak perforations followed by 8.43 ppg 2% KCI fluid. ---- NOTE: • Purpose of the KCI is to displace produced fluid back into the formation and provide good clean fluid in front of the cement to be bullheaded into the perforations. 8.3. RU E-Line. Test lubricator. MU & RIH w/ 4'-8' of 4 spf tubing punch guns and perforate 3'/2" 9.2# production tubing @ ±1,500'. POOH. RDMO E-Line. 8.4. RU cement unit and pump the following schedule of arctic blend cmt (AS1) down the tubing until the slurry has squeezed off the Tuluvak perforations @ 1,590' - 1,640' and then take returns on the casing side causing the cement to come through the tubing perforations and up to surface. RD & WOC 0 5 bbl Spacer o ±60 bbls AS1 (15..7 ppg - 0.93 cuft/skl) NOTE: • Ensure good cement to surface • Unsure of whether we will pump down through the top of the tree or in from the wing. Need 5 3/<" Otis XO or 3 1/8" 5M XO to pumping iron CQ Y~~C~ ~~S . r 8.5. After cement has had time to set up, cut the 16", 9 5/8" , 7" & 3 %i" pipe to 5' below tundra line. Recover Vetco wellhead equipment. 8.6. RDMO all equipment and perform reclaimation activities on the ice pad and surrounding areas. 12 OPERATOR'. FIELDI WELL WELL SKETCH: ANADARKO PETROLEUM CORPORATION Alaska Foothills /Gubik #3 (GU2 Loc) PROPOSED DRILLING RIG: (RKB XX') SURF LOC'. PERMIT: API NUMBER: Nabors 105 1N-3E-17 Lats9.aatas$ Lon9151.aazoss 207-ITS 50-28~-20D1T-0o DIRECTIONAL DATA KOP. 1.22 tleg @ 3,083 RKB MAX DEV'. 4.82 deg @ 3.374 RKB DLEG SEV'. 3.90 deg @ 3,145 RKB DEV @PERFS: 1.00 deg @ 1,650 RKB DEV @PERFS. 4.50 tleg @ 3,600 RKB DRILLING /COMPLETION FLUID DRILLING FLUID'. 13.60 ppg WBM DRILLING FLUID. ppg WBM (GMT DISPL FLD) COMPLETION FLUID'. 8.43 ppg KCI COMPLETION FLUID'. 6.80 ppg Dlasel (Arli<Gretle) PACKER FLUID: 8.80 ppg Diesel (Arlic Grade) WELLH EAD DATA TrPE vetoo 3 va° WP 5,000 psi T FLANGE : 3 1/8' SM C R A E p E THREAD'. 5 3/4' Olis TUBING HANGER: 71' SM IBT-M Threaded 2-3/8ths Pass Throughs ELEVATIONS: GL: 195' AMSL RKB-THF'. RKB-GL. 20.8' RKB-G L: THE to GL'. •O.8' EQUIPMENT DESCRIPTION ID OD DEPTH ND-RKB DEPTH MD-RKB RKB to'B' SECTION FLANGE 21.1 21.1 Cement to surface for both strings 30- Auger Hole 18' 6511 H-40 Conductor 15.250 18 000 105 105 CIM1 for DH methanol Injectlon 31,268' x1,268' CIM2for DH methanol Injection x1,314' 31,314' 9 5/B' 40# L-80 BTC Casng 8 835 9.875 1 014 1,014 12 114- Hole 1,027 1,027 Stage Coller@ 7,277' AS1 Cement to surf 1,277 1.277 Retreivable Packer x1,517' 37,517' 2.813-X-LN (Needs fo be within 50'of top pert) 2.831' x1,541' 31,541' TULUVAK FORMATION Pr = 977 psi ~ Mp (11.8 ppge) 7,590'-1,840' (50~ - 6 spf, 0.35" dia holes, +/-17 in penetration HES BWD Permanent Packer w/ ScoopHead 3f ,700' 31,700' 2.613" X-LN (Needs to be within 50' of top pert) 33,490' 33,491' EOT (after TCP Buns drop) x3,530' x3,531' NANUSHUK FORMATION Pr estimated 1,500 psi from RCI (suspect) 3,542'-582' (40~ - 6 spf, 0.35" dia holes, 30+inches penetration 3,540 3.542 3,580 3,582 $,612'$52' (40') - 6 spf, 0.35"dia holes, 30+inches penetration 3.610 3,612 3,fi50 3,652 18 PP9 Cement 10 +/-1,277' 8 3/4-Hole T 26# L-80 BTC-M Casing 6 276 7 000 3,93C 3.933 COMMENTS: MEASUREMENTS SHOWN ARE BASED ON DRLG RIG ZERO PLUG BACK DEPTH: 3,811 3,813 TOTAL WELL DEPTH: 3,930 3,933 DRAWING NOT TO SCALE PREPARED BY: M.A. Conrad DATE: 03/11/08 Rev 0 Wellbore Schematic Gubik Well (Alaska ).xls OPERATOR'. FIELD/WELL: WELL SKETCH: ANADARKO PETROLEUM CORPORATION Alaska Foothills /Gubik #3 (GU2 Loc) PROPOSED P&A DRILLING RIG: (RKB XX') SURF LOC: PERMIT'. API NUMBER: Nabors 105 1 N-3E-17 Lat 69.441453 Long 151.442055 207-'176 50-287-20017-00 DIRECTIONAL DATA KOP. 1.22 tleg @ 3,063 RKB MAX DEV: 4.82 tleg @ 3 374 RKB DLEG SEV: 3.90 tleg @ 3,745 RKB DEV @ PERFS: 1.00 deg @ 1,650 RKB DEV @ PERFS'. 4.50 deg @ 3,600 RKB DRILLING /COMPLETION FLUID DRILLING FLUID'. 73.fi0 ppg WBM DRILLING FLUID. ppg WBM (GMT DISPL FLD) COMPLETION FLUID: 843 ppg KCI COMPLETION FLUID: 6.80 ppg Diesel (Artic Grade) PACKER FLUID: 6.80 ppg Diesel (Artic Gratle) WELLH EAD DATA TYPE Velco 3l/8" WP 5,000 psi T FLANGE: 3 7/8" SM C R A E p E THREAD: 5 3/4' Otis TUBING HANGER: 71' SM IBT-M Threaded 2-3/Bths Pass Throughs ELEVATIONS: GL: 195' AMSL RKB-THF: RKB-GL: 20.8' RKB-G L: THF to GL'. -0.5' EQUIPMENT DESCRIPTION ID OD DEPTH ND-RKB DEPTH M0.RK6 RKB to'B' SECTION FLANGE 21.1 21.1 All Casing Strings & Tubing cut +l-5' below tundra line Cemenl to surface for both sUings 30' Auger Hole 16' 65A H-40 Conductor 15.250 16.000 105 105 3150 3150 3150 3150 Balanced cement plug +/-1,500' -suit CIMt for DH methanol Injection 31,268' 37,268' CIM2 far DH methanol Injection 21,314' 37,314' 9 5/e- 40# L-80 BTC Casing 8.835 9.875 1,014 1 014 121/4' Hole 1,027 1,027 Stage Collar @ 1,277' AS1 Cement to surf 1.277 1,277 Circulating holes 31,500' 11,500' Retreiveble Packer 37,577' 31,517' 2.873'X-LN 2.831' 11,541' 37,541' Cement Squeezed into Tuluvak Perforations TULUVAK FORMATION Pr = 977 psi (~ Mp (11.8 Ppge) 1,590'-1,840' (50') - 6 spf, 0.35" dia holes, +/-17 in generation HES BWD Permanent Packer wl ScoopHead 31,700' 31,700' Thru-Tubing CIBP wlo Cement 31,740' 31,740' 2.813' %-LN 33,491' 33,497' Thru-Tubing CIBP w/ 25' Cement on top 33,500' 13,500' EOT (after TCP guns drop) 33,537' 33,531' NANUSHUK FORMATION Pr estimated 1,500 psi from RCI (suspect) 3,542'-582' (40~ - 6 spf, 0.35"tlia holes, 30+inches penetration 3,540 3,542 3,580 3,582 1,612'$5Y (40') - 65p/, 0.35"dia holes, 30+inches penetration 3,610 3,612 3,650 3,652 8 3/4" Hole 7" 26# L-80 BTC-M Ca51np 6 276 7 000 3.930 3.933 COMMENTS: MEASUREMENTS SHOWN ARE BASED ON DRLG RIG ZERO PLUG BACK DEPTH: 3,811 3,813 TDIPBTD will l» determines waed on rathole needed to drop 7GP guns below N TOTAL WELL DEPTH: 3,930 3,933 DRAWING NOT TO SCALE PREPARED BY: M.A. Conratl DATE: 03/13/08 Rev 0 Wellbore Schematic Gubik Well (Alaska ).xls ~ ~ ~m Corpo Gubik #3 API: 50-287-20017-00 Tuluvak Sand Proposed Perforations 1,590'-1,640' and (50') BHP 977 PSI /EST BHT 73° F Baker Atlas HDI Log dated Feb 20, 2008 Original Hole ~m Corpo Gubik #3 API: 50-287-20017-00 Nanushuk Sand Proposed Perforations 3,542'-82' (40') & 3,612'-52' (40') BHP 1,500 PSI? /EST BHT 100° F Sperry LWD Mar 6, 2008 Bypass Hole 3600 ~ ~ leum Cor - Gubik #3 API: 50-287-20017-00 Nanushuk Sand Proposed Perforations 3,542'-82' (40') & 3,612'-52' (40') BHP 1,500 PSI? /EST BHT 100° F vW, Atlas Quad Combo Mar 7, 2008 °o Bypass Hole 200 r; . ~ i ,~ r~ - ~-, w m 0 0 i t W J O O ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 ~nadarl~~ Petroleum Corporation Mazch 14, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 ~ ~ ~,~ Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gu6ik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on Gubik #3 for the period March 7 through March 13, 2008, inclusive. March 7, 2008 3,950' MW 13.6 ppg Vis 51 sec Incl 4.65 deg Finish L/D MWD tools. R/U WL, N/D beli nipple, N/U lubricator. P/U logging tools: HDIL-~3VIAX-Cal-CN-ZDL-GR. RIH to TD, log out. POH and change tools to RCI. RIH w! RCI and take 15 pressure sets. March 8, 2008 3,950' MW 13.6 ppg Vis 51 sec Inc14.65 deg Finish running RCI log, POH, R/D WL. M/U clean-out BHA, RIH. Hole tight at 3,112'. Wash through w/o rotation. RIH to TD w/ no addn'1 hole probs. CBU x 2. POH, L/D HWDP and BHA. March 9, 2008 3,950' MW 13.6 ppg Vis 51 sec Incl 4.65 deg Cleaz floor. C/O top rams to 7". R/U to run casing. Set test joint of 7" csg in rams to test 7" rams -egged collar on test jt. P/iJ new test jt and test rams to 3,000 psi - OK. Csg tongs failed, R/U new set. Run 7" csg. March 10, 2008 3,950' MW 13.6 ppg Vis 51 sec Inc14.65 deg Run 7" csg to 3,935', washing thru tight spot at 1,604' and working thru KOP. R/D csg running tools, R/U cementers. Circ hole while hatching up. Pump l~` stage consisting of 115 bbls of 18 ppg cement, displace w/ mud. Bump plug, pressure up and open stage tool (at 1,300') w/ 3,100 psi. Circ above stage tool, received 1 bbl good cement back. Pump 2"d stage consisting of 43 bbls of 14.5 ppg gas-block cement, displace w/ mud. Land top • plug in stage tool and shift tool closed w/ 1,900 psi. Received 1 bbl 14.5 ppg cmt back at surface. Verify stage tool closed and R/D cementers. Test BOPE. March 11, 2008 3,950' MW 13.5 ppg Vis 53 sec Inc14.65 deg Test floor valves and accumulator. Change 7" rams to 3-1/2" X 5" VBRs. Repair BOPS while cleaning pits and organizing completion in pipe shed. Finish testing BOPE. M/U clean-out BHA and RIH. Drill up stage tool closing plug. Test casing to 500 psi. RIH to 3,759' March 12= 2008 3,950' MW 13.5 ppg Vis 56 sec Inc14.65 deg RIH, tag up at 3,807'. CBU X 2 and POH. R/U SLB WL. RIH w/ gauge ring, tag up at 3,773', POH. WL Run #2 - GR/CCL log to 3,773'. WL Run #3 - USIT/CBL. R/D WL equipment. Pressure test casing to 5,000 psi for 30 minutes -good test. M/U casing scraping BHA. March 13, 2008 3,950' MW 8.4 ppg Vis 28 sec Incl 4.65 deg Finish M/U csg scraper BHA and RIH to shut-off baffle. Drill rubber plug on baffle 3,807' to 3,808'. Circ well while cleaning pits and mixing weighted pill and. surfactant. Displace well w/ 2% KCl brine. POH, SB 20 stands DP. POH, L!D remainder of DP. L/D DCs. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION Sii~ ~e~aiaae Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 Fetrole_=m Corporation March 7, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite I00 Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on Gubik #3 for the period February 29 throu€;h March 6, 2008, inclusive. February 29, 2008 4,285' MW 14.3 ppg Vis 55 sec Inc12.31 deg Wash down from 3,262' to 3,454', partial returns at first, then full returns. Attempt to engage top of fish at 3,4:57' without success. POH, checking well for proper fill. L/D fishing BHA, M/U mule shoe on DP for cementing, RIH. March 1, 2008 2,950' MW 13.7 ppg Vis 70 sec Incl 0.84 deg RIH, tag TOF at 3,454'. Circ while It/LJ cementers. Test lines to 3,000 psi then pump 44 bbls weighted spacer, 49 bbls 17.0 ppg cement, 5 bbls spacer and 23 bbls mud. CIP at 0700 hrs. R/D cementers, POH to 2,503'. Circ out DP and POH. Pull wear ring, test BOPE to 250/3,000 psi. March 2, 2008 3,045' MW 13.6 ppg Vis 70 sec Inc10.84 deg Finish testing BOPE. M/U BHA and RIH. Tag cement at 2,970'. Dress cement to 3,045'. Cement held 20K lbs weight w/ pumps on. POH. M/U kickoff/directional drilling BHA and RIH. March 3, 2008 3,105' MW 13.3 ppg Vis 56 sec Incl 0.84 deg RIH to 3,015', orient tool face. Time drill, attempting to kick off cmt plug, 3,015' to 3,038'. Bit broke throu€;h hard cmt into soft cmt. Hard cmt re-encountered at 3,096'. Time drill, attempting to :kick off, 3,096' to 3,105'. 1 • • March 4, 2008 3,330' MW 13.3 ppg Vis 56 sec Inc14.82 deg Time drill (sliding w/ occasional rotation when stabilizer hung up) from 3,105' to 3,330' -kicked off cmt plug and built angle for separation from original wellbore. March 5, 2008 3,861' MW 13.3 ppg Vis 52 sec Incl 4.65 deg Drill and slide 3,330' to 3,527'. Make wiper trip to 2,952' -hole in good condition. Drill 3,527' to 3,861'. March 6, 2008 3,950' MW 13.5 ppg Vis 51 sec Incl 4.65 deg Drill 8-3/4" hole 3,861' to 3,950' TD. CBU, trip to csg shoe and back to TD - 8' fill. CBU, POH. Pulled tight at 3,633'. Raise MW 2 points while circ. POH w/ no further problems. S/B HWDP and jars, L/D BHA, download LWD tools. If you have any questions or require additional information, please contact me at 258, 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~e~o¢e Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, March 07, 2008 2:26 PM To: 'Bill Penrose' ~C~,~G[ 3,Z ~~~ Cc: DOA AOGCC Prudhoe Bay '~ Subject: RE: BOP Test at Anadarko Gubik #3 Request to delay testing BOPE at Gubik #3 (Nabors 105E) until Sunday, 3/9/2008 is approved. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, March 07, 2008 2:10 PM To: Regg, James B (DOA) Subject: BOP Test at Anadarko Gubik #3 Jim, Anadarko is currently running open-hole logs at TD in the Gubik #3. Logging will continue through tomorrow (Saturday) and 7" casing will be run on the following day (Sunday). A weekly BOP test is due tomorrow. Since the BOP lower ram body will require a pressure test on Sunday when the pipe rams are changed to 7" for running the casing, Anadarko proposes conducting the overall weekly BOP test on Sunday in conjunction with the ram test instead of on Saturday. Please let me know what you think. Thanks and regards, S~c~ ~e~vtade Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 3/7/2008 • ANADARKO PETROLEUM CORPORATION 3241 C St. STE. 603 ANCHORAGE, ALASKA. 99503 USA PH. (9~7) 273-63(JD adiarrl~~ Petroleum Corporation February 29, 200$ Mr. John Norman, Chair Alaska. Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 .. ~ l~~ RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on Gubik #3 for the period February 22 through February 28, 2008, inclusive. February 22, 2008 2,628' MW 16.6 ppg Vis 70 sec lncl 0.70 deg Finish logging with RCI tools. POH and R/D WL and lubricator, R/U bell nipple. M/U bit and BHA, RIH to 1,290'. Attempt CBU, found top drive to be frozen up. POH to shoe. Thaw top drive, standpipe and keliy hose. February 23, 2008 2,829' MW 16.2 ppg Vis 63 sec Intl 0.69 deg Thaw standpipe and kelly hose. Pump through mud lines and top drive, CBU at shoe - gas peak at 885 units. RIH to 1,480'. Grabber on top drive not functioning, bring top drive to floor and warm up. RIH to btm at 2,62$', CBU -max gas 220 units, Drill 8- 3/4" hole 2;628' to 2,829'. February 24, 2008 3,788' MW 15.4 ppg Vis 52 sec Incl 1.30 deg Drill 8-314" hole 2,829' to 3,176'. Make correction slide 3,176' to 3,206'. Drill 3,206' to 3,788'. Februar~25, 2008 4,173' MW 15.4 ppg Vis 52 sec Incl 1.31 deg Drill 8-3/4" hole 3,7$8' to 3,900'. IBOP failed to open after cnxn and top drive, keliy hose and standpipe froze. Thaw wane, Drill 3,900' to 4,130'. Begin losing mud at 2 - 6 bph. Pump LCM pill. Check well - no static losses. Dril14, i 30' to 4,173'. • Februaiy26, 2008 4,285" MW 14.6 ppg Vis 63 sec Inc12.31 deg Drill 8-3/4" hole 4,173' to 4,285' TD. C&C mud and POH. Pull #ight at 4,145', commence backreaming. Pipe stuck w/ bit at 3,737'. Jar down .and circ at 30 spm, lost circ. Pump LCM pill. Cut MW to 14.6 ppg and continue jarring dawn. Static fluid loss 1-3 bbUhr. Make blind backoff 143' below rotary table and replace one jt DP w/ pup to bring top of DP down to 3' a~ve RT. February 27, 2008 4,285' MW 14.6 ppg Vis 63 sec Ine12.31 deg Hang sheaves, R/U freepoint tools. Conduct freepoint investigation -found freepoint at 3,464'. POH and R/D freepoint tools. M/tJ string shot and RIH to 3,464'. Put left-hand torque into DP and fire string shot. Back aff and pick up. Start pumping at 30 spm w/ partial returns at first then complete lost returns. Slow pumping to 15 spm and mix and pump 50 bbl LCM pill. Static losses reduced from 10 bph to 2 bph. February 2$, 2008 4,285' MW 14.4 ppg Vis 64 sec Inc12.31 deg Blow do top drive, fill hale, monitor well -static. POH, checking torque on each cnxn. Back~ff of fish occurred at service break in drilling jars. M/U fishing BHA and RIH to 3,1b i' -took weight. Ream and wash down toward top of fish. (TOF at 3,457'.) If you have any questions. or require additional information, please contact me at 258- 344b. Sincerely, For ANADARKO PETROLEUM CORPORATION ~~ Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. ce: Fred McDougal /Chuck Rowe -Anadarko 2 C~ ~1~'~~ ~~~ ~,i~Gl~S~Q /v...~Po~..ow ~8~ OI~ ~ t7r~7 333 W. 7th AVENUE, SUITE 100 COI~SERQA7`IOI~T COAII-iI5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred McDougal Drilling Operations Manager Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, AK 99503 Re: Exploration Well, Gubik #3 Sundry Number: 308-067 Dear Mr. McDougal: 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). Due to travel logistics, 48 hour notice should be given. As provided iri 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 this2~day of February, 2008 Encl. ~b~" (~~ n ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 February 29, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ~nadarl~~ Petroleum C1orporation ~~~~` fi ~~ '`~a ~~ ~ 9 zoos ~~ ~~ RE: Request for Sundry Approval Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a request for the Commission's approval of Anadarko's plan to set a cement plug over a drilling assembly fish stuck in the Gubik #3 wellbore so the fish can be sidetracked and the well re-drilled to TD. The well had already been TD'd at 4,285' and the BHA was being pulled from the hole prior to conducting wireline logging operations when it became stuck with the bit at 3,737'. Attempts to jar it free were unsuccessful, so the drill string was backed off near the freepoint and pulled out of the hole, leaving the top of the fish at 3,_,457'. ~\~ ~ `~'1'~~1 ` „~ The subsequent attempt to engage the top of the BHA fish with an overshot fishing assembly was unsuccessful due to hard fill or rocks having fallen on top of the fish. It has been decided to terminate fishing operations, set a cement plug on the fish then sidetrack around it. The BOPE will be tested while waiting on the cement to cure. ~/' Attached you will find a Sundry Application and cementing plan. If you have any questions or require additional information, please contact me at 273-6302 or Bill Penrose at 258-3446. Sincerely, ANADARKO PETROLEUM CORPORATION =s~~~~ Fred McDougal Alaska Drilling Operations Manager cc: Bill Penrose ORIGINAL STATE OF ALASKA (,~~~ ALA OIL AND GAS CONSERVATION COM ISSION F~I~CE! APPLICATION FOR SUNDRY APPROVALS:~~~, 20 AAC 25.2so ~F~ 2 0 ~nnR 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ T,I~d~'•Exteh~"go~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Anadarko Petroleum Corporation Development ^ Exploratory ^ 207-176 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: 3201 C Street, Suit 603, Anchorage, AK, 99503 50-287-20017-00 ' 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 ~ Gubik #3 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ASRC Lease CA003 20 feet Exploratory 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4,285 MD 4,284 TVD 3457' 3,457 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 16" 105' 105' N/A N/A Surface 1007' 9-5/8" 1007' 1,007' 5750 psi 3090 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 Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory Q Development ^ Service ^ 15. Estimated Date for 29-Feb-08 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446 Printed Name Fred McDougal Title AK Drilling Ops Manager Signature Phone D to 273-6302 Z9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '7 g - ~p ~' Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~ ,. ~. C -r,'~v`~i,~~ '~~ ..~,~~.~'~~~`y ~t;~~~y~,~ Li~l Other: ~,~~::~~_~~~'h~~L~t~'~. L;~ ~' . ~" ~ ~ ~ . j Subsequent Form Required: ~ ~~ ~~C ~ ~ ~~~ ~, -~'~~ u ~G APPROVED BY 7 ~J d ll Approved by: COMMISSIONER THE COMMISSION Date: ` ( ll Form 10-403 Revis de 06/20060 ~ , ~' iv ~ ~, _ ~F~. ;,r ~,~ c~~ ~ zoos Submit in Duplicate~/~~ ~ ~ ~nadarl~~ Petroleum Corporation KO Balanced Cement Plug Procedure for Gubik #3 Cement abandonment in the hole will be achieved by setting a balanced cement plug from TD 3457 to 3957' MD as follows: 1. RIH with open ended drill pipe. Wash down the last two stands and tag the top of fish with care and minimal weight (TOF expected at 3,457' MD). Pick up 10' to 3,447'. 2. Circulate and condition mud. Use the top drive to rotate DP during cement job. 3. Pump 5-10 barrels of water ahead. 4. Pump 48.8 bbls of slurry volume as follows: 48.8 bbls (273 sks) Class G cement + 0.20% D046 (Antifoam) + 0.3% D065 (Dispersant) + 0.35% D167 (Fluid loss), + 0.2% S002 (Accelerator) + 0.7% D065 (Dispersant). 5. Pump 1-2 bbls of spacer behind at max rate to clear the cement from surface lines. Displace with mud and maintain pipe rotation. Ensure displacement pressure, flow rate, and volume are recorded POH five stands and circulate out. 6. POH and WOC. Cement thickening time is +6:00 hours. Test BOPE and M/U new drilling BHA while WOC. Schlumberger CemCAD E*well cementing recommendation for Kick-Off Plug Operator :Anadarko Well Gubik 3 Country : US Field Tuluvak/NanushukTest State :Alaska Prepared for : Mr. Bill Pinrose Location Nabors 105 Proposal No. : Draftv1 Service Point Prudhoe, AK Date Prepared : 2-29-2008 Business Phone 907-659-2434 FAX No. 907-659-2538 Prepared by :Tony Stafford Phone :907-273-1700 E-Mail Atltlress : tstaffordC~3anchorage.oilfield.slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reseNOir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger Client Anadarko Well Gubik 3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug (a) Section 1: well description Configuration :Plug Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :4400.0 ft BHST :103 degF Bit Size : 8 1/2 in Target K.O.P. :3300.0 ft ft 0 0 0 0 ~Ci cv • • • • Gubik ••••~•~• Tuluuak '• ; ;'• Nanushuk ~•~•~••• Torok a 0 0 0 Well Scbl~rger Lithology Formation Press. Page 2 guhik3v2.cfw; 02-29-2008; Loadcase P&A Plug (al; Version wcs-cem452_07 ~~ ~ aoo~ psi Client Anadarko Well Gubik3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug Ia1 Previous String MD OD Weight ID ft in Ib/ft in 1000.0 9 5/8 47.0 8.681 SIr~~r Drill Pipe MD OD Weight ID Grade Collapse Burst ft in Ib/ft in si si 3455.0 4 15.7 3.240 S135 23213 22444 Mean OH Diameter :8.500 in Mean Annular Excess :50.0 Mean OH Equivalent Diameter: 9.621 in Total OH Volume :305.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 3455.0 8.500 50.0 10.019 3800.0 8.500 0.0 8.500 3850.0 8.500 0.0 8.500 4400.0 8.500 0.0 8.500 The Well is considered VERTICAL Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1000.0 18.50 8.30 Gubik Sandstone 3000.0 21.00 9.80 Tuluvak Sandstone 4000.0 21.50 9.50 Nanushuk Sandstone 4300.0 21.50 9.50 Torok Sandstone 4400.0 21.50 9.50 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 900.0 900.0 45 2.2 2000.0 2000.0 85 3.0 3455.0 3455.0 103 2.3 3850.0 3850.0 112 2.3 4400.0 4400.0 125 2.3 gubik8v2.cfw; 02-29-2008 ; Loadcase P&A Plug lal; Version wcs-cem452_07 Page 3 • Client Anadarko Well Gubik 3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug lal ft o, I i0 u- c c 0 0 o- ~n cv 0 O 0 0 ~[] - ^ c c` O O Ll- O t., X u C Cr 0' C C Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Set 500' Kick-Off Plug from top of Fish (3,457) ]0 Original fluid Mud 14.70 Ib/gal P~ :24.000 cP Tv :40.00 Ibf/100ft2 Displacement Volume 35.2 bbl Drill Pipe Volume 35.2 bbl Total Volume 123.5 bbl TOC 2927.1 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al MUDPUSH XT 45.0 549.0 2378.1 15.80 k:7.20E-2 Ibf.s^n/ft2 n:0.333 Tv:15.77 Ibf/100ft2 Tail 43.3 527.9 2927.1 17.00 k:1.64E-21bf.s^n/ft2 n:0.831 Tv:5.671bf/100ft2 Tail 5.5 2917.0 17.00 k:1.64E-21bf.s^n/ft2 n:0.831 Tv:5.671bf/100ft2 MUDPUSH XT 5.7 2356.6 15.80 k:7.20E-2 Ibf.s^n/ft2 n:0.333 Tv:15.77 Ibf/100ft2 Mud 24.0 2.4 ':4.?C P~:24.000 cP Tv:40.00 Ibf/100ft2 SGMI~n~rger degF ft Page 4 guhik3v2.cfw; 02-29-2008 ; Loadcase P&A Plug (al; Version wcs-cem452_07 • i Client Anadarko Sc~l~~rger WeII Gubik 3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug (a) Static Securi Checks Frac 197 psi at 1000.0 ft Pore 332 psi at 1000.0 ft Cs .Pum out 21 ton Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. de F MUDPUSH XT 3.0 45.0 15.0 45.0 80 7-Start Pumping Spacer Tail 3.0 48.8 16.3 48.8 80 9-Start Cement Slurry MUDPUSH XT 3.0 5.7 1.9 5.7 80 7-Start Pumping Spacer Mud 3.0 24.0 8.0 24.0 80 19-Start Dis lacement Total 00:41 123.5 bbl hr:mn End Job: POOH above plug Slowly, Reverse out two DP volumes or until clean: WOC min 8 HR; confirm with cement lab test results Dynamic Security Checks Frac 164 psi at 1000.0 ft Pore 332 si at 1000.0 ft Page 5 gubik3v2.cfw; 02-29-2008: Loadcase P&A Plug (al; Version wcs-cem452_07 • • Client Anadarko Well Gubik 3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug lal ScMl~rg~r Temperature Results BHCT 90 degF Simulated Max HCT 103 degF Simulated BHCT 83 degF Max HCT Depth 3455.0 ft CT at TOC 83 de F Max HCT Time 00:00:00 hr:mn:sc Static temperatures At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 96 degF Bottom Hole (degF) (de F) 1G3 de F 0 a ur .~ Q 2 0 0 c~ .~ a: ~o ~ 10 15 20 25 30 35 40 45 Time (min) Fluids at 3455 ft 0 5 10 15 20 25 30 35 40 45 Time (min) Page 6 gubik3v2.cfw; 02-29-2008; Loadcase P&A Plug lal; Version wcs-cem452_07 • • Client Anadarko Well Gubik3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug (a) CemCADE tr = 1 UUU T[ OO c0 N 7 ~ N ~ a~ a` c c Q N O w~ 0 10 20 30 40 50 Time (min) Total Depth = 4400.0 ft Top of Cement = 2927.1 ft 'Mark of Schlumberger N N O N <0 m ~~ N ~ 7 N N N ~, a`~ c c Q N O W Schl~r~er Client : Anadarko Well Gubik 3 String Kick Off Plug District Prudhoe, AK Country : US Page 7 gubik3v2.cfw; 02-29-2008; Load Case P&A Plug (al; Version wcs-cem452_07 Time (min) • Client Anadarko SIr~er Well Gubik3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug (a) Section 4: fluid description Mud DESIGN Fluid No: 1 Rheo. Model : GINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh VOLUME FR ACTION Solids : 6.0 Oil : 0.0 Water :94.0 MUDPUSH XT DESIGN Fluid No: 2 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL_B. k : 7.20E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.333 Ty :15.771bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :50.7 bbl Density :14.701b/gal P~ :24.000 cP Tv :40.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :24.0 bbl Tail DESIGN Fluid No: 3 Density : 17.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.64E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.831 Tv :5.671bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : D907 Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid :3.858 gal/sk Yield :1.00 ft3/sk Solid Fraction :48.7 Job volume :48.8 bbl Quantity :272.50 sk Density :8.321b/gal Code Additives Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D167 0.350 %BWOC Fluid loss S002 0.200 %BWOC Accelerator D065 0.700 %BWOC Dis ersant Base Fluid :3.858 gal/sk Page 8 guhik3Jl.cfw;02-29-2008; LoatlCaseP&APlug~ai;Versionwcs-cem452_07 • Client Anadarko SIM~r~~r Well Gubik3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug (a) Section 5: operator summary Start Job: Circulate Two Hole volumes, 5atety Meeting, I est 5urtace tqulpment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments bbl/min bbl min bbl MUDPUSH XT 3.0 45.0 15.0 45.0 7-Start Pumping Spacer Tail 3.0 48.8 16.3 48.8 9-Start Cement Slurry MUDPUSH XT 3.0 5.7 1.9 5.7 7-Start Pumping Spacer Mud 3.0 24.0 8.0 24.0 19-Start Dis lacement Total Pumping Time :00:41 hr:mn End Job: POOH above plug Slowly, Reverse out two DP volumes or until clean TOTAL MATERIAL REQUIREMENTS Dead Volumes Name PumpedVolume bbl Operator Volumes Dead Vol. bbl Applies to Blend Dead Mass Ib Mud 24.0 0.0 Total Fluid 0 MUDPUSH XT 50.7 0.0 Total Fluid 0 Tail 48.8 0.0 Total Fluid 0 Chemical Wash 0.0 0.0 Total Fluid 0 100 Lead 0.0 0.0 Total Fluid 0 ASL FEB QC 0.0 AS1 0.0 Additives Total Quanti Item Quanti Pack. Name Packaging Comments D907 256151b 273 sack 941b D046 771b 2 sack 501b D182 2381b 10 sack 251b D031 205981b 188 sack 1101b D065 2561b 6 sack 501b D167 901b 4 sack 251b S002 511b 1 sack 1001b Mix Water Requirements Fresh water 62 bbl Page 9 gubik3v2.ciw; 02-29-2008; Loadcase P&A Plug (al; Version wcs-cem452_07 Client Anadarko Well Gubik3 String Kick Off Plug District Prudhoe, AK Country US Loadcase P&A Plug la- MIXING PREPARATION SIr~~r MUDPUSH XT Volume :50.7 bbl Density : 15.80 Ib/gal Code Quantity Design Fresh water 36.608 bbl D046 25.585 Ib 0.200 %BWOW D182 237.955 Ib 6.500 Ib/bbl of base fluid D031 20598.010 Ib 406.16 Ib/bbl of spacer Tail Volume :48.8 bbl Density : 17.00 Ib/gal Yield :1.00 ft3/sk D Phase Li uid Phase Blend : Ib Desi n Mix Water 25.0 bbl 10.0 bbl LAS Desi n D907 25615.346 Ib Fresh water 25.030 bbl 10.001 bbl D046 51.231 Ib 0.200 %BWOC D065 76.846 Ib 0.300 %BWOC D167 89.654 Ib 0.350 %BWOC S002 51.231 Ib 0.200 %BWOC D065 179.307 Ib 0.700 %BWOC Page 10 gubik3v2.cfw; 02-29-2008 ; Loadcase P&A Plug lal; Versi°n wcs-cem452_07 Schlumberger Laboratory Cement Test Report Gubik 3 17PPG Plug Pilot Si natures Fluid No : PAK plug08022 Client :Anadarko Location /Rig :Nabors 105 Date :Feb-28-2008 Well Name :Gubik 3 Field : Tuluvak/Nanushuk M. Schinnell Job Type Plug Depth 3800.0 ft TVD 3800.0 ft BHST 112 degF BHCT 96 degF BHP 1850 psi Starting Temp. 80 degF Time to Temp. 00:08 hr:mn Heating Rate 1.98 degF/min Startin Pressure 500 si Time to Pressure 00:08 hr:mn Schedule Com osition Slurry Density 17.00 Ib/gal Yield 1.00 ft3/sk Mix Fluid 3.913 gal/sk Solid Vol. Fraction 48.7 % Porosit 51.3 % Slur t e Conventional G 94 Ib of CEMENT Blend 199.77 Ib/ft3 Fresh water 3.858 al/sk Base Fluid D046 0.200 %BWOC Antifoam TU7E0006A0 D065 0.300 %BWOC Dispersant VF14175C21 D167 0.350 %BWOC Fluid loss 11581713051 S002 0.200 %BWOC Accelerator D010043-52-4 D065 0.700 %BWOC Dispersant VF14175C25 Rheolo Avera a readin s 300 282.0 355.0 200 202.0 293.5 100 117.5 174.0 60 78.5 119.0 30 45.5 72.5 6 15.5 26.5 3 12.0 18.5 10 sec Gel 22 28 10 min Gel 71 104 Tem erature 80 de F 98 de F Pv :260.458 cP Pv :326.885 cP Tv:25.191bf/100ft2 Tr:53.171bf/100ft2 Thickenin T ime 30 Bc 00:52 hr:mn 70 Bc 05:04 hr:mn 100 Bc 05:36 hr:mn NOTE: This is a pilot test; field blend may differ after testing. Please read field blend report carefully and compare to load out, contact the lab with any questions. Pilot testing done with Gubik 3 Surface Tail Field Blend cement sample, with additional D065 added to mix water. Page 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 29, 2008 3:49 PM To: 'Bill Penrose' Cc: Grimaldi, Louis R (DOA) Subject: RE: Gubik #3 Sundry App. L' Page 1 of 1 Bill, Commissioner Seamount asked me to pass on his "oral" approval of your plan. The only item I added was to contact the Inspector for the opportunity to witness the "tag" when you drill off the plug. Good luck. Tom Maunder, PE AOGCC From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, February 29, 2008 11:44 AM To: Maunder, Thomas E (DOA) Cc: alaska.drillingopsmgr@anadarko.com; Amjad Chaudhry; amber.babcock@fairweather.com Subject: Gubik #3 Sundry App. Tom, Here's the Sundry for setting the kickoff plug to sidetrack the fish in Gubik #3. We'll get a signed original and copy to you early this afternoon. The Commission's approval, verbal or otherwise, before the weekend would be appreciated. ~~ ~~L44.e Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 s 3/11/2008 • Maunder, Thomas E {DOA) From: Maunder, Thomas E {DOA} Sent: Friday, February 29, 2008 8.15 AM To: 'Bill Penrose' Cc: 'AOGCC North Slope Office' Subject: RE: BOP Test -Anadarko Gubik #3 ~ ~'"~ -- ~`'~ Page 1 of 1 Bill, I confirm our conversation. Please keep us advised. If it becomes necessary to plug back, you will need to at least get a proposal to me via email. An oral approval is possible, but I will need to speak with a Commissioner. A sundry will need to follow up to complete the required papenrvork. Call or message with any questions. I do not leave town until Sunday afternoon_ Tom Maunder, PE AOGCC 529-1645 From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, February 29, 2008 5:47 AM To: Maunder, Thomas E (DOA) Subject: BOP Test -Anadarko Gubik #3 Tom, I owed you this a-mail as soon as possible after our 12:50 lunchtime discussion on the phone. 1 confess events on the rig distracted me and Pve neglected to write until now. Please accept my apologies. As we discussed, the BHA is stuck in the hole at Gubik #3 and we jarred on it with the drilling jars while we lined up freepoint, bads off and fishing tools and ~rsonnei. We ran a freepoint, got backed off and pulled out of the hole. We are due a BOP test. 1 discussed with you the time-sensitive nature of the fishing operation and you agreed that we could go back in the hole with a fishing assembly, forgoing the BOP test until a more appropriate time. We don't expect to be fishing long. If we can't jar the fish loose quickly we plan to set a cement plug and sidetrack the fish. We plan to test BOPs as soon as we're out of the hole with the fish or in preparation for cementing. Regards, due Pew Vice President /Drilling Manager Fairwea#her E&P Services, Inc. 2000 East 88th Ave., Sui#e 200 Anchorage, Alaska 99507 907-258-3446 2/29/2008 Nabors 105 BOP Test ~ ~ Page 1 of 1 Regg, James B (DOA) From: Salario, John [John.Salario@anadarko.com] Sent: Wednesday, February 27, 2008 7:52 AM ,~ ~ 7"~ ~ ~~ To: Regg, James B (DOA) Gt,~k-'~3 Cc: Maunder, Thomas E (DOA) Subject: Nabors 105 BOP Test Jim /Tom Lou asked that we touched base and let you know our status, witch is that our drill string is stuck and we are unable to test BOP'S today. We are keeping the North Slope inspector updated on our situation. Thank You, Gary Goerlich / O'Neal Coyne Anadarko Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return a-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. 2/27/2008 Nabors 105 BOP Test • ~ Page 1 of 1 AAaunder, Thomas E DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 27, 2008 8:13 AM To: 'Satario, John' Cc: Regg, James B (DOA) Subject: RE: Nabors 105 BOP Test ~jv~ `~L John, Good luck. 1 had spoken with Bill Penrose and he related the situation. ~-~ ` -- `~ ~p Tom Maunder, PE AOGCC From: Salario, John [mailto:John.Salario@anadarko.rnm] Sent: Wednesday, February 27, 2008 7:52 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: Nabors 105 BOP Test Jim /Tom lou asked that we touched base and let you know our status, witch is that our drill string is stuck and we are unable to test BOP'S today. We are keeping the North Slope inspector updated on our situation. Thank You, Gary Goerlich / O'Neal Coyne Anadarko Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return a-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. ai2~i2aog ANADARKO PETROLEUM CORPORAT/ON 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. (907) 273-6300 adarrl~~ Petroleum Corporation February 22, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 {PTD # 207-176) ~~ ~ 7 Dear Mr. Norman, This is a report of Anadarko Petraleum Corporation's well operations on the Gubik #3 for the period February 15 through February 21, 2008, inclusive. February 15, 2008 2,628' MW i4.6 ppg Vis 57 sec Incl 0.70 deg C&C mud, observe well -slight flow due to gas breaking out of mud. Incr mud weight from 14.2 to 14.4 ppg. Observe well, POH 17 stds into shoe at 1,000'. Minor tight spots at 1,599', 1,250', 1,205' and 1,170'. Observe well while performing rig maint. RIH to 2,535', M/U top drive. Wash to btm, circulated up 10,035 units gas w/ MW cut to 13,7 ppg. Incr mud weight from 14.4 to 14.6 ppg while repairing rnud pump, Monitor well and POH. February 16, 2008 2,628' MW 15.2 ppg Vis 60 sec Incl 0.70 deg POH into shoe, monitor well -gas bubbles visible. RIH to btm, CBU -trip gas 7,168 units. Increase mud weight 14.6 to 15.0 ppg. S/D pumps for 20 min, observe well. CBU - max gas 330 units, BGG 60 units. POH into shoe, monitor well for 2 hrs. RIH to btm, CBU -trip gas 4,400 units, BGG 98 units. Raise mud weight from 15.0 to 15.4 PPg- February 17, 2008 2,628' MW 15.8 ppg Vis 61 sec Inc10.70 deg Increase mud weight from 15.0 to 15.4 ppg. SID pumps, observe well. POH into casing shoe -hole in goad condition. Observe well for 2 hrs. RIH to TD and CBU -max trip gas 4,050 units, mud wt cut to 14.7 ppg. Commence increasing. mud wt from 15.4 to 16.2 PPg• • • February 18, 2008 2,628' MW 16.6 ppg Vis 63 sec Incl 0.70 deg Weight up mud to 16.2 ppg. Check well for flow and POH into casing shoe at 1,007'. Hole in good condition and took correct amount of fill. Monitor well for 2 hrs -static. RIH to TD and circulate around. Max trip gas 7,000 units, mud wt cut to 15.2 ppg. Commence increasing mud wt from 16.2 to 16.6 ppg. February 19, 2008 2,628' MW 16.6 ppg Vis 61 sec Incl 0.70 deg Weigh up mud to 16.6 ppg. Check well for flow and POH into casing shoe at 1,007'. Hole in good condition. Monitor well for 2 hrs -static. RIH to TD and circulate around. Max trip gas 7,428 units. POH to shoe, change elevators while observing well -static. POH, SIB BHA. Test BOPE to 250/3,000 psi. Test witness waived by AOGCC. Download MWD and L/D same. LID stab and float sub. February 20, 2008 2,628' MW 16.6 ppg Vis 63 sec Intl 0.70 deg Handle BHA, RIH. CBU at shoe -max gas 8,200 units, mud cut to 14.7 ppg at max gas. RIH to btm, CBU. Max gas 2,610 units, mud eut to 15.7 ppg at max gas. C&C for logs. POH for logs -hole in good condition. M/U lubricator on shooting flange on annular preventer. Make up logging Run #1 (CH Tension -Temp - GR - CN - Zdens -Caliper - XMAC Acoustic) and RIH. February 21, 2008 2,628' MW 16.6 ppg Vis 62 sec Inc10.70 deg Continue OH logging Run #l. RID WL and iub, RIU bell nipple. MIU 8.75" cleanout BHA and RIH to btm. Hole in good shape. Circulate up copious large cuttings, 2' fill on btm. POH for logs. R/D riser, R1U Lub and WL. RIH w/ logging Run #2 (RCI). If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~~ ~~ Bill Penrose Vice President I Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal I Chuck Rowe -Anadarko 2 • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. {907) 273-6300 ~~a~~ Petroleum Corporation February 15, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ~ ~ ~ ~ ~~ RE: Weekly Report of Operations Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on the Gubik #3 for the period February 8 through February 14, 2008, inclusive. February 8, 2008 1,027' MW 10.7 ppg Vis 54 sec Intl 0.70 deg P/U 21 stands DP, SB in derrick. Center up BOPS, pull wear bushing, perform full-body test on BOPS and choke manifold. R/U test pump, AOGCC inspector Bob Noble on location. Test top VBRs, choke hose, HCR to 250/5000 psi. Leak on check valve. Tighten up on check valve and wellhead adapter flange. Re-test to 254/5000 -good test. Test btm VBRs, choke and kill HCR, manual choke and kill valves, valves 1 - 6 on choke manifold to 250/5000. Test annular preventer to 250/3000. February 9, 2008 1,027' MW 11.7 ppg Vis 58 sec Inc10.70 deg Continue to work on choke. Test choke valves to 250/5,000. Install spacers on blind rams. Test blinds and check valve. Pull test plug, set wear bushing, test-run manual locks on blinds. RIH w/ 5" HWDP and test VBRs against it. RIH to 742'. Test csg to 3,000 psi. RIH to 917'. Change top drive saver sub and grabber dies. February 10, 2008 1,047' MW 11.7 ppg Vis 53 sec Inc10.70 deg Tag FC at 926'. Drill FC and cement to 998'. Circ 2 hi-vis sweeps and POH. M/U smart BHA, test MWD, RIH. Drill float shoe, rat hole and 20' of new hole to 1,047'. C&C for LOT, pull back into shoe. February l 1.,.2008 1,285' MW 13.6 ppg Vis 56 sec Inc1 1.12 deg Perform LOT to 21.3 ppg EMW. Build mud weight to 13.fi ppg. Control drill 8-3/4" hole from 1,047' to 1,285' with background gas ranging from 1,~7 units to 9,000 units. • • February 12, 2008 1,706' MW 13.6 ppg Vis 52 sec Inc10.92 deg Drill 8-3/4" hole f/ 1,285' to 1,343' w/ background gas 44}0 -1,300 units. Drill and slide f/1,343' to 1,497' w! connection gas 400 -8,600 units. Drill and slide f/ 1,497' to 1,706'. February 13, 2008 2,149' MW 14.0 ppg Vis 49 sec Inc10.38 deg Drill 1,706' to 1,800', stopping to circulate nut gas every 4' - 10'. BGG 400-6~ units. Max cnxn gas 9,977 units. Drill and slide 1,800' to 2,000', circulating out gas every 10' to 50'. Max cnxn gas 4,000 units. C&C hole for wiper trip. Pump out of hole 2 stands. BGG at 3,900 units, circ back to btm. Raise MW f/ 13.6 to 13.8 ppg and S/D pumps for 20 min. Start pumps up, BU gas 5,000 units. S/D pumps again far 20 min. Start up pumps, BU gas 4,800 units. Raise MW f113.8 to 14.0 ppg. S/D pumps for 30 min. Start up pumps, BU gas 4,500 units. Control drill 2,000' to 2,149' w/ avg BGG of 475 units, cnxn gas 1,200 - 2,500 units. February 14, 2008 2,628' MW 14.2 ppg Vis 53 sec Inc10.17 deg Drill 2,149' to 2,b28'. BGG 450 -600 units, cnxn gas 2,9(}{} units. CBU and POH 5 stands. Fast stand pulled. tight. RIH to btm and CBU -circa up 7,500 units gas. Raise MW to 14.2 ppg. S/D and monitor well for 20 minutes - no flow, circ up 4,200 units gas. POH 7 stands. Line up trip tank and monitor on way back in. Proper hole fill and no tight spots. CBU on btm - BGG 360 - 400, cnxn gas 3,865 units. If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~c~ ~e~re~e Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 15, 2008 8:50 AM To: 'Bill Penrose' C, j`~ y. ~'~ ~ Subject: RE: Weekly Report -Anadarko Gubik #3 Thanks much Bill. Not a lot of fluid to compress with most of the shallow hole filled with 5" HWDP. I concur with the EMW calculation. The pressure pick is validated by the bleed down. With all the gas being seen in the 8-3/4" hole, testing the rams against the 5" HWDP was prudent. Call or message with any questions. Tom From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, February 15, 2008 8:35 AM To: Maunder, Thomas E (DOA) Subject: RE: Weekly Report -Anadarko Gubik #3 Tom, Page 1 of 2 Here you go. The curve isn't exactly a classic build-and-break curve which I attribute to the casing shoe being so shallow that the pressure ramped up quickly and broke over before a lot of data points could be plotted. We used the cementing unit which pumped mud at'/2 bbl/min. Note that, while this test form is set up to plot strokes vs pressure, the cementing unit's recorder was giving bbls/min. In order to make the curve meaningful, the leakoff data box in the upper right contains bbls x 10.nstead of strokes. That's also what's plotted along the bottom axis of the plot. Regards, S~i~ ~P.dt~t4de Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 15, 2008 8:11 AM To: Bill Penrose Subject: RE: Weekly Report -Anadarko Gubik #3 Hi Bill, As I remember, you all expected things to be gassy shallow and such is the case. One thing for sure, the delta between your LOT and the MW is getting smaller. If you don't mind, could you send the LOT information? Thanks in advance. Tom Maunder, PE AOGCC From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, February 15, 2008 6:59 AM To: Maunder, Thomas E (DOA) 2/15/2008 Page 2 of 2 Cc: Alaska.DrillingOpsMgr Subject: Weekly Report -Anadarko Gubik #3 Tom, Please find attached the weekly operations report for the Anadarko Gubik #3. Regards, ~i~ ~e~tocte Vice President /Drilling Manager Fairweather Ei3~P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 2/15/2008 CJ Well Name: Gubik #3 .~~~ ~ rl'+~ Csg SizelWt/Grade: 9-5/8", 40#, L-80, BTC Csg Setting Depth: 1007 TMD Mud Weight: 11.8 ppg LOT= 21.23 ppg - ~l Fluid Pumped= Bbls Estimated Pump Output: LEAK-OFF DATA Enter Strokes Enter Pressure Here Here 1 275 6 494 10 531 15 545• ~6t 20 586 25 595 ,. 30 586 34 604 39 641 44 650 49 636 54 668 59 687 64 664 Enter Holding Enter Holding Time Here Pressure Here 0 687 1 572 2 554 3 545 4 536 5 531 6 7 8 526 522 517 9 513 10 508 11 __ 504 12 499 13 494 • Date: 2!11/2008 Supervisor: Goerlich 1007 TVD Leakoff pressure = 494 psi Hole Depth = 1047 and Volume Back = bbls Barrels/Stroke CASING TEST DATA Enter Strokes Enter Pressure Here Here Time Herev Pressure Here • • f LEAK-OFF DATA f CASING TEST DATA 4000 i 3900 3800 - ~ 3700 -- -- 3600 ~ -- 3500 3400 3300 3200 3100 3000 i 2900 ~ 2800 2700 ~ 2600 2500 2400 -- 2300 2200 c 2100 2000 e m 1900 a` 1800 1700 1600 1500 1400 -- 1300 -- 1200 1100 1000 --- - 900 800 -- - - 700 - '. 600 - - - 500 -- 400 - - - - - 300 ~ -- 200 100 -- ~ - - ~ - 0 0 10 20 30 40 50 60 70 Strokes (# of) f LEAK-OFF DATA f-CASING TEST DATA 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 I 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 m ~ 2000 N a~i 1900 a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 5 10 15 20 25 30 Time (Minutes) • Appendix B Gubik Exploratory Well Anadarko Petroleum Company Note to File Request By application and supporting documentation submitted to the Commission on September 28, 2007, Anadarko Oil Company ("Anadarko") requests exemption from the oil discharge and prevention plan ("C-Plan"} requirements under AS 46.04.050(c) for their proposed Gubik exploratory gas well. Determinations 1. A gas-only determination for wells drilling in the Gubik area is not possible because oil indicators were encountered in Gubik Test No. 1 ("Gubik 1"), Gubik Test No. 2 ("Gubik 2") and Gubik Unit No. 1 ("Gubik Unit 1") and small quantities of oil were produced from the Prince Creek formation ("Prince Creek"} and Grandstand formation ("Grandstand") during testing in Gubik 2. 2. The Prince Creek produced dry gas at rates of up to 8 million cubic feet per day in the Gubik 2 well. The Chandler-Ninuluk undifferentiated formation ("Chandler- Ninuluk") produced at rates of up to 2.65 million cubic feet per day in Gubik 1. Similar rates are to be expected in offset wells. Abnormal pressures are to be expected in the stratigraphic equivalent of the interval from 1,792 to 1,841 feet in Gubik 2. 3. In general, reservoir quality degrades deeper in the geologic section. The highest quality reservoir rocks are found in the Prince Creek, with lesser quality rocks occurring in the Chandler-Ninuluk. The Seabee formation ("Seabee") and Grandstand contain sandstone intervals that are typically very poor in quality. Discussion Anadarko requests that their proposed Gubik exploratory well be exempt from C-Plan requirements as the well will not penetrate a formation capable of flowing oil to the surface. The proposed Gubik well will be located in TO1N, R03E, Umiat Meridian (Figure 1, below), about 100 miles southwest of Prudhoe Bay and about 17 miles east-northeast of the Umiat air strip. • • • Gubik Exploratory Well Determination Page 2 of 9 Note to File December 4, 2007 I have examined the well history records and mud log records from the three exploratory wells that are nearest to the proposed Gubik wells. They are, from west to east, Gubik 1, Gubik.2, and Gubik Unit 1 (Figure 1). Gubik Test No. 1 ,' ~ Gubik Unit No. 1 ®Gubik Test No. 2 Figure 1. Gubik Area Base Map Gubik 1 Gubik 1 was drilled to a depth of 6,000 feet, tested, then plugged and abandoned between May and August 1951 using 9.6 to 12.7 ppg water-base drilling mud. The well encountered seven formations. They are, from shallowest to deepest, the Gubik, Schrader Bluff, Prince Creek (Tuluvak Tongue), Seabee, Chandler-Ninuluk, Grandstand and Topagoruk. Oil indicators were recorded in the Prince Creek, Seabee, Chandler-Ninuluk, and Grandstand. Table 1 presents a compilation of this information from USGS Professional Paper 305-C ("PP 305-C"). Live oil was not reported in any of the detailed lithologic descriptions from the well site. The only report of live oil from Gubik 1 is in the "Oil and gas shows" table on page 228, which reports that shaly cores from the Grandstand between 4,261 and 4,543 feet reportedly bled traces of gas and oil from fractures.' ' USGS, 1958, USGS Professional Paper 305-C, p. 228. • • • Gubik Exploratory Well Determination Page 3 of 9 Note to File December 4, 2007 Well tests conducted yielded rates of up to 2,060,000 million cubic feet of gas per day ("MMCFD") from the Prince Creek and 2,651,000 MMCFD from the Chandler-Ninuluk. The test records in PP 305-C do not mention any recovered oil. Formation Petrol. Oil Stain / Cut Residue Porosity Air Perm Odor Shows % and Prince Creek Faint to None Very None to 15 0 (890-1,760') kerosene reported pale to brownish- like elow eeow Seabee (1,760 - None to None Very Yellow-brn, 8 to 29 0 to 988 3,305' faint re orted ale eas Chandler- Faint to None Very Greasy stain 10 to 15 0 to 265 Ninuluk (3,305 - good reported pale - to yellow 3,735' straw Grandstand Fair to None Pale Pale yellow No No (3,735 - 4,315' ood re orted straw to yellow anal sis anal sis Table 1. Oil Indicators from Gubik 1 Gas analyses conducted on three samples from 1,495, 1,738 sand 3,519 feet were dominated by methane (97.05, 97.05 and 94.7%, respectively) and ethane (1.25, 2.95, and 4.5%, respectively. Only the sample from 1,495 feet contained heavier gases ("propane plus", 1.57%). Gas analyses are not available for the interval from 4,261 and 4,543 feet. Gubik 1 encountered gas, small amounts of residual oil, and possibly very small amounts of mobile oil. The high mud weights used to drill the well may have damaged the well bore. Gubik 2 Gubik 2 was drilled to a depth of 4,620 feet using 11.5 to 12.7 ppg water-base drilling mud, and then tested. After running cement plugs from 2,300 to 2,200 feet, the crew swabbed in the well while tripping pipe. The well blew out, ignited, and collapsed the rig. The well sanded up, blew out again two days later, sanded up again, was extinguished with carbon dioxide, and the hole was filled with 204 barrels of water, which indicated the bridge was at about 1,800 feet. The well was junked and abandoned in December 1951. Table 2, below, displays the oil indicators reported while drilling and coring Gubik 2.2 Conventional core from the Tuluvak tongue of the Prince Creek reportedly bled oil and gas between 1,841 to 1,880 feet. The lithologic description of this portion of the core z USGS, cited above; data compiled from p.231- 253 in spreadsheet \\DOA-ANC- AOGCC\VOL1\fIOME\AOGCC\SFDAVIES\Daily_Document_Record\2007\071203_Gubik_Wells Lab_ Analyses_Combined. xls. • • ~ • Gubik Exploratory Well Determination Page 4 of 9 Note to File December 4, 2007 mentions faint odor, straw-colored cut and yellow residue from samples taken from 1,843 and 1,846 feet, but does not mention oil stain or live oil. Five core samples were analyzed for porosity and permeability from this interval. They measured 5, 18, 20, 20 and 25% porosity and 0, 61, 95, 270 and 3,780 and permeability. Formation Petrol. Oil Stain / Cut Residue Porosity Air Perm Odor Shows % and Prince Faint to Cores bled Pale to V pale 4 to 25 0 to 3,780 Creek fair oil & gas; yellow yellow to (most were (1,135 - olive- brown < 200 md) 2,010') colored stain in 2 sam les Seabee None to None None None <1 to 15 0 to 6 (2,010 - slight reported reported reported (9 of 13 3,585') samples measured 0 or <1) Chandler- V faint to None None to Greasy 2 to 14 0 to 60 Ninuluk good, reported v pale - stain to (most (3,585 - gasoline- straw yellow samples 4,025') like were 0) Grandstand None to Cores bled V pale Greasy 2 to 14 0 to <1 (all (4,025 - excellent oil & gas; straw to stain to but one 4,395') oil stain, yellow brownish- sample spotty to yellow measured strong 0) fluorescence Table 2. Oil Indicators from Gubik 2 DST 7, conducted from 1,792 to 1,841 feet in the Prince Creek, produced gas at a rate exceeding 8 million cubic feet per day.3 This is the only zone shown by testing to have high-pressure gas,4 and it is undoubtedly the source of the gas that blew out and caused the fire that destroyed the drilling rig. Records from DST 7 do not mention any associated oil or water production. No samples were analyzed from this test interval. DST 8, which tested from 1,844 to 1,885 feet, had an initial blow of 400 psi behind a f- inch orifice, but frozen flow prover lines prevented an accurate gas-volume determina- tion. No further gas or fluid information is reported in PP 305-C. DST 9, conducted from 1,87b to 1,885 feet, recovered 7 gallons of gas, oil and water cut mud. The closest sample to this interval is from 1,873 feet, and it measured 5% porosity and zero millidarcies permeability. 3 USGS, cited above, p. 253. a USGS, cited above, p. 231, 255. • Gubik Exploratory Well Determination Page 5 of 9 Note to File December 4, 2007 Oil and gas also reportedly bled from the upper portion of the Grandstand between 4,031 and 4,058 feet. s Samples taken from 4,037 feet and 4,047 feet were described as having fair to good oil odor, pale-straw-colored cut and very pale-yellow to yellow-colored, but there is no mention of oil staining or live oil in the lithologic description of the core. DST 19, conducted form 4,039 to 4,060 feet recovered 12 feet of water-cut mud in 180 minutes. Four core samples from this interval measured 4 to 8 % porosity, and from zero to less than 1 millidarcy permeability. DST 22, from 4,232 to 4,261 feet, recovered 60 feet of oil-cut mud in 165 minutes. Seven core samples from this DST interval measured 3 to 11% porosity, and all measured zero millidarcies permeability.6 Gubik 2 encountered gas and small amounts of both residual and moveable oil. The high mud weights used to drill the well may have damaged the well bore. Gubik Unit 1 A third exploration well, Gubik Unit 1, was drilled by Colorado Oil and Gas to a total depth of 4,406 feet from May to September of 1963 using 11.8 to 16.1 ppg mud. The well was tested, and then plugged and abandoned in November 1963. The "combination stratigraphic and gas log" and daily drilling reports note several instances minor oil stain and sample fluorescence, suggesting small amounts of residual oil. Prince Creek samples from 1,216 to 1,250 feet displayed moderate fluorescence, and moderate fluorescence and pale yellow cut were observed at 1,810 feet. The Seabee displayed passible oil staining at 2,950 and 3,250. The Chandler-Ninuluk showed signs of oil stain at 3,450 and 3,500 feet, a trace of residual oil at 3,590 feet, and scattered fluorescence and pale yellow cuts from 3,625 to 3,730 feet. The Grandstand displayed good sample fluorescence, but poor sample cut, from 4,130 to 4,150 feet. A total of 12 DSTs were conducted, but the records indicate only moderate amounts of gas and minor amounts of gas and water-cut drilling mud were recovered. There is no mention of recovered oil. Gubik Unit 1 encountered gas and small amounts of residual oil. The high to very high mud weights used to drill the well may have damaged the well bore. Reservoir Quality Laboratory analyses performed on samples from conventional cores recovered from Gubik 1 and Gubik 2 are presented on Figures 2 through 6, below. Correlations of wire line logs are obvious and of high confidence. Sample depths from Gubik 1 have been normalized to equivalent depths in Gubik 2. Nearly all samples were consisted of sandstone, and it is assumed that the USGS geologists selected representative samples from each core. s USGS, cited above, p. 252 and core descriptions on pages 239 and 240. 6 USGS, cited above, p. 252 to 254. • ~ • Gubik Exploratory Well Determination Page 6 of 9 Note to File December 4, 2007 30 zs zo e U m 15 a 0 `o a 10 S Gubik 1 and Gubik 2 -Porosity Measurements All Formations -Samples Arranged in Depth Order (Deeper to Right) Figure 2. Porosity Measurements from Gubik 1 and Gubik 2 soo 450 400 350 8 300 ~} 250 d 200 150 100 50 0 1 6 11 18 21 26 31 36 41 46 51 58 51 66 71 76 81 86 91 96 101106111118121126131 136 Sam de Number Figure 3. Permeability Measurements from Gubik 1 and Gubik 2 1 6 11 18 21 26 31 38 41 46 51 SB 61 86 71 76 81 86 81 86 101 106 111 116 721 126 131 136 141 Sample Number Gubik 1 and Gubik 2 -Permeability Measurements All Formations -Samples Arranged in Depth Order (Deeper to Right) sss area • • • • Gubik Exploratory Well Determination Page 7 of 9 Note to File December 4, 2007 In general, reservoir quality degrades deeper in the geologic section. The highest qualities of reservoir rocks were encountered in the Prince Creek, with porosity ranging from 4 to 29 percent and permeability ranging up to 3,780 millidarcies. a n m e r Gtblk 1 and b'ublk 2 - Paoslty Merit titrDik 1 and Grbik 2 - Pemrabeity sleasvsmwxs PDnee Creek Ftxmatlon - Samples Amarged In Depth lAdar Prince Crack FamraCOn -Samples Arraged m Dspth Order (Deeper to Rlgtt) - (Deeper to Right) >,e s a ao ~~ ~~ aA rfio m . Figure 4. Prince Creek -Porosity and Permeability Measurements Sandstone ranged from very fine- to medium-grained, with occasional occurrences of coarse- to granule-sized grains, soft and friable to occasionally hard, with varying quantities argillaceous and calcareous cement. Gubik 7 ~d Gubik Z -Porosity kAeaedrements SeWee Forman -Stmplea Arranged in Depth Ober (Deeper to Right) s s s ~ is 'r ,s u e r r n • aeeee.ae a rs, s a ~~ aA s s e GfiDik 1 and lkbik 2 - Permeability Meastrsnwas Ssabse Fmr3etion - Semplss Mrergsd in Depth Order (Deeper to Right) Figure 5. Seabee -Porosity and Permeability Measurements Sandstone intervals sampled from the Seabee were much poorer in quality: porosity ranged from 1 to 15 percent, and permeability ranged from 0 (12 samples) to 2 to 6 millidarcies (four samples). These sandstones were typically very fine-to fine-grained (occasionally medium grained), hard and massive, with slight to moderate amounts of calcareous cement. G 11 1fi t3 ii 31 Y N Y S3 Si n S-pY e-.r fi n x Gubik Exploratory Well Determination Note to File December 4, 2007 • • Page 8 of 9 Grbik 1 and Glbic 2 -Permeability Measvemerde Chandlsr~lintltk Formation - Sartplea Arrargad in Depth Order (Deeper to Ri~6t) i G6dwk 7 end GubiN 2 - Porosity hkesuremenb ChenAer-Ninuluk Fonntlion -Samples Arranged in Depth Cider (Deeperto Right) ^ a e _ +6 a . % 6 Figure 6. Chandler-Ninuluk -Porosity and Permeability Measurements Reservoir rock quality increases in the Chandler-Ninuluk. Porosity ranged from 2 to 15 percent, and permeability from 0 (most samples) to 265 millidarcies. Sandstone samples were typically silty, very fine- to medium-grained, and hard, with common slight to moderate amounts of calcareous cement. 0 a a e % a % 6 Gli6ik 1 end Gubik 2 - Porosity kkasuremmb Grandstand Formation -Sempks Arranged in Depth Order (Deeper to Right) Gtbik 1 and OlitRc 2 -Permeability Meestremerns Ora6dsbnd Formation - Sangles Arranged in Depth Order iDeeper to Right m w ~~ ~~ ae 19 >e 6 Figure 7. Grandstand -Porosity and Permeability Measurements The quality of potential reservoir rock in the Grandstand is very poor. Samples were very fine-to fine grained sandstone that was hard, silty, and generally non-calcareous. Porosity ranged from 2 to 14 percent. One sample measured less than 1 millidarcy permeability, and the other 21 samples were impermeable. t 6 n % n a e ^ e.6Mraeiee 1 6 11 % ai 31 Y s~rrew.. 6 11 % E1 Swpb Mw~Yr ^ ik E 1 Well Det~ tian ~ ~ ~a e 9 of 9 Gub xp oratory g Note to File December 4, 2007 Conclusions Qil indicators were encountered in Gubik 1, Gubik 2 and Gubik Unit 1. These indicators were observed to varying degrees within the Prince Creek, Seabee, Chandler-Ninuluk and Grandstand. Small quantities of oil were observed bleeding from cores from Gubik 1 and 2. Small quantities of oil were produced from the Prince Creek and Grandstand during testing in Gubik 2. Therefore, agas-only determination for wells drilling in the Gubik area is not possible. The Prince Creek produced dry gas at rates of up to 8 million cubic feet per day in the Gubik 2 well. The Chandler-Ninuluk produced at rates of up to 2.65 million cubic feet per day in Gubik 1. Abnormal pressures are to be expected in the stratigraphic equivalent of the interval from 1,792 to 1,841 feet in Gubik 2. In general, reservoir quality degrades deeper in the geologic section. The highest quality reservoir rocks are found in the Prince Creek, with lesser quality rocks occumng in the Chandler-Ninuluk. The Seabee and Grandstand contain sandstone intervals that are typically very po m quality. Steve Davies Sr. Petroleum Geologist December 4, 2007 • ANADARKO PETROLEUM CORPORATION 3201 C St. STE. 603 ANCHORAGE, ALASKA 99503 USA PH. {907) 273-6300 ~a~~ Petroleum Corporation February 8, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations ~ ,,, ,( Anadarko Petroleum Corporation: Gubik #3 (PTD # 207-176) ~ ~l/ ~~ Dear Mr. Norman, This is a report of Anadarko Petroleum Corporation's well operations on the Gubik #3 for the period January 31 through February 7, 2008, inclusive. January 31, 2008 278' MW 9.8 ppg Vis 67 sec M/U 12-1/4" bit, RIH, tag bottom at $5'. Build mud volume, test surface lines, wash from 85' to 105'. Drill from 105' to 278' wl packing off problems. Februarx 1, 2008 494' MW 9.8 ppg Vis 77 sec Inca 0.71 deg POOH, clean and inspect bit, RIH. Drill f/ 278' to 494'. POOH. M/IJ BHA with MWD and LWD components. February 2, 2008 1,027' MW 10.6 ppg Vis 83 sec Inc10.70 deg Finish M/U BHA, RIH. Ream to bottom (5' of fill). Drill 12-114" hole f/ 494' to 849'. Charge pump motor failed. Repair motor, drill f/ 849' to 1,027'.. C&C hole and POOH slowly for MAD pass. February 3, 2008 1,027' MW 10.6 ppg Vis 78 sec Inc10.70 deg MAD pass f/ 428' to 248'. RIH to 1,027 - no fill. C&C hole for casing and POH. Download LWD and R/U to run 9-5/8" casing. February 4, 2008 1,027 MW 10.7 ppg Vis 76 sec Inc10.70 deg Run 9-SI8" casing to 1,007'. Circ 2 casing volumes. R/D casing running equip. RIH w/ 4" DP and screw-in sub. Space out and screw into float collaz. Circ w/ rig pump. 1 • Hanger bypass ports plugged, lost circ. Rig hoses to take returns from conductor outlets. C&C well w/ full returns. Pump 38 bbls spacer, 127 bbls permafrost cement and 23 bbls Class G cement. Displace w/ mud using rig pumps. Full circulation throughout job. CIP at 2020 hrs. Back out screw-in sub and circ out. R/D lines. February 5, 2008 1,027' MW 10.7 ppg Vis 6b sec Inc10.70 deg POOH, SJB DP, L/D screw-in sub. L/D landing jt, N/D diverter line and riser. N/U wellhead and test to 4,800 psi -good test. N/U BOPS while cleaning pits. February 6, 2008 1,027' MW 10.7 ppg Vis 64 sec Inc10.70 deg Land annular preventer and measure for bell nipple. 1~~:-tall kill line, HCR and manual valves. Install bell nipple and turnbuckle. Install accumulator lines to BOPS, install choke line and hammer up all BOP bolts. Found shear ram blocks not fully retracting into bonnets. Remove ram blocks, set wear bushing. February 7, 2008 1,027' MW 10.7 ppg Vis 52 sec Inc10.70 deg L/D DCs f/ derrick. Laad pipe shed w/ 8-3/4" BHA. P/IJ and RIH on 4" DP to 800'. Circ hole and POOH. Open blind/shear doors, take measurements and re-tighten bolts. Remove manual locks f/ blind/shears, install rams and function -functioned properly. P/U 4" DP f/ pipe shed and stand back in derrick (SLM). If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, For ANADARKO PETROLEUM CORPORATION ~c~ ~eor~ade Bill Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. cc: Fred McDougal /Chuck Rowe -Anadarko 2 Page 1 of 1 Maunder, Thomas E (DOA) From: Bill Penrose [bill@#airweather.com] Sent: Thursday, January 31, 2008 7:37 AM To: Maunder, Thomas E (DOA} Subject: Anadarko Gubik#3 ~oe~ ~ ~~ r Tom, 1, ~j FYI. the Gubik #3 will spud today. I'll issue the first weekly operations report next Friday then each Friday after that. Regards, ~~d6 Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 1/31/2008 • ALA5SA OIL A1~TD GrAS COl'~5ERQATIOI~T COAII1i155IO1~T Fred McDougal Drilling Operations Manager Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, AK 99503 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Exploration Well, Gubik No. 3 Anadarko Petroleum Corporation Permit No: 207-176 Surface Location: 2411' FSL, 1767' FEL, SEC. 17, TO1N, R3E, UM Bottomhole Location: 2411' FSL, 1767' FEL, SEC. 17, TO l N, R3E, UM Dear Mr. McDougal: Enclosed is the approved application for permit to drill the above referenced exploration 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. A mudlog and samples are required for this remote exploratory well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals below conductor pipe and 10' sample intervals through target zones. At a minimum, openhole gamma ray, resistivity, and sonic or density porosity logs must be recorded from the base of conductor pipe to total depth of the well. Anadarko's intention to conduct flow testing and flare gas in amounts up Anadarko Petroleum Corp Gubik #3 Permit: 207-176 to 200 MMcf is acknowledged. Produced volumes should be reported to the Commission. 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 a minimum of 48 hours in advance at (907) 659-3607 (pager). DATED this~ay of January, 200$ cc: Department of Fish & Garne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. R STATE OF ALASKA ~ qEC 1 0 2007 AL ,-r<A OIL AND GAS CONSERVATION C M i SION PERMIT TO DRILL~c~~~~~-'~taska Oil & Gas Cons. Gommissun 20 aac 2s ons . _ _~_..___ 1a. Type of Work: Drill Q , Redrill ^ Re-entry ^ 1b. Current Well Class: Exploratory ~ 4 Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone ^ 1c. Specify if well is propose or. Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: Anadarko Petroleum Corporation 5. Bond: Blanket Q Single Well ^ Bond No. 22014630 ! 11. Well Name and Number: Gubik #3 3. Address: 3201 C Street, Suite 603, Anchorage, AK. 99503 6. Proposed Depth: MD: 4,400' TVD: 4,400' - 12. Field/Pool(s): 4a. Location of Well (Governmental Section): Surface: 176TFEL 2411'FSL S17 T01 N-R03E '` 7. Property Designation: ASRC Lease CA003 Exploratory Top of Productive Horizon: 1767'FEL 2411'FSL S17 T01N-R03E 8. Land Use Permit: ASRC 13. Approximate Spud Date: 1/2/2008 Total Depth: 1767'FEL 2411'FSL S17 T01N-R03E 9. Acres in Property: 3840 14. Distance to Nearest Property: 1,767' 4b. Location of Well (State Base Plane Coordinates): ASP N27 Surface: x- 314531 Y- 5647250 ~ Zone- 4 10. KB Elevation ,L~~'~Y/SL~{ (Height above GL): 20 feet ~,,.~p• 1 . Distance to Nearest Well 1 mile 16. Deviated wells: Kickoff depth: Maximum Hole Angle: 0 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2,791 psi Surface: 2,307 psi 18. Casing Program: Specifications To p -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 30" 16" 100' 100' 100' Grouted to surface - 12-1/4" 9-5/8" 40# L-80 BTC 1000' 0 0 1,000' 1,000' 146 bbls 8-3/4" '' 7" 26# L-80 BTC-M 4,400' 0 0 4,400' 4,400' 159 bbls 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 Q Drilling Program Q Time v. Depth Plot Q Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^~ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Bill Penrose 258-3446 Printed Name Fred McDougal Title Drilling Operations Manager Signature Phone 273-6302 Date / '7 O Commission Use Only Permit to Drill Number: ~? ~' ~ ~~ API Number: ~~1 50- ~iC.J 7 ~ ~ I ~ '' ®~ Permit qp oval Date: V[ Z ~ See cover letter for other requirements. Conditions of approval : If box is checked, w ay not be used to explore for, test, or produce c albed m thane, gas hydrates, or gas contained in shales: Other: ~~~~h~~~~~~ ` Samples req'd: Yes[vYNo^ Mud log req'd: Yes~No^ ` ` ~~ HZS measures: Yes^ No Q~ Directional svy req'd: Yes No~ ~~ ~~i~`~t~ '~VG ~~5 . 500 ~- Z~~~~~~ ~Q\ ~,-~ . ~(~~ ~5 ~ ~h<<CG~ APPROVED BY THE COMMISSION DATE: ~" ~is/' ,COMMISSIONER Form 10-401 Revised 12/2005 / bmit in Du licate " U!~I G i N~~~'~~~' p i i ANADARKO PETROLEUM CORPORATION 3201 CSt Ste. 603 ANCHORAGE, ALASKA 99503 U.S.A. PH. (907) 273-6300 Petroleum Corporation December 7, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Gubik #3 Dear Mr. Norman, RE~Ei`~ED DEC ~ Q 2007 Alaska Oil $ Gas Cons. Commission Arrchorag~e Anadarko Petroleum Corporation hereby applies for a Permit to Drill a gas exploration well from an ice pad in Brooks Range foothills approximately nine miles east of Umiat. Anadarko plans to use Nabors Rig #105E to drill its Gubik #3 well and complete it for testing before moving the rig to the Chandler #1 well location. The Gubik #3 will be tested and plugged and abandoned without the rig on location. Ice roads will be constructed between Umiat and the Gubik and Chandler locations to enable the ground movement of materials and personnel flown via fixed wing aircraft into Umiat. The drilling rig and camp will be mobilized via rolligon from a logistical support ice pad located adjacent to KRU 2P Pad. During drilling operations, the rolligons will carry fuel to the drilling location and waste mud and cuttings back to the 2P support pad for trans-shipment to the approved disposal facilities in Prudhoe Bay Field. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill 2) A plat showing the surface location of the well 3) Proposed drilling program 4) Drilling Time versus Depth Plot 5) Proposed Gubik #3 Wellbore Diagram 6) Pore Pressure Predictions 7) MASP Calculations 8) Drilling Area Risks and Waste Disposal 9) Casing Properties and Design Factors 10) Diagrams and Descriptions of the BOP Equipment to be Used 11) Drilling Fluid Program 12) Cementing Program The following are Anadarko's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Bill Penrose, Drilling Superintendent (20 AAC 25.070) (907) 258-3446 2) Geologic Data and Logs John Kamm, Senior Staff Geologist (20 AAC 25.071) (832) 636-8460 If you have any questions or require additional information, please contact me at (907) 273-6302 or Bill Penrose at (907) 258-3446. Sincerely, ANADAR OLEUM CORPORATION ~" :~~~ Fred McDougal -- Drilling Operations Manager enclosures cc: Bill Penrose -Fairweather C:\P ROJ ECTS\WORD\LTRH D. WPD REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION .~. ~~. y a ~ " i = ' ~ '' _- _- . - - -'` ,_ GUBIK 3 ~~i~' ~~h' \ `L ~:~' ter ~~~~ V'.r -~ .-es ;~ i : ` ' SCALE: ' ' . 15 i . ~ . ~`' _a~~, - . -:~~`16-~~_ ; 13' ~~~,• 18 .~, ~ ` . J i - ~`'~ 1 = 200 , ~ OX . _..- . .~i , ~ .., ~. - ,, : 4 ~~_ S ~~ ~ - \ • NOTES .,~ ~ J;~.~ ~. {; _ _~._~ i _ ~,I,, - .r. Vi p ~ M\~E ,~~ ~ ' ~M , ~ _ _u ~, . ~ ~ '~~ ~ ` ~ " { ` _~ ~'' 1. ELEVATIONS SHOWN ARE NAVD88 PER OPUS SOLUTION. 6 e•4•,p ~, - s ~ . ` -;~. ~ k _ -= ~ ~~ .~ ~21_u 22 ~'-~ ~~ I .~ y p ~ , 2. COORDINATES SHOWN ARE NAD27, -" _ _ _ " #,~~ ~w ' x - ~~~ ` 'w~~!~ ~ 'r~y~~~`1 ' ~`'~'~; ~ ~ ~ ~ ALASKA STATE PLANE ZONE 4. . . - ,' r" ~` ~ . ~''• .~, ~~` '} LL '•~_ ' °' ' ' ~ 3. GEODETIC COORDINATES ARE NAD 27. ° , _ , ;`~ '~ ' `~'~ -'==~J~~~~'`;~^X `-' - ~.:~ - `"' ^~ " 4. ALL DISTANCES ARE TRUE. 5. PAD IS ROTATED 70° WEST FROM TRUE _ ~'` way ~ ,% ,, ~ 'c._~::~,, _= - - ,>,,._ ~z z; =~ t fj; ' ~ - ~ •~ ~ t r :~ i27_< ' :~ . ~ ~ p % NORTH. Q ~ . _ _ ~:A .. m. ~- : a =~ ~ '~' "'~ '~~`; "TOWNSHIP 1 NORTH GUBIK 3 ~~s ~ t~ VICINITY MAP 1 MI ~ 1" = APPROX ~/ ,3 . . ~ ~ PROPOSED \ 35' ACCESS ` ~ ROAD `9 ` Q r o GUBIK 3 \ LOCATED WITHIN PROTRACTED S SEC. 17, T 1 N, & R 3 E, ~ ~O~ ~, ~°' f~ M"'~`~' F S ~ ~ UMIAT MERIDIAN. ~sA 2411' F.S. L, 1767' F.E.L. _ \~`~ 25' ~ \ Sip. ~' '` ~s~ LAT = 69°26'29.17" N ° ' " ~ O / /~o ~~95`, ~ o ~ 31.45 W 26 L~ LONG = 151 rrNGS Y = 5,647,250 L ~r cF ~sQ X = 314, 531 ' ~P 12' ~ M"~/ QPr~ ryry ~ J ~ ~o° / ~,z o 19~~ p /o /4 ~ S ~ / 4 4 2 - p 19 ~ O o ~ / , ~~ 9 ~,~ ~-- ~ T ~~ DENOTES SPILL TRAJECTORY c /COMPLE ION 3O' EQUIPMENT O~`v -~ STAKED CONDUCTOR LOCATION l STAGING h L4 ~ / (~ AREA ~~ ~ 9 o ~sO S00 " S LOUNSBURY ~ P a PRO ~~, ~ Q~ ~ / I TS, 5- POSED ICE PAD L \9 & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS l ( ~~ / ~ ~ / /' /95 ~ I . ~ ~ k d GUBIK 3 EXPLORATORY WELL \ a r o n a AS STAKED EXHIBIT WITH PAD CONFIGURATION Petroleum Corporation INCLUDING CONTOURS AND SPILL TRAJECTORY CADD FILE N0. LK601 D971 15 OCT. 07 DRAWING N0: LK601 D971 SHEET: 1 of 1 REV: 0 ~nadarl~~ Petroleum Corporation Gubik #3 SUMMARY DRILLING PROCEDURE Pre-Rig Work 1. Drill a conductor hole to ~80' below ground level, run a 16" conductor and grout the exterior with permafrost cement. ~ 2. Excavate around conductor and install 10' diameter, 12' deep insulated cellar. Fill the bottom of the cellar with permafrost cement one foot thick. 3. Cut off 16" conductor and install landing ring, diverter adapter, spacer spool and diverter tee `,~ Q Drilling Procedure Q~~ct~~~.~ `t ~~~~'~E ~~~`~~`~~~~'~~`°~ ~~~ t~ ~ ~'s ~ g 1. Move in Nabors Rig # 105 and rig up. Install diverter on diverter spool and function test. 2. M/U 12-1/4" bit on packed BHA. 3. RIH with Bit #1 and spud the well. Drill the 12-1/4" hole to +/- 1,000' using as light a weight on bit as necessary in to keep the hole as vertical as possible. Use water-base spud mud system as specified in the mud program. Use mud loggers and MWD/LWD to monitor progress through the section. 4. At the section TD, condition the hole for running casing. w 5. Run 9-5/8", 40#, L-80, BTC surface casing to +1,000' as follows: 9-5/8" float shoe 2 joints 9-5/8" casing 9-5/8" float collar 9-5/8" casing to surface Land the casing hanger in the wellhead, washing down if necessary. Back off and lay down the landing joint. M/LT float collar screw-in cementing sub and centralizer onto drill pipe and RIH. Screw into float collar. i ~ R/iJ cementing head onto drill pipe and test head and lines. Circulate and condition the hole for cementing. 6. Pump lead cement as follows: Begin pumping 50 bbls of 8.4 ppg Chemical Wash 100 at 4 bbl/min. Pump 50 bbls of 10.0 ppg MudPush XT spacer at 4 bbl/min. ~ ~ Follow spacer with 123 bbl (includes 200% excess) of 10.7 ppg ASL lead slurry at 4 bbls/min. As soon as clean lead cement is seen returning to surface, stop mixing and pumping lead cement and commence mixing and pumping tail cement as follows: ~' Pump 23 bbl (includes 50% excess) of 15.8 ppg V-215i Surface Tail FB slurry at 4 bbls/min. Drop top plug and displace with 9.5 bbls of 9.5 ppg drilling mud at 7 bbl/min. Bump plug with 500 psi. Hold pressure for 2 minutes. Bleed off and ensure floats are holding. Unscrew float collar cementing sub, circulate out drill pipe and POH. 7. While WOC, N/D diverter assembly and install multibowl wellhead and test. 8. N/LT 11", lOK WP BOPE with pipe rams sized for 4" drill pipe. Set test plug and test to 250/5,000 psi. Pull test plug, install wear bushing. 9. M/LT 8-3/4" clean-out BHA and RIH. Clean out to float collar and pressure test casing. Drill out float collar, cement, float shoe and 20' of new hole. Con~du~~ct -' leak-off test. ~, ~„~~,,~.~~.,~~~,,~ ~T~- `~1 ~~ ~~s Q~ 10. Pull bit back up into casing shoe and circulate and condition mud until properties are uniform and within specified parameters. POH. 11. M/IJ 8-3/4" drilling assembly on 4" drill pipe. 12. Dri118-3/4" vertical hole to planned 4,400' TD. Use mud loggers and MWD/LWD to monitor progress through the section. 13. At TD, circulate and condition the hole for open-hole logs. 14. Rig up electric wireline unit and run the following open hole logs: Run 1: GR/HDIL (res.) / CN/ZDL/XMAC (sonic) / WGI (borehole profile) Run 2: RCI (samples and pressures from Tuluvak and Nanushuk Sands) Run 3: GR/MREX Run 4: VSP (near offset) Run 5: Rotary SWCs 15. After logging is complete, circulate and condition hole for running casing. 16. Rig up casing running equipment and crew to run 7" casing. Install 7" rams in the `~ top BOP cavity. ~ .}~~~-. i ~~`l `~~~ ~ ~r 17. M/LT and run 7", 26#, L-80, BTC-M casing to TD as follows: 7" float shoe 2 joints 7" casing 7" float collar 7" casing to surface R/U cementing head and test head and lines. Circulate and condition the hole for cementing while reciprocating the casing. 18. While reciprocating the casing, pump cement as follows: Pump 10 bbls of 8.4 ppg Chemical Wash 100 at 5 bbl/min. Pump 40 bbls of 13.0 ppg MudPush XT spacer at 5 bbl/min. Drop the bottom wiper plug. Follow spacer with 19 bbl (includes no excess) of 10.7 ppg ASL lead slurry at 5 bbls/min. Follow lead with 140 bbl (includes 50% excess) of 15.8 ppg tail slurry at 5 bbls/min. Drop top plug and displace with 150 bbls of 12.5 ppg drilling mud at 7 bbl/min. Bump plug with 500 psi. Hold pressure for 2 minutes. Bleed off and ensure floats are holding. Rig down cementers and clean up. Clear rig floor. 19. R/U wireline and RIH with CBL/GR/CCL/Temp logging tools. Log entire wellbore with 1,000 psi applied. POH and R/D wireline. .~ 20. Pressure test 7" casing to 3,500 psi for 10 minutes. 21. RIH with 6-1/8" bit and 7" casing scraper to PBTD. Displace mud from wellbore with KCl completion fluid. POH, freeze-protecting top 1,000' of wellbore. Use vac trucks to empty the rig pit system of drilling mud, transferring the mud to storage tanks in preparation for moving the rig. 22. M/L7 TCP gun assembly with permanent packer and 3-1/2", 9.3#, L-80, IBT-M tailpipe on drill pipe. 23. RIH and correlate guns on depth (depth, to be near bottom of Tuluvak, will be determined from logs). Set packer/gun assembly and POH with drill pipe. 24. M/U production packer, chemical injection mandrel and sliding sleeve on 3-1/2", 9.3#, L-80, IBT-N tubing. 25. RIH to packer setting depth above top of Tulavak. Set packer. 26. P/LT 11 ", SM tubing hanger. Terminate CI control line and feed through tubing hanger. 27. Land and lock tubing hanger in wellhead "B" section. Install BPV. 28. N/D BOPE, N/U tree. Test tree to 5,000 psi. Freeze protect tree and all annulus valves. 29. Rig down and move drilling rig to the Chandler #1 drilling location. 30. Mobilize, rig up and test well testing equipment. 31. R/U pump and pressure up to fire TCP guns. R!D pump. 32. Perform flow test and buildups on Nanushuk Formation. 33. Gather surface and downhole fluid samples. 34. After final buildup period, R/U pump and re-inject all fluids produced into the Nanushuk Formation, followed by diesel. 35. R/U wireline and test lubricator. M/LJ and RIH with TTBP and set in 3-1/2" tailpipe within 50' of the top perfs. POH. 36. Pressure test TTBP. 37. M/L1 and RIH with through-tubing perforating guns and perforate the Tuluvak Formation. 38. POH and R/D wireline. 39. Perform flow tests and buildups on the Tuluvak Formation. 40. Gather downhole and surface fluid samples. 41. After final buildup period, R/U pump and re-inject all fluids produced into the Tuluvak perforations followed by diesel. 42. R/LJ wireline and test lubricator. M/LT and RIH with TTBP and set in the 3-1/2" tubing within 50' of the top perfs. POH. 43. Pressure test TTBP. Plug &Abandonment The Gubik #3 will be P&A'd without the drilling rig as specified in a separate procedure. Gubik #3 0 500 1000 1500 ^~ ~ 2000 ii c Q ~ 2500 3000 3500 4000 (3 Days) Test (10 Days) ~nadari~~ Petroleum Corporation P&A (2 Days) 4500 ~ ~ - 0 5 10 15 20 25 30 35 Days Last Update 8/13/2007 N/U diverter Drill 12-1/4" hole / Set 9-5/8" casing Drill 8-1/2" hole •i si ~~ Petrob~un Corporation Gubik #3 Tuluvak/NanushukTest Well Schematic 12-1/4" hole Top of elevated pressure interval expected at 1,500'± 8-3/4" hole 16" conductor at 100' 9-5/8", 40#, L-80, BTC casing at 1,000' Tuluvak 1,000' - 2,750' Nanushuk 2,850' - 3,400' 7", 26#, L-80, BTC-M casing at 4,400' Gubik#3 Geo-mechanical Plot t fl. m D m m L lip 0 1, 000 2,000 3,000 4,000 5,000 6,000 7,000 16" ubi i 9-5/ " Over-pres ure ~.. i terv I ±3 0' 00' I T luva k blow top pf T luva i - + - Fm. - ~ - ' - -, --- - ~a Gra . - - - - - ' ud 1 Nel~g if __ __ ( Pore :Press. + N nus uk _._ _._ _ '` _~im~ ~~~~ _._. _ ._. _ _ _ _ _ j~' ._ _. , r a t ds o d - -- J --1 - ~- I ~- -- -- -- - ~- -- - ~., -- ~- ~- I Tor k Mud Wt. From Offset Wells -APC Pore Pressure -APC Fracture Gradient Frac. Gradient 9 11 13 15 17 19 21 23 Mud Wt. in ppg Last Update 10/9/07 ada ~~ ~ ~oleum Corporat 2007 - 08 Foothills Exploration MAXIMUM ANTICIPATED SURFACE PRESSURES (MASP) Gubik #3 Note: Here MASP for each hole section is defined as the pore pressure at the next casing point less a gas column to surface. 12-1/4" Hole Section ~` This hole section will be drilled with a diverter only, no BOPS. While MASP will equal the formation pore pressure at the surface casing shoe depth of 1,000' less a gas gradient to the surface, it cannot be shut in, only diverted. Calculation: ~- MASP12-li4» _ (1,000 ft) ((10.0 ppg x .052)-0.11 psi/ft) = 410 psi 8-3/4" Hole Section `" The maximum anticipated surface pressure (MASP) for the 8-3/4" hole section in this vertical hole will be the greater of: a) the formation pore pressure in the over-pressured interval at 1,500'-2,200' less a full gas column to the surface, or b) the formation pore pressure at 4,400' TD less a full gas column to the surface Offsetting well information and subsurface pressure analysis indicate that the pore pressure in the over-pressured interval at 1,500'-2,200' will be 13.8 ppg EMW. Likewise, the pore pressure at 4,400' will be 12.2 ppg EMW. The gas column in the well is assigned a density gradient of 0.11 psi/ft. Calculations: a) MASPI,soo° _ (1,500 ft) ((13.8 ppg x .052)-0.11 psi/ft) = 911 psi MASPa,aoo° _ (2,200 ft) ((13.8 ppg x .052)-0.11 psi/ft) = 1,337 psi b) MASP4,4oo° _ (4,400 ft) ((12.2 ppg x .052)-0.11 psi/ft) = 2,307 psi ~` Thus MASP for the 8-3/4" hole section will be 2,307 psi. ~# ~nada~ Petroleum Corporation Drilling Area Risks and Waste Disposal Gubik #3 Drilling Area Risks: Wellbore Interference: The closest wellbore to this one is the plugged and abandoned Gubik Test #1 located 5,170' away so there is no anticipated interference expected between wellbores. Other nearby wells are the Gubik Unit #1 (5,875' away) and the Gubik Test #2 (8,300' away). See the enclosed vicinity map for the relative distances and bearings of these wells. Elevated Pressure /Shallow Gas: The operators of the three offset wells named above encountered elevated pressures and gas in the Tuluvak Formation between 1,400' and r° 1,800' (see the enclosed geo-mechanical plot for the expected pore pressure profile). For this reason, the surface casing in the Gubik #3 will be set at 1,000', near the top of the Tuluvak so that the overpressure interval is encountered after BOPS have been installed. Hydrates: There is a remote possibility of encountering with gas hydrates, though none of the offset wells did. If hydrates occur in this well, they will be treated with control ~ drilling, increase of mud weight, cooling of the mud and addition of lecithin. H2S: The Gubik #3 well will be drilled as one of a relatively dense clump of wells all drilled in the same area to the same horizons. None of the nearby offsetting Gubik wells encountered H2S, nor have any of the regional offsetting wells (East Colville, East Umiat, Big Bend, etc.), so there is no anticipated risk of H2S in this well. However, as a precaution, the rig and mud logging units will have functioning H2S detectors. ,f Disposal of Muds and Cuttings: ~3 Ste- ~ILIJ During drilling of the Gubik #~Y, all generated rock cuttings will be dried to the extent possible within the drilling rig, then carefully spread in an ice-bermed cuttings holding area to freeze. After they freeze, they will be broken up and loaded into rolligon-bourn hoppers for transportation to the 2P staging pad where they will be transshipped to trucks for hauling to BP's grind and inject facility at Prudhoe Bay. Similarly, waste drilling fluid will be transported via rolligon to the 2P staging pad for ultimate disposed in BP's grind and inject facility at Prudhoe Bay. ~ - t.. %- .. ~ ~ ~ ~ ~ ~ fr ~ ~.+.yw .- a ~ ~. ~...+-- a F,- _ J ~ fi - 1 t ,4 2~~ I, , f ~ 5 `~ ~ t 'I . ~.~ l~., t,' ~ ~ ~ -, ~ r~~ ..:~;~ ~~ f:f G~u b i.k:: ,3 ~ - "' ~.~.~. .~ ; ~ ; ~ Ir. , ~~ ~ 111 y 4 ~ 1 '~~ C""~~~,~ ;r ',. ~~ ~ .-L::~,_~ '' ~ C~ ti7` .. ` ~ {~'' . _ ~ 4 y _ t. .. Jf ' ~ ~ I ~?~ f - ~ --~ I f ~'` '`~~ 4..E _ - ~ -- --'a=~.;J~ ' ~_n~ , ~. _ !1 _ ° °~I//r ~~.y.. i' ~ -- ~~'~t. f', ~ ~ub~iyk Test. ~# 1 •_~:~.- ~- ~~~'; r :~,4ti ~-;. k .. ~ ;~ ~ y+ ~~~~1 ~, s -~ ~~ } ,3~. 2 ,~ ~~ ~ , +, ,, ~ ~ -- ~' j! t ~ ~~: ~ 233'` ~ J r ,~ - ~ ~ f r` 1 ~~ : ,~ ?~ ~,~~ .. ~ ,, ~,~.~~~_ ~ ;~Gub~k~('Jri-t~# 1 i ~; !~ ~ ~4 ''.. ..5 ti. // ~ 1 w1. ~ ~ ~~ ~•~•. ti'•~_ ~ ~ .",rat l i\i.._' . , ~~ . f f , ~,- - -~ ~~ ,r 1 1 r-'r~ `ti ,, . - t ~ ~_ -'fir- _~~ _ ... ... ~'~..~ _-_ 'M ~ /' ~ -y .;ti x ' l %.. ~~ .~ ~..~~ "~ : GubikTest #2 ~~ f-~;~~ ..~~~ ~~_, `~ -~~ ~ ~~ ~ _ ~. ~~~` r • _ ~~ .--` f ~4 ` ~~ 1ay'4'~ err} ` % ~. • -~ ( '.~ ,. f :'1 J E7 tJ ~ J~ ^~ f'1 '~~.,. ~ 1~ 1 -] j.J 1 ~ ~- ,.~' 1 rte' r t ; - --~, ~~ r N W E s Gubik M L ti __ on ap oca Project No. Checked By: 0 850 1,700 2,550 3,400 Date: ~2io~2oo7 File: Gublk ~etal~.mxd Feet Pst-~s++ C+~opvnrtbn Gubik #3 Casing Design Verification Planned Casing program 9-5/8" 7" Surface Casing Production Casing Depth (MD) 1,000' 4,400' Depth (TVD) 1,000' 4,400' Hole size 12-1/4" ~ 8-3/4" Weight (ppf) 40.00 26.00 Grade L-80 L-80 Connection BTC BTC-M Nominal ID (in) 8.835 6.276 API Casing Design Factors Design factors are essentially "safety factors" that allow the design of safe, reliable casing strings. Each operator may have his own set of design factors based on his experience and the condition of the pipe. Here we use API recommended design factors. API Design Factors: Tensile Joint Strength: Nt = 1.8 Collapse (from external pressure): Nc= 1.125 Burst (from internal pressure): Ni = 1.1 The pore pressures and fracture gradients used here are those derived from studies of offsetting well data in the Gubik, East Colville, East Umiat and Big Bend areas near Umiat, Alaska. Design Factor Calculations Burst Requirements Use maximum anticipated surface pressures (MASP) for each casing string. For each casing string MASP is the formation pressure at the next casing point less a gas column to surface. 9-S/8'; 40 #, L-80, BTCSurface Casing: MASP at 8-3/4" hole section TD of 4,400': MASP = (4,400') ((12.2 ppg x 0.052)-0.11 psi/ft) = 2,307 psi DFb =burst strength /burst stress = 5,750 psi / 2,307 psi = 2.5 T ; 26 #, L-80, BTC-M Production Casing: Maximum burst stress is formation hydrostaticpressure at TD less a gas column to surface: Burst stress = (4,400') ((12.2 ppg x 0.052)-0.1 lpsi/ft) = 2,307 psi /' DFb =burst strength /burst stress = 7,240 psi / 2,307 psi = 3.1 Collapse Requirements Use an external pressure consisting of the formation pore pressure at the casing shoe and an internal pressure of a gas column to surface. 9-5/8' ; 40 #, L-80, BTC Surface Casing: External pore pressure = 10.0 x 0.052 x 1,000' Internal pressure w/gas only = 0.11 x 1,000' Collapse stress = 520 psi - 110 psi = 410 psi DFc =collapse rating /collapse stress = 3,090 / 410 7'; 26 #, L-80, BTC-M Production Casing: External pore pressure = 12.2 x 0.052 x 4,400' = 520 psi = 110 psi = 7.5 V' = 2,791 psi Internal pressure w/gas only = 0.11 x 4,400' Collapse stress = 2,791 psi - 484 psi = 2,307 psi DFc =collapse rating /collapse stress = 5,410 psi / 2,307 psi = 484 psi = 2.3 Tension Check Use buoyed weight of casing in mud having the expected density when running the pipe. 9-S/8' ; 40 #. L-80. BTC Surface Casing: Weight in air = 1,000' x 401b/ft Weight of displaced fluid = 0.595 gal/ft x 1,000' x 10.0 ppg Pipe weight in fluid = 40,000 # - 5,950 # DFt =body tensile strength /buoyed wt = 916,000 # / 34,050 # 7':26 #. L-80. BTC-M Production Casing: Weight in air = 4,400' x 26 lb/ft Weight of displaced fluid = 0.392 gal/ft x 4,400' x 12.2 ppg Pipe weight in fluid = 114,400 # - 21,043 # = 40,000 # = 5,950 # = 34,050 # = 26.9 = 114,400 # = 21,043 # = 93,357 # DFt =joint tensile strength /buoyed wt = 604,000 # / 93,357 # = 6.5 • Anadarko Gubik #3 M~ SWACO DRILLING FLUIDS PROGRAM Gubik #3 Mud Program ,~ ,_ __ Name Signature Date Originator: Jim Dwyer Reviewed by: Hal Martens Customer A royal: Version: 1.1 October 29, 2007 Location North Slope Alaska Confidential 1 Date: October 29, 2007 Anadarko Gubik #3 Well Surntnary Gubik #3 is to be drilled vertically to a planned depth of 4,400' MD. Production zone target is to be the Torok formation. µ As with any exploration well there is pore pressure uncertainty. Logging will be done therefore consideration will need to be made concerning the use of mud products. Expected formation pressure of the Tuluvak at the upper portion of the ~` production interval may require that the fluid weight be increased to 13.8 ppg. Formation pressure of the Nanushuk and Torok is lower (12.2 - 12.6 ppg) than the Tuluvak. This will result in a ~1.5 ppg of extra mud weight being used while drilling the lower section of this interval. ECD, potential lost returns, and differential sticking will need to be carefully . watched. All product needed for this well will be delivered to Umiat by air or by rolligon prior to being delivered to the drilling location -52 miles away. In order to minimize the need of having large quantities of product on hand and also reduce the amount of cuttings that need to be hauled away, it is suggested that aKCI/Klagard system be used to drill at least the production interval. Typical dilution rates have been much lower for the KCI/Klagard system than for any other water based system (Gel/water, KCI/polymer, PHPA) that has been previously used for exploration drilling in remote locations. Fluid T e T ical Dilution'Rate bbls of#tuid er bbl of hale drilled Gel/Pol mer 5.8 - 8.1 bbls/bbl KCI/Pol mer 6.1 - 6.5 bbls/bbl PHPA 5.5 - 6.5 bbls/bbl KCI/Kla and 3.5 - 3.6 bbls/bbl The resulting improvement in the dilution rate of the KCI/Klagard system over other systems has been shown to dramatically reduce haul-off costs of both cuttings and excess fluids. Have contingency products on hand in the event that a weight increase is needed and to also combat any lost circulation problems that may occur. Fluid and Drilling Concerns - HSE. - Differential sticking due to filter cake build up through the exposed sand intervals. - Mud weight for hole/shale stability. - Waste management. - Wellbore stability throughout the drilling phase of the operations. - Hole cleaning. - Good cement jobs. - Log and core quality. - Minimization and control of waste management cost for the "drill cuttings" and associated fluids. Monitoring and efficient utilization of the trucks and gravel washer as required for this operation. Daily and interval summaries will be tallied and summarized for the end of well report. Location North Slope Alaska Confidential 2 Date: October 29, 2007 WELL CENTER 1. DNERIER ANNULAR NORMALLY OPEN. 2. FABRI-VALVE NORMALLY CLOSED. oew ~~/~--.--.- - ro Ac~uuuuroR aag . -04- -I FTCMI ~ccuwxAroa ~rb i 8 FABRI-YALYE i6" KMFE YAIVE AN9 700 FIANCES WELL CENTER NABORS RIG 105E DIVERTER CONFIGURATION NABORS ALASKA RIG 105E DIVERTER LINE LAYOUT -.1__ Nobon NasNa Onlliriy Iric. ~I'~gFp~~ 25]5 C Sbeat Seib 200 •IMtl~/OlO1~Of Mclwrasa _AbaMa 99507-2679 "' N4BOR5 ALASKA RIC 105E >~ DIVERTER LWE LAYOUT i6" ONLR7ER SYSTEM HYDRIL 13-5/8" 5k PSI GK ANNULAR BOP 5'-4~"~ i~" LATCHED HEAD STUDDED CONNECTION - 54-1/8" LENGTH ~ ~.~ /.~ ~~ i I 3'-1~" 10, SNAPPER 13-5/8" 5k PSI ~~. SL POSLOCK DOUBLE GATE _ _ _ _ STUDDED CONNECTION DRILLING SPOOL 1 ~~ 13-5/8" 5k PLAN ~» SHAFFER 13-5/8" 5k PSI SL POSLOCK SINGLE GATE STUDDED CONNECTION SHAFFER 5k 13.5/8" MODEL SL POSLOCK ELEVATION 14" PISTON BOP RAM BONNET ACCESS CLEARANCE NABORS ALASKA RIG 105E 13.5/8" 5K STUDDED BOP ASSEMBLY • • _ Anadarko Gubik #3 Project Summary Estimated Casing Hole_ Measured Waste Volume Mud Size. Size Depth Mud .footage Generated Density Range in in Profile ft T e Drilled Cuttin S /Mud 16" 108' 95/$" 12 1 /4" .1458 1,000' KCI/KLAGARD 1,000' ,~' 583 Bbls (cuttings) 10.0 -10.5 bbls/ft ~;Y 400 Bbls (Mud) ~.~: . ., a ;~ ~ ~` 2~o`u \\ , w ~ ~`-17L ' f, 7.0" - 4,400' KCI/K~,aGARD 3,400 1,193 Bbls (cuttings) 5 -14 12 bls/ft ~ 835 Bbls (mud) . >M~:-~ c-- '~:~, : ; F: Formation Tops Formation ,T ~ , ~ t~'°~~~tim :~<. ~, Base of Permafrost -800 Tuluvak --1,000 Nanushuk -2,850 Torok -4,800 IFE Goals and Benchmarking Minimize Cuttin sand fluid hauloff volumes No Stuck Pi e No Mud Related HSE Issues All Casin /Liner to Bottom ,~ ~ Location North Slope Alaska Confidential 3 Date: October 29, 2007 Anadarko Gubik #3 MI-SWACO was involved in the Noatak 1 well last year which dealt with several of the same waste management issues that will effect the Anadarko operations on Gubik 3 and Chandler 1. The following lessons learned on that project should be applied to the planning for the Anadarko wells: • Insulated tanks should be used and heating will still be necessary. • Tank farm personnel should be available for loading and unloading of tanks and maintenance of all manifolds, valves, and fittings. • Fluid should be mobilized to disposal site as soon as possible as tanks are filled. The Rollagan tanks can hold 70 to 80 barrels but high mud weight must also be considered for volume transported (i.e, 13.6 ppg x 42 gal x 80 = 45,696 Ibs). • 2-centrifugal pumps to help load or offload fluid as needed also the ability to roll the fluid as needed to prevent settling or freeze up. • 3" manifold rigged up so that all tanks suction and riser lines are hooked into a central location • Job shack and gen set needed for tank farm personnel on location FLUID WASTE MANAGEMENT A reserve pit will be built for cuttings storage while drilling. The cuttings will be frozen and then loaded into large cuttings boxes that will be hauled via Rolligon to Kuparuk for eventual transport to G&I facility. Liquid waste will be stored in the tank farm which should consist of ten 400 Bbl upright tanks (worst case scenario). If transporation issues due to adverse weather are a big issue; 4 tanks can be stored at the rig site for transport later. At minimum, tank storage capacity should be enough for displacing well and circulating pit volume when final casing is set. A glycol boiler will be rigged up for every 3 tanks to keep the liquid from freezing. The tanks, when they are delivered to location, should be fitted with any necessary ball valves or cam lock fittings. The parts need to be ordered to mate up the tanks and the rig or Vac Truck. Even with glycol heat on the tanks, the valves can freeze very easily and the butterfly valves built on the tanks sometimes may be difficult to open. The overall tank farm set needs a designated crew to run or rig up the farm so any freezing or valve issues can possibly be avoided. They would need to install and inspect all the proper equipment and fittings (boiler, trunk heaters, valves, fittings and hoses). During the drilling operations, CATCO Rolligon tanks can be utilized to haul liquid waste to Kuparuk. Once the tanks arrived in Kuparuk, they were loaded onto Vac trucks for transport to the dedicated disposal wells. A total of 1235 bbls of liquid mud under worst case scenario will be hauled off for injection. v Annular injection on the Gubik 3 well is not an option presently. ,~• Location North Slope Alaska Confidential 4 Date: October 29, 2007 • '` ° Anadarko Gubik #3 Surface Interval Drilling Fluid System KCI/Klagard Spud Mud Key Products M-I Wate, Caustic, Drispac Plus SL, Duovis, Bicarb, KCI, Resinex, Klagard Solids Control Shakers, 2 -Centrifuges Potential Problems Running gravel, unconsolidated sand, reactive clays, Lost Circulation INTERVAL MUD PROPERTIES Depth MD (ft) .Mud Wt. (ppg) Funnel Viscosity PV Yield Point (Ib/100ftz) API Fluid .Loss (ml/30min) pH Initial 9.5 -10.6 60 - 100 20 - 30 35 - 50 <8 9.0 - 9.5 Below Permafrost g 5 -10.6 60 - 100 20 - 35 35 - 50 <8 9.0 - 9.5 1000' TD (to cement the casing) 10.6 60 - 80 20 - 30 25 - 45 (or as per Cemcade) <6 9.0 - 9.5 Surface Interval Overview Surface to 1,000' MD Lithology through this zone is a composite of small gravel in the upper intervals with a grading downward to sand, clay, and some siltstone in the lower zones of this interval. Based upon work done on previous wells in this area a KCl/KLAGARD spud mud is recommended for the surface interval. Due to unique characteristics of this mud system, initial viscosities should be adjusted and maintained by Yield Point (35- 50 Ib/100ft2) throughout the permafrost which extends to a depth of ± 800' TVD. Gas hydrates may be encountered and precautions should be taken for such an occurrence (see "Surface Interval Hydrate Issue" enclosure). 9.625" surface casing will be set as per cementing procedures in drilling program. KCI/KLAGARD Formula Caustic 0.25 Ib/bbl Duovis 1.25 - 1.75 Ib/bbl Drispac 1 - 2+ Ib/bbl 6% KCI 22.0 Ib/bbl M-I Wate for density Klagard 8.0 Ib/bbl Location North Slope Alaska Confidential 5 Date: October 29, 2007 Anadarko Gubik #3 Surface Interval Drilling Concerns: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Based upon disposal and haul off volumes with no annular injection possible, a KCI/Klagard spud mud is recommended for the surface interval. Initial theological properties of 45 - 60 Ib/100ft2 Yield Point and -90 - 120 sec/qt Funnel Viscosities should be maintained through the permafrost. 9.625" surface casing will be set and the cement will be pumped in a single stage to surface. ,r' - Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered be prepared to increase the viscosity. - Excessive quantities of gravel and sand may indicate wellbore instability. Past exploration wells have increased properties up to a YP of --85 Ibs/100ft2 to combat this problem. - When drilling excessive amounts of sand, large Gel sweeps are recommended to help seal the sands and to help minimize seepage losses in the sands. Do not use Caustic when building these Gel sweeps. The objective is to be able to get as much Gel as possible in fresh water to be used as the sweep. - Sticky clays in the permafrost at and also in the zone below the permafrost can slow ROP from bit and BHA balling. If needed add Drilzone (at 1 %) and Nut Plug m (as allowed by MWD tools) to minimize clay to metal sticking. Drilzzone (at 1 %) may also be needed to help with shaker screen blinding. - Use as cold of water as possible for the initial make-up and for additions made to the mud system during the surface drilling operations. - Maintain low flow rates for the initial 200' of drilling to reduce the chance of washing out the conductor shoe. e - Lo circulation co e a problem betwee 'and interval ~ ~ ~n~.. ~c-~~.c.E ~o~ - Swabbing in the clays may also be a problem. Maintain or slightly increase the mud weight (.1 ppg) and continue additions of Drilzone at 15 to 30 gallons per hour and wiper runs through the surface interval may be necessary to clear the wellbore of the problematic clays. Drilzone maintained at 1.0% is also recommended to help with clay related issues. - To help insure good cement to surface after running the casing, condition the mud to a YP of at least 25 - 30 prior to cementing the casing or as recommended by Cemcade. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco CF, Tannathin, SAPP, and water on hand to ensure the desired theologies can be achieved. Use water sparingly to reduce the over all haul-off costs for this well. - Hydrates may be encountered (particularly at depths below the permafrost). Observe good drilling practices to `' determine severity of any influx and weight up as needed to maintain proper well control. See "Surface Hydrate Issues" enclosure. Location North Slope Alaska Confidential 6 Date: October 29, 2007 Anadarko Gubik #3 Surface Interval Operations Recommendations: - KCI /Klagard spud mud will be mixed on the rig. Add Soda Ash at 0.5 ppb and 2.5 ppb M-I Gel to the make-up water and allow the gel to hydrate as long as possible prior to mixing the other products. Use as cold of water as possible for the initial make-up and for additions made to the mud system during the surface drilling operations. - Drill ahead maintaining volume as needed. - Fluid weight is planned to be maintained at 10.0 ppg through out this interval. - If seepage losses in sands occur, use MIX II to aid in sealing these sands. - Increase the Klagard concentration, if needed for inhibition. Especially prior to short trips or back reaming. - Run all solids control equipment. Add drill water below the shaker to avoid washing unwanted solids back into the active system. Waste minimization is "Extremely Important" on this well. All cuttings and liquids have to be stored on location and hauled as needed by Rollagan for disposal. There is a possibility however that we may be able to inject liquids down the annulus after the 7" casing has been set and tested. (See Waste Management Plan) - If deemed necessary to help control hydrates add Lecithin at 2 ppb prior to drilling in the hydrate zone at 600' TVD and maintain this concentration to TD. Additions of Desco CF may be needed to control rheology after the Lecithin additions. See "Surface Hydrates Issues" enclosure for further detail. - Lower API fluid loss with Drispac Plus Superlo as needed to maintain hole stability. - To control rheology additions of Desco CF may be needed. - Lost circulation has been encountered on previous wells in this area. LCM pills successfully treated these losses. The recommended LCM pill formula for this interval is as follows: 1. 30 bbls of the existing fluid 2. 10 ppb Nut Plug Medium 3. 10 ppb MIX II Medium /Fine 4. 10 ppb Calcium Carbonate - If hole conditions allow, let the YP drop to 25 - 30 (no lower than 25) prior to cementing of the casing. Allow surface mud volumes to fall during the later stage of this interval to minimize waste fluid disposal costs. - Upon drill-out of the surface casing shoe, treat any cement returns with SAPP, Bicarb, and PH-6 as needed. Location North Slope Alaska Confidential ~ Date: October 29, 2007 Anadarko Gubik #3 5urtace Interval Virtual Hydraulics Mi SWACQ,~.~:,~- ©199`x2006 AM L.L.C. 'Mark of M-I L.L C VIRTUAL NYDRAULICS'SnapShot 4" DP 10.6 pP8@ 750 9>m ~ ~~'Y DAY (ft) NDITVD CsgODIID (Ib'c,~l) )a) c~~. 1 c MD: 1000 TVD:1000 Bit S ize: 1225 Dale: 10'29 Va (ltlmird ft Operaoor: Anadarko ft WeIlName: Gubik3 in Location: NarIhSlGpeAlaska Caurtlry: USA HdeClean PresSYreDistrit~m Ir~c (%) v~ c F P Bk=39.3 Am=3.1 DS=57.6 ._. m~„- ~~ DrillirgRud Waler$ased Mud MudW~cJk 10.6 IIY~I Test Temp 120 °F System Data RavRate 750 ~Ilmin PenetratianRale 150 Pofr RatarySpeed 100 rpm Wei~ltanBR 12 10001b BitNG¢zles 1.2633 in= Pressuel~wes ModfiedPawer Law Drill Strifg 508 psi MWD 2(10 psi Mohr 400 psi Bit 347 psi BitONOff 100 psi Amlus 28 psi SurfaceE4ip 46 psi U Tube Etl'ect 12 psi TaW System 1640 psi ESD ECD +Cut CsgShoe 10.68 11.02 11.25 TD __10.6.7 11.21 11.44 I VRDH-Version 3.1 F35.F70 (0197) Fila -Gubik 3.M ~B Jims F-70s Location North Slope Alaska Confidential 8 Date: October 29, 2007 PV (cP) YP, LSYP Qd100ft') s i ~ c • Anadarko Gubik #3 Surface Interval Hole Cleaning ©199:x2006 tv1-I LLC. IIVI~ `wAG`Q 4^ Dp MD: 10W fl -- Operator: Aredarko , ~,~ .7 'M ark o~M~I LL. C. ND: 1000 ft Well Name: G~ik3 * ' 10~6~@'~°~""' Bit Size: 1225 in I Loca6m: NarlhSlopeAlaska VRDH VIRTUAL HYDRAULICS Date: 11Y29/2007 Couitr : USA Hole Cleaning Anadarko Gubik 3 _ __ _ i ROP - 40 ttih r T-- I - ROP100ft/hr ~ - 160 tf/hr ROP^ - Poor HoleCleanin~__ 0.75 {-- K ,_ _ - _ _ _ - - _ , - - - ' 1 --- I _ Fair HoleCleanin~ ~ ~ __ 0.50 r-- c~ I d I_ - ~ i - ! - _. Good Hole Cleaning ~'. O - - 025- -- ~ --- j -... leanin , I 500 600 700 800 900 Flow Rate (aal/minl In all cases where hole cleaning is rated as either "Fair" , "Fair to Poor", or "Poor" extra precautions must be made to keep the well bore clean. 1. Extra time spent should be spent on circulation prior to connections and trips. 2. Adjust rheology if possible to help with hole cleaning. 3. Weighted high viscosity sweeps may help but should not be used as a primary cleaning strategy. 4. Maximized rpm while drilling and circulating will generally aid with hole cleaning. 5. Monitor PWD data (if available) closely. 6. Observe and chart pickup and slack off weights during each connection. Location North Slope Alaska Confidential 9 Date: October 29, 2007 Anadarko Gubik #3 Surface Interval Expected Pump Pressures M~ SWACQ _ ©199x2006 tuH L.L.C. ~Ma~korm-i~.~.c. VIRTUAL HYDRAULICS~IRDII* 000 Max Pump Press 4" DP IvD: 1000 - ft ND:t000 ft '°~6`~~'~°~"' Bk9ize:1225 `" Dale: 10/29/2007 Pump Pressure Anadarko Gubik 3 Operates: Aredarko i WeIlName: Gitik3 ~ `~~,: NesthSlapeAlaska Cwgrv' USA . _ - ROP40Pohr - ROP100ftAir 3000 - ROP 160 ftRlr Max Pum Press N Q - -, d L ~ __- - i ~ 2000 L a _ - __ - - ~ - --. Q. -- - ~ ~ __ II ~ _T _ _ _ _ a _ _ __ - 1000 - - _ r - -- _ i 500 600 700 FlowRate laal/min) 800 900 Location North Slope Alaska Confidential 10 Date: October 29, 2007 • i Anadarko Gubik #3 Production Interval Drilling Fluid System KCI/KLAGARD Key Products M-I Wate, Caustic, Drispac Plus SL, Duovis, Bicarb, DRILZONE, KCI, Resinex, KLAGARD Solids Control Shakers, Mud Cleaner, Centrifuge- Aggressively size screens Potential Problems = Hole cleaning Loss circulation/Differential sticking Hole stabilit INTERVAL MUD PROPERTIES Depth MD (ft) Mud Wt. (ppg) PV (Ib/1OOft2) Yield Point (Ib/100ft2) Gels (10 sec/10 min)' API Fluid Loss (ml/30min) Chlorides (mg/l} pH 1,000 - 1,100 10 - 13.8 , 15 - 30 18 - 25 8 -12/15 - 19 <6 28,000 - 32,000 9 - 9.5 1,100 - 4,400 13.8 ~ 15 - 30 18 - 25 8 -12/15 - 19 <6 28,000 - 32,000 9 - 9.5 Production Interval Objective ~~;~~; ~~ J~~,~z~at~ The production interval will be drilled/cored to a depth of -4,400' MD using an~-5" bit. The interval will begin with a 10 ppg fluid weight and will be weighted up to 13.8 ppg by 1,100' to help control the "Tuluvak" section of the interval. KCI/KLAGARD Formula Caustic 0.25 Ib/bbl Duovis 0.75 - 1.25 Ib/bbl Drispac 0.5 - 1.75 Ib/bbl 6% KCI 22.0 Ib/bbl M-I Wate for weight DrilZone 1.5 - 2% v/v Klagard 8.0 Ib/bbl Location North Slope Alaska Confidential 11 Date: October 29, 2007 Anadarko Gubik #t~3 Production Interval Considerations - Lithology for this interval is expected to be typical of this region consisting of sand, shale, and siltstones. - Ensure that the fluid properties are maintained to provide the best possible hole cleaning. Maintain mud weights as per program guidelines and or hole conditions and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Pore pressure and shale stability uncertainties do exist and care should be taken while drilling this interval. Monitor for any fluid losses and flow back closely. - Mud weight-up to 13.8 ppg will be needed prior to drilling through the Tuluvak. If practical, any additional fluid ~'' weight adjustments should be performed in 0.1 - 0.2 ppg increments using MI WATE or a weighted "spike" fluid. Keep current with directional drillers and mud loggers on MD depths and geological information. - If additional mud weight increases are required, control the ROP and flow rates as needed to avoid inducing a breakdown of any formations while drilling in the lower portion of this interval. Reduce pump rates immediately if packing off occurs. Pump high viscosity sweeps and ream carefully to clean the hole before proceeding with further drilling - Additions of Resinex and Soltex may be used to help lower the HPHT FL (<10cc @ 200 deg F) and ensure shale stability in the lower portion of the well. Additions of these products may not be desirable if coring or MDT work will performed. - Adjust rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Use good drilling and tripping practices. Break circulation slowly -Reduce pump speed 15 to 20% while reaming down. - Although not expected lost circulation may be a problem for this interval due to the possibility of depleted areas. Avoid drilling practices that could contribute to the breakdown and subsequent losses. Tripping and casing running speeds should be monitored closely. Rheology and mud weight should also be held within tight specification. - Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a high viscosity /weighted sweep and observe bottoms up again. - Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. Location North Slope Alaska Confidential 12 Date: October 29, 2007 ~ ~ Anadarko _Gubik #3 Production Interval Operations x,.75 ~~ ~~ ,Iz-~o~ ^ This interval will be drilled and cored using an.8:~~" bit to an expected interval TD of 4,400' MD. Care should be taken to monitor all drilling criteria to ensure that "best" drilling practices are being observed. • Interval pore pressures may vary. Planned mud weight requirements of 13.6 ppg at 1,100' MD will be observed. Uncertainty does exist; shale stability and pore pressures could require a higher or lower mud weight. Any fluid weight adjustments should be performed in 0.1 - 0.2 ppg increments using MI WATE or a weighted "spike" fluid. Keep current with directional drillers and MWD personnel on MD vs. ND depths for the following weight up points ^ Chlorides will be maintained at 28,000 - 32,000 throughout the interval. ^ KlaGard concentration will be maintained at ` 8 Ib/bbl throughout the interval. ^ The potential for lost circulation and/or differential sticking is present if the fluid weight is increased in the later portion of this interval. To help avoid issues such as these use the following as a guideline: 1. Manage ECD's • Maintain low gravity drilled solids to below 6% with solids control equipment and dilution. • Use Virtual Hydraulics ECD predictions vs. PWD actual values to appraise hole cleaning and hole conditions. If possible do not allow actual ECD's to exceed 0.5 ppg over predicted "clean hole" ECD. • Run TripPro Module of Virtual Hydraulics for surge/swab predictions with actual well bore and fluids data prior to RIH/POOH. Distribute and adhere to trip schedule. 2. Prior to TOOH • Circulate until a clean hole ECD is attained (< 0.5 ppg above predicted ECD). • If deemed necessary, spot a pill containing -5 ppb SafeCarb 250, 5 ppb SafeCarb 500 and 15 ppb G-Seal to cover any under pressured zones that may be found. • Keep the pipe moving as much as possible. 3. During TIH • Optimize tripping speed using Trip Pro. Location North Slope Alaska Confidential 13 Date: October 29, 2007 ~ r Anadarko Gubik #3 Production Interval Virtual Hydraulics Modeling ~ 7~It bi~ t_~..., IIVI~ SWI~C~ ©1992006 M-I L.L.C. 'Mark of M ~I L.L'. C. VIRTUAL HYDRAULICS'SnapShot* Deptlt Geometry Dersity (ft) ND/1VD CsgODIID (Ib'gal) !fit fin 1 0 I:y~ ~Ic I"~' ~ _ _ 4" pp ~ ND: 4400 ft ~~ Operator: Anadarko 13.6ppg@SOOgm i TVD:4400 ft WeIlName: Gftik3 BitSizQ;.B:s' in Loca6an: NarlhSlopeAlasska Dak~ 1a3vzoo7 canary usA PV(cP) Va HdeClean PresareDistri6Lbim YP, LSYP QH10Dft'9 (Itlmiry Irffic (%) sa fzo o aoo aoo vc c F P sit=ts.a Am=t3.8 DS=69.8 I t i PJ E VP L am Pressfre Losses NbdfiedPoNer Law Drill String 1397 psi MWD 250 psi AActor 150 psi Bft 328 psi BitOrVOft 100 psi Am(i(s 277 psi SfrfaceEc}ip 34 psi U Tibe Effect 11 psi Tafal System 2546 psi ESD ECD +Cut CsgShoe 13.72 15.14 15.19 TD 13.74 14.95 15.00 VRDH-Version 3.1 F35 +F]0 (2001) File ~GuClk 3.M DB F70flo Location North Slope Alaska Confidential 14 Date: October 29, 2007 Anadarko Gubik #3 Production Interval Hole Cleaning we+ ~=,,?~I b,t :fir '~T~'`'~ MI SWACC,~- ©199x2006 NH LL.C. ~ 4" DP ND: 4400 ft operasor: Aredarko ..~%^w' •rna,korm-u.~a ND: 4400 ft i WeIlName: GuSk3 VIRTUAL HYDRAULICS~IIRDN' ~ '3.6~c~~~ I Bit Size;81S `" '' `°~°": NarmslapeAlaska Dale: 10/31/2007 CaNr USA Hole Cleaning Anadarko Gubik 3 i - - ~ - - - - - .- -_ I _ - - _ - l _ _ - - __.- 1.00 - ROP254Ihr -. - ' I I ~ I - ROP55iVhr r - R O P 85 ft/h r - - -rte .- .- I ---~ - ----. __._. ~ _ ~PoorH-o_leCleann;~___ -- _~ I j--~ i i 0.75 ~, -7 1C ! _ ~ d _ fair Hole Cleaning ~ I ~ 0.50 t- V ~ _ ' ~ I~ - Good Hole Cleaning 'I O ' I i 2 ~ _. _ -- - I 025 Very Good Hole Cleaning ~ ~ L I i _ _~- -}- o Y I- I ~ =~~ 1- ~ ~ ~ 60 480 500 520 540 51 - - - 400 420 440 4 60 580 600 Flow Rate (aal/mint 1. Extra time spent should be spent on circulation prior to connections and trips. 2. Adjust rheology if possible to help with hole cleaning. 3. Weighted high viscosity sweeps may help but should not be used as a primary cleaning strategy. 4. Maximized rpm while drilling and circulating will generally aid with hole cleaning. 5. Monitor PWD data (if available) closely. 6. Observe and chart pickup and slack off weights during each connection. 7. Extra time spent should be spent on circulation prior to connections and trips. 8. Adjust rheology if possible to help with hole cleaning. 9. Weighted high viscosity sweeps may help but should not be used as a primary cleaning strategy. 10. Maximized rpm while drilling and circulating will generally aid with hole cleaning. 11. Monitor PWD data (if available) closely. 12. Observe and chart pickup and slack off weights during each connection. Location North Slope Alaska Confidential 15 Date: October 29, 2007 • Anadarko Gubik #3 Production Interval Expected Pump Pressures ~, 75 !~C MI SWACQ_.~-. ©19962006 I~ LL.C. - --- 'M ark of M-IL ~~~ww//~• ///Iw w~///^AAf///~/~//* L 4" DP ', MD: 4400 ft 13.6 ppg Q 500 gxn N D: 4400 , ft BitSize: b:5`~ in Date: 1013112007 Pump Pressure Anadarko Gubik 3 L a Q. E is FlowRate (aal/min) ~~ '121=£1 Operator: Aredarko Well Name: Gfbik3 Locatim: North Slope Alaska Location North Slope Alaska Confidential 16 Date: October 29, 2007 • Anadarko Gubik #3 Surface Interval Hydrate Issues Use the following guidelines to help minimize the effect that any hydrates which may have to the drilling operation. • Add 2 ppb Lecithin to the mud prior to drilling into the zone below the permafrost. Desco CF may be used to adjust rheology after the Lecithin additions are made. • Weigh the mud at both the possum belly and at the suction pit using pressurized and regular mud balances to determine the amount of gas that has become entrained in the mud. • Maintain the fluid at below 60°F if possible. • Minimize circulation time to reduce hydrate thawing. • Watch both drill rates and flow rates and make adjustments as needed to help diminish any problems that the surface equipment may have in handling the fluid and cuttings while circulating out any hydrates. • Weight up prior to drilling out of the permafrost. Watch the rate of depletion of the hydrates and increase the weight as needed to control the gas breakout from the hydrates. Production Interval Barite Sag Concerns Barite Sag (a reduction in the MW out due to the dynamic and static settling of barite) is a potential drilling hazard while using fluid densities above -11.5 ppg+. This well is designed for an 13.8 ppg fluid and unexpected conditions may make weight up or lubricant additions necessary. Both of these changes may contribute to a more likely chance of barite sag issues. Barite sag is also aggravated by circulating at low rates for extended periods of time, As a consequence, if it becomes necessary to circulate the 13.8 ppg mud at reduced rates, it is recommended that the pit watcher weigh and record MW = out using a pressurized and un-pressurized balance every 15 minutes minimum. Location North Slope Alaska Confidential 17 Date: October 29, 2007 i Schlumberger CemCAD E*well cementing recommendation for 9.625" Surface Operator :Anadarko Well :Gubik # 3 Country : US Field Tuluvak/NanushukTest State :Alaska Prepared for : Mr. Ron Stadem Location :Gubik Area Proposal No. : v2 Service Point Prudhoe, AK Date Prepared : 10-10-2007 Business Phone 907-659-2434 FAX No. 907-659-2538 Prepared by :Tony Stafford Phone :907-273-1700 E-Mail Address ttafford@anchorage.oilfield.slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumbergercan assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring I well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumherger or others is not to be inferred. * Mark of Schlumberger • Client Anadarko Well Gubik 3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD : 1000.0 ft BHST : 52 degF Bit Size : 12 1/4 in ft ~- 0 o_ 0 v 0 o_ 0 oa a 0 0 Well 'Sandstone'. Gubik Lithology • a - - F~~ F Pore ,''~~ ~i -, Sc~l~~rger psl 1000 i:.~ ~F Formation Press. Page 2 Guhik3cfw;10d0-2007; Loadcase Surface;Version wes-cem452_07 ~~ Client Anadarko SI~r~~r Well Gubik3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Previous String MD OD Weight ID ft in Ib/ft in 100.0 13 3/8 68.0 12.415 Landing Collar MD :920.0 ft Casing/liner Shoe MD :1000.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) ~' (psi) ~ (psi) 1000.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter :12.250 in ~ Mean Annular Excess :166.7 Mean OH Equivalent Diameter: 15.677 in Total OH Volume :214.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 800.0 12.250 200.0 16.276 1000.0 12.250 50.0 13.371 The Well is considered VERTICAL Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) pb/gap 1000.0 18.50 8.30 Gubik Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 21 0.0 1000.0 1000.0 52 3.1 Page 3 Gubik3.cTw;10-10-2007; LoadCaseSurface;Versionwcs-cem452_07 • Client Anadarko Well Gubik3 String 9.625 District Prudhoe, AK Country US Loadcase Surface ft o- D C 0 o_ 0 O o_ 0 eo 0 0 0 rw degF Temperature n c a: c ,-, b ~ C c a ~ Cy O C C S C 6 C C Hari. Departure ~a i ScNi~n~rgcr ft Page 4 GuClk3 rf 10-10-2007 LosdCasa Surface ;Version wcs-cem452_07 Client Anadarko Well Gubik3 String 9.625 District Prudhoe, AK Country US Loadcase Surface ~r CemCADE W l6 ZT 4 N 3 V N ~ N N a c c Q N O At Time (min) Total Depth = 1000.0 ft Top of Cement = 0.0 ft 'Mark of Schlumberger 0 N W f0 ZT Q N J ~ N ~ N N D_ c c Q N O L~ Scbl~rg~r Client :Anadarko Well Gubik 3 String :9.625" Surface District :Prudhoe, AK Country : US Scld~mberger Gubik3.ciw; 10-10-2007 ; Loadcase Surface; Version wcs-cem452_07 _ _i uuu n Page 5 Time (min) Client Anadarko Well Gubik 3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Section 2: fluid sequence Job Objectives: Cement to Surface • Sc~lw~~rg~r Original fluid Mud 9.50 Ib/gal P~ :17.000 cP Tv :15.00 Ibf/100ft2 Displacement Volume 69.8 bbl Total Volume 315.7 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al Chemical Wash 100 50.0 0.0 8.35 viscosity:53.000 cP MUDPUSH XT 50.0 0.0 10.00 P~:19.000 cP Tv:15.00 Ibf/100ft2 ASL Lead Slurry 123.1 800.0 0.0 10.70 k:4.06E-2 Ibf.s^n/ft2 n:0.345 Tv:0.03 Ibf/100ft2 Surface Tail Slurry 22.8 200.0 800.0 15.80 P~:76.600 cP Tv:9.92 Ibf/100ft2 Mud 69.8 0.0 9.50 P~:17.000 cP Tv:15.00 Ibf/100ft2 Static Security Checks Frac 41 psi at 100.0 ft Pore 12 psi at 100.0 ft Collapse 2964 psi at 920.0 ft Burst 5750 psi at 0.0 ft Cs .Pum out 14 ton ft psi 0 0 1000 - H+~dros~atic - Frac - Pore 0 0 0 v 0 0 o ~;-,., ao 0 0 0 rv Fluid Sequence Static 1Nell Securit}f Page 6 Guhik3.cfw; 10-10-2007; Loadcase Surface; Version wcs-cem452_07 • Client Anadarko Well Gubik3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Section 3: pumping schedule Start Job: Circulate Two Hole Volumes SI~~rg~r Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments Chemical Wash 4.0 50.0 12.5 50.0 80 5-Start Pumping Wash 100 MUDPUSH XT 4.0 50.0 12.5 50.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug ASL lead Slurry 4.0 123.1 .~'' , 30.8 123.1 80 13-Start Mixing Lead Slurry Tail Slurry 4.0 22.8 ~' 5.7 22.8 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 7.0 55.0 7.9 55.0 80 19-Start Displacement Mud 7.0 14.8 2.1 69.8 80 Slow rate to Bum Plu Total 01:21 315.7 bbl hr:mn End Job: Bump Plug; Bleed-off Pressure; Check Floats Dynamic Security Checks Frac 38 psi at 100.0 ft Pore 0 psi at 100.0 ft Collapse 2964 psi at 920.0 ft Burst 5643 si at 0.0 ft Temperature Results BHCT 80 degF Simulated Max HCT 78 degF Simulated BHCT 78 degF Max HCT Depth 1000.0 ft CT at TOC 72 de F Max HCT Time 01:21:26 hr:mn:sc Static temperatures At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 21 degF Bottom Hole de F de F 52 de F Page 7 Gubik3.ciw;10-10-2007; LoadCaseSurface;Versionwcs-cem452_07 • ! Client Anadarko Well Gubik3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Sc~l~n~rg~r o ------ -Galt. WHP v - Calc. Pump Press. ~f11 Q O r ~ 1 I I 0 10 20 30 d0 50 Time (min) Fluids at 1000 ft ~o C r .~ Q d S6 O ~ O 60 70 80 90 0 10 20 30 40 60 60 70 80 90 Time (min) Page 8 Gubik3.c(w; 10-10-2007 ; Loadcase Surface; Version wcs-cem452_07 • Client Anadarko S~I ~ Well Gubik3 m r~~r String 9.625 District Prudhoe, AK Country US Loadcase Surface Section 4: fluid description Fluid No: 1 Rheo. Model :BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh VOLUME FRACTION Solids : 6.0 Oil : 0.0 Water :94.0 Mud DESIGN Density :9.501b/gal P~ :17.000 cP Tv :15.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :69.8 bbl MUDPUSH XT DESIGN Fluid No: 2 Density : 10.00 Ib/gal Rheo. Model :BINGHAM p„ :19.000 cP At temp. : 80 degF Tv :15.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl V-215i Surface Tail FB DESIGN Fluid No: 4 Density : 15.80 Ib/gal Rheo. Model :BINGHAM p~ :76.600 cP At temp. : 81 degF Tv :9.92 Ibf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : D907 Mix Fluid :5.087 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Sack Weight : 94 Ib Solid Fraction :41.6 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D065 0.300 %BWOC Dispersant D167 0.350 %BWOC Fluid loss S002 0.650 %BWOC Accelerator D046 0.200 %BWOC Antifoam Thickening Time Schedule 9.3-1 100 Bc Compressive Strength Schedule () (psi) Job volumes :22.8 bbl Quantity :109.85 sk Base Fluid :5.087 gal/sk at 03:45 hr:mn at (hr:mn) Page 9 Guhik3.ciw;10-10-2007; LoadCaseSurface;Versionwcs-cem452_07 Client Anadarko Well Gubik 3 String 9.625 District Prudhoe, AK Country US Loadcase Surface SI~r~~r Chemical Wash 100 DESIGN Fluid No: 5 Density : 8.35 Ib/gal Rheo. Model :NEWTONIAN At temp. : (degF) Viscosity :53.000 cP Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl ASL DESIGN Fluid No: 6 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 4.06E-2 Ibf.s^n/ft2 At temp. : (degF) n :0.345 Tv :0.031bf/1DOft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : B809 Dry Density : 171.90 Ib/ft3 Sack Weight : 188 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid :42.210 gal/sk Yield :6.74 ft3/sk Solid Fraction :16.2 Density :8.321b/gal Job volume :123.1 bbl Quantity :102.61 sk Base Fluid :42.210 gal/sk i Section 5: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :980.0 ft Casing Shoe :1000.0 ft NB of Cent. Used :10 NB of Floating Cent. :6 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 680.0 7 1/3 IMPERIAL 100.0 860.0 1000.0 3 1/1 IMPERIAL 100.0 1000.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ib IMPERIAL 9 5/8 13.500 11.250 No Imperial 12.250 590.00 4411.00 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 10 Gubik3,cfiv:70-70-2007; LoadCaseSurface;Versionwcs-cem452_07 Client Anadarko Well Gubik 3 String 9.625 District Prudhoe, AK Country US Loadcase Surface Section 6: operator summary TOTAL MATERIAL REQUIREMENTS Dead Volumes Mix Water Requirements Fresh water 8842 gal SGbl~~rg~r Page 11 Guhik3 cfw ; 10-10-2007 LoarlCase Surface ;Version wcs-cem452_07 Client Anadarko Well Gubik 3 String 9.625 District Prudhoe, AK Country US Loadcase Surface SI~r~~r Page 12 Gubik3.ciw;10-10-2007; Loadcase Surface; Versionwcs-cem452_07 Schlumberger CemCAD E*well cementing recommendation for 7" Production Operator :Anadarko Well Gubik # 3 Country : US Field Tuluvak/Nanushuk Test State :Alaska Prepared for : Mr. Ron Stadem Location Gubik Area Proposal No. : v2 Service Point Prudhoe, AK Date Prepared : 10-10-2007 Business Phone 907-659-2434 FAX No. 907-659-2538 Prepared by :Tony Stafford Phone :907-273-1700 E-Mail Address tstaffordC~anchorage.oilfieltl.slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client Anadarko Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production~a) Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft o- 0 a o- ~ra N 0 0 0 0 ~. :Casing Single Land 0.0 ft :4400.0 ft 81 degF 8 3/4 i n UVe I I ' ' ' ' Gubik •••••••• Tuluvak ;'•'.'• Nanushuk •••••••• Torok Lithology Sc~l~rg~r (x 1000) psi o ~ ~.a Frao r, - - Pare ~ ~. s 1 .~ i i 4 1 Formation Press. Page 2 Gubik3.ciw;10-10-2007; Loadcase Production ia); Version wcs-cem452_07 r~ Client Anadarko ~In~~rg~r Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production (a- Previous String MD OD Weight ID ft in Ib/ft in 1000.0 9 5/8 40.0 8.835 Landing Collar MD :4320.0 ft Casing/liner Shoe MD :4400.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 4400.0 7 40.0 26.0 6.276 L-80 5410 7240 BTCM Mean OH Diameter :8.750 in ~ Mean Annular Excess :50.0 Mean OH Equivalent Diameter: 9.505 in Total OH Volume :298.4 bbl (including excess) The Well is considered VERTICAL Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1000.0 18.50 8.30 Gubik Sandstone 3000.0 21.00 9.80 Tuluvak Sandstone 4000.0 21.50 9.50 Nanushuk Sandstone 4300.0 21.50 9.50 Torok Sandstone 4400.0 21.50 9.50 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 21 0.0 1000.0 1000.0 51 3.0 4400.0 4400.0 81 1.4 Page 3 Guhik3.cfw;10-10-2007; LoadCaseProductionlal;Versionwcs-cem452_07 Client Anadarko Well Gubik 3 String 7 District Prudhoe, AK Country US Loadcase Production (a) ft o, I c 0 0 o- ~t; ~v 0 0 0 0 ~. ^ c 0 C7 o ~ x C Cr U- Cr C U- Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface and Zonal Isolation. ]0 Original fluid Mud 12.50 Ib/gal P~ :17.000 cP Tv :15.00 Ibf/100ft2 Displacement Volume 165.3 bbl Total Volume 383.1 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al Chemical Wash 100 10.0 0.0 8.35 viscosity:53.000 cP MUDPUSH XT 40.0 0.0 13.00 P~:19.000 cP Tv:15.00 Ibf/100ft2 ASL Lead Slurry 28.2 1000.0 0.0 10.70 P~:24.000 cP Tv:32.00 Ibf/100ft2 Tail Slurry 139.6 3400.0 1000.0 15.80 P~:76.600 cP Tv:9.92 Ibf/100ft2 Mud 165.3 0.0 12.50 P~:17.000 cP Tv:15.00 Ibf/100ft2 degF Schl~rg~r ft Page 4 Gu6ik3.cfw; 10-10-2007 ; Loadcase Production lal; Version wcs-cem452_07 • Client Anadarko Well Gubik 3 String 7 District Prudhoe, AK Country US Loadcase Production ial Sc~l~rg~r Page 5 Gubik3.cfw ; 10-10-2007; Loadcase Production lal; Version wcs-cem452_07 Static Security Checks Frac 405 psi at 1000.0 ft Pore 125 psi at 1000.0 ft Collapse 4644 psi at 4320.0 ft Burst 7146 psi at 1000.0 ft Cs .Pum out 37 ton • Client Anadarko Well Gubik 3 String 7 District Prudhoe, AK Country US Loadcase Production (a~ CemCADE m m ~_ ar ~v N ~ N N CZ C Q N O Depth = 1000 ft Frac - Pore - Hydrostatic 0 30 60 90 Time (min) Total Depth = 4400.0 ft Top of Cement = 0.0 ft 'Mark of Schlumberger N N N R rn sm ~~ N N N d ~ C C Q N O • Sc~l~~rg~r Client Anadarko Well Gubik 3 String 7" Production District Prudhoe, AK Country : US SCwl~l~l'Qgr Page 6 Guhik3.cfw; 10-10-2007; Loadcase Production lal; Version wcs-cem452_07 Time (min) Client Anadarko ~I~I ~UI Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production ~a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments Chemical Wash 5.0 10.0 2.0 10.0 80 5-Start Pumping Wash 100 MUDPUSH XT 5.0 40.0 8.0 40.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 ~ 0.0 80 4-Drop Bottom Plug ASL Lead 5.0 ~8!L' I 5.6 28.2 80 13-Start Mixing Lead Slurry Tail 5.0 139.6 27.9 139.6 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 7.0 150.0 21.4 150.0 80 19-Start Displacement Mud 7.0 15.3 2.2 165.3 80 Slow Rate to Bump Top Plug Total 01:17 383.1 bbl hr:mn End Job: Bump Top Plug; Bleed-Off Pressure; Check Floats Dynamic Security Checks Frac 224 psi at 1000.0 ft Pore 125 psi at 1000.0 ft Collapse 4644 psi at 4320.0 ft Burst 6424 si at 0.0 ft Temperature Results BHCT 81 degF Simulated Max HCT 81 degF Simulated BHCT 69 degF Max HCT Depth 4300.0 ft CT at TOC 76 de F Max HCT Time 00:00:00 hr:mn:sc Static temperatures At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 21 degF Bottom Hole de F de F 81 de F Page 7 Guhik3.cfw; 10-10-2007; Loadcase Production lal;Version wcs-cem452_07 • • Client Anadarko Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production~a) Sc~l~rg~r a ,~' Q -Calc. WHP - Calc. Pump Press. N~ n d 2 0 10 20 2° .~ i~ a ~ o ~~ i ~ i 30 40 50 60 Time (min) Fluids at 4400 ft 70 80 90 0 10 20 30 40 50 60 70 80 90 Time (min) Page S Guhik3.cfw; 10-10-2007 ; Loadcase Production (a~; Version wcs-cem452_07 U Client Anadarko Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production (a) Section 4: fluid description Fluid No: 1 Rheo. Model :BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh VOLUME FRACTION Solids : 6.0 Oil : 0.0 Water :94.0 Mud DESIGN SI~~r~~r Density :12.501b/gal P~ :17.000 cP Ty :15.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :165.3 bbl MUDPUSH XT DESIGN Fluid No: 2 Density : 13.00 Ib/gal Rheo. Model :BINGHAM P~ :19.000 cP At temp. : 80 degF Tv :15.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :40.0 bbl Tail Slurry DESIGN Fluid No: 3 Density : 15.80 Ib/gal Rheo. Model :BINGHAM P~ :76.600 cP At temp. : 81 degF Tv :9.92 Ibf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : D907 Mix Fluid :5.092 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 1.16 ft3/sk Sack Weight : 94 Ib Solid Fraction :41.4 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D167 0.350 %BWOC Fluid loss S002 0.200 %BWOC Accelerator Thickening Time Schedule 9.3-1 100 Bc Compressive Strength Schedule () (psi) Job volume :138.6 bbl / Quantity :674.54 sk Base Fluid :5.092 gal/sk at 03:45 hr:mn at (hr:mn) Page 9 Gu6ik3.cfw:10-10-2007; LoadCaseProduction~al;Versionwcs-cem452_07 • Client Anadarko Well Gubik 3 String 7 District Prudhoe, AK Country US Loadcase Production (a) SI~~rg~r Chemical Wash 100 DESIGN Fluid No: 4 Density : 8.35 Ib/gal Rheo. Model :NEWTONIAN At temp. : 80 degF Viscosity :53.000 cP Gel Strength : (Ibf/100ft2) Job volume :10.0 bbl ASL Lead Slurry DESIGN Fluid No: 6 Density : 10.70 Ib/gal Rheo. Model : GINGHAM p„ :24.000 cP At temp. : (degF) Tv :32.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) ,~-o g ~ DESIGN ~,( J llz~ BLEND SLURRY Name : G Mix Fluid :21.831 gal/sk Job volume : 2 I Dry Density : 199.77 Ib/ft3 Yield :4.57 ft3/sk Quantity : ` 4.70 sk Sack Weight : 94 Ib Solid Fraction :36.1 BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Base Fluid :21.232 gal/sk Section 5: centralizer placement Top of centralization :980.0 ft Bottom Cent. MD :4260.0 ft Casing Shoe :4400.0 ft NB of Cent. Used :21 NB of Floating Cent. :21 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 4280.0 21 1/4 NW-SP-7 -6-SP-I-8375 100.0 4260.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ib NW-SP-7 -6-SP-I- 7 9.374 7.996 No Hannover 8.375 278.76 1216.22 8375 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 10 Gu6ik3.cfiv;10-10-2007; Loadcase Production (a); Version wcs-cem452_07 ~ ~ Client Anadarko Well Gubik3 String 7 District Prudhoe, AK Country US Loadcase Production (a) Mix Water Requirements Fresh water 5566 gal S~~I~rg~r Page 11 Guhik3.cfw; 10-10-2007; Loadcase Production lal;Version wcs-cem452_01 Page 1 of 1 • • Davies, Stephen F (DOA From: Bill Penrose [bill cLDfairvveather.com] Sent: Wednesday, January 23, 20081:38 PM To: Davies, Stephen F (DOA} Cc: Maunder, Thomas E (DOA} Subject: Gubik #3 Steve, I just dropped off for you at the Commission front desk: 1. The originals of the Designation of Operator for Gubik #3 signed by representatives of BG and Petro-Canada 2. Copies of the certificates conferring a vice presidency and board directorship to the BG signer 3. A copy of the power of attorney assignment for the Petro-Canada signer Please let me know if there are any other impediments that you know of to the issuance of the PTD for this well. If so, I'll get right on it. Thanks and regards, Bitl Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 1/23/2008 Page 1 of 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, January 23, 2008 8:06 AM To: 'Bill Penrose ;Maunder, Thomas E (DOA} Subject: RE: Gubik #3 Designation of Operator Form Bill, I will pass the application along in the process, but will need the originals before final approval. Remember, the owner representative signing each form must provide evidence of signatory authority. Thanks, Steve Davies From: Bill Penrose [mailto:bill@fairweather.com] Sent: Wednesday, January 23, 2008 8:00 AM To: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: Gubik #3 Designation of Operator Form Tom and Steve, Here are scans of the Designation of Operator forms for Anadarko's Gubik #3. The originals were received this morning by Anadarko in Houston and they'll overnight them to me. Meanwhile, are these attachments suffiaent for you to approve the application for PTD? We hope to spud on Sunday. Regards, Bill .Penrose Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Dodds, Steve [mailto:Steve.Dodds@anadarka.com] Sent: Tuesday, January 22, 2008 2:27 PM To: McDougal, Fred Cc: Bowen, Kim; Bill Penrose Subject: Designation of Operator Form Attached please find copies of the subject form executed by BG, Petro-Canada and Anadarko along with a copy of the recorded Memorandum of Oil and Gas Lease. Steve Dodds Land Manager -Alaska Anadarko Petroleum Corporation P.O. Box 1330, Houston, TX 77251 Office: 832-636-3087 Cell: 281-433-1605 Fax: 832-636-5158 E-Mail: steve.dodds@anadarko.com 1/23/2008 Page 2 of 2 • Anadarko Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. 1/23l20Q8 Page 1 of 1 Davies, Stephen F (DOA) From: Bill Penrose [bill@fairweather.com] Sent: Wednesday, January 23, 2008 8:00 AM To: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: Gubik #3 Designation of Operator Form Attachments: Desigantion of Operator - Gubik.pdf; CA003.pdf Tom and Steve, • Here are scans of the Designation of Operator forms for Anadarko's Gubik #3. The originals were received this morning by Anadarko in Houston and they'll overnight them to me. Meanwhile, are these attachments sufficient for you to approve the agolication for PTD? We hope to spud on Sundav. Regards, .l3'Z~l P2YlY'OSG' Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage; Alaska 99507 907-258-3446 _. From: Dodds, Steve [mailto:Steve.Dodds@anadarko.com] Sent: Tuesday, January 22, 2008 2:27 PM To: McDougal, Fred Cc: Bowen, Kim; Bill Penrose Subject: Designation of Operator Form /' Z 3 •D ~ / ~( l~,u.- /fir ~l /~'"~--~/~e 1. /1/+PZd c3-y rfl c ,h a, / s rw/ ~~k ~c t4[.f-~s- ~~~a~ Attached please find copies of the subject form executed by BG, Petro-Canada and Anadarko along with a copy of the recorded Memorandum of Oil and Gas Lease. Steve Dodds Land Manager -Alaska na arko Petroleu orporation P.O. Box 1330, Houston, TX 77251 Office: 832-636-3087 Cell: 281-433-1605 Fax: 832-636-5158 E-Mail: steve.dodds@anadarko.com Anadarko Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return a-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. 1/23/2008 Page 1 of 1 • Maunder, Thomas E (DOA) From: Bill Penrose [bill@fairweather.com] Sent: Friday, January 18, 2008 10:31 AM To: Maunder, Thomas E (DOA} Cc: Regg, James B (DOA}; Davies, Stephen F (DOA}; Alaska.DrilttngOpsMgr, Bowen, Kim; Dodds, Steve Subject: RE: Gubic tssues Attachments: GUBIK-3 7ESTtNG LAYOUT.pdf Thanks, Tom. I've forwarded your note to folks at Anadarko for action on Point #1. On Point #2, we're aware that there's no specific approval for flaring, but we wished to have the flaring plan with its anticipated volumes and duration included in the APD so the Commission is aware of it and doesn't have a problem with it from a resource conservation standpoint. Point #3 -I've attached the testing equipment layout here. Sorry for the omission. Thanks and regards, ~G~P ~CK~140.~ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [maltoaom.maunder@alaska.gov) Sent: Friday, January 18, 2008 10:02 AM To: Bill Penrose Cc: Tim Regg; Stephen F Davies Subject: Gubic Issues Bill, Thanks for the traveling directions. Some other things ... 1. There is a note in the file from Steve Davies to Chuck on January 4 regarding a "Notice of Ownership Form". That appears to still be outstanding. 2. You had asked about gas flaring and we have a January 2 letter from Mr. Bowen. It is understood that thorough evaluation is necessary and it flaring or venting is a necessary part of that activity. There really isn't an up--front approval for flaring. That you all will flare is acknowledged. It is important that the produced volumes be measured and reported. The only other would be that flaring such volumes is "covered" in DEC's air permit. 3. [n the letter, a schematic of the testing equipment is mentioned however it does not appear that it was included. 1Ne would appreciate if you could send one. Email is fine. I look forward to your reply. Colt or message with any questions. Tom Maunder, PE AOGCG 1/18/2008 \ 35 FOOT \ / ICE ACCESS ROAD \~ ~I 1 ~~. 110' ~ ~~ I2't h 210"_ Q - WELL TEST / p,, a ~` EGUIPMENT 4t / ` ~~ STAGING ~ 2 +,~' / ` ~ ` AREA 1 '!C~ / 4 ~ ~ Qe FLARE ~ R ~ ~2 % ~ j ~_ ~ ~ j l / WELL / / ~ _ ~ CENTER ~_~ 1 NORTH ,a• '~ r~ +~ PREVAILING WIND DATA FROM UMIAT REGION OCTOBER TO MARCH 2005 • 2006 / 2 } 3 ~~ Q X20.0' GRAPHIC SCALE • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, January 18, 2008 3:53 PM To: Regg, James B (DOA) Subject: FW: GubiK Testing Equip P&ID Attachments: 2008-0118_GUBIC-PID .pdf I haven't reviewed the drawing. Page 1 of 2 From: Bill Penrose [mailto:bill@fairvveather.com] Sent: Friday, January 18, 2008 3:44 PM To: Maunder, Thomas E (DOA) Subject: GubiK Testing Equip P8cID Here you go, Tom. Note Jimmy's comment below. Regards, ~'i~ ~e~t~to~e Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Jimmy Clark [mailto:Jimmy.Clark@exprogroup.com] Sent: Friday, January 18, 2008 3:36 PM To: Bill Penrose Subject: FW: Gubic Here you go Bill. There is a mistake on the flare tip rating. We will be using a Mardair tip rated for 400,000 scf/d- 40,000,000 scf/d. Jimmy Clark ~ ~ Weil Test Project Manager North America Operations jimmy.clark@exprogroup.com Cell: (33%} 552-8978 No virus found in this incoming message. Checked by AVG Free Edition. Version: 7.5.516 /Virus Database: 269.19.5/1228 -Release Date: 1/16/2008 9:01 AM ~v~ C 7/1/2008 ~` ~ ~-1/W SK SIKKME T~'E oF[crm ~~ I ~~ffi ~ tlYO1C1ECID.M4i I ~i~n C Y 1lYE ID! YStl6 CII/.CIIY t!a ~RS • D)O)~ Ea.IIT TN11 Mg59 F'' ;;, , j 3 PHASE SEPNMTDR--aOf16CF/D CCMNR SYSTEM--PIEUMTIC GaS SC~ER'-If10MSCF/L ~f N-)uE aYf-10Y~ ~ etiM MRa1K wa M ~) MeT rye ~ ~ ~MS~~n tt wK uD~ /~F~ ~' aC1. Vm %1 i Al Yf/Mt ~n COI ~ p n V R p Q' m A 'p~°O •A ~ _ o n rtr ss PRIMARY STORAGE TANK FARM 52[aaGE Taats @) ~"""~aw'f"w°'"r~°a ~ " ~"6r1O~,"i a wa'g'i @'>o a»nr oM «9' w > C~ ~idnE~M: RMM [SN RMN STROP VRM K~1lWR T]P n~naavarn w~c)m R Darn n Eimm alwiDS rtasolYOKi°) r COMMODITY ABBREVIATIONS LEGEND * ~v mu rtm wia b umm ra, tmas xort m rr RGL Im em w rw tra D RMRI M a)M 1YN MIaM[ fRM QNa i lRD OM DaRMC) MNM SYllbl 01YIPN (Ar Op®L eNlaI11 VKVI IMY tPIMI M6 aY N I>t w1Ta 1rLLL NRM MMNRa )lEp OIIMI[ MMI MRL16 ~IW1 -M1M114) NR ODII[ L ui MItlYt tRa tooowrz tM Rr w1O11~ p.W iNi LRi MRa1t naY1 M1eM M)11)8 frfNl ~ MEtO! T AYO ~ rtlRli pl ~r90r w r s.a. ,,,,, lu ~W p b -I-i-r- RDIIr M _ ~ ~ ~ ~ p b02 Fink MMEII aRN R q IaM! n)4[ 11Y~Y 1lRa1 M[ N N N ctim s AAKO PETNOLEIIa CORPoRATKMI A N A D ~ ~ ~ ~ y ~ 11/191ROR) itif~ ' wFIMOaRtsmlwerrrAnoMaaoww i • ANADARKO PETROLEUM CORPORATION 3201 CSt Ste. 603 ANCHORAGE, ALASKA 99503 U.S.A. PH. (907) 273-6300 January 2, 2008 ~~~a~~ Petroleum Corporation ~s~~ ~ Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission ~~°~~"~ ~' 'F ~ ~ ~''~ 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Supplement to Application for Permit to Drill: Gubik #3 Dear Mr. Norman, Anadarko Petroleum Corporation currently has undergoing review at the Commission an application for Permit to Drill a gas exploration well, the Gubik #3, this winter. This letter is to present supplemental information for that application detailing Anadarko's proposed plans to flare gas during well testing. After the Gubik #3 is drilled and completed, the drilling .rig will be moved off the ice pad and well testing equipment will be assembled to conduct a comprehensive test of the gas reservoir there. A schematic of the pad and test equipment layout is attached which demonstrates the flow path of the gas, terminating at the flare boom. Gubik #3 being an exploratory well, we of course cannot be sure of the rates at which the well will flow and what the final flared amount will be. However, as a maximum, each of the two zones to be evaluated could be tested for as long as ten days and average gas rates of 20 mmscf per day resulting in a total flared volume of 200 mmscf per interval. It is very possible that a lower cumulative will be necessary; however, we request approval to flare up to 200 mmscf per interval if early test. results indicate that higher flow rates and/or longer flow periods are needed to adequately characterize the reservoir. It is very important to adequately assess the reservoir with this well due to the logistics and cost of drilling wells in this remote location. Volumes and pressures will be closely monitored so that analyses may be made of ultimate deliverability, an indication of reservoir size, efficiency of the completion, etc. These analyses are crucial to determining the economic viability of the project. ORIGINAL We would appreciate the Commission including this supplemental flaring request with the Gubik #3 application for Permit to Drill currently undergoing review at the Commission so that both can be addressed, and hopefully approved, simultaneously. If you have any questions or require additional information, please contact me at (907) 273-6319. Sincerely, ANADARKO PETROLEUM CORPORATION ~~~ B.K. Bowen General Manager -Alaska enclosure C:\PROJECTS\W ORD\LTRH D.W PD r ANADARKO PETROLEUM CORPORATION 3201 CSt Ste. 603 ANCHORAGE, ALASKA 99503 U.S.A. PH. (907) 273-6300 Petroleum Corporation January 2, 2008 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Supplement to Application for Permit to Drill: Gubik #3 Dear Mr. Norman, Anadarko Petroleum Corporation currently has undergoing review at the Commission an application for Permit to Drill a gas exploration well, the Gubik #3, this winter. This letter is to present supplemental information for that application detailing Anadarko's proposed plans to flare gas during well testing. After the Gubik #3 is drilled and completed, the drilling rig will be moved off the ice pad and well testing equipment will be assembled to conduct a comprehensive test of the gas reservoir there. A schematic of the pad and test equipment layout is attached which demonstrates the flow path of the gas, terminating at the flare boom. Gubik #3 being an exploratory well, we of course cannot be sure of the rates at which the well will flow and what the final flared amount will be. However, as a maximum, each of the two zones to be evaluated could be tested for as long as ten days and average gas rates of 20 mmscf per day resulting in a total flared volume of 200 mmscf per interval. It is very possible that a lower cumulative will be necessary; however, we request approval to flare up to 200 mmscf per interval if early test results indicate that higher flow rates and/or longer flow periods are. needed. to adequately characterize the reservoir. It is very important to adequately assess the reservoir with this well due to the logistics and cost of drilling wells in this remote location. Volumes. and pressures will be closely monitored so that analyses may be made of ultimate deliverability, an indication of reservoir size, efficiency of the completion, etc. These analyses are crucial to determining the economic viability of the project. DUPLICATE r ~ ~ We would appreciate the Commission including this supplemental flaring request with the Gubik #3 application for Permit to Drill currently undergoing review at the Commission so that both can be addressed, and hopefully approved, simultaneously. If you have any questions or require additional information, please contact me at (907) 273-6319. Sincerely, ANADARKO PETROLEUM CORPORATION ~~ B.K. Bowen General Manager -Alaska enclosure C:\PROJECTS\WORD\LTRH D. WPD Page 1 of 1 • Davies, Stephen F (DOA) From: Dodds, Steve [Steve.Dodds@anadarko.com] Sent: Friday, January 18, 2008 12:50 PM To: Davies, Stephen F (DOA) Cc: Bill Penrose; Bowen, Kim; Alaska.DrillingOpsMgr Subject: Designation of Operator Form - Gubik 3 Well Importance: High Attachments: Desig of Operator_BG to APC.pdf; Desig of Operator PC to APC.pdf; CA003.pdf Steve, Per our conversation today attached is the information we discussed. iJpon receipt of the executed forms from BG and Petro-Canada early next week I wilt execute an behalf of APC and forward to Bill Penrose for his fiurther handling. If you have any question or need more infarmatlon do not hesitate to contact me. Thank you for your assistance in this regard. ~~' Steve Dodds Land Manager -Alaska nadrko etroleu Corporation P.O. Box 1330, Houston, TX 77251 Office: 832-636-3087 Cell: 281-433-1605 Fax: 832-636-5158 E-Mail: steve.dodds@anadarko.com Anadarko Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return a-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. 1 /22/2008 s r STATE OF ALASKA ALASKA OIL AND GA5 CONSERVATION COMMISSION ®ESIGNATION OF OPE1~,4TOR 7n n nn ne nnn 1. Name and Address of Owner: BG Alaska E&P Inc. i 222 3rd Avenue SW, Ste. 500 ' Calgary, AB T2P OB4 2. Notice is hereby given of a desighation of operatorshlp for the oil and gas property described below: Legal description of properly: ASRC Lease CA 003 . Twn 1 N, R 3 E, Umiat Meridian, Section 17 Property Plat Attached: ^ 3. Name and Address of Designated Operator. Anadarko Petroleum Corporation P.O. Box 1330 Houston, TX 772 5 9-1 3 3D 4. Effective Date of Designation: 1!1!2008 5. Acceptance of operatorshlp for the above described properly within all attendant responsibilltlesand obiigaGons Is hereby acknowledged: Signature ~,,_ -~ Date ~}~.n~ .~,~ ~~ Printed Name a n ~ 1gc1~ Title ~ S l~c'f1G - t~ ~o~ fi 6. The Owner hereby certifies that th foregcing is true a correct (attach Power of Attorney or other evidence of authority of person signing): Signature ~ ' ~Of `~~~ ~ ~ ~ ~ " "'" Date ~ ~ ] ~~! 1 Printed Name ~' ~ L%i ~ti~~i-/i./v Title `~V ~~l~ ~ / ~,i ~-~9 ~~~`"~ ~~y /~~ ! ~_. 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by lwo Commissioners) Form 10-411 Rev.12/20D5 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Owner: Petro-Canada (Alaska), Inc. 150-6th Avenue, S.W., 26th Floor Calgary, AB T2P 3E3 2. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: ASRC Lease CA 003 Twn 1 N, R 3 E, Umiat Meridian, Section 17 Property Plat Attached: ^ 3. Name and Address of Designated Operator. Anadarko Petroleum Corporation P.O. Box 1330 Houston, TX 772 51-1 330 4. Effective Date of Designation: 1/1/2008 5. Acceptance of operatorship for the above described property within al! attendant responsibilities and obligations is hereby acknowledged: Signature -~~_~ ~ e~ Date Q'(1.1A(~.1'U G2, 2 Q ~~ Printed Name ~v~-CIIPXI. ,`• ~~~ ~ Title ,~tXlk £1 rln-ey - -n ~ r'QC~- 6. The Owner hereby certifies that the foregoing is true and correct (attach Power of Attorney or other evidence of authority of person signing): Signature /'d"r'"`-"+ Date ~-a~v.~~ t 7 ~z.ea~ Printed Name ~'~'` ..r >: (l.O~rZ.- I o ~-+ ~6-6r{r ~-~e ~' is /1'+'C-o/LJ bra ~ y ~ov~c{t o ~ ,,~-a(~/ 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) '~ Form 10-411 Rev.12/2005 Submit in duplicate a zoo~_ao~o4s_~ ' riiHiR~iuoi~oAODUwiui~ii~uuiuiiiriaiiuuiuiuNA~n memoawnom ox ort,wo cas ~.ense_~oo3 CC THIS MEMORANDUM OF OIL AND GAS LEASE made and entered into effective as of the 1St day of September, 2007 by and between ARCTIC SLOPE REGIONAL CORPORATION, an Alaska corporation, herein called "Lessor", and the following parties in the percentages shown (hereinafter collectively called "Lessee"): ~. Anadarko Petroleum Corporation (as to an undivided 33.34% interest), Petro-Canada (Alaska) Inc. (as to an undivided 33.33% interest), and BG Alaska E&P, Inc. (as to an undivided 33.33% interest) WITNESSETH: 1. Lessor ackriowledges that for valuable consideration, receipt of which is hereby acknowledged, and in consideration of the covenants and agreements contained in that certain Oil and Gas Lease referred to in paragraph.3 below, Lessor has granted, let and leased exclusively unto Lessee the real property hereinafter described for the purposes of exploring and prospecting for and, to the extent allowed by law, producing oil, gas and all other hydrocarbon and associated substances produced therewith, hereafter collectively referred to as "said substances", taking, storing, removing and disposing of said substances and certain uses and purposes incidental thereto, all as provided in and subject to the terms, conditions and provisions of said Oil and Gas Lease. The property covered by said Oil and Gas Lease, hereinafter referred to as "said land", is situated in the State of Alaska, and is described as follows: T.1 N., R. 3 E., Umiat Meridian. Alaska. Sections: 4, 5, 8, 9,16, and 17 ~ and containing 3,840 acres, more or less. 2. Subject to the terms, conditions and provisions thereof, said Oil and Gas Lease provides that it shall remain in force for a primary term commencing on the effective date hereof and ending on the 30th day of June, 2010, and as long thereafter as said Oil and Gas Lease is kept in force under any other provision of said Oil and Gas Lease, all as particularly set forth therein and subject to termination as therein provided. 3. This Memorandum of Oil and Gas Lease is made upon terms, covenants and conditions set forth in that certain Oil and Gas Lease dated effective September 1, 2007, by and between the parties hereto and covering said land, which Oil and Gas Lease is by this reference _ ~. .. ~ .. incorporated herein and made a part hereof in all~respects as though the same were fully set forth herein.- Nothing herein is intended or shall be construed to amend, change, alter, waive, or in anywise ,affect any of the terms; conditions, provisions, restrictions, covenants or agreements contained and provided in said Oil and Gas Lease. 4. Said Oil and Gas Lease and all its terms, conditions and provisions shall extend to and be binding upon the successors and assigns of the parties hereto, subject, however, to the restrictions, conditions and limitations with respect to assignments and transfers set out in said Oil and Gas Lease. IN WITNESS WHEREOF, the parties hereto have executed this Memorandum of Oil and Gas Lease effective as of the date first hereinabove set forth. LESSEE: LESSOR: Anadarko Petroleum Corporation B ~.~5~~:.._-_ Name: Steven K. Dodds Title: Aeent & Attorney-in-Fact LESSEE: Petro-Canada (Alaska), inc. By: Name:_Anne Parsonage Title: Attorney by Power of Attorney LESSEE: BG Alaska E&P, Inc. By: Name: Doug Arnell Title: Vice President & Director Arctic Slope Regional Corporation . By: Name: Teresa Irrun _ ' Title: Director-Resource Development iimAUmuumiiiiiii STATE OF ALASKA THIRD JUDICIAL DISTRICT The foregoing Oil and Gas Lease was acknowledged before me this day of , 2007 by Teresa Imin, Director-Resource Development of Arctic Slotie Regional Corporation, on behalf of the corporation. Notary Public for the State of Alaska My Commission Expires: , STATE OF TEXAS ) MONTGOMERY COUNTY ) s.s. Th foregoin Oil and Gas Lease was acknowledged before me this 1 ~ ~ day of 2007 by Steven K. Dodds. Agent & Attorney-in-Fact of Anadarko Petroleum Corporation, on behalf of the corporation. ~ IUII~ERLYANN QUfGGLE otary Publi for the State of T NOTAR1fPlIBUCSTATEOFTE%AS My Commission Expires: v ~,,~~ COMMISSION E%PIRES: APRIL 19, 2008 CITY OF CALGARY PROVINCE OF ALBERTA ) ss. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this day of , 2007 by Anne Parsonage, its Attorney by Power of Attomev_ ofPetro-Canada (Alaska), Inc., on behalf of the corporation. ,. Notary Public for the Province of Alberta My Commission Expires: CITY OF CALGARY PROVINCE OF ALBERTA ) s.s. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this day of .2007 by Doug Arnell, Vice President & Director of BG Alaska E&P, Inc., on behalf of the corporation. Notary Public Tor the Province of Alberta My Commission Expires: ~~i ~iiiiii«i~i« ii~ii~iii~iiii iii :::: ; _ . 3 of. 9 20f17-001048-0 incorporated herein and made a part hereof in all respects as though the same were fully set forth herein. Nothing herein is intended or shall be construed to amend, change, alter, waive, or in anywise affect any of the terms, conditions, provisions, restrictions, covenants or agreements contained and provided in said Oil and Gas Lease. 4. Said Oil and Gas Lease and all its terms, conditions and provisions shall extend to and be binding upon the successors-and assigns of the parties hereto, subject, however, to the restrictions, conditions and limitations with respect to assignments and transfers set out in said Oil and Gas Lease. IN WITNESS WHEREOF, the parties hereto have executed this Memorandum of Oil and Gas Lease effective as of the date first hereinabove set forth. LESSEE: Anadarko Petroleum Corporation By: Name: Steven K Dodds Title:_A~ent & Attorney-in-Fact LESSOR: Arctic S Regio al Corporation By: Name: Teresa Imm Title: Director-Resource Development LESSEE: Petro-Canada (Alaska), Inc. By: Name: Anne Parsonage Title:_ Attorney by Power of Attorn~ LESSEE: BG Alaska E&P, Inc. By: Name: Douc Arnell Title: Vice President & Director ~NER L, j~'h~ ~`v ~ ~ ' ~ - ' ~ 9 ~., NOTggy STATE OF ALASKA ~ ~ s.s i 'OUBLIG ~ N THIRD 3UDICIAL DISTRICT ~; ~ s.s. ~4,~~3:yr~ ~PS~: ~~, ,~ OF A~~ ) , ~~ 4 ~..= ~h~ °~ Expires' ~ Th~e f o regoing Oil and Gas Lease was acknowledged before me this Z$~' day of~~~~~~~~~~~' ~ ~ " ~~r~,,bay , 2007 by Teresa Imm. Director-Resource Development of Arctic Slope Reeional Corporation,,,ponbehalf ofthe corporation. ~ . LX-~~..t~ Notary Public for the State of laska My Commission Expires: '"f 21 1 p STATE OF TEXAS ) MONTGOMERY COUNTY ) ss. The foregoing Oil and Gas Lease was acknowledged before me this day of .2007 by Steven K. Dodds Agent & Attorney-in-Fact of Anadarko Petroleum Corporation, on behalf of the corporation. Notary Public for the State of Texas . My Commission Expires: CITY OF CALGARY PROVINCE OF ALBERTA ) ss. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this day of 2007 by Anne Parsonage its Attorney by Power of Attomev of Petro-Canada (Alaska), Inc., on behalf of the corporation. Notary Public for the Province of Alberta My Commission Expires: CITY OF CALGARY PROVINCE OF ALBERTA ) s.s. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this day of .2007 by Doue Arnell. Vice President & Director of BG Alaska E&P, Inc., on behalf of the corporation. Notary Public for the Province of Alberta My Commission Expires: III1111111111111III111Nilllllll 5 of 9 2007-OOi048-0 incorporated herein and made a part hereof in all respects as though the same were fully set forth herein. Nothing herein is intended or shall be construed to amend, change, alter, waive, or in anywise affect any of the terms, conditions, provisions, restrictions, covenants or agreements contained and provided in said Oil and Gas Lease. . 4.. Said Oil and Gas Lease and all its terms,- conditions and provisions shall extend to and be binding upon the successors and assigns ofthe-parties hereto, subject, however, to the restrictions; conditions and limitations with respect to assignments and transfers set out in said Oil and Gas Lease. IN WITNESS WHEREOF, the parties hereto have executed this Memorandum of Oil and Gas Lease effective as of the date first hereinabove set forth. LESSEE:. Anadarko Petroleum Corporation By: Name: Steven K. Dodds Title: Agent & Attorney-in-Fact LESSEE: Petro-Canada (Alasnka}, Inc. Name _Anne Parsonage Title: Attorney by Power of Attorney LESSEE: BG Alaska E&P, Inc. By: Name:_ Doug Arnell Title: Vice President & Director Ii01'IIII~IIIIIAIil~llh LESSOR: Arctic Slope Regional Corporation By: Name: Teresa Imm Title: Director-Resource Development STATE OF ALASKA ) THIRD JUDICIAL DISTRICT . ~ ) s.s. . •) The foregoing Oil and Gas Lease was acknowledged before me this day of , 2007 by Teresa Irnm. Director-Resource Development of ,Arctic Slope Re 'oval Corooration on behalf of the corporation. Notary Public for the State of Alaska My Commission Expires: STATE OF TEXAS } MONTGOMERY COUNTY ) ss. The foregoing Oii and Gas Lease was acknowledged before me this day of 2007 by Steven K. Dodds Agent & Attornev-in-Fact of Anadarko Petroleum Corporation, on behalf of the corporation. Notary Public for the State of Texas My Commission Expires: CITY OF CALGARY PROVINCE OF ALBERTA ) s.s. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this a8w day of _n1o v t n-, ci 4-'rt , 2007 by Anne Parsonage, its Attorney by Power of Attornev ofPetro-Canada (Alaska), Inc., on be if o€the corporation. ~ 7C3+'Zr EGGRY RUSSELL FALt!idC.~i ~ ~rr;ster, Solicitor, ivotary F~!Llir. ~e `~.9t'l1YYli55i0i1@r for 08ths in arc:: for the Notary ~ubli or the Pro' ce of Alberta provsnce at Alberta My Commission Exp f h d • H ; ~- CITY OF CALGARY PROVINCE OF ALBERTA } s.s. COUNTRY OF CANADA ) The foregoing Oil and Gas Lease was acknowledged before me this day of .2007 by Doug Arnell. Vice President & Director of BG Alaska E&P, Inc., on behalf of the corporation. incorporated herein and made a part hereof in all respects as though the same were fully set forth herein. Nothing herein is intended or shall be construed to amend, change, alter, waive, or in anywise affect any of the teens, conditions, provisions, restrictions, covenants or agreements contained and provided in said Oil and Gas Leaser' 4. Said Oil and Gas Lease and all its terms, conditions and provisions shall extend to and be binding upon the successors and assigns of the parties hereto, subject, however, to the restrictions, conditions and limitations with respect to assignments and transfers set out in said Oil and Gas Lease. IN WITNESS WHEREOF, the parties hereto have executed this Memorandum of Oil and Gas Lease effective as of the date first hereinabove set: forth. LESSEE: LESSOR: Anadarko Petroleum Corporation By: Name: Steven K. Dodds Title:__ .Agent &Attornev-in-Fact LESSEE: Petro-Canada (Alaska), Inc. Arctic Slope Regional Corporation By: Name: Teresa Irnn- Title: Director-Resource Development By: Name: Anne Parsonage Title: Attornev by Power of Attorn LESSEE: BG A ska E& Inc. By: /L Name: Arnell R'INIVIiIV!91AIdY0NN ~. STATE OF ALASKA ~ ) THIRD JUDICIAL DISTRICT ) s.s. The foregoing Oil and Gas Lease was acknowledged before me this day of ' 2007 by Teresa Imm Director-Resource Development of Arctic Slope Reeional Corporation, on behalf of the corporation. Notary Public for the State of Alaska My Commission Expires: STATE OF TEXAS MONTGOMERY COUNTY s.s. The foregoing Oil and Gas Lease was acknowledged before me this day of 2007 by Steven K. Dodds Agent & Attornev-in-Fact of Anadarko Petroleum Corporation, on behalf of the corporation. Notary Public for the State of Texas. My Commission Expires: CITY OF CALGARY PROVINCE OF ALBERTA ) s.s. COUNTRY OF CANADA ) The foregoing OiI and Gas Lease was acknowledged before me this day of 2007 by Anne Parsona~2e, its Attorney by Power of Attorney ofPetro-Canada (Alaska), Inc., on behalf of the corporation. Notary Public for the Province of Alberta °o y My Commission Expires: o fD 0 0 •~ i ~ ~ ~ CITY OF CALGARY PROVINCE OF ALBERTA ) __. COUNTRY OF CANADA ) ThLe~ foregoing Oil and Gas Lease was acknowledged before me this 29 day of _ [~ (5 V ~rn~j~Y , 2007 by Doue ArneIl. Vice President & Director of BG Alaska E&P, Inc., on behal of a corporation. 4 S ,`, ~~ ~ No~ b ' r _, e Province of Alberta >-~~~ ~vly ' ssLOn:Expir~s: :~:. ~, s ~ ~~~~'~~ss,~`C~ ~~gt,son :-.:~ ' - _ f,~fW~ertf`~"t Caw _ . ~,: , f~ .. °,5. ,.. • From: Bill Penrose [maitto:bill@fairweather.com) Sent: Friday, 3anuary 11, 2008 1:36 PM To: Regg, James B (DOA) Cc: Alston, )oe Subject: Rig Diagrams for Anadarko Gubik #3 PTD Jim, Here are all the drawings for Nabors Rig #105 that you requested except for the view showing the RKB elevation. That drawing is in the works and will be issued shortly. Please let me know if you need anything else. Regards, ~'i~ ~e~tode Vice President J Drilling Manager Fairweather E8P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 TO GASBUSTER TO FLARE ELEVATION LINE VIEW "B" 3 2 ®i ~ 5 6 ® ® I ~~ '~"'~" `J - - ELEVATION ~I-\Iy 1s VIEW "A" FROM PRESSURE 1NELLHEAD 18 17 E ~E WTIOIN 1 O ~ GUAGE O 3 16 15 14 11 12 31 13 ELEVATION PLAN VIEW VIEW "B" MATERIAL LIST ITEM I.D. NO. DESCRIPTION i AS0811161 _ 31/16' 10,000# CNV 'FC GATE VALVE 2 N1188 3.1/16'x31/14z311i6'x31/14x31/18'z 2-1/16' 10,000# x 23' OAL STUD. 6-WAV BLOCK 3 F3092AC 31/16' 10,000# BUND FLANGE 4 27430 31/16' z 10,000# VALVEWORKS 'VW-FC GATE YALYE 5 28782 31/18' x 10,000# VALVEWORKS 'VW-FC GATE VALVE 8 N1188 31/18' 10,000# STUDDED &WAV BLOCK 7 74192A 31/18' 10,000# BUND FLANGE B ASW03005 31/16' 10,000# CNV 'FC GATE VALVE 9 2]x30 31/18' z 10,000# VAIVEWORKS 'VW-FC GATE VALVE 10 74005A 31118' 10,000# x 14' OAL FLANGED SPACER SPOOL 11 N1105 31116' 10,000# STUDDED CROSS 12 F3092AC 31118' 70,000# BUNG FLANGE 13 F30B2AC 31!16' 10,000# BUND FLANGE 14 AS0703001 31/16' 70,000# CNV 'FC GATE VALVE 15 F326BAE 31/18' 10,000# z 18.50' OAL FLANGED SPACER SPOOL 76 1003900-2- 1178 31/14 10.0001 GORTEG 'NH-2 ADJUSTABLE CHOKE wl Y MAX ORIFACE 5.5. T.C. NEEDLE & SEAT 17 F3268AE 31/18' 10,000# x 3.187' OAL I DOUBLE STUDDED SPACER 18 AS0703008 31/16' 10,000# CNV •FC GATE VALVE _ 19 AS0703009 31/16' 10,000# CNV 'FC GATE VALVE __ 20 ASO]03007 31/16' t0,000k CNV 'FC GATE VALVE 21 A507O3008 31/18. 10,000# CNV 'FC GATE VALVE _ _' 22 F3288AE 31/16' 10,000# z 2-9/18' 10,000# x 3.00' '~. _ DOUBLE STUDDED ADAPTER SPOOL 23 9384 _ . c~ ours I~VOTE arFw~inrw w~so~~ ~ 74005A 31/18' 10,000# z 2-9/16' 10,OOD# x 15.25' OAL FLANGED ADAPTER SPOOL 25 AS0703003 31/16. 10,000# CNV 'FC GATE VALVE 28 N1105 31/18' 10,000# STUDDED CROSS 27 AS0703010 31/16' 10,000# CNV 'FC GATE VALVE 28 F3092AC 35!1@ 90.000# BUND FLANGE 29 A50]03004 31/18' 10,000# CNV 'FC GATE VALVE _._ _ 30 79005A 31/16' 10,000# z 32.082 OAL FLANGED SPACEP. SPOOL 31 30830 2-1/18' x 10,000# VALVEWORKS 'VW-FC GATE VALVE 32 51209 2-i11410.OWMx2i502 WECO TMNSMITTER Fi_L~,:..;J -FEMALE THREAD (TAPPED 2 x 1? NPI; ~ 31/16' 10,000# x .4' OAL FLANGED SPACER SPOOL 34 '.14 'U,000# BUND FLANGE 35 __ _ _ _!_1F 10.000# STUDDED 3WAV BLOCK LEGEND WHITE HANDLE VALVES \l~pp!/ NORMALLY OPEN RED HANDLE VALVES NORMALLY CLOSED i ~nr~«.~ 25'~2S CD ~~2~ 907- -FOOD NABORS ALASKA DRILLING RIG 105E 4~"~~""~ "`"~' A~ 9~D3-~ ^°~' waeoRS AUSKA RK: 1OSE 10,000# CHOKE MANIFOLD CONFIGURATION ^^~ s-VIS• ro,ooo/ RACE TRIM CHOKE 3 KRL ANNK'01.0 SYSTEM WELL CENTER f. ONERTER ANNULAR N0RAWIY OPEN. 2. FABRI-VALVE AIORItALLY CLOSED. AlOR WELL CENTER NABOBS RIG '~ 05E DIVERTER C0NFIGiJRAT10N NABOBS ALASKA RIG 105E DIVERTER LINE LAYOUT GOB 6IW6fH 01®LY i W~~49 11 ~IMC n ~~ Malin Almlm GiIYW Nc. ~~ 7375 C Sl t SWt 700 u ~ ~ UM~O~MA\~4~ ~~w NmMa 993115-7&K 907- -8000 NABOBS ALASKA RIG 105E ONEREER UNE UYWi ~ i6 ONERTER SYSfEN oerw n om® .wmm n av. 310Ci07 A JA JA ISSUED JOE AL510// JOE ALSipI RW. SIIiN A ouc ",^d~. '~."~ acxsnox "" A pOCipeErl 70(17 M0' ^OSE000.7 i a 1 - FUEL PUMP 105-5 TANK 105-13 TYPICAL OF 2 TANK 105-12 TYPICAL OF 3 BELOW TYPICAL OF 3 TANK 105-9 TANK 105-16 TYPICAL OF 2 - TANK 105-10 -TANK 105-25 TANK 105-11 X~L~; ° a~x~ LARY TANK 105-17 ' F LTAVK AUK TANK f --P pe gRTS ODULE x I CENTRIf UGE PUMP '~ i _~ ':I FUEL TANK MODU:.c .t< COLOSTART M - HA~LWAV MIX TANK r 0/~ l «. . ASS BB ]t]0 5 4B ',~ -. y MODUlE2 210A ; 1 1 SKID " ~•- ••.. ""' .... 21 ' GENSET MODULE 213A ., i „,,. TANK 105-20 TANK 105-39 -TANK 105-18 TYPICAL OF 6, BUT ONLY 2 USED AT A TIME. GHAKER N TANK 105-19 TANK 105-27 p DEGASSER MODULE 061 TANK 105- TA 105-4 -, '-'~- -~ _ _..~...,.. 011A _ GENSET MODULE 2 SUBSTRUOT 2138 212A "~' PUMP MANIFOLD CALGARIG REMOVABLE CATWALK - ~' - " ,,j MODULE 1q1 ~- MODULE ~ •.13 . _ ____ .............. ......... _ _ _ _ ........... .... ....... . . _ ________________. .. 0118 ' 'te a UTILIDOORMOOULE TANK 105-3 ~ ~, r° '~ GENSET MODULE '. `.« _ - '~' '{'~1~L~II~ti I; } xi lA ' " .r ATE TAN . . ...-.- . .. ......... __ __ ..... ...............__-.... ...... ..._._ . _ .. . ............. __ .. ... .. ... ;r, HOTWELL MODULE ~ ~~ ~ A U Oft 211B ; M LE _ _ ........... .......... .. ... ... __.__ ~ ~ TA Mf1. 11 USG ... ... ~ e ~ ... TIO _.._._::.:4. FD MoouLE z __ - - -------- -- 3~~I ~N~ ~ - ----- _'_- H ER - ---- - v VFD MODULE 1 221A . AUX. WATER TAN ...- . - .. ---------- ..-- .. ... ............. . .. .. 2218 1x1 . ......_____-__________ __________ _________............._.____ ___ .._......____..._________ .., ~~ _ Kvo xVSG TANK 105-7 TANK 105-15 _- i = -"------- =- ..::::::::::::::..... ------- ~u= - 1,~_u~-------------- - ------------ TANK 105-2E -- -- -___::::_:::::::::---:_ TYPICAL OF 2 - - ------------------------ ---------- - ------------------ --------- ----------- ---------------- ----------- --------------- --- ---"--------------------- -- ------------------ -- smea tee sx.aec ar.am e.n3 ll rxet e. aou TANKS. GROUND LEVEL 10l-1 Ja,ruua°a ww x ~ x ouw+rs wa or ~ ~... ; ~V., -. loses eDP .DCUwurae Ha cws eaeMLr wD 1oa-3 o rest PMMr waerArl°N xs OueRrs 1210E a3 - -----'--- ......... ........ ----- ................ .........................._. ...... .....-----"- _ --................- -- ' -.. ......--------.._..... 1os-~ let wr rout T.Tm cos. aESeL FVEL 1os-s R1EL FUYP x ~ 1~ clamors u1eE cIL TANK 105-14 '°'-' "°'~"""~` 1ee1 aN.3 eDe~R.A,Ee Io,-e TYPICAL OF 2 TANK 105-1 10l-s cowsrAar Fun reset s~ rxs. oE!¢ fT1D. '°'-'acansrwe muEr Luse °' ~.l. D,ee aL TYPICAL OF 2 1m-11 cowsrARr aJSLr ererroa a cos. cLrca 1os-1x cersEr LUKE s ~ v aas. wet aL 1os-u cQSer RwA.m+ 3 ° u.s cws. arcoL wAree w . TANK 105-29 TANK 105-2 s tos-1~uNEa wlcR x. x c 1w-u MuD PWM z ~ m cw.s. wee aL LSU run S o TYPICAL OF 2 . l 1m-1e AulnaAr nq rvEL srcaAa a ~ aa3o cnL 1os-1T Ru reset ss.x3 eels aewxc MW TANK 105-24 1°s-1e ra1P rww ST.e eeLS BeeuNC MuD 13s-1a Mu° rwats a roaurxc ee1.e aeLS ML10 ros-x° pETA4ER eW twat Sass eels oaADNC M1B 1oa-x1 Im-xx ~~-=3~~e *~ - Mme, ~_••'• ~" ~^~ TANK 105-23 10!-xt aATER twat - wzMARr laaex aw3. rNTEe 10l-x! nrmL srcawE s.Ta GALS arcs ne n ~ nonnan ana a Meole sslloollclloll vxc a M ~S 1as-v Moioe aL sr°a.¢ ro.Te rxs. lama oIL amI a alar s xnxtw~ w w re a rlua vq 103-I! QM OIL Sr01MOE ee.T6 ry c QM OIL 103-2! NYp. OIL SrOR~1GE ee.M CNS. Mm. OIL 10l-3e 1qG MFAle11 KIEL OAT iwet 700 fx.4 o11m NEL ~ey Npep~ NoYO OnIY' p Mc. ~Iel® M~clwooa~AlaYO~9elO] a~°~~°" tw-v NPE SNDx-PIPE sxAre NPU 1m GNS. Nro. aL e3T z6a77 e°°° 10!-xe IOa-xe rJ:1aAR eROaE arANe z • la DNS. ,~~ oe. RIG 705E 11~-.w y = AT w TMe s7~a~as.o~ u wa PLAN VIEW - LEVEL 1 SPCC PLAN 1a/or _ B SfcO atr6gr6 .am awx er oeatm er arPlolm n ea. JGl RAF JA A ~.~ NFL nroPN.IK ' 0.mi Mn 111E aeE ~' '~' OeQ1YN ~1E NTS °~ JULY 07 °~ ~705E-SPCC-1 9R~OF STORAGE TANK SCHEDULE TANK No. DESCRIPTION CAPACDY INTERMEDIATE LEVEL TANKS 105-6 AIR COMPRESSOR 2 O 6 QUARTS LUKE OIL 105-31 VAC PUMP 1 GAL. LURE OIL 105-32 TANK FOR VACUUM SYSTEM 134 GAlS. SLOP 105-34 DRAWWORKS 55 GAlS. LURE OIL 105-35 DRAWWORKS BRAKE HPU 10 GALS. HYD. OIL 105-36 MUD TANK AGITATOR 6 O 3.5 GALS. LUBE OIL 105-37 DEGASSER 5 GALS. LUBE OIL 105-38 CENTRIFUGE 5 QUARTS LUBE OIL ~ FUEi. ~-n'DRA000 I ~' -~ GLYCOL ~ ;~ MUD ~~~~~ LUBE i An~~ .,..e...r..ti., ~, a' RIG 105E ~ PLAN VIEW -LEVEL 2 SPCC PLAN STORAGE TANK SCHEDULE TANK No. DESCRIPTION CAPACITY UPPER LEVEL 105-40 HYD. OIL STORAGE ~2 89.76 GALS. HYD. OIL 105-41 GEAR OIL STORAGE M2 89.76 GALS. GEAR OIL 105-42 ROTARY TABLE 8 GALS. LURE Oll 105-43 HYDRAULIC TUGGER {J1 2 ®2 QUARTS LUBE OIL 105-44 TOP DRIVE GEAR BOX 10 GALS. LUBE OIL EUEi_ !+YDRAULIC '. GLYCOL '. MUD ~~e~ LUBE TANK 105-43 TYPICAL OF 2 105-42 105-44 ABOVE ~N~onAlawa ~" ...e......~ p,_, °~' RIG 105E " PLAN VIEW - LEVEL 3 SPCC PLAN va xEVrso.s 10' ELEVATION HYDRIL 13-5/8" 5k PSI GK ANNULAR BOP i~" LATCHED HEAD STUDDED CONNECTION 54-1/8" LENGTH SNAPPER 13-5/8" 5k PSI 0.. SL POSLOCK DOUBLE GATE STUDDED CONNECTION DRILLING SPOOL 1 ~~ 13-5/8" 5k ~.• SNAPPER 13-5/8" 5k PSI SL POSLOCK SINGLE GATE STUDDED CONNECTION NABOBS ALASKA RIG 105E 13.5/8" 5K STUDDED BOP ASSEMBLY \~~ 62' ~~ PLAN SFIAF~ER 5k 13-5/8" MODEL, SL POSLOCK 14" PISTON BOP RAM BONNET ACCESS CLEARANCE OmG A ~ dlr s~ M~RrB 6 ~a i ~~.~~~ .IWOr/M/r4~ Ane AImYO Y-SW_28.1Y ^~ ~, ~ NABOBS aASICA we ,0.5E BOP SlAC1C ODNF7LY/RA7K)N I Y ' J10CT07 A JA JA ISSUED 1 ~J E At510H 5K STU J-5/B ~ ~ DDED AS$EA BL ~ HW. 5"Ix ~ A art ~' •~' o[aaniox xvF A n,~E OCi08Ex T007 ~ i05E..000Y I of 1 '~. CUTTINGS CUTTINGS DISCHARGE TO BIN DISCHARGE TO BIN FORCED VENT TO OUTSIDE 3OLID3 DISCHARGE TO &N CENTRIFUGE 2 PS 6' Pi P7 6' P7 P2 8' ~ 8' 4' ~ TANK #8 0 -137 BBL 8' -1.42 BBL / IN. P1 8' B" Pt 8' PILL PR - 4B BBL -0.5 BBL / 8J. Pt O 8 MUD PUMP #2 MUD PUMP #1 TRIP TANK TANK #1 TANK #2 SHAKER#1 g SHAKER #2 ^4B BBL -133 BBL -133 BBL -0.5 BBLIIN. -1.388BL/IN. -1.38 BBL/IN. 7 g• V 8' 12' ti ® '~ 1T 3' is SIPHON BREAKER ®~ ,D' ®~ 8' VAC UNIT 12' TANK k5 TANK p0 TANK #3 - 13T BBL - 18388E -163 BBL - 1.42 BBL / IN. - 1.88 BBL / IN. -1.89 BBL / IN. P3 LEGEND PUMP KEY m Pt -MIX PUMP #1 (60 HPI 5X8 BUTTERFLY VALVE ~ O ~' P2-MIX PUMP Ill (80 HPI SXfi I~/I O TO STAND PIPE MANIFOLD GATE VALVE /v ~ P3 -CHARGE PUMP (80 HP) 5X8 I V~ P4-HOLE FILL PUMP (15 HPI4X3 MUD GUN WITH VALVE P5-CENTRIFUGE FEED PUMP (15 MP) 8X6 a SUCTION VALVE WITH BOLTON FLAT RUBBER REAL O PLUG OR BLIND FLANGE 2° TO KILL LINE ~_ FOR UTILITY HOOK-UP DAMPENER !\(r/71-JI BALL VALVE ~ AGITATOR HOPPER EQUALIZER FLOW ARROW -• POPAFF VALVE a SUCTION SCREEN 15 PSI RUPTURE VENT LINE ~~ ~~ Page 1 of 2 • Davies, Stephen F (DOA} From: Davies, Stephen F (DOA) Sent: Friday, January 04, 2008 9:54 AM To; 'Rowe, Chuck' Subject: Gubik 3 -Notice of Ownership Form Needed Chuck, While checking Commission's records, I noticed that Anadarko hasn't filed a Notice of Ownership form for the Gubik 3 lease. Regulation 20 AAC 25.022 states: "Within 15 days after a person becomes an owner of a property on which operations subject to this chapter are proposed to the commission or are being conducted, the person shall file a Notice of Ownership (Form 10-417)." (See the hyperlink provided in my December 20~' email, below.) Form 10-417 is fairly simple, and it is available on the Commission's web site at http:llwww.aogcc.alaska.gov/homeogc.shtml, near the center of the page under the "Forms -Notice Concerning Forms" hyperlink. Teresa Imm of ASRC or someone with a similar level of authority will have to sign the form for ASRC as the "Transferor." A Power of Attorney or similar evidence of signatory authority must be provided far whomever signs the form. Thanks, Steve Davies AOGCC 907-793-1224 From: Davies, Stephen F (DOA) Sent: Friday, January 04, 2008 9:24 AM To: 'Rowe, Chuck' Subject: RE: Gubik 3 Land Plat Chuck, Could you please send me a copy of the signed lease agreement? Thanks, Steve Davies From: Rowe, Chuck [mailto:Chuck.rowe@anadarko.com] Sent: Thursday, December 20, 2007 9:42 AM To: Davies, Stephen F (DOA) Cc: McDougal, Fred; bbritch@alaska.net Subject: RE: Gubik 3 Land Plat Steve- Attached you will find a lease agreement and corresponding map that details Anadarko's lease ownership in the vicinity of the Gubik prospect. Please call if you have questions or require additional information. Chuck Rowe Drilling Operations Manager 1!4!2008 Page 2 of 2 Anadarko Petroleum -Alaska • • Tele: 907-273-6302 Cell: 907-242-7131 From: Davies, Stephen F (DOA) [maitto:steve.davies@alaska.gov] Sent: Thursday, December 20, 2007 12:01 PM To: Rowe, Chuck Subject: Gubik 3 Land Plat Chuck, I am reviewing the permit to drill application for Gubik 3, and I have a request for you. Regulation 20 AAC 25.055(a)(2) requires that "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.° Per Commission regulations and state statutes, "landowner" means the owner of the subsurface estate of the tract affected. "owner means the person who has the right to drill into and produce from a pool and to appropriate the oil and gas the person produces ftom a pool for that person and others. "person" includes a natural person, corporation, association, partnership, receiver, trustee, executor, administrator, guardian, fiduciary or other representative of any kind, and includes a department, agency or instrumentality of the state of a governmental subdivision of the state. What I need is a land plat that will allow me to ensure that this set-back is honored by Gubik 3. The concerns are protection of correlative rights and the well bore survey requirements of 20 AAC 25.055. For your reference, the Commission's regulations are available online at http:/lwww.aogcc.alaska.gov/Regulations/Reglndex.shtml. Thanks for your help. I will email you if I have additional questions or requests. Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 Fax: (907} 276-7542 New Email Address: steve.davies@alaska.go_v 1/4/2008 Page 1 of 1 Davies, Stephen. F (DOA) From: Rowe, Chuck [Chuck.rowe@anadarko.com] Sent: Thursday, December 20, 2007 9:42 AM To: Davies, Stephen F (DOA) Cc: McDougal, Fred; bbritch@alaska.net Subject: RE: Gubik 3 Land Plat Attachments: Gubik Lease Summary.pdf Steve- Attached you will find a lease agreement and corresponding map that details Anadarko's lease ownership in the vicinity of the Gubik prospect. Please call if you have questions or require additional information. Chuck Rowe Drilling Operations Manager Anadarko Petroleum -Alaska Tele: 907-273-6302 Cell: 907-242-7131 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, December 20, 2007 12:01 PM To: Rowe, Chuck Subject: Gubik 3 Land Plat Chuck, I am reviewing the permit to drill application for Gubik 3, and I have a request for you. Regulation 20 AAC 25.055(a)(2) requires that "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." Per Commission regulations and state statutes, "landowner" means the owner of the subsurface estate of the tract affected. "owners' means the person who has the right to drill into and produce from a pool and to appropriate the oil and gas the person produces from a pool for that person and others. "person" includes a natural person, corporation, association, partnership, receiver, trustee, executor, administrator, guardian, fiduciary or other representative of any kind, and includes a department, agency or instrumentality of the state of a governmental subdivision of the state. What I need is a land plat that will allow me to ensure that this set-back is honored by Gubik 3. The concerns are protection of correlative rights and the well bore survey requirements of 20 AAC 25.055. For your reference, the Commission's regulations are available online at http://www.ao cg c.alaska.gov/Regulations/Reglndex.shtml. Thanks for your help. I will email you if I have additional questions or requests. Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 Fax: (907) 276-7542 New Email Address: steve.daviesCcaalaskagov 1/4/2008 MEMORANDUM OF OIL AND GAS LEASE - CA 003 THIS MEMORANDUM OF OIL AND GAS LEASE made and entered into effective as of the lst day of September, 2007 by and between ARCTIC SLOPE REGIONAL CORPORATION, an Alaska corporation, herein called "Lessor", and the following parties in the percentages shown (hereinafter collectively called "Lessee"): Anadarko Petroleum Corporation (as to an undivided 33.34% interest), Petro-Canada (Alaska) Inc. (as to an undivided 33.33% interest), and BG Alaska E&P, Inc. (as to an undivided 33.33% interest) WITNESSETH: 1. Lessor acknowledges that for valuable consideration, receipt of which is hereby acknowledged, and in consideration of the covenants and agreements contained in that certain Oil and Gas Lease referred to in paragraph 3 below, Lessor has granted, let and leased exclusively unto Lessee the real property hereinafter described for the purposes of exploring and prospecting for and, to the extent allowed by law, producing oil, gas and all other hydrocarbon and associated substances produced therewith, hereafter collectively referred to as "said substances", taking, storing, removing and disposing of said substances and certain uses and purposes incidental thereto, all as provided in and subject to the terms, conditions and provisions of said Oil and Gas Lease. The property covered by said Oil and Gas Lease, hereinafter referred to as "said land", is situated in the State of Alaska, and is described as follows: T.1 N.. R 3 E., Umiat Meridian. Alaska. Sections• 4, 5, 8.9.16, and 17 and containing 3,840 acres, more or less. 2. Subject to the terms, conditions and provisions thereof, said Oil and Gas Lease provides that it shall remain in force for a primary term commencing on the effective date hereof and ending on the 30~' day of June, 20101 and as long thereafter as said Oil and Gas Lease is kept in force under any other provision of said Oil and Gas Lease, all as particularly set forth therein and subject to termination as therein provided. 3. This Memorandum of Oil and Gas Lease is made upon terms, covenants and conditions set forth in that certain Oil and Gas Lease dated effective September 1, 2007, by and between the parties hereto and covering said land, which Oil and Gas Lease is by this reference CJ incorporated herein and made a part hereof in all respects as though the same were fully set forth herein. Nothing herein is intended or shall be construed to amend, change, alter, waive, or in anywise affect any of the terms, conditions, provisions, restrictions, covenants or agreements contained and provided in said Oil and Gas Lease. 4. Said Oil and Gas Lease and all its terms, conditions and provisions shall extend to and be binding upon the successors and assigns of the parties hereto, subject, however, to the restrictions, conditions and limitations with respect to assignments and transfers set out in said Oil and Gas Lease. IN WITNESS WHEREOF, the parties hereto have executed this Memorandum of Oil and Gas Lease effective as of the date first hereinabove set forth. LESSEE: Anadarko Petroleum Corporation By: Name: Steven K. Dodds Title: Agent & Attorney-in-Fact LESSOR: Arctic Slope Regional Corporation By: Name: Teresa Imm Title: Director-Resource Development LESSEE: Petro-Canada (Alaska), Inc. By: Name: Anne Parsonage Title: Attorne~YPower of Attorney LESSEE: BG Alaska E&P, Inc. By: Name: Doug Arnell Title: Vice President & Director • EXHIBIT A • ASRC LEASE CA 003 26 25 30 29 28 27 26 25 30 29 35 36 31 32 33 34 35 36 31 32 2 1 6 5 4 3 2 1 6 5 11 12 7 8 9 10 11 12 7 8 14 13 18 17 16 15 14 13 18 17 23 24 19 20 21 U~~ ~ 22 003E 23 24 19 20 26 25 30 29 28 27 26 25 30 29 2 35 36 31 32 33 34 35 36 31 __ 32 3 2 1 6 5 4 3 2 1 fi 5 4 11 12 7 8 9 10 11 12 7 8 9 Page 1 of 2 x , Regg, James B (DOA) :~ From: Regg, James B (DOA) Sent: Thursday, January 03, 2008 3:30 PM ~~~ ~ I~~~~ To: 'Bill Penrose' Subject: RE: Nabors 105E Rig Info -Trying to Correct a Disconnect Drawings we received for N106E: 1} "Rig 106E Plan View-Level 1" {DWG No. 106E-SPCC-1 ); 2) "Rig 106E Plan View -Level 2" (DWG No. 106E-SPCC-2); 3) "Rig 106E Plan View -Level 3" (DWG No. 106E-SPCC-3}; 4) "Diverter Line Layout" (no DWG #}; 5) "`Diverter System with 13-5/8" Annular" {no DWG #); 6) "11" 5K Blowout Preventer Wellhead Cellar Clearance" (DWG No. 106E_1011}; 7) Choke Manifold (no title, no DWG #) I did not send you copies since most approach 1 MB; I can send if this is not clear enough. Thank you again for helping gather this info. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Bill Penrose [mailto:bill@fairweather.com] Sent: Thursday, January 03, 2008 2:20 PM To: Regg, James B (DOA) Subject: RE: Nabors 105E Rig Info -Trying to Correct a Disconnect Jim, What we're looking for is what you have on RIG__1.06E, Joe is trying to put together the same package for 105E that you have for 106E. Regards, ~GGL j~~t4d~ Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, January 03, 2008 2:06 PM To: Bill Penrose Subject: RE: Nabors 105E Rig Info -Trying to Correct a Disconnect Attached are the only drawings (2) I was able to locate: Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 1 /3/2008 Page 2 of 2 phone: 907-793-1236 i ,fax: 907-276-7542 From: Bill Penrose [mailto:bill@fairweather.com) Sent: Thursday, January 03, 2008 1:50 PM To: Regg, James B (DOA) Subject: FW: Nabors 105E Rig Info -Trying to Correct a Disconnect Jim, I'm working with Nabors' CAD department to get the drawings for Rig 105E for you. Their Joe Alston sent the question below. Can you help? Thanks and regards, Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Alston, Joe [mailto:Joe.Alston@nabors.com) Sent: Thursday, January 03, 2008 12:22 PM To: Bill Penrose Subject: RE: Nabors 105E Rig Info -Trying to Correct a Disconnect 1/3/2008 Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) ` ~'ZI~~ Sent: Wednesday, January 02, 2008 4:37 PM ,~~~ To: 'bill@fairweather.com' Cc: Maunder, Thomas E (DOA) Subject: Nabors 105E Rig Info Below is a list of info we need regarding Nabors 105E since this is first use in State of Alaska. I'd appreciate large scale (11x17) or electronic so we can print in readable format. Nabors should have all this information readily available; we received similar info for N106E that is currently working for Unocal. 1) choke manifold diagram -show sequence (numbering of valves); 2) schematic showing KB elevation 3) diverter (copy provided in PTD application is fine) 4) diverter vent line (larger scale than what was provided in PTD application, please) 5) rig schematics (plan view) showing all levels (please reference all tankage volumes) 6) BOP with reference wellhead layout 7) flow schematic for drilling fluid flow We will also need a piping and instrumentation diagram before well testing at Gubi~{#3 is commenced. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 1 /2/2008 4 ANADARKO PETROLEUM CORPORATION 3201 CSL Sty 603 ANCHORAGE, ALASKA 99503 U.S.A. PH. (907) 273-6300 Petroleum Corporation December 20, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Hydrogen Sulfide Exemption Request Gubik -Chandler Foothills Prospects Dear Mr. Norman, Anadarko Petroleum Corporation proposes to drill two wells this winter, the Gubik #3 and the Chandler #1, in the Brooks Range Foothills east of Umiat. While the applications for permit to drill are being submitted under separate cover, a discussion with AOGCC staff indicates that applying for an H2S exemption separately could make the drilling permitting process more straightforward for both parties. Accordingly, Anadarko hereby requests an exemption from the hydrogen sulfide (H2S) requirements found in 20 AAC 25.065, subpart (c). Our rationale for this request is based on the documented absence of H2S in any of the nearby offsetting wells as ~ detailed in the attached evaluation of H2S potential in the Gubik -Chandler prospect area. If you have any questions or require additional information, please contact me at (907) 273-6302 or Bill Penrose at (907) 258-3446. Sincerely, ANADARKO PETROLEUM CORPORATION ~~..~~~ Chuck Rowe Drilling Operations Manager enclosures cc: Bill Penrose -Fairweather Brian Kelly -Anadarko r ~ H2S Evaluation in the Gubik /Chandler Exploration Area Nine offset wells were examined for the presence of hydrogen sulfide in the area of the planned Gubik #3 and Chandler #1 exploration wells. See the table below. Of the nine wells, none encountered measurable H2S. The planned Gubik #3 exploration well will be relatively shallow with a planned TD of 4,400' in the Torok Formation. The three closest offsets, all within two miles of the proposed Gubik #3 location, were drilled to similar depths and all three penetrated the same stratigraphic column (Tuluvak, Nanushuk and Torok Formations) expected in Gubik #3 and encountered no H2S. The Chandler #1 will be a deeper well, drilled to a maximum depth of 13,200' and will also TD in the Torok. The nearest offsets, East Umiat #1 and #2 and Colville Unit #1 and #2, were drilled to shallower depths of approximately 3,000' to 4,000' in the Nanushuk Formation. The deeper comparable wells in the area are the Seabee #1 and the Big Bend #1. The Seabee well was drilled to 15,611' and TD'd in the Kingak Formation. The Big Bend well was drilled to 10,737' and TD'd in the Torok. Both wells penetrated the entire stratigraphic column expected in the Chandler #1 and neither well encountered H2S in any of the formations penetrated. i Well Name (date TD Location Distance to Distance to Total Depth H2S Comments Gubik #3 Chandler #1 reached) Gubik Test #1 Penetrated the Tuluvak, Nanushuk (8/7!51) Sec. 19, T1N, R3E 1 mile 6.7 miles 6,000' TVD, MD No and Torok Gubik Test #2 Penetrated the Tuluvak, Nanushuk (12/10/51) Sec. 29, T1N, R3E 1.6 miles 6.3 miles 4,620' TVD, MD No and Torok Gubik Unit # 1 Penetrated the Tuluvak, Nanushuk (9/8/63) Sec. 21, T1N, R3E 1.1 miles 7.5 miles 4,406' TVD, MD No and Torok E. Umiat Unit #1 (3/4/64) Sec. 19, Tl S, R2E 10 miles 2.7 miles 3,347' TVD, MD No Penetrated the Nanushuk E. Umiat Unit #2 (5/10/69) Sec. 15, T1S, R1E 11.7 miles 5.5 miles 2,841' TVD, MD No Penetrated the Nanushuk Colville Unit #1 (3/8/70) Sec. 21, TiS, R1E 13.6 miles 6.9 miles 4,150' TVD, MD No Penetrated the Nanushuk Colville Unit #2 (12/14/71) Sec. 11, T1S, RIE 10.9 miles 4.9 miles 3,254' TVD, MD No Penetrated the Nanushuk Seabee #1 Penetrated Nanushuk, Torok, (7/1/79) Sec. 5, T1S, Rl W 18.4 miles 13.4 miles 15,611' TVD, M No Fortress Mtn and Pebble Shale Big Bend # 1 Penetrated Chandler, Grandstand, (3/2/93) Sec. 24, T3S, R2W 27.9 miles 20.5 miles 10,737' TVD, M No Torok and Fortress Mtn Fms The presence of H2S is not anticipated in the Gubik -Chandler prospect area. However, standard operating procedures for H2S detection (including sensors and alarms on the rig) and reaction (including escape and rescue air paks) will be in place at the rigsite and H2S precautions will be practiced at all times. wjp 12/20/07 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~C~C ~ ~'~ PTn~ ~ ~ ~ ~ ~~ Development Service ~ Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CIIECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt , (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 25.045(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. Please note the following specie! condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (,creme of well) until after f Comg~r},v Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Companv Name) must contact the Commission to obtain advance approval of such water well testing ro m. ~,-: ~nsnoo~ ___ _ WELL PERMIT CHECKLIST Field&PooIUMIAT-842000 ___WellName: GUBIK3 ____ __. Program EXP- .well boreseg [j _ PTD#:2071760 Company ANADARKO PETROLEUM CORPORATION ___ Initial Class/Type EXP / PEND GeoArea 890 __ Unit _ On/Off Shore On _ Annular Disposal Administration 1 Permit-fee atkached_ - - _ _ - _ _ _ - _ _ _ _ .. NA_ - - - _ 2 Lease number appropriate- - . - - - - Yes Received lease map D_ec. 29,2007 via email. _Requested signed-copy of the_lease agreement document.- - 3 Unique well-name and number - - - - - - - - - - - - - - Yes - - - . -111812008: Received_proof of ownership (lease agreement CA 003-re: Sec 4,5,8,9,16-& 1.7-of T1 N, R3E, UM). SFD 4 Well located in a-defnedpool- - - - - - - . - - - - No- - - . - Exploratory well_ 5 Well located proper distance_from drilling unit_boundary- _ _ - . Yes _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ I 6 Well located proper distance-from other wells_ - - - Yes - - _ _ - - Approximate_I -1_ mile from GubikTest No_. 1.- - - Y - , 7 Sufficient acreage-available in-drilling unit- - Yes - - _ - - ' 8 Ifdeviated,is-wellboreplatincluded______________ ___ NA_- -__.-_Vertical-well_-__ -- --- -_ .______ _- __--_.._______-..-__--_-.__ ii 9 Operator only affected party_ - - _ - Yes - - - - 1l18l2008:_Receiyed_proof of ownership (lease agreement);.$owners,_sodesignation-of operator-needed, 1/23-& 10 Operator has-appropriate-bond in force - - Yes - - 24108: Designation of Operator forms, received from Petro-Canada and-BG Alaska E&P,_and a[e-acceptable, - - - 11 Permit-can be issued withoutconseryationorder ------ --- ------- _____ Yes- -__-_SFD1/24108.___-._____ _..____--_______.______.._-____ ___ Appr Date 12 Permit-can be issued without administrative-appr_ova_I - - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - 13 Can permit be approved before 15-day wa-it- _ _ Yes - - _ SFD 1124/2008 I'I 14 Well located within area and strata authorized by Infection Order # (put 10# in-comments}-(For N_A_ - - 15 All wells-within 114-mil_e area of review identified (For service wel_I only)_ - - - - - - NA 16 Pre-produced injector_ dur_at_ion of pre production Less than 3 months-(For service well only) NA_ - - 17 Nonconven, gas conforms to AS31,05,030(j.1.A),~ 2.A-D} . - No- - - - 18 Conductor string provided Yes 100 ft; grouted losurface - Engineering x, 19 Surface casing.protects all_known USDWs - Yes cementto surface; no known U$DWs- - _ 1 20 CMT vol.adequate_tocircul_ateonconductor_&surf_csg-_--- -_-.__ __ Yes_ __________ ___ ________ ___ _ -_______-..________ X 21 CMT-voladequate_totie-in long string to surfcsg_..---.-- Yes_ _________________ _________________ __________--__-.-_------._--- 22 CMT willcoyer-all known-productive horizons- - Yes j 23 Casing designs adequate f_o[ C, T B &_permafrost- - - Yes A$L planned for lead_slurries for 7"and 9-518" csgs_ - - - •. 24 Adequate tankage_or reserve pit - - Yes 4000 bbl liquid waste tankage• temp pit for cuttings_(transport to KRU 2P); annular disposal NOTplanned X25 If a re-drill, has-a 10x403 far abandonment been approved - - - _ _ _ NA _ _ _ - _ - _ _ _ - . _ _ _ _ _ . _ _ - - - - - - - - - - - - - - 26 Adequate wellbore_seporation-proposed- _ _ - - . - - _ Yes - - . - _ - -vertical well;-closest well ~ 1 mile - _ _ - - - _ _ _ _ .. - _ _ _ _ _ _ _ - . _ - - - 27 If diverter required, does it meet regulations_ _ - - - - - - - . - Yes .. New ng (_Nabo_rs 105E), info received 01114!08. -Pre-spud inspection-planned. - _ - - Appr Date I28 Dulling fluid. program schematic & equip list adequate_ - - - .. Yes _ _ - Maximum expected formation pressure 12.0 ± EMW at X1300' tvd._ MW up to 13.8 ppg planned. - TEM 1118/20 29 BOPES,_do they meet regulation ~ Yes MASP=23Q7psi; 13-518", SKpsi WP stack; (ANN, PR, PR, BR) 30 B_OPE-press rating appropnate; test to (pu_t psig m comments) - - - Yes - - MASP calculated at 2307 psi 5000_psi initial BOP test, 3000 psi thereafter - - !31 Choke-manifold complies w1APl RP-53 (M_ay 84) Yes . - New rig (Nabors 105E); info received 01114108. Pre-spud inspection planned. - - '32 Work will occur without operation shutdown. - - - - - - Yes - - - - - .well test planned;_la out-drawin -received, P&ID re vested. Y 9 q 33 Is presenceof H2Sgas-probable- - - - - - - - - - - - - - No- . Rig will maintain monitoring-equipment !34 Mechanical condition of wells within AQR verified (FOr service well only} - - - NA- _ - _ _ - - ExploCaiion well _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - ~ 35 I Permitcan be issued wlo hydrogen.sulfide measures Yes - None enco_unte[ed in-offset wells; however, H2S sensors will be oRera_tional during drilling. . -- Geology 36 Data-presented on_ potential overpressure zones _ - - - Yes _ _ _ _ . Pare pressures as g[eat-as 12± ppg_EMWare-expected as shallow as 1300' MD. Surface casing will be-set at - - - Appr Date '37 Seismic analysis-of shallow gas_zones_ - - - - _ Yes - 1,000' MD4 and mud weights to 13,8-ppgore-planned, _ - - - SFD 12/1912007 38 Seabed cQnditron curve-Y (if off-shore) NA_ - - - - ~~39 ~, Contact namelphone for weekly-progress reports [exploratory only] . - Yes Fred McDougal, 907-273-6302- - - _ Geologic Date: Engineering Date Public Date Commissioner: Commissioner Commissioner • • 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. HALLIBURTON Sperry Drilling Services Anadarko Petroleum Corporation END OF WELL REPORT Gubik 3 &Gubik 3 BP01 ~` ~ _ ~ 9~ f~ ,. '` l f ~ ~..~i TABLE OF CONTENTS 1. General Information 2. Mudlogger's Daily Summary 3. Daily Operations Activity 4. Well Diagram 5. Lithology Summary 6. Hydrocarbon Notes 7. Show Reports a) Gubik 3 b) Gubik 3 BP01 8. Bit Record 9. Survey Report 10. Mud Record 11. Formation Evaluation Logs a) Gubik 3 b) Gubik 3 BP01 12. Data CD set a) Database, End of Well Report-digital format b) Digital logs, .emf, .pdf, .cgm formats c) Cuttings Sample Photomicrographs d) Digital Data files ascii, las 13. Morning Reports HALLIBURTON Sperry Drilling Services GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Spud Date: Total Depth Date:Gubik 3 Total Depth: Gubik 3 Bypass Date: Gubik 3 BP01 Total Depth Date:Gubik 3 BI Total Depth: Gubik 3 BP01 Rig Release Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Cartesian Coordinates: Drill Floor Elevation: Ground Elevation: Section: Township: Range: SDL Engineers: Company Geologist: SSDS Unit Number: Anadarko Petroleum Co. Nabors 105E Gubik 3 &Gubik 3 BP01 Exploration North Slope Borough Alaska United States 50-287-20017-00 AK-AM-0005551160 31 Jan, 2008 07:30 hrs 26 Feb, 2008 07:13 hrs 4285' MD; 4284.3' TVD 03 Mar, 2008 3:23 hrs 3016' MD Kickoff P01 06 Mar, 2008 10:10 hrs 3950' MD; 3947.4' TVD 11 Mar, 2007 06:00 hrs True 21.718° 80.013° 57468 nT 29 Jan, 2008 North 69° 26' 29.17" West 151 ° 26' 31.45" Y=5647250.00, X=314531.00 NAD27 Alaska State Planes, Zone 4 215.00' above MSL 195.00' above MSL 17 01N 03E Mike Daigle, Doug Wilson, Danny Kane, Nick Douck Allen Heinrich 110 HALLIBURTON i~ Sperry Drilling Services ' L ER' DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl MUD OGG S 2_ MUDLOGGER' S DAILY SUMMARY Please refer to Daily Operations Activity section for details /time breakdown from Drilling Represenatives Daily report. 30 Jan 2008 Rig up Nabors 105E test diverter and prepare to drill 12 '/4" hole. 31 Jan 2008 Pickup Bit #1 a 12 '/4" HTC EHT-11 with TFA of 0.6470, Drill collars, Jars and HWDP and spud Gubik 3 well at 0645 hrs drilling 12 '/4" hole from 108' MD, Drill to 278' MD and trip out of hole to pickup MWD tools. Samples consisted predominately of large 10-20mm hard angular welded volcanic sandstone fragments for interval 160-220' MD. Some interbedded hard siltstones to 30% of samples seen from 220-278' MD. Average ROP for this drilling interval was 19 ft/hr with drilling parameters WOB 10, RPM 80, SPP 220, GPM 270 with a mud weight of 9.6 ppg. Gas was seen from surface ranging from 1 to 4 units and comprised of methane. Ol Feb 2008 Trip out of the hole ,inspect bit, arrange pipe, Trip in hole and continue drilling from 278' to 478' MD without MWD. Circulate bottoms up. Trip out of hole to pickup MWD at 490' MD, pickup new Bit # 2 a 12 '/4" HTC MXL-1X with TFA of 0.6470, upload MWD. Samples consisted of predominately large 10-20 mm hard angular sandstone and siltstone fragments for interva1280-425' MD. From 425' to 478' MD the samples consisted of softening shale and crystal tuff. Trip gas from 278' MD was 10 units of all methane. Average ROP for this drilling interval was 55 ft/hr with drilling parameters WOB10-20, RPM 85, SPP 490, GPM 565 with a mud weight of 9.6 ppg. Gas ranged from 3-31 units and averaged 7 units composed of methane. 02 Feb 2008 Upload MWD, trip in hole and continue drilling 12 '/4" hole from 478' to 1027' MD increasing mud weight from 9.8 ppg to 10.6 ppg. Trip out of hole to 519' MD and perform MAD Pass with MWD to log hole from 518' MD to 253' MD. Samples consisted of sandstone, siltstone, shale and tuff for interva1478-1027' MD. Trip gas from 478' MD was 17 units of all methane. Average ROP for this drilling interval was 65 ft/hr with drilling parameters WOB 10-20, RPM 88- 105, SPP 1750, GPM 570 with a mud weight of 9.8-10.6 ppg. Gas ranged from 9-38 units and averaged 12 units composed of methane. 03 Feb 2008 Download MWD, laydown BHA, rig up to run casing, run 9 5/8" 40.61b/ft casing 04 Feb 2008 Finish running casing and set same at 1007' MD. Rig up cementing tools, circulate out past shakers and cement as per plan. Nipple down diverter. OS Feb 2008 Nipple up BOP. 06 Feb 2008 Nipple up BOP. 07 Feb 2008 Nipple up BOPand lay down drill pipe. 08 Feb 2008 Pickup 4" 15.7 ppf drill pipe and Test BOP. MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 n 09 Feb 2008 Finish testing BOP's, single in hole picking up drill pipe. 10 Feb 2008 Trip out. Pick up 8 3/4" Bit #3 a HTC MXL-1 with TFA of 0.647, Junk Basket, 6" Drill collars, Jars and 5" HWDP and trip in hole to drill cement. Tag float collar at 926, drill same and cement to 998` MD Increase mud weight to 11.7 ppg. Trip out of hole ,pickup Bit #4 a 8 '/4" HTC DP506X with TFA of 0.460, MWD, mud motor and run in hole. Drill out casing shoe and dri1120' of new formation to 1047' MD. Circulate and condition mud to 13.6 ppg and pull to shoe for leakoff test. 11 Feb 2008 Perform a leakoff test to 21.56 ppg EMW. With 13.6 ppg mud weight. Drill from 1047' to 1278' MD. Samples consisted of sandstone, siltstone, bentonitic claystone, tuff and minor coal for interval 1027-1278' MD. Average ROP for this drilling interval was 17.7 ft/hr with drilling parameters WOB 10-20, RPM 88-105, SPP 2500, GPM 507 with a mud weight of 13.6 ppg. Low average ROP due to drilling 5' and circulating out high gas. Gas ranged from 10-10,000 units (gas detector saturated) and averaged 1000 units composed of C1,C2,C3,Ic4, Nc4, and minor CS's (9-28 ppm ). First presence of C2 noted at 1051' MD. At 1079' MD the gas breakdown was comprised of C1,C2,C3,Ic4, Nc4, and minor CS's, which were seen through this days drilling interval. 12 Feb 2008 Dri118 3/4" hole from 1278' to 1706' MD. Cuttings samples consisted of sandstone, siltstone, tuff and minor shales and coals for interval 1278-1690' MD. Average ROP for this drilling interval was 17.1 ft/hr with drilling parameters WOB 10-20, RPM 105, SPP 2780, GPM 510 with a mud weight of 13.6 ppg. Continued low average ROP due to drilling 5' and circulating out high gas as well as control drilling at 20 fdhr. Gas ranged from 300-10,000 units (gas detector saturated) and averaged 800 units composed of C1,C2,C3,Ic4, Nc4, with CS gases increasing from 26 ppm at 1280' MD to 433 ppm by 1601' MD. 13 Feb 2008 Drill from 1706' to 2000' MD. Perform 4 pumps off for 30 minutes gas influx tests, with results of 5000 units, 2960 units, 4716 units and 4445 units. Increase mud weight to 13.85 ppg. Decision made to continue drilling. Drill from 2000' to 2150' MD. Cuttings samples consisted of siltstone, sandstone, minor shales and claystones for interval 1690- 1860' MD. From 1860 to 1957' MD the cuttings were comprised of shales, sandstones, siltstones and minor coals. From 1957 to 2150' MD, the formation was a massive shale with a silty shale interval from 2070-2147' MD. Average ROP for this drilling interval was 19.1 ft/hr with drilling parameters WOB 10-20, RPM 105, SPP 2800, GPM 476 with a mud weight of 13.8 ppg. Continued low average ROP due to control drilling to maintain 0° inclination as well as 2 slides. Gas ranged from 150-9337 units, averaging 600 units composed of C1,C2,C3,Ic4, Nc4, with CS gases decreasing from 725 ppm at 1763' MD to 2-5 ppm by 1950' MD. The drilling gas averaged at 450 units from 1950' to 2185' MD. 14 Feb 2008 Drill from 2185' to 2628' MD. Short trip 5 stands, circulate out gas-7500 units. Increase mud weight to 14.2 ppg. Shut down pumps for 20 minutes and monitor well. Circulate out 4200 units maximum gas at 1200 strokes. Trip out to 1954' MD, run to bottom and circulate out 3865 units of gas at 1226 strokes. Cuttings samples for this drilling interval consisted of predominately shale with some zones of siltstone, minor sandstone stringers and a tuff and tuffaceous siltstone from 2340-2395' MD. From 2560 to 2628' MD the formation graded from to a silty shale. Average ROP for this drilling interval was 19.9 ft/hr with drilling parameters WOB 10-20, RPM 105, SPP 2700, GPM 476 with a mud weight of 14.0-14.2 ppg. Gas ranged from 170-2856 units, averaging 561 units composed of C1,C2,C3,Ic4, Nc4, with no C5 gases from 2240' MD. The drilling gas averaged at 650 units from 2185' to 2628' MD. 15 Feb 2008 Circulate and condition mud shut down pumps for 20 minutes to observe well, Increase mud weight to 14.4 ppg. Short trip to shoe, monitor well for 2 hours. T.I.H., at 1280' T.I.H. displace mud gas to 400u, stayed at 400u average, at 1951' 2 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl gas increased to 850u avg. until breaking circulation at 2524', at 350 strokes circulation gas began in increase from 850u, ' by 730 strokes gas increased to 10035u "gas detector saturated", (MW 14.4 ppg with mud cut of 13.7ppg) circulating until 1580 stks, gas at 10035u began to decrease., at 3010 stks began to dec., at 3010 stks gas back to background of 260u., Circulate while increasing. mud weight to 14.6 ppg. Large number of cavings came across shakers at 1100 strokes. Cavings size were 3" x 4" and appear to be formation breakout with angular and concave shape. Estimated ' depth of cavings at 1200-1300' MD. 16 Feb 2008 Short trip to shoe, Monitor well-2hrs, TIH to 2523' (avg gas 600u displacing-14.6ppg mud), CBU wash to btm, Gas incr to 7320u at 1113 stks, slow pumps 30spm-90 gpm gas drop to 3125u, incr spm to 45-120 gpm gas incr to 4966u, gas begin decr at 1350 stks, gas to 120u backround by 4201 stks, gas at BU 1023u, circ and incr MW to 15.0 ppg, TOH to 991'- fill hole/5 stds, monitor well-2.5 hrs, TIH to 2520' (gas incr f/ 116u to 716u by 1756' displacing 15.0 ppg mud )( 1100 u bubble at 1373' TIH displace) ,gas avg 700u E 1756' to 2520' displacing 15.0 ppg mud, (1250u bubble at 2138' TIH displace, 980u bubble at 2233' TIH displace) (SEE BELOW), CBU- 90spm/240 gpm gas began to increase at 276 stks increased to maximum of 4690u at 1125 stks. (pump rate decr f/ 240 gpm to 81 gpm at 1105 stks ), at 4500 stks gas dec. to background of 40u. (SEE BELOW), Circulate while raising mud weight to 15.4ppg SHORT TRIP TO 991' MD 02-16-08 15.0 PPG MUD RIH DISPLACEMENT GAS BY STAND: STAND DEPTH MAX GAS 1 991-1088' 116U 2 1088-1183' 222U 3 1183-1277' 301U 4 1277-1373' 364U * AT 1373' -1100U BUBBLE 5 1373-1469' 441U 6 1469-1564' S64U 7 1564-1660' 663U 8 1660-1756' 716U 9 1756-1851' 745U 10 1851-1947' 766U 11 1947-2042' 786U 12 2042-2138' 708U * AT 2138' -1250U BUBBLE 13 2138-2234' 606U * AT 2233' -980U BUBBLE 14 2234-2327' 680U 15 2327-2425' 803U 16 2425-2520' 820U CIRCULATE BOTTOMS UP AT 2520' AND WASH TO BOTTOM BEGIN CIRCULATING AT 40 SPM-107 GPM. AT 276 STKS GAS BEGINS TO INCREASE (GPM 242, SPM 90) AT 470 STKS GAS TO SOOU AT 590 STKS GAS TO 1000U AT 735 STKS GAS TO 2000U AT 895 STKS GAS TO 3000U AT 1065 STKS GAS TO 4000U AT 1105 STKS GAS TO 4500U DECR FLOW RATE TO 81 GPM, 30 SPM AT 1125 STKS GAS TO 4690U (MAXIMUM) AT 1165 STKS GAS TO 3500U AT 1445 STKS GAS TO 3440U INCR FLOW RATE TO 164 GPM, 60 SPM AT 1680 STKS GAS TO 3850U ' MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl AT 2080 STKS GAS TO 2900U AT 2410 STKS GAS TO 1750U AT 2520 STKS GAS TO 1410U (BOTTOMS UP- NO PEAK ) AT 4100 STKS GAS TO 1178U GAS CIRCULATED DOWN TO 100 UNITS BACKROUND BY 5000 STKS ** VERY LITTLE CAVINGS SEEN AT 1125 STKS AND BOTTOMS UP. 17 Feb 2008 Circulate at 2613' while raise MW to 15.4 ppg, shutdown for 30 min, CBU, maximum gas 1001u at 1050 strokes (7.1 min- at 400 gpm), short trip to 989', monitor well for 2 hrs, RIH recording gas from displacement per stand-gas average 350u, 8- fast peaks (bubble) (5 sec duration) (1183'-1350u, 1469'-1160u, 1660'u-1200u, 1851'-1150u, 1947-1100u, 2138'-1296u, 2234'-1500u, 2425'-1100u) (SEE BELOW). ,CBU-88spm-237 gpm, at 140 stks gas began to increase, at 180 stks, gas spike to 1250u (bubble), at 470 stks incr flow rate to spm 140-gpm 376, Gas increase to maximum of 4044u at 1410 stks (SEE BELOW), circ down gas to 120u by 3900 stks, circ gas 60-90u range while increase MW to 16.2 ppg SHORT TRIP TO 989' MD 02-17-08 15.4 PPG MUD 0807HRS MONITOR WELL FOR 2 HRS AT 989' ii RIH DISPLACEMENT GAS BY STAND: STAND DEPTH MAX GAS 1 989-1084' 206U 2 1084-1183' 350U * -1350U BUBBLE (FAST PEAK) 3 1183-1277' 233U 4 1277-1373' 254U 5 1373-1469' 300U * -1160U BUBBLE (FAST PEAK) 6 1469-1564' 301U 7 1564-1660' 310U * -1200U BUBBLE (FAST PEAK) 8 1660-1756' 252U 9 1756-1851' 380U * -1150U BUBBLE (FAST PEAK) 10 1851-1947' 390U * -1100U BUBBLE (FAST PEAK) 11 1947-2042' 348U 12 2042-2138' 380U * -1296U BUBBLE (FAST PEAK) 13 2138-2234' 348U * -1500U BUBBLE(FAST PEAK) 14 2234-2327' 339U 15 2327-2425' 277U * -1100U BUBBLE (FAST PEAK) 16 2425-2520' 238U * NOTE: FAST PEAK-"BUBBLES DURATION 5 SECOND DURATION CIRCULATE BOTTOMS UP AT 2520' AND WASH TO BOTTOM BEGIN CIRCULATING AT 88 SPM-237 GPM. 4 '~~ MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl AT 140 STKS GAS BEGINS TO INCREASE 10 120U (GPM 237, SPM 90) ~ AT 180 STKS GAS SPIKE-BUBBLE TO 1250U ' i AT 320 STKS INCREASE FLOW RATE TO (GPM 360, SPM 135) AT 370 STKS GAS TO 770U AT 470 STKS INCREASE FLOW RATE TO (GPM 376, SPM 140) ' AT 528 STKS GAS TO 1000U AT 780 STKS GAS TO 1500U AT 1006 STKS GAS TO 2000U AT 1138 STKS GAS TO 2500U ' AT 1210 STKS GAS TO 3000U AT 1288 STKS GAS TO 3500U AT 1410 STKS GAS TO 4044U (MAXIMUM) ' AT 1565 STKS GAS TO 3800U AT 1750 STKS GAS TO 2750U AT 1905 STKS GAS TO 1800U AT 2113 STKS GAS TO 1000U AT 2520 STKS GAS TO 310U (BOTTOMS UP- NO PEAK ) GAS CIRCULATED DOWN TO 120 UNITS BACKROUND BY 3900 STKS 18 Feb 2008 Circulate & weight up mud to 16.2ppg. Short trip to 986' MD, monitor well for 2.5 hrs, trip in hole displacing 16.2 ppg mud. Circulate bottoms up. Peak gas of 6998u. (SEE BELOW). Circulate & weight up mud to 16.6 ppg. SHORT TRIP TO 986' MD 02-17-08 16.2 PPG MUD 1000HRS e MONITOR WELL FOR 2.5 HRS AT 986' RIH DISPLACEMENT GAS BY STAND: STAND DEPTH MAX GAS 1 986-1084' 200U 2 1084-1183' 358U * -1200U BUBBLE (FAST PEAK) 3 1183-1277' 274U 4 1277-1373' 440U 5 1373-1469' S30U * -1111U BUBBLE (FAST PEAK) 6 1469-1564' S02U 7 1564-1660' 388U * -1166U BUBBLE (FAST PEAK) 8 1660-1756' S63U ** 9 1756-1851' 729U ** 10 1851-1947' 709U ** 11 1947-2042' 740U ** 12 2042-2138' 840U ** 13 2138-2234' 1032U ** 14 2234-2327' 762U ** 15 2327-2425' 845U ** 16 2425-2520' 639U ** * NOTE: FAST PEAK-"BUBBLES DURATION 2-3 SECOND DURATION ** HIGHER READINGS DUE TO FASTER RUN SPEED TRIP IN HOLE (LARGER VOLUME OF MUD THROUGH GAS TRAP ) 5 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl CIRCULATE BOTTOMS UP AT 2518' AND WASH TO BOTTOM BEGIN CIRCULATING AT 80 SPM-215 GPM. Stroke count taken without subtracting fill up strokes =204 strokes AT 145 STKS GAS BEGINS TO INCREASE TO 170U (GPM 237, SPM 90) AT 175 STKS GAS SPIKE-BUBBLE TO 1200U AT 320 STKS INCREASE FLOW RATE TO (GPM 320, SPM 118) AT 380 STKS GAS TO 750U AT 450 STKS INCREASE FLOW RATE TO (GPM 400, SPM 148) AT 455 STKS GAS TO 1000U AT 572 STKS GAS TO 2000U AT 682 STKS GAS TO 3000U AT 812 STKS GAS TO 4000U AT 895 STKS GAS TO SOOOU AT 972 STKS GAS TO 6000U AT 1141 STKS GAS TO 6998U (MAXIMUM) AT 1290 STKS GAS TO 6000U AT 1425 STKS GAS TO 4800U AT 1629 STKS GAS TO 3000U AT 2075 STKS GAS TO 750U AT 2698 STKS GAS TO 1005U (BOTTOMS UP- PEAK ) GAS CIRCULATED DOWN TO 180 UNITS BACKROUND BY 3580 STKS 19 Feb 2008 Circulate & weight up mud to 16.6 ppg. Short trip to 984' MD, monitor well for 2.1 hrs, Trip in hole displacing 16.6 ppg mud. Circulate bottoms up with peak gas of 7418u at 1042 strokes. (SEE BELOW) .Circulate & at bottom then full trip out. Download MWD and laydown same. Bit #4 a 8 3/4" HTC DP506X made 1601 ft in 49.86 hrs and was graded 1-1-WT-AL-X-I-NO-LOG. ,,, SHORT TRIP TO 984' MD 02-19-08 16.6 PPG MUD 0530HRS MONITOR WELL FOR 2.1 HRS AT 984' RIH DISPLACEMENT GAS BY STAND: STAND DEPTH MAX GAS ' 1 984-1084' 320U * -1200U BUBBLE (FAST PEAK) 2 1084-1183' 360U * -1194U BUBBLE (FAST PEAK) 3 1183-1277' 360U 4 1277-1373' 405U * -1100U BUBBLE (FAST PEAK) 5 1373-1469' 441U 6 1469-1564' 410U * -1100U BUBBLE (FAST PEAK) 7 1564-1660' S09U ** 8 1660-1756' 487U ** 9 1756-1851' 376U 10 1851-1947' 322U 11 1947-2042' 496U 12 2042-2138' 310U * -1100U BUBBLE (FAST PEAK) i 6 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl 13 2138-2234' 358U 14 2234-2327' 355U 15 2327-2425' 350U * -1121U BUBBLE (FAST PEAK) 16 2425-2520' S89U * -1162U BUBBLE (FAST PEAK) * NOTE: FAST PEAK-"BUBBLES DURATION 2-3 SECOND DURATION ** HIGHER READINGS DUE TO FASTER RUN SPEED TRIP IN HOLE (LARGER VOLUME OF MUD THROUGH GAS TRAP ) CIRCULATE BOTTOMS UP AT 2517' AND WASH TO BOTTOM 0650 HRS BEGIN CIRCULATING- AT 80 SPM-215 GPM-STAGE UP. Stroke count taken without subtracting fill up strokes =67 strokes AT 180 STKS GAS BEGINS TO INCREASE TO 150U (GPM 237, SPM 90) AT 245 STKS GAS TO 600U -FLOW RATE (340 GPM, SPM 128) AT 280 STKS GAS TO 1000U - FLOW RATE TO (GPM 220, SPM 83) AT 440 STKS GAS TO 2000U - FLOW RATE TO (GPM 360, SPM 136) AT 490 STKS INCREASE FLOW RATE TO (GPM 400, SPM 148) AT 595 STKS GAS TO 3000U AT 715 STKS GAS TO 4000U AT 840 STKS GAS TO SOOOU AT 932 STKS GAS TO 6000U AT 965 STKS GAS TO 7000U AT 1042 STKS GAS TO 7478U (MAXIMUM) AT 1200 STKS GAS TO 5600U AT 1358 STKS GAS TO SOOOU AT 1501 STKS GAS TO 4000U AT 1631 STKS GAS TO 3000U AT 1779 STKS GAS TO 2000U AT 1980 STKS GAS TO 1000U AT 2200 STKS GAS TO SOOU AT 2775 STKS GAS TO 1026U (BOTTOMS UP- PEAK ) GAS CIRCULATED DOWN TO 170 UNITS BACKROUND BY 3500 STKS 20 Feb 2008 Latdown BHA, mud motor. Pickup new Bit #5 a 8 '/4" HTC L86 with 0.451 TFA and Trip in hole to 1069' MD (SEE BELOW), circulate, pull out of hole, R/U Baker wireline, run wireline logs. TRIP FROM 1069' MD TO BOTTOM 02-20-08 16.6 PPG MUD 0545 HRS TRIP IN FROM 1069' MD AFTER CIRCULATE OUT GAS 8200U AT 1069' MD SEQUENCE OF EVENTS: SHUT DOWN PUMPS FOR 12 MIN -MAKE CONNECTION 1 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 RIH 1 STAND FROM 1169-1265' CIRCULATING AT 60 SPM/ 164 GPM FOR 5.5 MIN 320 STKS- GAS 140 UNITS SHUT DOWN PUMPS FOR 8 MIN -MAKE CONNECTION RIH 1 STAND FROM 1265-1361' CIRCULATING AT 60 SPM/ 164 GPM FOR 6.5 MIN 420 STKS- GAS 142 UNITS SHUT DOWN PUMPS FOR 10 MIN -MAKE CONNECTION RIH 1 STAND FROM 1361-1453' CIRCULATING AT 60 SPM/ 164 GPM BY 980 STKS- GAS 7008 UNITS TRIP IN HOLE FROM 1453' TO BOTTOM GAS ON DISPLACEMENT AVERAGED 180 UNITS TRIP IN FROM 1453' TO BOTTOM CIRCULATE BOTTOMS UP AT 2517' AND WASH TO BOTTOM 0650 HRS FILL PIPE ZERO STROKE COUNT STAGE UP CIRCULATING TO 115 SPM-305 GPM. AT 170 STKS GAS TO 250U (GPM 305, SPM 115) AT 450 STKS GAS TO 240U -FLOW RATE TO (GPM 400, SPM 148) AT 900 STKS GAS TO 370U AT 1000 STKS GAS TO 600U AT 1040 STKS GAS TO 730U AT 1118 STKS GAS TO 1000U AT 1320 STKS GAS TO 2000U AT 1470 STKS GAS TO 2610U (MAXIMUM) DECREASE FLOW RATE TO (GPM 262, SPM 100) AT 1715 STKS GAS TO 1000U -INCREASE FLOW RATE TO (GPM 400, SPM 148) AT 2075 STKS GAS TO SOOU AT 2800 STKS GAS TO 2573U (BOTTOMS UP- PEAK ) AT 3150 STKS GAS TO 400U AT 4300 STKS GAS TO 200U 21 Feb 2008 Continue to run wireline logs. Rig down wireline. Pickup Bit # 6 a 8 3/4" HTC MXI8HDX with TFA of 0.451 and Trip in hole (SEE BELOW), pull out of hole, run wireline. TRIP FROM SURFACE TO BOTTOM 02-21-08 16.6 PPG MUD 0550 HRS TRIP IN TO 1165' MD ON TRIP TANK CIRCULATE BOTTOMS UP AT 1165' AT 0750 HRS BEGIN CIRCULATING AT 56 SPM-150 GPM. ZERO STROKES AT PSI INCREASE- FILL PIPE 111 STROKES AT 112 STKS GAS BEGAN TO INCREASE AT 160 STKS GAS TO 2650U BUBBLE AT 180 STKS GAS TO 506U FLOW RATE TO (GPM 235, SPM 80) AT 280 STKS GAS TO 580U AT 335 STKS GAS TO 480U FLOW RATE TO (GPM 250, SPM 85) L MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 AT 475 STKS GAS TO 1000U AT 650 STKS GAS TO 2000U FLOW RATE TO (GPM 200, SPM 75) AT 755 STKS GAS TO 3000U FLOW RATE TO (GPM 131, SPM 49) AT 800 STKS GAS TO 3422U (MAXIMUM) (GPM 105, SPM 39) AT 828 STKS GAS TO 2500U AT 865 STKS GAS TO 1000U FLOW RATE TO (GPM 136, SPM 50) AT 1101 STKS GAS TO 1000U FLOW RATE TO (GPM 274, SPM 101) AT 1218 STKS GAS TO 700U FLOW RATE TO (GPM 138, SPM 51) AT 1315 STKS GAS TO 300U FLOW RATE TO (GPM 200, SPM 75) AT 1500 STKS GAS TO 200U FLOW RATE TO (GPM 340, SPM 126) AT 1650 STKS GAS TO 200U FLOW RATE TO (GPM 166, SPM 62) AT 2219 STKS GAS TO 170U FLOW RATE TO (GPM 135, SPM 50) AT 3100 STKS GAS TO 130U FLOW RATE TO (GPM 405, SPM 150) RIH CIRCULATING DOWN STANDS FROM 1165' TO 1545' 0845 HRS 1165-1259' 180 U GAS MAXIMUM 1259-1353' 1353-1449' 356 U GAS MAXIMUM 551 U GAS MAXIMUM BUBBLE-1 SEC DURATION= 1850U 1449-1545' 556 U GAS MAXIMUM LARGE CUTTINGS AT SHAKER TRIP IN HOLE FROM 1545' TO 2588' ON TRIP TANK CIRCULATE BOTTOMS UP AT 2588' AND WASH TO BOTTOM 1030 HRS ZERO STROKES AT PSI INCREASE- FILL PIPE 88 STROKES STAGE UP CIRCULATING TO 98 SPM-260 GPM. AT 295 STKS GAS TO 200U (GPM 260, SPM 98) AT 600 STKS GAS TO 590U -FLOW RATE TO (GPM 400, SPM 148) AT 1300 STKS GAS TO 1000U AT 1325 STKS GAS TO 1109U (MAXIMUM) (GPM 400, SPM 148) AT 2798 STKS GAS TO 120U (BOTTOMS UP- NO PEAK ) AT 3000 STKS GAS TO lOSU 22 Feb 2008 Run elogs on Wireline, R/D Wireline, T.LH. to 1277, Circulate bottoms up (SEE BELOW), P.O.O.H. to shoe, Thaw top drive. TRIP IN FROM SURFACE TO 1277' MD 02-22-08 16.6 PPG MUD 1330HRS OUT OF HOLE 1700 HRS 2-21-08 FOR WIRELINE LOGS RUN WIRELINE FORMATION TESTER 10000 UNITS = 100% GAS IN AIR AT SHAKER GAS TRAP RIH DISPLACEMENT GAS BY STAND: FROM 1330 HRS 02-22-08 STAND DEPTH MAX GAS 180' 240U MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 3 267' 360U * -1830U BUBBLE (FAST PEAK) SNGL 297' 220U 1 SNGL 329' 268U SNGL 367' 280U 5 451' 462U ' 6 541' 490U * -4200U BUBBLE (FAST PEAK) 7 630' 467U 8 720' S29U 9 809' S85U * -4000U BUBBLE (FAST PEAK) 10 897' 612U 11 988' 632U 12 1086' 320U * -2553U BUBBLE (FAST PEAK) 13 1181' 441U 14 1277' 434U PULL TO 1183' 190U PULL TO 1085' TO THAW TOPDRIVE * BUBBLE (FAST PEAK) DURATION 1-2 SECONDS CIRCULATE BOTTOMS UP AT 1080' ZERO STROKE COUNT FOR FILL UP/ PSI INCREASE =204 strokes BEGIN CIRCULATING AT 103 SPM-277 GPM. AT 150 STKS GAS BEGINS TO INCREASE TO SOU (GPM 320, SPM120) AT 320 STKS GAS TO 320U -GAS SPIKE-BUBBLE TO 2650U (FAST PEAK) AT 450 STKS GAS 738U- FLOW RATE TO (GPM 304, SPM 113) AT 600 STKS GAS TO 610U AT 750 STKS GAS TO 519U (GPM 304, SPM 113 AT 950 STKS GAS TO 885U (MAXIMUM) AT 1100 STKS GAS TO 797U AT 1200 STKS GAS TO 600U AT 1380 STKS GAS TO 548U (BOTTOMS UP- NO PEAK ) AT 1600 STKS GAS TO 248U AT 2000 STKS GAS TO 115U LEVELED OUT ** NO EXCESS CAVINGS AT SHAKERS 23 Feb 2008 Thaw top drive, R.LH. with Bit 4rr1 a HTC DP506X with TFA of 0.460, mud motor and MWD, Circ bottoms up, (SEE BELOW). Drill ahead to 2830' MD. Let Mud weight reduce to 16.0 ppg. From 2628 to 2750' MD the formation consisted of a light gray moderately hard claystone. From 2750 to 2800' MD a soft to firm volcanic tuff which was underlain by a flaky to blocky shale to 2830' MD. Average ROP for this drilling interval was 35 ft/hr with drilling parameters WOB 30, RPM 80, SPP 3150, GPM 430 with a mud weight of 16.1 ppg. Gas ranged from 44-151 units, averaging 60 units composed of C1,C2,C3 with traces of C4's. RIH DISPLACEMENT GAS BY STAND: FROM 1085' MD - 0920 HRS 2-23-08 10 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 STAND DEPTH MAX GAS 13 1183' 135U 14 1277' 96U 15 1372' 121U 16 1467' 132U 17 1562' 145U CIRCULATE BOTTOMS UP AT 1558' ZERO STROKE COUNT FOR FILL UP/ PSI INCREASE =14 strokes BEGIN CIRCULATING AT 98 SPM-265 GPM. AT 390 STKS GAS TO 200U (GPM 264, SPM 98) AT 700 STKS GAS TO 450U (GPM 320, SPM 118) AT 830 STKS GAS TO 1410U AT 885 STKS GAS TO 2000U AT 1000 STKS GAS TO 2870U AT 1105 STKS GAS TO 3500U AT 1150 STKS GAS TO 3587U (MAXIMUM) AT 1260 STKS GAS TO 3350U AT 1370 STKS GAS TO 3000U (GPM 285, SPM 106) AT 1495 STKS GAS TO 2500U (GPM 269, SPM 100) AT 1607 STKS GAS TO 2000U AT 1820 STKS GAS TO 1000U (BOTTOMS UP- NO PEAK ) AT 2400 STKS GAS TO SOOU AT 2620 STKS GAS TO 1170U (BOTTOMS UP- PEAK?)CHARGE PMP EFF.? AT 2925 STKS GAS TO 620U AT 3335 STKS GAS TO 200U AT 3500 STKS GAS TO 155U LEVELED OUT ** NO EXCESS CAVINGS AT SHAKERS RIH DISPLACEMENT GAS BY STAND: FROM 1558' MD - 1120 HRS 2-23-08 STAND DEPTH MAX GAS 18 1657' l0U 19 1752' l0U 20 1847' l0U 21 1942' 65U 22 2037' 60U 23 2132' lOSU 24 2227' 85U 25 2322' 96U 26 2417' 89U 27 2512' S4U 28 2607' 64U CIRCULATE BOTTOMS UP AT 2616' ZERO STROKE COUNT FOR FILL UP/ PSI INCREASE =78 strokes 11 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPOl ~~ ' BEGIN CIRCULATING AT 111 SPM-301 GPM. AT 1000 STKS GAS TO 190U (GPM 301, SPM 112) AT 1500 STKS GAS TO 220U (GPM 301, SPM 112) AT 2000 STKS GAS TO 85U AT 2785 STKS GAS TO 99U 24 Feb 2008 Drilling from 2830' to 3850'. Reduce mud weight from 16.0 ppg to 15.4 ppg. Gas bubbles 5259u -3086' MD, 5254u-3143' MD, 5006u-3206' MD, 5252u- 3210' MD, 5256u- 3239' MD, SOlOu-3237' MD 4171u-3768' MD, 5253u-3893' MD. Noted that all gas bubbles are from depth at 1200-1250' MD as a result of cuttings containing drilled gas from lower sands passing this up hole formation. Cuttings samples for this drilling interval consisted of siltstone and sandstone zones with minor claystone and shale stringers. Average ROP for this drilling interval was 43 ft/hr with drilling parameters WOB 15, RPM 80, SPP 3350, GPM 430. Gas ranged from 114- 2437 units, averaging 250 units composed of C1,C2,C3,iC4, nC4 with some of CS's noted with gas peaks in sands. See mudlogs and show reports for lithology and gas breakdown details. 25 Feb 2008 Drilling from 3850' to 3883', thaw kelly hose, Drilling from 3883' to 4172' Reduce mud weight from 15.4 ppg to 15.0 ppg. Gas bubbles 5253u -3893' MD, 5200u-3897' MD, 4171u-3984' MD. Noted that gas bubble at 3987' MD from depth at 1200-1250' MD as a result of cuttings (3984' MD) contained drilled gas from lower sand 3984-3987' MD passing this up hole formation. Gas bubbles at 3893' and 3897' MD as aresult of pumps down for inoperable IBOP / thawing top drive hose. Cuttings samples for this drilling interval consisted of claystone and sandstone with a minor tuff. Average ROP for this drilling interval was 45 ft/hr with drilling parameters WOB 20, RPM 80, SPP 3450, GPM 430. Gas ranged from 125-630 units, averaging 200 units composed of C1,C2,C3,iC4, nC4 with some of CS's noted with gas peaks in sands. See mudlogs and show reports for lithology and gas breakdown details. 26 Feb 2008 Drilling from 4172' to 4285' Total Depth. Mud weight at 15.0 ppg. Circulate bottoms up and condition mud. Pull out of hole with 30k over from 4285 to 4145' MD. Backreaming out of hole from 4145 to 3816' MD, tight at 4076-3960-3840' MD. Backreaming out 3816 to 3737' MD. Stuck at 3737', Work Stuck Pipe, jarring down and circulating at 30 spm. Increased pump rate and lost circulation. Pumped LCM pills and reduce mud weight to 14.6 ppg. Made blind backoff at 143' below rotary table, picked up stand and pup joint for clearance. Maximum Circulating Gas on back ream 1276u. Average circulating Gas 100u. Cuttings samples for this drilling interval consisted of siltstone and some claystone at TD. Average ROP for this drilling interval was 20 ft/hr with drilling parameters WOB 20, RPM 80, SPP 3450, GPM 430. Gas ranged from 100-212 units, averaging 150-200 units composed of C1,C2,C3,iC4, nC4 with traces of CS's. 27 Feb 2008 Work stuck pipe, run backoff charge, backoff CBU max gas 1028u, gas bubble SOOOu, losses at 80% at 30gpm. 28 Feb 2008 P.O.O.H., pick up fishing tools, T.I.H. with fishing tools. 29 Feb 2008 Unsucessful in attempt to washover fish, P.O.O.H. to 2850', CBU max gas 461u,P.O.O.H. 2 more stands CBU max gas 707u, P.O.O.H. to 296', T.I.H. for cement. Max gas last 24 hours 9305u '~ ` Ol Mar 2008 T.I.H., cement, P.O.O.H., CBU, max gas 868u, avg. gas 414u, continue to trip out of hole, test B.O.P.'s. Make up new BHA. Pickup Bit # 3rr1 8 3/4" HTC MXL-1. 12 i i~ MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 02 Mar 2008 Run in hole with new BHA. Slip and cut drill line at casing shoe 955', T.LH. 30 STD's, CBU 4705u max gas SSOu avg., wash to fmd hard cement at 3045', P.O.O.H., pick up new bit #6 a HTC HC506ZX with TFA of 0.460, B.H.A with MWD and mud motor. Trip in hole. 03 Mar 2008 Trip in hole. Time drill from 3045' MD to 3063' MD without success. Drill cement in old hole from 3063' to 3080' MD, reattempt to kick off time drilling. Find hard cement at 3096' MD, time dri113096 to 3104' MD. with cuttings samples showing increased formation. 04 Mar 2008 Time Drilling from 3104' to 3116' MD' with cuttings samples showing increased formation. Continue time drilling to 3161' MD, increasing ROP. Rotate and drill from 3161' MD. Kick off point at 3116' MD. Rotate and Slide from 3165' to 3330' MD. Cuttings samples for this drilling interval consisted of siltstone and sandstone. Average ROP for this drilling interval was 40 ft/hr with drilling parameters WOB 5-10, RPM 60, SPP 2500, GPM 450. Gas ranged from 100- 1450 units, averaging 200 units composed of C1,C2,C3,iC4, nC4 with traces of CS's. Once out in new hole gas averaged 100 units while time drilling. Increased ROP and gas increased to 200-400 units. Gas bubble seen at 3135' MD was 5256 units, 3155' MD - 5257 units, 3195' MD 5008u, 4743u. OS Mar 2008 Drilling from 3330' to 3870'. Cuttings samples for this drilling interval consisted of siltstone and sandstone. Average ROP for this drilling interval was 40 ftlhr with drilling parameters WOB 5-10, RPM 60, SPP 2700, GPM 450. Gas ranged from 200-2450 units, averaging 400 units composed of C1,C2,C3,iC4, nC4 with traces of C5's. Gas bubbles seen at 3261' MD - 4463u, 3867u, SOOSu, 3325' MD-5006u ', ~ 06 Mar 2008 Drilling from 3870' to 3950, BPO1 Total depth'. Cuttings samples for this drilling interval consisted of predominately siltstone and a sandstone zone. Average ROP for this drilling interval was 35 ft/hr with drilling parameters WOB 10, RPM 60, SPP 2750, GPM 450. Gas ranged from 400-1150 units, averaging 400 units composed of C1,C2,C3,iC4, nC4 with traces of CS's. Gas bubbles continue from the uphole zone at 1250-1300' MD with circulating out gas peaks. Circulate bottoms up. Short trip to casing shoe. Trip to bottom. Circulatebottoms up. Max gas 10000 units(gas started increasing at 340 strokes). Gas from 3950' was 1020 units. Circulateanother bottoms up. Pu112 stands/tight. Circulate gas. Max gas 2120 units. Trip in hole t/bottom. Pu112 stands. Circulate gas. Max gas 2178 units. Increase mud weight f/13.4 t/13.6 ppg. Trip out. 07 Mar 2008 Trip out. Elog. 08 Mar 2008 Elog. TIH t/985'. Max gas f/disp. W/ TIH 6134 units. Circ. B/U. Gas started increasing at 320 strokes and increased t/10000 units at 750 stks. Gas stayed at 10000 units for 8 minutes. Circ. Until gas fell t/475 units. RIH t/3090'. Max gas f/disp going in hole 2610 units. Circ. B/LJ. Gas started going up at 465 stks. Max gas 10000 units at 1100 stks. Gas stayed up for 15 minutes and fell down t/475 units. RIH t/3905'. Max gas f/disp going in hole 200 units. Circ. B/LT. Max gas 1665 units. Circ. until gas decreased t/120 units. Trip out of hole. Rig up t/test rams 09 Mar 2008 Test BOP's. Rig up and run 7"casing. Max gas at 162' w/running casing 2063 units. Max gas gas at 286' w/run casing 1681 units. Max gas at 374' w/run casing 2089 units. Max gas at 495' w/rumiing casing 2237 units. 13 MUDLOGGER'S DAILY SUMMARY Anadarko Gubik 3 &Gubik 3 BPO1 Circulate at 510' w/n,nning casing max gas 4097 units after 346 strokes. Gas falls back after peaks to 70-200 units. 14 DAILY OPERSTIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPOl 3_ DAILY OPERATIONS ACTIVITY Time Elapsed IADC Operations Breakdown (hrs) Time code GUBIK 3 1 01-30-2008 0:00 - 6:00 6.00 02 P/U 3) 8" DRILL COLLARS AND STAND BACK IN DERRICK - P/U 2) 8" DC'S AND HANG IN ELEVATORS -FUNCTION ANNULAR -LOAD MWD TOOLS AND JARS IIN PIPE SHED -REPAIR ' WEIGHT INDICATOR 6:00 - 12:00 6.00 02 FILL CONDUCTOR, HYDRIL, AND RISER -CHECK FOR LEAKS AND REPAIR SAME -REPAIR HYDRAULIC HOSE ON TOP DRIVE 12:00 - 18:30 6.50 07 CONT. WORKING ON TOP DRIVE, CHANGE HYDRAULIC SERVICE LOOP 18:30 - 19:30 1.00 02 BUILD MUD VOLUME 1 19:30 - 22:00 2.50 07 DRESSER SLEEVE RUBBER FAILED -CHANGE DRESSER SLEEVE AND CHECK THE OTHERS 22:00 - 23:00 1.00 02 LAY DOWN 4' RIG TONGS AND PICK UP 3' RIG TONGS 23:00 - 0:00 1.00 02 MAKE UP BIT SUB, X-O TO DRILL COLLARS -ROTATE INTO 12 1/4" BIT TO CLEAN OUT ' SUSPECTED JUNK (AUGER TOOTH) IN HOLE 01-31-2008 0:00 - 1:30 1.50 02 MAKE UP 12 1/4" BIT AND ADJUST COBRA (E-Z TORQUE) 1:30 - 3:00 1.50 02 LAY DOWN 1) 8" DC & P/U JARS AND 1) 5" HVWT. DP 1 3:00 - 3:30 0.50 02 RIH TAG BTM @ 85' P/U OFF BTM 3:30 - 5:30 2.00 04 BUILD MUD VOLUME AND ADJUST WT. INDICATOR 5:30 - 6:00 0.50 02 TEST SUFACE LINES AND CHECK FOR LEAKS 6:00 - 7:30 1.50 02 WASH DOWN F/ 85' TO 105' 7:30 - 12:00 4.50 02 DRILL FROM 105' TO 141' LOAD 9 5/8" CAS. INTO PIPE SHED (550 GPM - 170 SPM - 350 PSI - 5 ' TO 10 BIT WT. 85RPM - 1 TO 3 TQ) 12:00 - 12:30 0.50 02 CONT. DRLG. FROM 141' TO 150' (550 GPM - 170 SPM - 350 PSI - 5 TO 10 BIT WT. 85RPM - 1 TO 3 TQ) 12:30 - 13:30 1.00 02 TQ. UP AND PACKED OFF AT 150' -ROTATE FREE AND ESTABLISH CIRC. 13:30 - 14:30 1.00 02 DRILL FROM 150' TO 190' (550 GPM - 170 SPM - 360 PSI - 5 TO 10 BIT WT. 85RPM - 1 TO 3 TO) 14:30 - 15:30 1.00 02 TO. UP AND PACKED OFF AT 190' -ROTATE FREE AND ESTABLISH CIRC. 15:30 - 23:00 7.50 02 DP.LG FROM 190' TO 278' -INCREASE VIS (550 GPM - 170 SPM - 365 PSI - 5 TO 10 BIT WT. 85RPM - 1 TO 3 TO) 23:00 - 23:30 0.50 05 POOH FROM 278' TO 190' 23:30 - 0:00 1.00 05 PULLED 5K OVER -SCREWED IN AND ROTATED AND CIRC. PULLED TO BTM OF CONDUCTOR 02-01-2008 0:00 - 0:30 0.50 05 BLOW DOWN TOP DRIVE AND CONT. POOH FRG::"n 190' TO SURFACE 0:30 - 2:00 1.50 05 CLEAN AND INSPECT BIT - P/U 3) 8" DC'S AND RIH TO 278` 2:00 -11:00 9.00 02 DRILL FROM 278' TO 494' - W06=10-15K -VIS= 55-90 MW=9.6-9.7 PSI=400-500 RPM=80-120 SPM=170-180 ROP=12' TO 100' GPM=555 TO 580 11:00 - 11:30 0.50 04 CIRCULATE HOLE CLEAN AND BLOW DOWN TOP DRIVE 11:30 - 12:00 0.50 05 POOH FROM 494' TO 403' SWABBED ~ 399' -BACK REAMED TO 313' 12:00 - 15:00 3.00 05 BACK REAMED TO 124' WORK TOOLS UP FROM 124' TO SURFACE - NO MUD RINGS OR SCARS ON BHA 15:00 - 16:00 1.00 06 CHANGE OIL IN TOP DRIVE AND ADJUST SPERRY HEIGHT ENCODER 16:00 - 21:30 5.50 05 PICK UP MWD TOOLS AND' BHA 21:30 - 23:00 1.50 05 LOAD DATA INTO MWD 23:00 - 0:00 1.00 05 LOAD NIKLEAR SOURCES INTO MV1+D 02-02-2008 0:00 - 1:00 1.00 05 MAKE UP STAB AND NON MAG FLEX COLLAR ATTEMPT TO RUN IN HOLE TAKING WEIGHT@ 170' LAY DOWN FLEX COLLAR AND PICK UP STAND OF HVYWT 1:00 - 2:00 1.00 03 REAM FROM 147' TO 244' (50 RPM - 80 SPM - 700 PSI) 2:00 - 2:30 0.50 05 POOH 244' TO 147' 2:30 - 3:00 0.50 05 TEST MWD AND STAND BACK HVYWT 3:00 - 4:00 1.00 05 M/U 3) FLEX COLLARS AND JARS 4:00 - 4:30 0.50 05 FUNCTION TEST MWD (GOOD) 4:30 - 6:30 2.00 03 REAM FROM 244' TO 494' (5' FILL ON BOTTOM) 6:30 15:00 8.50 02 DRILL 12 1/4" HOLE FROM 494' TO 849' (SPM=170 GPM=544 PSI=1400 WOB=20 TQ= 3 RPM=90ROP= 40 - 120 15:00 - 15:30 0.50 07 CHARGE PUMP MOTOR FAILED CHANGE OVER TO MUD MIX PUMP 15:30 - 20:00 4.50 02 DRILL WITH #1 MUD PUMP FROM 849' TO 1027' (WHILE REPAIRING CHARGE PUMP) 20:00 - 21:00 1.00 04 CIRC. HOLE CLEAN FOR SHORT TRIP 21:00 - 23:00 2.00 05 POOH FROM 1027' TO 716' PULLED 10K OVER REAMED UP TO 518' (SPM=60 I DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPO1 Time Elapsed IADC Operations Breakdown (hrs) Time code PSI=475 RPM=50) 23:00 - 0:00 1.00 03 MAD PASS FROM 518' TO 253' @ 200' PER HOUR (SPM=50 PSI=350 RPM=50) 02-03-2008 0:00 - 2:00 2.00 03 MAD PASS FROM 428' TO 248' BLOW DOWN TOP DRIVE. 2:00 - 3:00 1.00 05 R.I.H FROM 248' TO 966' CHANGE ELEVATORS TO 4" 3:00 - 3:30 0.50 02 WASH DOWN FROM 966' TO 1027' (NO FILL) 3:30 - 4:30 1.00 04 CIRC HOLE CLEAN @ 170-SPM, 1300- PSI, 80- RPM 4:30 - 5:00 0.50 05 BLOW DOWN TOP DRIVE POOH FROM 1027' TO 966' CHANGE ELEVATORS TO 5" 5:00 - 6:00 1.00 05 CONT TO POOH FROM 966' TO 150' (NO DRAG) 6:00 - 8:00 2.00 05 STAND BACK HWDP WITH JARS AND 1 STAND OF FLEX COLLARS. LAY DOWN STAB 8:00 -.13:00 5.00 05 PJSM UNLOADING NUKES DOWN LOAD TOOLS AND LAY DOWN BHA. 13:00 - 21:30 8.50 11 RIG UP CASING EQUIP AND STABBING BOARD 21:30 - 0:00 2.50 11 PJSM RUN 9 5/8" CASING AS PER PROGRAM ' 02-04-2008 0:00 - 4:00 4.00 11 RUN 9 5/8" 40# CAS. FROM 121' TO 1007' 2 CENTRALIZERS ON FIRST 2 JOINTS AND EVERY 3RD JOINT THERE AFTER 4:00 - 6:30 2.50 04 RIG UP CIRC. 2 CAS. VOLUMES @ 50 SPM, 325 PSI, 160 GPM RIG DOWN CIRC e LINES. 6:30 - 8:00 1.50 11 RIG DOWN CAS. EQUIPMENT 8:00 - 10:00 2.00 11 REMOVE STABBING BOARD. 10:00 - 13:30 3.50 05 R.I.H WITH 4" DP AND SCREW IN SUB SPACE OUT AND SCREW INTO FLOAT 13:30 - 15:30 2.00 04 CIRC. WITH RIG PUMP 90 SPM LOST CIRC WHEN HANGER BYPASS PORTS PLUGGED.LOST 126 BBLS TO FORMATION 15:30 - 16:00 0.50 04 RIGGED HOSES FROM CONDUCTOR TO SHAKERS 16:00 - 18:00 2.00 04 CIRC. WITH RIG PUMP @ 25 SPM AND HELD PJSM TAKE ON CITRIC PILL IN VAC TRUCK 18:00 - 0:00 6.00 11 PRESSURE TEST LINES TO 3000 PSI. PUMP 38 BBLS MUD PUSH @ 10 PPG 127 BBLS LEAD CEMENT @ 10.7 PPG, 23 BBLS TAIL CEMENT @ 15.8 PPG DISPLACE 1 WITH 10.4 PPG MUD WITH RIG PUMP 9.7 BBLS, CEMENT IN PLACE @ 2020, FLOATS HELD. BACK OUT CIRC SUB,PUMP FOAM BALL, CIRC. 2 BTM UP, RIG DOWN LINES. 02-05-2008 0:00 - 1:00 1.00 05 POOH WITH 4" DP AND STAND BACK IN DERRICK -LAY DAWN SCREW IN SUB 1:00 - 9:00 8.00 13 LAY DOWN LANDING JT. -NIPPLE DOWN DIVERTER LINE AND RISER AND REMOVE FROM CELLAR 9:00 - 15:30 6.50 13 NIPPLE UP WELLHEAD EQUIPMENT AND TEST TO 4800 PSI FOR 15 MIN (GOOD TEST) -CLEAN PITS WHILE NIPPLING UP 15:30 - 0:00 8.50 13 NIPPLE UP BOP'S 02-05-2008 LL KILL LINE 0:00 - 12:00 12.00 13 , LAND HYDRIL AND TAKE MEASUREMENT FOR BELL NIPPLE -INSTA HCR, AND MANUAL -INSTALL BELL NIPPLE AND TURN BUGKLES -CLEAN PITS 12:00 - 0:00 12.00 13 INSTALL ACCUMULATOR LINES TO BOP"S -INSTALL CHOKE LINE AND HAMMER UP ALL BOLTS ON BOP'S -BLIND RAM BLOCKS NOT RETRACTING BACK INTO BONNETS FULLY -REMOVE RAM BLOCKS AND INSTALL WEAR BUSHING 02-07-2008 0:00 - 13:00 13.00 05 LAY DOWN DC'S FROM DERRICK -LOAD PIPE SHED WITH 8 3/4" BHA AND PICK UP AND RUN IN HOLE -PICK UP 4" DP AND RUN IN HOLE TO 800' ' 13:00 - 14:30 1.50 04 CIRCULATE HOLE AND ROLL MUD OVER -BLOW DOWN TOP DRIVE 14:30 - 16:30 2.00 05 POOH FROM 800' TO 300' 16:30 - 17:30 1.00 07 OPEN BLIND /SHEAR DOORS ON BOP'S AND TAKE MEASUREMENTS RETIGHTEN ' 17:30 - 19:30 2.00 05 BOLTS POOH FROM 300' TO SURFACE 19:30 - 21:00 1.50 07 REMOVE MANUAL LOCKS FROM BLIND /SHEARS AND INSTALL RAMS AND FUNCTION (FUNCTIONED PROPERLY) 21:00 - 0:00 3.00 05 PICK UP 4" DP FROM PIPE SHED AND STAND BACK IN DERRICK SLM 1 02-08-2008 2 DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 SPOT Time Elapsed IADC Operations Breakdown 1 (hrs) Time code 0:00 - 6:00 6.00 05 PICK UP 21 STD. DP AND STAND BACK IN DERRICK 6:00 - 7:00 1.00 13 CENTER UP BOP'S 7:00 - 8:00 1.00 13 PULL WEAR BUSHING 8:00 - 11:00 11:00 - 13:30 3.00 2.50 13 13 FULL BODY TEST ON BOP'S AND CHOKE MANIFOLD FILL STACK AND CHOKE WITH HOT WATER AND RIG UP TEST PUMP TO TEST BOP'S ANDCHOKE -WITH STATE MAN 13:30 - 15:30 2.00 13 TEST TOP VBR'S /CHOKE HOSE AND HCR ON KILL LINE 250 LOW & 5000 HI -LEAK ON CHECK VALVE 15:30 - 17:30 2.00 13 TIGHTEN UP LEAKS ON CHECK VALVE AND ADAPTER FLANGE TO WELL HEAD 17:30 - 18:00 0.50 13 RETEST SAMIE 250 / 5000 GOOD TEST 18:00 - 0:00 6.00 13 TEST BOTTOM RAMS(VBR) -CHOKE AND KILL HCR -MANUAL CHOKE AND KILL VALVES -VALVES 1 THROUGH 6 ON CHOKE MANIFOLD - 250/ 5000 - 02-09-2008 0:00 - 0:30 0.50 07 CONTINUE WORK ON SUPER CHOKE 0:30 - 2:30 2.00 13 TEST CHOKE VALVES 250/5000 2:30 - 4:00 1.50 13 INSTALL SPACERS ON BLIND -REPOSITION CHECK VALVE ' 4:00 - 8:30 4.50 13 RIG DOWN TEST JT WITH CIRC. HEADPIN -RIG UP & TEST FLOOR VALVE & DART VALVE -TEST BLINDS & CHECK VALVE 8:30 - 10:30 2.00 13 LAY DOWN TEST JT -PULL TEST PLUG SET WEAR BUSHINIG -BLOW DOWN CHOKE -TEST RUN MANUAL LOCKS ON BLINDS 10:30 - 12:00 1.50 13 R.I.H. WITH STD 5" HWDP & BREAK DOWN SAME TO TEST VBR WITH 5" -PULL WEAR BUSHING 12:00 - 15:00 3.00 13 TEST UPPER VBR WITH 5" -SET WEAR BUSHING 15:00 - 17:30 2.50 05 T.I.H. TO 742' 17:30 - 19:30 2.00 11 RIG UP HEAD PINTO TEST CSG. -TEST TO 3000 PSI 19:30 - 20:00 0.50 05 R.I.H. WITH 2 STD HW TO 917' 20:00 - 0:00 4.00 06 CHANGE SAVER SUB ON TOP DRIVE TO XT39 & CHANGE DIES ON GRABBER. 02-10-2008 0:00 - 0:30 0.50 02 CONN @ 920" -BREAK CIRC. TAG FLOAT COLLAR @ 926' 0:30 - 5:30 5.00 02 DRILLED FLOAT COLLAR AND CEMENT TO 998' 5:30 - 8:00 2.50 04 CIRC. & CONDITIOIN MUD -PUMP 2 HI VIS SWEEPS TO PICK UP JUNK 8:00 - 8:30 0.50 05 STD BACK 1 STD OF 4" DP -BREAK OUT X-OVER -BLOW DOWN TOPDRIVE 8:30 - 11:30 3.00 05 POOH -BREAK OFF BIT & JUNK BASKETS -COUPLE OF SMALL CHUNKS OF METAL SNAP RING AND TWISTED UP COPPER BRAZING 11:30 - 12:00 0.50 05 P/U TOOLS FaR NEXT BHA -CLEAN RIG FLOOR 12:00 - 13:30 1.50 06 SERVICE TOff'DRIVE 13:30 - 15:00 1.50 05 MAKE UP BIT, MOTOR &MWD 15:00 - 16:00 1.00 05 DOWNLOAD ®ATA FOR MWD 16:00 - 18:00 2.00 05 MAKE UP REST OF BHA 18:00 - 19:00 1.00 05 TEST MWD - BLOWDOWN TOPDRIVE 19:00 - 21:00 2.00 05 R.LH. WITH HNNDP, TAG UP ON FLOAT COLLAR @ 926' HAD TO ROTATE THROCJGH 21:00 - 22:00 1.00 07 DRILLING CE)~IIENT. TROUBLE WITH PUMP PSI HOLDING STEADY, FLUCTUAT[NG FROM 1250 TO 800- CHECK PUMPS AND SURFACE EQUIPMENT 22:00 - 23:00 1.00 02 DRILLED FLOAT SHOE AND RAT HOLE & 20 NEW HOLE DOWN TO 1047 23:00 - 0:00 1.00 04 CIRC. & CON~3ITION FOR LEAK OFF, PULL INTO SHOE AND STAND BACK STD. ,BLOW DOWN TOP DRIVE 02-11-2008 0:00 - 3:30 3.50 14 RIG UP DOWELL & PERFORM L.O.T. EMW= 21.3 PPG 3:30 - 4:00 0.50 06 SERVICE RIG -GREASE SWIVEL PACKING TDS 4:00 - 12:00 8.00 04 BUILD MUD WEIGHT TO 13.6 PPG -CIRC. @ 2 BPM WHILE WEIGHTING UP 12:00 - 13:00 1.00 17 HOLD PRE JOB SAFETY MEETING -RUN SAFETY DRILLS 13:00 - 14:00 1.00 02 START DRILLING @ 1047 CIRC- GAS 9000 UNITS 14:00 - 15:00 1.00 02 DRILL TO 1150 CIRC GAS 5000 UNITS 15:00 - 16:00 1.00 02 DRILL TO 1242 CIRC GAS 5500 UNITS 16:00 - 17:00 1.00 02 DRILL TO 1245 CIRC GAS 4000 UNITS 17:00 - 18:00 1.00 02 DRILL TO 1249 CIRC GAS 3800 UNITS 18:00 - 19:00 1.00 02 DRILL TO 1252 CIRC GAS 2800 UNITS 19:00 - 20:00 1.00 02 DRILL TO 125Ni CIRC GAS 1300 UNITS 20:00 - 21:00 1.00 02 DRILL TO 1265 CIRC GAS 6800 UNITS 21:00 - 22:00 1.00 02 DRILL TO 1270 CIRC GAS 4000 UNITS 22:00 - 23:00 1.00 02 DRILL TO 1277 CIRC GAS 5760 UNITS 23:00 - 0:00 1.00 02 DRILL TO 1285 CIRC GAS 7500 UNITS DAILY OPERATIONS ACTIVITY ANADARKO - GiFBIK 3 & GUBIK 3 BPOl Time Elapsed IADC Operations Breakdown Ihrsl Time code 02-12-2008 0:00 - 7:30 7.50 02 DRILLED FROM 1285' TO 1343' (GAS 400 - 1 01000 UNITS) CHECKED BACKGROUND GAS @ 1290' 1300' 1326' 1343' (400 - 750) 7:30 - 12:00 4.50 02 DRILLED FROM 1343' TO 1497 (CANNECTIOrN GAS @ 1376 400 UNITS)(CONNECTION GAS @ 1472 8600 UNITS) SLIDE DRILL FROM 1435' TO 1450' 12:00 - 18:00 6.00 02 DRILLED FROM 1497 TO 1590' -TIGHTENED BELTS ON #2 MUDPUMP 18:00 - 18:30 0.50 02 SLIDE DRILL FROM 1590' TO 1610' 18:30 - 0:00 5.50 02 DRILLED FROM 1610' TO 1706' 02-13-2008 0:00 - 5:30 5.50 02 DRILL FROM 1706' TO 1800- DRILLING 4' TO 10' SECTIONS DEPENDING ON UNITS OF GAS, CIRCULATE GAS OUT WHEN GAS GOT ABOVE AVRAGE BACK GROUND OF 400 TO 600 UNITS -MAX. GAS OBSERVED WAS 9977 Uh81TS - 5:30 - 10:00 4.50 02 DRILL FROM 1800' TO 2000' -BACK GROUND GAS STABLIZED ENOUGH TO ALLOW DRILLING 10 TO 50 ' OF NEW HOLE BEFORE CIRCULATING OUT GAS.- MAX- GAS CIRCULATED OUT WAS 2166 UNfTS -CIRCULATE BOTTOMS UIP AND MONITOR WELL BEFORE CONNECTIONS /ALSO CHECK WELL BORE AFTER CONNECTION -CONNECTION GAS AT 1857 WAS 3850 UNITS - CONN-GAS @ 1955' WAS 4000 UNITS- SLIDE FROM 1857' TO 1882' & 1955' TO 1970' 10:00 - 10:30 0.50 04 CIRCULATE AVID CONDITION HOLE FOR WIPER TRIP 10:30 - 12:00 1.50 05 PUMP OUT OF THE HOLE SLOW AT 250 GPM -BACK GROUND GAS WAS 3900 UNITS -R.I.H. CIRCULATING STANDS DOWN 12:00 - 14:00 2.00 04 CIRCULATE AVID RAISE MUD WEIGHT UP FROM 13.6 TO 13.8 -SHUT PUMPS DOWN FOR 20 MINS. AND CHECK FOR FLOW SOME GAS BREAKING OUT CAUSING FLOW. START PUMPS BACK UP GAS UNITS 5000 14:00 - 16:00 2.00 04 FLOW CHECK FOR 20 MINS. STILL SOME GAS BREAKING OUT IN BUBBLES TURN PUMPS BACK ON CIRC_ BOTTOMS UP 4800 GAS UNffS 16:00 - 17:00 1.00 04 WEIGHT UP ML1D FROM 13.8 TO 14.0 17:00 - 17:30 0.50 04 SHUT PUMPS DOWN FOR 30 MINS. MONIT~ WELL. OBSERVED SOME FLOW DUE TO GAS BUBBLES 17:30 - 18:30 1.00 04 CIRC. WELL 4500 UNITS OF GAS ON PUMP STARTUP 18:30 - 19:30 1.00 02 DRILLED FROM 2000' TO 2053' 475 UNITS OF BACKGROUND GAS 19:30 - 21:00 1.50 06 SERVICE RIG AND TOP DRIVE 21:00 - 0:00 3.00 02 CONTROL DRILLED FROM 2053' TO 2149' CIRC. BOTTOMS UP BEFORE AND AFTER CONNECTIONS. WELL STATIC AFTER CONNECTION. @ 2053' HAD GAS @ 2500 UNITS, AFTER PUMP STARTUP. @ 2148' HAD GAS ~ 1200 UNITS 02-14-2008 0:00 - 4:00 4.00 02 DRILLED FROM! 2185' TO 2338' HAD BACKGROUND GAS FROM 450 - 600. CONNECTION GAS @ 2244' / 1950 UNITS. CONNECTION GAS @ 2338' 2900 UNITS 4:00 - 4:30 0.50 02 SLIDE FROM 2338' TO 2348' 4:30 - 11:00 6.50 02 CONTINUE DRILLING FROM 2348' TO 2628' 11:00 - 12:30 1.50 04 CIRC. BOTTOMIS UP. OBSERVED GAS BREAKING OUT AT SURFACE 12:30 - 13:30 1.00 05 TRIP OUT OF THE HOLE WITH 5 STANDS - LAST STAND PULLED TIGHT @ 2241- WAS ABLE TO WORK THROUGH WHILE PUMPING 13:30 - 14:30 1.00 05 RUN BACK IN HbOLE -REAM LAST 2 STANDS DOWN - 7500 UNITS Of GAS BACK ON BOTTON 14:30 - 19:00 4.50 04 CIRCULATE HO~.E AND RAISE MUO WEIGHT FROM 14 TO 14.2 -MIXING AT 30 SECONDS A SACK 19:00 - 20:30 1.50 04 CIRCULATE MUID AROUND- SHUT DOWN PU1t+/1PS FOR 20 MINUTES AND MONITOR WELL - GAS BREAKING OUT AT SURFACE CAUSING SLIGHT FLOW -CIRCULATE BOTTOMS UP - 4200 UNITS OF GAS AT 1200 STROKES -MONITOR WELL FOR 20 MINUTES -SOME GAS BREAKING OUT NO FLOW DETECTED 20:30 - 23:00 2.50 05 PULLED 7 STAIWDS UP TO 1954' -'VISUALLY MONITORING WELL BORE WHEN PULLING FIRST 5 STANDS -LINE UP TRIP TANK FOR NEXT 2 STANDS -LEAVE WELL ON TRIP TANK WHEN RUNNING BACt~( IN HOLE -GOOD HOLE FILL .AND NO TIGHT SPOTS 23:00 - 0:00 1.00 04 CIRCULATE BCitTTOMS UP - 3865 UNITS OF GAS AT 1226 STROKES -BACK GROUND GAS STABLIZED 36® TO 400 02-15-2008 0:00 - 1:30 1.50 04 CIRCULATE & CONDITION MUD, SHUT DOWN & OBSERVE WELL FOR 20 MIN. SLIGHT FLOW DUE TO GAS BREAKING OUT OF MUD -1300' UNITS 1:30 - 4:00 2.50 04 CIRCULATE & CONDITION MUD -BIUILD MUD WEIGHT 14.2 PPG - 14.4 PPG 4:00 - 4:30 0.50 04 SHUT DOWN & OBSERVE WELL FOR 20 MIN_ BLOW DOWN TOP DRIVE 4:30 - 8:00 3.50 05 PULL 17 STANDS UP INTO THE SHIOE 2627' - 1000' (PULLED 25K OVER @ 1599', 1250', 1205' AND 1170') WORKED BACK THROUGH THESE AREAS AND THEY CLEARED UP. t r ' DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 & GUBIK. 3 BPOl Time Elapsed IADC Operations Breakdown (hrs) Time code 8:00 - 10:00 2.00 06 OBSERVE WELL. CHANGE OUT STABBING GUIDE /LOWER SAVER VALVE /GREASE WASHPIPE,TOP DRIVE & BLOCKS /ADJUST LINK TILT ON BALES 10:00 - 12:00 2.00 05 TRIP IN HOLE TO 1280' DISPLACEMENT /GAS TO 400 UNITS. REMAINED AT 400 UNITS UNTIL. 1950' -GAS INCREASED TO 850 UNITS AND REMAINED AT 850 UNITS AVERAGE ON DISPLACEMENT. MADE UP TOP DRIVE BROKE CIRCULATION @ 2535'. CIRC OUT. AT 325 STKS GAS BEGINS TO INCREASE. AT 730 STKS GAS INCREASES TO 10035 UNITS FOff2 850 STKS 7 MIN. GAS CUT MUD WT WAS 13.7 BACKGROUND GAS REDUCED TO 260 UNITS. WASHED BOTTOM ~ 2628' 12:00 - 22:00 10.00 04 CONDITION MUD /INCREASE MUD WT FROM 14.4 TO 14.6 /PUMP # 2 WASHED OUT A SWAB CHANGED OUT PUMPLINERS FROM 6" TO 5.5 " SWITCHED TO PUMP # 1 AND CHANGED OUT PUMPLINERS FROM 6" TO 5.5 " 22:00 - 22:30 0.50 04 MONITORING WELL /BACKGROUND GAS 260 UNITS. LARGE NUMBER OF CAVINGS GAME ACROSS SHAKERS @ 1100 STROKES. CUTTINGS RANGED UP TO 3" X 4". APPEARS TO BE FORMATION BREAKOUT. SHAPE OF SAMPLES ARE ANGULAR AN® CONCAVE. 22:30 - 0:00 1.50 05 TRIP OUT OF HOLE, BLOW DOWN TOP DRIVE ' 02-16-2008 0:00 - 1:30 1.50 05 POH UP INTO SHOE. GOOD HOLE FILL, NO TIGHT SPOTS 1:30 - 2:00 0.50 08 MONITOR WELL /GAS BUBBLES STILL BREAKING OUT CAUSING SLIGHT DROP IN WELL BORE 2:00 - 3:00 1.00 04 PIT WATCHER NOTICED WASH WATER BEING PUMPED INTO PITS, REDUCING MUD WT TO 14.5. MIXED BAR TO RAISE WT BACK TO 14.6. HELD MEETING ABOUT THIS. 3:00 - 4:30 1.50 05 TRIP INTO HOLE 999' - 2620' (NO PROBLEMS) BACKGROUND GAS PEAKED @1250' MD / 1100 UNITS 4:30 - 7:00 2.50 04 CIRCULATE & CONDITION - 11.2 BBLS TO FILL PIPE / 32 BBLS PUMPED (GAS UNITS BI=GIN INCREASING AND PEAKED @ 7168 UNITS -MAXIMUM MUD CUT 12.9 PPG 7:00 - 11:00 4.00 04 INCREASE MUD WT FROM 14.6 TO 15.0 PPG 11:00 - 11:30 0.50 04 SHUT DOWN PUMPS FOR 20 MIN AND OBSERVE WELL 11:30 - 12:00 0.50 04 CIRCULATE BOTTOMS UP / AT 870 STROKES HAD 330 UNITS OF GAS, BACKGROUND GAS WENT DOWN TO 60 UNITS /GAS PEAK @ 331 UNITS 12:00 - 14:30 2.50 05 POH /FILL HOLE AT 5 STDS OUT /CALCULATED FILL 47 STK, 36BLS. HOLE TOOK 46 STKS TO FILL. STAND # 10 HOLE TOOK 29 STKS, 1.9 BBLS TO FILL. STAAVD # 15 TOOK 33 STKS, 2.1 BBLS TO FILL. POH TO SHOE 14:30 - 16:30 2.00 04 OBSERVING WELL /SERVICE TOP DRIVE 16:30 - 18:30 2.00 05 RUN IN HOLE -MAKE UP TOP DRIVE AND FILL PIPE @ 2532 (23 BBiLS) AND WASH TO BOTTOM 18:30 - 19:30 1.00 04 CIRCULATE BOTTOMS UP AND MONITOR GAS MAXIMUM GAS PEAKED AT 4400 UNITS AT 1100 STKS. -TOTAL STi20KES INCLUDE 359 STKS. TO FILL THE PIPE -MAXIMUM MUD CUT WAS 13.7 -GAS UNITS DOWN TO 98 AT 5200 STROKES 19:30 - 0:00 4.50 04 CIRCULATE HOLE AND RAISING MUD WEIGHT FROM 15.0 TO 15.4 PPG. 02-17-2008 0:00 - 3:00 3.00 04 3:00 - 3:30 0.50 08 3:30 - 6:00 2.50 05 6:00 - 8:00 2.00 08 8:00 - 9:30 1.50 05 9:30 - 12:00 12:00 - 0:00 2.50 04 12.00 04 INCREASE MUD WT 15 PPG TO 15.4 PPG SHUT DOWN PUMPS AND OBSERVE WELL FOR 20 MIN / SM AMTS OF GAS BREAKING OUT AT SURFACE. SHORT TRIP FROM 2627 - 990' / NO TIGHT SPOTS OR DRAG /CALCULATED FILL 47 STKS, 3 BBLS / 1ST 5 STDS OUT OF HOLE TOOK 4 BBLS /NEXT 5 STDS TOOK 3.5 BBLS /LAST 5 STDS TOOK 3.5 BBLS. OBSERVE WELL FOR 2 HRS /HOLE WAS STATIC AND DROPPED 5 " IN BELL NIPPLE. a SMALL AMT OF GAS BUBBLED UP. TRIP IN HOLE FROM 990' TO 2627' - DISPLACMENT OF FLUID - 1ST 5 STDS IN HOLE DISPLACED 4.2 BBLS, NEXT 5 STANDS 3.0 BBLS AND LAST 5 STANDS DISPLACED 3.fi BBLS. HOLE IN GOOD SHAPE - NO DRAG AND NO FILL ON BTM. BROKE CIRC / AT 525 STKS GAS WAS 1000 UNITS / AT 1410 STKS GAS MAXED OUT AT 4044 UNITS AND WAS GAS CUT FROM 15.4 TO 14.1 PPG / BACKGROUN'C GAS WENT DOWls9 TO 70 UNITS AT 2500 STKS . CIRCULATE AND START RAISING MUD WEIGHT FROM 15.4 TO 16.2 (AT MIDNIGHT MUID WT WAS 15.8 PPG) 02-18-2008 0:00 - 4:00 4.00 04 4:00 - 4:30 0.50 04 4:30 - 5:00 0.50 04 :00 - 7:30 .50 CONDITION AND WEIGHT UP MUD FROM 15.6 TO 16.2 PPG MONITOR WELL FOR 20 MINS. -GAS BUBBLES BREAKING OUT - NO FLOW DETECED CIRCULATE BOTTOMS UP -MAXIMUM GAS PEAKED AT 549 UNITS 05 PULL UP INTO SHOE @1007 - 17 STANDS PULLED - NO DRAG ENCOUNTERED -HOLE FILL WAS 1.4 BBLS. OVER CALCULATED -SOME MUD WAS LOST WHEPJ BREAKING OFF WET i DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPOl Time Elapsed IADC Operations Breakdown (hrs) Time code PIPE 7:30 - 9:30 2.00 08 HOLE FULL / IN 30 MINS MUD DROPPED 5" IN BELL NIPPLE. NEXT 30 M/I`1S MUD DROPPED TO 9" .NEXT 30 MINS MUD DROPPED TO 14 ". NEXT 30 MINS MUD DROPPED TO 22" ,WHICH WAS THE MAXIMUM DROP 9:30 - 9:45 0.25 05 BREAK OUT TOP DRIVE AND RIG UP TO RIH 9:45 - 11:15 1.50 05 RIH FIRST 5 STDS DISPLACED 5 BBLS /NEXT 5 SIDS DISPLACED 6.3 BBLS /NEXT 5 STANDS DISPLACED 5 BBLS. CALCULATED DISPLACEMENT 6.7 BBLS. HOLE IN GOOD SHAPE - NO FILL ON BOTTOM. 11:15 - 12:00 0.75 04 MADE UP TOP DRIVE /FILL PIPE W/ 205 STKS /BROKE CIRC /CBU / AT 572 STKS GAS AT FLOW LINE 2000 UNITS /GAS CUT MUD 16.0 PPG. AT 1141 STKS GAS PET FLOW LINE 7000 UNITS. (MAX GAS) MUD WT WAS 15.2 GAS CUT. AT 2698 STKS BOTT014OS UP /GAS AT FLOW LINE 1000 UNITS. MUD WT 15.6 PPG. AT 4000 STKS MUD WT 16.0 PPG 6 BACKGROUND GAS 120 UNITS - 60 UNITS. 12:00 - 15:00 3.00 12 CONFERRING WITH MANAGEMENT WHILE CIRCULATING THE WELL 15:00 - 0:00 9.00 04 INCREASE MUD WT FROM 16.2 TO 16.6 PPG /PUMP 150 SPM = 404 GPM 02-19-2008 0:00 - 0:30 0.50 04 CONTINUE TO RAISE MUD WT FROM 16.2 TO 16.6 PPG. -OBTAIN SLOW PUMP RATE WITH 16.6 MUD WT. 0:30 - 1:30 1.00 05 OBSERVE WELL FOR 20 MINS /CBU, AT 1100 STKS HAD 1300 UNITS OF GAS (MAX GAS). 1:30 - 3:30 2.00 05 BLOW DOWN TOP DRIVE / POH TO SHOE AT 1007`,! THE HOLE FILL WAS 2.2 OVER CALCULATED, CALCULATED FILL IS 10.2. HOLE CONDITION WAS GOOD. 3:30 - 5:30 2.00 08 OBSERVE WELL FOR 2 HRS, FLUID DROPPED 6" IN BELL NIPPLE. 5:30 - 7:00 1.50 05 RIH TO BOTTOM @ 2627', AT 7 STANDS IN HOLE 5®9 UNITS OF GAS / AT 11 STDS IN HOLE 496 UNITS OF GAS ! AT 16 STDS IN HOLE 589 UNITS OF GAS /DISPLACED THE CORRECT AMOUNT OF FLUID (3 BBLS PER 5 STANDS) HOLE IN GOOD SHAPE - N® FILL ON BOTTOM. '~^^ 8:30 1.5C 04 .~~ - MADE UP TOP DRIVE /FILL DP WITH 65 STKS : BRIS CIRC /CBU : ,,°.T 400) STKS 2000 !'NITS OF GAS / AT 1042 STKS 7428 UNITS OF GAS (MAX GAS) AT 2775 STKS 11726 UNITS OF GAS / AT 2775 STKS BOTTOMS UP -BACKGROUND GAS 120 - 67 UNITS. CIRC 'WELL CLEAN, BACKGROUND 60 UNITS. 8:30 - 11:00 2.50 05 POH TO SHOE AT 1007' /CHANGE OUT 4" ELEVATORS TO 5". /OBSERVE WELL, FLUID LEVEL STATIC. 11:00 - 15:00 4.00 05 CONTINUE POH -LAY DOWN 2 JTS. HWDP AND JARS- STAND BACK M4~lD & FLEX COLLARS 15:00 - 21:00 6.00 13 PULL WEAR BUSHING -SET TEST PLUG AND TEST BOP'S & CHOKE EOSJIPMENT TO 250 / 3000 PSI 21:00 - 0:00 3.00 05 DOWN LOAD MWD AND LAY DOWN SAME-LAY DO\iVN STABLIZER & FLOAT SUB 02-20-2008 0:00 - 3:30 3.50 05 3:30 - 5:00 1.50 05 5:00 - 5:30 0.50 05 5:30 - 8:30 3.00 05 8:30 - 9:00 0.50 04 9:00 - 12:00 3.00 04 12:00 - 15:30 3.50 05 15:30 - 16:00 0.50 05 16:00 - 20:30 4.50 10 20:30 - 0:00 3.50 10 02-21-2008 0:00 - 2:30 2.50 10 2:30- 4:00 1.50 10 4:00 - 6:00 2.00 06 6:00 - 6:30 0.50 05 .~ 6:30 - 8:00 1.50 05 8:00 - 13:00 5.00 05 LAY DOWN BHA L/D MOTOR /BIT /LATCH UP COLLARS / L/D SAME. C/O 4" EQUIP. P/U STAI~lD W/ BIT. L/D SAME. C/O T/5" EQUIP. P/U SPIRAL COLLARS. M/U BIT /FLT SUB (BLOW DN CHOKE) TIH W/ HWDP /CHANGE OUT TO 4" ELEVATORS, TIH W/4" DP TAGGED FLOAT COLLAR @ 926 ROTATE & PUMP PAST SAME -CBU AT SHOE / MAX GAS 8200 UNITS AT 980 STKS /GAS CUT FROM 16.6 TO 14.7 PPG. CONTINUE RIH WASH & REAM 5 STDS F BACKGROUND GAS DN TO 90 1J~11TS, CONT. RIH TO BOTTOM W/OUT WASHING OR REAMING. CBU MAX GAS 2610 UNITS. GAS CUT MUD 15.7 ,, CIRCULATE & CONDITION MUD FOR OPEN HOLE LOGS - 404 GPM POH FOR OPEN HOLE LOGS.- NO HOLE TROUBLE„ HOLE TOOK 3.07 BBLS / 5 STANDS LAY DOWN JARS AND STAND BACK 1 STAND OF DRILL COLLARS REMOVE FLOW NIPPLE FROM TOP OF BOP'S AND INSTALL FLANGE FOR WIRE LINE LUBRICATOR ,HOOK UP SHORT LUBICATOR -REMOVED AND SERVICED GRABBER OFF OF TOP DRIVE WHILE HiANDS WERE WORKING ON FLOW NIPPLE RIH WITH WIRE LINE -LOG TOOLS CONSIST OF- CH TENSION -TEMP. -LAMA RAY - COMPENSATED NEUTRON - Z- DENSILOG -CALIPERS - X-MAC ACOUSTIC LOG CONTINUE OPEN HOLE LOGS W/ RUN #1. RIG DN BAKER ATLAS, RIG DN LUB, RIG UP BELL NIPPLE. SERVICE TOP DRIVE, REINSTALL GRABBER & QUILL ON TOP DRIVE. MU 8.75 BIT, MU JARS. RIH TO SHOE, FILL DP W/ 67 STKS, CBU AT SHOE, AT 160 STKS HAD 2650 UNITS GAS, AT 800 STKS HAD 3422 UNITS OF GAS, AT 3100 STKS BG GAS 130 UNITS, CiONTINUE RIH, WASH & REAM NEXT 4 STDS, FROM 1165' TO 1259' HAD 180 UNITS OF GAS. FROM 1259' TO 1353' HAD 356 UNITS OF GAS. FROM 1353' TO 1449' HAD 551 UNITS OF GAS. FROM 1449' TO 1545' HAD 556 - 1850 UNITS OF GAS (MAX GAS), AT SHAKERS HAD AN AVALA8~ICHE OF CUTTINGS FROM V LG 4"-6" TO SM 1/2 "- 1". CONTINUE RIH, HOLE IN GOOD SHAPE, HAD 2' OF FILL ON BTM. CBU, G1RC & CONDITION MUD FOR OPEN HOLE LOGS, AT 1325 STKS HAD MIAX GAS OF 1109 UNITS. ii DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPOl Time (hrs) Elapsed Time IADC code Operations Breakdown 13:00 - 15:00 2.00 05 POH 2 STDS, BLOW DN TOP DRIVE, POH FOR OPEN HOLE LOGS, HOLE TAKING CORRECT AMT OF FLUID - 3.5 BBLS/ 5 STDS. 15:00 - 16:30 1.50 10 REMOVE RISER FROM TOP OF BOP STACK 16:30 - 20:00 3.50 13 PJSM WITH WIRE LINE CREWS -INSTALL WIRE LINE LUBICATOR & PICK UP E LINE TOOLS 20:00 - 0:00 4.00 10 RIH WITH WIRE LINE RCI TOOL - 02-22-2008 0:00 - 6:30 6.50 08 6:30 - 8:30 2.00 08 8:30 - 16:00 7.50 05 16:00 - 17:00 1.00 05 17:00 - 0:00 7.00 07 02-23-2008 0:00 - 8:30 8.50 07 8:30 - 9:00. 0.50 04 9:00 - 9:30 0.50 04 9:30 - 10:00 0.50 05 10:00 - 12:30 2.50 07 12:30 - 14:00 1.50 04 14:00 - 0:00 10:00 02 02-24-2008 0:00 - 4:00 4.00 02 4:00 - 4:30 0.50 07 4:30 - 12:30 8.00 02 12:30 - 13:00 0.50 02 13:00 - 14:00 1.00 17 14:00 - 14:30 0.50 07 14:30 - 0:00 9.50 02 02-25-2008 0:00 - 1:30 1.50 02 1:30 - 2:30 1.00 07 2:30 - 3:30 1.00 02 3:30 -14:30 11.00 07 14:30 - 16:30 2.00 07 16:30 - 23:00 23:00 - 23:30 6.50 0.50 02 04 23:30 0:00 0.50 02 02-26-2008 0:00 - 6:00 6.00 02 6:00 - 7:30 1.50 02 7:30 - 8:30 8:30 - 9:30 1.00 1.00 04 05 9:30 - 12:00 2.50 03 12:00 - 12:30 0.50 03 12:30 - 14:00 1.50 16 14:00 - 21:30 7.50 16 LOG WELL W/ BAKER ATLAS RCI TOOL TO 1161', POH WITH SAME. MADE 42 ATTEMPTS WITH 20 RESULTS: AT 1740' HAD MIN PSI OF 130 BUILDUP PRES OF 1357 / AT 1749' HAD MIN PRES OF 426 PSI BUILDUP PRES OF 1282 / AT 1591' HAD MIN PRES OF 918, BUILDUP PRES OF 976 / AT 1276' HAD MIN PRES OF 822, BUILDUP PRES OF 1095 / AT 1119' HAD MIN PRES OF 241 PSI, BUILDUP PRES OF 471. RIG DN BAKER ATLAS, RIG DN LUB, RIG UP BELL NIPPLE. M/U RR BIT, P/U BHA, RIH TO 1290'. ATTEMPT CBU, FOUND TOP DRIVE TO BE FROZEN UP. POOH TO SHOE THAW TOP DRIVE AND MUD LINE (STAND PIPE) TEMPS RANGING BETWEEN 0 AND +6 F. THAWING OUT STANDPIPE & KELLY HOSE ,AND GOOSE NECK. (AMBIENT TEMP -5 F) PUMP THROUGH MUD LINES AND TOP DRIVE CBU AT SHOE, GAS PEAK@ 885 UNITS /GAS CUT 14.7 PPG RIH TO 1480 TOP DRIVE COULDN'T MAKE CONNECTION, BROUGHT DN TO FLOOR TO WARM UP. MADE CONN ON FLOOR /BROKE CIRC. /GAS PEAK @ 3587 UNITS /GAS CUT 15.0 PPG RIH TO BTM @ 2628' CBU MAX GAS 220 UNITS DRLG AHEAD 8.75 HOLE FROM 2628' TO 2829'. MW - 16.1 PPG /SPM-160 / GPM-430 /OFF BTM - 2950 PSI / ON BTM - 3150 PSI, RPM - 80, TORQUE - 3-4K, WOB - 30K, ROP - 20 FPH DRILLING AHEAD FROM 2829' TO 2921' REPLACE GASKET ON PULSATION DAMPENER DRILL 8.75 HOLE FROM 2921' TO 3176', PUMPED 15 BBL LCM PILL. MADE AN INCLINATION CHANGE / MADE A 30' SLIDE FROM 3176' TO 3206'. HAD H2S ALARM GO OFF, EVAC RIG AND DRILLER CHECKED GAS DET. IN CELLAR WEARING A SCOTT AIR PACK AND GAS SNIFFER -FOUND NO H2S GAS AND CALLED BACK THE RIG CREW. NO FAULT FOUND W/ DETECTOR. RESUMED DRILLING & DRILLED TO 3210'. LOST POWER TO DRLG CONSOLE. ACADEMY HAND FOUND PROBLEM AND MADE REPAIR. DRLG AHEAD FROM 3210' TO 3788' - MW=15.4 MD=3600' SPM=160 GPM=430 PSI=3350 ON BTM PSI=3100 OFF BTM RPM=80 TO.=2-4K WOB=15 ROP=70-90 FPH DRLG F/3788' T/3884' OIL LEAK ON TOP DRIVE (CANRIG MECH. FIXED LEAK) DRLG F/3884' T/3900' IBOP WOULD NOT OPEN DUE TO COLD HYDRAULICS,CAUSING TOP DRIVE & KELLY HOSE TO FREEZE. THAWED OUT KELLY HOSE & STAND PIPE. M/U KELLY HOSE TO STAND PIPE AND TOP DRIVE. FOUND TOP DRIVE TO BE FROZEN, THAWED OUT TOP DRIVE. TEMP -40 F M/U TOP DRIVE TO DP, BROKE CIRC W/ PUMP # 1, COULD NOT PUMP W/ PUMP # 2 DUE TO ROD WASH PUMP BEING FROZEN. P/U DP W/ 50K OVER STRING WT, STRING WT =50 K. SLACKED OFF DP, ROTATED DP, PICKED BACK UP ON DP, DP WAS FREE. CBU. BACKGROUND GAS 120 UNITS MADE CONN, DRLG AHEAD W / 8.75 BIT FROM 3900' T/ 4130', LOSSES @ 2 BPM PUMPED 30 BBL LCM PILL, MIX 2 FINE @ 10 POUND PER BBL DRLG F/ 4130' T/ 4173' - MW=15.0 PPG SPM=160 GPM=430 PSI=3450 RPM=80 TO=5 WOB=20 ROP=50-70FPH DRILLING F/4173' T/4265' PUMP 10 BBLS KCL@ 4219' DRILLING F/4265' T/4285' PUMP15 BBLS KCL @ 4270' CIRCULATE & CONDITION MUD BLOW DOWN TOP DRIVE & POOH. F/4285' T/4145', 30K OVER @4285' BACK REAMING F/4145' T/3816', TIGHT @ 4076' - 3960' - 3840' BACK REAMING F/3816' T/3737' PULLED 30K OVER AND STUCK PIPE - JARRING DOWN AND CIRC. @ 30 SPM, INCREASED PUMP RATE AND LOST CIRC. PUMPED 15 BBL LCM PILL PUMPED 40 BBL LCM, PILL OVER TOP OF HOLE, CUT MUD WT TO 14.6 PPG, CONT. JARRING DN AND PUMPING LCM, STATIC FLUID LOSS WAS 1-3 BBL / HR. 7 ' DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPO1 Time Elapsed IADC Operations Breakdown (hrs) Time code 21:30 - 0:00 3.50 16 TORQUED CONNECTIONS ABOVE FLOOR AND MADE A BLIND BACKOFF 143' BELOW ROTARY TABLE -STOOD BACK 2 STANDS AND LOOKED AT PIN ON LAST JT. PIGKED UP 1) STAND AND 15' PUP (SO TOOL JT IS 3' ABOVE ROTARY TABLE) SCREWED INTO FISH 02-27-2008 0:00 - 0:30 0.50 16 PRE JOB SAFETY MEETING W/ BAKER ATLAS 0:30 - 4:30 4.00 16 HANG SHEAVES BELOW DERRICK BOARD, P/U LUBRICATOR & NEEDED TO MOVE SHEAVE BELOW CROWN P/U FREEPOINT TOOLS 4:30 - 6:30 2.00 16 WORK ON FOOTAGE COUNTER IN WIRELINE UNIT FOR 2 t-9RS. CORRELATE DEPTH BY PULLING T/148 K AND SLACKING OFF T/115 K 6:30 - 9:00 2.50 16 HOLD 2 TURNS RIGHT HAND TO. TO FIND FREE POINT -FOUND FREE POINT AT 3464' POOH W/ FREE POINT TOOLS AND LAY DOWN SAME 9:00 - 12:30 3.50 16 HOLD PJSM ON STRING SHOT - M/U SAME AND TEST VOLTAGE AND CONTINUITY - RIH W/ STRING SHOT T/3464' P/U T/ 85K 12:30 - 16:30 4.00 16 PUT 3 TURNS TO LEFT IN STRING AND STRING BACKED OUT BEFORE SHOT - RiETOROUED AND TRIED AGAIN SAME AS BEFORE RETOROUED -PUT 3 TURNS TO LEFT IN STRING FIRE STRING SHOT AND PUT 7 TUg2NS TO LEFT TO BACK OFF OF FISH 16:30 - 0:00 7.50 16 STARTED PUMPING AT 30 SPM WITH PARTIAL RETURNS -AFTER 60 STROKES UOST RETURNS -SLOWED TO 15 SPM AND MIXED AND PUMPED 50 BBL LCM PILL -SPOTTED ON BACK SIDE OF PIPE AND BLEW DOWN TOP DRfWE TO MONITOR WELL (FLUID LEVEL STAYED IN RISER WITH NO RETURNS DURING PUMPING OPERATIONS) STATIC LOSSES WERE @ 10 BBLS PER HR BEFORE LCM PILL AND 2 BBLS PER HR AFTER 02-28-2008 0:00 - 1:00 1.00 16 BLOW DOWN TOP DRIVE & MONITOR WELL 1:00 - 1:30 0.50 04 FILL HOLE WITH TRIP TANK, TOOK 10 BBLS 1:30 - 2:00 0.50 16 MONITOR WELL FOR 30 MIN, (WELL STATIC) 2:00 - 4:00 2.00 05 POOH FROM 3457' TO 2699' HOLE TOOK 17 BBLS TO FILL(CHECKING TORQUE ON EACH CONNECTION) , I 4:00 - 4:30 0.50 05 MONITOR WELL 30 MIN, (WELL STATIC) , 4:30 - 9:00 4.50 05 POOH FROM 2699' TO 690' (C1-IECKING TORQUE ON EACH. CONNECTION FOUND 2 LOOSE CONNECTIONS) 9:00 - 11:00 2.00 05 CHANGE ELEVATORS & STAND BACK HVWDP (CHECKING TORQUE ON EACH CONNECTION) (RETRIEVED 22.87 OF 31.93 OF JARS) LAY DOWN SAME 1 11:00 - 15:00 4.00 05 P/U FISHING BHA 15:00 - 15:30 0.50 06 GREASE WASH PIPE & TWIST KELLY HOSE 15:30 - 23:00 7.50 05 R.I.H. WITH OVERSHOT TO 3161' 23:00 - 0:00 1.00 03 TOOK 20K WT. SCREW IN & PUMP @ 20 SPM 200 PSI ROTATE @ 6 RPM & WAS6~ED TO BOTTOM 02-29-2008 0:00 - 6:00 6.00 .16 WASH DOWN FROM 3262' T/3454' -LOST 50 BBLS WITH PARTIAL RETURNS - PI~AflP @ 72 SPM 400 PSI GAS PEAKED ~ 9000 UNITS -REGAINED FULL RETURNS @ 3277 h1JMP @ 100 SPM 900 PSI GAS @ 80 UNITS 6:00 - 9:30 3.50 16 WASH DOWN F/3454' T/3457 '>JID NOT ENGAGE TOP OF FISH - NO PUMP INCREASE -PICKED UP AND HAD 20K OVERPULL -GRAPPLE DIDN'T SHOW ANY SIGNS OF TAGGINCF FISH 9:30 - 10:30 1.00 05 PUMP DRY JOB AND BLOW DOWN TOP DRIVE 10:30 - 11:30 1.00 05 POOH F/3457' T/2877' - 20K OVERPULL @ 3327' 8~ 3262' -SWABBED 3 BBLS F/30fi~' T/2877' 11:30 - 12:30 1.00 04 CIRC. BTMS UP -MONITOR VbIELL (STATIC) AND BLOW D01/UN TOP DRIVE 12:30 - 13:00 0.50 05 POOH F/2877' T/2784' PUMPIh1G @ 80 SPM 13:00 - 15:00 2.00 04 CIRC. OUT 600 UNITS OF GAS OUT @ 80 SPM @ 2784' -BLOW DOWN TOP DRIVE 15:00 - 20:00 00 05 5 POOH F/2784' T/2688' -WELL. FLOWING -SCREW INTO TOP DRIVE AND PUMP Or~JT Tl2592' @ . 80 SPM -WELL STATIC @25912' BLOW DOWN TOP DRIVE AND POOH F/2592' T/9'~:8' ' 20:00 - 22:00 2.00 05 LAY DOWN FISHING BHA AN® STAND BACK 1) STAND OF DC'S (FOUND PUMP OIJT SUB TO BE PARTIALLY OPENED WITI-! RUBBER IN PORT) 22:00 - 23:00 1.00 06 SERVICE RIG AND CLEAN TOOLS FROM FLOOR 23:00 - 0:00 1.00 05 MAKE UP MULE SHOE FOR SETTING CEMENT PLUG AND R!H T/489' 03-01-2008 0:00 - 3:30 3.50 05 TIH F/ 489' T/ 2503' -INSTALL FOSV & DART VALVE -CONT. iN HOLE TAG @ 34545' 3:30 - 4:00 0.50 05 LAY DOWN 1 JNT. DRILL PIPE FOR SPACE OUT 4:00 - 5:00 1.00 15 RIG UP CEMENT CIRC. &CIRC MANIFOLD 5:00 - 6:00 1.00 04 CIRC. BOTTOMS UP @ 3442' AN/100 STROKES = 6.4 BBLS PER MIN. = 1300 PSI. C9AS PEAK @ 2900 UNITS W / 1200 STROKES, HELD SAFETY MEETING ON CEMENTING JOB 6:00 - 7:30 1.50 15 PUMP 4 BBLS FRESHWATER„ TEST LINES T/ 30010 PSI. PUMP 44 BBLS MUD PUSS @ 3.2 BBLS PER MIN. = 4500 PSI. Giu1T 49 BBLS @ 17 PPG, 5 BBLS MUD PUSH & 23 BBLS MUD @ 2.9 BBLS PER MIN. = 400 PSI, RIO DOWN CEMENTERS (CEMENT IN PLACE @ 0700 IHRS) 7:30 - 8:30 1.00 05 POOH F/ 3442' T/ 2503' i~ DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPO1 Time Elapsed IADC Operations Breakdown 1 (hrs) Time code 8'30 - 9:30 1.00 15 REMOVE DART VALVE, RIG UP TO CIRC. THRU CEMENT HOSE, PUMP NERF BALL @ 7 BBLS PER MIN. (2700 STROKES) RIG DOWN CIRC HOSE & BREAK OFF FOSV 9:30 - 12:30 3.00 05 POOH F/ 2503' T! SURFACE LAY DG4/VN MULE SHOE 12:30 - 0:00 11.50 13 PULL WEAR RING, INSTALL TEST PLUG. TEST BOP'S AND RELATED EQUIP. T/ 250 PSI LOW 1 AND 3000 PSI HIGH GUBIK 3 BP01 03-02-2008 0:00 - 1:30 1.50 05 FINISH MAKING UP BHA & T.I.H T/ 822' 1:30 - 2:30 1.00 04 BREAK CIRC. 8~ CIRC @ REDUCED ELATE WHILE SLIP & CUT. R/U TO TEST 4" SAFETY VALVE 2:30 - 4:30 2.00 06 CUT DRILL LINE 265' (TEST 4" SAFETY VALVES WHILE SLIP & CUT T/250 PSI LOW / 3000 PSI HIGH) 4:30 - 6:00 1.50 13 TEST LOWER TOP DRIVE VALVE, UiPPER TOP DRIVE VALVE & FOUR.1/2" T.I.W. T/ 250 PSI LOW ! 3000 PSI HIGH 6:00 - 8:00 2.00 05 TIH FROM 822' TO 2652' 8:00 - 8:30 0.50 04 CIRC. BOTTOMS UP @ 6.4 BBLS MIN. (4400 UNITS OF GAS PEAK) 8:30 - 10:00 1.50 02 FEEL FOR CEMENT FROM 2652' TO 2970' 10:00 - 10:30 0.50 02 DRILL CEMENT FROM 2970' TO 3045' 10:30 - 11:00 0.50 04 CIRC. BOTTOMS UP @ 6.4 BBLS MtAd. 11:00 - 11:30 0.50 04 PUMP DRY JOB & BLOW DOWN TOP DRIVE, ROTARY HOSE 11:30 - 15:30 4.00 05 POOH FROM 3045' TO SURFACE (STRAP HVYWT DP AND COLLARS) 15:30 - 16:00 0.50 06 CLEAR RIG FL©OR AND SERVICE TOP DRIVE 16:00 - 20:30 4.50 05 MAKE UP BHA #8 UP LOAD MWD TOOLS 20:30 - 22:00 1.50 05 RIH T/1000' -SHALLOW TEST MWD FOOLS @ 450 GPM -BLOW DOWN TOP DRIVE 22:00 - 0:00 2.00 05 CONT. RIH W/ 4" DP T/2885' 03-03-2008 0:00 - 0:30 0.50 05 TIH FROM 2761' TO 2857' 0:30 - 1:00 0.50 04 FILL PIPE / CBU /SURVEY 1:00 - 3:00 2.00 02 ORIENT TOOLFACE TROUGHING FROM 2856' TO 3015' 3:00 - 16:30 13.50 02 TIME DRILL AS DIRECTED BY DIRECTIONAL DRILLER FROM 3015' TO 3032' -SPM=160 GPM=432 PSI=2120 16:30 - 17:00 0.50 04 WORK PIIPE AND CBU - UP WT. =85 - DN WT. = 85 17:00 - 18:00 1 00 02 TIMED DRILLING AS DIRECTED BY DIRECTIONAL DRILLER FROM 3032' TO 3038' -SPM=140 . GPM=370 PSI=1650. @ 1720HRS SFiiJT OFF PUMPS, SET DOWN ON CEMENT ONLY TOOK 10K BROKE TFIRU CEMENT. 18:00 - 18:30 0.50 04 CANRIG HAND INSPECT TOP DRIVE 18:30 - 19:00 0.50 02 ROTATE FROM 3038' TO 3048' 5 - 10K ON BIT LOOKING FOR HARD CEMENT 19:00 - 0:00 5.00 02 SLIDE & WASH FROM 3048' TO 30961 SLIDE TIMED DRILLING FROM 3096' TO 3105' SPM = 180, GPM = 502, PSI = 2800 03-04-2008 0:00 - 16:00 16.00 02 TIMED DRILLING SLIDE @ 2' PER H®UR FROM 3104' TO 3165' -SPM=165 GPM=450 PSI=2300 MW=13.4 PPG ' 16:00 - 18:00 2.00 02 ROTATE F/3165' T/3189' (SURVEY 2.49 INC. 209 AZIM.) ROT F/3189' T/3205' (SURVEY 2.94 INC. 219 AZIM.) ROT. F/3205' T/3241' WOB=S-10 K SPM=165 GPM=450 PSI=2600 DIFF. PSI=200 18:00 - 19:00 1.00 02 SLIDE F/ 3241' T/3253' SPM=165 GPM=450 PSI=2500 -HANGING UP NOT DRLG OFF REAM 10' 19:00 - 19:30 0.50 02 ROTATE F/3253' T/ 3262' SPM=184 G+PM=495 PSI=2800 ' 19:30 - 20:00 0.50 02 SLIDE F/ 3262' T/3264' SPM=165 GPM=450 PSI=2500 - 15 K OVERPULL HANGING UP NOT DRLG OFF REAM 30' 20:00 - 21:15 1.25 02 ROT. F/3264' T/3290' WOB=5-10 K SPM=185 GPM=500 PSI=2700 RPM=60 21:15 - 23:30 2.25 02 SLIDE FROM 3290' TO 3310' SPM = 174, GPM = 465, PSI = 2500 23:30 - 0:00 0.50 02 ROTATE FROM 3310' TO 3330' SPM = 174, GPM = 465, PSI = 2500 -ACTUAL SLIDING TIME _ 17.59 ACTUAL E:OTATING TIME = 2.41 03-05-2008 0:00 - 1:00 1 00 02 ROTATE FROM 3330' TO 3346' -SPM = 168 GPM = 451 PSI = 2400 WOB=8K 1:00 - 1:30 . 0.50 02 SLIDE DRILL FROM 3346' TO 3355' - 168 SPM = 2400 PSI & 451 GPM - 6K WOB 1:30 - 2:00 0.50 02 DRILL FROM 3355' TO 3365' - 168 SPIvI = 2450 PSI &451 GPM - 60 RPM - 8K WOB 2:00 - 2:30 0.50 02 SLIDE DRILL FROM 3365 TO 3375' - 168 SPM - 2400 PSI & 451 GPM - 4K WOB 2:30 - 7:00 4.50 02 DRILL FROM 3375' TO 3527' - 168 SP"M = 2450 PSI - 451 GPM - 60RPM - 8K WOB -SURVEY @ 3388 CONNECTION & SURVEY @ 3433' 7:00 - 7:30 0.50 04 CIRC. BOTTOMS UP -BLOW DOWN TOP DRIVE 7:30 - 9:00 1.50 02 SHORT TRIP FROM 3527' TO 2952' ~ PROBLEMS RIH TO 3527' ' 9 DAILY OPERATIONS ACTIVITY ANADARKO - GUBIK 3 & GUBIK 3 ~PO1 Time Elapsed IADC Operations Breakdown (hrs) Time code 9:00 10:00 1.00 04 CIRC GAS OUT 6980 UNITS OF GAS PEAK 10:00 - 14:00 4.00 02 ROTATING FROM 3527' TO 3626' SPM 165 = 443 GPM - 2500 PSI - 7-10 WOB - 60 RPM 14:00 - 22:00 8.00 02 ROTATING FROM 3626' TO 3818" TORQUED UP @ 3647' REAMED 30' TIGHT HOLE PULLED 15K OVER, WORKED THRU 22:00 - 0:00 2.00 02 ROTATING FROM 3818' TO 3861' -SPM 187 = 505 GPM - 3000 PSI - 70 RPM - 10K WOB - ~ 3830' INCREASE IN PUMP 250-300 PSI, POSSIBLE PLUGGED JET. 03-06-2008 0:00 - 2:30 2.50 02 DRILLING FROM 3861' TO 3950' (TD) - 187 SPM = 505 GPM @ 3150 PSI - 70RPM - 9K WOB3 2:30 - 3:30 1.00 04 CIRC. BOTTOMS UP -PUMP UP SURVEY -MIX PILL 3:30 - 4:00 0.50 05 POOH FROM 3950' TO 3915' (FREE) 4:00 - 4:30 0.50 04 SPOT PILL -PUMP DRY JOB -BLOW DOWN TOP DRIVE 4:30 - 7:30 3.00 05 POOH FROM 3915' TO SHOE - 15K SPOT DRAG FROM 3890' TO 3845' 7:30 - 9:30 2.00 05 RIH FROM SHOE TO 3915' -TOOK WT @ 3116' (10K) PICK UP & WORK THRU 9:30 - 10:00 0.50 03 BREAK CIRC. & WASH DOWN FROM 3915' TO 3950' (8' FILL) 10:00 - 12:00 2.00 04 CIRC BOTTOMS UP 2 TIMES (10017 UNITS GAS PEAK) 12:00 - 13:00 1.00 05 POOH -PUMP SLUG -BLOW DOWN TOP DRIVE - 100K UP 100K DOWN 13:00 - 14:00 1.00 05 RIH -PULLED 2 STANDS, HOLE SWABING, RUN 2 STANDS BACK IN &CIRC. BOTTOMS U~' 14:00 - 15:00 1.00 05 POOH FROM 3950' TO 3633' - 100K UP 100K DOWN 15:00 - 16:30 1.50 04 KELLY UP @ 3633' TIGHT HOLE PULLED 20K OVER / 50K DOWN -CIRC 164 SPM = 443 GRM @ 2400 PSI -BUILD MUD WEIGHT FROM 13.4 TO 13.6 16:30 - 19:30 3.00 05 POOH FROM 3633' TO 1200' (NO HOLE PROBLEMS) BLOW DOWN TOP DRIVE 19:30 - 20:00 0.50 17 H2S ALARM WENT OFF, EVACUATED RIG TO SAFE BRIEFING AREA DRILLER, TOOLPUSd-1ER, DONNED SCBA & WENT THRU RIG WITH HAND HELD MONITOR (FALSE ALARM) 20:00 - 21:00 1.00 05 POOH FROM 1200' TO 980' - H2S ALARM WENT OFF AGAIN (SAME DRILL AS ABOVE) 21:00 - 22:00 1.00 05 POOH FROM 980' STAND BACK 5" HWDP & JARS 22:00 - 0:00 2.00 05 LAY DOWN BHA DOWNLOAD MWD T®OLS 03-07-2008 0:00 - 1:30 1.50 05 FINISH LAYING DOWN MWD TOOLS 1:30 - 2:00 0.50 17 SAFETY MEETING WITH WIRE LINE CREW ON RIGGING UP AND RUNNING WIRE-LINE DOGS 2:00 - 3:30 1.50 10 REMOVE BELL NIPPLE AND INSTALL LUBRICATOR -RIG UP WIRE LINE SHEEVES 3:30 - 5:00 1.50 10 PICK UP LOGGING TOOLS 5:00 - 14:30 9.50 10 RIH WITH FIRST RUN OF WIRE LINE TOOLS HDIL- X MAX - 6 ARM CALIPER - CN - ZDL - GR POH AND CHANGE TOOLS 14:30 - 0:00 9.50 10 RIH WITH RCI - 15 TESTS MADE UP TO 3559' 03-08-2008 0:00 - 6:00 6.00 10 WIRE LINE RUN #2 WITH RCI 6:00 - 9:00 3.00 10 LAY DOWN LOGGING TOOLS AND RELATED EQUIPMENT- RIG DOWN LIBICATOR AND NIPPLE UP BELL NIPPLE 9:00 - 11:00 2.00 05 PU STAND OF DRILL COLLARS AND MAKE UP BIT SUB W/ FLOATAND BIT- RUN IN HOLE WITH REST BHA AND 2 STANDS DP TO SHOE 11:00 - 12:00 1.00 04 CBU @ SHOE -PEAK GAS WAS 10,OOo0 UNITS -BLOW DOWN TOP DRIVE 12:00 - 15:00 3.00 05 RIH -TIGHT AT 3112' -KELLY UP AND WORK THROUGH W/ 90 SPM AND NO ROTATION - CIRC OUT 10,000 UNITS OF GAS - RE~4M OUT HOLE- 15:00 - 16:00 1.00 05 RIH TO TD - NO OTHER HOLE PROBLEMS 16:00 - 18:00 2.00 04 CIRC. 2 BOTTOMS UP @ 156 SPM - 420GPM 18:00 - 21:30 3.50 05 POH- NO HOLE PROBLEMS ENCOUNTERED- GOOD HOLE FILL 21:30 - 0:00 2.50 05 POH LAYING DOWN THE HWDP AND REST OF THE BHA 03-09-2008 0:00 - 0:30 0.50 06 GETTING TOOLS & EQUIP. OFF OF RIG FLOOR 0:30 - 2:00 1.50 11 MAKE UP WEAR RING PULLER -PULL WEAR RING -SET TEST PLUG -CLOSE BLIND RADiIS - OPEN ANNULUS - C/O T.P. RAMS TO 7' 2:00 - 3:00 1.00 BEGIN DAYLIGHT SAVINGS TIME 3:00 - 5:00 2.00 X BOLT NOT STARTING -OPEN RAMS TAKE OUT O-RING AND BOLT -FILE 5:00 - 8:00 3.00 11 RIG UP TO RUN CASING, WHILE WOF~KING ON BOP BOLT -RIG DOWN SHORT BALES -RIG UP CASING BALES & CHANGE MUD PUMP LINER - #2 CYLINDER COMPLETE 8:00 - 10:00 2.00 13 MAKE UP 7' TEST JT. WITH HEADPIN ~& PORTED SUBS -SCREW INTO TEST PLUG -FILL STACK -TEST RAMS (NOT PRESSURING UP) 10:00 - 11:00 1.00 13 EGGED COLLAR 11:00 - 12:00 1.00 PICK UP TEST TOOLS -MAKE UP NE1/V TESTT JT. -SCREW 7' X/O TO TEST PLUG INTO .JT. OF CASING -MAKE UP FLOOR VALVE - X/O INTO TOP OF TEST JT. NOT TIGHT. #1 MUO PUMP COMPLETE WITH 6.5" LINERS. 10 I,t DAILY OPERATIONS ACTIVITY ANADARKO -GUBIK 3 &GUBIK 3 BPO1 I' Time Elapsed IADC Operations Breakdown ' (hrs) Time code 12:00 - 13:00 1.00 MAKE UP 7" TEST JOINT -RIG UP TEST PUMP -SET IN BOP 13:00 - 13:30 0.50 13 TEST 7" PIPE REAMS @3000 PSI FOR 5 BNIN. -RIG DOWN TEST JT. & TEST PUMP. 13:30 - 14:30 1.00 11 HANG STABING BOARD INSIDE DERRICK 14:30 - 20:00 5.50 11 FLY CASING TOOLS ON RIG FLOOR WITH CRANE -CASING TONGS FAILED -RIG UP SET #2 ' 20:00 - 0:00 4.00 11 RUN 7" CASING - CIRC. SHOE JTS. -PUT CENTRALIZERS IN PLACE -HAD TO PUSH DOV~IN FIRST 12 JTS. 11 t Anadarko Gubik 3 1 I nch / 500 ft MD Well Dia ram ROP Avg ~ Temp EWR ° F ~~ ~ fph 300 0 ~ ~ _ -..... ... _..__.. ~.~. ,. Mud Wt In ~,. , -... Pp9 - . ~ ~ $ 18 ,~ •-------- ----- -----•••• EWR Dee p Gamma Ray _ ~ ~ ~ 0 Avg. Gas 5K app ~ ~ ~ Max. Gas 5K 1 ohm-m 100 150 0 _ _ __ ........... ---------------------- Mp units WRAP X 1 WRAP X 1 o - ~ ~ r rs~ - ~ ~ •. ' ' ~ ~ ' ~ ~ ' • ~ ,~ o o ... ~ i i has . ~ i i :~~ ... _ i i ~ - '~ ti.. .. - ~ .......... ....... _ _ `ter .. _ f' f.. o ~~~_ :,.. f .. ~` ~ ~~~• ... ~:... yj~` Y r ~. N _--._ I ~ , i o = 1 k~ ' ' ~ ~t ~ ! •. , 7 s ~ - 1 ~ • f r•- r a N / O ---- ~ ~' J .. ~-~ I i I t ~ .. ' ~~ _ 0 ~ ~ _~ . ~ . Anadarko Gubik 3 BP01 1 Inch / 500 ft MD Well Dia ram ROP Avg ~, Temp EWR ° F ~~o fph ~ _ . _ _ _~,.... ,, . ~,-_ _ ..~ . 300 0 ~ ~ ~ 8 Mud Wt In PP9 18 = o ... --........ .................................. EWR Deep Gamma Ray ~ ~ ~ 0 Avg. Gas _____5K api ~ ~ 0 Max. Gas 5K 1 ohm-m 100 0 150 --~ - _ _ ........................................... MD units WRAP X 1 WRAP X 1 J iI!' -~-a-:-' ... Ss~ Lithologic Summary ANADARKO GUBIK 3 5_ Lithologic Summary Depth (ft) Formation Lithology and Remarks Reference Information Below to Mudlogs and Cuttings Sample Photomicrographs LITHOLOGIC DESCRIPTIONS IN DESCENDING ORDER WITH DEPTH FORMATION NAMING AND INTERVALS FROM PROGNOSIS 105 - 1027 SCHRADER BLUFF Massive volcanic/ volcanoclastic sandstones in upper portion with interbedded shales, siltstones, sandstones and tuffs in lower section of interval. SANDSTONE light gray, very light gray in part, very fine grain, subangular, well sorted, very well cemented-very hard, siliceous cement, predominately quartz-grading to quartzite in part, trace visible porosity, predominately tight, secondary mineral grains, trace pyrite, trace chalcopyrite, predominately 10-20mm angular fragments in sample, no stain odor fluorescence or cut. SILTSTONE light graybrown, lightgray, platy-blocky, angular-splintery in part, noncalcareous, some sandstone interbeds+laminations, siliceous cemented+cherty in part, trace carbonaceous specks, hard-very hard. SANDSTONE light gray, very light gray in part, very fine-fine grain, subangular, well sorted, moderately-well cemented, siliceous cement,moderate cement-calcareous cement, predominately quartz, some quartzite in part, trace visible pinpoint porosity, tight, increase friable in part, secondary mineral grains, carbonaceous inclusions, predominately 10-20 mm angular fragments in sample, no fluorescence. SHALE medium gray, dark gray, platy-blocky, non-trace calcareous, some carbonaceous material, interbedded with siltstone, decreasing hard-to very firm. TUFF white, pale light gray, extra fine-very fine grain, platy, glass shards, abundant white + black crystals, siliceously cemented- medium hard-hard SANDSTONE light gray-gray, angular-subangular, fine-veryfine grain, medium grain in part, moderately-well consolidated, tight cemented in part, noncalcareous. TUFF white, tan, verylightgray, blocky-angular, some glass shards, waxy, some veryfinegrain sand in part, predominately clean, veryfirm-veryhard. SHALE medium-darkgray, blocky-platy, massive-nonfissile, microcarbonaceous specks,micromica, noncalcareous, siliceous in part, trace pyrite, medium hard-hard, grading to siltstone. SILTSTONE medium-darkgray, blocky, grading + interbedded with very fine grain sandstone, microcarbonaceous specks, noncalcareous, very firm in part, predominately medium hard. SANDSTONE light-medium gray, veryfine-finegrain, subangular, well sorted, medium-well cemented, lithic, 10% carbonaceous specks, mineral grains, quartz, noncalcareous, some tuffaceous matrix, medium hard-friable, no fluorescence. 0 Lithologic Summary ANADARKO GUBIK 3 Depth (ft) Formation Lithology and Remarks 1027 - 1800 PRINCE CREEK / TULUVAK Well defined gas fine to medium grained sandstones in upper portion of interval Bounded by siltstones with some very dull sample fluorescence and carbonaceous material. Massive tuff with minor coals. Lower gas sandstone packages less well consolidated with larger grain size and abundant grain/ lithic fragments. SILTSTONE light gray, some medium gray in part, platy, some microlaminations, noncalcareous scattered microcarbonaceous specks, micromicaceous, reworked, tuffaceous- volcanic in part, firm-medium hard in part. SANDSTONE predominately white-very light gray, very fine-fine grain subangular-angular, well sorted, poorly cemented-clay matrix, friable-firm, noncalcareous, increasing microcarbonaceous materiall, mica, trace siltstone, decreasing tuffaceous in part, 50% very pale dull yellow-white sample fluorescence,no cut fluorescence SANDSTONE predominately white, very light gray in part, very fine-fine grain subangular- angular, well sorted, poor cement-clay matrix, friable-firm, noncalcareous, increasing microcarbonaceous material, trace coal fragments, mica, trace siltstone, 50% very pale dull yellow-white sample fluorescence,no cut fluorescence CLAYSTONE very light gray, platy-splintery, predominately bentonite, clean, firm-medium hard in part. SANDSTONE predominately white, very light gray in part, fine-medium grain, subangular- angular, moderately consolidated, 30% very pale dull yellow-white sample fluorescence,no cut fluorescence SANDSTONE light gray-gray, white in part., very fine-fine grain, subangular-angular, moderately-well consolidated, well sorted, microcarbonaceous, micromicaceous, veryslightly calcareous, no sample fluorescence,no cut fluorescence. SILTSTONE very light gray-light gray,some dark gray, platy-blocky very slightly calcareous in part, predominately grading to extra fine grain sandstone, lithic, tuffaceous, microcarbonaceous+micromicaceous, friable-medium hard TUFF very pale light gray, amorphous, puffy, lithic, some crystal fragments, soft SANDSTONE clear-opaque, black, light-dark gray, white, trace green, trace brown, fine- coarse grain, subangular-angular, moderately-consolidated, poorly sorted, quartz, quartzite fragments, chert fragments, lithic fragments, 2% coal fragments, sandstone fragments noncalcareous, no stain odor fluorescence or cut. SANDSTONE light gray-gray, fine-coarse, subangular-angular, moderately-consolidated, well sorted, tuff fragments, very arenaceous lithic fragments,2% coal fragments, sandstone fragments noncalcareous, no stain odor fluorescence or cut. Lithologic Summary ANADARKO GUBIK 3 Depth (ft) Formation Lithology and Remarks ' 1800 - 2750 SEABEE Predominately a massive shale with minor siltstones, tuffs and sandstones. A ' bounding claystone at the base. SHALE medium-darkgray, blocky-platy, massive, clean, calcareous, some micromica, 1 carbonaceous, very firm-medium hard. SILTSTONE light gray-very light gray-white, blocky-amorphous, grading to sandstone in part, calcareous, lithic, soft-firm. j SHALE gray-light gray, blocky-platy, medium firm-firm, hard in part., slightly calcareous. SILTSTONE medium gray, light gray in part, platy, predominately noncalcareous, some calcareous in part, microcarbonaceous+microcarbonaceous, laminations, abundant volcanic+tuffaceous material,some micro crystalline mineral fragments, firm-very firm. SHALE medium gray, light gray in part, platy-subblocky, grading to claystone, dessicated partings along bedding planes, trace disseminated pyrite, microsilty+grading to silstone in part, non-very slightly calcareous,some calcareous fracture filling, soft-very firm. 2750 - 3300 NANUSHUK Tuff and shales in upper portion of zone. Lower section contains interbedded very fine grained well consolidated silty lithic sands with and grading to siltstones. TUFF white-light gray, angular, soft-firm, amorphous, well sorted, non calcareous SHALE dark gray, flaky-blocky, medium firm-firm, well sorted, slightly organic clay well partings carbon material. SANDSTONE light gray-gray, angular to subangular, fine-very fine grain, moderately-well consolidated, well sorted SILTSTONE light gray, amorphous-platy, slightly calcareous micromicaceous, increasing microcarbonaceous, soft-very firm, some bitspin in sample SANDSTONE light gray-gray, very fine to fine grain,angular to subangular, moderately-well consolidated, medium sorted, lithic, slighty calcareous-calcareous, very firm-medium hard , no visible porosity, no fluorescence. SANDSTONE light gray-gray, salt&pepper, very fine to fine grain,angular to subangular, well cemented, moderately sorted, trace lithic, silty in part, non-very slightly calcareous in part, microcarbonaceous specks, mineral grains,no visible porosity, trace calcareous fracture fills, trace pyrite nodules, very firm-medium hard, no fluorescence. Lithologic Summary ANADARKO GUBIK 3 Depth (ft) Formation Lithology and Remarks 3300 - 4100 GRANDSTAND Upper portion of interval has a massive sandstone package bounded by siltstones. Lower section has a massive claystone overlaying a well defined sandstone. SILTSTONE medium gray, platy, micromicaceous, clean, calcareous, firm-medium hard in part. SANDSTONE clear-light gray, angular to subangular, fine-medium grain, moderately-well consolidated, moderately sorted, mica+mineral fragments, some carbonaceous material, calcareous, no visible fluorescence. SANDSTONE clear-light gray, white in part., angular to subangular, fine-medium grain, moderately-well consolidated, tight cemented in part, moderately sorted, abundant carbonaceous material, non calcareous, no visible fluorescence. SILTSTONE gray-light gray, dark gray in part, angular to subangular, firm-hard, very hard in part, non calcareous, no fluorescence CLAYSTONE very light gray-gray, amorphous, soft, trace sandstone inclusions, non calcareous, soft-firm in sample SANDSTONE light gray, angular to subangular, fine-medium grain, loosely-moderately consolidated, well consolidated in part., moderately sorted, calcareous, no fluorescence. 4100 - 4285 TOROK Massive noncalcareous silts tone. SILTSTONE dark gray-dark brown, subangular, firm-hard, non calcareous, no fluorescence i~ 3 1 '' HYDROCARBON NOTES FOR GUBIK 3 & GUBIK 3 BPO1 Gas Scale used for Gas Detection equipment: 10,000 units=100%=1,000,000 ppm gas in air *** 10,000 units gas =gas detector saturated = no air in gas trap or gas trap suction hose Please refer to 5" Mudlog, 5"Gas Ratio log and Pixler Plot Show Reports for more detail. 1) Presence of Methane from commencement of drilling surface to 1027' MD. Uncertain about depth of Permafrost and if the methane is "methanehydrates". Tool temperature data from the MWD phase 4 resistivity tool (shown on 2" & 5" mudlog in Total Gas / Resistivity track) showed 65-80° F drilling the 12 '/4" section. 2) First Indication of Ethane at 1050' MD. 3) Cl, C2, C3, iC4 and nC4 first encountered at 1081' MD. 4) 6500 units gas with 11.7 ppg mud weight from sandstone at 1081-1089' MD (Show Report 1 ). Cuttings samples showed 10% very pale dull yellow sample fluorescence with no cut fluorescence. Some microcarbonaceous material was noted. 5) Mud weight increased to 13.65 ppg after gas peak of 8700 units seen at 1121-1124' MD. This sandstone interval showed an increase in dull pale yellow sample fluorescence to 50%, with no cut fluorescence. An increase in microcarbonaceous material was noted. Possible condensate (Show Report 2 ). r 6) Sandstone interval 1234' to 1292' MD showed first presence of Pentanes in small quantities. Maximum gas in this interval was 10034 units at 1277' MD. First "early connection gas" noted at 1271' MD and early pumps off gas at 1286' MD as coming up before the expected bottoms up lag time (all early connection gases/ pumps off gas and short trip gas maximums were seen at about 1000-1100 strokes ). After drilling this interval early connection gases were noted to 2628' MD (See mudlog). Averaged chromatograph data and Hydrocarbon ratios data contained in the Chart "GUBIK 3 GAS ZONE DATA" collated from the well chromatograph data support that the interval 1236- 1260' MD was the most likely zone for these gas influxes. Cuttings samples in the depth interval 1234' to 1295' MD showed 30-50% very pale dull yellow-white sample fluorescence with no cut or cut fluorescence. Tool temperature data from the MWD phase 4 resistivity tool shows a marked temperature increase at 1210' MD from 90° F to 120° F at 1295' MD. Thereafter temperature was seen to stabilize and increase slowly. See Show reports 3 A, B, C. Condensate potential. -' 7) A sandstone and underlying tuff interval from 1470-1502' MD with a gas peak to 8500 units showed an increase in Pentanes, although there was no sample fluorescence, cut or cut fluorescence (Show Report 6 ). 8) The sandstones drilled from 1586-1645' MD and 1705-1768' MD showed a marked increase in the amount of Pentanes. Maximum gases were seen to 10,000 units in both zones. Cuttings samples showed no sample fluorescence white light cut or cut fluorescence. 2-5% coal fragments were noted (Show reports 7 A, B & Show Report 8 ). 9) A sandstone interval from 1886-1907' MD with a gas peak to 9500 units showed much less Pentanes than the prior intervals with no sample fluorescence, cut or cut fluorescence (Show Report 9 ). 10) Drilling was stopped at 2002' MD to ascertain whether 13.7-13.8 ppg mud weight was correct. A series of pumps off tests were performed and drilling proceeded without mud weight increase. 11) The 8 3/a" hole section was drilled to 2628' MD, where wireline logs were to be run. Mud weight was increased from 14.0 ppg to 16.6 ppg to see if gas from uphole zone at 1234-1292' MD could be stabilized for wireline logging. See Daily Operations Summary, Mudlogger's Daily Summary and chart " GUBIK 3 CHROMATOGRAPH DATA FROM CIRCULATED OUT GAS PEAKS" for details. During these tests "gas bubbles "were noted as coming from the uphole zone at 1234-1292' MD. With a duration of 1-3 seconds breaking out at the bell nipple and possum belly, there were no consistent chromatograph readings to help in identifying exactly where they were from. 12) A sandstone drilled from 3208-3292' MD with a maximum gas peak to 710 units drilling with 16.2 ppg mud weight showed no sample fluorescence, cut or cut fluorescence (Show Reports 14 & 15 ). 13) A sandstone interval from 3529-3623' MD with a gas peak to 2400 units showed no sample fluorescence, cut or cut fluorescence (Show Reports 19 A, B, C ). Mud weight 14) Gas bubbles of 1-3 second duration that averaged near 5000 units were noted as preceding bottoms up for many sandstone intervals with increase in drilled gas from 3085' MD to TD with the notable exception of the large sandstone interva13529-3623' MD with mud weight 15.4 ppg. The gas bubble trend of preceding bottoms up for circulated up gas increases was seen in the Gubik 3 BPO1 sidetrack as well. 15) Preliminary analysis from Pixler plots suggests that the sandstone zones at 1234' to 1292' MD, 1586-1645' MD and 1705-1768' MD could produce gas. 16) No liquid hydrocarbons were noted in cuttings samples as being cut fluorescence, although possible condensate in zones 1121-1124' MD and 1234' to 1292' MD. GUBIK 3 GAS ZONE DATA (AVERAGED FOR INTERVAL ) I DEPTH INTERVAL I GAS I C1 I C2 I C3 I TC4 I TC5 I 1081-1089 3565 74651 8280 5463 1315 3 1121-1130 5161 226690 43866 17696 5460 5 1236-1260 2737 149821 12004 3256 696 8 1263-1266 3827 214781 22384 7977 1692 16 1273-1292 6686 206917 26541 5831 1286 12 1316-1321 7226 222356 33585 13729 3970 19 1475-1489 6059 269393 9405 1903 554 52 1587-1602 4742 253380 15869 3061 965 79 1618-1622 8109 715174 33825 19195 2142 197 1630-1636 9617 814934 33478 8441 3094 686 1714-1721 7414 553816 30212 10997 3819 650 1736-1743 8581 695268 48287 17007 6211 800 1902-1906 3783 320234 16405 4977 1408 59 3537-3543 2154 196413 4225 427 83 10 3549-3558 1713 184060 3747 389 76 8 C1/C2 C1/C3 C1/TC4 C1/TC5 10 22 95 10086 6 14 45 53413 14 57 282 32793 12 40 197 19718 11 51 242 34705 8 23 84 20753 29 141 485 7514 17 106 359 5053 22 111 364 3788 25 118 301 1331 19 51 146 1042 15 42 115 904 20 66 229 12511 47 463 2376 20312 49 474 2417 24334 GUBIK 3 EARLY CONNECTION GAS AND PUMPS OFF GAS DATA 1271-2533 ~ 4653 ~ 191842 ~ 15177 ~ 3892 ~ 911 ~ 6 ~ ~ 16 ~ 63 ~ 267 ~ 158190 ~ ~ i ~ ~ ~ i ~ ~ ~ ~ i ~ ~ ~ ~ i ~ ~ ~ GUBIK 3 CHROMATOGRAPH DATA FROM CIRCULATED OUT GAS PEAKS TIME DATE DEPTH TOTAL C1 C2 C3 IC4 NC4 C4 TOTAL IC5 NC5 C5 TOTAL C1/C2 C1/C3 C1/C4 C1/C5 HOLE GAS m m m m m m m m m ratio ratio ratio ratio units 11:49:01 2/14/2008 2628 3561 256737 17525 3897 585 222 807 11 0 11 15 66 318 23453 13:59:18 2/14/2008 2628 7690 675072 34483 7541 1077 556 1633 6 2 8 20 90 413 87027 19:33:32 2/14/2008 2628 3960 388424 18483 3621 498 178 676 0 0 0 21 107 574 -999 22:57:36 2/14/2008 2628 3880 337379 19481 4947 855 284 1139 0 0 0 17 68 296 -999 22:58:27 2/14/2008 2628 3880 335604 20598 5179 917 328 1245 3 0 3 16 65 270 99092 11:31:10 2/15/2008 2628 10034 903434 46415 8382 1066 448 1514 2 0 2 20 108 597 409302 11:32:50 2/15/2008 2628 10034 855272 44261 8477 1152 464 1615 12 0 12 19 101 530 71719 11:33:41 2/15/2008 2628 10034 857613 44177 8568 1169 471 1640 12 0 12 19 100 523 71399 11:35:21 2/15/2008 2628 10037 872123 45054 9077 1216 589 1806 3 0 3 19 96 483 306588 11:36:12 2/15/2008 2628 10037 921790 47099 9481 1223 668 1890 37 0 37 20 97 488 24681 4:53:22 2/16/2008 2628 7160 627052 19504 2340 214 108 322 0 0 0 32 268 1950 -999 18:41:27 2/16/2008 2628 4690 450465 12268 1169 98 55 153 0 0 0 37 385 2937 -999 9:46:02 2/17/2008 2628 4044 399598 10074 911 70 10 80 0 0 0 40 439 4985 -999 11:30:39 2/18/2008 2628 6998 633813 23190 3338 386 131 517 0 0 0 27 190 1225 -999 7:03:12 2/19/2008 2628 7478 676199 29385 4766 576 186 762 0 0 0 23 142 888 -999 GUBIK 3 GAS CHROMATOGRAPH CALIBRATION DATA CG C1 CF CG C2 CF CG C3 CF CG C4 CG C4 CG C5 CG C5 Time Date Iso CF CG C4 CG C4 Norm CF CG C4 Iso CF CG C5 CG C5 Norm CF CG C5 CG C1 CG C1 RT CG C2 CG C2 RT CG C3 CG C3 RT CG C4 Iso Iso RT Norm Norm RT CG C5 Iso Iso RT Norm Norm RT (ppm) (sec) (ppm) (sec) (ppm) (sec) (ppm) (sec) (ppm) (sec) (ppm) (sec) (ppm) (sec) 14:17:14 5-Feb-08 10000 0.000666 9.96 4980 0.000334 11.48 5000 0.000218 14.76 2500 0.000171 20.5 2500 0.000169 22.54 1000 0.00013 36.68 1000 0.00013 40.84 10:35:03 6-Feb-0B 10000 0.00066 9.98 4980 0.00033 11.52 5000 0.000215 14.78 2500 0.00017 20.54 2500 0.000168 22.58 1000 0.000129 36.72 1000 0.00013 40.86 12:21:37 7-Feb-0B 10000 0.000665 9.96 4980 0.000332 11.48 5000 0.000217 14.74 2500 0.000171 20.46 2500 0.000169 22.48 1000 0.000129 36.58 1000 0.000129 40.7 7:47:39 8-Feb-0B 10000 0.000674 9.98 4980 0.000337 11.5 5000 0.00022 14.74 2500 0.000173 20.46 2500 0.000172 22.48 1000 0.000131 36.48 1000 0.000131 40.6 9:51:49 9-Feb-08 10000 0.000672 9.96 4980 0.000336 11.48 5000 0.00022 14.72 2500 0.000173 20.46 2500 0.000171 22.5 1000 0.000131 36.62 1000 0.000133 40.76 8:21:15 10-Feb-OS 10000 0.000676 9.96 4980 0.000337 11.48 5000 0.00022 14.74 2500 0.000173 20.48 2500 0.000172 22.5 1000 0.000131 36.66 1000 0.000131 40.78 8:23:09 15-Feb-OS 10000 0.000666 10.02 4980 0.000333 11.54 5000 0.000217 14.8 2500 0.000171 20.56 2500 0.000169 22.6 1000 0.00013 36.78 1000 0.00013 40.92 8:51:34 18-Feti-08 10000 0.000656 10.04 4980 0.000327 11.56 5000 0.000214 14.82 2500 0.000168 20.6 2500 0.000166 22.64 1000 0.000128 36.84 1000 0.000127 40.98 3:55:33 19-Feb-08 10000 0.000664 10.02 4980 0.000333 11.54 5000 0.000217 14.82 2500 0.00017 20.62 2500 0.000168 22.66 1000 0.000129 36.92 1000 0.000129 41.06 15:30:28 20-Feb-08 10000 0.000662 10 4980 0.000332 11.54 5000 0.000217 14.82 2500 0.00017 20.6 2500 0.000168 22.66 1000 0.000129 36.94 1000 0.000129 41.12 2:08:53 21-Feb-08 10000 0.000666 10.04 4980 0.000332 11.56 5000 0.000217 14.78 2500 0.000171 20.48 2500 0.000169 22.48 1000 0.00013 36.46 1000 0.00013 40.54 3:22:29 22-Feb-08 10000 0.00067 10.02 4980 0.000334 11.54 5000 0.000218 14.78 2500 0.000172 20.48 2500 0.000172 22.5 1000 0.000131 36.44 1000 0.000132 40.52 5:09:14 23-Feb-OS 10000 0.000666 9.98 4980 0.000333 11.5 5000 0.000217 14.76 2500 0.00017 20.52 2500 0.000169 22.56 1000 0.00013 36.74 1000 0.00013 40.88 18:42:42 9-Mar-08 10000 0.000695 10 4980 0.000347 11.5 5000 0.000225 14.8 2500 0.000177 20.5 2500 0.000177 22.5 1000 0.000135 36.5 1000 0.000138 40.6 ~: 3 ;i,' °R , ~: ,yy.:: ~ zr ":ia::.... i ` ii ...ijii'rx3..: ttf . ~ iij!jiiij:j!ijj Viz:: . j:,3i:x .:I:.,: ' I :If i. i'IYjr ., c ~:.IL:a^:,... .:.y ": .. i u,.., ~,..:o:u.., ' i li i'...a . I 'iili I iijji5iaijr 5::: l . sperry'SUn Well Name: GUBIK 3 Depth (MD) 1080 to 1089 ft ~~ Location: FOOTHILLS (TVD) 1080 to 1089 ft DRILLING SERVICES Operator: ANADARKO Show Report No. 1 -i Show Report Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 11-Feb-08 Report Delivered To: John Kamm i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50%, Itgy,wh, vltgy, of-fgr, ~ sbang, wsrt, mcmt-cly mtx, sme wcmtd, ncalc, sme miccarb, mtl, mica, intbd w/ sltst, tr fri, nsofc. ,% F e; : . , : ,~ . ~ ~ ~.. 7 ::.~,,:::~: :::::,: Depth 1081 ft Gas ---------------------------9 --- iA Flowline Back rou :. ...... :::. : :,: :,,:: , : °i° .... : x Units 6448 Mud Chlorides (1000's) 44 ------------------------------------------------------ nd Show . Hydrocarbon Ratios , C1 C1 C1 C1 E j.il C2 C3 C4 C5 :ja ppm ppm ppm Hydrocarbon Ratios 't? 1000 0 . :~ C1 135688 - 2582 = 133106 C1/C2 = 8.7 :II ' C2 15313 - 64 = 15249 C1/C3 = 12.6 wi 3 l C3 10608 - 6 = 10602 C1/C4 = 58 . iNj C4 2282 - 0 = 2282 C1/C5 = 26621 NPH C5 5 - 0 = 5 -------------------------------------------------------------------------------------- n P d t 00.0 ~--~- ~-- -~ "` iYi ro uc jo I:; Analysis x Gas Oil Water Non-Producible Hydrocarbons `3 2 % ~ ~ ' € :: '` Depth 1082 ft Gas --- --------------------------- s) 44 x Units 4102 Mud Chlorides (1000 ------------------------------------------------------ as ::: ~„ 3iji g Flowline Back round Show ~. :e ij pPm PPm Ppm ,., a; Hydrocarbon Ratios ii 0.0 - ------ - - -------------- .. ~i ~i ; ;~ C1 135688 - 2582 = 133106 C1/C2 = 8.7 ~~ C2 15313 - 64 = 15249 C1/C3 = 12.6 l Oil !~ C3 10608 - 6 = 10602 C1/C4 = 58.3 ` y C4 2282 - 0 = 2282 C1/C5 = 26621 C5 5 - 0 = 5 .; PH ~j ,i; 'ii -------------------------------------------------------------------------------------- ~j Production ICI; Analysis x Gas Oil Water Non-Producible Hydrocarbons °' 1.0 i Ij ii s Depth 1083 ft Gas ---------------------------g -- Flowline Back rou % x Units 4100 Mud Chlorides (1000's) 44 ------------------------------------------------------- nd Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C 1 ;'I 5 ii ~,I' Ppm PPm PPm Hydrocarbon Ratios 1000 0 . C1 273151 - 2582 = 270569 C1/C2 = 6.9 ,I 9 8 39344 j C1/C3 = . ,j C2 39408 - 64 = i "j C3 27632 - 6 = 27626 C1/C4 = 39.7 l ' r C4 6808 - 0 = 6808 C1/C5 = 15916 N P H `' C5 17 0 = 17 F! Z•---------~---------------------------------------------------------------------------- :iii Production 00.0 _______ ~ --~~-~ -- --------- Ii ~: ~: rl ibl H d b d rocar ons y uc e Analysis x Gas Oil Water Non-Pro 4 ° /o 44 hl i 1000' Gas Depth 1084 ft Gas -- i--------------------------- or s) x Units 2277 Mud C des ( ------------------------------------------------------- - ;~: ~' 9 Flowline Back round Show :' ppm PPm pPm Hydrocarbon Ratios 0.0 - - - --------- ---- - ------- ------- .. ijii ,..: ~I C1 127972 - 2582 = 125390 C1/C2 = 11.0 Oil C2 11492 - 64 = 11428 C1/C3 = 16.7 a C3 7535 - 6 = 7529 C1/C4 = 65.0 ' C4 1930 - 0 = 1930 CuC5 = 1567a C5 8 - 0 = 8 i w ------------------------------ ----------------------------------------------- i,~ Productlon ::: Analysis x C~as Oil Water Non-Producible Hydrocarbons ::: e: : ......... ter'::: "f~ ::. ........ ..,:;s;;::,:~:..::..: ~:. .rf:,~:.,.::.:, •~:L; :: L..,.:.: .......... ..:.:,::~::3::: u .,.,... 1 ..ra:j .i~:.~:°i~fi;~;. ;::;::::1 .... :. ~ :: r: r.~ :.e:~ u:x .:.... ........ ,..::.+.r;. .,H.. i.. E. 1.0 . :':!iizeee8:se!$ii „1.3 .......... ~.:.. r'3fjfj' Fiji`! I:I.I iijjjl ~ :I.. eallfiG .'i:r:::s: ~Il::z::z:zl. i j:....: :r:i:;:s;:;;;,:;:;:.:::: ` .i...e]Y.,z:r...arn eY 1.1.. .p.lu~j~iw "13 .. .j; o:if ^eei' ilia ' sperry-sun DRILLING SERVICES Show Report Well Name: GUBIK 3 Depth (MD) 1120 to 1130 ft Location: FOOTHILLS (ND) 1120 to 1130 ft Operator: ANADARKO Show Report No. 2 Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 11-Feb-08 Report Delivered To: John Kamm i! : InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 60%, predominately white to very light gray, very fine grain, subangular, well sorted, medium cemented with clay matrix, some well cemented, noncalcareous, some microcarbonaceous material, micaceous, interbedded with siltstone, tuffaceous in part, friable, 10% very pale dull sample fluorescence, no odor-stain, no cut fluorescence. Fu ... :. :: ........ ~ ~~~~~ n.:.:..:...:...:>... .:: ,~ 1 Depth 1121 ft Gas ~!i---------------------------9 --- Flowtine Back rou : . /° x Units 9390 Mud Chlorides (1000's) 44 ------------------------------------------------------ nd Show Hydrocarbon Ratios C1 C1 C1 Ci - - - C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 279252 - 5054 = 274198 C1/C2 = 4.6 ' E':. C2 60344 - 327 = 60017 C1/C3 = 12.5 i 5 '; C3 22126 - 167 = 21959 C1/C4 = 42 . C4 6493 - 43 = 6450 C1/C5 = 45700 NPH , __ 'i P ti n d 100.0 ----~--'~---- - ,:; ,tl ro uc o ' ` Analysis x Gas Oil Water Non-Producible Hydrocarbons ! 2 ' ----- Depth ---1122 ft Gas ------- --- ' s) ---- 44----- x Units 9385 Mud Chlorides (1000 ------------------------------------------ Gas ;~! '~` 9 Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 0.0 . - - _ - --- --- - . - ---- ------ _ _ ~; ;i! C1 296425 - 5054 = 291371 C1/C2 = a.o !5 I C2 72454 - 327 = 72127 C1/C3 = 10.9 Oil C3 26976 - 167 = 26809 C1/C4 = 35.2 ~' C4 8319 - 43 = 8276 C1/C5 = 32375 ,, `! C5 9 - 0 = 9 PH -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ; '''' ~~' s II! `~ Depth 1126 ft Gas ---------------------------9 -- Flowline Back rou % x Units 5812 Mud Chlorides (1000's) 44 ------------------------------------------------------- nd Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C ' 1 5 ~ :. PPm ppm Ppm °~i Hydrocarbon Ratios 1000 0 : b . '` C1 253771 - 5054 = 248717 C1/C2 = 5.2 48281 C1/C3 = 12 0 48608 327 . = - C2 C3 20935 - 167 = 20768 C1/C4 = 36.4 !° C4 6867 - 43 = 6824 C1/C5 = 41453 NPH N!i ~` ,; C5 6 - 0 = 6 Producbon 100.0 ------- -~~ ~-- --- .r P ibl H d b d ' ' ons ro y rocar uc e Analysis x Gas Oil Water Non- ~ l! 4 % !'' 44 0' Gas `r Depth 1128 ft Gas ,:: i.--------------------------- --- s) x Units 4788 Mud Chlorides (100 ------------------------------------------------------- _ 9 ;,,, Flowline Back round Show „! PPm PPm PPm ~" Hydrocarbon Ratios 10.0 - -- !p! ,:, !,~ C1 262980 - 5054 = 257926 C1/C2 = 5.1 ~! O l C2 51342 - 327 = 51015 C1/C3 = 11.6 i ! R ` C3 22348 - 167 = 22181 C1/C4 = 37.8 ~: :;:~ '" !~ C4 6869 - 43 = 6826 C1/C5 = 28658 9 '' C5 9 0 u - _ NPH .~ ------------------------------- ----------------------------------------------- ~:: Product!on ii=; Analys!s Gas O!I Water Non-Produc!ble Hydrocarbons 'i!i. ........ ,,~...........:.: ~.. ...::,... :.::~~ ........ r :... .. i.. ,......... ,. ~.,.. ,sR I... i..... ~ . ,~. :::: a..6.: t...... ..... uz::l..~: p.~ .. ~,e. 1.0 i,:.:,:.;.,. .: r .., .y~.:. .:.::4 -:. ;,~ .. iii . il. l~.:~,l,l.. ~ l i i . . ...~. .:..~i:ll.,:i ~I:. ":~N' =~':s:;f lii!i!;r::::,::..~t:: ,r :!'rr': .... .........:. ..b~ ;:: ;i ::i~ g ' i 'r °!:r..,~ I iiai ' lM` ~ ~ ! ' ~ ! ! : i ii!,!i°iii':._ .!:ii : ia ~;;.: !iii 'i sperry-sun ~' ii DRILLING SERVICES '! Show Report c ,:. . ; i:.!.. E!.€iliii< iii i ' +i ?e4 .I Well Name: GUBIK 3 Depth (MD) 1235 to 1250 ft , Location: FOOTHILLS (TVD) 1235 to 1250 ft Operator: ANADARKO Show Report No. 3A ,ii Report Prepared By: Mike Daigle! Doug Wilson Date/Time: 11-Feb-OS ~€„ Report Delivered To: John Kamm ~ ii ,: Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 50%, prerdominately white j'~ very light gray in part, very fine to fine grain, subangular to angular, wekk sorted, poorly cemented with clay matrix, friable to firm, NN noncalcareous, increased amount of microcarbonaceous material, micaceous, trace siltstone, 50% pale dull yellow-white sample f' fluorescence, no odor-stain, no cut fluorescence. iII` !!: ::: :: ::: Iii: 1 ,. Depth 1237 ft Gas ~'---------------------------9 --- '' Flowlme Back rou ii.! x Units 3824 Mud Chlorides (1000's) 44 ------------------------------------------------------ nd Show C C Hydrocarbon Ratios 1 C1 C1 Ci - - - 2 C3 C4 C :, ". ! 5 IiK ppm ppm ppm Hydrocarbon Ratios 1000 0 ~I' . ~; C1 201818 - 5428 = 196390 C1/C2 = 14.1 ;~; ~ II ~ C2 14234 - 295 = 13939 C1/C3 = 49.5 0 'I~ C3 4074 - 106 = 3968 C1/C4 = 244 . C4 843 - 38 = 805 C1/C5 = 13093 NPH C5 15 - 0 = 15 -------------------------------------------------------------------------------------- ti P d 100.0 --- ---- .-~ IN! on ro uc iI Analysis x Gas Oil Water Non-Producible Hydrocarbons ~' ,: 2 ` % r. ii !; ' !!. ,; ,!i, Depth 1238 ft Gas Iili--------------------------- --- s) 44----- x Units 2489 Mud Chlorides (1000 ------------------------------------------------- Gas 9 ~' Flowlme Back round Show a; a' PPm PPm PPm Hydrocarbon Ratios 0.0 _ - - - - ~~~- - ---- _ ! =i t' "I !~ C1 - C1/C2 = 18.1 203871 5428 = 198443 iI C2 11269 - 295 = 10974 C1/C3 = 82.5 ~a Oil :! C3 2510 - 106 = 2404 C1/C4 = 419.5 i ! Its C4 511 - 38 = 473 C1/C5 = 15265 I:. C5 13 - 0 = 13 NPH !is `'-------------------------------------------------------------------------------------- Production '~! Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 !iI ;~; 3 i!.u, Depth 1245 ft Gas °---------------------------9 -- Flowlme Back rou % x Units 4298 Mud Chlorides (1000's) 44 ------------------------------------------------------- nd Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - 3 C4 C li 1 5 i, ,. ~~~ ppm m m pP PP Hydrocarbon Ratios II i 1000 0 ' '' ti . ! C1 270685 - 5428 = 265257 C1/C2 = 11.3 li'! C2 23864 - 295 = 23569 C1/C3 = 50.9 'M 'ili C3 5313 - 106 = 5207 C1lC4 = 296.0 II ;li: C4 934 - 38 = 896 C1/C5 = 13263 NPH ! ;:! iii-------------------------------------------------------------------------------------- P d ti 100.0 ---- ~ --- ' - --- - :.: IIjI ro uc on '! Analysis x Gas Oil Water Non-Producible Hydrocarbons ~ l '' 4 % ' ' Gas iiii "; Depth 1249 ft Gas s) 44 x Units 3976 Mud Chlorides (1000 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 0 - - --------- - _ . - --- ------------- ---------- --- . ~~ C1 240882 - 5428 = 235454 C1/C2 = 8.2 I Oil 20.8 il C2 29079 - 295 = 28784 C1/C3 = !~ C3 11429 - 106 = 11323 C1/C4 = 81.0 ' C4 2946 - 38 = 2908 C1/C5 = 16818 I` 14 !!!! C5 p - 14 ;!i - - NPH : ii; ; . . - ------- -------------------------------------- i''€------ ------------------------ !I Production `!' Analysis Gas Oil Water Non-Producible Hydrocarbons ::: ::: i.. .. ... :: ......... ..:. :.............:.::..! !...:..........:... :.............!. .. ::... ......... . . ........ ....r:. : .. .. ~! 1. is !.:. Jn € :.:. i.ur..u. ..E.. n:€: i...ursar.; u, :....:: icy:::::::..:.....: ~..........:.. ~ . !i .. .~:: ... :r. y.>uu;...:..n;. : ~: §. i.a,,. ^.e:v.n i ii!:i:i::::uuu;u: d. .. •~ :::...:..:.,-~ i..... .:......:..!:!::r:::....: i I H. ..:.. .:: ~ ........:::::..:.N~ .,!.,.. ~~..>.:..:::.! .:. €..::....... I € I III I............ !. ::::..........:. :. .I I I'....:::::::::::... 1.0 ....!. ..... a •n...i i .u:n: r.u:n~i i.::. !...:........ i.i..l..::: ......:.... I!......I. .. I ..:. •!!:..!... : ':pp!!e L. N I i... ~..ua;u, yi i.. noo..:. i .. : i .. :...1. I...:.!.:.....:..!.:.IU.,: .!..i,,.i I: ~ I....... 6 i!'I..'.:'.''u. e':~:!!!::!&" q.: ''.. a:..u: ~ :. .. 1.... .N .~ ..:.li.n i. E .. R:. ... .:i ... i u. .. . .,::::.:..:....:....!.....I.....II: .:. :.: ... I ... ........... E.: ; t ,5 niH '7.:2'4v:.. e. ..... ... ......:.,.. q:Y;.:. :~ : :: :0: ; i :.: ' ... :: , ~ ~ ~ :::~: ~ `~ : ~ iri : jiiii i;i,r:.: i:. °.~-~:~: i - .. !; ~u~ I' !~' "~ , : ,;. i ; : ii :!. .:. ~i:i::::ud sperry-sun DRILLING SERVICES Show Report , ~ .~ s :. ::.. .. :::. well Name: GUBIK 3 Location: FOOTHILLS Operator: ANADARKO Report Prepared By: Mike Daigle/ Doug Wilson Report Delivered To: John Kamm .:.: . . ~ :.u : ~ ~::i~::! Depth (MD) 1250 to 1270 ft (TVD) 1250 to 1270 ft .! Show Report No. 36 Date/Time: 11-Feb-OS a- Ve ~ .:::::.: ~: :::. .. ,~~::. ., i~ "s . ....:,:; ::. ::.::.:~:.: ..:~:. :. l ~`i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 90%, predominantly white, '~' very light gray in part, fine to medium grain, subangular to angular, moderately consolidated, 30% very pale dull yellow white, sample l : fluorescence, no odor-stain, no cut fluorescence. ~' ~i yE ~ :! A ~ % ._ Depth 1252 ft Gas x Units 3740 Mud Chlorides (1000's) 44 ,: ---------------------------9-------------------- Flowline Back round Show C - C2 1 Hydrocarbon Ratios C1 C1 C1 - - - C3 C4 C ~ , 5 ! : C psi ,s ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 230015 - 5530 = 224485 C1/C2 = 11.9 i C2 20042 - 1164 = 18878 C1/C3 = 39.7 :. ~ ~~ C3 5862 - 201 = 5661 C1/C4 = 186 8 C4 1213 11 = 1202 . C1/C5 = 17268 NPH - ---------------------------------------------- ------- ti P d 100.0 -- -------- ------ ---- ---- :: ! :: , on ro uc ~ , Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 ~ ! ' t ' : ` .. i'? : Depth 1258 ---------------------- ft Gas --- ----- x Units 1943 ------------------- s) 44 Mud Chlorides (1000 ------------------------------- ---- Gas : ,i; ~~~ :. Flowline Ppm g Back round Show PPm PP-n ydrocarbon Ratios 0 0 _ - - - ~ - - - ~ - ---- _ - --- : ., :; - ~:: . ~~ ~~ C1 165888 - 5530 = 160358 C1/C2 = 22.9 h~ C2 8169 - 1164 = 7005 C1/C3 = 110.7 Oil Y C3 1650 - 201 = 1449 C1/C4 = 477.3 t ,~ i C4 347 - C5 10 - 11 = 336 0 = 10 C1/C5 = 16036 NPH ! yi :: ~; d s -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ~i 3 !: De th 1263 ft Gas -------- P -----------------9 --- Flowline Back rou % x Units 6185 Mud Chlorides 1000's 44 -------------------------------- ~-----~-------------- nd Show C - C 1 2 Hydrocarbon Ratios C1 C1 C - - - C3 C4 C 1 5 ; ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 141379 - 5530 = 135849 C1/C2 = 18.3 it C2 8582 - 1164 = 7418 C1/C3 = 62.4 ~ :. °k ~~ C3 2379 - 201 = 2178 Ci/C4 = 290.3 , "` C4 479 - 11 = 468 C1/C5 = 27170 NPH :,, ^ C5 5 - 0 = 5 -------------------------------------------------------------------------------------- P d t 100.0 ------ - - ' ~-- ` l ~' = ro uc ion b Analysis x Gas Oil Water ons Non-Producible Hydrocar `zi; 4 % "" •: , :;!; ' as !~! ' !~ :i; Depth 1265 --------------------- ft Gas ------ -- x Units 6872 ------------------- s 44 Mud Chlorides 1000 -------------- ~----- ~ ------------- :: Flowline PPm 9 Back round Show PPm PPm ydrocarbon Ratios 0.0 _ _ _ . - ----- :::, ~i '~ ' C1 288183 - 5530 = 282653 C1/C2 = 11.3 ! Oil ;;~ C2 26186 - 1164 = 25022 C1/C3 = 21.1 _~ C3 13574 - 201 = 13373 C1/C4 = 97.7 :::: ,,,; "' ~ C4 2905 C5 26 - 11 = 2894 _ 0 = 26 C1/C5 = 10871 : h ' .,; !li ! ------------------------------- ----------------------------------------------- Production y y Anal sis Gas Oil Water Non-Producible H drocarbons .an.... :uq ~ a ~a::..::..:-::. : ~.! . I .azi:. :: .. ....... .:.... ........~ 15 ~L.:. ~:. 1.0 . . € . j' .:rui is ;piRiiiii~[[[:~ i : ~ €~E:E . p ~ it h.:.; ..: ......••' ..... ~:::::.:r...o .. i:. . •::jeeee '"' .... ::I,:u:gn,::.: e: it ~.'iijle:iFli'nji5°li~i irli; f~i sperry-sun DRILLING SERVICES Show Report :,... ~ a: i i l i iii I:e'ili iiiii i'i:'i6t::^' ii , 1 it ` e Ails Sn { i,i iii;l'~'iT~1t. :I~e:Mi.: .: i. ' .i...:.i:i:..rai~..:m: . i ., 'i liP.!.',eee9u> . ,ii€iiiiii~€%~ .li! .iWl.u, iiPilP . :~": Well Name: GUBIK 3 Depth (MD) 1270 to 1280 ft Location: FOOTHILLS (ND) 1270 to 1280 ft Operator: ANADARKO Show Report No. 3C `! Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 11-Feb-OS ' Report Delivered To: John Kamm i~ : q . .,:. , e. .: :,:ua:i:ipypy : J ~ ;, , . . : a ..:; : ~ .. ..y..~ .. ::.: , u::: I:I:.zi:iz:i:: II1 'i:.l Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 90%, predominately white ~~ very light gray in part, fine to medium grain, subangular to angular, moderately consolidated, well sorted, 30% very pale dull yellow-white sample fluorescence, no odor-stain, no cut fluorescence. ci ;~, E 31 i, l ~~ ... r ~ Depth 1272 ft Gas rou Flowlme Back % x Units 4771 Mud Chlorides (1000's) 44 nd Show C C2 Hydroca i C C rbon atios 1 C1 C1 3 C4 C 5 g ~; Vii' PPm PPm PPm ~~ Hydrocarbon Ratios i 1000.0 C1 236511 - 2334 = 234177 C1/C2 = 7.8 C2 29996 - 161 = 29835 C1/C3 = 41.5 1 C3 5671 - 31 = 5640 C1/C4 = 207 . 1'i C4 1136 - 5 = 1131 C1/C5 = 29272 NPH C5 8 - 0 -- $ ----------------------------- i---------------------------------------------- ------- :: P d ti 100.0 ----- - --- -- ~ ~ , -------- ---- ro uc on ~~ Analysis x Gas Oil Water Non-Producible Hydrocarbons :Si '' . Fi • 2 % ' ; ' - -- Depth ---1274-- ft Gas s) ---- 44----- x Units 8936 Mud Chlorides (1000 Gas i;~ Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10.0 _ -- - _ _ _ _ - -- .. ----- --------- I t~ C1 328570 - 2334 = 326236 C1IC2 = 5.a i ? i ii Ij C2 60482 - 161 = 60321 C1/C3 = 26.2 I14 - I~i C3 12471 - 31 - 12440 C1IC4 = 119.6 Oil ;~ C4 2733 - 5 = 2728 C1/C5 = 14829 _ C5 22 0 = 22 I ii; '_' { -------------- .------------------------------------------------------------------------ i Production r Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 :i i 41 g ''~ Depth 1276 ft Gas '---------------------------9 -- Flowl~ne Back rou % x Units 10030 Mud Chlorides (1000's) 44 ------------------------------------------------------- nd Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C 1 t' 5 ; ppm ppm ppm Hydrocarbon Ratios 000 0 ''` !ill ,;i . ;;; C1 336111 - 2334 = 333777 C1/C2 = 4.7 19 3 "' . C2 70883 - 161 = 70722 C1/C3 = ; C3 17296 - 31 = 17265 C1/C4 = 83.6 . C4 3996 - 5 = 3991 C1/C5 = 13351 NPH ~< /i C5 25 0 = 25 ---------------- ---------------------------------------------- -------------------- P d ti 00.0 _ --- _ ~ ---- - -- -~' - - --- -------- h: i ro uc on b ons Analysis x Gas Oil Water Non-Producible Hydrocar s l': 4 . ' Gas ~ Depth 1277 ft Gas --------------------------- -- s) 44 x Units 9904 Mud Chlorides (1000 ------------------------------------------------------- _ _ ::: 9 Flowlme Back round Show ppm PPm ppm Hydrocarbon Ratios 10.0 _ _ _ - --- - --- . - --- ------------ ---------- ---- C1 342585 - 2334 = 340251 C1/C2 = a.4 Oil C2 77278 - 161 = 77117 C1/C3 = 17.2 Fj~ iii C3 19794 - 31 = 19763 C1/C4 = 72.8 ,:! 1.. ;iii C4 4676 - 5 = 4671 C1/C5 = 11733 'i C5 29 - 0 = 29 iii NPH ~ ::i------------------------------- ----------------------------------------------- Production ':': Analysis Gas Oil Water Non-Producible Hydrocarbons ..~ :. :::::: ; ..P. .......... ........................... ...... ::,,,,...............i:,:, .,.. w... :JZi:F'.. y .: i 'f'G'eE'r.':f:!:i..` ~YE;''i'il]iiiie::~fi?::~ :ani:i:e:i:1:i:B1:1:],::e'•e 'e'ei:eal:::::~•i.^.,^x .k:i ~;illi:ii~::~:::~ ~::::~:~:;:::.:~:~i~:::::::::::::::.::..:e:e.... <~e'~ .i.. i::........:. ~iR'i2ii~.a?!' {...... w.. I.. .T. ...d.. .al:j;~°:"•:, w.... ................ ~.y.::. uarcxa..uuub:::x..r. .:... .......... ... ... ....................................... .`'v..:... ~:... :! .. ..... .i ................1:;4:6: .:.....q......,....q!(, ..i:i:i::u::: u:. unp E.: :..:::::.::.>:.::.:: ~.:: wrrruuuuuxw...: {,:.. 1 ........ w ....................... .. ....... ...... .. 1.0 ..ii...:.;.:.; ., f ..I.. :..9{ i~ ......n... .i,,: i:l iilii I. .. u...:..::: I ..... : :. i!ik:. i:. I:iAl ~-;.., ',.: 'e!Ifiz.....H.., ..~:eyy.. :IC:p: ...uu.•u: ...5.....:~lil1~~~ .. ... .us;:: ....u,e....a..u.. "' :lili E . [i~rT ,. E ~: ililiiii?i i`E!l!Ell'41~::i`i'i~iiiii i ii. ";i'i ` ~... $ T! ~; ~. iii i;;, i, i y i:l y i rb:iE4.y i .'~r. I '..I ~ -L I'ii ~ i ~ i i ixi: ` . :'i !: ~ '~ ~ i : ...::..:........:.......: ....., r': iHi sperry-sun ~' DRILLING SERVICES Show Report ~i '!! , . .; ~ . . . :.::: ::.::...: .. . .,., :. .• Well Name: GUBIK 3 Depth (MD) 1280 to 1294 ft Location: FOOTHILLS (TVD) 1280 to 1294 ft ; Operator: ANADARKO Show Report No. 3D -i!i Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 11-Feb-08 II'~ Report Delivered To: John Kamm k InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 90%, light gray to gray, ~' white in part, fine to medium grain, subangular to angular, moderately consolidated, well sorted, 30% very pale yellow white sample iii! fluorescence, no stain-odor, no cut fluorescence. I :: :: ~:: :e? . ~ . , ...:u::..:. i::: : ~~ 1 `€Ii Depth 1280 ft Gas ,,; i:i: iIEI---------------------------9 --- Flowlme Back rou :.:...u 1.~ °i° x Units 5797 Mud Chlorides (1000's) 44 ------------------------------------------------------ nd Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 iii v '~i ppm ppm ppm Hydrocarbon Ratios 1000 0 . z C1 274654 - 2334 = 272320 C1/C2 = 10.8 ' I C2 25344 - 161 = 25183 C1/C3 = 57.5 k iili 7 'I~ C3 4769 - 31 = 4738 C1/C4 = 283 . C4 965 - 5 = 960 C1/C5 = 27232 NPH ~°~E ~: C5 10 - 0 = 10 ... ~:= Production 100.0 -~ sis x Gas Oil Water Non-Producible Hydrocarbons ~~` Anal y l iii iI 2 ~ ;iii ^~ ' ~i Depth 1285 ft Gas '~ --------------------------- --- s) 44 x Units 7496 Mud Chlorides (1000 ------------------------------------------------------ Gas 9 Flowline Back round Show I PPm PPm PPm i Hydrocarbon Ratios 10.0 . - - ~- -- -------- _ _ - . ------------ _ _ C1 261432 - 2334 = 259098 C1/C2 = 11.2 C2 23381 - 161 = 23220 C1/C3 = 61.4 Oil li ,: C3 4254 - 31 = 4223 C1/C4 = 312.9 C4 833 - 5 = 828 C1/C5 = 25910 ^~ C5 10 - 0 = 10 ' NPH -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ~~' a ri ~~ Depth 1290 ft Gas ::i---------------------------9 -- ~~ Flowline Back rou % x Units 9351 Mud Chlorides (1000's) 44 ------------------------------------------------------- nd Show C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C 1 ! .. 5 P ppm ppm ppm ~;` Hydrocarbon Ratios 1000 0 . i IIj C1 318532 - 2334 = 316198 C1/C2 = 12.6 i i !iu 3 = 52 / 3 25101 . C1 C ;. C2 25262 - 161 = C3 6074 - 31 = 6043 C1/C4 = 258.8 ;i,l C4 1227 5 = 1222 C1/C5 10200 :: - _ NPH , ~i.. , '~' i , iii C5 31 - 0 = 31 ----------------- -------------------------------------------------------------------- Production 00.0 ------ - - --------- ~ ----------------- ::: 3,i? <; i!: ibl H d b P d `ii ons y rocar ro uc e Analysis x Gas Oil Water Non- 4 % ii r ~ ~~ 44 0' Gas : Depth 1294 ft Gas ~ .: I,G -------------------------- -- ' s) x Units 3354 Mud Chlorides (100 ------------------------------------------------------- _ - - 9 :lii Flowlme Back round Show I! PPm PPm Ppm Hydrocarbon Ratios 10.0 - - - ---------- ----- _ --- ------------ -- !~ ~; ;; C1 232317 - 2334 = 229983 C1/C2 = 21.1 Oil t':. C2 11047 - 161 = 10886 C1/C3 = 108.0 .Iii ~,: "~ is C3 2160 - 31 = 2129 C1/C4 = 473.2 I' C4 491 - 5 = 486 C1/C5 = 16427 iii iii: C5 14 - 0 = 14 ii NPH : :. iii------------------------------- ----------------------------------------------- I! Production ,. Analysis Gas Oil Water Non-Producible Hydrocarbons :. :........ n:.i ..~....:... :'i•i'i` .:.~. .i:.y...:.e.. ~..: :..f: Via. .. h.. :!! ::::: ::.:.:.u:....:yy.........;.. I.t. :. :.uuEAF:::w`; % ..... ... :'.::...... .: .:..:..:..::9F.E:Jia:z.... ::: ~. ....:..:..:... ~+.. , ...:.......;::... ~~~ 1.0 { ~. E.li. ~. E :: E I.:: i'%iG%s:: ..Et...ee::::•• ....::psn...:...r:9 J a i .,ii:,:::.a,:::.,::3 .,i;:::;.... ~ E~ ,.3:^e^.. ~ E...pp p... 5 Vii' i 1~.. .i:31::.: !:: i. .~ ... S Ni. . II !3 : ~. M:h[ .. i.: . ii:. i {.~.4...::~ . ••.i : ... ~E:::x.z~ !l:. +E 4~1 .::.... E e;?:'a:. ~ :: gf:i Zq: j !;! .:. is: .,q:: ., ' '1 . .eei ~eii, i 3eil. :,. ... a ,..~,. .i ,ii'iie "ii" :iei SE eiY.eiiii e;ej, 4uii~'Y,fil:i::y: :ei;^:Yinuif^ ^"SiL:+:fiy'n,:'io:if 1.. aLiu:u.~' i.,. ie'fi al:f'E':Ee:l"F:,[Leee~. ..1 :iufj;iiA$:e :..:.n..>~:....~... f . .. ! :ii iiii'riii:i: „• i i5:i? i i:i :lil l' ,, C"' l ' ' ~. ~ . y.....a. .. .. ,:, i~' eee !' s er 'SU11 e! ~! ~ ~ k DRILLING SERVICES Show Report ~ . . ! ; ;a . isi8„ee,,:u.,... i:. .... rte:.. ::... i , ......:::.:~ u::.:r ~ i H i rl [:3[~~ i i i ~ , ': Well Name: GUBIK 3 Depth (MD) 1313 to 1327 ft l Location: FOOTHILLS (TVD) 1313 to 1327 ft Operator: ANADARKO Show Report No. 4 Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 11-Feb-08 Report Delivered To: John Kamm ,: .. .. ,:~ . : , :.:. .. . . :: .i:i:~i: i~.~ , Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 90%, light gray to gray, r white in part, fine to medium grain, subangular to angular, moderately consolidated, well sorted, 30% very pale dull yellow white sample a I , fluorescence, no stain, no cut fluorescence ti ~: ~ 1 Depth 1317 ft Gas .:---------------------------g --- 'i Flowlme Back rou = /° x Units 10034 Mud Chlorides (1000's) 44 ------------------------------------------------------ nd Show atios Hydrocarbon ~ C1 C1 C1 C1 - - - - C2 C3 C4 C5 ':: ': eet te t ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 332363 - 35624 = 296739 C1/C2 = 4.1 f C2 74412 - 2502 = 71910 C1/C3 = 11.6 C3 26173 - 567 = 25606 C1/C4 = 42.2 (re C4 7155 - 129 = 7026 C1/C5 = 6901 NPH ~.; I' lli C5 43 - 0 = 43 ::: !i -------------------------------------------------------------------------------------- ~~ Production 00.0 ---------------- ----.-~-~-- - ' ------------ I.: " ' ° ~ Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 44 ' Depth 1319 ft Gas -------------------------------- x Units 9077 Mud Chlorides (1000 s) ------------------------------------------------------ Gas ei ,. i s Flowline Background Show 1 ie eeei PPm ppm PPm ~ Hydrocarbon Ratios 10.0 _ _ . ~ ~ ----- - _ - - ---- ------ ---- _ _ ----- ------- f i`ii r;! a C1 317987 1 35624 = 282363 C1/C2 = 5 . - 4 7 '3 C1/C3 = 10.1 C2 57939 - 2502 = 55 3 Oil ='i C3 28510 - 567 = 27943 C1/C4 = 31.7 C4 9025 - 129 = 8896 C1/C5 = 9412 ;;~~ ~'• C5 30 - 0 = 30 ------ €' NPH 1 it,; iue ily a - ------------------------------------------------------------------ ei~ Production eI! Analysis x Gas Oil Water Non-Producible Hydrocarbons .0 r . ~!; ~; e g % Depth 1324 ft Gas x Units 4361 Mud Chlorides (1000's) 44 .i .lee---------------------------~ --------------------------------------------------------- le Flowline Back round Show C C Hydroca 1 C 2 C rbon Ratios 1 C1 C 3 C4 C 1 °, e` 5 14i PPm PPm PPm i' Hydrocarbon Ratios 1000 0 'I" ! . C1 273935 - 35624 = 238311 C1/C2 = 17.0 ~ 1 2502 = 14038 C1/C3 = 67 16540 ' ~' . C2 - i C3 4119 - 567 = 3552 C1/C4 = 225.9 "^ C4 1184 - 129 = 1055 C1/C5 = 15887 NPH ~' r~ C5 15 - 0 = 15 ---------------------------------------- Production 100.0 _ ----- ' ~- --- -- - ! ,iil b N P d ibl H d eie W rocar ons on- ro uc e y Analysis x Gas Oil ater le ~ e 4 % ` 44 1000' i M d Chl id Gas e De th 1327 ft Gas >= -------- p --------------------- B k ts 5604 u or es s x Un ------------------------------------------------------- d Sh ~ - .1 `' !~ Flowline groun ow ac ::. ppm pp-n Ppm lief ;Ii Hydrocarbon Ratios 0.0 - - - - _ .. ;eee eeei eeee C1 35624 = 67126 C1/C2 = 17.4 102750 - Oil " C2 6351 - 2502 = 3849 C1/C3 = 53.6 e'e e C3 1820 - 567 = 1253 C1/C4 = 193.4 l f C4 476 - 129 = 347 C1/C5 = 16782 C5 4 0 4 NPH e ` '' ------------- ------- ------------------------------------ 1-- ----------- -- ~j Production ii!! ei Analysis caas Od Water Non Producible Hydrocarbons i.:: 14:: ' n a . , : ... ,, rbi.;; a ":' .. T. :....::u.... .. . v .:..::... ...•.......... eE l 1.0 ..i ..i.i:l:.e : .i....e....l.:l.eiei:e ii iif'~ i. ..f... ..f i ....::: i ...i a l ... . .............. .h:, ill! el:.e 'i 1i1~ye rsi... eie rei'e ..i N:::::i: iiq. eyeee,:::a::,I .., „ ... i lu ie" 'iJJEi ~!yz:x3::a~:;:, eef eI eee. i.,, ' .. Lr~..; eeB?'.' e,.f.. .:: :leuuunirzi:z'.`:.`..... •'e:iY' i I ...eee if ...~ f .. rii i'i; li'.'!ie 'el.... iii i']i i!i i .... !: v ~' ~!, ~:i!!!i'!i. ~ perry'SUn DRILLING SERVICES Show Report .. . . 'uii::!!~!' ! 19:, i'!!.!~.s!!! Well Name: GUBIK 3 Location: FOOTHILLS Operator: ANADARKO Report Prepared By: Mike Daigle/ Doug Wilson Report Delivered To: John Kamm , •!:!i! yi ~r!!r.liiil., s~ ~~' Depth (MD) 1368 to 1375 ft (TVD) 1368 to 1375 ft Show Report No. 5 Date/Time: 11-Feb-OS 'ili ~~~ ~~ Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone 40%, light gray-gray, very fine grain, subangular, moderate sorted, poor cemented, silty-grading to siltstone, some carbonaceous material, no sample '!'! ~; fluorescence, no cutfluorescence. ~ ~ ,~ ` ! 1 °io Depth 1369 ft Gas x Units 4203 Mud Chlorides (1000's) 44 Flowline Background Show C1 C2 Hydrocarbon Ratios C1 C1 C1 C3 C4 C5 ! ij ~~` iu! PPm PPm PPm Hydrocarbon Ratios 1000 0 . <` C1 136334 - 47799 = 88535 C1/C2 = 21.5 C2 7079 - 2965 = 4114 C1/C3 = 97.9 ` C3 1738 - 834 = 904 C1/C4 = 388 3 ~ l C4 453 - 225 = 228 . C1/C5 = 12648 NPH ' ~, !'~ C5 8 - 1 = 7 Production 100.0 - --- --~-~----- ---------------- e Analysis x Gas Oil Water Non-Producible Hydrocarbons !I 2 % ~ Depth 1370 ft Gas x Units 4676 Mud Chlorides (1000's) 44 Gas !, ,;:: ~ !i'! ia ~, --------g --------------------- ------------------- Flowline Back round Show PPm ppm PPm ------ ------------------------------ Hydrocarbon Ratios 0.0 - - - - - ----------- _ _ _ - - ~ _ i ! C1 270664 - 47799 = 222865 C1/C2 = 18.8 !~! C2 14822 - 2965 = 11857 C1/C3 = 104.5 ! F Oil ` C3 2967 - 834 = 2133 C1/C4 = 390.3 `! :> II C4 796 - 8 C5 - 225 = 571 1 - - C1/C5 = 31838 .,. :,: -!! r!! illl !iii ------------------------- Production Analysis x Gas ------------------------------------------------------------- Oil Water Non-Producible Hydrocarbons 1.0 ;;!!. g °io Depth 1371 ft Gas x Units 4600 Mud Chlorides (1000's) 44 ------------------ -------------------------------------- ---------9 ------------------- Flowline Back round Show C - C 1 2 Hydroca C - C rbon Ratios 1 C1 C - - 3 C4 C 1 iiii 5 its 511 !li! pPm PPm PPm Hydrocarbon Ratios 000 0 ,. ! . ~" C1 289399 - 47799 = 241600 C1/C2 = 17.9 1 13506 2965 C1/C3 = 112 8 - C2 1647 = . C3 2975 - 834 = 2141 C1/C4 = 406.7 C4 819 - 225 = 594 C1IC5 = 30200 NPH !!:: !i "!~ ;! '! C5 9 - 1 = 8 _ Production 00.0 --------- - -----~-~- - ------- --------- ! ~` H d b N P d ibl !III Analysis x Gas Oil Water y rocar ons on- ro uc e !ia 1 4 ~' 44 1000' M d Chl id Gas :: !:: .i ~ De th 1372 ft ------- p --------------- Gas -- --- x Units 4000 ------------------- u or es s ------------------------------------ _ - ~ ! 9 Flowline Back round Show ppm PPm PPm Hydrocarbon Ratios 10.0 - _ _ ... _ _ - - !! !~ ; C1 235611 - 47799 = 187812 C1/C2 = 23.8 i O l k C2 10850 - 2965 = 7885 C1/C3 = 142.1 i ~ !!! C3 2156 - 834 = 1322 C1/C4 = 517.4 , `~` i!€ C4 588 - C5 6 - 225 = 363 1 = 5 C1/C5 = 37562 NPH !~ !iil .,, :. ::: '!!' :::: _ Production ------------- Analysis Gas Oil Water Non-Producible Hydrocarbons ,. .......,, ....:... .t. ,.,.,.,:::a..::::.: ...... ::...... ... .. ........... ,..,.. r . : ... ............ . .i,.., .. ,..,...... d~ r..,.... N. .... .,......, ,. . , . .. ~. ... ........ ,. i .. ..... .:::~ .:... ... .. ..... ....... .. n.,. 'Y 'i ..... ... ........................ ... ,.. ............. a, ... , .,~., ..,.. i ..a.....1.. .... !. 1 , ... 1. t .~..... ......., .,.. .... : . .., !i . ::.::. ,....::~~ N ', 6:: ....~c ......... a,. .. ....:..... ...,,. . :i : :.. i! : . ~ ~: i. ~ ,:.:.,:,.. ..~,y: .. .... !~ ,.I sperry-sun ~: I;~ DRILLING SERVICES Show Report ~ . .."li ~ '!i'il1i41111?i:i:i ~a:i:ri::'..E:'s ~ liiil'.i::,.::i:i:,ai,a~ il:l.i~ill!:9~9!an"i ..:^... .... ~.. A1syEiYJjEl?EEE'a. .., I.,:,p .:. .... , ~ ..... ,.. i~; Well Name: GUBIK 3 Depth (MD) 1470 to 1495 ft I i Location: FOOTHILLS (TVD) 1470 to 1495 ft (j Operator: ANADARKO Show Report No. 6 ~' Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 12-Feb-08 v Report Delivered To: John Kamm -iii ~ jii; ! !!" Inter retation: Chromato rah as in air anal sis from as tra at ossum bell 'll P 9 P 9 Y 9 P P Y~ ~I~ Formation: Sandstone-light gray to gray, white in part, fine to medium grain, subangular to angular, moderately consolidated, well sorted, carbonaceous, micromicaceous, very slightly calcareous, no sample fluorescence, no cut fluorescence or white light cut. I2 I= i ~i 1 la! Depth 1477 ft Gas i~ ------------------- Flowline Backgrou °i° x Units 5566 Mud Chlorides (1000's) na nd Show ~ HydrocarbonRatios C1 C1 C1 C1 C2 C3 C4 C5 iII I IiEi ppm ppm ppm Hydrocarbon Ratios 1000 0 . r' C1 286632 - 46036 = 240596 C1/C2 = 28.2 I` C2 11558 - 3038 = 8520 C1/C3 = 144.1 1 5 `II C3 2486 - 816 = 1670 C1/C4 = 474 . C4 718 - 211 = 507 C1/C5 = 3645 NPH C5 67 - 1 = 66 ~` Pr duction 100.0 ----~--~-~ o ! ! Analysis x Gas Oil Water Non-Producible Hydrocarbons ! it 2 ' ----- Depth ---1482 ft Gas ------- --- s) ---- na x Units -- 8404 Mud Chlorides (1000 - ---------------------------- ----- Gas ::: 9 ~ Flowline Back round Show ;ry' Iiii pPm PPm PPm Hydrocarbon Ratios ~li ~ 0.0 ------- - ---- _ ~ ~ - - ----- ----- ~ ---- -------- Sri ~ ,i, NI ~' ! :il : '~ C1 344916 - 46036 = 298880 C1/C2 = 34.3 '' C2 11756 - 3038 = 8718 C1/C3 = 265.2 Oil `` C3 1943 - 816 = 1127 C1lC4 = 803.4 C4 583 - 211 = 372 C1/C5 = 4598 !i. ,,, ~~ - - - 1 65 66 !~ C5 N ------------------------------------ ------------- ---------- ------------- -- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 0 ~~ g liii ::: Depth 1486 ft Gas ilii "~ ---------Flowline ----Backgrou % x Units 6681 Mud Chlorides (1000's) na nd------- Show -------------------------------------- C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C iiii 1 ~! :. 5 ppm ppm ppm Hydrocarbon Ratios 0 1000 5 46036 = 281284 C1/C2 = 37 327320 . . - C1 i ,~ , s 7497 C1/C3 = 218 0 10 3038 3 . = 5 5 - C2 `'3` C3 2106 - 816 = 1290 C1/C4 = 648.1 ~ i;.; C4 645 - 211 = 434 C1/C5 = 3853 NPH :E C5 74 - 1 = 73 Production 100.0 ~~-~- - ---- --------- ii i H d b l ~! y rocar ons b e Analysis x Gas Oil Water Non-Produc ~ ' i~; 4 hl i 1000' Gas Depth 1488 ft Gas r:.:: ::--------------------------- -- s) na or x Units 5241 Mud C des ( ------------------------------------------------------- _ - - i .. ' ! g Flowline Back round Show !j ppm ppm ppm :: Iii Hydrocarbon Ratios 0.0 _ - ~ ~ _ .. iii °' '" ~'' : C1 268857 - 46036 = 222821 C1/C2 = a8.7 Oil C2 7613 - 3038 = 4575 C1/C3 = 248.4 `'I "~ C3 1713 # 816 = 897 C1/Ca = 779.1 C4 497 # 211 = 286 C1/C5 = 4741 C5 48 - 1 = 47 ;.: ° NPH ------------------------------- ----------------------------------------------- ,i u Production ::: .Analysis Gas Oil Water Non-Producible Hydrocarbons Ei .... ..... ....s ..,..... E..E E ......::.:::...... ..... i.:. i .. E ..i .. ... tl:E R ..i......,.. ...i.. .E ..il E . ;... ........ .. . .... ......... .... ,. .:. i I .E.........;:. .... E .................... :.,.,.,........... .... Ei ,...::...i......i . I it iJ............. i i,E,i,..,..:..::::,--... i i I.I..::.n....u.,.....,...E ...E ., i i... u:. • .... y...,....,:................ ..... .. .::::.. ....,....:.:...:., :,...1 .::..,:..:., :.::::........ .. ..........:.i. .....:: 1.0 ....... ... E .. ..i .::.:4.:: ::i I,i:E:::v: : iJj: i. ,~~::. :: ~:eu-:r..... . N':.Er:::z:::... .. ..;:. ~i ~ ~, E.~E iLgy:::!::::a:.. e' : .:.: 4.............H . i.. ... e:e:3EEi .. .id ,. E....... i ..i..,.i...:..:.~ ~~~ ! ~ i,n,,::.:,;:::..... ::-~ im. s:ls. , ~ I .. ~:. ,:, IN ~ : ~:i1ii:~ i:ii:i :.. il= ...3...ie :: 2 ... p u e' ~ ~T::'. si : ,. i,i S:I.iISiEE:i i ,I i I I E' `li i.' i iii i'ii':i[iiii~ r'~!"%rii'?ii'~i~>i?i: ~ '! L!,;?~':r i °' i li i r ` EI'd.i4 ! L 3i. t: sperry-sun DRILLING SERVICES Show Report „j :: ..... . .. :.;::..:..:z::: . .. ::. .:::: . ~ .:ne 84. i ::E Well Name: GUBIK 3 Depth (MD) 1584 to 1610 ft i Location: FOOTHILLS (TVD) 1584 to 1610 ft °i ;, Operator: ANADARKO Show Report No. 7A ~~ Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 13-Feb-08 Report Delivered To: John Kamm . . . ~ ...::... .. .:::.. . ::..k. ~:.:.:.. iii! Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. llii li Formation: Sandstone- clear to opaque, black, light to dark gray, white, trace green, fine to very very coarse grain, subangular to angular, ~l~l moderately consolidated, poorly sorted, quartz, quartzite fragments, chert fragments, variable lithic fragments, 5% coal fragments, y: : sandstone fra ments, noncalcareous, no stain odor fluorescence or cut fluorescence. ,.. iiil g ~~ .....................n .: . i::4~:E : :: : : .... ....e' :':9 ux..]::e.... 1 z Depth 1589 ft Gas x ,:: _ ii ---------Flowline ----Back round g i , :.: , :. e :: .: a °io Units 5517 Mud Chlorides (1000's) na --------§how -------------------------------------- C C Hydroca 1 C 2 C rbonRatios 1 C1 3 C4 C C 1 5 i ,' ij PPm PPm PPm ii Hydrocarbon Ratios ; i 1000.0 ~~ C1 303226 - 58273 = 244953 C1/C2 = 17.2 ~ ! C2 17114 - 2908 = 14206 C1/C3 = 196.4 4 C3 2019 - 772 = 1247 C1/C4 = 612 . `': C4 584 - 184 = 400 C1/C5 = 4374 NPH i' ,iii ,::; '°' Production 100.0 ---- - ---~--~ - ~:: sis x Gas Oil Water Non-Producible Hydrocarbons v~ Anal y 2 ' ~i Depth 1595 ft Gas xli - -------------------------- --- s) na x Units 7077 Mud Chlorides (1000 ------------------------------------------------------ Gas i 9 Flowlme Back round Show :::: ;: Ppm pPm PPm i"i Hydrocarbon Ratios E 0.0 _-- ------- ----- _ ~ ~ ~ - --- ------------- _ _ - ---------- .~ 't C1 315535 - 58273 = 257262 C1/C2 = 10.0 C2 28674 - 2908 = 25766 C1/C3 = 48.7 Oil ii C3 6050 - 772 = 5278 C1/C4 = 122.6 II ,,,. iiii C4 2282 - 184 = 2098 C1/C5 = 1214 C5 213 - 1 = 212 NPH ,:. -------------------------------------------------------------------------------------- Production ii Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 3 °i° Depth 1611 ft Gas x Units 4223 Mud Chlorides (1000's) na '~ Flowline Background Show C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C ~i 1 5 ppm ppm ppm ,; Hydrocarbon Ratios 1000 0 ,~I . ?i C1 361868 - 58273 = 303595 C1/C2 = 21.7 ':i j 4 13965 C1/C3 = 62 16 2908 . = 873 - I( C2 C3 5635 - 772 = 4863 C1/C4 = 193.7 ( ~` C4 1751 - 184 = 1567 C1/C5 = 2551 NPH ~ iii -CS---------120 - 1 -------- 119 ~- ------------------- ------------------------------------ '" Production 100.0 ----------- - ~ ~ ~ it ~i ibl H d b N P d y rocar ons on- ro uc e Analysis x Gas Oil Water 4 ~~i n d Chl id 1000' M Gas „i Depth 1619 ft Gas -- '''--------------------------- a or s) u es ( x Units 8090 ------------------------------------------------------- 9 Flowline Back round Show ppm ppm ppm '^' i:ii Hydrocarbon Ratios 0.0 _ - - - _ _ _ '` C1 654478 - 58273 = 596205 C1/C2 = 16.6 ~! Oil C2 38894 - 2908 = 35986 C1/C3 = 104.3 C3 6486 - 772 = 5714 C1/C4 = 222.8 w C4 2860 - 184 = 2676 C1/C5 = 2908 ::: :::: :::: 205 C5 206 - 1 = :::: :::: :::: 1i ------ Production Analysis C~as O!I Water Non Producible Hydrocarbons ;; - .. .. . i??E ' i. E. ...a r. ~ ~~: ;:i.: in:l ~' .E "~1's' : s. ' .: E. ...L....,a r r'i' ~ Ir:' :. a,i:i,i~i . I..::. i.i. - .a. i;:~ iriE::i . ..o:.,:F:z . I a :..~5::.. M C, .. :.:..:.::... .:...z.: ..r..., h E:.:E::: !ai:::i .:i.. ,i . f.^::'. '.L'~.:.: :! i. i i f f-, ~' ilr . .f II == sperry-sun ~~ DRILLING SERVICES Show Report I!r ~ §n ti~ {~i 'a:n: ~ ~ eiiil,!.ii.l,:_:i . ' i iiirfii!iie-i~ i!`::; i s f°'lll fail .. :1. ~:'i,l,;~ltll...:...: I , i~.l ~l::k.~t°,I Well Name: GUBIK 3 Depth (MD) 1610 to 1645 ft ;l Location: FOOTHILLS (TVD) 1610 to 1645 ft Operator: ANADARKO Show Report No. 7B Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 13-Feb-08 I'r Report Delivered To: John Kamm ICI 'f' ~ .: f..::.::..:::.:.,: ~ .::..:..:.:::..::..... . 9i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- clear to opaque, black, light to dark gray, white, trace green&brn, fine to coarse grain, subangular to angular, ;" moderately consolidated, poorly sorted, quartz, quartzite fragments, chert fragments, variable lithic fragments, 2% coal fragments, 'c sandstone fragments, noncalcareous, no stain odor fluorescence or cut fluorescence. i : . . : ~: .. : f: . ~ ..::. . .. .::.. :.:: ........ .§ :~ . :.~,:,: . . :f '~ 1 °i° Depth 1621 ft Gas x Units 8642 Mud Chlorides (1000's) na ---------------------------9 --------------------------------------------------------- Flowline Back round Show Hydrocarbon Ratios Ci C1 C1 C1 - - - - '. C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 0 it . i., 'lli C1 756222 - 58273 = 697949 C1/C2 = 27.2 f ti~ C2 28531 - 2908 = 25623 C1/C3 = 256.8 ?' 3 C3 3490 - 772 = 2718 C1/C4 = 537 . C4 1483 - 184 = 1299 C1/C5 = 2920 NPH C5 240 - 1 = 239 :: --- -------------------------- ------- ------------ - ------------------ Production 100.0 ,. ~ st; Analysis x Gas Oil Water Non-Producible Hydrocarbons f `~' :ffl 2 ~ illi ~' ' Depth 1631 ft Gas --------- ---- s) na x Units 9846 Mud Chlorides (1000 -------------------------------------- n -------- Gas Show Flowline Backgrou d ff ppm PP-n PPm Hydrocarbon Ratios 10.0 - - - - - - i ;; fii; II' ~' C1 900531 - 58273 = 842258 C1/C2 = 18.2 '~ I C2 49238 - 2908 = 46330 C1/C3 = 55.2 5' Oil C3 16040 - 772 = 15268 C1/C4 = 156.5 -! C4 5567 - 184 = 5383 C1/C5 = 1872 ! f ~•! C5 451 1 = 450 NPH .;f ~' '''' Production Analysis x Gas Oil Water Non-Producible Hydrocarbons ~' 3 °i° Depth 1633 ft Gas x Units 10034 Mud Chlorides (1000's) na •° f' Flowline Background Show Hydrocarbon Ratios ,:. C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm PPm PPm Hydrocarbon Ratios , 1000 0 f . C1 920533 - 58273 = 862260 C1/C2 = 23.3 9 2908 = 37059 C1/C3 = 101 39967 . - C2 n` ;:~ C3 9236 - 772 = 8464 C1/C4 = 258.6 !'!! !;!~ C4 3518 - 184 = 3334 C1/C5 = 1573 NPH !~! C5 549 1 - 548 !; - - li-----°°----------°----------------------------------------------------------------- '!! Production 00.0 ---------- -"-- ---~ ~ . - 4i, ~' ° ibl H d b N P d W ' y rocar ons ater on- ro uc e Analysis x Gas Oil y ~':- 4 ::: ifii ;ifl id 1000' M d Chl Gas ''f Cij Depth 1635 ft Gas fi ------------------------------- s) na or x Units 10036 u es ( ----------------- !ii Flowline Background Show PPm PPm PPm Hydrocarbon Ratios 10.0 ~ - ' - ----- _ _ _ s i ~~ C1 927649 - 58273 = 869376 C1/C2 = 29.6 ;i Oil C2 32278 - 2908 = 29370 C1/C3 = 180.9 ii ,b " C3 5577 - 772 = 4805 C1/C4 = 408.5 ' ' ? C4 2312 - 184 = 2128 C1/C5 = 1206 _ C5 722 1 = 721 >, NPH 'k ffff ~`f , Production '"! Analysis x Gas Oil Water Non-Producible Hydrocarbons f::: r p ............ .. .::...........:....::§>r:::...... .. ... ........., ,,, raf ..::f. §:.~ ::.... ~,,:.,r..,:rr-§:.§ffffrfff::.:z:.::::.,... L::::::::;.. :~~!~ ....... ................: .u.z§ffifz ... .. ... .... .......: e§N ... .......... ,. .,. I ,i. i... ..::. ......... .. ... .... .. ...........i.....'... .....,.........J, i1. 1 160....zrE::............ ........... ...: ..:.....: ... ... :.:.. .... .. ............ , , I, .. .... .... .. !E.. ......... .......................................................f ...,..:.. :..w. , .,. ..... i ... .............h i. i, .. .la,i.,:.:~~:.::.a::.a:u:.!::::::.::!:ii i, ~....... .uar;.r : :::: ..:.:......::.:.:::: ...:....:...::::: ..:::::: f§uuu§uuxxrr:......o...:.., ..f.,/...a.. . ii ., n.i~ ~,..i. u.,,,-;....l..i.. ~W.. !,....... arraaara 3iif ;, !~ §§:!:.I!d i:. r f::, ~~ ~.. 1..6.,..9:1... r:f§,.:: ..,::v :,,::::z::. ,r , '9irE 'sxfffr:f:,~a ~:' "I... :~i :: (~E q .......1.1..... I li. Ili li .,.,uf... :n .~ . ::.: ,:u. as§~::.......... .e:e'fi: W:. eefu .si i. I I i s~ N A~~ ...~s,::6,::z.::§sy..::nf::.!. I i. I. i:.§.,.6:. a:, ..J. ..: ~ ::::~:u::v :. ~. 4v .efFf :ie: 2~ ' ` :` .! !:rk y, 'ri ~j ;;rti ~;i~~~ ,. :n" 'i `i;' h ' 2 Ir ' ' ° :.; i;i ;ir .i r fiirk' iiiir5, i .; nL,ya; i"'p::l sperry-sun .. DRILLING SERVICES Show Report i n3 a. ~ e.iii::k, a . Well Name: GUBIK 3 Location: FOOTHILLS Operator: ANADARKO Report Prepared By: Mike Daigle/ Doug Wilson Report Delivered To: John Kamm .. .. d: ii , k.!.. ii: A ... iii Depth (MD) 1700 to 1766 ft i (TVD) 1700 to 1766 ft ,; Show Report No. 8 Date/Time: 13-Feb-08 i ~, InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, white, trace green, fine to coarse grain, angular to subangular, moderate to loose consolidated, well sorted, variable lithic fragments, quartz, trace coal fragments, slightly calcareous, trace mineral fluorescence, no cur fluorescence. ,: ~: tN ! ...: ~ % Depth 1715 ft Gas x Units 7457 Mud Chlorides (1000's) na ---------------------------9 --------------------------------------------------------- Flowlme Back round Show C - C 1 2 Hydrocarbon Ratios C1 C1 C - - - C3 C4 C ~_ 1 5 ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 693422 - 50644 = 642778 C1/C2 = 23.9 ~~' ~~ C2 29757 - 2815 = 26942 C1/C3 = 74.1 C3 9366 - 686 = 8680 C1/C4 = 199 9 4 C4 3396 - 180 = 3216 . C1/C5 = 1042 NPH ~l i::! ` llii C5 618 - 1 = 617 -------------------------------------------------------- Production 00.0 - ---- ~.- --- , ~ ' `` :: ilii 1i! !;i Analysis x Gas Oil Water Non-Producible Hydrocarbons ~~ 2 _; ' ! i Depth 1721 ft ------------------------- Gas -- --- x Units 9337 ------------------- s) na Mud Chlorides (1000 ----------------------------------- Gas ii' ,:: 'IE j ' 9 Flowlme Back round Show PPm PPm PPm ydrocarbon Ratios 0.0 -- _ _ ------ ~___- - - i.: :iii _: ; ~' C1 771946 - 50644 = 721302 C1/C2 = 17.2 pi ;jl C2 44859 - 2815 = 42044 C1/C3 = 47.8 ... !'~ Oil '~' C3 15764 - 686 = 15078 C1/C4 = 133.3 i:!i ~i: 5593 - C4 C5 1226 - 180 = 5413 1 = 1225 C1/C5 = 589 NPH E -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 s ,: ~; De th 1736 ft Gas ------------- . Flowline Backgrou % x Units 9086 Mud Chlorides 1000's na ---------------- -------------------- nd Show C - C 1 2 Hydrocarbon Ratios C1 C1 C - - - C3 C4 C 1 5 i~ ppm ppm ppm Hydrocarbon Ratios 1000 0 i` Ir . ~' C1 742034 - 50644 = 691390 C1/C2 = 16.4 42204 1 1/C3 = 49 0 C2 45019 - 28 5 = . C C3 14809 - 686 = 14123 C1/C4 = 135.7 I 4ti C4 5276 - 180 = 5096 C1/C5 = 1005 NPH !I' 1, I C5 689 - 1 = 688 -------------------- ------------------------------ Production ----------------------------------- 00.0 --- -- -~ ~--- . - - - --------- :: l t H d b l !` Analysis x Gas Oil Water ons y rocar Non-Producib e ili li 4 % i~ != 00' Gas :k 'r: Depth 1741 ft - Gas x Units 9982 -- s) na Mud Chlorides (10 ------------------------------------ _ . ~~i Flowline Background Show PPm ppm PPm Hydrocarbon Ratios 10.0 - ~ _ ~ ~ _ _ ---- -- ---- --- ~; !~' ~'I' C1 826247 - 50644 = 775603 C1/C2 = 14.1 Oil '' '~! C2 57887 - 2815 = 55072 C1/C3 = 40.0 ~~ '~ ' C3 20073 - 686 = 19387 C1/C4 = 102.7 I i '~~ :` !~i .iii C4 7731 - C5 1143 - 180 = 7551 1 = 1142 C1/C5 = 679 NPH '~ ii 6i i( ------------------------------- - Production Anaysis x Gas Oil Water Non-Producible Hydrocarbons ...... .. ..;!k:!:k i :: h..aa... : :..::r'.-- .'.M~. .::::-" 1.0 :ki:'::':i:ii iiirir fig!; ...t, si:~ .. ~E.4 i! 11'lFii~:,i:!i'.!eaa i ~..i.....,.... ~F ::u:u:!:.. ~'!;-s a i . ~ 1i." ....: r ~ I e -~ ;i ! s1i . . .. .... i~ u~ sperry-sun .~ DRILLING SERVICES ~ Show Report ^' lii I ~`.'@' ,!,...~ ,.n ,. ir,::~..i~.. ,€€ ~.3i!`~i':i's"iii i1f'ili~xr~ ~eSrJK:;!i:ia:'f;~'i.ys well Name: GUBIK3 Depth(MD) 1886 to 1907 ft Location: FOOTHILLS (TVD) 1886 to 1907 ft ~' ai O erator: ANADARKO Show Report No. 9 .b. Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 13-Feb-08 Report Delivered To: John Kamm i li 4s Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. pf Formation: Sandstone- white, very light gray in part, very fine to fine grain, subangular, well sorted, moderate to well consolidated, white ~~ clay tuffaceous matrix, no to trace visible porosity, calcareous, nicrocarbonaceous, friable to medium hard in part, volcanic, some fine ~!i .: ;,:: ~ grain mineral and lithic fragments, no fluorescence, no cut fluorescence. ~' 1 ~~' Depth 1889 ft Gas ' ---------------------------9 --- Flowlme Back rou °i° x Units 2952 Mud Chlorides (1000's) na -----------------------------------------------'------ nd Show Hydrocarbon~~Ratios C1 C1 C1 C1 C2 C3 C4 C5 i. '" ppm ppm ppm 4 Hydrocarbon Ratios 1000 0 ~ ~j'~ . C1 280233 - 51477 = 228756 C1/C2 = 25.8 ~~. C2 12069 - 3204 = 8865 C1/C3 = 99.9 II„ ~' C3 3160 - 871 = 2289 C1/C4 = 303.8 C4 979 - 226 = 753 C1/C5 = 3750 NPH C5 62 - 1 = 61 Production 100.0 ------ ----~.-~-~ --- -- - '; b ~ ~ ons Analysis x Gas Oil Water Non-Producible Hydrocar I I 2 € ! € € ' ~i ~ ~ Depth 1900 ft Gas i ,..:--------------------------- --- ~ s) na x Units 4208 Mud Chlorides (1000 ------------------------------------------------------ Gas ': :: ~~' 9 ! Flowlme Back round Show iii PPm pPm PPm ~;:: ii Hydrocarbon Ratios 0.0 .. - - - -- - --------- _ _ - - - ------------- _ ------- ------- :: ; i i C1 306127 - 51477 = 254650 C1/C2 = 11.1 „ III C2 26143 - 3204 = 22939 C1/C3 = 26.3 i Oil 4 C3 10571 - 871 = 9700 C1/C4 = 111.9 ° C4 2501 - 226 = 2275 C1/C5 = 5197 ? iii ji!i C5 50 - 1 = 49 4 NPH r ' - ------------------------------------------------------------------------ Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 >,,, 3 ;; ;l,i De th 1903 ft Gas p i---------------------------9 -- r;; Flowlme Back rou °i° x Units 3831 Mud Chlorides 1000's na ( ) ------------------------------------------------------- nd Show C _ C Hydrocarbon Ratios 1 C1 C1 C - - 2 C3 C4 C `i 1 iri its 5 I y, ppm ppm ppm ~~j Hydrocarbon Ratios 000 0 ;ii; 'i . C1 342961 - 51477 = 291484 C1/C2 = 20.5 4 3204 = 14218 C1/C3 = 66 17422 `} . - C2 it ` C3 5258 - 871 = 4387 C1/C4 = 231.0 'ii C4 1488 - 226 = 1262 C1/C5 = 3939 ; NPH l ' , iii; C5 75 1 = 74 ut-------------------------------------------------------------------------------------- i:: Production 00.0 - ---------- _ - '-~---- ---------------- N P d ibl H d b Oil W t on- ro y rocar ons a er uc e Analysis x Gas a 4 % iii 3862 M d Chl id 1000' i Gas ,,; ~' i De th 1905 ft Gas p !--------------------------- -- B k ~ s na or x Un u es ts ( ) --------------- - d Sh w :. 9 roun o Flowlme ac :. ppm ppm ppm I':ii Hydrocarbon Ratios 0.0 - _ _ 3i i C1 348102 - 51477 = 296625 C1/C2 = 25.5 i i 5 Oil i `iii C2 14831 - 3204 = 11627 C1/C3 = 88.3 iij ~i °t C3 4230 - 871 = 3359 C1/C4 = 282.0 C4 1278 - 226 = 1052 C1/C5 = 3190 `ii C5 94 - 1 = 93 is NPH ------------------------------- ----------------------------------------------- ;= Production "` Analysis x Gas Oil Water Non-Producible Hydrocarbons lii ~~ .3t~ ~ ;.y,. ~E;I'Ed~ifAr 1.0 '.,i~ i~ lii .$:°;.F,',.j';: "i L'[ill':.: eaEE~. ~n~~'~ <`'^':1'3~1'i.:. i.f ;i,; ';: y:l sperry'SUn ~ DRILLING SERVICES ~€ Show Report l u, ! well Name: GUBIK 3 Depth (MD) 2863 to 2913 ft Location: FOOTHILLS (TVD) 2863 to 2913 ft ~' Operator: ANADARKO Show Report No. 10 Report Prepared By: Mike Daigle/ Doug Wilson Datelrime: 24-Feb-08 ~' Report Delivered To: John Kamm ~u :l I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, very fine to fine grain, subangular to angular, moderately to well consolidated, well sorted, no fluorescence, no cut fluorescence. .; I~ ( :A .:::: ~ .~ ~ Depth 2867 ft Gas :,---------------------------g --- Flowline Back rou :::. .. ... ..... % x Units 203 Mud Chlorides (1000'9) na ----------------------------- ----------------------- nd Show . ~ C - C H drocarbon Ratios Y 1 C1 C1 C - - - 2 C3 C4 C 1 5 y m m m PP PP PP H drocarbon Ratios 1000 0 . C1 19879 - 4343 = 15536 C1/C2 = 39.6 = r C2 572 - 180 = 392 C1/C3 = 125.3 9 C3 146 - 22 = 124 C1/C4 = 456 . ' C4 36 - 2 = 34 C1/C5 = 7768 " NPH i li€-------------------------------------------------------------------------------------- ~ Production 100.0 ::,: ~'' Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 ' . ----- Depth ---2875 ft Gas ------- --- '' 9) ---- na----- x Units 222 Mud Chlorides (1000 -----------------------°----------------- Gas '' 9 ! Flowline Back round Show ~ 'e:: ~li PPm PPm PPm Hydrocarbon Ratios 0.0 ---' - --------- ------------ ------------- iir€ hl iii .; C1 21955 - 4343 = 17612 C1/C2 = 40.8 ':, C2 612 - 180 = 432 C1/C3 = 132.4 '~ Oil C3 155 - 22 = 133 C1/C4 = 489.2 ~i ?;~ A~i C4 38 - 2 = 36 C1/C5 = 17612 C5 1 - 0 = 1 NPH '' -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ! 3 '!€ De th 2880 ft Gas x Units 235 Mud Chlorides 1000'9 na ~ --------9 --------------------------------------------------------- Flowline Back round Show C C Hydroca 1 C 2 C rbon Ratios 1 C1 C 3 C4 C :.:: 3 1 ;c €, 5 ~) ppm ppm ppm Hydrocarbon Ratios 1000 0 a . C1 23166 - 4343 = 18823 C1/C2 = 39.3 479 C1/C3 = 129 8 180 6 . = 59 - C2 C3 167 - 22 = 145 C1/C4 = 384.1 I~'i C4 51 - 2 = 49 C1/C5 = 18823 NPH C5 1 - 0 = 1 Production 100.0 - --------- ----~ ~ ~- i:: !i ~" Analysis x Gas Oil Water Non-Producible Hydrocarbons ' l ~I'~ 4 % ~~ M d Chl id 1000' Gas Depth 2889 ft Gas ~` --------------------------- -- 9) na u or es ( x Units 245 ------------------------------------------------------- - - g Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 10.0 ~ - - - - ------- _ _ ~ ;~[ C1 24692 - 4343 = 20349 C1/C2 = 38.0 i O I C2 715 - 180 = 535 c1/c3 = 142.3 ' C3 165 - 22 = 143 C1/C4 = 635.9 C4 34 - 2 = 32 C1/C5 = 20349 :: .:~ ,: -- NPH .; ----- ~3~ Production P( Analysis x Gas Oil Water Non-Producible Hydrocarbons ~::3. !! ::i::::..... ~::! .. a 11 e..... ..A :::::.......:.......:.:: ~~.~ i...:..Aa::.1a::e::' ~ .!!:I,I.J. 3 e. .~::e;:. '3:.. ':~:;i:A ~!~i:a...m :~.:. ,~... ::I €€!:,:::.::.::..~.: .:l, 1.0 €:!,,,; :. ~. l q,,.:~,., R:i .n . ..I ! ~• ,! :: :.::,.:III I:I.I..!..il;.:..,..;::~: '~ ., :.:~:. ~ l~if ~ " ~ ~ ~ ~ ~ ~ ~ ~' sperry-sun ~' DRILLING SERVICES Show Report li ~ ~ i i ~i! ~ lr i~ i y4j! ji~ iN ..., :e F Well Name: GUBIK 3 Depth (MD) 3030 to 3055 ft = Location: FOOTHILLS (TVD) 3030 to 3055 ft ~'t '' Operator: ANADARKO Show Report No. 11 (I~~ Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 23-Feb-08 ! Re ort Delivered To: John Kamm t P 'iii ,::. j; lnterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. ~i Formation: Sandstone- light gray to gray, very fine to fine grain, angular to subangular, moderate to well consolidated, moderately sorted, ~r: lithic, silty, slightly calcareous to calcareous, very firm to medium hard, no fluorescence, no cut fluorescence. 1 ,.. . .~:~,. .:. : : : :: :: : : 1..... /° r!::v 0 r~ ,! Depth 3033 ft Gas x Units 182 Mud Chlorides (1000's) na cl ---------Flowline ----Background--------Show -------------------------------------- , : n : R : : ,i o s ~Hydrocarbo at C1 C1 C1 C1 C2 C3 C4 C5 : ~t , ;~ ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 18295 - 5172 = 13123 C1/C2 = 54.7 C2 469 - 229 = 240 C1/C3 = 222.4 C3 111 - 52 = 59 C1/C4 = 1640 4 F!! . !`! C4 11 - 3 = 8 C1/C5 = 1640 NPH .-: K!; C5 8 - 0 = 8 ii~! Production 00.0 ------- -- --~--~ -- ~~~ ------ ~: ~ Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 "' ' ;!s ~ Depth 3035 ft Gas --------------------------- --- s) na x Units 163 Mud Chlorides (1000 ----------------------------- --------------------- -- Gas y 9 Flowline Back round Show !r~ ppm ppm Ppm :.: '!' H drocarbon Ratios 0.0 ---- - ----- _ _ ~ - _ _ :::: Ii C1 15297 - 5172 = 10125 C1/C2 = 53.9 : ~~ C2 417 - 229 = 188 C1/C3 = 259.6 Oil C3 91 - 52 = 39 C1/C4 = #DIV/0! ! ' C4 3 - 3 = 0 C1/C5 = #DIV/0! tip: C5 0 - 0 = 0 .,. - ;:: ,::: ~t' ! .-------------------------------------------------------------------------------------- I! Production ~!' Analysis x Gas Oil Water Non-Producible Hydrocarbons ~:~: 1.0 ~~' ~i~! ° ;ir:, 3 /° ~~ Depth 3037 ft Gas x Units 141 Mud Chlorides (1000's) na ! !---------------------------9 --------------------------------------------------------- Flowlme Back round Show C C Hydrocarbon Ratio 1 C1 C3 s C1 C 4 C 1 z! s! 5 = PPm PPm ppm H drocarbon Ratios 1000 0 I!~ . k a C1 12301 - 5172 = 7129 C1/C2 = 59.9 229 = 119 C1/C3 = 419 4 2 348 . - C € 'C ~ C3 69 - 52 = 17 C1/C4 = 3564.5 ~!' C4 5 - 3 = 2 C1/C5 = #DIV/0! NPH C5 0 - 0 = 0 -------------------------------------------------------------------------------------- Production 100.0 --------- ----- - ~ ~ ~ --- ----------------- 1 n N P d ibl H d b l i Oil W t G '!' on- ro uc y rocar o s Ana ys s x a er e as ~E 4 % .'s i !i! D h 304 ft G na 116 M d Chl id 1000' U it Gas :: ept as 6 :: ::: ::--------------------------- -- i B or es ( s) x n s u ------------------------------------------------------- d Sh _ - ~k ( 9 1~~ Flowl ne ack roun ow ::: :,: :,: ppm PPm PPR- n= Hydrocarbon Ratios 0.0 . - _~- - --------- _ -- ::. ,: .. i! ' i r C1 10691 - 5172 = 5519 C1/C2 = 58.7 Oil I.: ~! C2 323 - 229 = 94 C1/C3 = 276.0 :: i'! 20 C1/C4 = 262.8 C3 72 - 52 = C4 24 - 3 = 21 C1/C5 = #DIV/0! C5 0 - 0 = 0 ~:: ,.: ------ NPH `~ ~:. ------------------------------- ----------------------------y ----------- ..: Production l!i Analysis x Vas Oil Water Non Producble H drocarbons ~... .. . , „.H ::€e.!s;! ;:; ... ui.r:r ,: IL.... .. i €,. :.~:.: :.. 1.0 .......n:. ~iiiS~ ".;`.-...,s:: ,,.. h~ ~:, ........ ,:......... ~. ... i:€ ...........t:e . -:: !i ! . .... . ~...~ :`•''' l~ ' Y, j.:l E .:, ~ i°e Eie.]EEEe]eee . if'FI is `. ii .,y li'i'I:KI1~ I,y:;.: i. l:'yi i ' ~ H°i a:: . e :ii `= sperry-sun 1s '~ DRILLING SERVICES E,: Show Report :: •s 'EII ~:E j . , , , . Well Name: GUBIK 3 Depth (MD) 3087 to 3120 ft Location: FOOTHILLS (TVD) 3087 to 3120 ft a Operator: ANADARKO Show Report No. 12 Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 23-Feb-OS Report Delivered To: John Kamm . ~ ......,.. ,. :,.::: ,. .... KI `i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, very fine to fine grain, angular to subangular, moderately sorted, well cemented, decreasingly lithic, silty in part, non-very slightly calcareous, microcarbonaceous specks, mineral grains, no visible porosity, very firm to medium hard, ;i ;: no fluorescence, no odor, no stain, no cut fluorescence ~!i ... w....: i . ' ' ' ' ' ' ' :ee,~u:e:: .:~:e~:w::e":.:: :i ,. k:,M1,. :, •. :ee 1 Depth 3087 ft Gas ..: ---------------------------9 --- Flowline Back rou .i , .., un .:e ye ::y.n % x Units 309 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 . ii2 PPm pPm PPm DUI Hydrocarbon Ratios ul ~!~ `~I 1000.0 C1 33021 - 6965 = 26056 C1/C2 = 49.1 C2 804 - 273 = 531 C1/C3 = 226.6 1 4 C3 175 - 60 = 115 C1/C4 = 766 . C4 55 - 21 = 34 C1/C5 = 5211 NPH ,ii ii C5 5 - 0 = 5 -------------------------------------------------------- ,.E--- -------------------------- ;r Production 00.0 ----- ---- -- - ~ ' ------ ,. i ::: :: ::: Analysis x Gas Oil Water Non-Producible Hydrocarbons ; 2 % ~ ' Depth 3089 ft Gas --------------------------- --- s) na x Units 319 Mud Chlorides (1000 ------------------------------------------------------ Gas 9 j,l Flowline Back round Show 1.. `' pPm PPm PPm :! ~ Hydrocarbon Ratios 0.0 . - - . - ------------- - _ _ _ - - ------------ _ . '' .s': ,.: Ij~ ~~ C1 34993 - 6965 = 28028 C1/C2 = 48.8 l C2 847 - 273 = 574 C1/C3 = 226.0 y ; ~. Oil li C3 184 - 60 = 124 C1/C4 = 757.5 C4 58 - 21 = 37 C1/C5 = 4671 C5 6 - 0 = 6 NPH jj-------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 3 °i° Ni[. Depth 3091 ft Gas x Units 293 Mud Chlorides (1000's) na :: "II Flowline Back round Show C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C 1 ::: 5 Iii; {:: ;~! PPm pPm PPm Hydrocarbon Ratios 1000.0 C1 30876 - 6965 = 23911 C1/C2 = 49.3 ' 273 = 485 C1/C3 = 225 6 758 . - C2 i 106 C1/C4 = 771.3 '`j C3 166 - 60 = Er l j~ C4 52 - 21 = 31 C1/C5 = 2989 NPH l, jjj III C5 8 - 0 = 8 ik ~~ Production 00.0 ---- - ----~ --- - ------------ y <. 'u E€ E ibl H d b N P d W t y= r;E y rocar ons er on- ro uc e Anal sis x Gas Oil a Y %i ~I r [ i; 4 % . ~;li lil ' l i 1 00' Gas -- Depth ---3093 ft Gas ~~ °--- ------- -- s) na or x Units 242 Mud Ch des ( 0 ---------------------------------------------------- --- - - 9 Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 10.0 - - - ~ _ "'I ~ ~ C1 23733 - 6965 = 16768 C1/C2 = 49.9 ~~ Oil C2 609 - 273 = 336 C1/C3 = 215.0 ~4 '` C3 138 - 60 = 78 C1/C4 = 882.5 f' jF `' C4 40 - 21 = 19 C1/C5 = 5589 C5 3 0 = 3 NPH i' M. ~; ------------- -------------°---------------- ---------------------------------- .,E; Production ,E; Analysis Gas Oil Water Non-Producible Hydrocarbons j'' ..... ,:,.::. . ~. .... .::::::::a::::M1::::n::::M1EE::.. .. I , , yl• ~':--a:::;:.......rr:. .:.,.. ,,:......... ~.,.. ,,, Ers::z;: .... . i l., i i . 5 .. i..... .... ...: .. .::..:..:..:..:..:..:..:.. :.... ........: K.,,.........,...: :: ,,:::.::,::. ( W i q.. .,::. ::. o-rrsr:.:rruuauunu;;, J: !I ,'i,.,w2; is %.:ueaa:;u::x^ua.ly, Jn.. p, ,,.. rr. yJr:..a:u>. ~';.. 4?L.raaara ... .... ..... ........................ i 1.0 .....:.::....... , , . ~ . z:...... ..:.a:.a...!,. ~ . ~:y . i , ': rrr;•. ~ .: r. .. r:li=€=„ E .~ ... .. E..::.z::::r:::::,ii:;...E .'c .. F,:M1 .. ,::::ai:ai.... ,Z... ':::a3::z:::....... r:... i. ,::. , ;.u:.i,.a :..~.. :.: ! ~ !:i Ee3e:g:M1:::::::.a:.~: . 11 . n, . ....u..,, , ~; ~; ,. : ill I... J, .:.:::e,: , u:l: . " ., .... !.: .. : . : ::: ~~ : ~ '~ ' ~ ° . .."i!k!,. .. ny:,rke!!IS!::u::::::..w. 5.: 4. : PJL¢n!p~., s;?e':S:.:Li~!e':u::lug!u:k:i;N~~1Ci:a ......., ....:.~:..........:..:..:.....,~.. sperry-sun lj DRILLING SERVICES ~~ Show Report ! ! ! .. :!:! :: !. : :: : is i ::: !?iri!:'~ . gan. ."!G;~i:k: ~ e. ! .~'F::::i. ~. :.I! ::! ;.i.?~: a!r;';;I;!!::sa.. ~ .. I ..:..~.~....1.:...:.!;!z°: a: !. .: 11 .~.,..~ ~ -::i I . . !!r: .ti: !I!' Well Name: GUBIK 3 Depth (MD) 3128 to 3184 ft ~i Location: FOOTHILLS (TVD) 3128 to 3184 ft I' Operator: ANADARKO Show Report No. 13 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 23-Feb-08 Report Delivered To: John Kamm ~ ..::. x a~i '! Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. ~~ Formation: Sandstone- light gray to gray, very fine to fine grain, angular to subangular, moderately sorted, well cemented, decreasingly lithic, silty in part, non-very slightly calcareous, microcarbonaceous specks, mineral grains, no visible porosity, very firm to medium hard, ~I no fluorescence, no odor, no stain, no cut fluorescence 1 ~~ Depth 3145 ft Gas x !;; ::::---------------------------9----- !! Flowline Back round % Units 311 Mud Chlorides (1000's) na ----------------------------------------------------- Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 '' a; °' !~' d `i ~( PPm PPm PPm Hydrocarbon Ratios 1000 0 . C1 33356 - 6965 = 26391 C1/C2 = 49.4 ,oI C2 807 - 273 = 534 C1/C3 = 207.8 'III C3 187 - 60 = 127 C1/C4 = 659 8 . ar '~ C4 61 - 21 = 40 C1/C5 = 3770 NPH '.~~ C5 7 - 0 = 7 .: Production 100.0 ~ '' Analysis x Gas Oil Water Non-Producible Hydrocarbons !! ;n; i 2 % I; ~ I l; k; I ' ~ I III Depth 3153 ft Gas ;a€--------------------------- --- '= s) na x Units 544 Mud Chlorides (1000 ------------------------------------------------------ Gas 9 Flowline Back round Show PPm ppm PPm Hydrocarbon Ratios 10.0 .... - - - - - ~ _ --- u I! C1 57587 - 6965 = 50622 C1/C2 = 50.6 ~ ~ ti ;,. - - C1/C3 = 241.1 C2 1273 273 - 1000 ~ III Oil C3 270 - 60 = 210 C1/C4 = 803.5 C4 84 - 21 = 63 C1/C5 = 3894 C5 13 - 0 = 13 . ' NPH __ _ ------------------------------------------------------------------------ ka! Production ~~! Analysis x Gas Oil Water Non-Producible Hydrocarbons ;! 1.0 ;i; I, ~~~ s Ii;I ----- Depth ---3156 ft Gas Flowline Backgrou pia x Units 628 -- Mud Chlorides (1000_s)-_---- na----- nd Show C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C e, 1 5 , PPm PPm PPm ;{ :: Hydrocarbon Ratios 000 0 !;: :ill . ;; C1 71662 - 6965 = 64697 C1/C2 = 49.7 P'; 1303 C1/C3 = 238 7 1 76 273 f i C2 . = 5 - : ; C3 331 - 60 = 271 Ci/C4 = 818.9 'j E C4 100 - 21 = 79 C1lC5 = 3235 NPH 'u! C5 20 - 0 = 20 :!:: llll-------------------------------------------------------------------------------------- I Production ! 00.0 - --------- _ --~~-~-- . - ; !:, N P d ibl H d b rocar ons on- ro uc e y jl Analysis x Gas Oil Water l a 3;! I l' hl id 1000' Gas l Depth 3163 ft Gas ;!;; !!!--------------------------- -- s) na or es ( x Units 460 Mud C ------------------------------------------------------- g :III Flowline Back round Show ", :.:: ppm Ppm PPm I~ Hydrocarbon Ratios 0.0 . . _ _ !p "~ C1 41839 - 6965 = 34874 C1/C2 = 50.0 ~ O I C2 971 - 273 = 698 C1/C3 = 219.3 B " !!I il~j C3 219 - 60 = 159 C1IC4 = 658.0 1 ICI C4 74 - 21 = 53 C1/C5 = 2325 ~I C5 15 - 0 = 15 . --- NPH ,4 .. ..: : .! -- --------------------------- -------------------------------------------- ?II Production Analysis Gas Oil Water Non-Producible Hydrocarbons {! ... ....... ............ ,. ......... „ ,..... . .. R:..::. ,.., .,...:. .I..... .. r.:.. ~:........... , .,~: 1 'k :4, ~x.~! :sa R ek!~. .!~. ::.! :. i : !:!:!:k!:!:!:k!:... ..~ h I... :. lua ::~ .:.:r................a~{~fl .n .. ..... ~, '~:xi~!k¢z! .... I :::z: ' .~r!! !!!!k::::::::~::y!::^:~€:: :~:: is ...., v.~. ~: :. i. {`u: rr!y::::::::::...... 1.0 ....... ... .... I..:...:.... !.s:•:.::.. .. i........ : .:! .. I.. :..1.., :. h:.........:aazi!i`!.. ...::....... :.a:~:.,.... .......: `N ...3. !:i! I : :.,:.k: ~~ !: n r !!!!;i°i:l'i !!!~:.::..: i . II:: I: ll::. ~i.. :;!I!:!:k:!:!k~., it I . I! ::.!:!:.... r. III i...... 1 ~ :.!.......:. €...~.! i.:.:..... i i.. i..I.!..... :. Ii.. .. .:.r: 2';~e:I 'n:I .:isusxiuura ~ ............... :€~. .. ' ' i!kI!EfM[~ .:::.. .....r. aaaaa:::F'E ~i !'S!li !:~ !i?! sperry-sun '~ DRILLING SERVICES Show Report ::.k,:3,.'. E:;n3'r:y::3::r:~F4!;Etl i ...i r:.' .;.C ea .::!60:.,!.x9 .r r¢ : 'r yiE;y~.r:::.::6.:yeK':.:: ei~:P, I Well Name: GUBIK 3 Depth (MD) 3205 to 3225 ft Location: FOOTHILLS (TVD) 3205 to 3225 ft Operator: ANADARKO Show Report No. 14 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 23-Feb-08 ;~ Report Delivered To: John Kamm :~J! ~I ~~ .::: un.. ..~... ........:i..:.~a.: e' . ':' : :: .~ : : .<. : a ...:... .:f, ! i !ll! '`~l InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. ~" Formation: Sandstone- light gray to gray, salt & pepper, very fine to fine grain, angular to subangular, moderately sorted, well cemented, trace lithic, silty in part, non to very slightly calcareous in part, microcarbonaceous specks, mineral grains, no visible porosity, trace calcite :E, fracture filling, trace pyrite nodules, very firm to medim hard, no stain, odor, fluorescence or cut fluorescence. !~€ , ::: s! ~ 'I! ~ ~~~~~~~ ~ ~ ~ilq 7 Ilj Depth 3211 ft Gas .,---------------------------9 --- Flowline Back rou ° /o x Units 677 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ~i [ PPm PPm PPm `~= Hydrocarbon Ratios ~ .2 1000.0 !'' C1 67304 - 9190 = 58114 C1/C2 = 42.4 ~! C2 1665 - 294 = 1371 C1/C3 = 209.8 !~ ,.3, '"' C3 342 - 65 = 277 Ci/C4 = 774 9 . l C4 96 - 21 = 75 C1/C5 = 3059 NPH C5 19 - 0 = 19 -x. Production 100.0 --- ---- ~-' ---- .-~ ~! Analysis x Gas Oil Water Non-Producible Hydrocarbons lei 2 % ' ~` !' ' ~ Depth 3218 ft Gas --------------------------- --- s) na x Units 500 Mud Chlorides (1000 ------------------------------------------------------ Gas ;. 9 Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 0.0 _ .. - - ------------- _ _ - . - - - _ . --------- --- - ~~ !: -: ` C1 50034 - 9190 = 40844 C1/C2 = a1.6 ` C2 1277 - 294 = 983 C1/C3 = 176.8 ' Oil C3 296 - 65 = 231 C1/C4 = 559.5 ' C4 94 - 21 = 73 C1/C5 = 1857 !~ 22 ~~~ C5 22 - 0 = .! ''! Production ---------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 g °i° Depth 3223 ft Gas x Units 707 Mud Chlorides (1000's) na !'€ =,---------------------------9 --------------------------------------------------------- Flowline Back round Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C 1 :: 5 ~'i PPm PPm PPm !Ij. Hydrocarbon Ratios ! 1000 0 ! . ~i C1 80665 - 9190 = 71475 C1/C2 = 44.9 1593 C1/C3 = 206 6 1887 294 . - = C2 !j C3 411 - 65 = 346 C1/C4 = 707.7 :.;I j C4 122 - 21 = 101 C1/C5 2749 NPH : -------------- -------------------------------------------------------------------- Production 100.0 ------- - ----- ~ ~---- ---- ----------- ~'I H b N P d ibl d `~ r y rocar ons on- ro uc e Analysis x Gas Oil Water 3: 4 i % 'i ..: "!' 1000' M d Chl id Gas :.,; Depth 3225 ft Gas ,.. ~::: °--------------------------- -- I s) na u or es ( x Units 619 ------------------------------------------------------- _ ~ !i ~ g Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 0.0 _ - - ' - _ _ - ---- I` 1! :: I . ' ~; C1 69673 - 9190 = 60483 C1/C2 = 45.6 f~ oil C2 1620 - 294 = 1326 C 1 /C3 = 217.6 C3 343 - 65 = 278 C1/C4 = 746.7 C4 102 - 21 = 81 C1/C5 = 2749 C5 22 - 0 = 22 ;: NPH a _ ------------------------------ ----------------------------------------------- ~;` Production ::: Analysis x Gas nOil rlWater Non-Producible Hydrocarbons 1:: ..ili:` :z: r.3., :..:. :.:j3;: ~:! .G 3: .r::oe::ttitit6::i:s::i:s::i:s:::: .; .;,.. .:..n: r:.....::..::...s :.. 1.0 :.if:e..uu:..::: uup:. . ..:3..:..:..:::,,.~.: ~ . V P ~ . 3. :EEiEE:7EE3EEEE3:;i: e:i' ! ............. .I. ................ ~ k....... X33 .. :... :.. •.... :i. :h .:3:::y!:yy:'::, . .... .:.:h... ...... ................:..~~r::::::::r~;:r.. !~ ..1u ,: e eiele.Te'eie?l: i~i:s:au4i::;e§iiii" . ~. 1' ii ee ... ~ . ~.44::v;v.. •! i; i i i E ol': i :i' vi' 'ili"I y9eeijilj'ir ~f:A4'•.... I .~ii~i:' I r......ll. , N II I: ~r;.aur..e...Y lielele: 1.1 a ii ii. ~';ll?lil'e'eli;iii;]S& :.i.:...,:,.. .: I:. iii eli'$: l, vi;: . .. . . . '~n~a i :.l: eil~i e. I ~~.: I' ~ • II I ?i I • I te ~ . , , . . li i sperry-sun "' DRILLING SERVICES Show Report . , ,. . . e.. . . . .. .. : „ . .. ~ .. .,: ei:~ : :.. ::k......~:. ... :: :.1.: . .:......> : i Well Name: GUBIK 3 Depth (MD) 3234 to 3252 ft Location: FOOTHILLS (TVD) 3234 to 3252 ft i Operator: ANADARKO Show Report No. 15 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 23-Feb-08 Report Delivered To: John Kamm ;E k k' Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. ~e Formation: Sandstone- light gray to gray, salt & pepper, very fine to fine grain, angular to subangular, moderately sorted, well cemented, trace lithic, silty in part, non to very slightly calcareous in part, microcarbonaceous specks, mineral grains, no visible porosity, trace calcite !E fracture filling, trace pyrite nodules, very firm to medim hard, no stain, odor, fluorescence or cut fluorescence. i-.ti . -- ~~ ~ ~°i° Depth 3242 ft Gas x Units 629 Mud Chlorides (1000's) na ---------------------------9 --------------------------------------------------------- Flowlrne Back round Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - i C2 C3 C4 C5 m m m I"I PP PP PP Hydrocarbon Ratios 1000 0 ; . W; ~ C1 71583 - 10662 = 60921 C1/C2 = 41.4 C2 1779 - 308 = 1471 C1/C3 = 175.6 3 C3 415 - 68 = 347 C1/C4 = 516 li . _~ C4 140 - 22 = 118 C1/C5 = 1562 NPH ~; '~` C5 39 - 0 = 39 Iii; :::_ i ------------------------------------------------------------------------------------- P d ti 00.0 ----- - --- ----Y-~--= ~ ~ ------ -- :y `il :i ro uc on it Analysis x Gas Oil Water Non-Producible Hydrocarbons ~,, 2 % ;e ' 11 Depth 3244 ft Gas --- --------------------------- s) na x Units 530 Mud Chlorides (1000 ------------------------------------------------------ Gas !' 9 Flowlrne Back round Show PPm Ppm Ppm Hydrocarbon Ratios 0.0 ~_--- - _ _ :~; .lie ;: !I C1 53360 - 10662 = 42698 C1/C2 = a2.7 i i ` ! ~4j 'ill ~ C2 1308 - 308 = 1000 C1/C3 = 180.9 ill Oil ' I~~ C3 304 - 68 = 236 C1/C4 = 520.7 C4 104 - 22 = 82 C1/C5 = 2372 C5 18 - 0 = 18 NPH I I~ -------------------------------------------------------------------------------------- =' Production ~~ Analysis x Gas Oil Water Non-Producible Hydrocarbons x 3 % :: i Depth 3246 ft Gas x Units 420 Mud Chlorides (1000's) na ~-------------------------------------------------------------------------------------- i! Flowline Background Show 1.0 Hydrocarbon Ratios ::: C1 C1 C1 C1 ? - - - - ui, C2 C3 C4 C5 i ppm ppm ppm Hydrocarbon Ratios 1000 0 "Y ale . C1 41855 - 10662 = 31193 C1/C2 = 39.9 C2 1089 - 308 = 781 C1/C3 = 147.8 `I lie C3 279 - 68 = 211 C1/C4 = 371.3 - _ C4 106 22 84 C1/C5 = 1114 NPH C5 28 - 0 = 28 ,.. -------------------------------------------------------------------------------------- Production 00.0 --- - --- ~~-~---- . - 111 °° °ee H b d y rocar ons Analysis x Gas Oil Water Non-Producible e ' iiii ~i 4 % . I';e 1 00' Gas Depth 3251 ft Gas . --------------------------- -- s) na x Units 365 Mud Chlorides ( 0 ------------------------------------------------------- - 'I 9 Flowline Back round Show .; PPm PPm PPm li` Hydrocarbon Ratios 0.0 - - - - - ------------ - .. ---- ----- --- : =~ C1 36998 - 10662 = 26336 C1/C2 = 37.8 ~i l O '~ C2 1005 - 308 = 697 C1/C3 = 150.5 r ~` C3 243 - 68 = 175 C1/C4 = 399.0 ~! yi i~l 88 22 66 C1/C5 = 1254 ee C4 - _ u C5 21 - 0 = 21 PH :------------------------------- ----------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons :.• ,~.... ... :. :.... . ............ ... .. , t..,.,...:... .. ..... ................... •.v .v. .. ~.. ....n d E i........ u.»a: F ,..P:e•.:.N:..i. i, 1 :::: ... .a:.N.u..:y ~.u a, .:.>u..,, `1: ~ ..ne. ..., .. ...q: .uupE„ .............. v:l:l .....:.q..4..i.v iuv >~:.. .....:. i. :~ilu.. . ~.: ,.:.::.,:..:..:..E:.,:l:.:i~ . ~ ~..r.. ~w..,...:..:.: I I .,..........:il i I i 1.0 p1' ..:..::~i:ii ...k......::.... .. .1'11:1! I =:l @I.; riji :I I'4i:1 i::!li"•"'i`ii . ~ i [ ! I: o.! ::.r:¢ ..I I.... .I li:::4: .. i...p... .... iiii: xiili311 iv I . i.: a..i .. , i ,..i.,.. ...Y I : .. i i.l:::::::,, n::l:.:s:ii:r:'i~ri i:i~ ~ I:::::::.:::i e:i:aei,li' I i : ...i.:.;; ...i ~: I, i:...l..,::.:.,...,..i ..Yv, ..i II .Li:i.. .. .. ... .-:..... ,.in. .nai .. ii i.. .4. uu ~ , ,,,::::::::::.,:. :., ii~eii~ ;i , . c;l'` :'"a` -.1 °u ai sperry-sun ~~ ~`:. DRILLING SERVICES Show Report ., : : : ue`.~,r:;i is ,..: ~ ." i ti."~k.' ''III ~! i~- .: . u;, ., , , ~ .: i.!:. !Iii !III li'i:!!I'a':tiii!I'9ii!':a : ~ a 4: iu; ~ m';! i ~ ~ i ,~ H• ~ i ;ii •I Well Name: GUBIK 3 Depth (MD) 3270 to 3312 ft Location: FOOTHILLS (TVD) 3270 to 3312 ft Show Report No. 16 'i Operator: ANADARKO ! Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 11-Feb-08 ii Report Delivered To: John Kamm 1~~ InterpfetatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, white, salt 8 pepper, very fine to fine grained, grading to siltstone, siltstone is very calcareous, no stain, odor fluorescence or cut fluorescence. 7i ° iii ......., .,......:.. ' . ......... ::::~ .::::.:.:.: , i : :.,,,... y,. 1. Depth 3273 ft Gas :'-------------------------------- ! Flowlme Backgrou ~:. ~~% x Units 386 Mud Chlorides (1000'8) na ------------------------------------------------------ nd Show , Hydrocarbon Ratios C1 C1 C1 C1 I`i ,! - - - - :,I C2 C3 C4 C5 ! it ppm ppm ppm !:! H drocarbon Ratios !'? y 1000 0 i i . ! ;~ C1 42501 - 12067 = 30434 C1/C2 = 37.0 C2 1225 - 403 = 822 C1/C3 = 101.1 II! 3 C3 397 - 96 = 301 C1/C4 = 232 ~~! . ii _ C4 163 - 32 - 131 C1/C5 = 597 NPH ~ ki C5 53 - 2 = 51 iti-------------------------------------------------------------------------------------- t. Production 100.0 --- ~ ' -- -------- -------- 5= Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 % !ii ~ ' Ei Depth 3274 ft Gas ~ --------------------------- --- 8) na x Units 351 Mud Chlorides (1000 ------------------------------------------------------ Gas g Flowline Back round Show PPm PPm PPm Hydrocarbon Ratios 10.0 .. - - ~ _ - - - ------------ _ iii ii C1 36545 - 12067 = 24478 C1/C2 = 38.7 '~ C2 1036 - 403 = 633 C1/C3 = 109.3 it Oil C3 320 - 96 = 224 C1/C4 = 249.8 ,.~ C4 130 - 32 = 98 C1/C5 = 612 :: i'` C5 42 - 2 = 40 i NPH -- __ -------------------------------------------------------------------------------- ~ "! Production ! Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ii i~! 3 Depth 3279 ft Gas !'r!---------------------------9 -- i! Flowlme Back rou % x Units 302 Mud Chlorides (1000's) na ------------------------------------------------------- nd Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C ~I 1 5 ppm ppm ppm Hydrocarbon Ratios 1000 0 ! ;! . ~I C1 31739 - 12067 = 19672 C1IC2 = 34.2 ~i 87 8 7 . 5 C1/C3 = C2 978 - 403 = 5 !![[ C3 320 - 96 = 224 C1/C4 = 187.4 ii C4 137 - 32 = 105 C1/C5 = 492 ~ NPH ' ! ::5 :::: :::: ~~~~ C5 42 2 = 40 ::: - :::: :::: '~~° Production 0.0 _ : : H b d I y rocar ons Analysis x Gas Oil Water Non-Producible 4 :!! ~„ ' : .: s . De th 3281 ft Gas -- !I!i -------- p ----------------- s) na x Units 312 Mud Chlorides (1000 ------------------------------------------------- : g Flowlme Back round Show ~' PPm PPm PPm °= ~° Hydrocarbon Ratios i , 0.0 _ _ _ _ _ ------- ~ _ - - ----- ------- !; ~' ! i . = '` C1 33293 - 12067 = 21226 C1/C2 = 33.3 l O 3ij C2 1040 - 403 = 637 C1/C3 = 84.9 i i!!i ~~:: ! C3 346 - 96 = 250 C1/C4 = 187.8 i C4 145 - 32 = 113 C1/C5 518 ii C5 43 2 = 41 .,, NP :! i~l ------------------------------- ----------------------------------------------- Production .. Analysis x Gas Oil Water Non-Producible Hydrocarbons !! EI!:. riE::~.~~q. ~.a.'s icy ~'~;.~~°:ii~.:z~,:.... i;;kM.::~,:~ '>'~ a :,:,:i:': :.~ ~ ~ vz;5:"~i. ':.`z: ': ` '.~iGlis 0 :ix; "'i': ::: ii i° ° °'ei,i ~: ~~}~~ ~ ~i!:~ i iiii ~!~::I::zi!ti! ~ia~~ i!I Iliil i!i': iiiiEi:ii!ii!'!!i!I!!Ilii N 'r'~i i!i!I!E :iL;.: ~ ii i' iiiiiiilifliiii ~r~~N ,x~~ r:iii~:l ii4 ili~i,i~, c: . . I~ .;, sperry-sun ~' DRILLING SERVICES Show Report ~ij Well Name: GUBIK 3 Depth (MD) 3394 to 3417 ft Location: FOOTHILLS (TVD) 3394 to 3417 ft .k Operator: ANADARKO Show Report No. 17 Report Prepared By: Mike Daigle/ Doug Wilson Datelrime: 25-Feb-08 Report Delivered To: John Kamm ~ ,,i .. .: lid Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. ll'~ Formation: Sandstone- white, light gray in part, fine to medium grain, some angular coarse grain in part, subangular to angular, poorly sorted poorly to moderatelt cemented in part, white clay matrix-cement, friable in part, quartz, micaceous and mineral fragment, some carbonaceous 1 '" material, no visible porosity, no stain odor fluoprescence or cut fluorescence. `E e ~ ~ '~ ~ ~~ ~ ~ ~ ~ ~ °i° ~ ~~ ~~~ ~ ~ Depth 3397 ft Gas x Units 300 Mud Chlorides (1000's) na ' ---------------------------9---------------------------------------------------------- Flowtine Back round Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 `' ppm ppm ppm Hydrocarbon Ratios 1000 0 '` . C1 32888 - 10473 = 22415 C1/C2 = 43.4 I`j C2 884 - 367 = 517 C1/C3 = 329.6 I: ,i 5 '~ C3 147 - 79 = 68 C1/C4 = 1318 ~~! . C4 44 - 27 = 17 C1/C5 = 3202 NPH '! .. C5 7 - 0 = 7 ~~ Productwn 100.0 ---- ----~-~-~-- .-~ <~ ~ `~ Analysis x Gas Oil Water Non-Producible Hydrocarbons iiii '~ 2 % li ' ~I Depth 3399 ft Gas --------------------------- --- s) na x Units 267 Mud Chlorides (1000 ------------------------------------------------------ as :,: `' 9 Flowlme Back round Show ::: ppm PPm PPm ~::: iii: ; Hydrocarbon Ratios 0.0 . - - - ------- _ ~ ~ ~ _ ---------------- _ . -- ~! ~ I ' C1 27015 - 10473 = 16542 C1/C2 = 48.8 i~~ ~ ! C2 706 - 367 = 339 C1/C3 = aa7.1 I~' I`I Oil C3 116 - 79 = 37 C1/C4 = 1838.0 C4 36 - 27 = 9 C1/C5 = 16542 'ii C5 1 - 0 = 1 .., NPH :,:, !!li-------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 s !j Depth 3400 ft Gas :::: iiii---------------------------9 --- !~ Flowlme Back rou % x Units 221 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show C C Hydrocarbon Ratios i C1 C1 C 2 C3 C4 C 1 5 iii Ppm PPm PPm Hydrocarbon Ratios 1000 0 ~i . C1 20714 - 10473 = 10241 C1/C2 = 53.9 4 190 C1/C3 = 602 7 367 . - = C2 55 C3 96 - 79 = 17 C1/C4 = 2560.3 ij C4 31 - 27 = 4 C1/C5 = 3414 i NPH ~ ~ iti C5 3 - 0 = 3 _ Production 100.0 ----- - - --- -y ~ --- ~- --- ~: H d b N P d ibl `~ y rocar ons on- ro uc e Analysis x Gas Oil Water u i ~i!~ 4 % ~ Ij iii; i 1000' Gas :i5 Depth 3402 ft Gas :: --------------------------- -- s) na x Units 291 Mud Chlor des ( ------------------------------------------------------- _ - - ~i .. ~' 9 Flowlme Back round Show ppm PPm PPm Ni Hydrocarbon Ratios 10.0 _ _ .. . _ .. --- --- -- `. ~" C1/C2 = 31.7 C1 22408 - 10473 = 11935 Oil C2 743 - 367 = 376 C1/C3 = 202.3 C3 138 - 79 = 59 C1/C4 = 1193.5 ?ii C4 37 - 27 = 10 C1/C5 = 3978 C5 3 0 3 NPH ~~~i i'i ~~ :.: x': Production INi Analysis x Gas Oil Water Non-Producible Hydrocarbons ::::~.. ~ :..:..::. ::::...z.z:: u::r,~ ~ .....:.::...:::::,rn:: ~ i :i..a::.:.z.:z:::,.re:r:r.:: , ., ....:......... ... .. :......... ....I. J. ~..J... ~.. ~..:.. , .:.......::. .............:...:..:.., i. ,..: ....:....: i... ~....n..r.. F : .. i. .. i ~!.i i:...i.uu..ur...oo.. . ,. ,:: .,.~........,x:.~,.....,.... ,~ ...............:::.:::...,,. , :..I:.ii i ....I I.ti.~rl ,,.. .,. g.::os.::.:.:::...:.::.:.... .~l~ .... I.:..a.,...a.:.,....:I.:.: i, .I.:::.::ax<.::.::n N. t.. i~.:, .......,:.. .~,:.. :~.:..,:~.. :..::.. ..:..:..i....:..~::l.l 1. i.i...,.......,..i...:..,...~.I..I. ICI:. i,.:. ......,..i.. ... :..i::,:a:::[: ,:~.; .. :...u.u.uo.:•~;.i : I i ~. i.~...~...... ~.i~:.l II .i .............I.i i .. .... :: `~:, .i.:i .::. .i...... h... 'i ii::?... ?i...C~ :. i.iiii a~ . r ~... y:~......ti..... ~..::: I y.. ~~au::,::..,.... ~ i::::. .,::. .'i~,.y>,.: ...,.,:.. iii ~i ii9ieile::e.° ::..:::::::: t t ?iijiljjjjjl ~jjjr:, jPh"- f~: jii '~~ sperry-sun a DRILLING SERVICES ~l Show Report ~a ~Iil ;j: li7ilyil~ q , 5. ~i' € Well Name: GUBIK3 Depth (MD) 3487 to 3533 ft jij Location: FOOTHILLS (TVD) 3487 to 3533 ft ' Operator: ANADARKO Show Report No. 18 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 25-Feb-08 Report Delivered To: John Kamm ,.jr . ~:~ ~:::.:. . ~: l; . ~ jij: Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. i'jj Formation :Sandstone- clear to light gray, fine to medium grain, angular to subangular, moderately to well consolidated, moderately `ii ~ij sorted, mica and mineral fragments, some carbonaceous material, calcareous, no visible porosity, no stain odor fluorescence or ~j cut fluorescence. €: , = 1 'Ij Depth 3511 ft Gas --------------------------9---- I:I. Flowline Back rou Rio x Units 450 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm ppm ppm $~ Hydrocarbon Ratios 1000 0 . ,' C1 43312 - 9343 = 33969 C1/C2 = 42.6 ..~ C2 1120 - 322 = 798 C1/C3 = 326.6 8 C3 178 - 74 = 104 C1/C4 = 1095 . . ,~ ~~il C4 56 - 25 = 31 C1/C5 = 4853 NPH , -------------------------------------------------------------------------------------- ,:~ P n d t 100.0 --- ------ ---- ~. ------- ,: Ij ro uc io =1i Analysis x Gas Oil Water Non-Producible Hydrocarbons ~ 11 o € `~ : ' 2 j€i€ va ' ; : ;Er; Ni De th 3514 ft Gas ,i€ P --------------------------- --- s) na x Units 858 Mud Chlorides 1000 ------------------------------------------------------ Gas ~€ a~ 9 Flowline Back round Show pPm Ppm pPm Hydrocarbon Ratios 10.0 _ _ _ _ ----- _ _ _ " - - _ _ r ;I l C1 86267 - 9343 = 76924 C1/C2 = 44.2 ~ : C2 2063 - 322 = 1741 C1/C3 = 312.7 Oil C3 320 - 74 = 246 C1/C4 = 1148.1 o-j tli 3497 C4 92 25 = 67 C1/C5 = .; - ,::: :::: " C5 22 - 0 = 22 Ili; ". -------------------------------------------------------------------------------------- N~ Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 €iI 3 ;~ ~~ De th 3517 ft Gas --------9 -- ------- p --------- ~~; Flowline Back rou Rio x Units 1234 Mud Chlorides 1000's na ---------------- ( ) ----------------- -------------------- nd Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C t= ~~ 1 I-€ :: 5 j '' PPm Ppm PPm ~I Hydrocarbon Ratios 1000 0 jjj ~,; u' . ' C1 135746 - 9343 = 126403 C1/C2 = 44.8 ~I ~' li 1 2819 C1 = 309 'III C ''' . / 3 C2 3141 - 322 = i. : :: ~ C3 483 - 74 = 409 C1/C4 = 1192.5 'ji ~ C4 131 - 25 = 106 C1/C5 = 4359 NPH .j C5 29 - 0 = 29 ~j Production 100.0 ---' -~ ------ - ----- - ~_ H b d ons y rocar Analysis x Gas Oil Water Non-Producible 3';i 4 % 1 0' as ----- Depth --- 3520-- ft Gas ------- s) ---- na x Units 990 Mud Chlorides ( 00 -- ----------------------------------- ----- Flowline Background Show €' ';~j ppm PPm PPm Hydrocarbon Ratios 0.0 _ _ - - --------- ---- _ _ --- ------------- it ' C1 90099 - 9343 = 80756 C1/C2 = a3.6 O 1 C2 2175 - 322 = 1853 C1/C3 = 299.1 i ' Ij:: C3 344 - 74 = 270 C1/C4 = 1121.6 ,;:, Iijj '~ ~' C4 97 - 25 = 72 C1/C5 = 3671 C5 22 - 0 = 22 - NPH ~' :, ^E Nj _ ------------ ------------------------------ ---------------------------------- :r:.i Production ~`j Analysis x Gas Oil Water Non-Producible Hydrocarbons ::: ji;: ,.... .,... iiIII ~ r; jI' '' i}5iiir5:irri5i?'~'' I i.'• i:i:4i:,€r~.: i ~ I jL:~::':i ~~:,:::ri ....y€ .III"ri':I.::;:;: i' . ~ ...•:~:::... j........:: e:e:eeeee! "i .. ... ~. ,.: j4 :e,pr 1.0 :~,~ riiiii?::: ~ ~"y`~I"`~':,'a=:~~ r.•r::z. .. ._:: ~ a. d:€ti! iiEr . € ~ n.: ~,:,.e ~¢.: ~' ::ei'j^iz::. ~: ~~>z ~I., :,,hj..; ~'Irja':ijii,-~;: ~. ,~~'€€'ii::::;~ .... ... ^" '. .,. ~' 1 ii i~ II'. I"1 Iii '~ ! ! ~.:,I:;.i:..,.. E ]E:~;:::. :eek.: sperry'SUn DRILLING SERVICES Show Report .x ~u+e:: :..~! i :.i ~.r... `~'f t!ii'~rl r•?`:`:iEif : 1i.a ii a Vpye i! . .'.''Siu'£'i..;. Well Name: GUBIK 3 Location: FOOTHILLS Operator: ANADARKO Report Prepared By: Mike Daigle/ Doug Wilson Report Delivered To: John Kamm 4[r:r:ili:r, i^'... .:.I:~s.. .. .r. n::. jlJp:: ~: e!: n...: ~~ l ,..:I; 4. i ir: ~ ~:.1fii:' : II .'u~? I .I... ~: ~r.h.. : ~~i!idi.e.1., i .~I ' Depth (MD) 3535 to 3595 ft (TVD) 3535 to 3595 ft ~€ Show Report No. 19A Date/Time: 25-Feb-OS ''` ! IEI! Ei: '" ~! , Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation :Sandstone- clear to light gray, fine to medium grain, angular to subangular, moderately to well consolidated, moderately • sorted, mica and mineral fragments, some carbonaceous material, calcareous, no visible porosity, no stain odor fluorescence or I'! ~ cut fluorescence. ~~~ I . ~ .. : o ~ ~ ~ ... .:.....:.. .. .: ' Ir::::r:::r:;.:a•::. , .:......~ x:...,.......:....:•~ : : t :::,. .:::: :. ~ Depth 3537 ft Gas x ---------------------------g ---- Flowline Back round ... ... :,.: . ::: .. a :. .:~ ~:. .rr °i° Units 1625 Mud Chlorides (1000's) na ----------------------------------------------------- Show .. r. . C1 - C2 . . Hydrocarbon Ratios C1 C1 C1 - - - C3 C4 C5 t =! !jjj r~ ppm C1 162805 - ppm ppm 13757 = 149048 Hydrocarbon Ratios C1/C2 = 50.7 1000.0 ~j '! '` C2 3342 - 403 = 2939 C1/C3 = 546.0 C3 345 - 72 = 273 C1/C4 = 3312 2 x€ s C4 70 - 25 = 45 . C1/C5 = 18631 NPH !'!` 'I :: :::: ii? '~' C5 8 - 0 = 8 -------------------------------------------------------------------------------------- Production 00.0 - ( I" .:. '!i !F! Analysis x Gas Oil Water Non-Producible Hydrocarbons !!~ 2 ,,, ' II! ~: Depth 3540 ---------------------- ft Gas ---------- x Units 2442 ------------------ s) na Mud Chlorides (1000 ------------------------------------ Gas It! ::: i€! !iii ! Flowline Ppm Background Show PPm PPm ydrocarbon Ratios 0.0 . - - - ----- _ "' . - - --- - - ---- _ . ----- ------- ~j i ' ! I:Ii !i" ~~~ C1 229300 - 13757 = 215543 C1/C2 = 44.7 C2 5223 - 403 = 4820 C1/C3 = 47x.8 !! ! '~ Oil i:i ~ ! i€ III! 526 - C3 454 72 = C1/C4 = 2952.6 ,:: ., C4 98 - C5 12 - 25 = 73 0 = 12 C1/C5 = 17962 N H l -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons O ~!I I! !r I 3 "~ De th 3542 ft Gas ! p ---------------------------9 --- Flowtine Back rou o /° x Units 1996 Mud Chlorides 1000's na ( ) ------------------------------------------------------ nd Show C - C 1 2 Hydroca C - C rbon Ratio 1 3 s C1 C - - C4 C yi '. 1 5 ; ~`i ji ppm PPm PPm Hydrocarbon Ratios 1000 0 !~ . C1 160047 - 13757 = 146290 C1/C2 = 52.3 ! 2797 403 7 C1/C3 = 573 G C2 3200 - = . C3 327 - 72 = 255 C1/C4 = 3483.1 C4 67 - 25 = 42 C1/C5 = 18286 NPH :. - C5 8 0 = 8 ---------------------- Production 00.0 - - ----- - --- -- ~~ ~---- - ----- :::: iiii ~~~ !!11 ibl H d b d Analysis x Gas Oil Water ons Non-Pro y rocar uc e 4 % i :-: ::: hl id 1000' Gas !I' .. Depth 3544 ft Gas ,:: --------------- -- x Units 870 ------------------- h s) na or es ( Mud C ------------------------------------ _ . . ,; r; n ; !;' ..1 j Flowline ppm 9 Back round S ow pPm pPm Hydrocarbon Ratios 10.0 - - . - - .. z t a1! C1 88599 - 13757 = 74842 C1/C2 = 53.4 dl1 l O ! C2 1805 - 403 = 1402 C1/C3 = 613.5 i !' C3 194 - 72 = 122 C1/C4 = 3563.9 ~ Iii !! :: :: C4 46 - C5 1 - 25 = 21 0 = 1 C1/C5 = 74842 -- NPH !;~ !4 .. :::: :e:u _ --------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons ......~:u'e'z:iz::z: "'~ ieiYle!ib:!! 111 iii'ii i, 4 .~I~ '.... ,,'''a4a: ~~ i ::::. t..";.';%%::.~A>iy>°~,S'z~:r:."+,~:5'G'w.s'!1~~ .,~: f; ..9• , ~, :: .....i:9e:e:9r•••......... .: :i: rij;zxxti:;:l:]j?!ij:: ,n~:,ryq; . ~ ~l I l i~iiie Sreeesee•.. i::fE! 11;'"':i~'.+': 1.0 e..~![li ili!eiiei';Iil p eT"~,n,Hl! ~eli~ :JlY::z iiii :s:: !i~!::~::eiii ~Ii Hl!I IIIIineFi?i?iee .!f!ifi lii!! ! ': i^.'ff~~!t~~{~:,~ee eie ~i!ilii3:eeieeezif J d u: ~ : ... .p I++Grr.r...:.:"ie !i.i. ~ CF!u !E y'~ ~ 4T ;!! i!i ;'f'~¢ "f:^^~::.li' :::'F:` :' 31:-'ri "i:, ~1:31:3:::~3::: 33:::: E;. :iii' eie' 'i Vii' ~~ ~! sperry-sun ~~. DRILLING SERVICES i~ z~ Show Report .':i'.. ::.i:.. ..3.::sA:.>.:a~.,.::.:re- i... r": a'i: ..:.;t?«::li:.~a:!C;3r;:;r•..:.. ~:3~3iN!3tie;!i3e::1 ..:~,.;:.~:~,.:,:::.:..Y~.. ~::~::::.:.:..:- .::r:~:::~i:!;;•. ell Name: GUBIK 3 Depth MD 3535 to 3595 ft =` ( ) ii! ~n Location: FOOTHILLS (TVD) 3535 to 3595 ft es; Operator: ANADARKO Show Report No. 198 ;,r:.e Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 25-Feb-08 Report Delivered To: John Kamm p~ InterpretBtlOrt: Chromatograph gas in air analysis from gas trap at possum belly. u If i3! Formation :Sandstone- clear to light gray, fine to medium grain, angular to subangular, moderately to well consolidated, moderately '¢ sorted, mica and mineral fragments, some carbonaceous material, calcareous, no visible porosity, no stain odor fluorescence or cutfluorescence. ,.: :, e` ::e 3F: . ... :: :::: ...........:::z:::.::~::z<:i:..:e..:y:s~::~~:.:.vu. :i:i: e":.::::::::a:a.:i .... ... .:. ... ............ . .3 e. .: a aaa s 'a ' ' ' ' ' ' i a:e. pae :::::.:~.:;::::Ve n:e: :Ce ^:..uue 1 j Depth 3550 ft Gas '---------------------------9 --- Flowline Back rou , e., . ., .. e . .:: .... .. ! u...u.r.... .r.. % x Units 1629 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show . ; . i Hydrocarbon Ratios C1 C1 C1 C1 - - - - '' C2 C3 C4 C5 . ppm PPm ppm Hydrocarbon Ratios 1000 0 .i, . ` C1 174420 - 13757 = 160663 C1/C2 = 52.9 ii !ee C2 3438 - 403 = 3035 C1/C3 = 582.1 C3 348 - 72 = 276 C1/C4 = 3570 3 . ~! C4 70 - 25 = 45 C1/C5 = 32133 NPH ~~ C5 5 - 0 = 5 '~' Production 100.0 ,-~ `' Analysis x Gas Oil Water Non-Producible Hydrocarbons Ike r` iii; 2 % !~i ' Depth 3553 ft Gas --------------------------- --- s) na x Units 1851 Mud Chlorides (1000 ------------------------------------------------------ Gas ee; k3 9 Flowlme Back round Show E PPm PPm PPm ='i Hydrocarbon Ratios ,.;! 10.0 .. - - ------------ --- - - . - - ----- - ---- ~ . ------ --------- !!!! tip C1 195301 - 13757 = 181544 C1/C2 = 50.1 !lei !. C2 4026 - 403 = 3623 C1/C3 = 532.4 Oil ~ C3 413 - 72 = 341 C1/C4 = 3300.8 ' C4 80 - 25 = 55 C1/C5 = 18154 C5 10 - 0 = 10 NPH -- ---------------------------------------------------------------------------------- ~y Production ;. ue Analysis x Gas Oil Water Non-Producible Hydrocarbons ~, 3 % Depth 3559 ft Gas x Units 1382 Mud Chlorides (1000's) na :, ---------------------------9 --------------------------------------------------------- ^' Flowlme Back round Show 1.0 ydrocarbon Ratios `L C1 C1 C1 C1 - - - - C2 C3 C4 C5 i PPm PPm PPm ~~I Hydrocarbon Ratios ,l 1000 0 . C1 150305 - 13757 = 136548 C1/C2 = 51.7 - 2640 C1/C3 = 557 3 403 3043 . - = ~ C2 C3 317 - 72 = 245 C1/C4 = 3413.7 C4 65 - 25 = 40 C1/C5 = 17069 NPH ile:.e ;:; C5 8 0 8 e;3:_ '~ Producton 00.0 ---~-~ ::: !, e!!i ibl H d b N P d ~~ y rocar ons on- ro uc e Analysis x Gas Oil Water ~' ~ ` 4 % ~~ i 1000' M d Chl id Gas ee:e I,i~ Depth 3561 ft Gas eeee------------------- --- s) na or u es ( x Units 896 w-------------------------------------- --------§ n . - - ,:: 3! ho Flowline Backgrou d ::, PPm PPm PPm Hydrocarbon Ratios 10.0 _ _ _ _ . , ! !~! C1 96339 - 13757 = 82582 C1lC2 = 52.0 ° ~, Oil ;,, :il C2 1991 - 403 = 1588 C1/C3 = 569.5 ~e 1! ~! ie:! ' C3 217 - 72 = 145 C1/C4 = 3590.5 fie '' C4 48 - 25 = 23 C1/C5 = 13764 C5 6 - 0 = 6 NPH ------------------------------- ----------------------------------------------- Production L~ "' Analyses x Gas Oil Water Non Producible Hydrocarbons fie; ....~,yy. ~. :~:.m~.::.z::z.. 33:3m 3 U :..333 ..i !! . ... :.. i :. ~. .. ::~:: ee:r 3:3:11:.! 1.0 e!ei ill! i::: z:::.::>.,...:: ~ . ir.~; :~i a game ; i!!e .: i. . °i i' ' s 3E3' Fea ~` ~t~ .I.... .!•A '~ ! is ..i :::^.^: eg. ! .. 7 :..:N:~;g~`•~Y3..g..: !: •:i: ~!ee:i:i ::e 3~ a n.: it : I E : I~:. :i i k ' 3 ;N... . it~' ~~~:: ..I ~ 3......i e ~I!i'!e: i :i:.a::i :e: ...~..a:.a :.. .!::!~1~~E"........11 .:.. .....:... .nr:..: .{.,..:...J..e:'ei 3 is `~ ~. :.>.>:::::~i ::ge:n::::::: t i~ 1 r : _ ` ;; ~ ; . .: i`; I!iiiii!i!i:iiiii:iiriii!ji5:!uii!i!iiii iii?ri!~ti:t' !i !i;:: ~c •iii 'i&x: .§' ..!:i;r~°.. I i::ll l$ji ~; ! iii. ... :.::..:...:..:..:.:..:.... s ..:. !. ~: ! .. c .... ~: sperry-sun Well Name: GUBIK 3 Depth (MD) 3535 to 3595 ft Location: FOOTHILLS (TVD) 3535 to 3595 ft : DRILLING SERVICES Operator: ANADARKO Show Report No. 19C Show Report Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 25-Feb-08 Report Delivered To: John Kamm Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. ;.! Ij Formation :Sandstone- clear to light gray, fine to medium grain, angular to subangular, moderately to well consolidated, moderately iti sorted, mica and mineral fragments, some carbonaceous material, calcareous, no visible porosity, no stain odor fluorescence or s cut fluorescence. i! ~ !,I, !!!! Depth 3574 ft Gas i!!! --------------------------9 --- I~Ij Flowlrne Back rou ~~~% x Units 1121 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show Hydroca C1 C - - C2 C rbon Ratios 1 C1 C1 ! - - ~; 3 C4 C5 :! ppm ppm ppm Hydrocarbon Ratios 1000 0 y ! !~~ y: . m C1 118059 - 13757 = 104302 C1/C2 = 44.2 °~~ ~ `! C2 2763 - 403 = 2360 C1/C3 = 521.5 I'~ C3 272 - 72 = 200 C1/C4 = ###### C4 29 - 25 = 4 C1/C5 = 17384 NPH .! _ n P d ti 100.0 ---- ---- --- --- --~-~----- --- !:ji ro uc o ' Analysis x Gas Oil Water Non-Producible Hydrocarbons ~ iii .. 2 ea % ' ., Depth 3577 ft Gas --------------------------- --- s) na x Units 1284 Mud Chlorides (1000 ----------------------------- ----------------------- Gas .. 'N! !'! ! Y 9 Flowlrne Back round Show I! ppm PPm Ppm iii H drocarbon Ratios 10.0 - - ~ ~ ----------- _ _ --- ----- _ ~ --------- - - it : C1 143903 - 13757 = 130146 C1/C2 = 46.0 i C2 3231 - 403 = 2828 C1/C3 = 650.7 'ai i I~ Oil s ~!' - ii!i C3 272 - 72 - 200 C1IC4 = 3337.1 `! C4 64 - 25 = 39 C1/C5 = 16268 (~ C5 8 - 0 = 8 NPH :. ! -------------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 'i~l ~` ,~~ 3 !., iii De th 3580 ft Gas isi -------- p --------------------- Flowline Backgrou % x Units 1151 Mud Chlorides 1000's na --------------------------------- ~ -------------------- nd Show C - C Hydrocarbon Ratio 1 C1 - 2 C3 s C1 C - - C4 C 'll 1 !; 5 I~' !ii PPm pPm pPm iili Hydrocarbon Ratios 1000 0 ;!: IIII . € Ii! C1 119558 - 13757 = 105801 C1/C2 = 47.7 1/ = 789 6 2218 h . C C3 C2 2621 - 403 = C3 206 - 72 = 134 C1/C4 = 3778.6 !!! ' C4 53 - 25 = 28 C1/C5 = 15114 NPH ije :: ,~ - C5 7 - 0 -- 7 Production 100.0 - ----'-~ -- . - ------ ------- ! bl H d b ' ons y rocar e Analysis x Gas Oil Water Non-Produci F~' ~;' 4 % :.y ! 1 0' ::: i De th 3586 ft Gas ! ' s na x Units 751 Mud Chlorides 00 ~ - f Flowline Background Show ~ PPm PPm Ppm Hydrocarbon Ratios 10.0 _ _ - " - ~ _ - ------------ - lii !! ~' ~' C1 87869 - 13757 = 74112 C1/C2 = a7.o Oil C2 1981 - 403 = 1578 C1/C3 = 628.1 E C3 190 - 72 = 118 C1/C4 = 2470.4 !;: I I C4 55 - 25 = 30 C1/C5 = 9264 ii'i C5 8 - 0 = 8 r NPH ----------------------------------------------- :isi------------------------------- j~N Production ,4nalysis x Gas Od Water Non-Producible Hydrocarbons :. -:. ,.. 1 :::. , 1.0 r u ' ii;!::Liii.ltili!i ~..;; . j: I' iil'. ' I "; 0~::::em::::::::: '! -r~ :!I' i .Dill ii i'!!. 5ij.;ti''i'~' `~~ :~ ; ff , J::n~q,.. a i!!, . ip. i 'u : `I sperry-sun g DRILLING SERVICES `~' Show Report :I ~° r!i:, ., ti.in!!:!!.~ 'ill~ii!iE!~!:::::~::::::::5:.:~a!,g •~'~ k:i?i..~'r' well Name: GUBIK3 Depth(MD) 3611 to 3655 ft ; Location: FOOTHILLS (TVD) 3611 to 3655 ft Operator: ANADARKO Show Report No. 20 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 24-Feb-OS 11 Report Delivered To: John Kamm iil ' i 'I: ,i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- clear to light gray, white in part, fine to medium grain, angular to subangular, moderately to well consolidated, tightly cemented in part, moderately sorted, abundant carbonaceous material, non calcareous, no visible porosity, no stain, odor, fluorescence or cut fluorescence. ~:: ::,;.. . :. ~:: :~x i:.. ,~ ~ ~ . . .. : !ee:.. .. :~ ~ .: 4 De th 3615 ft Gas --------9 --- -------- P --------- Flowline Back rou .. ... i .. ... ~: e:...:.r. :. : t:.d % x Units 839 Mud Chlorides 1000's na ---------------- ~ ) ---------------- -------------------- nd Show Hydrocarbon Ratios C1 C1 C1 C1 - - - C2 C3 C4 C5 ` "= ppm ppm ppm 'i! Hydrocarbon Ratios ! 1000 0 ~ . "~ C1 84948 - 23164 = 61784 C1/C2 = 39.8 iii: I C2 2242 - 688 = 1554 C1/C3 = 297.0 9 C3 330 - 122 = 208 C1/C4 = 1625 . ~= C4 77 - 39 = 38 C1/C5 = 5617 NPH r C5 16 5 = 11 -------------------------------------------------------------------------------------- : Production 100.0 --- ------ - _ . . u : ! ill; Analysis x Gas Oil Water Non-Producible Hydrocarbons :: Ilil 2 ~ ' ,: Depth 3620 ft Gas l -------- --- '' s) na----- x Units 908 Mud Chlorides (1000 ------------------------------------------------- Gas 9 Flowline Back round Show pPm PPm PPm Hydrocarbon Ratios ~ 0.0 ---~- ------- ----- _ .. - - -- -- ----- _ _ --- : is i 11 C1 102931 - 23164 = 79767 C1/C2 = 41.8 ~` C2 2596 - 688 = 1908 C1/C3 = 343.8 it '!ll Oil C3 354 - 122 = 232 C1/C4 = 1945.5 ` C4 80 - 39 = 41 C1/C5 = 7252 € C5 16 - 5 = 11 -- ~! ~i: !------------------------------------------------------------------------------------ i Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ilil il! g °i° ilK Depth 3630 ft Gas x Units 700 Mud Chlorides (1000's) na ---------------------------9 --------------------------------------------------------- Flowlme Back round Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C 1 5 i m m m ,~ PP PP PP :!, Hydrocarbon Ratios 1000 0 a ! . 69538 - 23164 = 46374 C1/C2 = a2.8 ill: c1 1083 C1/C3 = 291 7 1771 688 I;il . - = C2 i i C3 281 - 122 = 159 C1/C4 = 1405.3 ,`~ C4 72 - 39 = 33 C1/C5 = 4637 NPH ~:--CS----------15 5 = -10 ~" Production 100.0 ~ -~ --- ~- ----- (I '•' !iii b N P d ibl H d i'i rocar ons on- ro uc e y Analysis x Gas Oil Water :iii 4 % ~` id 1000' 1 M d Chl Gas Depth 3636 ft Gas ~::, ,:: --------------------------- -- '"i s) na or x Units 7 u es ( 0 ------------------------------------------------------- Sh - - g ow Flowlme Back round PPm PPm PPm !t! '~E` Hydrocarbon Ratios i!i 0.0 _ - - - _ _ :: !ii i C1 71072 - 23164 = 47908 C1/C2 = 42.4 ~lii Oil C2 1819 - 688 = 1131 C1/C3 = 246.9 li 1 ~i C3 316 - 122 = 194 C1/C4 = 977.7 'ryl C4 88 - 39 = 49 C1/C5 = 3422 I C5 19 - 5 = 14 -- NPH E,, l,i, r!I------------------------------- --------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 3; 'kuii~ ~ E~i~iiYh!i ~i:i" .:....:.xx....... k ..:h ::::.:~::::u::::~;:;: ~::.:kN ... .. :. !iii:s:l:X:~!i: ..4x:3..: .:.<:a: ::i:.::i::~ i i .:E.!.:.....x... EE:I !. ~ ::i9!i~:::::>:::..::: i I.I:IIE:E!,::::::::::,....,::' ::: E.E li ~ ~:!I i' :. a E ~. ... .. E. a .........:.x........::.. .A. . i . i . n..:.u!i:+i l i 9 i .:.... uar... E:i!i?jei:~ :!e]A:~ Eiiifiee:z ..............:.,.::..:f.. F4a .....:.: . .:.................,x:..:..q":.:1:.:::.:.:::. .......:...........,:... I . :.uW 1.0 "E:r::: -s!:r':==;>3tt>: .h!r:~:,., nt.:.....::.... !!;i w . e!:!f Ei! YjE~eiii'' eee.3ei~~"[.. ...:::; Vie::... :.n!1ei EY'e].:.. a.. ' h'::.....E..:..:...,.nhl:!.,,::::u ::.!... . . :.t' `si"i ieilaa.e:Eee::.e3e~$'p~" .:....... .... ~!;; liii :......:. ~::::n:s::: s:.r:.raa: .~ sperry-su h II 'I DRILLING SERVICES Show Report ii; .. i ~li ~eyi "e,';Ai.',ua..... I i:l,.I;;: A .~! `~k: ~i Well Name: GUBIK 3 Depth (MD) 3760 to 3811 ft Location: FOOTHILLS (ND) 3760 to 3811 ft ' .I Operator: ANADARKO Show Report No. 21 Report Prepared By: Mike Daigle/ Doug Wilson Datelfime: 25-Feb-08 Report Delivered To: John Kamm ;x Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, very fine to fine grain, medium grain in part, angular to subangular, moderately sorted, well consolidated, tightly cemented in part, no stain, odor, fluorescence or cut fluorescence. .:.I ~ 1 % Depth 3769 ft Gas x Units 400 Mud Chlorides (1000's) na ~! Flowlme Background Show ...:: ~... I: I::I:,I..:: ::.:. .,: ,I,I.i~ i Hydrocarbon Ratios :!, k~ C1 C1 C1 C1 'ii - - - - !: C2 C3 C4 C5 ppm ppm ppm !~ H drocarbon Ratios ill y 1000 0 u ;:j . 'I' C1 40585 - 11277 = 29308 C1/C2 = 35.5 C2 1288 - 462 = 826 C1/C3 = 418.7 i C3 159 - 89 = 70 C1/C4 = 610.6 C4 74 - 26 = 48 C1/C5 = 2093 NPH C5 14 - 0 = 14 Production 100.0 A l i Oil W t N P d ibl H d b G !~~! rocar ons na ys s x as a er on- ro uc e y 2 % I'i h i 2 M hl id 1000' :i Dept 3775 ft Gas !I-------------------------------- Fl l B k s) na x Un ts 46 ud C or es ( ----------- ---- -------------------------------------- d Sh Gas 'I'i !` ,i; ow me groun ow ac ~~ il ppm ppm ppm ,: ii Hydrocarbon Ratios 0.0 _-- -------------- .-- - ------- --- _ _ --------- ; is C1 47029 - 11277 = 35752 C1/C2 = 37.1 C2 1426 - 462 = 964 C1/C3 = 151.5 2 236 Oil C1/C4 = 458.4 C3 3 5 - 89 = 78 C1/C5 = 1324 C4 104 - 26 = C5 27 - 0 = 27 NPH .: ,:;: 'i' Production ; Analysis x Gas Oil Water Non-Producible Hydrocarbons I! i;; 3 °i° ``! Depth 3779 ft Gas x Units 460 Mud Chlorides (1000's) na I; ____ ~!! Flowline Background Show !i Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 i~' ~1 Hydrocarbon Ratios 1000 0 . - :: C1 61028 - 11277 - 49751 C1/C2 = 35.0 ~ 462 = 1423 C1/C3 = 140 5 C2 1885 i . - ~r ti"i C3 443 - 89 = 354 C1/C4 = 432.6 ~K; ~ C4 141 - 26 = 115 C1/C5 = 1213 NPH I~ i'i---------------------------------------------- ------------------------------------ INi Production 100.0 ------------ -----~ -'--~- ------------- :ei .c, , ` > Analysis x Gas Oil Water Non-Producible Hydrocarbons ~ : ~ 4 0 /o E I D th 3787 ft G na 561 M d Chl id 1000' U it Gas ~' as ep ---------------------------9 -- B Fl li k or x n s u es ( s) ------------------------------------------------------- Sh d - ~ ~ ~' °III ow roun ow ne ac I,: ,,: ppm ppm ppm ~; Hydrocarbon Ratios 0.0 _ ~ - - - ~ _ . : ~? i°` r C1/C2 = 31.0 C1 48064 - 11277 = 36787 ` i Oil ` '" 1647 - 462 = ;~! C2 1185 C1/C3 = 133.8 ;`:. 3 2 4 275 9 " C1/C4 = 44 . - 8 C3 36 = y i?'. i C4 109 - 26 = 83 C1/C5 = 1599 ~ t, C5 23 0 = 23 --- NPH j ili - ------------------------------- -------------------------------------------- Production ~N Analysis x Gas Oil Water Non-Producible Hydrocarbons ii:i.. 1.0 ~' ~; ,.... ; ;r: ii?".lip iiii;i( `:. ~ II i ..:li... .I Ili:,: II . ni : : ~ i. sperry'$un DRILLING SERVICES Show Report ~, , Well Name: GUBIK 3 Depth (MD) 3970 to 3994 ft Location: FOOTHILLS (TVD) 3970 to 3994 ft Operator: ANADARKO Show Report No. 22 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 26-Feb-08 Report Delivered To: John Kamm Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, very fine to fine grain, medium grain in part, angular to subangular, moderately sorted, well consolidated, tightly cemented in part, no stain, odor, fluorescence or cut fluorescence. ~ °i° Depth 3769 ft Gas x Units 400 Mud Chlorides (1000's) na ----------------------- ---g -------------- ------------------------------------------ Flowline Back round Show Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 40585 - 11277 = 29308 C1/C2 = 35.5 C2 1288 - 462 = 826 C1/C3 = 418.7 C3 159 - 89 = 70 C1/C4 = 610.6 C4 74 - 26 = 48 C1/C5 = 2093 NPH C5 14 - 0 = 14 Production 100.0 --- ---- -------~.-~-~-- ----------------- Anal i x G Oil W t N P d ibl H d b ~a ys s as a er on- ro uc y rocar ons e 2 % De th 3775 ft G U it 462 M d Chl id 1000' ----- --- p -_ as -------- Fl wlin B k x n s-- u or s) na es ( ------- ----------------------------------- - d Sh Gas : o e ac groun ow Ppm pPm PPm Hydrocarbon Ratios 0.0 _ . - - ___-- _ _ ~; ::~ ; 7 C1 4 029 - 11277 = 35752 C1/C2 = 37.1 ti C2 1426 - 462 = 964 C1/C3 = 151.5 'i l C3 325 89 = 236 C1/C = Oil ll€ - 4 458.4 104 26 = 78 C C C Iii I 4 - 1/ 5 = 1324 C5 27 - 0 = 27 ------------- NPH 1 0 it iiii -" Production ni il! Analysis x Gas Oil Water Non-Producible Hydrocarbons . Ill 3 °i° Depth 3779 ft Gas x Units 460 Mud Chlorides (1000's) na ------------------------------------------- ------------------------------------------ ' Flowline Background Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C i "~' il! 5 j .r: PPm PPm ppm ~i Hydrocarbon Ratios 1000 0 i . C1 61028 - 11277 = 49751 C1/C2 = 35.0 ~ C2 1885 - 462 = 1423 C1/C3 = 140 5 . C3 443 - 89 = 354 C1/C4 = 432.6 NPH '~ C4 141 - 26 = 115 C1/C5 = 1213 ~` __C5__________41 ____ 0 = 41 :~ Production 100.0 ----------- _ Anal sis x Gas Oil Water Non-Producible H drocarbons I y y 4 De th 3787 ft Gas x Units 561 Mud Chlorid s (1000's) na Gas p ---------Flowline ----Back rou e nd--------Show -------------------------------------- ~-- ~~ g PPm PPm PPm Hydrocarbon Ratios 10.0 _ - - - ~ _ I ~! 48064 36787 11277 - C1/C2 = 31.0 = C1 Oil C2 1647 - 462 = 1185 C1/C3 = 133.8 C3 364 89 = 275 C1/C4 = 443 2 - . 109 26 = 83 C1/C5 = 1599 ~ - C4 C5 23 - 0 = 23 :--------- --------------------- ----------------------------------------------- NPH 1 0 ? Iii - Production Analysis x Gas Oil Water Non-Producible Hydrocarbons ., ~aaa:. ~~:... a. :.~~:~~. !~'.;;K. ' ::.^:i: ~::. ~a~::..x: ~'1i ' .~! :•3"..: '•5'. ~ :.~!_.~: I.:I ~. .. ;. '.r.. ..x3;s,;: .r=ti:~3i ~:; ~ :~ i'~~ ..,;~;~~~.:,, ...~~,.. i2G'd'n .. ~:. . . it' ii i ~i:: ; . I .: .. i...:::s?~'i iii: :.. u. ~. ~ 1. . ':;.: i~i. i. ~iU;~:~i:.;iii;;:;::ei;:::re::::r;:i:r:.: " a::r::i..:, ~~ sperry'SUn DRILLING SERVICES ~ Show Report „g '~li .' :..:.::.~.:......:: .. ~~ I: well Name: GUBIK3 Depth(MD) 4034 to 4100 ft Location: FOOTHILLS (TVD) 4034 to 4100 ft 11 CIE; Operator: ANADARKO Show Report No. 23 :;; Report Prepared By: Mike Daigle/ Doug Wilson DatelTime: 26-Feb-08 ,~i Report Delivered To: John Kamm . ,, :...::. .: .... .. . ........... . ... .. ... ....: .. .:.. : .: : , . . . . . .. ................. .::.:.:e! 'j 1 .I InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- li ht ra to ra ve fine to fine rain, medium rain in art, an ular to suban ular, moderatel sorted, well ~! 9 9 Y 9 Y: rY 9 9 P 9 9 Y ! consolidated, tightly cemented in part, no stain, odor, fluorescence or cut fluorescence. I .: . :e.::: ::.:.::.:' :: : ... . . . : 1 °io Depth 3769 ft Gas x Units 400 Mud Chlorides (1000's) na :: :t----------------------- ---g --------------------------------------------------------- Flowlme Back round Show Hydrocarbon Ratios C1 C1 C1 C1 _ - - - C2 C3 C4 C5 , ,1 ppm ppm ppm Hydrocarbon Ratios 1000 0 h . C1 40585 - 11277 = 29308 C1/C2 = 35.5 ,~ C2 1288 - 462 = 826 C1/C3 = 418.7 x C3 159 - 89 = 70 C1/C4 = 610.6 C4 74 - 26 = 48 C1/C5 = 2093 NPH ~; :: :; :., ~~'~ Production I 100.0 . ~ !; - ,,: ~; Anal sis x Gas Oil Water Non-Producibl H dr rb n y y Ii e oca o s ;;; . ~~! f , .: ea :j ii ~! De th 3775 ft G x Unit 462 M d Chl id 1000' ~ ! p as '` Flowlme Back rou s u or es ( s) na nd Sh w Gas y e.. o !, ,~~~ PPm ppm PPm Hydrocarbon Ratios i! 0.0 _ _ .. - ----------------- _ -- -- -------- - - - r:.; 1 47029 11277 35752 - C = C1/C2 = 37.1 ' = ~~~ ' C2 1426 - 462 = 964 C1/C3 = 151.5 I ~1 ' C3 325 89 = 236 C1/C4 = 458 4 Oil j! - . -I C4 104 26 = 78 C1/C5 = 1324 ~:: '` - e: :::: :::: C5 27 - 0 = 27 :~: NPH I11 ,~~ '~~ Production tit Analysis x Gas Oil Water Non-Producible Hydrocarbons I ~!I `~ 3 °io ~'` ;. Depth 3779 ft Gas x Units 460 Mud Chlorides (1000's) na 1-------------------------------------------------------------------------------- Flowlme Background Show C C Hydroca 1 C 2 C rbon Ratio 1 3 s C1 C C4 C ~`~ 1 ::: 5 e1 i ppm ppm ppm Hydrocarbon Ratios 000 0 1 ~~e Ill: !'~ 61028 11277 4 7 . I, C1 - = 9 51 C1/C2 = 35.0 ,e. C2 1885 - 462 = 1423 C1/C3 = 140 5 i* . ' C3 443 - 89 = 354 C1/C4 = 432.6 NPH t :. 11 H C4 141 - 26 = 115 C1IC5 = 1213 .. ;. ~I :; ; :: ;r - °' C5 41 0 = 41 fi Production 00.0 -- ----'-~---- _ ~ ----- ----- , ~I~ '..: ~~~ I111 X11 Analysis x Gas Oil Water Non-Producible H drocarbons y 4 0 /o De th 3787 ft Gas x Units 561 Mud Chlorides (1000's) na Gas i!I p ---------Flowline ----Back rou nd--------Show -------------------------------------- - - - I' g PPm Ppm PPm Hydrocarbon Ratios 10.0 - - ' - _ _ . 1111 ii I C1 48064 11277 = 36787 C C !' - 1/ 2 = 31.0 Oil j» C2 1647 - 462 = 1185 C1/C3 = 133.8 C3 364 89 = 275 C1/C4 = 443 2 i "~ - . C4 109 26 = 83 C1/C5 = 1599 j I! i'I! - C5 23 - 0 = 23 ". .. ---------------------------------------- NPH 1 0 I? 11~ i1 Production Analysis x Gas Oil Water Non-Producible Hydrocarbons .:.~E:::.,::..: e:l~e i~' . E .uui..: ..1 eel:e.:,:...:.. ?eeeli?eeeeiei'e'iiF:eieiu•u::~ . ei(j'e"':':".....-- : f.l''. ..1... J~:. :::.... ........... v'~'•:iu. i........., s! AI~::M:a:!]fee'l;:eeeeieeyeeeey';ee:"'eeee ":1iBlei~:''1"••.. •.•.:~:.. eeeei iiii{iii ee` . t..: . :uo:e:]e!::y:xe,x:9yjy::yyy:...F:.. .:^::.r. ~..:,........u:...:e:~::~:.::...S.i.u•S; asa:.: a;:;m!ejj!e: ~:.:..: eie 3!ieei .................. i :.:n., ... ..... ij'. .... ::..I............: .... s ....:.......:.:..:......::.:... ~::.:......:....U:..i'i .. .:~ 3 Ii. ~:........ . w:: i'i. . . `vii" uiJi'`:i zja~li.... ..fix. :.:f. iejii~i:e :::e:x:. .:::~ i::fir'i. 4.:.3.:.. :I1. . ~' H e } , . '.~'<:Y i. y3.:j$Ny'a'r :..U ~ rj~ ~;,; :~z:``:?iiii •'.~ . sperry'$un DRILLING SERVICES Show Report Well Name: GUBIK 3 BP01 Depth (MD) 3208 to 3229 ft Location: FOOTHILLS (TVD) 3207 to 3228 ft Operator: ANADARKO Show Report No. 1 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 7-Mar-08 Report Delivered To: John Kamm '' ii ` i Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, very fine to fine grain, angular to subangular, well sorted, well cemented, decreasingly f lithic, silty in part, non-very slightly calcareous, microcarbonaceous specks, mineral grains, no visible porosity, very firm to medium hard, "~ no fluorescence, no odor, no stain, no cut fluorescence ::. ~ 1 % :.: lei De th 3210 ft Gas x Units 456 Mud Chlorides 1000's na _ P ( ) --------------------------9 --------------------------------------------------------- li Flowline Back round Show ~ Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ~~ ~:. ~;, t Ppm PPm PPm ag Hydrocarbon Ratios 1000 0 ~: <li . C1 50196 - 18209 = 31987 C1/C2 = 42.3 C2 1609 - 853 = 756 C1/C3 = 166.6 4 C3 377 - 185 = 192 C1/C4 = 477 . C4 97 - 30 = 67 C1/C5 = 31987 NPH ~! ~~,i,i C5 1 0 = 1 ~'i---------------------- Production 100.0 -------- --- -- Y ' -- ------ -- !; "' ' ~k ~ Analysis x Gas Oil Water Non-Producible Hydrocarbons ~ 2 ' "' Depth 3213 ft Gas ti--------------------------- --- s) na x Units 462 Mud Chlorides (1000 ------------------------------------------------------ Gas ~ 9 ,;i Flowline Back round Show PPm Ppm PPm ,i Hydrocarbon Ratios 0.0 ---~- ------ ----- . - - - - -- ------------ _ _ --- - ------- ~ I: ;,f C1 49249 - 18209 = 31040 C1/C2 = 41.8 v ` C2 1596 - 853 = 743 C1/C3 = 164.2 Oil C3 374 - 185 = 189 C1/C4 = 431.1 C4 102 - 30 = 72 C1/C5 = 15520 C5 2 - 0 = 2 -- NPH f :: _ ----------------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 ~s ~ " 3 Depth 3226 ft Gas x Units 639 Mud Chlorides (1000's) na ~' !---------------------------9 --------------------------------------------------------- Flowlme Back round Show ~ C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C ~ 1 5 I ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 66717 - 18209 = 48508 C1/C2 = 38.4 3 853 = 1263 C1/C3 = 148 2116 . C2 - ~~ C3 512 - 185 = 327 C1/C4 = 437.0 `' ' If C4 141 - 30 = 111 C1/C5 = 24254 NPH C5 2 - 0 = 2 .:. °r -------------------------------------------------------------------------------------- Production 00.0 --- -~~-~--- ~~ b N P d ibl H d rocar ons on- ro uc e y ~ Analysis x Gas Oil Water ~ /I ., I:.I , "I 4 : % . i ;... ;. , '~ 1000' M d Chl id Gas j~!j --- Depth 3229 ft Gas !I-- --------------- -- s) na----- or x Units 759 u es ( -------------------------------------------------- Sh - - ~;i ~' 9 ow Flowline Back round PPm PPm PPm Hydrocarbon Ratios :: 10.0 - - - - - ~--- .. --- : `!I !ill ~~ Ikl C1 73475 - 18209 = 55266 C1/C2 = 37.4 ~~ Oil ' i C2 2331 - 853 = 1478 C1/C3 = 153.9 ~ C3 544 - 185 = 359 C1/C4 = 472.4 ~ C4 147 - 30 = 117 C1/C5 = 55266 C5 1 0 = 1 --- NPH ~ ~i F: ~ ---- ------------------------------- ---------------------------------------- Production I ij ,~i; Analysis Gas Oil Water Non-Producible Hydrocarbons .. ..~;.. ,IS .. ::~ ~::: "!51 i °i e ~ ~ r...... ,.fh' 1.0 i{e .~ Uq ~ ''l ..I ::. irk if .. h :: :I :..C , I. :pSf ..t'~.~~.•... : {: :f` ` 9pf:;. it . s y~ !'i - ,;Ef: i:::a:.u:.::.: .:~ ~: .. I...,,.., ,~!i sperry'SUn DRILLING SERVICES "~ Show Report I~ ... ':e: . . r .,~ y~, F,y~ Siiu~~.: e!~, 'eELrre ~:e:En. .E EY:F~1xk;. GE:tr y''~~1.,:"'vi3 lyii~J`~ee~~~y~,~j. .:: ~!~eN: .. ,n,li:n. x: ~' K :...~. ..: :e. :.sz. Well Name: GUBIK 3 BP01 Depth (MD) 3233 to 3257 ft ` Location: FOOTHILLS (TVD) 3232 to 3256 ft ~! Operator: ANADARKO Show Report No. 2 'E Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 7-Mar-08 i ::: !~~I Report Delivered To: John Kamm r! :.: ..,.....: : : . :. ~ : ,.. ...... , :.: : :. : ,. ::, ...... E ~E . .... .. 6 II'. Interpr@tatlOn: Chromatograph gas in air analysis from gas trap at possum belly. '~ Formation: Sandstone- light gray to gray, very fine to fine grain, angular to subangular, moderately sorted, well cemented, trace lithic, silty in part, non to very slightly calcareous in part, microcarbonaceous specks, mineral grains, no visible porosity, `Et `' trace pyrite, very firm to medim hard, no stain, odor, fluorescence or cut fluorescence. ,: .:.M ~ ~ ~ Depth 3233 ft Gas s .,'---------------------------9---- Flowlme Back rou :-~:~:~, °i° x Units 510 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show . Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 ;` ~~! a ;„ PPm PPm PPm Hydrocarbon Ratios 1000 0 ~E E . ,F ` C1 52893 - 18209 = 34684 C1/C2 = 27.2 C2 2126 - 853 = 1273 C1/C3 = 120.0 C3 474 - 185 = 289 C1/C4 = 408.0 C4 115 - 30 = 85 C1/C5 = 34684 NPH C5 1 - 0 = 1 .::: E;~ -------------------------------------------------------- . _-Production ----------------- 00.0 ----------- -----~.-~-~ b Analysis x Gas Oil Water Non-Producible Hydrocar ons 2 % y rl~ hl i 1 ' iii ---- Depth ---3235 ft Gas ~~~ or s) ---- na x Units 378 Mud C des ( 000 ----- h Gas ow Flowline Back round S ti 9 sp PPm PPm PPm ... Hydrocarbon Ratios 10.0 - - -- ----------------- _ - - ---------------- - - --------------- _; ~ .. C1 37326 - 18209 = 19117 C1/C2 = 27.9 :II C2 1539 - 853 = 686 C1/C3 = 116.6 1 4 Oil I C1/C4 = 398.3 C3 349 - 185 = 6 'I VII ~ C4 78 - 30 = 48 C1/C5 = 19117 :: C5 1 - 0 = 1 ~::: -------- NPH 1 0 k ------------------------------------------------------------------------------ Production ''' Analysis x Gas Oil Water Non-Producible Hydrocarbons . 3 °i° Depth 3247 ft Gas x Units 272 Mud Chlorides (1000's) na ---------------------------g --------------------------------------------------------- ;g Flowline Back round Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C 1 r ,.:: ,,:, 5 ppm ppm ppm :; Hydrocarbon Ratios 1000 0 „~ . C1 27267 - 18209 = 9058 C1/C2 = 45.5 ..! ail 853 = 199 C1/C3 = 107 8 2 1052 . - C ~ C3 269 - 185 = 84 C1/C4 = 205.9 j k 4; C4 74 - 30 = 44 C1/C5 = #DIV/0! NPH ~j ~_ C5 0 0 = 0 1! -------------------------------------------------------------------------------------- Production 00.0 ---- _ ---~ - - ---- _ ~ ------------ ;; „I; ,,: j': n-Pr ibl H drocarbons l i Oil W t N d A G y ys s x a er o o uc e na as 4 '~ D h 3252 ft G 229 M d Chl id 1000' U it Gas ept as ---------------------------9 -- ;w ! Fl li B k s) na n u or es ( x s ------------------------------------------------------- d Sh . - ~ iE , ow roun ow ne ac Diu ,:, Ppm PPm PPm .: Hydrocarbon Ratios 0.0 _ ~ ' - _ _ - i~I `Iii iii: C1 20774 - 18209 = 2565 C1/C2 = 135.0 O l : C2 872 - 853 = 19 C1/C3 = 62.6 t 1 , C1/C4 = 106.9 i, C3 226 - 185 = 4 x C4 54 - 30 = 24 C1/C5 = 2565 ,; C5 1 - 0 = 1 ---- NPH I ~i :,:: ;r; ------------------------------- ------------------------------------------- ° Production rii "' Analysis x Gas Od Water Non Producble Hydrocarbons ~ ..:: .; .: 1.0 eeee .u.u. na:ye:::G .:.....:::a.... .E:r:.e..:E r :i:;.I:L:.:n ~,.,;......:.:., . «a. E ~ ei!:iti :'° lini;li9:li'~.s 4,i~!:4'. ~'[: a. ~. ..~~:~E i e:Ue:B]e e:e~': ~' E~ ~ it ~ i :I::: ;a.;i~. . ,.: I;..u;a:, ...n.:2... uau: ec';.. .a:::::a... ....~!~..... :.... .. ...... 1~!E... ...9::.....:.u:¢!E:E:~.i E :. '~ i;;; `'' ,INy .:... ... `~ sperP~/-su h DRILLING SERVICES ''~ Show Report ij. i! ~ l „ul;..,:.:1~ °:r~;:;:. ~. r~:.;;:: a:i!i~ii5ir9'rliR:;. € i nlai~~iS:;jni I; ~' ~ Il "i'r::..- u; :i:; Well Name: GUBIK 3 BP01 Depth (MD) 3273 to 3304 ft k Location: FOOTHILLS (TVD) 3272 to 3303 ft ~!! Operator: ANADARKO Show Report No. 3 Report Prepared By: Mike Daigle/ Doug Wilson Dateffime: 7-Mar-08 Report Delivered To: John Kamm Interpretation: Chromatograph gas in air analysis.from gas trap at possum belly. Formation: Sandstone- light gray to gray, salt & pepper, very fine to fine grain, angular to subangular, well sorted, mod -well cemented, ~~I trace lithic, silty in part, non to very slightly calcareous in part, microcarbonaceous specks, mineral grains, no visible porosity, trace calcite ~€ III ve firm to medim hard, no stain, odor, fluorescence or cut fluorescence. €Ir ry la: n ~~ ~~ ~.::: :::,::.~. ~ :,..;.;.. .::. ~ °i° ;.: ,_ ~ De th 3279 ft Gas x Units 360 Mud Chlorides 1000's na Flowline Background Show Hydrocarbon Ratios ~ C1 Ci C1 C1 C2 C3 C4 C5 ; ppm ppm ppm Hydrocarbon Ratios 1000.0 C1 31048 - 13543 = 17505 C1/C2 = 27.8 °" It C2 1344 - 715 = 629 C1/C3 = 72.3 C3 428 - 186 = 242 C1/C4 = 142 3 ' . C4 159 - 36 = 123 C1/C5 = 4376 NPH ~€ C5 4 - 0 = 4 €-------------------------------------------------------------------------------------- ~' Production 100.0 --------- - ----- ~ ' ---- -- - - ''€ ~I'` x Gas Oil Water Non-Producible Hydrocarbons .: Analysis i' I Iii 2 :, 'll ' De th 3281 ft Gas ~`~ ----- P - -- ------------ ------------ s na----- x Units 456 Mud Chlorides 1000 ---- --------------- ~----- ~ -------- ---- --------- Gas ,~ Flowline Background Show ~° pPm PPm PPm Hydrocarbon Ratios 10.0 _ ~ _ _ - ------- ~ ~ - ~ -- _ ------- ~i 1111 ' ~` = C1 45725 - 13543 = 32182 C1/C2 = 28.5 ~; `~I C2 1845 - 715 = 1130 C1/C3 = 86.0 I:l ~ Oil ! C3 560 - 186 = 374 C1/C4 = 213.1 ~~ 'I~' €€ 32182 C4 187 - 36 = 151 C1/C5 = ~~; il. C5 1 - 0 = 1 PH ,~, ~: ,: -------------------------------------------------------------------------------------- Product€on Analysis x Gas Oil Water Non-Producible Hydrocarbons 1.0 '€` s °i° Depth 3285 ft Gas x Units 305 Mud Chlorides (1000's) na ;,,- --------g --------------------------------------------------------- Flowline Back round Show C - C Hydrocarbon Ratios 1 C1 C1 C - - - 2 C3 C4 C -! 1 ~? ~ 5 PPm PPm PP-n Hydrocarbon Ratios 1000 0 I€; "` . r` C1 26757 - 13543 = 13214 C1/C2 = 22.5 715 = 588 C1/C3 = 97 9 1303 . - C2 C3 321 - 186 = 135 C1/C4 = 249.3 C4 89 - 36 = 53 C1/C5 = 13214 NPH ,~ `I C5 1 - 0 = 1 Product€on 100.0 _ ---~~ ~ - ------------ n N P d ibl H d b Oil W t 1 l i G er on- ro uc e y rocar o s a . Ana ys s x as 4 ° 2 M d hl id 1000' Gas Depth 3288 ft Gas •~ r: ----- - !' ~' s) na 7 u or es ( x Units 3 C ---- ----------------------------------- Sh - - Flowline Back round ow : r( 9 'r PPm Ppm PPm ,~ ~' Hydrocarbon Ratios 10.0 ~ ~ - - ~ ----------------- _ ~- ----------------- ------------ - ° ;€€ ~ I C1 25144 - 13543 = 11601 C1/C2 = 20.4 O i C2 1284 - 715 = 569 C1/C3 = 102.7 i 9 C3 299 - 186 = 113 C1/C4 = 305.3 ~~~' I' ;€ 38 C1/C5 = 11601 C4 74 - 36 = ,,, C5 1 - 0 = 1 €: NPH !.:: ------------------------------- ----------------------------------------------- Product€on Analysis x Gas Oil Water Non-Producible Hydrocarbons . .: 1.0 .,. . € ~ ~ ^.'.E "N .: ~ , ~Il:: .. r~,,,..:....~ ::u=:.:. fl;~~' :. .. .. ..i. ~;~~G1!!;jlt :.: :..€ J.I.. .:, I..: :e. zFjeiee::::::::a.:.;~ : Nr.: €~ -I .:., ::: "r.'ii i? iiek ' i i ii!' ij hiii'iii,ii.i:, i fi;h;,il.:ii!liii sperl"~/-sun DRILLING SERVICES '=! Show Report ~ :: ilE . . r L ^' i j'::l'e °'~.'i ~ ii3i';ii~ ^'i~ eilie!iiiiiiiii iji e i ' 1"j i::iii, in:::i:. ;.. il;,,;i;,i:i'riiiiii:,::i:::r:i:I:::::~* ..' . . , '. ,. ~ :Eii!~i.'i- .iii`§ii o.PE' ,i! Well Name: GUBIK 3 BP01 Depth (MD) 3512 to 3534 ft Location: FOOTHILLS (TVD) 3511 to 3533 ft Operator: ANADARKO Show Report No. 4 Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 7-Mar-08 s Report Delivered To: John Kamm l ~! InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. "! Formation: Sandstone- li ht ra to ra white, salt & e er, ve fine to fine rained, an ular to suban ular, moderate sorted, well to N 9 9 Y 9 Y' PPP rY 9 9 9 ~Ii' ;;~ moderately cemented, calcareous and siliceous cement, no visible porosity, mineral grains, some carbonaceous, quartz, no stain odor fluorescence or cutfluorescence. :.. ~~ ......... . : : ... ~ ' ~ ~ .. a:xr;:n :r: u :m :r ;,:z ss:.::i: ~!::i:::r.:i im ::: u:u.,a.:i i i. ,.a..:..::z.:.. .:..:.!:i:.:..::: .: ! :a:.r . ~ °i° ;~ Depth 3513 ft Gas x Units 476 Mud Chlorides (1000's) na ---------------------------------------------------- Flowline Background Show I Hydrocarbon Ratios C1 C1 C1 - - - C2 C3 C4 C1 - C5 .Ei PPm PPm PPm Hydrocarbon Ratios 1000 0 =` ?' 46347 24221 3 9 22126 . I C1/C2 = 3 . C1 - = i~ 1870 11 6 714 C1/C3 = 159.3 C2 - = 5 i~ ~' t' C3 406 - 254 = 152 C1/C4 = 781.3 E Ij~ C4 82 - 51 = 31 C1/C5 = 24221 NPH j q jiil ;ill C5 1 - 0 = 1 i-------------------------------------------------------------------------------------- Production 00.0 ---------- -- - ---~-~----- _ ------------ ^N ', A l i Oil W N P d ibl H d b G t na ys s x as a er on- ro uc e y rocar ons 2 "" D h 1 i 57 M d Chl id 1000' '' ept 35 5 ft Gas -------------------------------- Fl li B k s) na x Un ts 5 u or es ( ------------------------------------------------------ d Sh Gas A ow ne ac groun ow PPm PPm PPm l Hydrocarbon Ratios 10.0 _ _ - - - ~ - ----- - ~ . :: E` ' I C1 58753 - 22126 = 36627 C1/C2 = 33.3 j ..: ~~ C2 2256 - 1156 = 1100 C1/C3 = 159.9 ~"' ~': 22 Oil iii; 9 C1/C4 = 481.9 ' C3 483 - 254 = ai i ~' °!" C4 127 - 51 = 76 C1/C5 = 36627 sa C5 1 - 0 = 1 . ; ---------- NPH 1 0 ---------------------------------------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons . 3 °io `" Depth 3518 ft Gas x Units 302 Mud Chlorides (1000's) na ------------ -.------------9 --------------------------------------------------- Flowline Back round Show C - C Hydroca 1 C - 2 C rbon Ratio 1 3 s C1 C - - C4 C 1 iii: 5 Ii' PPm PPm PPm ~~ Hydrocarbon Ratios 1000 0 ti ~~ . C1 62661 - 22126 = 40535 C1/C2 = 34.2 1156 = 1185 C1/C3 = 160 2 `x C2 2341 . - . C3 507 - 254 = 253 C1/C4 = 596.1 C4 119 - 51 = 68 C1/C5 = 40535 NPH C5 1 - 0 = 1 ! Production 100.0 ---- --- -r--~ ~~ --------------- r l Oil W r Non-Producible H drocarbons A i G t III; ys y na s x as a e ~ iEiE IEEE ~ % D th 3520 ft G na it 502 M d Chl id 1000' U Gas ep as IIII---------------------------g -- Fl l B k x n u or es ( s) s ------------ ------------------------------------------ d Sh - - roun ow i ow ine ac i:. k! PPm PPm PPm "ti Hydrocarbon Ratios 10.0 _ - - - - _ _ _ •" C1 46685 - 22126 = 24559 C1/C2 = 37.5 ~` Oil C2 1811 - 1156 = 655 C1/C3 = 183.3 Iii; 134 C1/C4 = 663 8 388 254 ~~E` iE . - = C3 37 j ! `I C1/C5 = 24559 E C4 88 - 51 = '"E C5 1 - 0 = 1 :: ,y: ----------- NPH , I ~: ESE----------- ------------------- ------- Production ----------------------------- iiii Analysis x Gas Oil Water Non-Producible Hydrocarbons ,........ Ei~. E 3 ^ :::.:::::r- ::::: :i. :fi~'i~16 i :P . i ~i iiiii 'I:"'~• `"ijE ~ ~ ~..I.ti..i ii iii ~, ~, ..! :. i 1.:.. i:ii:::.:. i" I " iiN E ~.:., ::.3:ri ..!I :.:..:....'; ii:i f r l .ai.. .. ~: I..... I ~I '~~ sperry-sun fijj "'' DRILLING SERVICES ~;~ l~ Show Report ~ , .:. ,k i. ' J, e i , i::' u. a eA':9~ iEja,'~'j j;]ee:::~!ji e, il.: e„ • :'il~~l' ii'Jj ii~ i!eyueijij' y'e{'jj l~ejjee9.:. ~e:i.4. !' '~,~:! I :!:::Ij .:i':1'." Ijjiijl~P,:• :eij! i',i . e'~: i ~ ~ I i, ,~,iij, ~~ ~I!nili5i:i'ia:'S~ :~ Well Name: GUBIK 3 BP01 Depth (MD) 3545 to 3592 ft Location: FOOTHILLS (TVD) 3544 to 3591 ft :i Operator: ANADARKO Show Report No. 5A Report Prepared By: Mike Daigle/ Doug Wilson Daterrime: 7-Mar-08 Report Delivered To: John Kamm InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation :Sandstone- light gray, white, medium gray in part, very fine to fine grain, angular to subangular, moderately to well consolidated, ~j well sorted, mica and mineral fragments, some carbonaceous partings, slightly calcareous, no visible porosity, no stain odor fluorescence ;`( cut fluorescence. :: ::: I ~~ ~ ' Depth 3548 ft Gas ~~---------------------------9 --- Flowline Back rou °i° x Units 700 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show Hydrocarbon~Ratios C1 C1 C1 - - - C2 C3 C4 C1 - C5 iii ppm ppm ppm Hydrocarbon Ratios . C1 63377 - 29325 = 34052 C1/C2 = 30.7 1000.0 C2 2366 - 1257 = 1109 C1/C3 = 176.4 C3 478 - 285 = 193 Ci/C4 = 830.5 j C4 110 - 69 = 41 C1/C5 = 34052 NPH C5 1 - 0 = 1 Production 100.0 ---- --- y-~-~ e!j t Analysis x Gas Oil Water Non-Producible Hydrocarbons ` 2 M Chl i 1000' Depth 3551 ft Gas s) na or x Units 425 ud des ( Gas ~i ' Flowline Background Show ,:` PPm PPm PPm ~~~ Hydrocarbon Ratios 10.0 _ _ _ _ _ ------ _ - ---- ------ _ j .. ':. ''" '~ 44200 - 29325 = 14875 C1/C2 = 29.3 ~ C1 ~' `' C2 1764 - 1257 = 507 C1IC3 = 156.6 Oil C3 380 - 285 = 95 C1/C4 = 991.7 `! C4 84 - 69 = 15 C1/C5 = 14875 C5 1 - 0 = 1 ------- NPH 1 0 ::! kj------------------------------------------------------------------------------- Production ~~ Analysis x Gas Oil Water Non-Producible Hydrocarbons . ~~ 3 Depth 3583 ft Gas x Units 333 Mud Chlorides (1000's) na I`I---------------------------9 --------------------------------------------------------- °i Flowline Back round Show C - C Hydroca 1 C - 2 C rbon Ratios 1 C1 C - - 3 C4 C 1 ,: 5 I PPm PPm PPm Hydrocarbon Ratios 1000 0 o; .l j! . j`" C1 34006 - 29325 = 4681 C1/C2 = 40.4 ~ ~ 1257 = 116 C1/C3 = 126 5 2 1373 !'~~ ! ; . - - C !~~ C3 248 - 285 = -37 C1/C4 = -2340.5 lii !; C4 67 - 69 = -2 C1/C5 = 4681 NPH =i C5 1 - 0 = 1 °!~ Producton 100.0 ---- ---~~-~ - N P d ibl H d b l i Oil W t G on- ro uc y rocar ons ys s x a er e Ana as 4 !~ D h ft G n 326 M d Chl id 1000' U it as .ji j; as ept 3585 :.;- ----- - r: B k a n u or es ( s) x s ---- ----------------------------------- d Sh - - ;; ` .j Flowline roun ow ac ! .: PPm PPm PPm Hydrocarbon Ratios 0.0 ~~~-- ------------- - .. ~ ----------------- ------------ i € ~ 34537 - 29325 = 5212 C1/C2 = 35.2 C1 Oil 1257 = 148 C1/C3 = -306.6 C2 1405 - t ` ~~ C3 268 - 285 = -17 C1/C4 = -274.3 i::: rj:. C4 50 - 69 = -19 C1/C5 = 5212 :,. I~il C5 1 - 0 = 1 ,::: NPH ------------------------------- ----------------------------------------------- .<: Production Analysis x Gas Oil Water Non Producble Hydrocarbons . .. "€.~.. ...... ::r .. 1.0 ::; ,::::::::: .: I . .... hi.i. ~ • .......... Iii ~~ ..I.u I ,. ................:.i. u,:: k I:.: , .!....... ~. :.., i.. , ,:,a,.:.,:s..... :::y :...: u E: lui. -.:. I :"ii! .'.i .:.,.,. :.:r; :'`i`~a'N I , i :,i I ,i. !..!:,.:,..:.,. ...:...........:, ............. j jt jji: i; ;i:: ts" ~.... is i,°. :4.:: i u.;,..:. : iiEi r i : ' I i~ ' ~:'~ :-~! sperry'SUn DRILLING SERVICES Show Re ort P E~.. .: . .. . :: ' ~ :. r .yl, . :~ ;.. : ;i;Ei ': ;i:: i I ~ : . iiii Well Name: GUBIK 3 BP01 Depth (MD) 3608 to 3653 ft ~ry Location: FOOTHILLS (TVD) 3607 to 3652 ft ~~Ii Operator: ANADARKO Show Report No. 6 I!i Illi Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 7-Mar-08 Report Delivered To: John Kamm ili rt . ~ e :. N ~~! InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation :Sandstone- light gray, white in part, some medium gray in part, very fine to medium grain, subangular to subround, moderately ;` sorted, moderately to well cemented in part, some siliceous cement, very slightly calcareous in part, trace visible porosity, tightly cemented j~ :~ in part, quartz, some mgr lithic and mineral fragments, abundant carbonaceous partings and material, no fluorescence, no cut e:. 0 1 /o Depth 3612 ft Gas x Units 297 Mud Chlorides (1000's) na w ::----------------------- ---g --------------------------------------------------------- Flowlme Back round Show :,:::n:::R:::::;1:::, H drocarbo at os y C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 26293 - 20646 = 5647 C1/C2 = 21.5 1 112 263 8 C1/C3 = 102.7 C2 3 3 - 0 = C3 324 - 269 = 55 C1/C4 = 332.2 'I' C4 64 - 47 = 17 C1/C5 = #DIV/0! NPH 'l ~G i! C5 1 - 1 = 0 -Production 100.0 ------~.-~-~-- ----------------- A l i Oil W t N P d ibl H d b G rocar ons na ys s x a er on- ro uc e y as ii 2 ':€ ti D h 3 21 G 1000' U i 613 M d Chl id ;':. ept as 6 ft ' ---------------------------9 --- Fl l B k s) na__--- x n ts u or es ( ------------------------------------------------- d Sh Gas ;,;; ow ow me ac roun Ppm PPm PPm Hydrocarbon Ratios 10.0 _ _ ~ _ -------- - . - - - - ------ -------- _ _ = C1 56119 - 20646 = 35473 C1/C2 = 24.6 t' I~~ C2 2562 - 1120 = 1442 C1/C3 = 124.0 Oil ~iI C3 555 - 269 = 286 C1/C4 = 466.8 R ~' _ iii; C4 123 47 76 C1/C5 = #DIV/0! :-: °' C5 1 1 = 0 ,,, '. ~~ I - ;; Production !il Analysis x Gas Oil Water Non-Producible Hydrocarbons i ~; lii s °i° Depth 3624 ft Gas x Units 1184 Mud Chlorides (1000's) na ,, _ ---------Flowline ----Back pound-"----""show """'----'-"---------------------"-"" FE 9 C C Hydroca 1 C 2 C rbon Ratios 1 C1 C 3 C4 C 1 5 ppm ppm ppm Hydrocarbon Ratios 1000 0 `~ . `s C1 120425 - 20646 = 99779 C1/C2 = 25.4 1120 = 3933 C1/C3 = 140 9 C2 5053 . - ~ll C3 977 - 269 = 708 C1/C4 = 712.7 ~ u il 'ii C4 187 - 47 = 140 C1/C5 = #DIV/0! NPH lll; ~_ _: C5 1 - 1 = 0 :-------------------------------------------------------------------------------------- Production 00.0 --------- _ -~"-~---- _ ~ - : i ,u N n-Prod ible H drocarbons A l i G Oil W t y na ys s x as a er o uc ii' 4 r D th 3627 ft G na d Chl id 1000' U it 731 M Gas ep as II_______________________________ Fl li B k or s) x n s u es ( ____________ __________________________________________ d Sh - ~ - °" i;j ow groun ow ne ac :i: PPm Ppm PPm fill `ii Hydrocarbon Ratios li 0.0 _ - - --------------- ~ _ _ -------- €. E:[ ii i! :;:: .iii it i i ~` ~~~ C1 20646 = 31368 C1/C2 = 29.a 52014 - ", Oil iili C2 2188 - 1120 = 1068 C1/C3 = 185.6 >sj 169 !I'~ C1/C4 = 1363.8 C3 438 - 269 = 23 C1/C5 = 3137 : C4 70 - 47 = :::: - ill C5 11 1 = 10 ------------------------------------- 1 0 ii "i ~~ Production ----------------- ---------- 'll iix Analysis x Gas Oil Water Non Producible Hydrocarbons ~::; ;!: :, . - .iE!. "i iis':.E.sE:: ~a:::;;r:::;!::: ::::6.:.::.31"':=::~;.V'~'::~'; „I I li ii4iiilir:~lliiili... r i:- ti:i:~:iir:ill~i " ~""~ ;i `~ ee sperry'$un '~ ~ DRILLING SERVICES ,~ Show Report 3:'~u~ e~il,.. i ji~iNtl~ FN;C~ . Well Name: GUBIK 3 BP01 Depth (MD) 3768 to 3820 ft Location: FOOTHILLS (TVD) 3766 to 3818 ft Operator: ANADARKO Show Report No. 7 r' ~: Report Prepared By: Mike Daigle/ Doug Wilson Date/Time: 7-Mar-08 jai J:i Report Delivered To: John Kamm 'j „ I ' ~l InterpretatlOn: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- light gray to gray, fine to medium grain, angular to subangular, moderately sorted, moderately to well cemented, no visibly porosity, no stain, odor, fluorescence or cut fluorescence. !;i• j j N ,: i :, "I 1 Depth 3771 ft Gas ---------------------------9 --- Flowline Back rou °i° x Units 400 Mud Chlorides (1000's) na ------------------------------------------------------ nd Show : ~ Hydrocarbon Ratios C1 C1 C1 C1 - - - - C2 C3 C4 C5 II i ;r :.' ppm ppm ppm Hydrocarbon Ratios 1000 0 . C1 39860 - 19904 = 19956 C1/C2 = 31.3 t ti~ C2 1776 - 1138 = 638 C1/C3 = 117.4 .:: !l C3 460 - 290 = 170 C1/C4 = 424.6 fir I C4 116 - 69 = 47 C1/C5 = 19956 NPH !~! C5 1 - 0 = 1 Production 100.0 - -------~--~-~- ~ ' ~i ? Analysis x Gas Oil Water Non-Producible Hydrocarbons 'tl ~a 2 % i ' ~ Depth 3777 ft Gas ~'f _---- - - ---------- ------- --- s) na x Units 516 Mud Chlorides (1000 ____ ----------------------------------- ---- Gas ` g ';:.; Flowline Back round Show :.: ~~ PPm PPm PPm j Hydrocarbon Ratios 0.0 --'-- --------- - - --- _ ::: ,: :.: '° ,r. C1 56687 - 19904 = 36783 C1/C2 = 30.3 C2 2353 - 1138 = 1215 C1/C3 = 110.5 Oil R, C3 623 - 290 = 333 C1/C4 = 408.7 '~ C4 159 - 69 = 90 C1/C5 = 36783 0 = 1 C5 1 ------ N ! a: :: ' I - I!------------------------------ ----------------------------------------------- Production Analysis x Gas Oil Water Non-Producible Hydrocarbons .0 k 3 % Depth 3782 ft Gas x Units 451 Mud Chlorides (1000's) na Flowline Background Show C C Hydrocarbon Ratios 1 C1 C1 C 2 C3 C4 C 1 5 ,.( ppm ppm ppm r` Hydrocarbon Ratios 000 0 j !l ~.: . !~j; - ;f C1 46614 - 19904 - 26710 C1/C2 = 28.9 ~ 1138 = 923 C1/C3 = 105 2 2061 ~ . - C2 C3 544 - 290 = 254 C1/C4 = 365.9 C4 142 - 69 = 73 C1/C5 = 26710 NPH ~;= C5 1 - 0 = 1 N Production 100.0 - -- -~ -~ _- ----- ~, H b N P d ibl d W t r y rocar ons er on- ro uc e ,; Analysis x Gas Oil a ~ ~; i, 4 D h na 1000' 406 M d Chl id U it Gas 3787 ft Gas ept i .--------------------------- -- u or es ( s) x n s ------------------------------------------------------- Sh - - `~` g ow Flowline Back round ~ PPm ppm PPm Hydrocarbon Ratios 0.0 _ . - - _ _ N iiy k iii! C1 40861 - 19904 = 20957 C1/C2 = 28.7 ~ Oil yz ~II' C2 1868 - 1138 = 730 C1/C3 = 99.3 i1i 211 C1/C4 = 332.7 I C3 501 - 290 = rl C4 132 - 69 = 63 C1/C5 = 20957 C5 1 - 0 = 1 ---- NPH ; l;l ill; ,,: ------------------------------- ------------------------------------------- Production Analysis x Gas Od Water Non Producble Hydrocarbons i 03r. .,. ih.'`"~~.'~ ,.:. 1.0 , :~a ~ :..: ili::. psi ' i~s~`~ .!./' .,... ,:::r.~. ::: '' j'j! ,.I", ~`.: ~l ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ HALLIBURTON Sperry Drilling Services BIT RECORD WELL NAME: Gubik 3 LOCATION Foothills, Nortb Slope OPERATOR: Anadarko Petroleum Co. AREA: Umiat CONTRACTOR: Nabors 105E STATE: Alaska BHA # Bit # Bit Type Bit Size Depth IN Depth OUT Footage Bit Hours TFA AVG ROP WOB max RPM max UMP PRES (max) FLOW GPM (max) Bit Grade Remarks 1 1 Hughes EHT 11 12.25 105 494 389 17.00 0.647 22.9 is 60 950 570 na POOH for PIU MWD 2 2 Hughes MXL-1X 12.25 494 1027 533 8.78 0.647 60.7 20 100 1370 550 1-1-NO-A-E-I-NO-TD POOH for 9 718" casing 3 3 Hughes MXL-1 8.75 926 998 72 2.00 0.650 36.0 5 85 1200 400 2-1-CT-M-E-I-ER-BHA Drill Float Collar, Cement 4 4 Hughes DP506X 8.75 998 2628 1630 49.90 0.460 32.7 10 130 3450 507 1-1-WT-AL-X-I-NO-LOG Drill 9 7IS" Csg Shoe, Drill 8 314" hole 5 5 Hughes MXL-1 8.75 2628 2628 0 0.00 0.650 0.0 0-0-NO-A-O-I-NO-BHA Wiper trip for logs 6 5RR Hughes MXL-1 8.75 2628 2628 0 0.00 0.451 0.0 1-1-NO-A-X-I-NO-BHA Wiper trip for logs 7 4RR Hughes DP506X 8.75 2628 4285 1657 45.50 0.460 36.0 t5 135 3700 430 Drill to TD Gubik 3 -Lost in Hole 8 5RR Hughes MXL-1 8.75 2950 3045 95 cmt 0.50 0.451 150.0 Dress off Cement for Sidetrack 9 6 Hughes DP506ZX 8.75 3046 3950 904 40.55 0.460 22.0 ~ 5 135 3000 500 1-1-ER-A-X-I-NO-TD Sidetrack, Drill to TD Gubik 3 BP01 ~ o ~ 1000 2000 t fl. d L C~ G 3000 4000 5000 Drill h2 1/4" Anadarko Gubik 3 &Gubik 3 BP01 Days -vs- Depth Prognosed Actual Set 9 5/ 'casing at 10 7' Dri 18 3/4" 2628' Incr -High gas, BOP Test. 5 10 15 20 25 30 35 40 45 Rig Days Sperry Drilling Services Survey Report Company: Anadarko Date: 3/12/2008 "Time: 09:05:13 Page: 1 Field: Gubik Co-orduiate(A'E) Reference: Well: Gubik 3, True North Site: Gubik 3 Vertical (TVD) Reference: Gubik3: @ 215.0 195+20 @ 0.0 215.0 Well: Gubik 3 Section (VS) Re[erence: Well (O.OON,O.OOE,2 06.55Azi) Wellpath: Gubik 3 P61 Survey CalculatN~n Method: Minimum Curvature llb: ©racle Survey _ -- -- - MD Intl Azim TVD Sys TVD N/S E/~V MapN Mapl? Tuol ft deg deg ft ft ft f4 ft ft 00 0.00 0.00 20 20.00 -195.00 0.00 0.~ 5647249.59 314530.96 TIE LINE . 143.77 0.06 265.00 143.77 -71.23 -0.01 -0.06 5647249.59 314530.90 MWD 230.63 0.48 151.18 230.63 15.63 -0.33 0.07 5647249.26 314531.02 MWD 325.99 0.54 179.13 325.99 110.99 -1.13 0.26 5647248.46 314531.20 MWD 410.41 0.71 185.58 410.40 195.40 -2.05 0.22 5647247.54 314531.13 MWD 499.61 0.57 203.28 499.59 284.59 -3.00 -0.01 5647246.59 314530.88 MWD 588.49 0.56 189.33 588.47 373.47 -3.84 -0.25 5647245.76 314530.62 MWD 676.96 0.53 184.99 676.94 461.94 -4.67 -0.35 5647244.93 314530.49 MWD 860.00 0.68 178.32 859.97 644.97 -6.60 -0.40 5647243.00 314530.40 MWD 919.68 0.70 186.79 919.64 704.64 -7.32 -0.43 5647242.29 314530.35 MWD 1007.00 0.86 208.33 1006.95 791.95 -8.42 -0.81 5647241.19 314529.95 MWD 1027.53 0.91 212.13 1027.48 812.48 -8.70 -0.97 5647240.92 314529.79 MWD 1121.96 1.11 215.23 1121.90 906.90 -10.08 -1.89 5647239.56 314528.83 MWD 1214.77 1.12 211.41 1214.69 999.69 -11.59 -2.89 5647238.08 314527.80 MWD 1313.69 1.19 212.13 1313.59 1098.59 -13.28 -3.94 5647236.41 314526.71 MWD 1411.53 1.23 217.57 1411.41 1196.41 -14.98 -5.12 5647234.74 314525.49 MWD 1458.64 0.98 216.84 1458.51 1243.51 -15.70 -5.67 5647234.03 314524.93 MWD 1508.40 0.99 204.57 1508.26 1293.26 -16.43 -6.10 5647233.31 314524.48 MWD 1604.56 0.92 222.35 1604.41 1389.41 -17.76 -6.97 5647232.01 314523.58 MWD 1698.49 1.11 219.67 1698.32 1483.32 -19.01 -8.05 5647230.77 314522.46 MWD 1796.23 1.33 231.76 1796.04 1581.04 -20.45 -9.55 5647229.38 314520.93 MWD 1892.38 0.66 229.23 1892.18 1677.18 -21.50 -10.85 5647228.36 314519.61 MWD 1937.19 0.31 217.09 1936.98 1721.98 -21.76 -11.11 5647228.10 314519.34 MWD 1989.71 0.25 221.86 1989.50 1774.50 -21.96 -11.28 5647227.90 314519.17 MWD 2086.04 0.38 225.91 2085.83 1870.83 -22.34 -11.65 5647227.53 314518.79 MWD 2180.27 0.14 342.24 2180.06 1965.06 -22.45 -11.91 5647227.43 314518.53 MWD 2276.13 0.14 195.43 2275.92 2060.92 -22.45 -11.97 5647227.43 314518.46 MWD 2372.55 0.22 272.46 2372.34 2157.34 -22.55 -12.19 5647227.33 314518.24 MWD 2470.75 0.14 182.08 2470.54 2255.54 -22.67 -12.38 5647227.23 314518.05 MWD 2566.29 0.28 216.38 2566.08 2351.08 -22.97 -12.52 5647226.92 314517.90 MWD Field: Gubik Sec. 17 T 1 N R 3E UM USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: Gubik 3 Slot Name: 5028720017 Well Position: +N/-S 0.00 ft Northing: 5647249.59 ft Latitude: 69 26 29.170 N +E/-W 0.00 ft Easting : 314530.96 ft Longitude: 151 26 31.450 W Position Uncertainty: 0.00 ft Wellpath: Gubik 3 PB1 Drilled From: Well Ref. Point 502872001770 Tie-on DeptL: 20.00 ft Current Datum: Gubik3: @ 215.0 195+20 @ 03i•ight 215.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1 /29/2008 Declination: 21.72 deg Field Strength: 57468 nT Mag Dip Angle: 80.01 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 20.00 0.00 0.00 206.55 Survey Program for Definitive Wellpath Date: 3/11/2008 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 143.77 4285.00 Gubik 3 PB1 MWD Sperry (143. MWD MWD -Standard Sperry Drilling Services Survey Report Company:. Anadarko- Feld:. Gtabik Site: Gubik 3 Well: Gubik 3 Wellpath: Gubik 3 P6'1 Snrvev MD ft Intl deg Azim deg TVD ft Sys TVD ft 2667. 32 0.56 206. 55 2667. 11 2452. 11 2762. 38 0.67 197 .72 2762 .16 2547. 16 2857. 21 0.69 189 .01 2856 .99 2641. 99 2952. 31 0.84 193 .18 2952 .08 2737. 08 3048. 04 1.05 190 .93 3047 .79 2832. 79 3147 .33 1.15 189 .91 3147 .07 2932. 07 3242 .54 1.21 203 .33 3242 .26 3027. 26 3339 .58 1.24 206 .42 3339 .27 3124. 27 3435 .39 1.32 201 .30 3435 .06 3220. 06 3530 .89 1.14 203 .61 3530 .54 3315. 54 3628 .86 1.17 201 .75 3628 .49 3413 .49 3724 .98 1.30 203 .48 3724 .59 3509 .59 3819 .76 1.46 203 .89 3819 .34 3604 .34 3918 .22 1.44 217 .54 3917 .77 3702 .77 4014 .26 1.31 211 .95 4013 .78 3798 .78 4095 .36 1.48 207 .26 4094 .85 3879 .85 4206 .28 2.31 217 .47 4205 .71 3990 .71 4285 .00 2.31 217 .47 4284 .37 4069 .37 N/S E/W 1VLapN - 1V'Iap[: Tool ft <fh ft ft -23.61 -12.89 5647226.29 314517.52 MWD -24.56 -13.27 5647225.36 314517.12 MWD -25.65 -13.53 5647224.27 314516.83 MWD -26.89 -13.78 5647223.03 314516.56 MWD -28.44 -14.10 5647221.50 314516.19 MWD -30.31 -14.45 5647219.63 314515.81 MWD -32.18 -15.01 5647217.78 314515.20 MWD -34.06 -15.88 5647215.92 314514.28 MWD -36.01 -16.74 5647213.99 314513.38 MWD -37.91 -17.52 5647212.11 314512.55 MWD -39.73 -18.28 5647210.31 314511.75 MWD -41.64 -19.08 5647208.41 314510.90 MWD -43.73 -20.00 5647206.35 314509.94 MWD -45.86 -21.26. 5647204.25 314508.63 MWD -47.75 -22.58 5647202.39 314507.27 MWD -49.47 -23.55 5647200.70 314506.26 MWD -52.51 -25.56 5647197.70 314504.17 MWD -55.03 -27.49 5647195.23 314502.18 MWD Date: 3/12/2008 Time: 09:05:13 Page: 2 Co-ordinate(NE) Reference: Well: Gubik 3, True North Vertical (TVDI Reference: Gubik3: @ 215.0 195+20 C~ 0.0 215.0 Section (VSl Reference: Well (O.OON,O.OOE,206.55Azi) i Surrey Calculation D4ethod: Minimum Curvature Db: Oracle Sperry Drilling Services Survey Report - - Company: Anadarko Date: 3/12/2008 Time: 09:06:04 Page: 1 I Field: Gubik Cyr-ordinate(NE) Reference: Well: Gubik 3, True Nor4~ Sfte: Gubik 3 ~/erti~al (TVll) Reference: Gu bik3: @ 215.0 195+~ @ 0.0 215.0 Well: Gubik 3 Section (VS) Keference: Well (O.OON,O.OOE,2 26.4t9Azi) Wellpath: Gubik 3 Servey Calculation Method: Mi nimum Curvature Db: Oracle Field: Gubik Sec. 17 T 1 N R 3E UM USA Map System:US State Pla ne Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: Gubik 3 Slot Name: 5028720017 WeII Position: +N/-S 0.00 ft Northing: 5647249.59 ft Latitude: 69 26 29.170 N +E/-W 0.00 ft Easting : 314530.96 ft Longitude: 151 26 31.450 W Position Uncertainty: 0.00 ft Wellpath: Gubik 3 Drilled From: Gubik 3 P61 502872001700 Tie-on Depth: 2952.00 ft Current Datum: Gubik3: @ 215.0 195+20 @ Q32ight 215.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/29/2008 Declination: 21.72 deg Field Strength: 57468 nT Mag bip Angle: 80.01 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction fi ft ft deg 20.00 0.00 0.00 226.49 Survey Program for Definitive Wellpath Date: 3/11/2008 Validated: N o Version: 3 Actual From To Survey Toolcode Tool Na~ae ft ft 143.77 2952.31 Gubik 3 PB1 MWD Sperry (143. IsAWD MWD -Standard 3082.95 3950.00 Gubik 3 MWD Sperry (3082.95-39 EaAWD MWD -Standard Survey - _--- - __ MD Incl Azim TVD Sys TVD N/S E/W hlapN D9apE Tool ft deg deg ft ft ft ft ft ft 20.00 0.00 0.00 20.00 -195.00 O.00 0.00 5647249.59 314530.96 TIE LINE 143.77 0.06 265.00 143.77 -71.23 -01.01 -0.06 5647249.59 314530.90 MWD 230.63 0.48 151.18 230.63 15.63 -01_33 0.07 5647249.26 314531.02 MWD 325.99 0.54 179.13 325.99 110.99 -1.13 0.26 5647248.46 314531.20 MWD 410.41 0.71 185.58 410.40 195.40 -2.05 0.22 5647247.54 314531.13 MWD 499.61 0.57 203.28 499.59 284.59 -3.00 -0.01 5647246.59 314530.88 MW® 588.49 0.56 189.33 588.47 373.47 -3,84 -0.25 5647245.76 314530.62 MWD 676.96 0.53 184.99 676.94 461.94 -4.87 -0.36 5647244.93 314530.49 MWD 860.00 0.68 178.32 859.97 644.97 -6.60 -0.40 5647243.00 314530.40 MWD 919.68 0.70 186.79 919.64 704.64 -7.32 -0.43 5647242.29 314530.35 MWD 1007.00 0.86 208.33 1006.95 791.95 -$_42 -0.81 5647241.19 314529.95 MWD 1027.53 0.91 212.13 1027.48 812.48 -8.70 -0.97 5647240.92 314529.79 MWD 1121.96 1.11 215.23 1121.90 906.90 -1(D.08 -1.89 5647239.56 314528.83 MWD 1214.77 1.12 211.41 1214.69 999.69 -11.59 -2.89 5647238.0$ 314527.80 MWD 1313.69 1.19 212.13 1313.59 1098.59 -13.28 -3.94 5647236.41 314526.71 MWD 1411.53 1.23 217.57 1411.41 1196.41 -14.98 -5.12 5647234.74 314525.49 MWD 1458.64 0.98 216.84 1458.51 1243.51 -15.70 -5.67 5647234.03 314524.93 MWD 1508.40 0.99 204.57 1508.26 1293.26 -i6-43 -6.10 5647233.31 314524.48 MWD 1604.56 0.92 222.35 1604.41 1389.41 -1.76 -6.97 5647232.01 314523.58 MWD 1698.49 1.11 219.67 1698.32 1483.32 -191.01 -8.05 5647230.77 314522.46 MWD 1796.23 1.33 231.76 1796.04 1581.04 -20.45 -9.55 5647229.38 314520.93 MWD 1892.38 0.66 229.23 1892.18 1677.18 -21.50 -10.85 5647228.36 314519.61 MWD 1937.19 0.31 217.09 1936.98 1721.98 -21.76 -11.11 5647228.10 314519.34 MWD 1989.71 0.25 221.86 1989.50 1774.50 -2196 -11.28 5647227.90 314519.17 MWD 2086.04 0.38 225.91 2085.83 1870.83 -22.34 -11.65 5647227.53 314518.79 MWD 2180.27 0.14 342.24 2180.06 1965.06 -22.45 -11.91 5647227.43 314518.53 MWD 2276.13 0.14 195.43 2275.92 2060.92 -22:45 -11.97 5647227.43 314518.46 MWD 2372.55 0.22 272.46 2372.34 2157.34 -22..55 -12.19 5647227.33 314518.24 MWD 2470.75 0.14 182.08 2470.54 2255.54 -22.67 -12.38 5647227.23 314518.05 MWD 1 Sperry Drilling Services Survey Report Company: Anadarko Field: Gubik Sites Gubik 3 'Well: Gubik 3 WeUpaths Gubik 3 Survey MD Incl Azim ft deg deg. 2566. 29 0.28 216. 38 2667. 32 0.56 206. 55 2762. 38 0.67 197. 72 2857. 21 0.69 189. 01 2952 .31 0.84 193. 18 3082 .95 1.22 198. 46 3116 .00 2.12 208. 05 3129 .45 2.49 209. 95 3145 .36 2.94 219. 15 3179 .27 3.50 221. 89 3224 .62 3.63 223. 32 3275 .34 3.91 229. 37 3325 .51 4.59 235. 06 3373 .61 4.82 242. 35 3469 .44 4.65 238. 64 3562 .69 4.57 241. 53 3660 .36 4.47 239. 70 3756 .49 4.27 240. 88 3853 .75 4.23 240. 95 3887 .20 4.18 242. 73 3950 .00 4.18 242. 73 -- ___ _ _ _ __ __ l Date: 3/12/2008 Time: 09:06:04 Page: 2 Co-ordinate(NF) Reference: Well: Ctiubik 3, True North Vertical (TVDj Reference: Gubik3: @ 215.0 195+20 @ 0.0 215.0 Section (VS) Reference: Well (O.OON,O.OOE,226.49Azi) Sgrvey Calculation Method: Minimum Curvature llb: Oracle ~TVU S TVD N/S E/W MapN MapE Tool I ys ft ft ft ft ft 2566. 08 2351. 08 -22.97 -12.52 5647226.92 2667. 11 2452. 11 -23.61 -12. 89 5647226.29 2762. 16 2547. 16 -24.56 -13. 27 5647225.36 2856. 99 2641. 99 -25.65 -13. 53 5647224.27 2952. 08 2737. 08 -26.89 -13. 78 5647223.03 3082. 70 2867. 70 -29.14 -14 .43 5647220.80 3115. 73 2900 .73 -30.02 -14 .83 5647219.93 3129. 17 2914 .17 -30.49 -15 .10 5647219.47 3145. 06 2930 .06 -31.11 -15 .53 5647218.86 3178. 92 2963 .92 -32.55 -16 .77 5647217.45 3224. 18 3009 .18 -34.63 -18 .67 5647215.42 3274. 79 3059 .79 -36.92 -21 .09 5647213.18 3324. 82 3109 .82 -39.18 -24 .03 5647210.99 3372. 76 3157 .76 -41.22 -27 .40 5647209.03 3468. 27 3253 .27 -45.11 -34 .28 5647205.30 3561. 21 3346 .21 -48.85 -40 .78 5647201.72 3658. 58 3443 .58 -52.63 -47 .48 5647198.10 3754. 43 3539 .43 -56.26 -53 .84 5647194.62 3851. 42 3636 .42 -59.76 -60 .14 5647191.27 3884. 78 3669 .78 -60.92 -62 .31 5647190.16 3947. 42 3732 .42 -63.02 -66 .37 5647188.16 ft- - 314517.90 M W D 314517.52 MWD 314517.12 MWD 314516.83 MWD 314516.56 M W D 314515.85 MWD 314515.43 MWD 314515.15 MWD 314514.71 MWD 314513.43 MWD 314511.48 MWD 314509.01 MWD 314506.01 MWD 314502.60 MWD 314495.63 MWD 314489.05 MWD 314482.25 MWD 314475.81 MWD 314469.43 M W D 314467.24 MWD 314463.12 MWD z` :y ~~~~ Sec ~ MD Inc z 4zso.oo o.oo Sperry Drilling Services _ - CASINGDETAILS COMPANY DETAILS: Anadarko No TVD MD Name Size q t so.oa eo.oo ts^ is Calculation Method: Minimum Curvature G u bi k-3 2 1000.00 1000.00 9 5/a" 9-5/8 Error System: ISCWSA 3 4249.99 4249.99 7" 7 Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based DDI=0.00 n O O s 0 0 0 rn C O O O Jr a q .~ H ~ ~ ~ ~ ~ ~ ~ SECTION DETAILS ~~... -_.._,.._....,__......._~ .-,.........Rii Azi TVD +N/-S +E/-W DLeg ~TFace VSec Target p o.oo o.oo o.oo o.oo o.oo o.oo o.oo N o.oo a2so.oo o.oo o.oo o.oo o.oo o.oo __. P. WELL DETAII,S: Gubik-3 Ground Level: 195.00 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5647250.00 314.531.00 69°26'29.174N t47°26'31.449W REFERENCE INFORMATION Co-oNinate (N/E) Reference: Well Gubik-3, True Nodh Vertical (TVD) Reference: RKB Cd1215.OOft (20+195) Measuml Depth Reference: RKB @ 215.OOft (20+195) Calculation Method: Minimum Curvature -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 Veeti~~l S~ccinn nt 0.00®(1000 ftlin) -240 -200 -160 -120 -80 -40 0 40 80 120 16U 2UU Z4U Weat(•)/~a~t(~) (100 fUin) ~~~ -~~~ Customer : Anadarko Well : Gubik #3 Field : Gubik Field ---- DRILLING SERVICES Location : AK-MJ-0005551150 Rig : 105-E BHA Report Job # : AK-MJ-0005551160 BHA# 1 BHA# 1 Date In 2/1/2008 MD In (ft) :494 TVD In (ft) :494 Date Out 2/3/2008 MD Out (ft) : 1027 TVD Out(ft): 1027 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32's) TFA (in') Dup Condition 1 12.250 Hughes MXL-1X 5139552 1x13, 3x15 0.647 1-1-NO-A-E-I-NO-TD MOTOR DATA Run # OD (in) MFR Mode( Serial# Bend Nzl (l3Ys) Avg Dif (ps7 Cum Circ Hrs 1 8.000 SSDS SperryDril! 800569 0.78° 82 22.49 COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit -Center # # (in) (in) (in) {Ibs/ft) (irt) Blade (ft) 1 Roller Cone Steel 5139552 ~ 12.250 12.250 P 6-5/8" Reg 1.06 2 8" SperryDrill Lobe 4/5 - 5.3 stg 800569 8.000 ~ 5.000 ~ 12.187 104.39 B 6-518" H90 , 30.84 3.18 3 Integral Blade Stabilizer 419 ~ 8.080 2.300 12.250 1 160.59 B 6-5/8" H90 ~ 4.67 ' 33.95 4 Non-Mag Pressure Sub 751 i i 8.000 i i i 1.700 :: 163.57 B 6-5/8" Reg 2.02 5 8" DGR EWR 162715 i 7.960 ~ 2.250 ' 156.05 B 6-5/8" Reg ~ 23.40 6 8" NUKE 90159816 8.000 2.250 12250 ~ 157.75 B 6-5/8" Reg 37.27 7 8" Puller 190159817 7.880 ( 2.250 i 152.65 B 6-5/8" Reg ! 20.25 8 ~ 8" BAT Sonic 22.18 ~ 7.950 f 2.250 1 155.62 B 6-5/8" Reg I 22.18 9 Non-Mag Float Sub 3939 ~ 7.940 ~ -3.000 ~ 144.66 B 6-518" H90 2.43 10 Integral Blade Stabilizer 10591651 8.000 ~ 2.500 ~ 12.250 154.58 B 6-5/8" H90 7.49 147.45 11 ~ 1x Non-Mag Flex Driil Collar 192420 7.680 2.400 ~ 142.46 , J B 6-5/8" H90 ( 30.96 12 ( 1x Non-Mag Flex Drill Collar 935 ~ 7.530 2.400 ~ 136.35 ~ B 6-518" H90 i 30.72 13 ~ 1 x Non-Mag Flex Drill Collar 1 ! 192415 ~ 7.760 2.400 145.76 1 B 6-518" H90 I! 30.85 14 Daily Mechanical Drilling Jars 17710012 ~ 7.750 2.750 s 140.52 ~ B 4-1/2" IF ~ 34.52 15 23x HWDP I i 5.000 ~ 3.000 ~ j 49.30' B4-1/2" IF ~ 687.84 j j ~ ~ ~ ~ !~ e ~ ~ ~ ~ ~ 966.50 I g ( ~ ~ Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drily String QD(in) Len (ft) WOB (klbs) 10 20 15 Drilling : 8.93 in Air {Total) RPM (rpm) 80 95 87 Reaming : 3.50 in Mud (Total) Flow (gpm) 285 550 469 Circ-Other : 10.06 in Air {Bel Jars) : 0 } SPP (psi) 725 1420 1205 Total : 22.49 in Mud (Bel Jars:: 0 PERFORMANCE In Out Distance(ft) ROP {ft/hr) Build (°/100') Turn (°/100') DLS (°1100') Inclination (deg) 0.58 ~ 0.91 Oriented : 0.00 0 ( I 0.00 Azimuth (deg) 201.93 !~ 212.04 Rotated : 533.00 ~ ~ f 0.54 ~ 0.54 I Tote! : 533.00 ~ 60 ~ 0.06 0.00 i 0.07 COMMENTS Motor bend set @ 0.78 /Rev/Gal = .26 /Planned flow rate = 500 - 650 Torque bit to 28,000 ft/lbs. / 6-5/8 REG torque = 56,000 ft/Ibs. 6-5/8 H-90 torque = 52,000 ft/Ibs. Max Bit weight = 35 K 5, ~~~ _ ~~~ Customer : Anadarko p y W ell : Gubik #3 Fleid : Gubdc Field - G SERV D R I L L) N ICE 5 Location : AK MJ-0005551160 _ Rig : 105-E BHA R@~JOI`t Job # : AK-MJ-0005551160 BHA# 2 BHA# 2 Date In :2/912008 MD In (ft) :1027 TVD In (ft) :1027 Date Out 2/10/2008 MD Out (t~: 1027 TVD Out(ft) : 1027 BIT DATA Bit# OD (in) MFR Style Serial# Nozzles (/32's) TFA (irk) Dull Condition 2 8.750 Hughes MXL-1 5118843 1x13, 3x15 0.647 2-1-CT-M -E-I-ER-BHiA MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum Circ His COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit - Centber # # (in} (in) {in) (tbs/ft) (ft} Blade (tlt} 1 Roller Cone Steel 5118843 8.750 8.750 P 4112" Reg I 0.83 I 2 Boot basket #1 2669395 7.500 P 41/2" Reg ( 4.60 3 Boot basket #2 ; 24510124 6.800 ~ ~ ~ f P 41/2" Reg B 41/2" H90 3.90 2 50 4 Bit Sub /Float ~ ~ . 5 3x Drill collar { 6.750 2.500 ~ ~ 105.00 j B 41/2" H90 !{ 92.73 6 Drilling Jar ~ 16220197 6.250 2.250 ~ 91.01 ~ B 4112" !F I 31.93 7 2x HWDP ~ `( 5.000 3.000 ~ 49.30 ' B 41/2" IF 60.00 8 1x Non-Mag Flex Drill Collar J 10800525 I 6.780 2.875 100.92 ~ B 41/2" IF 31.07 9 , 1x Non-Mag Flex Drilf Collar (10855809 6.780 2.875 100.92 B 41/2" IF ' ~ 30.55 10 { 1x Non-Mag Flex DrilFCollar 10800526 6.550 2.875 92.71 B 41/2" IF 31.07 11 ~ Cross Over Sub ~ ~ 3•~ t { E I f 1 ~ { ~ ~ ~ { ~ ~ ~ ~ ~ I ~ ( ~ ~ 292.18 i j i ~ I {I i ~ i Parameter Min Max Ave Activity Hrs BHA Weig~'ri (Ib) Drill String OD(in) Len(1~} WOB (klbs} Drilling : .0.00 in Air ('total) ~ RPM (rpm) Reaming : 0.00 in Mud (Totaq ~ ~ Flow (gpm) Circ-Other : 2.50 in Air (Bel Jars) : 0 SPP (psi) Total : 2.50 in Mud (Bel Jars' : 0 PERFORMANCE fn Out Distance(ft) ROP (ft/hr) Build (°/100'' Turn (°1100') DLS (°/100') Inclination (deg) ( 0.91 ' 0.91 Oriented Azimuth (deg) ~ 212.04 ! 212.04 Rotated : ; ~ j ! Totaf ; ' I COMMENTS ~p~~~y~~~~ Customer: Anadarko Well :Gubik #3 F ield : Gubik F'reld DRILLING SERVI CE 5 Location : AK-MJ-0005551160 Rig : 105-E BHA Report Job # : AK-MJ-0005551160 BHA# 3 BHA# 3 Date In ~2/10/200E MD In (ft) :1027 TVD In (it) :1027 Date Out 2/2012008 MD Out (ft) : 2628 TVD Out(ft): 2628 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (132'x) TFA (ink DuH Condition 3 8.750 Hughes DP506X 7118400 6x10 0.460 1-1-WT-AL-X-I-NO-LOG MOTOR DATA Run # OD (in) MFR Model Serial# Benxi Nzl (/32's) Avg Oit (psi) Cum C~rc Hrs 2 7.010 SSDS SperryDrill 700205 0.93' ~ 63 154.94 COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit-Center # # (in) (in} (in) (Ibs/ft) (ft) Blade (ft) 1 PDC 7118400 8.750 2.500 8.750 ! 188.20 P 4-1/2" R;eg 0.95 2 6-3/4" SperryDrill Lobe 7/8 - 6.0 stg 700205 7.010 4.753 8.375 ' 71.06 6 4-1/2" IF 25.29 2.53 3 Integral Blade Stabilizer 192463 6.780 2.875 8.313 ~ 100.92 B 4-112" lF 5.62 28.79 4 6-3/4" DGR / EWR 90163660 6.750 1.920 112.09 B 4-1 /2" IF 23.15 5 6-3/4" Neg. Pulser 901636557 6.750 1.920 112,09 6 4-1/2" IF 20.15 6 Integral Blade Stabilizer 10801075 6.770 2.875 8.375 100.55 B 4-1/2" IF 7.00 78.86 7 Non-Mag Float Sub 172605 6.610 2.875 94.82 B 4-1/2" IF 2.49 8 1x Non-Mag Flex Driil Collar 10800526 6.550 2.875 92.71 B 4-1/2" IF 31.07 9 1x Non-Mag Flex Drill Collar 10800525 6.780 2.875 100.92 B 4-1/2" IF 31.07 10 1x Non-Mag Flex Drill Collar 10855809 6.780 2.875 100.92 B 4-1/2" IF 30.55 11 Cross Over Sub 017 6.550 2.875 92.71 B 4-1/2" HI90\ 2.35 12 3x Drill collar 6.750 2.500 105.00 B 4-1 /2" HI90 92.73 13 Drilling Jar 16220197 6.250 2.250 91.01 B 4-1/2" IF 31.93 14 23x HWDP 5.000 3.000 49.30 B 4-1/2" IF 687.84 15 Cross Over Sub 4.000 2.36 y 994.55 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Dri ll String OD(in) Len (ft) WOB (klbs) 3 15 7 Drilling : 49.86 in Air (Total) ` RPM (rpm) 75 80 80 Reaming : 0.00 in Mud (Totatj Fiow (gpm) 285 515 499 Circ-Other :105.09 in Air (Bel Jars) : 27390 SPP (psi) 725 3250 2756 Total :154.94 in Mud (Bel Jars' : 20460 PERFORMANCE to Out Distance(ft) ROP (ft/hr) Build (°/100') Tuna (°/100') DLS (°1100') Inclination (deg) 0.91 0.45 Oriented : 77.00 32 Azimuth (deg) 212.04 208.92 Rotated : 1524.00 32 Total: 1601.00 32 -0.03 0)_00 0.®3 COMMENTS Bit trq. 4 1 /2 REG = 14k Motor bend set @ 0.93 /Rev/Gal = 0.33 4 1/2" IF trq = 32k 4 112" H90 = 28k Drilling Parameters: Flow 400 - 550 GPM RPM 60 - 120 WOB 5 - 30 KLB ~~~~~~~~~ Customer : Anadarko 1Me11 : Gubik #3 Field : Gubik Field DRILL 1 N C9 S E !~ V I C E S Location . AK-MJ-0005551160 Rig : 105-E 6 HA Report Job # : AK-MJ-0005551160 BHA# 4 BHA# 4 Date In 2/20/200E MD In (ft) :2628 TVD In (ft) :2628 Date Out 2/21/2008 MD Out (ft): 2628 TVD Out (ft) : 2628 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32`s) TFA (in2) Dull Condition 4 8.750 hUGHES L86 5107672 3x14 0.451 1-1-N -A -E-1-NO-LOG MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nal (/32's) Avg Dif (psi) Cum Ctrc Hrs COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit -Center # # (in) (in) (in) (Ibs/ft) (ft) Blade (ft) 1 Roller Cone Insert 5107672 8.750 3.000 180.84 P 4-1/2" Reg 0.88 2 Float Sub Nab029 6.750 B 4-1/2" H90 2.51 3 3x Drill collar 6.750 2.500 105.00 B 4-1 /2" H90 92.73 4 Drilling Jar 16220197 6.250 2.250 91.01 B 4-1/2" IF 31.93 5 23x HWDP 5.000 3.000 49.30 B 4-1/2" IF 687.84 6 Cross Over Sub 4.000 B XT39 2.36 818.25 Parameter Min Max Ave WOB (klbs) RPM (rpm) Flow (gpm) SPP (psi) PERFORMANCE In Out Inclination (deg) 0.45 0.45 Azimuth (deg) 208.92 208.92 Activity Hrs BNA Weight (Ib) Drill Drilling : D.00 in Air (Total) Reaming : 0.00 in Mud (Total) Circ-Other : 2.50 in Air (Bel Jars) : 0 Total : 2.50 in Mud (Bel Jars;: 0 Distance(ft) ROP (ft/hr) Build (°/100') Turn (°/100') DLS (°/100') Oriented Rotated Total OD(in) L.en (ft) COMMENTS SpE?I~t~y- SUI"1 DRIL°L.ING SERVICES BHA R@p01"°t Customer : Anadarko Well :Gubik #3 f=ield : Gubik Field Location : AK-MJ-0005551160 Rig : 105-E Job # : AK-MJ-0005551160 BHA# 5 BHA# 5 : Date In :2/21 /2001: MD In (ft) :2628 TVD In (ft) :2628 Date Out 2/22/2008 MD Out (ft) : 2628 TVD Out (ft) : 2628 BIT DATA Bit # OD (in) MFR Style Seriat# Nozzles (/32's) TFA (in') Dull Condition 4rr1 8.750 Hughes MXIBHDX 5107672 3x14 0.451 1-1-N -A -E-I-NO-BHA MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzt (!32's) Avg Dif (pst) Cum Cire Hrs~ COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit -Center # # (in) (in) (in} (Ibslft} (irl~ Blade (ft) 1 Rolier Cone Insert 5107672 8.750 3.000 180.84 P 4-112" Reg 0.88 2 Float Sub Nab029 6.750 B 4-1/2" H90 :2.51 3 3x Drill collar 6.750 2.500 105.00 B 4-1/2" H90 912.73 4 Drilling Jar 16220197 6.250 2.250 91.01 B 4-1/2" IF 31.93 5 23x HWDP 5.000 3.000 49.30 B 4-112" IF 687.84 6 Cross Over Sub 4.000 B X739 2.36 8'f~8.25 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String WOB (klbs) Drilling : 0.00 in Air (Total) RPM (rpm) Reaming : 0.00 in Mud (Total) flow (gpm) Circ-Other : 2.00 in Air (Bel Jars) : 0 SPP (psi) Total : 2.00 in Mud (Bel Jars; : 0 PERFORMANCE fn Out Distance(ftl ROP (ft/hr) Build (°N00°) Turn Inclination (deg) Azimuth (deg) 0.45 208.92 0.45 208.92 Oriented Rotated Total OD(in) Len DLS COMMENTS f For polishing off cement ~~~ _~~ Customer: Anadarko Well : Gubik #3 Field : Gubik Field D R I L. L I N G 5 E R V 1 C E E Location : AK-MJ-0005551160 Rig : 105-E BHA R@p®i't Job # : AK-MJ-0005551160 BHA# 6 BHA# 6 : -Date !n 2/22/200E MD In (ft) :2628 TVD in (ft) :2628 Date Out 2/29!2008 MD Out (ft) : 4286 TVD Out(ft) : 4285 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (032'x) TFA {in2) Dull Condition 3rr1 8.750 Hughes DP506X 7118400 6x10 0.460 MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nal (/32's) Avg Dif {psi) Cum Circ Hrs 3 7.000 SSDS SperryDrill 700162 0.93° 293 57.50 COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit -Center # # (in) (in) (in) (Ibs/ft) (ft) Blade (ft) ~ 1 PDC 7118400 8.750 2.500 8.750 188.20 P 4-1 /2" Reg 0.95 2 6-3/4" SperryDrill Lobe 718 - 6.0 stg 700162 7.000 4.753 8.375 70.69 B 4-1 /2" IF 25.35 3.15 3 Integral Blade Stabilizer 192463 6.780 2.875 8.313 100.92 B 4-1 /2" IF 5.62 28.85 4 6-3/4" DGR / EWR 6.750 1.920 112.09 B 4-1/2" IF 23.77 5 6-314" Neg. Puiser 6.750 1.920 2.500 112.09 B 4-1/2" IF 20.51 6 Integral Blade Stabilizer 10801075 6.770 2.875 8.375 100.55 6 4-1 /2" IF 7.00 79.90 7 Non-Mag Float Sub 172605 6.610 2.875 94.82 B 4-112" IF 2.49 8 1x Non-Mag Flex Drill Collar 10800526 6.550 2.875 92.71 B 4-1/2" IF 31.07 9 1x Non-Mag Flex Drill Collar 10800525 6.780 2.875 100.92 B 4-1/2" IF 31.07 10 1x Non-Mag Flex Drill Collar 10855809 6.780 2.875 100.92 B 4-1/2" IF 30.55 11 Cross Over Sub 017 6.550 2.875 92.71 B 4-1 /2" H90\ 2.35 12 3 x Drill Collars 6.750 2.500 105.23 B 4-1l2" H90 92.73 13 Drilling Jar 16220197 6.250 2.250 91.01 B 4-1/2" IF 31.93 14 23x HWDP 5.000 3.000 49.30 B 4-1/2" IF 687.84 15 Cross Over Sub 4.000 2.500 26.10 B XT 39 2.36 995.59 Parameter Min Max WOB (klbs) 10 30 RPM (rpm) 80 80 Flow (gpm) 435 435 SPP (psi) 3100 3300 PERFORMANCE Ave 20 80 435 3160 Activity Drilling Reaming Circ-0ther Total Hrs BHA Weight (Ib) Driil String 45.51 in Air (Total) 64393 0.00 in Mud (Total) 49966 11.99 in Air (Bei Jars) : 27515 57.50 in Mud (Bel Jars; : 21350 OD(in} Len(ft) In Out Inclination (deg) 0.45 2.31 Azimuth (deg) 208.92 217.14 COMMENTS Gamma = 35.83 Res = 43.56 Directional = 60.02 .29 Revolutions per gallon Distance(ft) ROP (ft/hr) Build (°!100') Tum (°/100') DLS (°/100') Oriented : 0.00 0 0.20 Rotated : 1658.00 36 0.30 0.00 Total: 1658.00 36 0.11 0.00 0.11 -- 5pef~'I'~y®501"1 Customer : Anadarko Well : Gubik #3 Field :Gubik Field D R I L L I N C7 5 E R V I C E 5 Location : AK-MJ-0005551160 Rig : 105-E BHA Repo Job # : AK-MJ-0005551160 BElA# 7 BHA# 7 Date In ;3/3/2008 MD In (ft) :4286 TVD In (ft) :4285 Date Out 3!3/2008 MD Out (ft): 4286 TVD Out(ft): 4285 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32's) TFA (inz) Dull Condition 4rr1 8.750 Hughes MX18HDX 5107672 3x14 0.451 MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum C~c Hrs~ COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit-Center # # (in) (in) (in) (Ibs/ft) (ft) Blade (ft) 1 Roller Cone Insert 5107672 8.750 3.000 180.84 P 4-1/2" Reg 0.88 2 Float Sub Nab029 6.750 B 4-112" H90 2.51 3 3x Drill collar 6.750 2.500 105.00 B 4-1/2" H90 92.56 4 Cross Over Sub 6.600 2.875 94.47 B 4-112" IF 2.30 5 23x HWDP 5.000 3.000 49.30 B 4-1/2" IF 687.84 6 Cross Over Sub 4.000 B XT39 2.36 788.45 I Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill WOB (klbs) Drilling : 0.00 in Air (Totan RPM (rpm) Reaming : 1.50 in Mud (Total) Flow (gpm) Circ-Other : 1.50 in Air (Bel Jars) : 0 SPP (psi) Total : 3.00 in Mud (Bel Jars' : 0 PERFORMANCE In Out Inclination (deg) Azimuth (deg) 2.31 217.14 2.31 217.14 OD(in) ILen(ft) ~ Distance(ft) ROP (ft/hr) Build (°/100') Turn (°l100') DLS (°/'100') Oriented : Rotated Total COMMBNTS ~perr ~ 5un Customer : Anadarko Well :Gubik #3 Sidetrack Field : Gubik Field DRILLING SERVICE 5 Location : AK-MJ-0005551160 Rig :105-E BHA Report .lob # : AK-MJ-0005551160 BHA# 8 BHA# 8 Date In ,3/4/2008 MD In (ft) :3046 TVD In (ft) :3046 Date Cur 3/8/2008 MD Cur (ft) : 3950 TVD Cur(ft) : 3947 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32's) TFA (in') Dull Condition 5 8.750 Hughes HC506ZX 7010617 6x10 0.460 1-1-ER-A -X-I-NO-TD MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum Circe Hrs 4 6.750 SSDS SperryDrill 700025 1.50° 15$ 56.7 COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit - Center # # (in) (in) (in) (Ibs/ft} (ft) Bladle {ft) 1 PDC 7010617 8.750 2.500 8.750 188.20 P 4-1l2" Reg 0.95 2 6-3/4" SperryDrill Lobe 7/8 - 6.0 stg 700025 6.750 4.753 8.437 61.48 ' B 4-1 /2" 1F 25.18 3.05 3 Integral Blade Stabilizer 101125 6.820 2.930 8.500 101.52 B 4-1/2" IF 5.62 2'8.73 4 6-314" DGR / EWR 165515 6.750 1.920 112.09 B 4-1 /2" IF 23.70 5 DM 195265 6.750 1.920 112.09 B 4-112" IF 9.18 6 TM 220316 6.860 1.920 116.09 B 4-1/2" IF 10.04 7 Non-Mag Float Sub 172605 6.610 2.875 94.82 B 4-1 /2" IF 2.49 8 Integral Blade Stabilizer 42973 6.780 2.875 8.500 100.92 B 4-1/2" IF 6.78 >110.87 9 1x Non-Mag Flex Drill Collar 10735095 6.700 2.820 98.87 B 4-1 /2" IF 30.08 10 Non-Mag 1x Flex Drill Collar 6.580 2.875 93.76 B 4-1 /2" IF 30.64 11 1x Non-Mag Flex Drill Collar 10956324 6.800 2.930 100.79 6 4-1/2" IF 31.0$ 12 Drilling Jar 1776050 6.300 2.312 91.93 B 4-1 /2" IF 31.88 13 23x HWDP ` 5.000 3:000 49.30 B 4-1/2" IF 687.84 14 Cross Over Sub ;; 4.000 2:500 26.10 B XT 39 2.36 897.82 Parameter Min Max WOB (klbs) 1 10 RPM (rpm) 60 70 Flow (gpm) : 450 500 SPP (psi) 2300 3050 PERFORMANCE Ave Activity Hrs ' BHA Weight (Ib) Drill 7 Drilling : 40.55 in Air (Total) : 53951 63 Reaming : 2.33 in Mud (Total) ~ 42932 469 Circ-Other : 13.90 in Air (Bel Jars) : 17048 2663 Total : 56.78 in Mud (Bel Jars' :. 13566 In Out Inclination (deg) 1.11 4.18 Azimuth (deg) 197.33 242.73 Lem (ft) Distance(ft) ROP (ftfir) Build (°/100') Turn (°/100') DLS (°I-100') Oriented : 100.00 9 Rotated : 8{04.00 24 Total: 904.00 22 0.34 5.02 0.39 COMMENTS r r~ rr rr rr ,rr r r r^r r rr rr rr r r rr rr r r `~° T Casing Record Sperry Drilling Services Water-based Mud Record Company: Anadarko Well Gubik 3 &Gubik BP01 Rig Nabors 105E Mud Co MI -Swaco Area Foothills - Umiat, Alaska Job No: AK-AM-0005551181 Spud Date 31 Jan 2008 TD Date: Mar 6, 2008 16" CSG 105 ft MD 9 7/8" Csg 1007 ft MD Date Depth ft - MD Wt ppg Vis sec PV YP Ib1100 Gels Ib1100ft` Filt m130m RBOOIRSOOIR2001R1001R61R3 Rheometer Cake 32nds Solids % Wate~ro~i % Sd % Pm pH MBT Pf/Mf Chlor ppm(k) Hard Ca++ Remarks 31-Jan 278 9.60 54 10 36 9/11/11 7.4 56/46/38/32/10/9 3 5 93 0.50 10.5 2.0 0.40/1.30 44.0 160 Drillin 12.25 hole 1-Feb 500 9.70 78 27 39 18/27/43 8.0 93/66/53/39/15/14 3 9 91 0.20 0.60 9.8 15.0 0.50/1.00 47.0 40 Drillin 12.25 hole 2-Feb 780 9.80 75 22 37 18/31/54 7.2 81/59/49/37/19/17 3 10 90 0.20 0.40 9.4 20.0 0.3/0.9 38.0 80 Drillin 12.25 hole 3-Feb 1027 10.60 78 25 36 19/33/63 7.0 86/61/47/35/23/15 3 13 87 0.25 0.20 9.4 22.0 0.40/1.00 39.0 120 WOC 4-Feb 1027 10.70 65 11 32 17/29/47 7.9 56/44/35/37/15/14 3 12 88 0.30 0.40 9.1 25.0 0.3/0.8 36.0 100 WOC 5-Feb 1027 10.70 66 14 27 15/27/45 7.8 55/41/33/27/13/11 3 12 88 0.25 0.40 9.1 25.0 0.25/0.70 35.0 120 Nipple Up 6-Feb 1027 10.70 66 13 27 15/25/44 7.8 53/40/30/26/12/10 3 12 88 0.25 0.50 9.0 25.0 0.3/0.6 36.0 120 Nipple Up 7-Feb 1027 10.70 68 14 29 16/27/47 7.8 57/43/32/27/13/11 3 12 88 0.20 0.40 9.1 25.0 0.3/0.7 36.0 120 Nipple Up 8-Feb 1027 10.70 67 17 24 15/25/46 7.8 56/41/32/26/14/12 3 12 88 0.25 0.35 9.2 25.0 0.3/0.6 36.0 120 Test BOP 9-Feb 1027 11.70 58 22 30 9/11 /13 5.2 74/52/40/36/9/8 2 15 85 0.00 0.00 7.3 0.0 0.0/0.5 45.0 240 Reserve Sample -Test BOP 10-Feb 1027 11.55 54 21 27 8/9/11 5.4 69/48/38/33/8/7 2 15 85 0.00 0.00 7.9 0.0 0.2/0.8 45.0 240 Drill Cement 11-Feb 1100 13.65 55 30 35 12/21/33 6.4 95/65/52/37/11/9 3 23 77 0.00 0.60 10.4 2.0 0.5/1.8 43.0 320 Drillin 8.75" 12-Feb 1508 13.65 56 27 56 16/19/24 5.8 110/83/72/59/19/15 3 23 77 0.10 0.30 9.4 3.0 0.1/1.8 40.0 40 Drillin 8.75" 13-Feb 2150 13.85 51 28 38 13/21/24 5.4 94/66/44/35/15/12 3 24 75.95 0.10 0.30 9.0 7.0 0.2/1.3 38.0 40 Drillin 8.75" 14-Feb 2627 14.00 52 26 39 9/20/30 6.0 91/65/54/39/9/6 1 25 75-tr 0.25 0.20 9.0 7.0 0.1/1.1 33.0 120 Wiper Trip 15-Feb 2627 14.60 57 31 33 10/23/28 5.6 95/64155/38/9/8 1 27 72/1 0.50 0.30 9.4 8.0 0.2/1.3 31.0 120 Wi er Trip 16-Feb 2627 15.40 60 30 38 11/24/32 5.2 98/68/57/40/10/9 2 31 68/1.5 0.25 0.30 9.6 8.0 0.2/1.7 30.0 60 Circ & Cond Mud 17-Feb 2627 15.80 61 36 45 15/32/44 6.0 117/81/66/49/13/11 2 32 66/2 0.25 0.40 9.7 9.0 0.35/1.9 33.0 80 Increase Mud Wt. 18-Feb 2627 16.60 63 36 43 18/43/44 6.8 115/79/65/47/14/12 2 35 32 0.25 0.30 9.2 9.0 0.25/1.6 29.0 60 Circulate 19-Feb 2627 16.60 61 40 40 19/48/49 7.6 120/80/63/44/15/13 2 34 33 0.25 0.30 9.0 9.0 0.30/2.0 30.0 60 Test BOP 20-Feb 2627 16.60 63 37 39 16/45/50 5.8 113/76/62/43/15/12 2 34 64/2 0.25 0.70 9.7 9.0 0.60/2.1 30.0 40 Wireline L in 21-Feb 2627 16.60 62 43 45 18/48/55 6.5 131/88/67/48/13111 2 35 64/2 0.25 0.20 9.5 9.0 0.35/1.7 29.0 60 Wireline L in 22-Feb 2627 16.60 70 35 40 19/49/56 7.8 110/75/61/42!16/15 2 35 64/2 0.25 0.25 9.5 8.0 0.20/1.6 29.0 20 Thaw Kell Hose 23-Feb 2829 16.20 63 28 39 0.15 9.5 .25/1.7 31.0 40 Drillin 8.75" 24-Feb 3788 15.40 52 30 42 0.60 10.0 .55/2.5 33.0 40 Drilling 8.75" 25-Feb 4173 15.00 52 30 42 0.50 10.0 .6/2.6 33.5 20 Drillin 8.75" 26-Feb 4285 14.60 63 24 41 0.40 9.8 .4/2.4 30.0 20 RIH wl Freepoint 27-Feb 4285 14.60 63 24 40 0.40 9.2 .3/2.4 30.5 20 TOOH 28-Feb 4285 14.40 64 27 20 0.20 9.5 .25/2.5 38.0 20 Wash Down to Fish 29-Feb 4285 14.30 55 20 34 0.30 9.4 .2/2.4 37.5 20 CBU 1-Mar 2950 14.40 70 21 39 0.30 9.5 .2/2.2 36.0 20 RIH to to CMT 2-Mar 2950 13.60 70 32 31 0.80 12.1 .8/2.2 36.0 20 Timed Drillin 3-Mar 3105 13.30 56 26 31 1.70 12.2 .5/2.5 29.0 160 Timed Drillin 4-Mar 3330 13.40 54 27 34 11/26/31 5.6 88/61/48/34/10/7 2 23 77/1 0.10 0.80 11.8 6.0 .5/2.4 28.5 160 Drillin 8.75" 5-Mar 3861 13.40 52 27 35 8/16/23 5.6 89/62/50/35/8/6 2 22 77/1 0.20 0.50 11.8 6.0 .3/2.4 33.0 120 Drillin 8.75" 6-Mar 3950 13.60 51 27 32 9/20/27 5.4 86/59/49/37/8/6 2 23 77/1 0.10 0.60 11.8 6.0 .4/2.4 31.0 100 Drillin 8.75" to TD 7-Mar 3950 13.60 51 27 32 9120/27 5.4 86/59/49/37/8/6 2 23 77/1 0.10 0.60 11.8 6.0 .4/2.4 31.0 100 Wireline Lo in 8-Mar 3950 13.60 51 22 30 6/13/20 5.6 74/5?J37/23/7/4 2 23 77/1 0.10 0.90 11.5 7.0 .6/2.1 29.0 120 Cleanout Run 2" Measured Depth COMBINATION MUDLOG t Sperry Drilling Services .. s ~ r z tip- - t ~~ ~ •~. k a t ®, ® ; 5" Measured Depth C®MBINATION MUDLOG Sperry Drilling Services ~,% ~ a } ~ ~ ~v ~ `. ,. ® ® ,. , 5" Measure ®epth Gas Rati Log Sperry Drilling Services °, ~ ' t 2" Measure ®epth Drilling ynamics Sperry Drilling Services i~c ® ~ 2" Measured Depth COMBINATION MUDLOG Sperry Drilling Services ka. ,1 , 4 -:Y 3 ~ ~~ ~ v. ~r ~~~J.:.~ 'k. L~' =S ': , \. =~ ~ ' ~~ 5" Measure ®epth COMBINAT MUDLOG ~: Sperry Drilling Services ~~ '~ .~ ~ - ,• e"~ " y t ~ T ~ ,~ ~~~ ~ g~`-~-' ',~ f~... , ! ~ °~ ~ :: y~ '> ~?,- ~~ a ~ 0 5" Measured ®epth Gas Ratio i.og ~,~ Sperry Drilling services r~ 4 ~ ~ ~ ~'~ ~_' ~ ~ r ~ x ._ ~ ~ y F"~ ~'t'1 ~'k ~ ~ ~~~~ ~~~~ 3 ~~~~~~~3 it a ~ ~~`® 2" Meas r Depth Drilling Dyna ics ST Detail 4 i F ! - '.. Sperry Drilling Services ~~ ~ r ~`; x- ~ ~ -, ~ ~ 4~ '' ~ '~ ~=~ "~ r ~~:~"y ,w .C>~. ~ ~ !w7'_? 4 s?J 4' i...ti ~ a_ rte, ~ f ;- j ~~ Database CD Gubik 3 (50-2~7-20017-00) Gubik3 BP01 (50-27-20017-01 Sperry Drilling Services ,~ ! `J. C - )~ +k f~.1 ~ ~, ~ ~' '~f ~ ~' ~ g tp~:. '~'h`v ~ 't `.{ fiat ~ .' ~ft i '1 __ }~ ~ A. -~ _ . ~~'~ ~ 3 ... 'A ]~ `~ ~~ Digital Logs, EOWR, Cuttings sample Photograp s, Ascii CD Gubik 3 (50-287-20017-00) Gubik3 BP01 (50-287-20017-01 Sperry Drilling Services Sperry Oritling Servioes Mudlogger's Morning Report Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost •:::::. ~:: . :::::. ::. :::::: Report No.: 1 Date: 1 /31 /2008 0000 Midnight Depth 278 Footage Last 24 hrs: 190 Rig Activity: Drill Surface Report For: HeinrichlGoerlich Midnt-3 AM 24 hr Avg 24 hr Max ~ Pump and Flow Data R.O.P. na ft/hr 19 ft/hr ( na ft/hr @ 0 )Pumps 170 spm Flow rate 5z/ gpm `:~`::`# Gas* na units 1 unit: ( 31 units @ 0 ) Pump Capacity 3.14 gps Pump Liner & Strk 6xs in. Sample Quality ~ Good x^ Fair ~ Poor Pump Pres 30o psi Mud Wt In 9.60 ppg Visc 6o secs API felt ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 9.60 ppg \ Ibs/100ft2 Gels PV cP YP pH Sd MBT \ _ _ _ _ _ _ iii Bit No.: 1 Type: x Mill-tooth Bit Size: 12.25" Jets: _ x _x _ TFA: 0.6470 i':•.`•.' Wt On Bit: na RPM: _ _ na Hrs. On Bit: na Total Revs on Bit: Footage for Bit Run 0 Trip Depth: 278 ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Clyst %Cly %Sltst 30 %Sst 70 %Sh Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 160 to 196 31 3 410 196 to 278 2 1 125 to to to to to to to to to to to to 4 hr Recap P/U Bit # 1 DC Jars HWDP and Spud well, Drill to 278' MD. TOOH. Samples consisted of predominately large (10-20 mm) hard angular sandstone fragments for interval 160-220' MD. Some interbedded hard siltstones to 30% seen from 220-278' MD. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane * 10000 units = 100% Gas In Alr ::: Sperry drilling S®rvi Mudlogger's Morning Report Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $2,910 :..::.::. ~::: ~ .:::::. :. .:::::: Report No.: 2 Date: 2/1/2008 0000 Midnight Depth 494 Footage Last 24 hrs: 216 Rig Activity: Upload MWD Report For: HeinrichlGoerlich Current 24 hrAvg 24 hr Max Pump and Flow Data R.O.P. na ft/hr 55 ft/hr ( 82 ft/hr @ 370 ) Pumps 175 spm Flow rate 565 gpm ':`:~': Gas* na units 7 unit: ( 31 units @ 492 ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. Sample Quality ~ Good x^ Fair ~ Poor Pump Pres 490 psi Mud Wt In 9.60 ppg Visc 6o secs API felt ml HTHP ml Mud Wt at Max Gas ppg Mud Wt Out 9.60 ppg PV _cP YP _Ibs/100ft2 Gels _\ _\ _MBT_pH Sd Bit No.: 1 Type: Mill-tooth Bit Size: 12.25" Jets: x x x TFA: 0.6470 Wt On Bit: 5-10 RPM: 85 Hrs. On Bit: 11.4 Total Revs on Bit: Footage for Bit Run 0 Trip Depth: 278 ft Trip Gas: 10 Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 5 %Cly %Sltst 40 %Sst 20 %Sh 35 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft ft ft ft units units units units ppg ppg ppg ppg ft ft ft ft units units units units ppg ppg ppg ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 278 to 360 8 3 779 360 to 450 20 13 884 450 to 470 8 5 215 470 to 494 31 12 837 to to to to to to to to to to 4 hr Recap TOOH Inspect Bit, arrange pipe, TIH, drill 278-490' MD, CBU, TOOH, P/U NB 2, Upload MWD Samples consisted of predominately large (10-20 mm) hard angular sandstone and Siltstone fragments for interval . 280-425' MD. 425' MD to 490' MD Samples consisted of softening shale and crystal tuff. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane '" 10000 units = 100% Gas In Air .......... :::::: •:::::. Customer: ANADARKO Report No.: 3 ~~'~""°~"~~~~ Well: Gubik3 Date: 2/2/2008 Sperry Grilling s®rvices Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 533 Rig: Nabors 105E Rig Activity: Mad Pass Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $2,910 Current 24 hr Avg 24 hr Max ~ Pump and Flow Data # R.O.P. na fUhr 65 ft/hr ( 230 ft/hr @ 812 )Pumps 178 spm Flow rate 570 gpm 3» Gas* 9 units 12 unit: ( 38 units @ 507 )Pump Capacity 3.14 gps `'; Pump Liner & Strk sX9 in. Sample Quality ~ Good x^ Fair ~ Poor Pump Pres 1750 psi Mud Wt In 10.60 ppg Visc 83 secs API felt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 Bit No.: 2 Type: x Htc Bit Size: 12.25" Jets: x _x _TFA: 0.6470 Wt On Bit: 39741 RPM: _ _ 88-105 Hrs. On Bit: 8.9 Total Revs on Bit: Footage for Bit Run 533 Trip Depth: 478 ft Trip Gas: 17 Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm ... Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane 10000 units = 100% Gas In Air <:> :s: a>: .>::<:.:::::<.>:.::::.>:.:::::.::.:> ::.::::::.::::::::::::::::::::::::::::::::::::.~ :. :::::::::.:::::::::::::::::::::::::::::::::::::::::::::::::::::.~::.~: .~.~::. •:::::: :::.~:::::.::::.::~:::::::::::::::::::::::::.......................... ..................:: :. Customer: ANADARKO 4 Report No.: ~~"'~"'~~~"~~~~ Well: Gubik 3 Date: 2/3/2008 '•E '•': Sperry Grilling services Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Run Casing Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $2,910 Current 24 hr Avg 24 hr Max Pump and Flow Data ':'•`: ':':': R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm ~ : Gas* units unit: ( units @ ) Pump Capacity 3.14 gps Pump Liner & Strk 6XS in. ':'•. ':': Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.60 ppg Visc 83 secs API filt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 Bit No.: Type: Bit Size: Jets: x _x _TFA: x _ _ Wt On Bit: RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm ppg Short Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: Tight Spots: to _ Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to to 24 hr Recap La down B.H.A., ri u for casin ,run casin . Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane 10000 units = 100% Gas In Air <':,`:~ •:::::. •:::. ~: 5 Customer: ANADARKO Report No.: ' ~' ~~"'°~"'~' Well: Gubik 3 Date: 2/4/2008 ~' Sp®rry C7riliir~g Services Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Nipple Up BOP Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $3,960 Current 24 hr Avg 24 hr Max Pump and Flow Data `:~ R.O.P. ft/hr fUhr ( ft/hr @ ) Pumps spm Flow rate gpm > ': Gas* units unit: ( units @ ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. `•. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.60 ppg Visc 83 secs API felt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 E Ei Bit No.: Type: x _x _TFA: x Bit Size: Jets: ii i Wt On Bit: RPM: _ _ 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %SSt 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to to 24 hr Recap Finished runnin casin Ri ed u cementin tools, circulate out ast shakers, and cemented as er Ian. Ni le u BOP. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane 10000 units = 100% Gas In Air F~ IJ .::::: .:::::: Customer: ANADARKO s : Report No ' ~~~ ~ ~~~~~ . ~` •` "' "' Well: Gubik 3 Date: 2/5/2008 `•i`•i Sperry Grilling Se:rvio®s Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Nipple Up BOP Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $3,960 Current 24 hr Avg 24 hr Max Pump and Flow Data >: R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm Gases units unit: ( units @ ) Pump Capacity 3.14 gps Pump Liner & Strk 6xs in. # ` << Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.60 ppg Visc s3 secs API felt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 iii Bit No.: Type: Bit Size: Jets: x _ _ x _x _TFA: iii _ Wt On Bit: RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: .ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to 24 hr Recap Ni le u BOP. ? :i Logging Engineer: Doug Wilson !Mike Daigle /Danny Kane * 10000 units = 100% Gas In Air ~, U J J J :::::: ~ :::.. 7 Customer: ANADARKO Report No.: '` ~~'~""'t'"'t~~ Well: Gubik 3 Date: 2/6/2008 <'• Sp®rry Drilling s®rvioes Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Nipple Up BOP Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data i R.O.P. ft/hr fUhr ( ft/hr @ ) Pumps spm Flow rate gpm #'; `:':':': Gas* units unit: ( units @ ) Pump Capacity 3.14 gps ': Pump Liner & Strk sX9 in. i3 Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.60 ppg Visc 83 secs API felt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 Bit No.: Type: x _x _TFA: Bit Size: Jets: x Wt On Bit: RPM: _ _ 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to 24 hr Recap Ni le u BOP. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane 10000 units = 100% Gas In Air •`. ": .......... Customer: ANADARKO Report No.: ~~'~°°°~°~~~"'~~ Well: Gubik 3 Date: 2/7/2008 Sp®rry Oriliing s®rvi~®s Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Nipple Up BOP Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data ':'i'i R.O.P. ft/hr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm '• Gas" units unit: ( units @ ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in.? Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.60 ppg Visc 83 secs API felt 7.0 ml HTHP ml Mud Wt at Max Gas 9.7 ppg Mud Wt Out 10.60 ppg PV 22 cP YP 35 Ibs/100ft2 Gels 17 \ 29 \ 52 MBT 0.3 pH 9.3 Sd 0.25 t No.: Type: Bit Size: t On Bit: RPM: 0 Hrs. On Bit: Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to to eca~ Lay down GAS PEAKS Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot nnninn Fnninccr rlnnn \A/ilcnn / ~Aika flainle / rlannv Kane/.lason Mesh * 10000 units = 100% Gas In Air Jets: _x _ x _x _TFA: Total Revs on Bit: Footage for Bit Run _ Mud Cut ppg Trip CI: ppm _ Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft :::::: ~::::. Customer: ANADARKO 9 Report No.: ` ~' ~°~~"`"t""~~~ Well: Gubik 3 Date: 2/8/2008 Sperry Grilling servic®s Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Test B.O.P. Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data EE E R.O.P. fUhr ft/hr ( ft/hr @ ) Pumps spm Flow rate gpm '• Gas" units unit: ( units @ ) Pump Capacity 3.14 gps # s Pump Liner & Strk sxs in. : Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.70 ppg Visc 67 secs API felt 7.8 ml HTHP ml Mud Wt at Max Gas 10.7 ppg Mud Wt Out 0.00 ppg PV 17 cP YP 24 Ibs/100ft2 Gels 15 \ 25 \ 46 MBT 2.5 pH 9.2 Sd 0.25 Bit No.: Type: Bit Size: Jets: x TFA: x x •'•. •`•` _ _ _ _ Wt On Bit: RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: ppg Short Trip CI: ppm Mud Cut: Tight Spots: to _ Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm MaX Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to to 24 hr Recap La down i e, Test B.O.P. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason MeaE 10000 units = 100% Gas In Air Customer: ANADARKO ..................::: •::::::10:::::: Report No.: `" ~~'~"""t"'°~~ Well: Gubik 3 Date: 2/9/2008 i~:` Sp®rry ~rilting se:rvioas Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: T.I.H. Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data ','; R.O.P. ft/hr fUhr ( ft/hr @ ) Pumps spm Flow rate gpm `` I`~~~•`: Gas* units unit: ( units @ ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. ~>. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres psi Mud Wt In 10.70 ppg Visc 67 secs API felt 7.8 ml HTHP ml Mud Wt at Max Gas 10.7 ppg 00 ppg PV Mud Wt Out 0 17 cP YP 24 Ibs/100ft2 Gels 15 \ 25 \ 46 MBT 2.5 pH 9.2 Sd 0.25 % . .. ;::Bit No.: Type: Bit Size: Jets: x x _x _TFA Wt On Bit: RPM: 0 Hrs. On Bit: Total Revs on Bit: rootage Tar tsit rtun Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ,,, ft units ppg ft _ units ppg ft units ppg [~24 hr Recap Test B.O.P.'s, Trip in hole. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meab 10000 units = 100% Gas In .......... •. :::::: :::::: Customer: ANADARKO Report No.: 1 1 ~~,~~„t...~~t"'t:"~ Well: Gubik 3 Date: 2/10/2008 perry drilling services Area: North Slope Midnight Depth 1027 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Drilling Cement Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 Mud Wt Out 11.65 ppg PV 21 cP YP 25 Ibs/100ft2 Gels 8 \ 10 \ 13 MBT 0.0 pH 7.9 Sd 0.00 ::: Bit No.: Type: _ Wt On Bit: RPM: Trip Depth: Short Trip Depth Tight Spots: .,, Current Lithology: %Sd Bit Size: x Jets: x _x _TFA: 0 Hrs. On Bit: _ _ Total Revs on Bit: Footage for Bit Run ft Trip Gas: Mud Cut ppg Trip CI: ppm ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft %Tuff %Cly %Sltst 20 %Sst 70 %Sh 10 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to _ to to ~~24 hr Recap P.O.O.H., T.I.H. with new B.H.A., Drill cement. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meah 10000 units = 100% Gas In A Customer: ANADARKO Report No.: 12 ~~~~~ Well: Gubik 3 Date: 2/11/2008 Sperry drilling ssr..ioes Area: North Slope Midnight Depth 1278 Lease: Exploration Footage Last 24 hrs: 231' Rig: Nabors 105E Rig Activity: Drilling Ahead Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich ,,, Mudlogger's Morning Report Daily Cost : $4,015 .,, Current 24 hr Avg 24 hr Max Pump and Flow Data iii R.O.P. 0 ft/hr 17.7 ft/hr ( 156 ft/hr @ 1100 ) Pumps 158 spm Flow rate 507 gpm `:iE Gas* 637 units 1000 unit: ( 10100 units @ 1277' ) Pump Capacity 3.14 gps Pump Liner & Strk sX9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2511 psi Mud Wt In 13.60 ppg Visc 55 secs API felt 6.4 ml HTHP ml Mud Wt at Max Gas 13.6 ppg Mud Wt Out 13.60 ppg PV 30 cP YP 35 Ibs/100ft2 Gels 12 \ 21 \ 33 MBT 2.0 pH 10.4 Sd 0.00 Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: `~~ Wt On Bit: RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm ,,, Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 5 %Sst 95 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 1082' to 1089' 6491 3000 273151 39408 27632 6366 17 1118' to 1136' 8930 4000 296425 72454 26976 7977 9 1271 to 1278 10100 6000 342585 77278 19794 3608 28 to to to to to to to to to to to ]24 hr RecaF Drilling from 1047' to 1 Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meab 10000 units = 100% Gas In Air <:<; Sp®rry Grilling Services Mudlogger's Morning Report Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 •::::::. ':: . :::: ::.~ ::. : ::::::. Report No.: 1 3 Date: 2/12/2008 Midnight Depth 1690' Footage Last 24 hrs: 412' Rig Activity: Drilling Ahead Report For: HeinrichlGoerlich Current 24 hr Avg 24 hr Max Pump and Flow Data ~~`• R.O.P. 20.4 ft/hr 17.1 ft/hr ( 156 ft/hr @ 1100 ) Pumps 160 spm Flow rate 510 gpm #` Gas* 875 units 800 unit: ( 10034 units @ 1600' ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. s% Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2777 psi . Mud Wt In 13.60 ppg Visc 56 secs API felt 5.8 ml HTHP ml Mud Wt at Max Gas 13.5 ppg Mud Wt Out 13.60 ppg PV 27 cP YP 56 Ibs/100ft2 Gels 16 \ 19 \ 24 MBT 3.0 pH 9.4 Sd 0.10 % Current Lithology: %Sd %Tuff %Cly %SItSt 5 %Sst 95 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 1278' to 1296' 9436 6000 318532 25262 4765 692 26 1315' to 1331' 10034 6000 332363 7278 1963 5958 43 1340' to 1345' 6850 5000 255893 20505 5045 808 226 1477' to 1494' 8590 8400 335978 13173 2180 637 67 1587' to 1642' 10035 4500 927649 32278 5577 1117 433 to to to to to to to to to ':;~24 hr Recap Drilling from 1278' to Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meab '" 10000 units = 100% Gas In A Customer: ANADARKO Report No.: :•::::14:::::: ..................::: `" ~"~~""~"'~~~ Well: Gubik 3 Date: 2/13/2008 ~ii Sp®rry ~rilling^we:rvioes Area: North Slope Midnight Depth 2150' Lease: Exploration Footage Last 24 hrs: 460' Rig: Nabors 105E Rig Activity: Drilling Ahead Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Mudlogger's Morning Report Daily Cost : $4,015 ... Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 33.5 ft/hr 19.1 fUhr ( 246 ft/hr @ 2002 ) Pumps 148 spm Flow rate 476 gpm z':' »> Gas* 486 units 600 unit: ( 9337 units @ 1700' ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in.i<'• ': Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2800 psi Mud Wt In 13.85 ppg Visc 51 secs API felt 5.4 ml HTHP ml Mud Wt at Max Gas 13.6 ppg Mud Wt Out 14.00 ppg PV 28 cP YP 38 Ibs/100ft2 Gels 13 \ 21 \ 24 MBT 7.0 pH 9.0 Sd 0.10 <i Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: Wt On Bit: RPM: Hrs. On Bit: 19.0 Total Revs on Bit: Footage for Bit Run 1126' Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ... Tight Spots: to _ Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff %Cly %Sltst 5 %Sst 95 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 1662' to 1675' 3359 2500 149433 7753 2083 555 60 1698' to 1763' 9337 4200 826247 57887 20073 3941 725 1898' to 1907' 4208 3000 348012 14831 4230 786 65 1939' to 1957' 3853 1500 205751 10503 3207 546 18 2052' to 2052' 2401 2401 33255 1972 505 87 2 to to to to to to to to to hr Recap Drilling from 1690' to 2150' ', Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meab 10000 units = 1 UU% Vas In Hir ::~ Sp®rry Drilling Services Mudlogger's Morning Report .... ~~~~~ ..... Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 15 Date: 2/14/2008 Midnight Depth 2628' Footage Last 24 hrs: 478' Rig Activity: Circulating Report For: HeinrichlGoerlich ``~ Current 24 hr Avg 24 hr Max ~ Pump and Flow Data ': R.O.P. N/A fUhr 19.9 ft/hr ( 174 ft/hr @ 2628' )Pumps 148 spm Flow rate 476 gpm Gas* 326 units 561 unit: ( 2856 units @ 2628' )Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2700 psi Mud Wt In 14.00 ppg Visc 52 secs API felt 6.0 ml HTHP ml Mud Wt at Max Gas 13.7 ppg Mud Wt Out 14.20 ppg PV 26 cP YP 39 Ibs/100ft2 Gels 9 \ 20 \ 30 MBT 7.0 pH 9.0 Sd 0.25 No.: Type: Bit Size: Jets: _x _ x _x _TFA: On Bit: RPM: Hrs. On Bit: 27.6 Total Revs on Bit: Footage for Bit Run 1601' Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth 2628' ft Short Trip Gas: 7669 Mud Cut: N/A ppg Short Trip CI: 35000 ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 2242' to 2242' 1919 1919 56102 3226 848 159 0 2339' to 2339' 2856 2856 61428 3154 8122 152 0 2437' to 2450' 2673 1500 147017 7583 1782 299 0 2533' to 2533' 2008 2008 60182 3429 865 155 0 to to to to to to to to to to '~~24 hr Recap Drilling from 2150' to 2628', short trip, increase mud weight, circulate `•.~ Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meab 10000 units = 100% Gas In Airl~~`•.`'•. ..................::: ::::::s~ :.::. ~~ 1 Customer: ANADARKO Report No.: ~'' ~'~""'~"°~~~~ Well: Gubik 3 Date: 2/15/2008 Sperry ~riliing servioes Area: North Slope Midnight Depth 2628' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Short Trip Mudlogger's Morning Report Job No.: AK-AM-5551160 Report For: HeinrichlGoerlich Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A )Pumps N/A spm Flow rate N/A gpm Gas* N/A units 561 unit: ( 10036 units @ 2628' )Pump Capacity 3.14 gps `:':3 Pump Liner & Strk sXS in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres N/A psi Mud Wt In 14.60 ppg Visc 57 secs API felt 5.8 ml HTHP ml Mud Wt at Max Gas 13.7 ppg Mud Wt Out 14.60 ppg PV 28 cP YP 37 Ibs/100ft2 Gels 9 \ 21 \ 26 MBT 8.0 pH 9.4 Sd 0.50 s# Bit No.: Type: Bit Size: Jets: _x _ x _x _ TFA: Wt On Bit: RPM: Hrs. On Bit: 27.6 Total Revs on Bit: Footage for Bit Run 1601' Trip Depth: ft Trip Gas: Mud Cut ppg Trip CI: ppm Short Trip Depth 2628' ft Short Trip Gas: 10036 Mud Cut: _ppg Short Trip CI: 35000 ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to to to to 24 hr Recap Circulate, Short tri to shoe,T.I.H., at 1280' T.I.H. dis lace mud as to 400u, sta ed at 400u avera e, at 1951' as inc. to 850u av .until breakin circulation at 2524', at 350 stks circulation as began in inc. from 850u, b 730 stks gas inc. to 10000u "gas detector saturated", (MW 14.4ppg with mud cut of 13.7ppg)circulating until 1580 stks, gas at 10000u `: began to dec., at 3010 stks gas back to background of 260u., Circulate while inc. mud weight to 14.6ppg Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meah * 10000 units = 100% Gas In Air `•.>`•.i Sperry Oriliing Service: Mudlogger's Morning Report Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 Report No.: 17 Date: 2/16/2008 Midnight Depth 2628' Footage Last 24 hrs: N/A Rig Activity: Circulating Report For: Heinrich\ Salariol Wesl Current 24 hr Avg 24 hr Max Pump and Flow Data >~ R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A ) Pumps 148 spm Flow rate 400 gpm Gas* 40 units 200 unit: ( 7320 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 6X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2246 psi Mud Wt In 15.00 ppg Visc 58 secs API felt 6.4 ml HTHP ml Mud Wt at Max Gas 12.9 ppg Mud Wt Out 15.40 ppg PV 29 cP YP 38 Ibs/100ft2 Gels 10 \ 23 \ 30 MBT 8.0 pH 9.2 Sd 0.25 Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to ::: to ............... .... .rr•,:::::::...............r................ :::::::::.,•:.:~::::::::...:.. .:.. •:;•f~;:•::•::•::~ :•::• ........ .. ,......... s.::::::::.v:.... : r•::::.... ~ ~ •::.,•::::::::::,,....: ,•.,••:::::::::: .... . ~•:::,..::::.. ::::::::::::.,•::::::::::.::. .f. ~. 24 hr Recap: Circulate, Short tri to shoe, Monitor well-2hrs, TIH to 2523' av as 600u dis lacin~~-14.6 mud ,CBU wash to btm, Gas incr to 7320u at 1113 stks, slow um s 30s m-90 g m as dro to 3125u, incr s m to 45-120 g m gas incr to 4966u, gas begin decr at 1350 stks, gas to 120u backround by 4201 stks, gas at BU 1023u, circ and incr MW to 15.0 ppg, TOH to 991'- fill hole/5 stds, monitor well-2.5 hrs, TIH to 2520' (gas incr f/ 116u to 716u by 1756' displacing 15.0 ppg mud )( 1100 u bubble at 1373' TIH displace) ,gas avg 700u f/ 1756'to 2520' displacing 15.0 ppg mud, (1250u bubble at 2138' TIH displace, 980u bubble at 2233' TIH displace ), CBU- 90spm/240 gpm gas began to increase at 276 stks increased to maximum of 4690u at 1125 stks. (pump rate decr f/ 240 gpm to 81 gpm at 1105 stks ), at 4500 stks gas dec. to background of 40u. Circulate while raising mud weight to 15.4ppg Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meabon 10000 Urllts = 100% Gas In Alr t~~~tw~~f~~~ Sp®rry Grilling S®rvio®s Mudlogger's Morning Report Customer :.::.:: .::::::ANADARKO:.::.~ ~.: :,:~:•~:Report •No.:': ~ :::. .:...,1,9,,...: Well: Gubik 3 Date: 2/18/2008 Area: North Slope Midnight Depth 2628' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Circulating Job No.: AK-AM-5551160 Report For: Heinrich\ Salario\ Wesi Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data '~`:~' R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas" 22 units 100 unit: ( 6998 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 16.60 ppg Visc 63 secs API fill 6.8 ml HTHP ml Mud Wt at Max Gas N/A ppg Mud Wt Out 16.60 ppg PV 36 cP YP 43 Ibs/100ft2 Gels 17 \ 41 \ 41 MBT 9_0 pH 9.2 Sd 0.25 Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: •.`•• Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: 2628 ft Trip Gas: 6998 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth to to to to to to to to to to to ::. :.:• ::~:~: ~ :. s: • : .: . ,. . : : : ,: ::,. 24 hr Recap: Circulate & ~ ::.`: 16.6oaa. Gas in units Max Average ht up mud to 16.2ppa. Short trip. Peak qas of 6998u. Circulate & weight up mud to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/ Jason Meabon 10000 units = 100% Gas In Air ::: Sperry Oriliing Services Mudlogger's Morning Report Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 :.::::.::Report~No.:~: :::: •::::::.20.~::::. Date: 2/19/2008 Midnight Depth 2628' Footage Last 24 hrs: N/A Rig Activity: Testing BOP Report For: Heinrich\ Salariol West Current 24 hr Avg 24 hr Max Pump and Flow Data f<'>•. R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* 0 units 100 unit: ( 7418 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 0 psi Mud Wt In 16.60 ppg Visc 63 secs API felt 6.8 ml HTHP ml Mud Wt at Max Gas N/A ppg Mud Wt Out 16.60 ppg PV 36 cP YP 43 Ibs/100ft2 Gels 17 \ 41 \ 41 MBT 9.0 pH 9.2 Sd 0.25 :;:Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: :: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: 2628 ft Trip Gas: 7418 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to ... ::: to ........ .....::::................::::.....................::: ............:N • •;::::::::.:......:: •:.. ... :::,:•:: .....-----~--x-.......... .:: ....... ............ :.:...............:::.:::::::::::... ~........... •::::::::... ~ :::::...... .... ...: :.:.: .........:....: .........:........,......ff.......:. ..r.............:..: .........f:............:::::• .... ~•...,•::.::::::.:::... :...., ..:::.,:.::::.::::::::::::.•::: t.::::.t . sif+.':: .:::.: :.: ......:~~i ......:. sir...::::::......:.:...::.. }. ;':'i .....•k ...... 24 hr Recap: Circulate & wei ht u mud to 16.6 .Short tri ed with eak as of 7418u at 1042 strokes. Circulate & at bottom then full tri out. Testin BOP. Logging Engineer: Doug Wilson !Mike Daigle /Danny Kane/Jason Meabon 10000 units = 100% Gas In Alr ':#' •::.~:. :::::• Customer: ANADARKO Report No.: 21 '•`'• ` ~~""'t"'~t"`~~ Well: Gubik 3 Date: 2/20/2008 i Sperry ~riliing Servioes Area: North Slope Midnight Depth 2628' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Wireline Job No.: AK-AM-5551160 Report For: Heinrich\Salario\Wesi Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data € R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* 0 units 100 unit: ( 8200 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. ~`:•`~ Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 0 psi Mud Wt In 16.60 ppg Visc 63 secs API felt 5.8 ml HTHP ml Mud Wt at Max Gas N/A ppg Mud Wt Out 16.60 ppg PV 37 cP YP 39 Ibs/100ft2 Gels 16 \ 45 \ 50 MBT 9.0 pH 9.7 Sd 0.25 % ::;.;.Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: '•i'•i Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: 2628 ft Trip Gas: 8200 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth Gas in units Max Average to to to to to to to to to to to ::,..{~,~,//iii:::,,:::: ~;;:: ~:;•rx>.::>:<::+?J:i3,':~:~:~:~:~::;.~.~~.."'j,'l/:>:::t:,///~ 24.hr Recap: Trip in hole, circulate, pull out of ho. GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot R/U Baker wireline, run wireline. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meabon '` 10000 units = 100% Gas In A .~~..~ t.,,~"t'" Sperry Oriliir-g Service: Mudlogger's Morning Report .'." ...~.. .,..., ..~ ~ ,..~~ ...... ~~ ..... Customer: ANADARKO No.: Report 22 Well: Gubik 3 Date: 2/21/2008 Area: North Slope Midnight Depth 2628' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Wireline Job No.: AK-AM-5551160 Report For: Heinrich\ Salario\ Wesi Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr 0 ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm iEE Gas" 0 units 100 unit: ( 3400 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in.z Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 0 psi Mud Wt In 16.60 ppg Visc 63 secs API filt 5.8 ml HTHP ml Mud Wt at Max Gas N/A ppg .. Mud Wt Out 16.60 ppg PV 37 cP YP 39 Ibs/100ft2 Gels 16 \ 45 \ 50 MBT 9.0 pH 9.7 Sd 0.25 % Current Lithology: %Sd %Tuff 10 %Cly Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg Depth to to to to to to to to to to to hr Recap: Trip in hole, c %Sltst 50 %Sst 10 %$h 30 ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot II out of hole, run wireline. Gas in units Max Average Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/Jason Meabon 10000 units = 100% Gas In Air :::; t~~.~tw~~t~ Sp®rry i~rilling S®rvice: Mudlogger's Morning Report ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 •:::::. ':::::. . .:::::. :::::. No.: Report 23 Date: 2/22/2008 Midnight Depth 2628' Footage Last 24 hrs: N/A Rig Activity: Thaw Top Drive Report For: Heinrich\ Salario\ Wesl Current 24 hr Avg 24 hr Max Pump and Flow Data z R.O.P. N/A ft/hr 0 fUhr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm >< Gas* 0 units 100 unit: ( 4200 units @ 2628' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 16.60 ppg Visc 7o secs API felt 7.8 ml HTHP ml Mud Wt at Max Gas N/A ppg Mud Wt Out 16.60 ppg PV 35 cP YP 40 Ibs/100ft2 Gels 19 \ 49 \ 56 MBT 8.0 pH 9.5 Sd 0.25 Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: ~~ Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: 2628' ft Trip Gas: 4200 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth Gas in units M8X Average to to to to to to to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot to to to ... to ::: ::: , ::: ::::. .... >` 24 hr.Recap: Wireline, R/D Wireline, T.I.H. to 1277', Circula bottoms up, P.O.O.H. to shoe, Thaw top drive. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/ Nick Douck " 10000 units = 100% Gas In Alr ~~,L.,t...t ~ ~.,.t"'~"'~ Sperry drilling S®rvioes Mudlogger's Morning Report Customer: ANADARKO Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $4,015 ~:: :.;:.>:.;: • :::::: ::. •:::::. No.: Report 24 Date: 2/23/2008 Midnight Depth 2830' Footage Last 24 hrs: 202' Rig Activity: Drilling Ahead Report For: Heinrich\ Salario\ Wesi Current 24 hr Avg 24 hr Max Pump and Flow Data '`:`:~ R.O.P. 6.2 ft/hr 8.4 fUhr ( 133 ft/hr @ 2805' ) Pumps 0 spm Flow rate 0 gpm Gas" 44 units 60 unit: ( 151 units @ 2813' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 16.00 ppg Visc 63 secs API felt 6.8 ml HTHP ml Mud Wt at Max Gas 16.6 ppg Mud Wt Out 16.00 ppg PV 28 cP YP 39 Ibs/100ft2 Gels 22 \ 50 \ 53 MBT 7.0 pH 9.5 Sd 0.25 EEE Bit No.: Type: Bit Size: Jets: _x _ x _x _TFA: ~':~#E Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: 2628' ft Trip Gas: 3597 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd %Tuff 10 %Cly %Sltst 50 %Sst 10 %Sh 30 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to ... ::: to ... :.:f~ .r::•::•::•::•::•::•::•:;;~:r:~:~.:: ...f . . f......~..:~::~•::~:~:~:~ ~•.f•: ~•:::::..::,::,.. ..r . ...fr•:::,,,: •~ . . f........ . <'>': 24 hr Recap: Thaw top drive, T.I.H., Circ bottoms up, Drill ahead. Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/ Nick Douck * 10000 units = 100% Gas In A :::::. •:::::. Customer: ANADARKO Report No.: 25 ~I" ~'~"'"t "t~~ Well: Gubik 3 Date: 2/24/2008 :~: Sperry Grilling S®rvicgs Area: North Slope Midnight Depth 3850' Lease: Exploration Footage Last 24 hrs: 1024' Rig: Nabors 105E Rig Activity: Drilling Ahead Job No.: AK-AM-5551160 Report For: Heinrich\Salario\Wesi .._ Mudlogger's Morning Report Daily Cost : $4,015 , Current 24 hr Avg 24 hr Max I Pump and Flow Data R.O.P. 63.7 ft/hr 42.6 ft/hr ( 498 ft/hr @ 3849' )Pumps 156 spm Flow rate 422 gpm !# Gas* 114 units 160 unit: ( 5259 units @ 3832' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. €s Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 3277 psi Mud Wt In 15.40 ppg Visc 52 secs API felt 5.8 ml HTHP ml Mud Wt at Max Gas 15.4 ppg Mud Wt Out 15.40 ppg PV 30 cP YP 42 Ibs/100ft2 Gels 31 \ 53 \ 60 MBT 9.0 pH 10.0 Sd 0.25 Bit No.: 3RR Type: Bit Size: Jets: _ x x x TFA: ?~]Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd 0 %Tuff 0 %Cly 5 %Sltst 5 %Sst 90 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot 3080 to 3170 622 130 70286 1576 323 97 20 3200 to 3280 707 200 80664 1886 410 121 26 3480 to 3545 2437 1200 229300 5222 526 98 12 3545 to 3654 1831 1250 195302 4109 842 82 9 3765 to 3810 538 345 61028 1884 443 140 41 to to to to to ... ... to ... .:::. :•~:k~:..... .., . •::::. '• 24 hr Recap: Drilling from 2830' to 3850' Gas bubbles 5259u -3086' MD, 5254u-3143' MD, 5006u-3206' MD, 5252u- 3210' MD, 5256u- 3239' MD, 5010u-3237' MD 4171u-3768' MD, 5253u-3893' MD '~~Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/ Nick Douck "` 10000 units = 100% Gas In A .......................................::: Customer: ANADARKO Report No.: 27 ~~~~ Well: Gubik 3 Date: 2/26/2008 ;: sp®rry Grilling s®rvi~®~ Area: North Slope Midnight Depth 4285' Lease: Exploration Footage Last 24 hrs: 110' Rig: Nabors 105E Rig Activity: Work Stuck Pipe Job No.: AK-AM-5551160 Report For: Heinrich\Salario\Wes1 .. . Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr 15 ft/hr ( 45 ft/hr @ 4224' ) Pumps 0 spm Flow rate 0 gpm Gas" N/A units 100 unit: ( 212 units @ 4215' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. '•. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 15.00 ppg Visc 52 secs API felt 5.8 ml HTHP ml Mud Wt at Max Gas 15.0 ppg Mud Wt Out 15.00 ppg PV 30 cP YP 42 Ibs/100ft2 Gels 31 \ 53 \ 60 MBT 9.0 pH 10.0 Sd 0.25 Current Lithology: %Sd 0 %Tuff 0 %Cly 40 %Sltst 50 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to hr Recap: Drilling from 4172' to Max Circ. Gas on back ream 1~ P.O.O.H., Stuck at 3743', Work Stuck Gas 100u Logging Engineer: Doug Wilson /Mike Daigle /Danny Kane/ Nick Douck * 10000 units = 100% Gas In Alr ::: ..................:::. Customer: ANADARKO Report No.: 2 ~°~'~""~`°~~~ Well: Gubik 3 Date: 2/27/2008 ~:~: Sperry drilling Sarvioes Area: North Slope Midnight Depth 4285' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Work Stuck Pipe Job No.: AK-AM-5551160 Report For: Heinrich\ Salario\ Wesi :., Mudlogger's Morning Report Daily Cost : $4,015 ... Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm # Gas* N/A units N/A unit: ( N/A units @ N/A ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. '>< Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 0 psi Mud Wt In 15.00 ppg Visc 52 secs API filt 5.8 ml HTHP ml Mud Wt at Max Gas 15.0 ppg Mud Wt Out 15.00 ppg PV 30 cP YP 42 Ibs/100ft2 Gels 31 \ 53 \ 60 MBT 9.0 pH 10.0 Sd 0.25 •`.~Bit No.: 3RR Type: Bit Size: Jets: _x _ x _x _TFA: <'•: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd 0 %Tuff 0 %Cly 40 %Sltst 50 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm MaX Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to .:.. ..:. to ::., :::.:<:- ::. ::::::::::::::::::::::: ....::::::. ::::::::::::::::::::::,:s ..f~ :. .,.~,.. ::: ~...• 24 hr Recap: Work stuck pipe, run backoff charge, backoff ,, CBU max gas 1028u, bubble 5000u, losses at 80% at 30gpm. Logging Engineer: Doug Wilson /Mike Daigle 10000 units = 100% Gas In Air :: Customer: ANADARKO Report No.: ~~~"'t"'"~~~~ Well: Gubik3 Date: 2/28/2008 Sperry Drilling S~rvicas Area: North Slope Midnight Depth 4285' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: T.I.H. with Fish Job No.: AK-AM-5551160 Report For: Heinrich\ Salariol Wesl Mudlogger's Morning Report Daily Cost : $4,015 Current 24 hr Avg 24 hr Max Pump and Flow Data ~' ~ R.O.P. N/A ft/hr N/A ft/hr ( N/A ftlhr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* N/A units N/A unit: ( N/A units @ N/A ) Pump Capacity 3.14 gps ? : Pump Liner & Strk 5.5X9 in.ii i Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 14.70 ppg Visc 64 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas 14.7 ppg Mud Wt Out 14.70 ppg PV 24 cP YP 40 Ibs/100ft2 Gels 39 \ 54 \ 59 MBT 8.0 pH 9.2 Sd 0.25 E~> # Bit No.: 3RR Type: Bit Size: Jets: x _x _ TFA: x _ _ Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd 0 %Tuff 0 %Cly 40 %Sltst 50 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft -units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to .. : : . :: :: to .;: .. •: . .. .. : : : . ......: •::::::: ••:::•:::•::•::•: •:::: •: •::::: f ..., •::: •::•::::::•:::••.....~• ...:.. • ... , ... .......................... •:::... . .,.:.....::..: r ...............:.:::::::::~..~.., ~/ ~ :: ...... :::::::::::: v ........ ..f rir r :::~++•i:•i'ir.; •:.•:..•.•.•.•.•.•.•Yrr .xf+x . ............r •::::: x::::: x.:•::~•i:•:, •:::: •~....". r..:8:• ~..•.••.•... s rr•:::..v+•r.. :: +:'.r •:: ...::.v. ivr:::;; .{.::.:: rY v ...r rtw:•::•r •'•'•'•.•.•i.•.... •x r.r r + +r.?•'r'::::....r ............. n...... .::•::•: x r r::::::• •.•::::;:{riii::•::i?•i:•:::{...... :: .•.•.+.•.•.. ~I:+. ~.1 ~...... }...........v .:::... f n ... ..........::::....... rf A..r . .fi~ ..............r.............~.+.j+/,~.•'r:'i.~rr:::::::rr.... rr. •::i •ii........ri.:. . r:: 'Nt. ... rr~J:{?:•:•::•::•::.;•:;:.;;:. 4' 24 hr Recap: P.O.O.H., ick u fishin tools, T.I.H. with fishin tools. Logging Engineer: Doug wiison /Mike Daigle * 10000 units = 100% Gas In Air ~~ ~~. ~ ~a,~..,t,...t ~ t"'IE'"~3 Sp®rry Grilling S®rvio®s Mudlogger's Morning Report ~ Well: Gubik 3 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $3,390 ::..~:.Report.No.:':::::. .::::::3.~:::::: Date: 2/29/2008 Midnight Depth 4285' Footage Last 24 hrs: N/A Rig Activity: T.I.H. for Cemen~ Report For: Heinrich\ Salario\ Wesl Current 24 hr Avg 24 hr Max ~ Pump and Flow Data is: R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr (~ N/A ) F'umps U spm f-IOw rate u gpm Gas* N/A units N/A unit: ( N/A units @ N/A )Pump Capacity 3.14 gps Pump Liner & Strk 5.5x9 in. ""~~~ Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi Mud Wt In 14.70 ppg Visc 64 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas 14.7 ppg Mud Wt Out 14.70 ppg PV 24 cP YP 40 Ibs/100ft2 Gels 39 \ 54 \ 59 MBT 8.0 pH 9.2 Sd 0.25 ;` Bit No.: 3RR Type: Bit Size: Jets: _x _ x _x _TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Sd 0 %Tuff 0 %Cly 40 %Sltst 50 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to »: . ,,,.:::::::::..... ::•f•::•::~:~: •::•::•::•: ~•~ :.:.: r•:, :::::..........................,..,~ ...., ::.......::::::::::::..,.....:•............. ~ ,..:.::::. ... ..l.... xs ...~ :;Y~; . ...3 r••: •:: •::::: •:.. :::::::::}ff~..........:...•::::.::::f ........................................./ .:..~ ::::::::::::::::::::: ............ < ..:.....::.........:.....:;.:r ........ ..:::.:: ... ......:.:.... ....:....:. ':i 24 hr Recap: Unsucessful in attempt to washover fish, P.O.O.H. to 2850', CBU max gas 461 u,P.O.O.H. 2 more stands CBU max gas 707u, P.O.O.H. to 296', T.I.H. for cement. Max gas last 24 hours 9305u ;;.:Logging Engineer: Doug Wilson /Mike Daigle 10000 units = 100% Gas In Sperry drilling Services Mudlogger's Morning Report :::: :.::..:.: ~:.~:.::. ~ ~~ ':~~~:~ .,..~~ ::~~ ~...,,. Customer : ANADARKO Report No.: 31 Well: Gubik 3 Date: 3/1/2008 Area: North Slope Midnight Depth 4285' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: P/U B.H.A. Job No.: AK-AM-5551160 Report For: Heinrich\ Salariol Wesi Daily Cost : $3,390 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* N/A units N/A unit: ( N/A units @ N/A ) Pump Capacity 3.14 gps ; Pump Liner & Strk 5.5X9 in.'`•.'. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 0 psi ... Mud Wt In 13.50 ppg Visc 55 secs API filt 5.4 ml HTHP ml Mud Wt at Max Gas 13.5 ppg Mud Wt Out 13.50 ppg PV 20 cP YP 34 Ibs/100ft2 Gels 5 \ 10 \ 14 MBT 6.0 pH 9.4 Sd 0.10 Current Lithology: %Sd 0 %Tuff 0 %Cly 40 %Sltst 50 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm MaX Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to .......................::.r:-~---~-•::::::.::::.:...•...~...........................:...............•.,....~ ......... .rte..... .:.;,:.,:~: ~;::•::•:;;:•::r•:~::~;:~>: ,.c:f:r•::::,,f f..:•::::::::::~•:.:.....~~.f.. ...~.... .~. ,./ , ~ hr Recap: T.I.H., cement, P.O.O.H., CBU, max gas 868u, avg. gas 414u, continue to trip out of hole, test B.O.P.'s, pickup new B.H.A. .:.;:Logging Engineer: Doug Wilson /Mike Daigle 10000 units = 100% Gas In A :::::. •. ~:::: Customer: ANADARKO Report No.: 32 ~~'~"""t""~t"'~~ Well: Gubik 3 Date: 3/1/2008 ~:: Sparry drilling s®r..ioes Area: North Slope Midnight Depth 4285' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: T.I.H. Job No.: AK-AM-5551160 Report For: Heinrich\ Salario\ Wesl :_, Mudlogger's Morning Report Daily Cost : $3,390 ... Current 24 hr Avg 24 hr Max Pump and Flow Data ?~'~`: R.O.P. N/A ft/hr N/A ft/hr ( N/A ft/hr @ N/A ) Pumps 0 spm Flow rate 0 gpm Gas* N/A units N/A unit: ( N/A units @ N/A ) Pump Capacity 3.14 gps •.':, Pump Liner & Strk 5.5X9 in.: Sample Quality ~ Good ~ Fair ~ Poor Pump Pres o psi .. :::: "'' Mud Wt In 13.60 ppg Visc 70 secs API felt 5.0 ml HTHP ml Mud Wt at Max Gas 13.6 ppg ':~ Mud Wt Out 13.60 ppg PV 32 cP YP 31 Ibs/100ft2 Gels 9 \ 20 \ 27 MBT 4.0 pH 12.1 Sd 0.10 i~Bit No.: 3RR Type: Bit Size: Jets: _x _ x _x _TFA: :':~ Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 1601' ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max to to to to to to to to to to to •hr Recap: Slip and cut drill line at hard cement at 3015', P.O.O.H., I Average C1 C2 C3 C4 Tot C5 Tot ing shoe 955', T.I.H. 30 STD's, CBU 4705u max gas 550u avg., wash to up new B.H.A., Trip on hole. Logging Engineer: Doug Wilson /Mike Daigle * 10000 units = 100% Gas In Air ::: Sperry Grilling ^aervioes Mudlogger's Morning Report ustomer:.:.: ~:.~~.::.::ANADARKO~•~~:~~~ '::..~:.Report~No.:~: :•~~ ~..,,..33,.,.:. Well: Gubik # 3 BP 1 Date: 3/3/2008 Area: North Slope Midnight Depth 3106' Lease: Exploration Footage Last 24 hrs: N/A Rig: Nabors 105E Rig Activity: Drill Cement Job No.: AK-AM-5551160 Report For: Heinrich) Salario\ Wesi Daily Cost : $3,390 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 2 ft/hr 1 fUhr ( N/A ft/hr @ N/A ) Pumps 184 spm Flow rate 494 gpm ~`:?': Gas* 40 units 40 unit: ( 136 units @ 3102' ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. ~~~:`' • Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2950 psi .,, Mud Wt In 13.30 ppg Visc 56 secs API felt _ 5.5 ml HTHP ml Mud Wt at Max Gas 13.3 ppg Mud Wt Out 13.30 ppg PV 26 cP YP 31 Ibs/100ft2 Gels 10 \ 24 \ 33 MBT 5.0 pH 12.2 Sd 0.20 Bit No.: Type: _ '`. Wt On Bit: RPM: Short Trip-1 Depth: Short Trip-2 Depth Tight Spots: _ Bit Size Hrs. On Bit: ft Trip Gas: ft Short Trip Gas: Jets: _x _ x _x _TFA: Total Revs on Bit: Footage for Bit Run 1601' _ Mud Cut N/A ppg Trip CI: ppm _ Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: %Cmt 95 %Tuff 0 %Cly 0 %SItSt 0 %SSt 0 %Sh 5 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth to to to to to to to to to to to hr Recap: [ me GAS PEAKS Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to kick off Logging Engineer: Doug Wilson /Mike Daigle /Nick Douck /Leonard Grove * 10000 units = 100% Gas In Air ::: !3p®rry Orilting Sarvio®s Mudlogger's Morning Report ~~~~: :.~,;::•~• :::~::,: . ~~: :•::,;:.:. ,...,, :~. •~~.~~, Customer: ANADARKO Report No.: 34 Well: Gubik # 3 BP 1 Date: 3/4/2008 Area: North Slope Midnight Depth 3336' Lease: Exploration Footage Last 24 hrs: 230' Rig: Nabors 105E Rig Activity: Drilling Ahead Job No.: AK-AM-5551160 Report For: Heinrich) Salario\ Wesl Daily Cost : $3,390 ~~ Current 24 hr Avg 24 hr Max ~ Pump and Flow Data R.O.P. 15 ft/hr 9.5 ft/hr ( 86 ft/hr @ 3166' )Pumps 161 spm Flow rate 434 gpm i ":'`: Gas" 144 units 150 unit: ( 5256 units @ 3287' )Pump Capacity 3.14 gps `. Pump Liner & Strk 5.5X9 in. ?i': >`~ Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 2450 psi Mud Wt In 13.40 ppg Visc 56 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas 13.3 ppg Mud Wt Out 13.40 ppg PV 25 cP YP 29 Ibs/100ft2 Gels 9 \ 25 \ 30 MBT 7.0 pH 12.0 Sd 0.20 Bit No.: Type: Bit Size: Wt On Bit: RPM: Hrs. On Bit: Short Trip-1 Depth: ft Trip Gas: Short Trip-2 Depth ft Short Trip Gas: Tight Spots: Current Lithology: %Cmt 0 %Tuff 0 %Cly 0 Jets: _x _ x _x _TFA: Total Revs on Bit: Footage for Bit Run 1601' Mud Cut N/A ppg Trip CI: ppm _ Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft %Sltst 60 %Sst 40 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to .:.......:::..........::::•.;•., ... .........,. ,.r...:::: • •,::.::..:.::: hr Recap: Drilling from 3106' to 3336' Logging Engineer: Doug Wilson /Mike Daigle /Nick Douck /Leonard Grove 10000 units = 100% Gas In Alr ::~ t~~a.~.,tx.. t ~ ~...~ t"ik"'~S Sp®rry Oriliing S®rvic®: Mudlogger's Morning Report Customer:.::.:: .~~:.::.:~ANADARKO~~~~~~~~; .:~~.:::Report.No.:~~::: :. .~~~~~ 35~~ :,~~ Well: Gubik # 3 BP 1 Date: 3/5/2008 Area: North Slope Midnight Depth 3870' Lease: Exploration Footage Last 24 hrs: 534' Rig: Nabors 105E Rig Activity: Drilling Ahead Job No.: AK-AM-5551160 Report For: Daily Cost : $4,090 CoynelGoerlich '€ Current 24 hr Avg 24 hr Max Pump and Flow Data :: `> R.O.P. 37.5 ft/hr 22.5 ft/hr ( 70 ft/hr @ 3508' ) Pumps 185 spm Flow rate 496 gpm Gas* 160 units 150 unit: ( 6971 units @ 3529' ) Pump Capacity 3.14 gps .': Pump Liner 8 Strk 5.5x9 in.~#i Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 3424 psi ... Mud Wt In 13.40 ppg Visc 52 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas 13.4 ppg Mud Wt Out 13.40 ppg PV 27 cP YP 35 Ibs/100ft2 Gels 8 \ 16 \ 23 MBT 6.0 pH 11.8 Sd 0.20 Bit No.: Type: Bit Size: •::. •::. "`' Wt On Bit: RPM: Hrs. On Bit: Short Trip-1 Depth: ft Trip Gas: Short Trip-2 Depth ft Short Trip Gas: ,,. Tight Spots: Jets: _x _ x _x _TFA: _ Total Revs on Bit: Footage for Bit Run 855' _ Mud Cut N/A ppg Trip CI: ppm _ Mud Cut: _ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft Current Lithology: %Cmt 0 %Tuff 0 %Cly 0 %Sltst 90 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to >:a to ::. w: ::: :::: ; ' xrr •>:•~>:#•;:•,::;ffr..>:::~:~:~~::x~ ~ f~:as•„~......:.... ,z~f% f . fig'., ;;:f !........~.....,.~....................:::::: •,r : r. ! +r:~ ~ f J :: ~ +J • ~ ~ v: : x:.. }; ~: ;q':.... ///.~'f.~r: iii::r{rr; • ::::::::.::::. s'•'.•'..•:...:::::::.:. ~ ........ .. .... . ~:~ .r~ ~i :: ... •:• ii is i:::.... n.:::::::J~:::::::i .. ...: . ::.,:: .. {,y:.}•x: ryn •::{:~ i~...: ... :: ..... P: 9 3 24 hr Reca Drillin from 3336' to 3870' •'•.~ Logging Engineer: Doug Wilson /Mike Daigle /Nick Douck /Leonard Grove * 10000 units = 100% Gas In Air ~:: Sperry Grilling Services Mudlogger's Morning Report Customer: ANADARKO Well: Gubik # 3 BP 1 Area: North Slope Lease: Exploration Rig: Nabors 105E Job No.: AK-AM-5551160 Daily Cost : $3,390 .:::::.Report~No.:~::.~ . •:::::.36:::::. Date: 3/6/2008 Midnight Depth 3950 Footage Last 24 hrs: 80 Rig Activity: trip out Report For: CoynelGoerlich Current 24 hr Avg 24 hr Max ~ Pump and Flow Data R.O.P. na ft/hr 45 ft/hr ( 91 ft/hr @ 3928 )Pumps 186 spm Flow rate 498 gpm ii; Gas* 8 units 217 unit; ( 529 units @ 3947 )Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in. Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 3500 psi Mud Wt In 13.60 ppg Visc 51 secs API felt 5.4 ml HTHP ml Mud Wt at Max Gas 13.6 ppg Mud Wt Out 13.60 ppg PV 27 cP YP 32 Ibs/100ft2 Gels 9 \ 20 \ 27 MBT 6.0 pH 11.8 Sd 0.10 No.: 6 Type: HC506ZX Bit Size: 8 3/4 Jets: 6 x 10 x _x _TFA: 0.4600 On Bit: 39733 RPM: 110 Hrs. On Bit: 59.5 Total Revs on Bit: NA Footage for Bit Run 934 Short Trip-1 Depth: 3950 ft Trip Gas: 10000 Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Cmt 0 %Tuff 0 %Clyst _ 40 %Sltst 60 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm MaX Average C1 C2 C3 C4 Tot C5 Tot 3915 to 3915 454 200 42537 2311 507 93 0 3947 to 3947 529 200 51808 3004 696 145 0 to to to to to to to to to ..r%!:. ..,r.::: :~.,':, ,4,:,:, ..;•,,.. .o:.::.„f.; .,:?..,. •,+~ ,ar•r.• ox%:•;. .rr'r'.',tr:•:.::,•: •::•::•::~ ,....:. ....:::. ..:..... r:tr.rr:...:;•+:;::;:;•:+:•::•::•:::.n.. ...::.:.r.....4:.,•'tt„•:,;,• k•.::•::::::rr/• :+.•::::.;••: •, 1.:.::....t...Y.,•\.:»:•::•::•:r: •:::::.,, 24 hr Recap: Drilling from 3870' to 3950'. Circulate bottoms up. Short trip to casing shoe. Trip to bottom. Circulate bottoms up. Max gas 10000 units(gas started increasing at 340 strokes). Gas from 3950' was 1020 units. Circulate another bottoms up. Pull 2 stands/tight. Circulate gas. Max gas 2120 units. Trip in hole t/bottom. Pull 2 stands. Circulate gas. Max gas 2178 units. Increas mud weight f/13.4 t/13.6 ppg. Trip out. Logging Engineer: Doug Wilson /Larry Lynch 10000 units = 100% Gas In Air ::I Customer: ANADARKO Report No.: 37 '' ''' ~'£°°t"°~~~"'~~ Well: Gubik # 3 BP 1 Date: 3/7/2008 8parry Grilling s®rvioe3s Area: North Slope Midnight Depth 3950 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: Elog ' Job No.: AK-AM-5551160 Report For: Mudlogger s Morning Report Daily Cost : $3,390 WestlGoerlich Current 24 hr Avg 24 hr Max Pump and Flow Data i ii R.O.P, na ft/hr na ftlhr ( na ft/hr @ na ) Pumps na spm Flow rate na gpm i ii Gas" na units na unit: ( 0 units @ na ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5X9 in.ii i' ': Sample Quality ~ Good ~ Fair ~ Poor Pump Pres na psi Mud Wt In 13.60 ppg Visc 51 secs API felt 5.5 ml HTHP ml Mud Wt at Max Gas na ppg Mud Wt Out 13.60 ppg PV 21 cP YP 37 Ibs/100ft2 Gels 7 \ 15 \ 23 MBT 6.0 pH 11.7 Sd 0.20 s `•3 Bit No.: na Type: na Bit Size: x _TFA: na Jets: x x # Wt On Bit: na RPM: na Hrs. On Bit: _ _ _ na Total Revs on Bit: Footage for Bit Run Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: ppg Short Trip CI: ppm Mud Cut: Tight Spots: _ to Feet of Fill on Bottom: ft Current Lithology: %Cmt 0 %Tuff 0 %Clyst 40 %Sltst 60 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to :: : to :: .: . .... .... ... :::::. :::::::::::: •:::. .. f•.::: ....... ,.,,....f:{ff :.... {f{fi.fi::::::::';'::':f:r:rr:x~:r:: f;` •:r.::r... {: fff`•:::::•::•::•::•::•:::::•.:...{~f •........;f:.......:...:+,.•:::: ••:::::•:.::.:•... . ... f::...:.:......... ::::.,: ..i ........... :: . ':: >: 24 hr Recap: Tri out. Elo . ':'•.': ": Logging Engineer: Doug Wilson /Larry Lynch 10000 units = 100% Gas In Air •.~.:~: :::.~: Customer: ANADARKO Report No.: 38 ``'' ~~'~""t"~~t"'~~~ Well: Gubik# 3 BP 1 Date: 3/8/2008 `:•`: Sperry Or•iliing s®rvioes Area: North Slope Midnight Depth 3950 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: rig up test rams ' Job No.: AK-AM-5551160 Report For: ... Mudlogger s Morning Report Daily Cost : $3,390 WestlGoerlich .. . Current 24 hr Avg 24 hr Max Pump and Flow Data s R.O.P. na ft/hr na fUhr ( na ft/hr @ na ) Pumps na spm Flow rate na gpm ~~~~: Gas" na units na unit: ( 10000 units @ w/circ ) Pump Capacity 3.14 gps Pump Liner & Strk 5.5x9 in.s ~~ Sample Quality ~ Good ~ Fair ~ Poor Pump Pres na psi Mud Wt In 13.60 ppg Visc 51 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas na ppg Mud Wt Out 13.60 ppg PV 22 cP YP 30 Ibs/100ft2 Gels 6 \ 13 \ 20 MBT 7.0 pH 11.5 Sd 0.10 `';'Bit No.: na Type: na Bit Size: na Jets: _x _ x _x _TFA: ::::: Wt On Bit: na RPM: na Hrs. On Bit: na Total Revs on Bit: Footage for Bit Run Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Cmt 0 %Tuff 0 %Clyst 40 %Sltst 60 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to ... to ... l r v. f. F.. ...+ :: ~~~::•i'•:•i:i~:~: ::: .. s......... s .... .:::::::::.:w r v:.vv:::.v:.v... :::::::?...•. s.. /r ............. r. .. f.+~J`/ l.•: •:::::::::::::::::.•:::::: r:. +.+/.::•:•:•:•: is}:•}:..• xr~ r. 1 /:::::+. •!•::::.vyF../::{~:•i} .. ~: f+f:'v:~i:~:i:: ::: •::::: ~::v::: :v :::::... ..: ........: . { ! fi.. .rf:..r........................... r:::::::::::::: r~............~..~. .. ..:::::::;:.$:~:::?x.i ....... }. ~.::.... fifi. ~.....3'!?•: ~:~::::$:::• •.•.... >: 24 hr Recap:• Elog. TIH t/985'. Max gas f/disp. W/TIH 6134 units. Circ. B/U. Gas started increasing at 320 strokes and increased t/10000 units at 750 stks. Gas stayed at 10000 units for 8 minutes. Circ. Until gas fell t/475 units. RIH U3090'. Max gas f/disp going in hole 2610 units. Circ. B/U. Gas started going up at 465 stks. Max gas 10000 units at 1100 stks. Gas stayed up for 15 minutes and fell down t/475 units. RIH t/3905'. Max gas f/disp going in hole 200 units. Circ. B/U. Max gas 1665 units. Circ. until gas decreased t/120 units. Trip out of hole. Rig up t/test rams Logging Engineer: Doug Wilson /Larry Lynch 10000 units = 100% Gas In Air :: '' : 39 Customer: ANADARKO Report No ' : ~~~~~~ . Well: Gubik # 3 BP 1 Date: 3/9/2008 i Sp®rry Oriliir~g S®rvi~®s Area: North Slope Midnight Depth 3950 Lease: Exploration Footage Last 24 hrs: 0 Rig: Nabors 105E Rig Activity: run 7" casing Job No.: AK-AM-5551160 Report For: Mudlogger's Morning Report Daily Cost : $3,390 WestlGoerlich Current 24 hr Avg 24 hr Max Pump and Fiow Data #i R.O.P. na ft/hr na ft/hr ( na ft/hr @ na ) Pumps 46 spm Flow rate 124 gpm ~'?. Gas* na units na unit: ( 4097 units @ run casing) Pump Capacity 3.14 gps ~'. Pump Liner & Strk 5.5X9 in. ``; Sample Quality ~ Good ~ Fair ~ Poor Pump Pres 145 psi Mud Wt In 13.60 ppg Visc 51 secs API felt 5.6 ml HTHP ml Mud Wt at Max Gas na ppg Mud Wt Out 13.60 ppg PV 22 cP YP 30 Ibs/100ft2 Gels 6 \ 13 \ 20 MBT 7.0 pH 11.3 Sd 0.10 I No.: na Type: na Bit Size: na Jets: _x _ x _x _TFA: t On Bit: na RPM: na Hrs. On Bit: na Total Revs on Bit: Footage for Bit Run Short Trip-1 Depth: ft Trip Gas: Mud Cut N/A ppg Trip CI: ppm Short Trip-2 Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: %Cmt 0 %Tuff 0 %Clyst 40 %Sltst 60 %Sst 10 %Sh 0 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Average C1 C2 C3 C4 Tot C5 Tot to to to to to to to to to to to :::f~.•:':iii::::•:'^:•::•:?::::•:?:::sy::•. f~.~ ~l r~::,..v:::::: n; v: •.:•::::: n:.~::::::::.Y....n. r ................... J ' r v.. si: v:.;:.•.:.:.:.v: vvv::::r.' ~ •:.~:: ' n..... ...• ....} .. ~.. ..... f..x ....• r..... :::::... ... . '::iJJ/ ' ~.~ vex. '.tiff:<,v:::•'• •! .. / .~ ../ .. Fi. J. 1 hr Recap: Test BOP's. Rig up and run 7"casing. Max gas at 162' w/running casing 2063 units. Max gas gas at 286' w/run casing 1681 units. Max gas at 374' w/run casing 2089 units. Max gas at 495' w/running casing 2237 units. Circulate at 510' w/running casing max gas 4097 units after 346 strokes. Gas falls back after peaks to 70-200 units. ~~~Logging Engineer: Doug Wilson /Larry Lynch 10000 units = 100% Gas In A
