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205-201
~, Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ©'~-` - ~~~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III II~III II II III III RESCAN DIG TAL DATA OVERSIZED (Scannable) ~olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Protect Proofing III IIIIIIIIIII IIIII BY: Maria Date: D D !sl Scanning Preparation ~_ x 30 = ~~ + ~ =TOTAL PAGES__ ~ I I (Count does not include cover sheet) BY: Maria Date: ~ T rI f7 ~ lsl Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include co er sheet) Page Count Matches Number in Scanning Preparation: ~/ YES NO BY: Maria Date: ~ ~ 0 ~ /s/ ~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II') II I II II I (III ReScanned III IIIIIIIIIII IIIII BY: Maria __ Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc • BP Exploration (Alaska) Ina Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~ty~ 3 ,~. E:a ~,~t°:~ ~~ ~L G~~ ,~y t t'1~.,1 August 14, 2009 `~'`"'"~`" Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, • bp ~~~~~~~~ ocT o 5 zoas ~I~sk~ Dii ~a Gas Cons. Gorr~~~6A~n Anchara~e ~x.+~/`-~ ' ~" ~ Z.-- I d ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Expioration (Alaska ) lnc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-OSA 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 500292t9670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 IVA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-is 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 02 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-236 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-326L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 S/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-t00 2031710 5002923t820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-f 12 2071720 50029233800000 NA surface NA s' ~ w~ DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2052010 Well Name/No. PRUDHOE BAY UN BORE Z-108 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23292-00-00 MD 7432 TVD 6831 Completion Date 6/5/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -- -_-- DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / PWD. RES /AIT, DT /BHC, CNL, LDL, GR, (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 7432 Open 2/14/2006 Directional Survey 0 7432 Open 2/14/2006 og Cement Evaluation 5 Col 1 7040 7320 6/14/2006 SCMT-CB, GR, CCL 4-Jun- i 2006 I ~[u C Lis 15446-6acnmaRay 111 7431 Open 9/28/2007 LIS Veri, GR, ROP w.PDS and TIF graphics I~ag 15446 Gamma Ray 25 Blu 108 7432 Open 9/28/2007 MD ARC, GR, Composite Final Print 4-Feb-2006 og 15446 Gamma Ray 25 Blu 108 7432 Open 9/28/2007 ND ARC, GR, Composite Final Print 4-Feb-2006 ;~ C Lis 15589°°fnduction/Resistivity 264 7390 Open 10/26/2007 LIS Veri, AIT, SD, CNT w/PDS graphics ~g See Notes 25 Col 1 264 7414 Open 10/26/2007 MD Platform Express, BHC on TLC wireline, SP, AIT, BHC, LDT, CNL, GR Feb-5- 2006 og See Notes 25 Col 1 264 7414 Open 10/26/2007 TVD Platform Express, BHC on TLC wireline, SP, AIT, BHC, LDT, CNL, GR Feb-5-2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2052010 Well Name/No. PRUDHOE BAY UN BORE Z-108 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23292-00-00 MD 7432 TVD 6831 Completion Date 6/5/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? Y N Chips Received? `f`f'tV-' Formation Tops ~/ N Analysis 4~/iG'~ Received? Comments: Date: Compliance Reviewed By: OV~ Schlemberger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4454 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Borealis Date BL Color CD W-213 V-215 Z-108 S-124 5-125P61 11661175 11584491 11212828 40014242 40015467 MEM TEMP/PRESS SURVEY CH EDIT PDC GR USIT OH WIRELINE PEX EDIT ` OH MWDILWD EDIT OH MWDILWD EDIT -~ 09129107 04123/07 02/05/06 11/05/06 07/07107 1 2 3 2 1 1 1 1 V-121 40015007 OH MWD/LWD EDIT 3t• 03124107 2 1 V-222 40015319 OH MWDILWD EDIT 06108/07 2 1 W-210 40014842 OH MWDILWD EDIT '~ 02126107 2 1 V-216 40015066 OH MWDILWD EDIT 04/07107 2 1 W-204 40014637 OH MWDILWD EDIT 01129107 2 1 W-204PB1 40014637 OH MWDILWD EDIT 01/24/07 2. 1 W-204L1 40014637 OH MWDILWD EDIT 02/07/07 1 1 W-204L2 40014637 OH MWDILWD EDIT 1; 02120107 1 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 . -- ' 900 E Benson Blvd. , Anchorage AK 99508-4254, ~~~' Date Delivered: ~~ - __ ~ ~' o,"~"? aei 16ti Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by. 10/19/07 osnolo7 • • • • Schlum~rger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4409 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 Field: Polaris Orion Borealis Date BL Color CD V-203L1 40012957 OH EDIT MWDA.WD 01/24/06 2 1 V-112 Z-108 Z-100 40013154 40012738 NIA OH EDIT MWD/LWD V O OH EDIT MWDILWD SBHP SURVEY ~ 03102/06 02104/07 09/15/07 2 2 1 1 1 5-213A 11855809 SBHP SURVEY 08131107 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. t •;., 4. C"' ~~ ~ tl i , Petrotechnical Data Center LR2-1 µ i i, f' 900 E Benson Blvd. - __ r-- ~ '• ~~' Anchorage AK 99508.4254 Date Delivered: '` )" ~.1 r;a U L °d a 1~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ` ~ 1 rj Received by: /` STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~~ V JUN z ~ t0U6 Alaska Oil ~. Gas Cu>1s. Commission •,.,.ti...~~o 1a. Well Status:®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o Q GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1br,.~llfollClass: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 6/5/2006 12. Permit to Dri11 Number 205-201 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/30/2006 13. API Number 50-029-23292-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/4/2006 14. Well Name and Number: PBU Z-108 4305 FSL, 3578 FEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 1625' FSL, 3479' FEL, SEC. 19, T11 N, R12E, UM g• KB Elevation (ft): 82.5' 15. Field /Pool(s): Prudhoe Bay Field /Borealis Pool Total Depth: 1573' FSL, 3467' FEL, SEC. 19, T11 N, R12E, UM 9. Plug Back Depth (MD+TVD) 7343 + 6745 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599099 y- 5959100 Zone- ASP4 10. Total Depth (MD+TVD) 7432 + 6831' Ft 16. Property Designation: ADL 028255 TPI: x- 599245 y- 5956422 Zone- ASP4 Total Depth: x- 599257 Y- 5956371 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 19 W h if ff h 20 Thi k f P f t 18. Directional Survey ®Yes ^ No ater dept , ore . o s N/A MSL ness o erma ros . c 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / PWD, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MO ETTING EPTH TVD'' HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM $IZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set Approx. 9-5/8" 40# L-80 29' 3248' 29' 3003' 12-1/4" 550 sx AS Lite II, 295 sx Class 'G' 7" 26# L-80 29' 7427' 29' 6826' 8-3/4" 166 sx AS Lite 216 sx Class 'G' 23. Perforations open.to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 7181' 7123' MD TVD MD TVD 7232' - 7257 6638' - 6662' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 109 Bbls of Diesel 26• PRODUCTION TEST Date First Production: June 6, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 6/10/2006 Hours Tested 5 PRODUCTION FOR TEST PERIOD • OIL-BBL 28 GAS-McF 13 WATER-BBL 25 CHOKE SIZE 176° GAS-OIL RATIO 450 Flow Tubing Press. 30 Casing Pressure 1740 CALCULATED 24-HOUR RATE OIL-BBL 133 GAS-MCF 60 WATER-BBL 120 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~JOdVIPtI_=Ci(?~ S ~~ JUN ~ ~ 2rJ06 Form 10-407 Revised 12/2003 '/ 1 ~ ~ ~ ~ ~ ~Of~TINUED ON REVERSE $IDE 28. GEOLOGIC MARK 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3402' 3140' None Ugnu M Sands 4647' 4255' Schrader Bluff N Sandstones 4963' 4538' Schrader Bluff O Sandstones 5160' 4717' Base Schrader Bluff /Top Colville 5554' 5075' HRZ 6950' 6367 Kalubik 7196' 6603' Kuparuk C 7229' 6635' LCU 7273' 6677' Kuparuk A 7283' 6687' Miluveach 7332' 6734' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date O ~(~~ f i~ PBU Z-108 205-201 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Dnuing Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only T ~ ' m n rn _' n CC C ~ ^~ LL W ~' r a 2 m m a V n ~ N N rn o N V. d N Q i Y J d N ~. .~ N r N i d d : `-' Q a` O rn i m rn U i 3 ~ ~ ` ~ ~ ~ y^ m ~ z L d Q. ~' ~ i Q ~ Q ~/~ V J K LL ~~ O ' V + J ` ^ ^ ` W O ~ ~ O m Y I a' o ~ ! ~ ' rS J ~~ - i ~ o ~ ~ s o M a m ~ I ~ r~ N m 00 Op T ~ ~ ~ T N T N ~ ~ N ~ ~ ~ 0 ~ ~ - ~ z i (~ C ~ ~ t9 ~~~, N ~ O ~ M M J U ii d F !~ (~ N a N O N M N d a BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1 /29/2006 00:00 - 14:00 14:00 - 21:30 21:30 - 22:30 Z-108 Z-108 DRILL+COMPLETE NABOBS ALASKA DRILLING NABORS7ES Hours ' Task Code NPT 14.00 MOB P 7.50 RIGU P Start: 1 /29/2006 Rig Release: 2/10/2006 Rig Number: 7ES Phase PRE PRE 1.00 ~ RIGU P ~ ~ PRE 22:30 - 00:00 1.50 RIGU P PRE 1/30/2006 00:00 - 06:00 6.00 RIGU P PRE 06:00 - 06:30 I 0.501 RIGU I P I I PRE 06:30 - 09:30 3.00 RIGU P PRE 09:30 - 10:30 1.00 RIGU P PRE 10:30 - 11:00 0.50 RIGU P PRE 11:00 - 12:00 1.00 RIGU P PRE 12:00 - 12:30 I 0.501 DRILL I P I I SURF 12:30 - 15:00 2.50 DRILL P SURF 15:00 - 15:30 0.50 DRILL P SURF 15:30 - 17:30 2.00 DRILL P SURF 17:30 - 18:30 1.00 DRILL P SURF 18:30 - 19:00 0.50 DRILL P SURF 19:00 - 00:00 5.00 DRILL P SURF 1/31/2006 100:00- 13:00 13.001 DRILL P (SURF 13:00- 13:30 I 0.501 DRILL IP I (SURF 13:30 - 15:30 I 2.001 DRILL I P I I SURF 15:30 - 17:00 i.50 DRILL P SURF 17:00 - 17:30 0.50 DRILL P SURF 17:30 - 19:30 2.00 DRILL P SURF 19:30 - 00:00 4.50 DRILL P SURF Page 1 of 7 Spud Date: 1/30/2006 End: 2/10/2006 Description of Operations Move rig f/S-400 to Z-108. Inspect derrick, ready to raise. PJSM and raise derrick. Bridle down and pin blocks to top drive. Raise and pin cattle chute. Lay mats, place herculite and berm up cellar. Spot sub over well, spot pit module. Hook up service lines to pit complex. Ready to take on fluids at 21:30. Unable to spot mats prior to rig move due to Pad prep. Accept rig at 21:30 1-29-2006. Hang bridle lines, attach bails and elevators. NU diverter. Hold pre-spud meeting w/WSL, tour pusher, all hands. .Continue to NU diverter. Clean snow and ice out of diverter line. Hook up diverter line. Spot Geo, MI and MWD modules and hook up cables. Take on hot water to pits. Thaw Pits. Take on spud mud. Load pipe shed w/4" HT-40 drill pipe. Function test diverter and knife edge valve. Review action required by all hands in case of diverter emergency and hold D3 Diverter drill. Specify safe briefing areas. AOGCC rep Chuck Scheave wavied witness of function test. PU 28 stds. 4" HT-40 drill pipe. PU HWDP and jars. Load pipeshed w/BHA and x/o. PU partial BHA #1 w/12-1/4" RR bit, 1.83 deg. PDM motor assy. and UBHO for Gyro surveying. Spud well at 12:00. MW = 8.8 ppg. Find ice at 50'. Fill conductor and surface circ system. Check for leaks--none. Drill f/109' to 206'. POH and PU additional BHA. RU Gyrodata/Sperry W/L and gyro survey equipment. Run Gyro survey. Drill f/126' to 285'. POH 2 stds and pickup additional BHA. RIH to 266' and run gyro survey. RIH to 285' and drill to 536'. Up wt. 62K. SO wt 60K. Rot wt. 61 K. 569 gpm, 1050 psi. Run gyro at every connection and alternating gyros as required. MW = 9.1 ppg. ADT =2.47 hrs. Drill 12-1/4" surface hole f/536' to 1851' running gyro surveys as required to 700'. RD a line. 550 gpm, 1950 psi. Up wt. 85K, SO wt. 65K, Rot. wt. 75K. , tq. on 6K, tq. off 3K. CBU 265 bbls. at 573 gpm, 1950 psi. 60 rpm, tq. off 3K. MW 9.2 ppg in & out. POH to 213', tight f/1140' to 1165', f/1020' to 1060', f/740' to 790', and f/485' to 506'. Wipe clean OK. Handle BHA, CO bit, and change motor bend to 1.5 deg. Service top drive and crown. RIH to 1851' and wash last stand to bottom at 1851'. Drill f/1851' to 2487'. Up wt. 90K, SO wt. 80K, Rot. wt. 85K. 600 gpm, 2400 psi on, 2200 psi off, 80 rpm, tq. on 5K, tq. off 3K. MW = 9.5 ppg. ADT = 11.43, ART = 5.4, AST = 6.03. Printed: 2/13/2006 12:01:57 PM BP EXPLORATION Operations Summary Report Page 2 of 7 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To Z-108 Z-108 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 7ES Task TE A DRI Code LING ~ NPT Start I Rig Rig Phase Spud Date: 1/30/2006 : 1/29/2006 End: 2/10/2006 Release: 2/10/2006 Number: 7ES Description of Operations 2/1/2006 00:00 - 05:30 5.50 DRILL P SURF Drill 12-1/4" surface hole to TD at 3263'. Up wt. 103K, SO wt. 80K, Rot. wt.95K. 600 gpm, 2800 psi on, 2200 psi off, 80 rpm, tq. on 6K, tq. off 3.5K. ADT = 3.25, AST =.37,ART = 2.88, Jar Hours = 174.2 05:30 - 07:00 1.50 DRILL P SURF Circulate Bottoms Up, Pull 1 Stand Every 85 bbls Pumed From 3263' to 2710' 07:00 - 08:00 1.00 DRILL P SURF Short Trip To 1754', Well attempting to swab From 2680' to 2040' With 25K Overpull, wipe out tight spots. OK 08:00 - 09:00 1.00 DRILL P SURF RIH To 3263'. No Hole Problems. Break Circulation 09:00 - 10:30 1.50 DRILL P SURF Circulate Bottoms Up, Pull 1 Stand Every 85 bbls Pumped From 3263' to 2710' 10:30 - 12:00 1.50 DRILL P SURF POOH To 625', Mud Wt In 9.6 ppg, Mud Wt Out 9.6 ppg 12:00 - 12:30 0.50 DRILL P SURF POOH From 625' 12:30 - 15:00 2.50 DRILL P SURF Lay Down MWD, Lay Down Motor. 15:00 - 15:30 0.50 DRILL P SURF Clean and Clear Floor. 15:30 - 16:00 0.50 CASE P SURF Make dummy landing run with 9-58" hanger /landing joint. 16:00 - 18:00 2.00 CASE P SURF Rig up 9-5/8" casing tools 18:00 - 18:30 0.50 CASE P SURF PJSM - MU Shoe track / Bakerlok all connections up to float collar and check floats. MU touque 8100 ft/Ibs. 18:30 - 00:00 5.50 CASE P SURF Cont' Run 9-5/8" casing placing bow spring centrizers on first 25 joints. Pipe held up at 2060' work and wash casing down to 2360' with 6.5 bpm 420 psi. 2/2/2006 00:00 - 02:00 2.00 CASE P SURF Wash and work 9-5/8" surface casing from 2360' to 2690' with 6.5 bpm 420 psi. Run Dry from 2690' to bottom with no problems circulate last joint down. MU casing hanger/ landing joint and land casing. 02:00 - 02:30 0.50 CEMT P SURF RD Franks fill up tool. Blow down top drive and MU 9-5/8" cement head and circulating lines. 02:30 - 05:00 2.50 CEMT P SURF Circulate and condition mud for cement staging pumps up to 422 GPM 705 psi. Adjust mud properties to < 70 vis. YP 15 UP Wt. 155k DN Wt. 115k 05:00 - 07:30 2.50 CEMT P SURF Pump 5 bbls water & test lines to 3500 psi. 80 bbls Mud Push II @ 10. i ppg. Drop bottom plug & pump 440 bbls 10.7 ppg Lead Arctic Set Lite II cement w/ red dye. Pump 61 bbls 15.8 ppg Class G Tail cement. Drop top plug & wash up with 10 bbls water followed by 228 bbls mud with rig pumps at 10 bpm 1300 psi. Reciprocate pipe until first 50bb1 of lead out the shoe Bump plug W/ 500 psi over to 1800 psi. and hold for 5 min. Bleed off pressure & check floats -floats holding. During cement job maintained full returns throughout job. 125 bbl of cement returns back to surface. CIP @ 0730 hrs. 07:30 - 09:00 1.50 CEMT P SURF Wash up stack and flow line. Rig down casing equipment. Pull .landing joint. Nipple down diverter line 09:00 - 10:00 1.00 DIVRTR P SURF Nipple down riser and annular 10:00 - 13:30 3.50 WHSUR P SURF Nipple up wellhead. Test casing head seal to 1000 psi for 5 ( i min, Good Test. Nipple up BOPE stack 13:30 - 14:00 0.50 CASE P SURF Clear floor of casing equipment f 14:00 - 15:30 1.50 BOPSU P SURF Rig up to test BOPE ( 15:30 - 18:30 3.00 BOPSU P SURF Test BOPE and choke manifold 250 psi low 3500 psi high. Test ~ wittnessed by AOGCC rep Lou Grimaldi, NBR Toolpusher Larry W, WSL Lance Vaughan 18:30 - 19:30 1.00 BOPSU P SURF Rig down test equipment and blowdown lines. Finish loading ~ drill pipe in pipe shed and strap Printed: 2/13/2006 12:01:57 PM BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: Z-108 Common Well Name: Z-108 Spud Date: 1/30/2006 Event Name: DRILL+COMPLETE Start: 1/29/2006 End: 2/10/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/10/2006 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To 'j Hours ~~ Task ~ Code NPT li Phase j Description of Operations 2/2/2006 19:30 - 23:00 3.50 DRILL P PROD1 Pick up 72 joints of 4" Ht drill pipe & rack back in the derrick 23:00 - 00:00 1.00 DRILL P PROD1 Pick up and m/u 8-3/4" bit, 1.15 deg motor, arc, mwd, nm stab,2 mn spiral dc,nm stab, nm spiral dc, saver sub, hyd jars, xo, 21 jts 4" hwdp, 1 jt 4" dp, 8-3/4" ghost reamer,51 jts 4" drill pipe, 8-3/4" ghost reamer 2/3/2006 00:00 - 01:30 1.50 DRILL P PROD1 Pick up and m/u 8-3/4" bit, 1.15 deg motor, arc, mwd, nm stab,2 mn spiral dc,nm stab, nm spiral dc, saver sub, hyd jars, xo, 21 jts 4" hwdp, 1 jt 4" dp, 8-3/4" ghost reamer,51 jts 4" drill pipe, 8-3/4" ghost reamer 01:30 - 04:30 3.00 DRILL P PROD1 Pick up 60 joints 4" drill pipe from pipe shed. Tagging landing collar at 3162 04:30 - 05:30 1.00 EVAL P PROD1 Rig up to test casing. Test 9-5/8" casing to 3500 psi for 30 min 05:30 - 07:30 2.00 DRILL P PROD1 Drill cement and shoe track plus 20 foot of new hole to 3283. Change out LNSD mud while drilling cement and shoe track at 500 gpm / 1140 psi / 40 rpm / Tq 5k, Cement drilled with 10k bit wt. 07:30 - 08:30 1.00 DRILL P PROD1 Rig up to test. Perform LOT with 8.8 ppg to an EMW of 14.9 ppg, Surface pressure 990 psi 08:30 - 12:00 3.50 DRILL P PROD1 Drill 8-3/4" hole from 3263 to 3869. Mud wt in 9.0 ppg, Mud wt out 9.0 ppg, 565 gpm C~3 1460 psi, Up 110k, Dwn wt 85k, Rot wt 85k, Tq off 4k, Tq on 5k, 120 rpm, Caculated ECD 9.64 ppg, Acutal ECD 10.ippg 12:00 - 00:00 12.00 DRILL P PROD1 Drill 8-3/4" hole from 3869 to 5535. Mud wt in 9.0 ppg, Mud wt out 9.0 ppg, 550 gpm @ 1900 psi, Up 150k, Dwn wt 105k, Rot wt 125k, Tq off 6k, Tq on 7k - 8k, 120 rpm, Caculated ECD 9.65 ppg, Actual 10.2 ppg 2/4!2006 00:00 - 06:00 6.00 DRILL P PROD1 Drill 8-3/4" hole from 5535 to 7030. Mud wt in 9.1 ppg, Mud wt out 92 ppg, Pump a hi vis sweep at 6080 a 20 percent increase in cuttings was observed at bottoms up. Begin weighting mud up from a 9.1 ppg at 6500, to a 9.9 ppg at 6680.Up wt 170k, Down wt 125k, Rot wt 140k, Rpm 120, WOB 10 -30k, Tq on 10k, Tq off 7k, 550 gpm 3276 psi on bottom, 3035 psi off bottom. Calculated ECD 10.5 ppg, Actual ECD 11.16 06:00 - 15:30 9.50 DRILL P PROD1 Drill 8-3/4 hole from 7030 to 7432 TD. - At 7130 well lost 20 bbls, observe slight flow. CBU, check MW had .3 ppg gas cut on bottoms up. Circ mud wt even @ 9.9 ppg in /out. Con't drilling to 7330 ft, observed gas cut mud (.6 ppg) & oil at surface. Flow check showing slight flow. Con't drilling to TD ~ 7432 ft begin weighting mud up towards 10.3 ppg. Up wt 175k, Dwn wt 130k, Rot wt 145k, Tq on bottom 8-9k, Tq off bottom 8k, 550 gpm 3000 psi on bottom, 2760 psi off bottom, AST 0, ART 1.83 15:30 - 18:00 2.50 DRILL P PROD1 Circulate and weight up mud from a 9.9 ppg to a 10.3 ppg, 550 gpm 2860 psi, Rotating and reciprocating pipe, 140 rpm, Tq 7k, Observe well bore -Static 18:00 - 19:00 1.00 DRILL P PROD1 Blow down top drive, POOH from 7432 to 7060, Four stands, Well attempting to swab. 19:00 - 22:00 3.00 DRILL P PROD1 Back ream from 7060 to 5405, 470 gpm 2200 psi, 80 rpm, Actual ECD 11.50, Calculated ECD 10.85, Large amount of cuttings coming across shale shakers while back reaming. Shale shakers cleaned up at 5405 once upper 'Ghost' reamer entered 9 5!8" casing. Blow down top drive, monitor the well Printed: 2/13/2006 12:01:57 PM BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: Z-108 Common Well Name: Z-108 Spud Date: 1/30/2006 Event Name: DRILL+COMPLETE Start: 1/29/2006 End: 2/10/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/10/2006 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours ~ Task ~ Code ~ NPT ~ Phase - Description of Operations 2/4/2006 19:00 - 22:00 3.00 DRILL P PROD1 bore for 10 min -static. Lost 56 bbls to well bore while back reaming 22:00 - 00:00 2.00 DRILL P PRODi POOH from 5405 to 3207, 9-5/8 casing shoe at 3248 2/5/2006 00:00 - 01:30 1.50 DRILL P PROD1 Cut drilling line 01:30 - 02:00 0.50 DRILL P PROD1 Service top drive 02:00 -04:00 2.00 DRILL P PROD1 RIH to TD at 7432. Filling pipe at 5500. No problems running to bottom 04:00 - 07:00 3.00 DRILL P PRODi Circulate bottoms up observe slight increase in cuttings at shale shaker. Pump 50 bbl hi vis sweep around at 500 gpm 2545 psi. Cond mud for logging and running casing. Calculated ECD 10.8 ppg. Actual 11.0 ppg. Mud wt in 10.3 /out 10.3 07:00 - 11:30 4.50 DRILL P PRODi POOH to 6482 wet. Pump dry job and blow down top drive. Encountering 30k over pull at 6494 top of HRZ. Intermittent over pulls of 20k from 7190 to 7160. Cont to POOH. Lay down ghost reamers 11:30 - 12:00 0.50 DRILL P PROD1 Std back HWDP,Iay down jar 12:00 - 14:00 2.00 DRILL P PROD1 Lay down 3 nmdc, nm stb, break bit, lay down mwd and motor 14:00 - 14:30 0.50 EVAL P PROD1 Clean and clear rig floor of unnessary tools. Function BOP. 14:30 - 16:00 1.50 EVAL P PROD1 Rig up Schlumberger E-Line 16:00 - 19:30 3.50 EVAL P PRODi RIH with plattorm express to 7006 WLM setting down 1000 Ibs of compression, several attempts were made to pass below 7006 which were unsuccessful. Logged the well up from 7006 to 250. Remove source and prepare to hang sheave in derrick for drill pipe conveyed logging. 19:30 - 22:30 3.00 EVAL P PROD1 Mobilize Schlumberger DPC tools. Behead wire line. 22:30 - 00:00 1.50 EVAL P PROD1 Load source, 2/6/2006 00:00 - 00:30 0.50 EVAL N DPRB PROD1 Hang sheave in derrick 00:30 - 02:00 1.50 EVAL N DPRB PRODi RIH w/ with platform express logging tools on 4" HT drill pipe to 9-5/8 casing shoe @ 3248' 02:00 - 03:00 1.00 EVAL N DPRB PROD1 Circulate bottoms up @ 3 bbl /min 190 psi, Mud wt in 10.3 / Out 10.3 03:00 - 08:00 5.00 EVAL N DPRB PROD1 RIH w/ with platform express logging tools on 4" HT drill pipe to 6522'. Filling drill pipe every 10 stand's run 08:00 - 09:00 1.00 EVAL N DPRB PROD1 Make up cross over and side door entry sub. Pump wire line head down to 6000' at 63 spm 413 psi. Alfow wire line to free fall. Latch up to wet connect. 09:00 - 10:00 1.00 EVAL N DPRB PROD1 Log in the hole at 900 to 1000 feet per hour to 7420'. Taking 1200 to 1500 pounds of down weight from 7012' to 7018'. Up wt 150k ,Slack off 110k 10:00 - 11:00 1.00 EVAL N DPRB PROD1 Log out of the hole from 7420' tp 6522' at 1500 to 1800 feet per hour 11:00 - 11:30 0.50 EVAL N DPRB PROD1 Disconnect from wet connect and remove wire line from side door entry sub 11:30 - 12:00 0.50 EVAL N DPRB PROD1 Break and lay down side door entry sub and cross over's 12:00 - 15:30 3.50 EVAL N DPRB PROD1 Pump dry job and POOH from 6553' to 200' 15:30 - 17:00 1.50 EVAL N DPRB PROD1 Remove source and lay down looging tools. Function BOPS 17:00 - 17:30 0.50 EVAL P PROD1 Drain stack, pull wear ring, make dummy run w/ csg hanger and set set plug 17:30 - 18:30 1.00 EVAL P PROD1 Change top pipe rams from 3-1/2" x 6" to 7" rams 18:30 - 20:00 1.50 EVAL P PROD1 Install test jt, test top pipe ram door seals to 3500 psi for 10 min, rig down test equipment, pull test plug and blow down line's. 20:00 - 22:00 2.00 CASE P RUNPRD Rig up 7" casing equipment Printed: 2/13/2006 12:01:57 PM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: Z ell Name: Z e: Name: From - To ! -108 -108 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 7ES Task TE A DRI Code LING NPT '~ Start I Rig Rig Phase Spud Date: 1/30/2006 : 1/29/2006 End: 2/10/2006 Release: 2/10/2006 Number: 7ES Description of Operations 2/6/2006 22:00 - 22:30 0.50 CASE P RUNPRD Make up 7" float equipment, check floats, baker loc first three joint's 22:30 - 00:00 1.50 CASE P RUNPRD Run 7" 26# BTC-M, L-80 casing to 659'. Average make up torque 8500 foot pounds 2/7/2006 00:00 - 04:00 4.00 CASE P RUNPRD Run 7" 26# BTC-M, L-80 x TC-II casing to 3216' 04:00 - 05:00 1.00 CASE P RUNPRD Ciculate 1.5 times the 7" casing volume at the 9-5/8" casing shoe at 6 bbl /min 465 psi. Up wt 105k slack off 90k. Mud wt in 10.3 ppg /Out 10.3 ppg 05:00 - 14:00 9.00 CASE P RUNPRD Run 7" 26# L- 80 TC-II casing to 7393'. Filling each joint of casing on the fly and fill every 10 joints to the top with 10.3 ppg mud to 4130'. From 4130' to 6560' Circulate every 20 joints ran at 6 bbls a min and 530 psi. Mud wt in 10.3 ppg /Out 10.3 ppg. Up weight 190k, Slack off weight 130k. Lost a total of 12 bbls. Average make up torque for the 7" 26# L-80 TC-I 18800 foot pounds. Increase touque to 9300 fUlbs at 6500'. 14:00 - 14:30 0.50 CASE P RUNPRD Land 7" casing at 7424'. Lay down franks fill up tool. Make up cement head. Shoe Q 7424' Float collar @ 7340' 14:30 - 16:30 2.00 CEMT P RUNPRD Stage pumps up to 6 bbl /min, 610 psi. Up weight 225k, Slack off weight 145k. Lost 17 bbls while circulating 16:30 - 19:00 2.50 CEMT P RUNPRD PJSM - Test lines to 4000. Clear water from lines through Tee and pump 20 bbls mud push @ 11 ppg. Drop bottom plug. Pump 73 bbls. LiteCRETE lead cement C~3 12. ppg. Pump 45 bbls tail cement C 15.8 ppg. Drop top plug and pump 2.5 bbls of fresh water to clear cement from lines through Tee. Displace cement with sea water w/ rig pumps until plugs bump at 450 bbls. Pressure to 1450 psi and hold 5 minutes. Bleed off pressure and check floats. Floats held. CIP ~ 17:45 hrs. Good Returns during cement job. Reciprocate casing 20'. 19:00 - 20:30 1.50 CEMT P RUNPRD Blow down lines. Rig down casing equipment. Change out bails. Clean and clear floor of unnecessary tools. 20:30 - 22:30 2.00 WHSUR P RUNPRD Install FMC 7" pack off. Run in lock down screws and test to 5000 psi for 10 minutes 22:30 - 00:00 1.50 BOPSU P RUNPRD Function BOPE. Change out top pipe rams from 7" to 3-1/2" x 6" varibale rams 2/8/2006 00:00 - 01:00 1.00 BOPSU P RUNPRD Install test plug, test top pipe rams to 250 psi low 3500 psi high. Rig down test equipment and install wear ring. 01:00 -04:00 3.00 CASE P RUNPRD RIH with 4" drill pipe from the derrick Perform annular LOT with 10.3 ppg. EMW of 14.3 ppg. Pumped 3.3 bbl at 600 psi, Cleared 9-5/8" x 7" annulus with 110 bbls of 12.6 ppg drilling mud and freeze protected with 70 bbls of diesel at 2.3 bbl /min 425 psi. This was done out of the critical path. 04:00 - 11:30 7.50 CASE N RREP RUNPRD Trouble shoot pipe skate, Change out pipe handler shuttle valve 11:30 - 19:00 7.50 CASE P RUNPRD Lay down 4" drill pipe 19:00 - 19:30 0.50 BOPSU P RUNPRD Pull wear ring and rig up to test 7" casing 19:30 - 21:00 1.50 BOPSU P RUNPRD Test 7" casing to 3500 psi for 30 minutes. 21:00 - 23:00 2.00 BUNCO RUNCMP Make dummy run with hanger. Rig up casing equipment and Halliburton "1" wire spooling unit: 23:00 - 00:00 1.00 BUNCO RUNCMP Run 3-1/2" 9.2# IBT-M L-80 tubing with Halliburton "I" wire. Average make torque 2800 foot pounds 2/9/2006 00:00 - 06:00 6.00 BUNCO RUNCMP Run 3-1/2" 9.2#IBT-M L-80 tubing with Halliburton "I" wire. Ran two X- nipples below the S-3 packer and one X nipple above Printed: 2/13/2006 12:01:57 PM BP EXPLORATION Operations Summary Report Legal Welf Name: Z-108 Common Well Name: Z-108 Event Name: DRILL+COMPLETE Start: 1/29/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/10/2006 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To ', Hours ~ Task ;Code 2/9/2006 00:00 - 06:00 ~ 6.00 ~ RUNCOI~P 06:00 - 10:00 I 4.00 10:00 - 14:30 I 4.50 14:30 - 15:00 I 0.50 15:00 - 16:00 I 1.00 16:00 - 18:00 I 2.00 18:00 - 20:00 I 2.00 20:00 - 21:00 I 1.00 21:00 - 22:30 1.50 BOPSU P 22:30 - 00:00 1.50 WHSUR P 0/2006 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 05:00 2.00 WHSUR P 05:00 - 06:00 1.00 WHSUR P 06:00 - 06:30 0.50 WHSUR 06:30 - 07:00 0.50 WHSUR P 07:00 - 08:00 1.00 WHSUR P Page 6 of 7 Spud Date: 1/30/2006 End: 2/10/2006 NPT ; Phase Description of Operations RUNCMP the packer with 1 gas lift mandrel with a DCR valve set at 7060.95 and 5 gas lift mandrels dressed with MMG with dummy on K latch. Ran a total of 132 joints of 3-1/2" 9.2#IBT tubing. All connections below packer Baker Loc. Average make up torque 2800 foot pounds RUNCMP Change out 3-1/2" elevators to 4-4/2" elevators, change dies in casing tongs, RUNCMP Run 4-1/2" 12.6# L-80 IBT tubing. Ran a total of 65 joints of 4-1/2" 12.6# L80 IBT tubing. Average make up torque 3800 foot pounds. Ran 139 over the collar clamps on the 3-1/2" tubing. Ran 14 half clamps on the 3-1/2" tubing Ran 66 over the collar clamps on the 4-1/2" tubing Ran 2 half clamps on the 4-1/2" tubing Total clamps used for Halliburton "I" wire = 221 Final bottom pressure on "I" wire 2905 psi RUNCMP Make up tubing hanger and attach "I" wire to tubing hanger and test "I" wire to 5000 psi. Land hanger. Wire line entry guide settling depth 7181.26'. Up weight 100k, Slack off weight 80k RUNCMP Verify hanger set. Run in lock down screws. Rig up to reverse circulate, test lines to 3500 psi RUNCMP Reverse circulate 257 bbls of clean sea water at 3 bbl /min 300 psi RUNCMP Drop 1-5/16" ball and rod, allow ball to seat on X nipple. Pressure tubing to 3500 psi to set Baker S 3 packer, hold pressure for 30 minutes. Bleed tubing pressure down to 2000 psi. Pressure up tubing to 3500 psi for 30 minutes. Bleed off annulus pressure to 0, then bleed off tubing pressure to 0. Pressure up annulus and shear DCR valve at 2500 psi, Continue to pump 2 bbls to verify DCR valve sheared. Pump 2 bbls down the annulus at 98 gpm 425 psi to verify DCR valve sheared RUNCMP Rig down and blow down lines. Set and test TWC valve from below to 1000 psi. RUNCMP Nipple down BOPE and set back. RUNCMP Nipple up adapter flange RUNCMP Make up adapter flange. Terminate "I" wire. Final pressure 2930 psi at 7102'. Make up tree RUNCMP Test adapter flange and tree to 5000 psi for 10 minutes RUNCMP Rig up DSM lubricator and pull TWC valve RUNCMP Rig up and test lines to 2000 psi. Pump 109 bbls of freeze protect with Little Red Hot Oil Services at 2 bbl /min 800 psi. Final pressure 400psi RUNCMP Allow freeze protect to u-tube RUNCMP Suck lines back and rig down lines RUNCMP Install BPV with DSM and test from below to 1000 psi RUNCMP Remove secondary annulus valve and install V R plugs in 7" x 4-1/2" annuls valves. Secure tree, and install all valves and gauges. Printed: 2/13/2006 12:01:57 PM Printed: 2/13/2006 12:01:57 PM ~;,) c . ~ ~ ww w w ~®. ,;; ~~ ~- i ua purvey r~epvrt Report Date: 4-Feb-O6 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 177.130° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: Z-PAD / Z-108 TVD Reference Datum: Rotary Table Well: Z-108 TVD Reference Elevation: 82.22 ft relative to MSL Borehole: Z-108 Sea Bed /Ground Level Elevation: 54.00 ft relative to MSL UWI/API#: 500292329200 Magnetic Declination: 24.375° Survey Name /Date: Z-108 /February 3, 2006 Total Field Strength: 57580.982 nT Tort /AHD / DDI / ERD ratio: 74.557° / 2768.43 ft / 5.351 / 0.405 Magnetic Dip: 80.831 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 03, 2006 Location Latllong: N 7017 51.732, W 14911 50.925 Magnetic Declination Model: BGGM 2005 Location Grid N/E Y/X: N 5959100.200 ftUS, E 599099.160 ftUS North Reference: True North Grid Convergence Angle: +0.75554456° Total Corr Mag North -> True North: +24.375° Grid Scale Factor: 0.99991116 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n n n ft it n de 100 n ftUS ftUS hilt U.UU U.VU U.UU -tfL."L"L U.UU U.VV U.VU U.UU V.UV U.UU U.UU ~`J~`JIUV.ZU b`J`JV`J`J.10 IV /V I/ DI,/3L VV 14`J I I OV.yL~ GYD-GC-SS 98.00 0.32 308.23 15.78 98.00 -0.18 0.27 0.27 0.17 -0.21 0.33 5959100.37 599098.94 N 70 17 51.733 W 149 11 50.931 170.00 0.38 257.59 87.78 170.00 -0.27 0.69 0.65 0.24 -0.61 0.42 5959100.43 599098.55 N 70 17 51.734 W 149 11 50.942 260.00 1.37 206.06 177.77 259.99 0.72 1.99 1.58 -0.79 -1.37 1.30 5959099.39 599097.80 N 70 17 51.724 W 149 t 1 50.965 350.00 2.47 200.30 267.72 349.94 3.44 5.01 4.37 -3.57 -2.52 1.24 5959096.59 599096.69 N 70 17 51.696 W 14911 50.998 440.00 4.08 192.05 357.57 439.79 8.32 10.14 9.36 -8.52 -3.86 1.86 5959091.63 599095.42 N 70 17 51.648 W 149 11 51.037 531.00 4.95 189.27 448.28 530.50 15.29 17.30 16.40 -15.56 -5.17 0.99 5959084.57 599094.20 N 70 17 51.579 W 149 11 51.075 621.00 5.93 184.50 537.88 620.10 23.69 25.83 24.81 -24.03 -6.16 1.20 5959076.09 599093.32 N 70 17 51.495 W 149 11 51.104 Last GYD-GC-SS 709.00 8.58 180.78 625.17 707.39 34.76 36.94 35.74 -35.13 -6.60 3.06 5959064.99 599093.02 N 70 17 51.386 W 149 11 51.117 First MWD+IFR+MS 824.86 11.63 179.85 739.21 821.43 55.05 57.26 55.86 -55.45 -6.69 2.64 5959044.67 599093.20 N 70 17 51.186 W 149 11 51.120 918.93 14.13 182.63 830.91 913.13 75.95 78.23 76.75 -76.41 -7.19 2.74 5959023.71 599092.98 N 70 17 50.980 W 149 11 4 1010.95 17.38 183.55 919.46 1001.68 100.80 103.21 101.71 -101.35 -8.56 3.54 5958998.75 599091.94 N 70 17 50.735 W 149 11 1105.39 19.32 184.14 1009.10 1091.32 130.32 132.94 131.44 -131.02 -10.56 2.06 5958969.07 599090.33 N 70 17 50.443 W 149 11 5.33 1206.46 22.14 181.23 1103.62 1185.84 165.92 168.70 167.19 -166.74 -12.18 2.97 5958933.33 599089.19 N 7017 50.092 W 149 11 51.280 1301.61 24.21 180.71 1191.08 1273.30 203.28 206.15 204.58 -204.18 -12.80 2.19 5958895.89 599089.05 N 70 17 49.724 W 149 11 51.298 1398.47 26.81 180.73 1278.49 1360.71 244.91 247.86 246.25 -245.89 -13.33 2.68 5958854.18 599089.08 N 70 17 49.313 W 149 11 51.313 1489.61 27.76 182.41 1359.49 1441.71 286.56 289.64 288.01 -287.65 -14.48 1.34 5958812.41 599088.47 N 70 17 48.903 W 149 11 51.347 1585.90 27.64 183.42 1444.75 1526.97 331.09 334.39 332.77 -332.35 -16.76 0.50 5958767.69 599086.79 N 70 17 48.463 W 14911 51.413 1686.80 27.63 183.47 1534.14 1616.36 377.61 381.20 379.57 -379.06 -19.57 0.03 5958720.95 599084.59 N 70 17 48.004 W 149 11 51.495 1783.02 27.77 183.94 1619.33 1701.55 422.04 425.92 424.29 -423.70 -22.46 0.27 5958676.28 599082.29 N 70 17 47.565 W 149 11 51.579 1874.85 27.42 184.35 1700.71 1782.93 464.26 468.46 466.82 -466.12 -25.53 0.43 5958633.82 599079.78 N 70 17 47.147 W 149 11 51.669 1969.97 26.22 184.77 1785.60 1867.82 506.82 511.38 509.73 -508.90 -28.94 1.28 5958591.01 599076.93 N 70 17 46.727 W 149 11 51.768 2065.08 26.75 184.10 1870.73 1952.95 548.89 553.79 552.13 -551.19 -32.22 0.64 5958548.68 599074.21 N 70 17 46.311 W 149 11 51.864 SurveyEditor Ver SP 1.0 Bld( doc40x_56) Z-108~Z-108~Z-108~Z-108 Generated 5/17/2006 3:42 PM Page 1 of 3 Comments Measured Inclination Azimuth. Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft tt ft de 100 ft ftUS ftUS 'L1d1.y5 Lb. ti/ liiL. ;Sti 1`JS/ .Lti LU:i`J.425 5yl.lif by/.;i:S 2257.87 28. 82 181. 03 2042 .15 2124.37 636.69 641.98 2353.68 28. 88 180. 60 2126 .07 2208.29 682.82 688.21 2449.81 28. 29 182. 43 2210. 48 2292.70 728.67 734.20 2546.13 27. 82 182 .28 2295 .48 2377.70 773.79 779.50 2641.11 27. 60 182 .27 2379 .57 2461.79 817.77 823.67 2736.73 27. 08 182. 08 2464 .51 2546.73 861.52 867.58 2829.23 26. 28 181. 61 2547 .16 2629.38 902.91 909.11 2926.62 27. 46 183. 33 2634 .04 2716.26 946.73 953.13 3023.97 27. 17 183. 51 2720 .53 2802.75 991.13 997.80 3119.72 26. 91 183. 22 2805. 81 2888.03 1034.41 1041.33 3194.56 26. 61 183. 74 2872. 64 2954.86 1067.90 1075.03 3328.53 26. 87 183. 17 2992. 28 3074.50 1127.81 1135.30 3424.46 26. 78 183. 71 3077. 89 3160.11 1170.83 1178.59 3520.42 26. 53 183 .96 3163 .65 3245.87 1213.59 1221.64 3616.21 26. 48 183 .83 3249 .37 3331.59 1256.04 1264.39 3711.33 26. 53 183 .31 3334 .50 3416.72 1298.22 1306.84 3807.41 26. 17 184. 84 3420 .59 3502.81 1340.55 1349.48 3902.98 25. 95 185. 04 3506. 45 3588.67 1382.15 1391.47 4000.26 25. 82 185. 36 3593. 97 3676.19 1424.20 1433.94 4097.20 26. 16 185. 54 3681. 10 3763.32 1466.23 1476.42 4195.06 25. 67 186. 01 3769. 12 3851.34 1508.51 1519.19 4291.52 26. 33 185. 62 3855. 82 3938.04 1550.31 1561.47 4387.47 26. 49 185. 33 3941. 76 4023.98 1592.54 1604.15 4482.97 26. 57 185. 36 4027 .20 4109.42 1634.76 1646.81 4576.54 27. 41 186 .89 4110 .58 4192.80 1676.69 1689.27 4673.44 27. 61 184 .01 4196 .53 4278.75 1720.97 1734.02 4769.84 25. 85 180 .74 4282 .63 4364.85 1764.13 1777.37 4865.02 26. 27 180. 50 4368 .13 4450.35 1805.86 1819.18 4960.38 25. 76 177. 88 4453 .83 4536.05 1847.65 1861.00 5056.44 25. 52 171. 46 4540 .45 4622.67 1889.12 1902.53 5150.85 24. 01 170. 22 4626 .17 4708.39 1928.43 1942.08 5246.61 24.78 165.81 4713.39 4795.61 5340.92 24.30 163.27 4799.18 4881.40 5436.88 25.06 162.13 4886.38 4968.60 5532.28 24.15 164.35 4973.12 5055.34 5627.98 23.08 164.10 5060.80 5143.02 5724.21 23.32 163.18 5149.25 5231.47 5819.18 23.39 162.12 5236.44 5318.66 5914.26 23.94 161.48 5323.52 5405.74 6010.62 23.20 164.53 5411.85 5494.07 byb.b/ -5y4.bb 640.30 -639.29 686.49 -685.51 732.46 -731.49 777.76 -776.75 821.93 -820.88 865.84 -864.76 907.36 -906.27 951.38 -950.25 996.05 -994.84 1039.57 -1038.29 1073.27 -1071.93 1133.54 -1132.09 1176.83 -1175.31 1219.87 -1218.26 1262.62 -1260.91 1305.06 -1303.28 1347.70 -1345.81 1389.66 -1387.64 1432.10 -1429.93 1474.55 -1472.22 1517.28 -1514.77 1559.52 -1556.84 1602.17 -1599.32 1644.80 -1641.79 1687.22 -1684.01 1731.94 -1728.56 1775.28 -1771.86 1817.04 -1813.67 1858.74 -1855.48 1899.78 -1896.82 1938.43 -1935.86 -34. tl / -35.98 -36.63 -37.84 -39.70 -41.46 -43.12 -44.46 -46.37 -49.04 -51.59 -53.64 -57.27 -59.87 -62.75 -65.65 -68.29 -71.32 -74.93 -78.78 -82.82 -87.12 -91.40 -95.47 -99.45 103.99 108.23 110.07 110.52 109.94 106.09 -99.81 1967.45 1981.61 1976.64 -1974 .52 -91.58 2005 .68 2020.78 2013.90 -2012 .26 -81.15 2044 .48 2060.84 2051.68 -2050 .51 -69.23 2083 .03 2100.56 2089.34 -2088 .54 -57.76 2120 .39 2138.90 2125.96 -2125 .43 -47.34 2157 .26 2176.80 2162.11 -2161 .80 -36.66 2193 .71 2214.45 2197.88 -2197 .74 -25.43 2230 .51 2252.62 2234.03 -2233 .99 -13.51 2267 .86 2291.14 2270.82 -2270 .82 -2.24 U.tfl bybt55U5.1y SyyU/L.J3 IV /V 1 / 45.tStSJ VV 14y 11 51.yi5 2.33 5958460.55 599071.62 N 7017 45.444 W 149 11 51.973 0.23 5958414.33 599071.57 N 70 17 44.990 W 149 11 51.993 1.10 5958368.34 599070.97 N 70 17 44.537 W 149 11 52.028 0.49 5958323.07 599069.70 N 70 17 44.092 W 149 11 52.082 0.23 5958278.92 599068.53 N 70 17 43.658 W 149 11 52.133 0.55 5958235.02 599067.45 N 70 17 43.227 W 149 11 52.182 0.89 5958193.50 599066.65 N 70 17 42.818 W 149 11 52.221 1.45 5958149.51 599065.32 N 70 17 42.386 W 14911 52.276 0.31 5958104.89 599063.25 N 70 17 41.947 W 149 t 1 52.354 0.30 5958061.41 599061.27 N 70 17 41.520 W 149 11 0.51 5958027.76 599059.66 N 70 17 41.189 W 149 11 0.27 5957967.55 599056.83 N 70 17 40.598 W 149 11 52.594 0.27 5957924.31 599054.80 N 70 17 40.173 W 14911 52.670 0.29 5957881.33 599052.49 N 70 17 39.750 W 149 11 52.754 0.08 5957838.65 599050.15 N 70 17 39.331 W 149 11 52.838 0.25 5957796.26 599048.06 N 70 17 38.914 W 149 11 52.915 0.80 5957753.69 599045.60 N 70 17 38.496 W 14911 53.003 0.25 5957711.82 599042.53 N 70 17 38.084 W 149 11 53.109 0.20 5957669.48 599039.24 N 70 17 37.668 W 149 11 53.221 0.36 5957627.15 599035.77 N 70 17 37.252 W 149 11 53.338 0.54 5957584.55 599032.03 N 70 17 36.834 W 149 11 53.464 0.71 5957542.43 599028.30 N 70 17 36.420 W 149 11 53.589 0.21 5957499.90 599024.79 N 7017 36.002 W 149 11 53.707 0.08 5957457.39 599021.38 N 70 17 35.585 W 149 11 53.823 1.16 5957415.11 599017.40 N 70 17 35.169 W 149 11 53.955 1.39 5957370.52 599013.74 N 70 17 34.731 W 149 11 54.079 2.38 5957327.20 599012.48 N 70 17 34.305 W 149 11 5 32 0.45 5957285.39 599012.57 N 7017 33.894 W 149 t 1 1.32 5957243.60 599013.71 N 70 17 33.483 W 149 11 9 2.90 5957202.32 599018.10 N 70 17 33.077 W 14911 54.017 1.69 5957163.37 599024.90 N 70 17 32.693 W 149 11 53.833 2.06 5957124.83 599033.63 N 70 17 32.312 W 149 11 53.594 1.23 5957087.23 599044.56 N 70 17 31.941 W 149 11 53.290 0.93 5957049.14 599056.98 N 70 17 31.565 W 149 11 52.942 1.36 5957011.27 599068.95 N 70 17 31.191 W 149 11 52.608 1.12 5956974.52 599079.85 N 70 17 30.828 W 14911 52.304 0.45 5956938.30 599091.01 N 70 17 30.470 W 149 11 51.993 0.45 5956902.52 599102.71 N 70 17 30.117 W 149 11 51.666 0.64 5956866.43 599115.10 N 70 17 29.760 W 149 11 51.319 1.48 5956829.75 599126.86 N 70 17 29.398 W 149 11 50.990 SurveyEditor Ver SP 1.0 Bld( doc40x_56) Z-108~Z-108~Z-10812-108 Generated 5/17/2006 3:42 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS tilU(i.y4 L3.Lif lli3.y5 55UU.35 b5ti'L.b/ 'L:iU4.`Jl L:iL`J.15 "L:SU/.41 -'C3V/.4U tl.UtS U.L5 by5b/y:i.:iL 6202.34 23.10 163.89 5588.04 5670.26 2341.48 2366.71 2343.57 -2343.50 18.49 0.19 5956757.36 6297.22 22.76 164.05 5675.43 5757.65 2377.48 2403.68 2379.20 -2379.02 28.70 0.36 5956721.98 6394.34 21.97 163.32 5765.24 5847.46 2413.42 2440.63 2414.81 -2414.49 39.07 0.86 5956686.65 6488.81 21.48 164.10 5853.00 5935.22 2447.43 2475.60 2448.54 -2448.05 48.88 0.60 5956653.23 6584.75 21.28 164.77 5942.34 6024.56 2481.55 2510.57 2482.43 -2481.75 58.27 0.33 5956619.66 6679.89 21.12 163.79 6031.04 6113.26 2515.09 2544.98 2515.77 -2514.86 67.59 0.41 5956586.67 6775.38 19.96 163.78 6120.46 6202.68 2547.69 2578.48 2548.20 -2547.03 76.95 1.21 5956554.63 6871.37 19.46 164.99 6210.82 6293.04 2579.26 2610.85 2579.63 -2578.21 85.66 0.67 5956523.58 6967.09 17.78 165.49 6301.53 6383.75 2609.17 2641.42 2609.43 -2607.76 93.45 1.76 5956494.14 7063.16 16.94 166.62 6393.22 6475.44 2637.30 2670.08 2637.49 -2635.58 100.37 0.94 5956466.41 7159.53 15.68 168.10 6485.71 6567.93 2663.96 2697.14 2664.10 -2661.98 106.30 1.38 5956440.09 7255.38 15.21 167.57 6578.10 6660.32 2689.15 2722.67 268925 -2686.93 111.68 0.51 5956415.22 7351.27 15.09 167.41 6670.66 6752.88 2713.86 2747.73 2713.93 -2711.40 117.11 0.13 5956390.83 Last MWD+IFR+MS 7370.90 14.83 167.30 6689.63 6771.85 2718.86 2752.79 2718.91 -2716.34 118.22 1.33 5956385.90 TD (Projected) 7432.00 14.83 167.30 6748.69 6830.91 2734.26 2768.43 2734.31 -2731.60 121.66 0.00 5956370.69 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata - gyro single shots -- Gyrodata gy ro orientation surveys. Not to be run above 70 degrees incl ination. ) MWD +IFR + MS - (In-field referenced MWD with mull-stat ion analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4305 FSL 3578 FEL S19 T11 N R12E UM 5959100.20 599099.16 BHL : 1573 FSL 3468 FEL S19 T11 N R12E UM 5956370.69 599256.81 5yy1J/.b/ IV /U 1 / Ly.V:iC W 14tl 11 bU.titSy 599148.54 N 70 17 28:683 W 149 11 50.386 599159.22 N 70 17 28.334 W 149 11 50.089 599170.06 N 70 17 27.985 W 149 11 49.786 599180.31 N 70 17 27.655 W 149 11 49.500 599190.14 N 70 17 27.324 W 149 11 49.227 599199.90 N 70 17 26.998 W 149 11 48.955 599209.68 N 70 17 26.682 W 149 11 48.683 599218.80 N 70 17 26.375 W 149 11 48.429 599226.98 N 70 17 26.084 W 149 11 48.202 599234.26 N 70 17 25.811 W 149 11 0 599240.54 N 70 17 25.551 W 149 11 4 . 7 599246.25 N 70 17 25.306 W 149 11 47.670 599252.00 N 70 17 25.065 W 149 11 47.512 599253.17 N 70 17 25.017 W 149 11 47.480. 599256.81 N 70 17 24.867 W 149 11 47.380 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) Z-108~Z-108~Z-108~Z-108 Generated 5/17/2006 3:42 PM Page 3 of 3 • • Well: Z-108 Accept: 01/29/06 Field: Prudhoe Bay Unit Spud: 01/30/06 API: 50-029-23292-00 Release: 02/10/06 Permit: 205-201 Ria: Nabors 7ES PRE-RIG WORK 05/29/06 PULLED BALL AND ROD AT 7153' SLM. PULL DCR SHEAR VALVE IN STA #1. PULLED DGLV'S IN STA'S #5 AND #6. 05/30/06 SET GENERIC GLV (1500#, 1/4" PORT) IN STA #6. SET OGLV (5/16" PORT) IN STA #5. SET DGLV IN STA #1. PULL RHC PLUG BODY AT 7159' SLM. DRIFTED W/2.5 DUMMY GUN, TEL, SAMPLE BAILER TO 7340' CORRECTED (NO PERFS) -SMALL AMOUNT OF FILL IN BAILER. TURN WELL OVER TO DSO -LEFT WELL SHUT IN. 06/04/06 LOGGED TWO SCMT PASSES AT 30 FPM FROM TD TO TUBING TAIL. FOUND GOOD CEMENT ABOVE PERF INTERVAL AND SPOTTY CEMENT BELOW. CALLED TOWN AND DECISION WAS MADE TO POSTPONE PERF OPERATION UNTIL SCMT DATA WAS REVIEWED, LEAVING UNIT ON LOCATION IN CASE DECISION IS MADE TO PERF TOMORROW MORNING. SCMT PASSES UPLOADED TO INTERACT. 06/05/06 PERFORATION -INTERVAL 7232' - 7257' 2506 MIX PJ-OMEGA/PF HMX, 6 SPF, 60 DEG. PAD OP NOTIFIED UPON DEPARTURE. RDMO. NOTIFIED PAD OPERATOR TO POP WELL. JOB COMPLETE! 06/08/06 T/I/0=1300/1740/0 (HOT DIESEL DOWN TBG -POSSIBLE PLUG) SPEAR IN WITH 5 BBLS NEET METH., FOLLOWED BY 60 BBLS 180° DIESEL. FWHP'S=2100/1700/420. 06/10/06 T/I/O = 1710/1710/160. TEMP = SI. IA FL (FO REQUEST). IA FLAT 3080' (BETWEEN STA #6 AND #5). TREE = CMJ 4-1/16 5M WELLHEAD = FMC ACTUATOR = I KB. ELEV = 82.5' I BF. ELEV -~ 54 KOP - 400' 'Max Angle = 29 @ 2354' Datum MD - _ - ???? ~~~~ NOTES: CHROME NIPPLES & GLV XO TS z-cos Datum TV D - .. SS ~ 20" CONDUCTER ~-~ 10; 4-1/2" TBG, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 2767 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" ~- j 3248• 7" CSG, 28#, L-80 TCII, ID = 8.278" 4607 Minimum ID = 2.813" @ 7081' 3-1/2" HES X NIPPLE ~3-1/2" TBG, 9.2#, L-801ST, .0087 bpf, ID=2.992" ~-i 7181 PERFORATION SUMMARY REF LOG: XXXXXX ON DDIMMtYY ANGLE AT TOP PERF: 15 r~ 7232' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 8 7232 - 7257 O 08/05/08 PBTD - j 7340' 7" CSG, 28#, L-80 BTC-M, ID = 8.278" 7424' 2338 - i4-1/2" HES X NIP, ID = 3.813" 2767 4-1/2" X 3-112" XO, ID = 3.958" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 6 2821 2722 26 MMG DOME RK 16 05/30!06 5 3812 3507 26 MMG SO RK 20 05130/06 4 5266 4813 25 MMG DMY RK 0 02/08/06 3 6009 5492 23 MMG DMY RK 0 02/08/08 2 6655 6090 21 MMG DMY RK 0 02/08/06 1 7052 8465 17 MMG DMY RK 0 05/30/06 7~ 081' I-j 3-1 /2" HES X NIP, ID = 2.813" 7102 3-1/2" HES GAUGE CARRIER, ID = 2.992" ~wlCABLETO SURFACE IN IA 7121' 3-1/2" X 4-1/2" XO, ID = 2.980" 7123' 7" X 4-112" BKR S3 PKR, ID = 3.870" 7127' 4-1/2" X 3-1/2" XO, ID = 2.980" 714$' 3-112" HES X NIP, ID = 2.813" 7169' - 3-1/2" HES X NIP, ID = 2.813" 7177' - 7" MARKER JT w /RR TAG 71$1' 3-1/2" WLEG, ID = 2.992" ~~ ELMDTTLOGNOTAVAILABLE 7r 279' 7" MARKER JT w 1RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 02111!06 N7ES ORIGINAL COMPLETION 02/25!08 RWL/TLH DRLG DRAFT CORRECTIONS 05!30/08 DAV/PJC GLV C/O 08/05/08 RRD/PAG PERF BOREALIS UNIT WELL: Z-108 PERMff No: 2052010 API No: 50-029-23292-00 SEC 19, T11 N, R12E, 4305' FSL, 3578' FEL BP Exploration (Alaska) N C v'I ~`-~ G SCHLUMBERGER Survey report Client ...................: BP Exploration Alaska, Inc. Field ....................: Borealis well .....................: Z-108 API number ...............: 50-029-23292-00 Engineer .................: F. Medina Rig :.....................: Nabors 7ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent........ DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 54.0 ft N/A Top Drive 82.22 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 177.13 degrees [(0)2006 IDEAL ID10_2C_O1J Spud date ................: 30-Jan-06 Last survey date.........: 04-Feb-06 Total accepted surveys...: 80 MD of first survey.......: 0.00 ft MD of last survey........: 7432.00 ft 4-Feb-2006 17:11:23 Page 1 of 4 • ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 31-Jan-2006 Magnetic field strength..: 1151.62 HCNT Magnetic dec (+E/W-).....: 24.38 degrees Magnetic dip .............: 80.83 degrees ---- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G ..............: H ............... Dip ............. of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 meal 1151.62 HCNT 80.83 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.38 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.38 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 4-Feb-2006 17:11:23 Page 2 of 4 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) -------- (deg) ------- 100f) ----- - type (deg) ---- ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 -------- 0.00 -------- 0.00 -------- 0.00 -------- 0.00 ------- 0.00 ----- 0.00 - ---- ------ TIP None 2 98.00 0.32 308.23 98.00 98.00 -0.18 0.17 -0.21 0.27 308.23 0.33 BP _GYD SS 3 170.00 0.38 257.59 72.00 170.00 -0.27 0.24 -0.61 0.65 291.80 0.42 BP _GYD SS 4 260.00 1.37 206.03 90.00 259.99 0.72 -0.79 -1.37 1.58 240.07 1.30 BP _GYD SS 5 350.00 2.47 200.30 90.00 349.94 3.44 -3.57 -2.51 4.37 215.13 1.24 BP GYD SS 6 440.00 4.08 192.05 90.00 439.79 8.32 -8.52 -3.86 9.36 204.34 1.86 BP _GYD SS 7 531.00 4.95 189.27 91.00 530.50 15.29 -15.57 -5.16 16.40 198.36 0.99 BP - GYD SS • 8 621.00 5.93 184.50 90.00 620.10 23.69 -24.03 -6.15 24.81 194.36 1.20 BP _GYD SS 9 709.00 8.58 180.78 88.00 707.39 34.76 -35.13 -6.60 35.74 190.64 3.06 BP _GYD SS 10 824.86 11.63 179.85 115.86 821.43 55.05 -55.45 -6.69 55.86 186.88 2.64 BP MWD+IFR+MS 11 918.93 14.13 182.63 94.07 913.13 75.95 -76.41 -7.19 76.75 185.38 2.74 BP _MWD+IFR+MS 12 1010.95 17.38 183.55 92.02 1001.68 100.80 -101.35 -8.56 101.72 184.83 3.54 BP _MWD+IFR+MS 13 1105.39 19.32 184.14 94.44 1091.32 130.32 -131.02 -10.56 131.44 184.61 2.06 BP _MWD+IFR+MS 14 1206.46 22.14 181.23 101.07 1185.84 165.92 -166.74 -12.17 167.19 184.18 2.97 BP _MWD+IFR+MS 15 1301.61 24.21 180.71 95.15 1273.30 203.28 -204.18 -12.80 204.58 183.59 2.19 BP MWD+IFR+MS 16 1398.47 26.81 180.73 96.86 1360.71 244.91 -245.89 -13.33 246.25 183.10 2.68 BP _MWD+IFR+MS 17 1489.61 27.76 182.41 91.14 1441.71 286.56 -287.65 -14.48 288.01 182.88 1.34 BP _MWD+IFR+MS 18 1585.90 27.64 183.42 96.29 1526.97 331.09 -332.35 -16.76 332.77 182.89 0.50 BP _MWD+IFR+MS 19 1686.80 27.63 183.47 100.90 1616.36 377.61 -379.06 -19.57 379.57 182.96 0.03 BP _MWD+IFR+MS 20 1783.02 27.77 183.94 96.22 1701.55 422.04 -423.70 -22.46 424.29 183.03 0.27 BP MWD+IFR+MS 21 1874.85 27.42 184.35 91.83 1782.93 464.26 -466.12 -25.53 466.82 183.14 0.43 BP _MWD+IFR+MS • 22 1969.97 26.22 184.77 95.12 1867.82 506.82 -508.90 -28.94 509.73 183.25 1.28 BP _MWD+IFR+MS 23 2065.08 26.75 184.10 95.11 1952.95 548.89 -551.19 -32.22 552.13 183.35 0.64 BP _MWD+IFR+MS 24 2161.95 26.67 182.36 96.87 2039.48 592.18 -594.66 -34.67 595.67 183.34 0.81 BP _MWD+IFR+MS 25 2257.87 28.82 181.03 95.92 2124.37 636.69 -639.29 -35.97 640.30 183.22 2.33 BP MWD+IFR+MS 26 2353.68 28.88 180.60 95.81 2208.29 682.82 -685.51 -36.63 686.49 183.06 0.23 BP _MWD+IFR+MS 27 2449.81 28.29 182.43 96.13 2292.70 728.68 -731.49 -37.84 732.47 182.96 1.10 BP _MWD+IFR+MS 28 2546.13 27.82 182.28 96.32 2377.70 773.79 -776.75 -39.70 777.76 182.93 0.49 BP _MWD+IFR+MS 29 2641.11 27.60 182.27 94.98 2461.79 817.78 -820.88 -41.46 821.93 182.89 0.23 BP _MWD+IFR+MS 30 2736.73 27.08 182.08 95.62 2546.73 861.52 -864.76 -43.12 865.84 182.85 0.55 BP MWD+IFR+MS [(0)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 4-Feb-2006 17:11:23 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2829.23 26.28 181.61 92.50 2629.38 902.91 -906.27 -44.46 907.36 182.81 0.89 BP _MWD+IFR+MS 32 2926.62 27.46 183.33 97.39 2716.26 946.73 -950.25 -46.37 951.38 182.79 1.45 BP _MWD+IFR+MS 33 3023.97 27.17 183.51 97.35 2802.75 991.13 -994.84 -49.04 996.05 182.82 0.31 BP _MWD+IFR+MS 34 3119.72 26.91 183.22 95.75 2888.03 1034.41 -1038.29 -51.59 1039.57 182.84 0.30 BP _MWD+IFR+MS 35 3194.56 26.61 183.74 74.84 2954.86 1067.90 -1071.93 -53.64 1073.27 182.86 0.51 BP MWD+IFR+MS 36 3328.53 26.87 183.17 133.97 3074.50 1127.81 -1132.10 -57.27 1133.54 182.90 0.27 BP MWD+IFR+MS 37 3424.46 26.78 183.71 95.93 3160.11 1170.83 -1175.31 -59.87 1176.83 182.92 0.27 BP - MWD+IFR+MS • 38 3520.42 26.53 183.96 95.96 3245.87 1213.59 -1218.26 -62.74 1219.87 182.95 0.29 BP _MWD+IFR+MS 39 3616.21 26.48 183.83 95.79 3331.59 1256.04 -1260.91 -65.65 1262.62 182.98 0.08 BP _MWD+IFR+MS 40 3711.33 26.53 183.31 95.12 3416.72 1298.22 -1303.28 -68.29 1305.06 183.00 0.25 BP MWD+IFR+MS 41 3807.41 26.17 184.84 96.08 3502.81 1340.55 -1345.81 -71.32 1347.70 183.03 0.80 BP _MWD+IFR+MS 42 3902.98 25.95 185.04 95.57 3588.67 1382.15 -1387.64 -74.93 1389.66 183.09 0.25 BP .MWD+IFR+MS 43 4000.26 25.82 185.36 97.28 3676.19 1424.20 -1429.93 -78.78 1432.10 183.15 0.20 BP _MWD+IFR+MS 44 4097.20 26.16 185.54 96.94 3763.32 1466.23 -1472.22 -82.82 1474.55 183.22 0.36 BP _MWD+IFR+MS 45 4195.06 25.67 186.01 97.86 3851.34 1508.51 -1514.77 -87.12 1517.28 183.29 0.54 BP MWD+IFR+MS 46 4291.52 26.33 185.62 96.46 3938.04 1550.31 -1556.84 -91.40 1559.52 183.36 0.71 BP _MWD+IFR+MS 47 4387.47 26.49 185.33 95.95 4023.98 1592.54 -1599.32 -95.47 1602.17 183.42 0.21 BP _MWD+IFR+MS 48 4482.97 26.57 185.36 95.50 4109.42 1634.76 -1641.80 -99.45 1644.80 183.47 0.08 BP _MWD+IFR+MS 49 4576.54 27.41 186.89 93.57 4192.80 1676.69 -1684.01 -103.99 1687.22 183.53 1.16 BP _MWD+IFR+MS 50 4673.44 27.61 184.01 96.90 4278.75 1720.97 -1728.56 -108.23 1731.94 183.58 1.39 BP MWD+IFR+MS 51 4769.84 25.85 180.74 96.40 4364.85 1764.13 -1771.86 -110.07 1775.28 183.55 2.38 BP _MWD+IFR+MS • 52 4865.02 26.27 180.50 95.18 4450.35 1805.86 -1813.67 -110.52 1817.04 183.49 0.45 BP _MWD+IFR+MS 53 4960.38 25.76 177.88 95.36 4536.05 1847.65 -1855.48 -109.94 1858.74 183.39 1.32 BP _MWD+IFR+MS 54 5056.44 25.52 171.46 96.06 4622.67 1889.12 -1896.82 -106.09 1899.78 183.20 2.90 BP _MWD+IFR+MS 55 5150.85 24.01 170.22 94.41 4708.39 1928.43 -1935.86 -99.81 1938.43 182.95 1.69 BP MWD+IFR+MS 56 5246.61 24.78 165.81 95.76 4795.61 1967.45 -1974.52 -91.58 1976.64 182.66 2.06 BP _MWD+IFR+MS 57 5340.92 24.30 163.27 94.31 4881.40 2005.68 -2012.26 -81.15 2013.90 182.31 1.23 BP _MWD+IFR+MS 58 5436.88 25.06 162.13 95.96 4968.60 2044.48 -2050.51 -69.23 2051.68 181.93 0.93 BP _MWD+IFR+MS 59 5532.28 24.15 164.35 95.40 5055.34 2083.03 -2088.54 -57.76 2089.34 181.58 1.36 BP _MWD+IFR+MS 60 5627.98 23.08 164.10 95.70 5143.02 2120.39 -2125.43 -47.34 2125.96 181.28 1.12 BP MWD+IFR+MS [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 4-Feb-2006 17:11:23 Page 4 of 4 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) --------- (ft) ------- (ft) -------- (deg) ------- 100f) ----- - type (deg) ---- ------ --- 61 -------- 5724.21 ------ 23.32 ------- 163.18 ------ 96.23 -------- 5231.47 -------- 2157.26 --------- -2161.80 ------- -36.66 -------- 2162.11 ------- 180.97 ----- 0.45 - BP ---- ------ _MWD+IFR+MS 62 5819.18 23.39 162.12 94.97 5318.66 2193.71 -2197.74 -25.43 2197.88 180.66 0.45 BP _MWD+IFR+MS 63 5914.26 23.94 161.48 95.08 5405.74 2230.51 -2233.99 -13.51 2234.03 180.35 0.64 BP _MWD+IFR+MS 64 6010.62 23.20 164.53 96.36 5494.07 2267.86 -2270.82 -2.24 2270.82 180.06 1.48 BP _MWD+IFR+MS 65 6106.94 23.28 163.95 96.32 5582.57 2304.91 -2307.40 8.08 2307.41 179.80 0.25 BP MWD+IFR+MS 66 6202.34 23.10 163.89 95.40 5670.26 2341.48 -2343.50 18.49 2343.57 179.55 0.19 BP _MWD+IFR+MS 67 6297.22 22.76 164.05 94.88 5757.65 2377.48 -2379.02 28.70 2379.20 179.31 0.36 BP - MWD+IFR+MS 68 6394.34 21.97 163.32 97.12 5847.46 2413.42 -2414.49 39.07 2414.81 179.07 0.86 BP _MWD+IFR+MS 69 6488.81 21.48 164.10 94.47 5935.22 2447.43 -2448.05 48.89 2448.54 178.86 0.60 BP _MWD+IFR+MS 70 6584.75 21.28 164.77 95.94 6024.56 2481.55 -2481.75 58.27 2482.43 178.65 0.33 BP MWD+IFR+MS 71 6679.89 21.12 163.79 95.14 6113.26 2515.09 -2514.86 67.59 2515.77 178.46 0.41 BP _MWD+IFR+MS 72 6775.38 19.96 163.78 95.49 6202.68 2547.69 -2547.03 76.95 2548.20 178.27 1.21 BP _MWD+IFR+MS 73 6871.37 19.46 164.99 95.99 6293.04 2579.27 -2578.21 85.66 2579.63 178.10 0.67 BP _MWD+IFR+MS 74 6967.09 17.78 165.49 95.72 6383.75 2609.17 -2607.76 93.46 2609.44 177.95 1.76 BP _MWD+IFR+MS 75 7063.16 16.94 166.62 96.07 6475.44 2637.30 -2635.58 100.37 2637.49 177.82 0.94 BP MWD+IFR+MS 76 7159.53 15.68 168.10 96.37 6567.93 2663.96 -2661.98 10.6.30 2664.10 177.71 1.38 BP _MWD+IFR+MS 77 7255.38 15.21 167.57 95.85 6660.32 2689.16 -2686.93 111.68 2689.25 177.62 0.51 BP _MWD+IFR+MS 78 7351.27 15.09 167.41 95.89 6752.88 2713.86 -2711.40 117.11 2713.93 177.53 0.13 BP _MWD+IFR+MS 79 7370.90 14.83 167.30 19.63 6771.84 2718.86 -2716.34 118.22 2718.91 177.51 1.33 BP MWD+IFR+MS 80 7432.00 14.83 167.30 61.10 6830.91 2734.26 -2731.60 121.66 2734.31 177.45 0.00 Projection to TD • [(c)2006 IDEAL ID10 2C O1] ., ij~ r .i /J Sn~erg~ ~ ~-~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2938 ATTN: Beth Well Job # Log Description NO. 3838 Company: Alaska Oil ti Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, SuHe 700 Anchorage, AK 99501 Field: Orion Borealis Date BL Color CD L-200L$ 40010090 OH LDWG EDIT OF MWDILWD 02118/04 2 7 Z-108•- 11225977 SCMT 06/04/06 1 L-214A 11217230 USIT 03/16/06 1 L-215 10913049 USIT 09/26/05 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-7 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~~ / t" • ~ ~ ?@~,/' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN, Beth ~ ~ Received by: 1 ~ ~°"°°'~'- ~CEIV~.D 1lUN ~_ 4 7.OOfi ~ ~ Gi! & Gas Eons. Commission anchorage 06/09/06 • • STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Suprv~~ Z~J7~a; ~ ~ t~ ~ -~_ ~ (,~~ BOPE Test Report Comm Contractor/Rig No.: Nabors 7ES „PTDt#: 2052010 DATE: 2/2/2006 Inspector Lou Grimaldi =Insp Source;' '' Operator: BP EXPLORATION (ALASKA) INC Operator Rep: Lance Vaughn Rig Rep: Larry Wurdeman ', Inspector Type Operation. DRILL Rams. Annular: Valves. Inspection No: bopLG06020214260~ Type Test: INIT 3 ; Test Pressure: 250/3500 250/300 250/3500 ~ Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P P System Pressure 3000 P Housekeeping: P Pit Level Indicators P P ~ Pressure After Closure 1550 P PTD On Location P Flow Indicator P P 200 PSI Attained :16 P Standing Order Posted P Meth Gas Detector P P ;Full Pressure Attained 1:38 P Weil Sign P H2S Gas Detector P P z Blind Switch Covers: Toth station; P Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): 5 x 1850 P Hazard Sec. P ACC Misc \ NA Misc NA F,.,_,,..~~_ .~ . ..-_~~_ ~-_.~_,_ ._, LOOR SAFTY VALVES: ...w_ _....._~._ .. _.__~._ _, _,_.~._._ BOP ._.~....,_.,_ ~_._.._., STACK. ,~_~._ _~_ ~_.~..~ ~ -~~,._._,,.. _.._.~.,.. _.. _.~_ .~,_,___ a. CHOKE MANIFOLD: Quantity P/F ' Quantity Size P/F Quantity P/F Upper Kelly 1 _ P Annular Preventer 1 13 5/8 P No. Valves 16 P Lower Kelly __ 1 P '. Pipe Rams 1 3.5 X 6 P Manual Chokes 1 P Ball Type __ 1 P Lower Pipe Rams 1 2 7/8 X 5 P Hydraulic Chokes 1 P Inside BOP 1 P Blind Rams 1 Blind P CH Misc NA FSV Misc _ NA Choke Ln. Valves 1 3 1/8 P HCR Valves 1 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 none NA BOPS Misc 0 none NA Test Results Number of Failures: 0 Remarks Good test (5 hours), rig and BOPE in good condition. • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No Z-108 v~' ~~~ Dispatched To: Melen Warman Date Dispatched: 0-Jan-00 Installation/Rig Nabors-7ES Dispatched By: Mauricio Perdomo Data No Of Prints No of ~'lo ies Surveys 2 1 RECE ED FEB 1 2006 ONBGass Caamiwion Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nrose 1 @slb.com Fax:907-561-8317 LWD Log Delivery V1.1, 10-02-03 Y ~ ~~. a ~ . ~ s~ ~_ ~ ~ ~' ~~ ~.~ ~ ~~n a ~ '~~ fry, ~~' ~ ~ ~) ~~ ~~~ ~ ~ ~%"~~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~ ~~ ~~++ ~ t~~ ~r ~ ~ ~• ~Lt'•7~A OII/ ~ ~j°°'~ 333 W. T"AVENUE, SUITE 100 CO1~T5ERQATI011T COrII-II5SI011T ~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 Robert Tirpack ~ FAX (so7~ 27s-75x2 Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU Z-108 BP Exploration (Alaska) Inc. Permit No: 205-201 Surface Location: 4305' FSL, 3578' FEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 1521' FSL, 3450' FEL, SEC. 19, T11N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been :issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). _ hairman DATED this day of~e~nth, 2005 Orman cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~(x~A- L Z/ l z 20o s' ALASKA AND GAS CONSERVATION CONI~ISSION ~~~ PERMIT TO DRILL 20 AAC 25.005 o~c ~ ~ z~o~ ia. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ® t i ~ Ilfi~ti Slr]t@ ^ Stratigraphic Test ^ Service ^ Development G e Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Z-108 3. Address: P.O. Box 196612, Anchorage, Alaska 99519.6612 6. Proposed Depth: MD 7433 TVD 6813 12. Field /Pool(s): Prudhoe Bay Field /Borealis Pool 4a. Location of Well (Governmental Section): Surface: 4305' FSL 3578' FEL SEC 19 T11 N R12E UM 7. Property Designation: ADL 028255 , , . , , , Top of Productive Horizon: 1603' FSL, 3474' FEL, SEC. 19, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 15, 2005 / Total Depth: 1521' FSL, 3450' FEL, SEC. 19, Ti 1 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6750' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599099 - 5959100 Zone- ASP4 10. KB Elevation Plan (Height above GL): 82.5 feet t5. Distance to Nearest well Within Pool Z-103 is offset by 2300' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 27 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3138 Surface: 2482 18. Casing rogram: Size Specifications Setting Depth To Bottom uantity o ement c.f. or sacks ; Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 80' 29' 29' 109' 109' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3128' 29' 29' 3157' 2933' 27 sx Arcticset Lite, 292 sx'G' 8-3/4" 7" 26# L-80 BTC-M 7403' 29' 29' 7432' 6813' 162 sx Class 'G', 219 sx Class 'G' 19. PRESENT.WELL'CONDITION SUMM ARY (To be completed foreRedrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Len h Size Cement Volume MD TVD r P i Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name Robert Tirpack Title Senior Drilling Engineer //~~..~~oo ~,~ Prepared ey NameMumber: Si nature lfL~~'~~ °.' Phone 564-4166 Date %~ f ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,20.E-^ b API Number: 50- D 2. -.~ •3 ,2 ,,2. Permit Ap rova Date: See cover letter for other requirements Conditions of Approval: Samp s Required ^ Yes ~ No Mud Log Required r'; Yes ~r No Hy og n Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No Other: Qc,.-t- '~ p P O ~ SOO ~ ~u' , ~$r 5 C l•) C t )~ a,~t~rw~„-~e 3oPE {-~~.~- ~ >~ ee ~~e i s ~ y~roi:~ec(. APPROVED BY ~ ~ Q~ ~( A roved B ~ ,~"~ THE COMMISSION Date J (((,,,(((»> Form to-401 I~sed`e~S[aelba 4,.~ ,,,,a. !~ ~ ~ ~ I I y /-~ ~ Submit In Duplicate r ~ Well Name: Z-108 Well Plan Summary T e of Well roducer or in'ector : Slant Producer Surface Location: 4305' FSL, 3578' FEL, Sec. 19, T11 N, R12E ~ X = 599,099 Y = 5,959,100 Z-108 Target 1 Kuparuk : 1603' FSL, 3474' FEL, Sec. 19, T11 N, R12E X = 599,250' Y = 5,956,400' Z =6,530' TVDss Z-108 Production BHL: 1,521' FSL, 3450' FEL, Sec. 19, T~i~l, R12E X = 599,275' Y = 5,956,318' Z = 6,730' TVDss ~ l N WU~ AFE Number: BRD5M4192 Ri Nabors 7ES GL: 54.0' KB: 28.5' Estimated Start Date: Dec. 15, 2005 O eratin da s to com lete: 13.6 TD: 7,433' MD TVD: 6,813' Max Inc: 26.65° KBE: 82.5' Well Design: I USH Grassroots Producer / 3-'h" IBT-M x 4-~/z" IBT-M completion w/ downhole aauae and I-wire. Current Well Information General Distance to Nearest Property: 6,750' to the nearest PBU property line Distance to Nearest Well in Pool: 2,300' from Z-108 to Z-103 API Number: 50-029-XXXXX . Well Type: Development -Aurora Producer Current Status: New well, 20" X 34" insulated conductor Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 109' RKB BHP: 3,219 psi ~ 6,645' TVDss (9.2 ppg EMW). BHT: 155°F C«~ 6,730' TVDss estimated Casing/Tubing Program Hole Size Csg / Tb O.D. WUFt Grade ~ Conn ~ Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 42" 20" 215.5# A-53 Weld 80' 29' / 29' 109' / 109' 12-'/a" 9 5/s" 40# L-80 BTC 5,750 3,090 3,128' 29' / 29' 3,157' / 2, 933' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 7,403' 29' / 29' 7,432' / 6,813' Tubin 4-~h" 12.6# L-80 IBT-M 8,430 7,500 2,774' 29' / 29' 2,803' / 2,615' Tubin 3-'/z" 9.2# L-80 IBT-M 10,160 10,530 4,271' 2,803' / 2,615' 7,074' / 6,484' Z-108 Permit to Drill Page 1 • Formation Markers Z-108 (Based on Schlumberger (P3)) • Formation To s MD TVD TVDss Pore si EMW H drocarbons G1 54 54 265 No SV6 1,112 1,098 1,015 No SV5 1,814 1,733 1,650 793 8.8 No SV4 1,948 1,853 1,770 847 8.8 No Base Permafrost 1,982 1,883 1,800 862 8.8 No SV3 2,468 2,318 2,235 1061 8.8 No SV2 2,687 2,513 2,430 1149 8.8 No SVi 3,045 2,833 2,750 1296 8.8 No UG4A 3,403 3,153 3,070 1443 8.8 No UG4 3,463 3,203 3,120 1466 8.8 No UG3 3,794 3,503 3,420 1603 8.8 No UG1 4,331 3,983 3,900 1823 8.8 No To Schrader/Ma Sand 4,667 4,283 4,200 1960 8.8 No Na 4,947 4,533 4,450 2074 8.8 No Nb 4,975 4,558 4,475 2086 8.8 Possible OA 5,141 4,708 4,625 2154 8.8 No Obf Base 5,528 5,063 4,980 2317 8.8 No CM2 5,724 5,243 5,160 No Fault #1 6,380 5,843 5,760 No CM1 Colville Shales 6,613 6,060 5,977 No THRZ 6,964 6,383 6,300 No Kalubik 7,215 6,612 6,530 No TKD 7,226 6,623 6,540 No TKC4 7,247 6,643 6,560 3,178 9.2 Yes TKB_LCU Ku aruk B 7,313 6,703 6,620 3,207 9.2 No TKA5 7,318 6,708 6,625 3,209 9.2 No TKA4 7,340 6,728 6,645 3,219 9.2 No OWC 7,351 6,738 6,655 TMLV 7,367 6,753 6,670 FWL 7,378 6,763 6,680 Production T.D. 7,432 6,813 6,730 Mud Pro ram: 12'/a" Surface Hole Mud Properties: Spud -Freshwater Mud Interval Densit Funnel Vis PV YP FL Chlorides PH 110-2,000 8.8 - 9.2 250-300 30-55 50-70 NC-8.0 <1000 9.0-9.5 2,000-3,157 9.2 - 9.5 225-250 30-55 45-60 8.0 <1000 9.0-9.5 8 3/a" Intermediate Hole Mud Properties: Freshwater Mud (LSND) Interval Density LGS (%) PV YP FL HTHP FL pH Chlorides MBT 3,157'-6,855"' 8.8-9.2 <6.0 10-16 20-26 4.0-7.0 N/C 9.5-10 <500 < 18 6,850'-7,432' .9 <8.0 18-24 20-26 3.0-4.0 <8.0 9.5-10 <500 < 20 "6,855 is 100'TVD abHRZ. Surve and Lo in Pro ram: 12-'/a" Hole Section: Surface Gyro will be needed (run. to 1000' or as conditions dictate) O n Hole: MWD / GR Cased hole: None 8-3/a" Hole Section: MWD / GR / PWD O n Hole: Wire Line Quad Combo Cased Hole: None 9~4 Z-108 Permit to Drill Page 2 - Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well Z-03 Z-04 Z-05 Distance to Nearb Well 52.47' 17.47 17.39 Z-04 and Z-05 will require well house removal in order to move over well Z -108. Z-03 may also require well house removal. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautiona Comment Z-02 89.74-ft 569-ft 79.57-ft Use Travelin C tinder G ro Z-02A 89.93-ft 577-ft 79.56-ft Use Travelin C tinder G ro Z-03 54.88-ft 259-ft 50.47-ft Use Travelin C tinder G ro Z-04 18.58-ft 488-ft 10.58-ft Use Travelin C tinder G ro Z-04A 18.35-ft 477-ft 10.41-ft Use Travelin C tinder G ro Z-05 18.07-ft 490-ft 10.20-ft Use Travelin C tinder G ro Z-06 52.82-ft 530-ft 44.65-ft Use Travelin C tinder G ro Z-07 87.03-ft 633-ft 76.18-ft Use Travelin C tinder G ro Z-07A 87.03-ft 633-ft 76.18-ft Use Travelin C tinder G ro Cement Calculations: Casin Size: 9 5/e" in 40-Ib/ft L-80 BTC -Single Stage Basis: Lead: 250% a mover gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: urface- Tail: 750' of apz~ hole with 30% excess, plus 86' shoe track Tail TOC: 2,407' and Total Cement Volume: Spacer 80 bbls of Viscosified acer weighted to 10.1 ppg (Mud P II) Lead 418 bbls, 2,346 ft sks 10.7 ASL G + adds - ;44~`ft /sk Tail 61 bbls, 342 ft 2 „irks 15.8 Class G + adds - .17y /sk Temp BHST = 70° F, B T 80° F estimated by Schlumbe _ r In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size: 7" 26 Ib/ft L-80 BTC-M -Single Stage Basis: Lead: 2,048' o en hole with 30% excess over gauge hole Lead TOC: ,167' and 500' and above tanned U nu Ma to at 4,667' MD Tail: 1,21 T open hole with 30% excess, plus 86' shoe track Tail TOC: 6,215' MD 1000' MD above tanned to KUP C at 7,215' Total Cement Volume: Spacer 20 bbls of Viscosifie,Si,Spacer (Mudpush II Design) Weighted to 11.0 ppg Lead 72 bbls, 404 ft , ~ks 12.0 G + adds - k Tail 46 bbls, 258 ft , i9 ks 15.8 G + Gasblok - :1 t /sk Temp BHST =155° F, T 120° F estimated by Schlu rger Z-108 Permit to Drill Page 3 l~ Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures.Based upon ~~ calculations below, BOP equipment will be tested to 3,500 psi. Due to anticipated surface pressures not exceeding 3,000 psi, it will not be necessary to have two sets of pipe rams installed at all times. r BOP regular test frequency for Z-108 will be 14 days. Function test every 7 days. ~' Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: • 7" Casing Test: Disposal 3,138~isi -Top of Kuparuk (9.2 ppg @ 6,560' TVDss) ,48 psi -Based on a full column of gas C«3 0.10 psi/ft 00 psi/250 psi Rams 2,500 psi/250 psi Annular LO 0' from 9 5/s" shoe 2. bls with an 12.1 ppg EMW LOT :4ppg seawater / 6.8 ppg Diesel 3,500 psi • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Z-108 Permit to Drill Page 4 • C Z-108 Drill and Complete Procedure Summary Pre-Rig Operations: 1. Weld an FMC landing ring, for the FMC slim-hole wellhead, on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MI/RU Nabors 7ES. j 2. Nipple up the diverter spool and riser. P/U sufficient length of 4"drill pipe and stand back in the derrick. 3. M/U a 12 ~/a" drilling assembly. Spud and directionally drill surface hole to the base of the permafrost and trip for a new bit. 4. RIH and drill the remainder of the surface hole to approximately 100' tvd below the SV1 sand. POOH and UD BHA. 5. R/U, run, and cement the 9 5/8", 40# casing back to surface. A TAM port collar may be run as a contingency. ~ 6. N/D the riser spool and N/U the FMC casing head and tubing spool. 7. N/U the BOPE and test to 3,500 psi. ~ 8. MU 8 3/a" MWD/LWD drilling assembly and RIH to the landing collar. 9. Test the 9 5/8" casing to 3,500 psi for 30 minutes. Record the test. 10. Drill out cement, float equipment, and the shoe. Displace the w~ to 8.8 ppg LSND drilling fluid. 11. Drill approximately 20' new formation and perform a LOT. 12. Drill ahead, according to directional proposal, to -100' above the HRZ. 13. Increase mud weight, via spike fluid, to 9.9 ppg. 14. Drill according to directional plan to long string TD, 100' past TMLV. 15. Condition hole as necessary. POOH, UD all 4" drill pipe. 16. R/U Schlumberger and log open hole w/ wireline quad court 17. R/U, run, and cement the 7", 26# long string casing. 18. Install casing pack-off and test per FMC representative. Record test. 19. Freeze-protect the 9 5/s" x 7" annulus, once the cement has reached 500 psi compressive strength. Confirm that the OA is open. 20. R/U and run a 3'/z", 9.2#, L-80 IBT-M x 4'h", 12.6#, L-80 IBT-M completion w/ downhole gauge and I-wire. 21. Position pkr 200' above TKUP. RILDS. 22. Reverse circulate seawater and corrosion Inhibitor. 23. Drop ball/rod and set packer. 24. Individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. ~ 25. Shear DCR valve. 26. Install TWC and test. 27. N/D the BOPE. 28. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi. 29. RU DSM. Pull TWC. 30. R/U circulating lines and test. Freeze-protect the tubing and annulus to 2,000'. Allow the diesel to U-tube to equilibrium. Need 500 psi underbalance for post rig perforating. 31. Install a BPV and VR plugs in the annulus valves. 32. Secure, rig down and move off. j Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install the well house, instrumentation, and flow line. 3. Post rig perforating will be charged to a separate AFE. Z-108 Permit to Drill Page 5 • • Z-108 Detailed Drilling Procedure Job 1: MIRU Critical Issues: - Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted. Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. - Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. - Z-04, Z-05 and maybe Z-03 require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre- job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearb Wells Distance to Z-03 52.47' Distance to Z-04 17.47' Distance to Z-05 17.39' - Z Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should berfol owed at all times. Adjacent surface producers: Adjacent bottom hole producers: Z-03 10 ppm Z-01 N/A Z-04 N/A Z-02 N/A Z-05 10 ppm Z-03 10 ppm Z-06 10 ppm Z-11 N/A Z-07 10 ppm Z-13 10 ppm Z-08 10 ppm Z-46 N/A The maximum level of H2S recently recorded on the pad was ~10 ppm. The maximum level ever recorded on the pad was -20 ppm back in Aug. 2000. l Reference SOP: • "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 121/x" Surface Hole Critical Issues: - At Z-Pad, shallow gas hydrates are present. Tight hole, bridging, and obstructions have been encountered while drilling. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. - Close Approach: Z-04, Z-05 and maybe Z-03 will be required to have the wellhouse removed due to surface location proximity to the Z-108. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run to at least 1,000'. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. - Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SVi sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SVi sands. Z-108 Permit to Drill Page 6 r ~ Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" • Follow Schlumberger logging practices and recommendations Job 3: Run 9 s/e" Surface Casing Critical Issues: - Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates have been encountered on Z-pad all the way through the SV1 and slightly beyond. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. - Casing drift: 9 5/8", 40# special drift casing is being used (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3/a" bit (float equipment, casing hanger, etc). - Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD as a contingency, if hole conditions warrant. If displacement goes according to plan, bump plug and walk pressure to 3,500 psi and hold for 30 minutes for casing pressure test. Reference RPs: • "Casing and Liner Running Procedure" • "Surface Casing and Cementing Guidelines" • "Surface Casing Port Collar Procedure" Job 4: Drill 8-3/a" Production Hole Critical Issues: - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. - LOT: Perform a LOT. KICK TOLERANCE: Based upon the max expected Kuparuk reservoir pressure of 9.2 ppg and 9.9 ppg mud, a 12.1 ppg leak-off will provide 52.2 bbls of kick tolerance. ~ Contact Anchorage personnel if LOT is less than 12.1 .ppg. Based upon off-set drilling data, a minimum leak-off of 13 ppg is expected at the 9 5/e" shoe. - Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. - Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. - Faults: One fault is expected in the Z-108 8-3/a" hole section. Losses are not expected to be associated with this fault. Details are listed below for reference: - Fault #1: 6,380' MD 5,843' TVD 5,760' TVDss Throw: 170' SW - Screen Blinding: Add EMI 697 as per MI mud program while drilling the Ugnu/heavy oil sands. - 7" casing landing point: The 7" casing setting point will be picked based on drilling 100' MD past the top Miluveach to get open hole E-line logs across A5 and A4 sands. A Rigsite Geologist will be required on site to pick casing point. Reference RPs: • Standard Operating Procedure for Leak-off and Formation Integrity Tests Z-108 Permit to Drill Page 7 • • • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. Job 5: Run and Cement 7" Production Casing Critical Issues: - Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary. - Install 7" rams and test. - Cement Job: The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 1000' above the TKUP to 500' above the top of the Ugnu Ma and the tail will cover from the shoe up 1000' above TKUP. Reciprocate pipe as long as possible while cementing. Keep cementing ECD's below 13.0 ppg EMW during the displacement. - Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9 5/a" casing outer annulus with 67 bbls of diesel (2,500' MD). Ensure adouble-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the freeze protection as the hydrostatic pressure of the mud and diesel could be over 100 psi underbalance to the open hole. - Centralization/Differential Sticking: Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - Mud Requirements: Thin the mud as per MI's Mud Program. Thinner mud will aid in achieving good displacement and a better cement job will result from thinner mud at TD. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. - Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. - TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC-M casing is on the rig floor before running casing. Reference RPs: • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" Job 6: Run 4-~/s" x 3-'/z "Completion Critical Issues: - Planned completion is 4-1/2" x 3-1/2", L-80, IBT-M, Including a HES 3-1/2" Symphony down hole pressure gauge. - Extreme care should be taken when running the completion to avoid damaging the I-wire associated with the down hole pressure gauge. Ensure that the I-wire ports in the tubing hanger and adapter flange are aligned after the packer is set. - Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the tubing and 7" casing inner annulus with 96 bbls of diesel (2,814' MD, 2,600' TVD), the hydrostatic pressure will be 7.85 ppg vs. 9.2 ppg EMW of the formation pressure at the target reservoir. - Under balanced perforations will be post rig E-line. Z-108 Permit to Drill Page 8 • ~ Reference RPs: • "Completion Design and Running" RP • "Tubing Connections" RP Job 13: ND/NU/Release Rig Critical Issues: - Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. - Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - Z-04, Z-05 and maybe Z-03 are in close proximity to Z-108 and care should be taken while moving off this well. Spotters should be employed at all times. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearb Wells Distance to Z-03 52.47' Distance to Z-04 17.47' Distance to Z-05 17.39' Reference RPs: • "Freeze Protecting an Inner Annulus" RP Z-108 Permit to Drill Page 9 r • Z-108 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: Gas hydrates may be encountered near the base of the Permafrost at 1982' MD and near the TD hole section as well. • Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: • The production hole section will be drilled with a recommended mud weight of 9.9 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.2 ppg pore pressure. • Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. • Z-108 is expected to cross one fault in the intermediate hole section. The approximate location of the fault is 6,380' +/- 200' and has an estimated throw of 170'. Lost circulation is considered a minimum risk. HYDROGEN SULFIDE - H2S This drill-site not designated as an H2S drill site. Recent wells test do not indicate H2S concentration which exceed 20 ppm. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies • i Variance Request Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Request The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore.:.for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be #unc#ion pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested #o more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; ~- 20 AAC 25.285 (f)(2) TUBING WORKOVERS: 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) #rom the BOPS requirements in (e) of this section if the variance provides at least an equally effective means of well control; WELLHEAD = FMC KB. ELEV = T ! 82.5' BF. EIEV = 54' KOP - 400' Max Angle = 27 @ 1,440' Datum MD = Datum TV D = ~ Z-108 Proposed i TREE = CM/ 4-1 /16 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W/ 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11" X 4-1/2" ADPFLANGE= 11"X4-1/16" ~3-112" X 4-1/2" XO 2803' 9-5/8" CSG, 40#, L-80, BTC ID = 8.835^ 3157 Minimum ID = 2.813" @ 6,939' 3-1/2" HES X NIPPLE PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: NOTE SIZE SPF INTERVAL Opn/Sqz DATE 3-1/2" TBG, 9.2#, L-80, IBT-M, 0.0087 bpf, 7069' ID = 2.992" 7" 26# L-80 MARKER JOINT W! PfPTAG ~ 7173' (1 JTABOVETKUP) ' 7" 26# L-80 MARKER JOINT W/ PIP TAG 7313' (KUP B) PBTD 7346' 2677' 4-1/2" HES X NIPPLE, ID = 3.813" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 5 2814 2600 27 MMG DMY BK-5 4 3807 3500 27 MMG DMY BK-5 3 5262 4800 24 MMG DMY BK-5 2 6003 5500 23 MMG DMY BK-5 1 6534 6000 23 MMG DMY BK-5 6939' 3-1/2" HES X NIPPLE, ID = 2.813" 6960' HES 3-112" SYMPHONY BHG w/ I-WIRE 7014' 3-1 /2" X 4-1 /2" XO 7015' 7" x 4-1/2" BAKER S-3 PKR, ID= 3.88" 7020' 3-1/2" X 4-112" XO 7041' 3-1/2" HES X NIPPLE, ID = 2.813" 7062' 3-1l2" HES X NIPPLE, ID = 2.813" 7074' ~ HES 3-1/2" WLEG 7432' 7" CSG, 26#, L-80 BTGM, 0.0383 bpf, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 11/04/05 STG Original Completion WELL: Z-108 PERMfr No: API No: SEC 19, T11 N, R12E, 975' FNL, 1375' FWL BP Exploration (Alaska) by Schlumberger Z-108 (P4) Proposal Report Date: December 6, 2005 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Explorafion Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: Z-PAD I Z-108 ~ ~ ~ 6/O Vertical Section Azimuth: 177.130° Vertcal Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table ~ Well: Plan Z-108 ~OVe TVD Reference Elevation: 82.50 ft relative to MSL Borehole: Plan Z-108 ppp Sea Bed 1 Ground Level Elevation: 54.00 ft relative to MSL UWUAPI#: 50029 Magnetic Declination: 24.424° Survey Name 1 Date: Z-108 (P4) !December 6, 2005 Total Field Strength: 57580.513 nT Tort 1 AND 1 DDI 1 ERD ratio: 35.428° 12821.63 ft / 5.038 / 0.414 Magnetic Dip: 80.829° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 18, 2005 Location LaVLong: N 70.29770322, W 149.19747911 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5959100.200 ftUS, E 599099.160 ftUS North Reference: True Norlh Gdd Convergence Angle: +0.75554456° Total Corr Mag North -> True North: +24.424° Comments Measured Inclination Azimuth Subsea TVD TVD Vertical NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section o-rc ft n nn de de ft ft ft ft ft d 1100 ft de de 1700 ft de 1700 ft ftUS ftUS ,..~ .,.., J. IOJ.JI -vc.JV V.vv V.VV V.VV V.VV V.VV -Iro.v°JIVI U.UU V.UU VyDeIVV.LU OyyUy`J.lb N/U.Ltl//U3LL VV"14`J.14!/4/`Jll KOP Bld 1.5/100 300.00 0.00 183.31 217.50 300.00 0.00 0.00 0.00 0.00 -176.69M 0.00 0.00 5959100.20 599099.16 N 70.29770322 W 149.19747911 G1 347.50 0.71 183.31 265.00 347.50 0.29 -0.29 -0.02 1.50 -176.69M 1.50 0.00 5959099.90 599099.15 N 70.29770242 W 149.19747925 Bld 2.5/100 400.00 1.50 183.31 317.49 399.99 1.30 -1.31 -0.08 1.50 -176.67M 1.50 0.00 5959098.89 599099.10 N 70.29769965 W 149.19747973 500.00 4.00 183.33 417.37 499.87 6.07 -6.10 -0.35 2.50 -176.67M 2.50 0.02 5959094.10 599098.89 N 70.29768657 W 149.19748198 600.00 6.50 183.33 516.94 599.44 15.17 -15.23 -0.88 2.50 O.OOG 2.50 0.00 5959084.96 599098.48 N 70.29766162 W 149.19748628 700.00 9.00 183.33 616.02 698.52 28.57 -28.69 -1.67 2.50 O.OOG 2.50 0.00 5959071.49 599097.87 N 70.29762484 W 149.19749262 800.00 11.50 183.33 714.41 796.91 46.26 -46.45 -2.70 2.50 O.OOG 2.50 0.00 5959053.72 599097.07 N 70.29757632 W 149.19750099 900.00 14.00 183.33 811.94 894.44 68.20 -68.48 -3.98 2.50 O.OOG 2.50 0.00 5959031.67 599096.08 N 70.29751613 W 149.19751138 1000.00 16.50 183.33 908.41 990.91 94.35 -94.74 -5.51 2.50 O.OOG 2.50 0.00 5959005.40 599094.90 N 70.29744440 W 149.19752376 1100.00 19.00 183.33 1003.64 1086.14 124.65 -125.17 -7.29 2.50 O.OOG 2.50 0.00 5958974.95 599093.53 N 70.29736126 W 149.19753811 SV6 1112.02 19.30 183.33 1015.00 1097.50 128.57 -129.11 -7.52 2.50 O.OOG 2.50 0.00 5958971.01 599093.35 N 70.29735050 W 149.19753996 1200.00 21.50 183.33 1097.45 1179.95 159.06 -159.72 -9.30 2.50 O.OOG 2.50 0.00 5958940.38 599091.97 N 70.29726687 W 149.1975 1300.00 24.00 183.33 1189.67 1272.17 197.50 -198.33 -11.55 2.50 O.OOG 2.50 0.00 5958901.76 599090.23 5 N 70.29716141 W 149.19757 1400.00 26.50 183.33 1280.11 1362.61 239.90 -240.91 -14.03 2.50 O.OOG 2.50 0.00 5958859.15 599088.31 N 70.29704508 W 149.19759269 End Crv 1406.16 26.65 183.33 1285.62 1368.12 242.64 -243.66 -14.19 2.50 O.OOG 2.50 0.00 5958856.40 599088.19 N 70.29703756 W 149.19759399 SVS 1813.87 26.65 183.33 1650.00 1732.50 424.47 -426.25 -24.82 0.00 O.OOG 0.00 0.00 5958673.70 599079.96 N 70.29653874 W 149.19768010 SV4 1948.14 26.65 183.33 1770.00 1852.50 484.35 -486.38 -28.33 0.00 O.OOG 0.00 0.00 5958613.53 599077.25 N 70.29637447 W 149.19770846 Base Perm 1981.71 26.65 183.33 1800.00 1882.50 499.32 -501.41 -29.20 0.00 O.OOG 0.00 0.00 5958598.49 599076.57 N 70.29633340 W 149.19771555 SV3 2468.43 26.65 183.33 2235.00 2317.50 716.39 -719.39 -41.90 0.00 O.OOG 0.00 0.00 5958380.39 599066.75 N 70.29573791 W 149.19781834 SV2 2686.62 26.65 183.33 2430.00 2512.50 813.70 -817.10 -47.59 0.00 O.OOG 0.00 0.00 5958282.61 599062.35 N 70.29547096 W 149.19786442 SVl 3044.67 26.65 183.33 2750.00 2832.50 973.38 -977.45 -56.93 0.00 O.OOG 0.00 0.00 5958122.17 599055.13 N 70.29503290 W 149.19794004 9-5/8" Csg Pt 3156.56 26.65 183.33 2850.00 2932.50 1023.28 -1027.56 -59.85 0.00 O.OOG 0.00 0.00 5958072.03 599052.87 N 70.29489600 W 149.19796366 UG4A 3402.72 26.65 183.33 3070.00 3152.50 1133.06 -1137.80 -66.27 0.00 O.OOG 0.00 0.00 5957961.73 599047.90 N 70.29459483 W 149.19801565 UG3 3794.33 26.65 183.33 3420.00 3502.50 1307.71 -1313.19 -76.49 0.00 O.OOG 0.00 0.00 5957786.24 599040.00 N 70.29411570 W 149.19809834 WeIlDesign Ver SP 1.0 Bld(doc40x_56) Z-108\Plan Z-1081PIan Z-108\Z-108 (P4) Generated 12/6/2005 8:15 AM Page 1 of 2 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 1100 ft de de 1100 ft de 100 ft ftUS ftUS UG1 4331.41 26.65 183.33 3900.00 3982.50 Ma 4667.08 26.65 183.33 4200.00 4282.50 Na 4946.80 26.65 183.33 4450.00 4532.50 Crv 3/100 4974.12 26.65 183.33 4474.41 4556.91 Nb 4974.78 26.64 183.29 4475.00 4557.50 5000.00 26.31 181.78 4497.58 4580.08 5100.00 25.14 175.41 4587.69 4670.19 Z-108 Flt int Tgt 5113.60 25.00 174.50 4600.00 4682.50 OA 5141.14 24.63 172.74 4625.00 4707.50 5200.00 23.91 168.82 4678.66 4761.16 End Bld 5266.58 23.22 164.12 4739.70 4822.20 OBf Base 5528.07 23.22 164.12 4980.00 5062.50 CM2 5723.94 23.22 164.12 5160.00 5242.50 Fault Crossing 6376.83 23.22 164.12 5760.00 5842.50 CMl 6612.96 23.22 164.12 5977.00 6059.50 THRZ 6964.44 23.22 164.12 6300.00 6382.50 TKLB 7214.70 23.22 164.12 6529.99 6612.49 Target 7214.72 23.22 164.12 6530.00 6612.50 TKD 7225.60 23.22 164.12 6540.00 6622.50 TKC 7247.36 23.22 164.12 6560.00 6642.50 TKB / LCU 7312.65 23.22 164.12 6620.00 6702.50 TKAS 7318.09 23.22 164.12 6625.00 6707.50 TKA4 7339.85 23.22 164.12 6645.00 6727.50 OWC 7350.73 23.22 164.12 6655.00 6737.50 TMLV 7367.06 23.22 164.12 6670.00 6752.50 FWL 7377.94 23.22 164.12 6680.00 6762.50 TD / 7" Csg Pt 7432.35 ~ 23.22 164.12 6730.00 6812.50 Lea al Description: Surface : 4305 FSL 3578 FEL S19 T11 N R12E UM Target : 1602 FSL 3474 FEL S19 T11 N R12E UM BHL : 1520 FSL 3451 FEL S19 T11 N R12E UM 1547.23 -1553.71 -90.50 0.00 O.OOG 0.00 0.00 5957545.57 599029.16 N 70.29345860 W 149.19821174 1696.93 -1704.04 -99.26 0.00 O.OOG 0.00 0.00 5957395.16 599022.39 N 70.29304792 W 149.19828262 1821.68 -1829.31 -106.55 0.00 O.OOG 0.00 0.00 5957269.81 599016.75 N 70.29270568 W 149.19834168 1833.86 -1841.54 -107.27 0.00 -117.19G 0.00 0.00 5957257.57 599016.19 N 70.29267226 W 149.19834744 1834.16 -1841.84 -107.28 3.00 -117.16G -1.37 -5.95 5957257.27 599016.18 N 70.29267146 W 149.19834758 1845.35 -1853.07 -107.78 3.00 -115.80G -1.34 -6.02 5957246.04 599015.83 N 70.29264077 W 149.19835161 1888.68 -1896.40 -106.77 3.00 -110.06G -1.17 -6.37 5957202.73 599017.42 N 70.29252239 W 149.19834340 1894.43 -1902.14 -106.26 3.00 -117.44G -1.01 -6.67 5957197.00 599015.00 N 70.29250672 W 149.19833929 1905.97 -1913.63 -104.98 3.00 -115.84G -1.35 -6.39 5957185.53 599019.43 N 70.29247534 W 149.19832891 1930.00 -1937.50 -101.11 3.00 -112.26G -1.22 -6.67 5957161.71 599023.61 N 70.29241013 W 149.19829763 1956.15 -1963.36 -94.90 3.00 O.OOG -1.03 -7.05 5957135.94 599030.16 N 7029233946 W 149.198247 2056.61 -2062.53 -66.70 0.00 O.OOG 0.00 0.00 5957037.16 599059.67 N 70.29206854 W 149.198019 2131.85 -2136.82 -45.57 0.00 O.OOG 0.00 0.00 5956963.16 599081.77 N 70.29186560 W 149.19784801 2382.68 -2384.43 24.85 0.00 O.OOG 0.00 0.00 5956716.52 599155.45 N 70.29118914 W 149.19727794 2473.40 -2473.98 50.32 0.00 O.OOG 0.00 0.00 5956627.32 599182.09 N 70.29094449 W 149.19707178 2608.43 -2607.28 88.23 0.00 O.OOG 0.00 0.00 5956494.55 599221.76 N 70.29058033 W 149.19676491 2704.58 -2702.20 115.23 0.00 O.OOG 0.00 0.00 5956400.00 599250.00 N 70.29032103 W 149.19654642 2704.58 -2702.20 115.23 0.00 O.OOG 0.00 0.00 5956400.00 599250.00 N 70.29032101 W 149.19654641 2708.76 -2706.33 116.40 0.00 O.OOG 0.00 0.00 5956395.89 599251.23 N 70.29030974 W 149.19653691 2717.12 -2714.58 118.75 0.00 O.OOG 0.00 0.00 5956387.67 599253.68 N 70.29028719 W 149.19651791 2742.20 -2739.34 125.79 0.00 O.OOG 0.00 0.00 5956363.00 599261.05 N 70.29021954 W 149.19646091 2744.29 -2741.41 126.38 0.00 O.DOG 0.00 0.00 5956360.95 599261.66 N70.29021391 W149.19645616 2752.66 -2749.66 128.73 0.00 O.OOG 0.00 0.00 5956352.73 599264.12 N 70.29019136 W 149.19643716 2756.84 -2753.79 129.90 0.00 O.OOG 0.00 0.00 5956348.62 599265.35 N 70.29018008 W 149.19642766 2763.11 -2759.98 131.66 0.00 O.OOG 0.00 0.00 5956342.45 599267.19 N 70.29016317 W 149.19641341 2767.29 -2764.10 132.84 0.00 O.OOG 0.00 0.00 5956338.34 599268.42 N 70.29015190 W 149.19640391 2788.19 -2784.74 138.70 0.00 O.OOG 0.00 0.00 5956317.79 599274.56 N 70.29009553 W 149.19635641 Northi ng (Y) [ftUS] Eastin g (X) [ftUS] 5959100.20 599099.16 5956400.00 599250.00 5956317.79 599274.56 WeIlDesign Ver SP 1.0 Bid( doc40x_56) Z-108\Plan Z-108\Plan Z-108\2-108 (P4) Generated 12/6/2005 8:15 AM Page 2 of 2 t~~ ~ • Schlumberger WELL Z-108 (P4) FIELD Prudhoe Bay Unit - WOA STRUCTURE Z-PAD llagnelw Paramelera SuRace Lucalwn NAD2] Alaa6a SW1e Planes. Zone OJ US Feal Mncellan ebua Moeel'. RGGM1I 2005 DiP 60 629' Oa1e. December t6, 2005 tal N)0 t) 51 i32 Nonbmg 5959 00 20 11115 Grid Lonv • "Sea 58' Sbl 2-108 NO Rel' Ro1sy TaU1e 162 50 A above MSLI M11ag Oec. •2a +1a• FS Si 560.5 nT Lon W119115D.925 EasOng 59509916 M1US Scale Fact'.0999911t Sfi1 PWn. L-tO61PYl Snry Dale December 06. 2005 0 800 1600 2400 3200 0 800 1600 2400 `o 0 °O 3200 c _~ c~ N >O 4000 4800 5600 6400 ~titq~iilti''~'i~i( iiiii-siiiiiiiil TD l7" Csg Pt -108 (P4) 0 800 1600 2400 3200 4000 4800 5600 6400 0 800 1600 2400 3200 Vertical Section (ft) Azim = 177.13°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V E~F~ Schlumberger WELL FIELD STRUCNRE Z-108 (P4) Prudhoe Bay Unit - WOA Z-PAD llagneac Parameiars Sunace Locaann NAD2i AlasMa SIa1e Planes. Zone 0<. US Feel acaNanepus hloGel. 9GGh1 3005 Dip 80 B29' Dale. Decempel :B 3005 Lal N/0 !] 51 ]32 NuriM1~ng 59 5910 0 3 0 110 5 GnC Donv •0 ]SSSda9fi' SIM 2~1p9 ND Rel Rotary TaEle 183 50 a aEOVe MSL) hlag Dac. •3a <3a' FS: S15BO S ni ton' Wla91t SC.925 Easling'. 5990991fi 1105 Scala Fact.09999t!t5fit Plan 2~10N IPal 51W Dale Dxamper Ofi. 3005 -800 -400 0 400 800 U '400 -800 n n n Z -1200 0 0 v C _~ (0 fo -1600 V V V -2000 -2400 -2800 0 '400 -800 -1200 -1600 -2000 -2400 -2800 -800 -400 0 400 800 c« W Scale = 1(in):400(ft) E »> Plan Z-108/Plan Z-108 i o~~ 20~~ 3~0~ ~~0 ADO 5 ~~0 6 0~0 ~~0 8 0 00 ~o -- Plan Z-103 • 00 0 i0°° ~ ,~ 00 00 ~oo ° • BP Anticollision Report • Company:.. BP Amoco ` Field: Prudhoe Bay. Reference. Site: PB Z Pad Reference Well: Plan Z-108 Reference Wellpath: Plan Z-108 ~~ NO GLOBAL SCAN: Using user defined selection & scan criteria ~I, Interpolation Method: MD Interva-: 20.00 ft !, Depth Range: 28.50 to 7432.35 ft Maximum Radius:10000.00 ft ' Survey Program for Definitive Wellpath Date: 12/6/2005 ' Time: 08:34:17 Page: 1 Co-ordinate(NE) Reference:... Well'. Plan Z-108, True North Vertical (TVb) Refetence• Z-108 Plait 82 5 Db: Oracle Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA ENipse j Trav Cylinder North Ellipse + Casing ', Date: 2/14/2005 Validated: No Version: 2 ~ Planned From To Survey Toolcode Tool Name ft ft I -- _ ~ --- -- j 28.50 1000.00 - _ - ------- _ ------- Planned: Plan #4 V2 -- -- GYD-GC-SS -- - - --- - - - " - - ------- ---"--- Gyrodata gyro single shots '~ 1000.00 2400.00 Planned: Plan #4 V2 MWD MWD -Standard ~ 1000.00 7432.35 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole. Size - Name !, ft ft in in 3156.56 2932.50 9.625 12.250 9 5/8" 7432.35 6812.50 7A00 8.750 7" ~ Summary <---- ------ Offset Wellpath. ---- --------> Reference Offset 'Ctr-Ctr Na-Go Allowable ~ Site WeII' Wellpath MD MD " Distance Area Deviation Warning: ft ft ft ft ft PB Z Pad - ExpansiorPlan Ivi Z-40 Plan Z-40 V1 Plan: Pla 379.21 380.00 847.26 7.16 840.10 Pass. Major Risk PB Z Pad - ExpansiorPlan Ivi Z-41 Plan Z-41 V1 Plan: Pla 3274.49 3340.00 567.94 74.48 493.47 Pass: Major Risk PB Z Pad - Expansiori~lan Ivi Z-42 Plan Z-42 V1 Plan: Pla 786.40 800.00 889.60 14.93 874.67 Pass: Major Risk PB Z Pad - ExpansiorPlan Ivi Z-44 Plan Z-44 V1 Plan: Pla 786.98 800.00 819.69 15.05 804.65 Pass: Major Risk PB Z Pad - ExpansiorPlan Ivi Z-45 Plan Z-45 V1 Plan: Pla 359.42 360.00 831.90 6.90 825.00 Pass: Major Risk PB Z Pad - ExpansiorPlan Ivi Z-55 Plan Z-55 V1 Plan: Pla 1268.10 1320.00 732.84 21.27 711.56 Pass: Major Risk PB Z Pad - Expansiorl'lan Ivi Z-57 Plan Z-57 V1 Plan: Pla 720.67 760.00 778.23 13.88 764.34 Pass: Major Risk i PB Z Pad - ExpansiorPlan Ivi Z-60 Plan Z-60 V1 Plan: Pla 470.64 480.00 917.93 8.91 909.02 Pass: Major Risk ', PB Z Pad - ExpansiorPlan Ivi Z-61 Plan Z-61 V1 Plan: Pla 433.36 440.00 863.46 8.20 855.26 Pass: Major Risk PB Z Pad - ExpansiorPlan Ivi Z-63 Plan Z-63 V1 Plan: Pla 1188.24 1360.00 711.85 21.99 689.86 Pass: Major Risk PB Z Pad - ExpansiorPlan Kup Z-105 Plan Z-105 V1 Plan: PI 786.15 800.00 919.56 14.93 904.63 Pass: Major Risk PB Z Pad - ExpansiorPian Kup Z-106 Plan Z-106 V1 Plan: PI 563.50 580.00 933.85 10.68 923.16 Pass: Major Risk PB Z Pad - Expansio~lan Kup Z-113 Plan Z-113 V1 Plan: PI 414.76 420.00 848.37 7.84 840.53 Pass: Major Risk PB Z Pad - Expansiori~lan Kup Z-115 Plan Z-115 V1 Plan: PI 652.03 660.00 880.81 12.33 868.48 Pass: Major Risk PB Z Pad - ExpansiorPlan Sch Z-219 Plan Z-219 V1 Plan: PI 525.65 540.00 819.54 9.97 809.57 Pass: Major Risk PB Z Pad - Expansio~lan Sch Z-220 Plan Z-220 V1 Plan: PI 526.52 540.00 903.57 9.97 893.59 Pass: Major Risk '; PB Z Pad - Expansiori~lan Sch Z-221 Plan Z-221 V1 Plan: PI 527.01 540.00 765.16 9.98 755.18 Pass: Major Risk ', PB Z Pad - Expansiori~lan Sch Z-307 Plan Z-307 V1 Plan: PI 395.81 400.00 1016.76 7.48 1009.28 Pass: Major Risk PB Z Pad - ExpansiorPlan Sch Z-308 Plan Z-308 V1 Plan: PI 526.08 540.00 1032.46 9.97 1022.49 Pass: Major Risk PB Z Pad - Expansiori~lan Sch Z-309 Plan Z-309 V1 Plan: PI 581.43 600.00 1063.05 11.03 1052.02 Pass: Major Risk I, PB Z Pad - Expansiori?lan Sch Z-310 Plan Z-310 V1 Plan: PI 1692.42 1840.00 718.30 33.56 684.74 Pass: Major Risk ', PB Z Pad - ExpansiorPlan Sch Z-311 Plan Z-311 V1 Plan: PI 554.98 560.00 1032.31 10.47 1021.84 Pass: Major Risk ~~~ PB Z Pad - ExpansiorPlan Sch Z-312 Plan Z-312 V1 Plan: PI 457.48 460.00 1047.01 8.63 1038.38 Pass: Major Risk i PB Z Pad - Expansior6~lan Sch Z-314 Plan Z-314 V1 Plan: PI 574.55 580.00 1017.65 10.84 1006.81 Pass: Major Risk PB Z Pad - Expansiorl~lan Sch Z-322 Plan Z-322 V1 Plan: PI 768.13 780.00 804.34 14.57 789.77 Pass: Major Risk ! PB Z Pad - ExpansiorPlan Sch Z-H207 Plan Z-H207 V1 Plan: P 545.50 560.00 795.10 10.38 784.72 Pass: Major Risk PB Z Pad Plan Z-102 Plan Z-102 V2 Plan: PI 754.09 800.00 260.64 14.31 246.33 Pass: Major Risk PB Z Pad Plan Z-104 Plan Z-104 V1 Plan: PI 375.03 380.00 272.01 6.79 265.21 Pass: Major Risk PB Z Pad Plan Z-109 Plan Z-109 V1 Plan: PI 860.37 860.00 33.02 15.86 17.15 Pass: Major Risk PB Z Pad Plan Z-110 Plan Z-110 V1 Plan: PI 699.91 740.00 266.62 12.59 254.03 Pass: Major Risk '~ PB Z Pad Plan Z-111 Plan Z-111 V1 Plan: PI 337.89 340.00 267.97 6.12 261.85 Pass: Major Risk ', PB Z Pad Plan Z-112 Plan Z-112 V1 Plan: PI 337.47 340.00 263.08 6.12 256.97 Pass: Major Risk PB Z Pad Plan Z-114 Plan Z-114 V1 Plan: PI 336.95 340.00 276.52 6.11 270.41 Pass: Major Risk I PB Z Pad Plan Z-200 (3.5) Plan Z-200 OBd V1 Plan 524.37 520.00 35.60 9.50 26.10 Pass: Major Risk PB Z Pad Plan Z-200 (3.5) Plan Z-200L1 OBb/a V3 524.37 520.00 35.60 9.61 25.99 Pass: Major Risk j PB Z Pad Plan Z-200 (3.5) Plan Z-200L2 OA V4 Pla 524.37 520.00 35.60 9.50 26.10 Pass: Major Risk PB Z Pad Z-01 Z-01 V1 589.22 600.00 122.71 12.16 110.55 Pass: Major Risk PB Z Pad Z-02 Plan Z-026 V2 Plan: PI 578.36 580.00 89.28 10.79 78.49 Pass: Major Risk PB Z Pad Z-02 Z-02 V3 589.16 600.00 89.56 11.06 78.50 Pass: Major Risk PB Z Pad Z-02 Z-02A V1 577.38 580.00 89.25 10.77 78.49 Pass: Major Risk PB Z Pad Z-03 Z-03 V4 258.73 260.00 54.22 4.59 49.63 Pass: Major Risk PB Z Pad Z-04 Z-04 V6 488.03 500.00 17.89 8.39 9.50 Pass: Major Risk ~ ~ BP Anticollision Report Companyr BP Amoco Date: 12/6/2005 Time: 08:34:17. Page:: 2 'Field: Prudhoe Bay.. Reference Site: PB Z Pad Co-ordinate(NE) Reference: Well: Pla n Z-108, True North ! !Reference WeIL• Plan Z-1.08 Vertical (T'VD) Reference: Z-108 Plan 82.5 ', Reference Wellpath: Plan Z-108 ` - -- I?b: Oraole - -- ------ Summary <- - Offset Wellpath - --------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area 13eviatian Warning i ft ~ , ft fY ft PB Z Pad Z-04 Z-04A V10 477.13 480.00 17.66 8.32 9.34 Pass: Major Risk ', PB Z Pad Z-05 Plan#3 Z-05AP61 VO Pla 489.83 500.00 18.65 8.32 10.33 Pass: Major Risk ', PB Z Pad Z-05 Plan#4 Z-05A VO Plan: 489.83 500.00 18.65 8.32 10.33 Pass: Major Risk I PB Z Pad Z-05 Z-05 V3 489.83 500.00 18.65 8.26 10.40 Pass: Major Risk '; PB Z Pad Z-06 Plan#7 Z-06A V3 Plan: 530.24 540.00 53.43 8.72 44.71 Pass: Major Risk PB Z Pad Z-06 Z-06 V1 530.24 540.00 53.43 8.55 44.88 Pass: Major Risk ail PB Z Pad Z-07A Z-07A V1 632.78 640.00 87.62 11.19 76.43 Pass: Major Risk ;~ PB Z Pad Z-07 Z-07 V1 632.78 640.00 87.62 11.19 76.43 Pass: Major Risk PB Z Pad Z-08A Z-08A V1 593.99 600.00 127.63 13.45 114.18 Pass: Major Risk PB Z Pad Z-08 Z-08 V1 593.99 600.00 127.63 13.45 114.18 Pass: Major Risk PB Z Pad Z-09 Plan 1, Z-09A V1 Plan: 658.79 660.00 157.67 13.41 144.26 Pass: Major Risk PB Z Pad Z-09 Z-09 V4 667.36 680.00 157.77 13.34 144.43 Pass: Major Risk ',' PB Z Pad Z-100 Z-100 V7 394.05 400.00 590.91 6.74 584.17 Pass: Major Risk '~, PB Z Pad Z-101 Plan Z-101A V3 Plan: Z 534.11 560.00 619.05 9.16 609.89 Pass: Major Risk i PB Z Pad Z-101 Plan Z-101AP61 VO Plan 534.11 560.00 619.05 9.41 609.64 Pass: Major Risk ~I it PB Z Pad Z-101 Z-101 V5 517.22 539.97 618.72 8.98 609.75 Pass: Major Risk '~ PB Z Pad Z-103 Z-103 V1 374.51 380.00 283.58 6.37 277.21 Pass: Major Risk PB Z Pad Z-103 Z-103P61 V3 374.51 380.00 283.58 6.37 277.21 Pass: Major Risk PB Z Pad Z-103 Z-103P62 V1 374.51 380.00 283.58 6.37 277.21 Pass: Major Risk i PB Z Pad Z-10 Z-10 V1 590.47 600.00 192.72 12.02 180.70 Pass: Major Risk PB Z Pad Z-10 Z-10A WPS V1 Plan: Z-1 596.82 600.00 192.85 12.11 180.74 Pass: Major Risk PB Z Pad Z-11 Plan#3, Z-11A V1 Plan: 685.61 700.00 377.91 10.77 367.14 Pass: Major Risk PB Z Pad Z-11 Z-11 V1 685.61 700.00 377.91 10.92 366.99 Pass: Major Risk PB Z Pad Z-12 Z-12 V1 7418.31 7880.00 258.86 155.52 103.34 Pass: Major Risk ', j PB Z Pad Z-13 Z-13 V3 704.79 720.00 447.99 12.08 435.91 Pass: Major Risk PB Z Pad Z-13 Z-13A V2 713.44 720.00 448.15 12.24 435.91 Pass: Major Risk PB Z Pad Z-13 Z-13APB1 V3 713.44 720.00 448.15 12.18 435.97 Pass: Major Risk !; PB Z Pad Z-14A Z-14A V1 685.14 700.00 482.94 12.51 470.43 Pass: Major Risk i PB Z Pad Z-14 Plan Z-14B V4 Plan: PI 674.62 680.00 482.74 12.48 470.26 Pass: Major Risk ', PB Z Pad Z-14 Z-14 V1 685.14 700.00 482.94 12.51 470.43 Pass: Major Risk i PB Z Pad Z-15 Z-15 V1 742.41 760.00 517.30 12.91 504.39 Pass: Major Risk PB Z Pad Z-16 Z-16 V1 591.55 600.00 557.57 12.56 545.01 Pass: Major Risk PB Z Pad Z-17 Z-17 V1 742.30 760.00 587.36 12.95 574.41 Pass: Major Risk PB Z Pad Z-18 Z-18 V1 605.92 620.00 622.55 10.82 611.73 Pass: Major Risk j 'j PB Z Pad Z-19 Plan Z-19A V3 Plan: PI 555.22 560.00 659.46 13.13 646.33 Pass: Major Risk ', PB Z Pad Z-19 Z-19 V1 570.29 580.00 659.89 13.55 646.34 Pass: Major Risk ', I, PB Z Pad Z-20 Plan Z-20A V1 Plan: PI 749.94 760.00 691.82 14.13 677.69 Pass: Major Risk PB Z Pad Z-20 Z-20 V1 760.66 780.00 691.99 14.15 677.84 Pass: Major Risk ', PB Z Pad Z-210 Z-210 V6 220.58 220.00 258.78 4.25 254.53 Pass: Major Risk ~, PB Z Pad Z-210 Z-210P61 V7 220.58 220.00 258.78 4.25 254.53 Pass: Major Risk ', ', PB Z Pad Z-21 Z-21 V3 347.30 360.00 390.38 6.82 383.56 Pass: Major Risk PB Z Pad Z-21 Z-21 A VS 353.55 360.00 390.46 6.69 383.77 Pass: Major Risk PB Z Pad Z-22A Z-22A V1 410.34 420.00 418.10 6.80 411.31 Pass: Major Risk ~I PB Z Pad Z-22B Z-22B V1 410.34 420.00 418.10 6.80 411.31 Pass: Major Risk PB Z Pad Z-22 . Z-22 V1 410.34 420.00 418.10 6.80 411.31 Pass: Major Risk PB Z Pad Z-23 Z-23 V3 438.87 460.00 444.01 8.85 435.16 Pass: Major Risk PB Z Pad Z-23 Z-23A V2 412.70 420.00 443.98 7.41 436.56 Pass: Major Risk PB Z Pad Z-23 Z-23B V7 411.36 420.00 443.95 7.46 436.49 Pass: Major Risk ' PB Z Pad Z-24 Z-24 V1 384.56 400.00 474.12 9.68 464.45 Pass: Major Risk PB Z Pad Z-25 Z-25 V1 438.93 460.00 502.27 8.66 493.61 Pass: Major Risk PB Z Pad Z-26 Z-26 V1 386.69 400.00 532.89 7.92 524.96 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 384.96 400.00 264.74 7.37 257.38 Pass: Major Risk j PB Z Pad Z-28 Z-28 V1 385.00 400.00 261.17 8.09 253.09 Pass: Major Risk j '; PB Z Pad Z-29 Z-29 V1 328.75 340.00 260.10 6.12 253.99 Pass: Major Risk !, j PB Z Pad Z-30 Z-30 V7 406.34 420.00 266.83 7.05 259.78 Pass: Major Risk '~, PB Z Pad Z-30 Z-30A V9 396.43 400.00 266.61 6.82 259.79 Pass: Major Risk PB Z Pad Z-31 Z-31 V1 392.49 400.00 276.25 6.87 269.38 Pass: Major Risk PB Z Pad Z-32A Z-32A V7 326.86 320.00 288.67 6.24 282.43 Pass: Major Risk ', PB Z Pad Z-326L1 Z-326L1 V2 313.22 320.00 288.59 6.17 282.42 Pass: Major Risk PB Z Pad Z-32BPB1 Z-32BPB1 V2 313.22 320.00 288.59 6.17 282.42 Pass: Major Risk ~, ', PB Z Pad Z-32BP62 Z-32BPB2 V2 313.22 320.00 288.59 6.17 282.42 Pass: Major Risk ', PB Z Pad Z-32B Z-326 V2 313.22 320.00 288.59 6.17 282.42 Pass: Major Risk PB Z Pad Z-32 Z-32 V2 313.22 320.00 288.59 6.17 282.42 Pass: Major Risk • . BP Anticollision Report Company:_ BP Amoco Date: 12L6/2005 Time: 08:34:17 Page:. 3 Field: , Prudhoe Bay ; Reference Site: PB Z Pad Co-ordinate(PiE) Reference: WeA: Plan Z-108, True North Reference Well: Plan Z-108 Vertical (TVD) Reference: Z-108. Plan 82.5 Reference Wellpath; Plan Z-'108 Db: Oracie Summary <---~-~ --- Offset Wellpath -- -----~----> Reference Offset. Ctr-Ctr No-Go- Allowable : ~-' Site Well Wellpath MD MD` ,Distance Area Deviation Warning - ft ft ft ft ft ~ PB Z Pad Z-33 Plan Z-33B V2 Plan: PI 347.73 360.00 306.87 8.05 298.81 Pass: Major Risk PB Z Pad Z-33 Z-33 V1 366.49 380.00 305.91 6.34 299.57 Pass: Major Risk PB Z Pad Z-33 Z-33A V1 347.73 360.00 306.87 7.88 298.99 Pass: Major Risk PB Z Pad Z-35P67 Z-35P61 V2 676.99 680.00 266.33 10.78 255.56 Pass: Major Risk j PB Z Pad Z-35 Z-35 V2 676.99 680.00 266.33 10.78 255.56 Pass: Major Risk PB Z Pad Z-38P61 Z-38PB1 V3 737.06 740.00 366.46 11.76 354.70 Pass: Major Risk PB Z Pad Z-38 Z-38 V5 737.06 740.00 366.46 11.76 354.70 Pass: Major Risk PB Z Pad Z-39 Z-39 V18 731.35 740.00 347.76 11.43 336.33 Pass: Major Risk PB Z Pad Z-39 Z-39A V4 731.35 740.00 347.76 11.43 336.33 Pass: Major Risk PB Z Pad Z-46 Plan Z-46A V7 Plan: PI 359.21 360.00 639.74 6.42 633.32 Pass: Major Risk PB Z Pad Z-46 Z-46 V8 Plan: Plan #10 339.35 340.00 639.37 6.10 633.27 Pass: Major Risk ~ j ~ • Field: Prudhoe Bay ~ Site: PB Z Pad '~ ' Well: Plan Z-108 ~~ ~ I Wellpath: Plan Z-108 n 100 0 l00 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation ](OONin] • . Site: PB Z Pad Drilling Target Conf.: 95% Description: Map Northing: 5956400.00 ft Map Easting :599250.00 ft - - -- -- - Latitude: 70° 17'25.156N - - y~ Pol on - _ - ------ X ft 1 -148.02 2 -151.98 3 148.02 4 151.98 - -2300 -2+00 • Target: Z-108 Tgt 1 Well: Plan Z-108 Based on: Planned Program Vertical Depth: 6530.00 ft below Mean Sea Level Local +N/-S: -2702.19 ft Loca] +E/-W: 115.23 ft Longitude 149°1.1'47.567W - Yft MapEft -_ MapNft 151.98 599100.00 5956550.00 -148.02 599100.00 5956250.00 -151.98 599400.00 5956250.00 148.02 599400.00 5956550.00 , 0 -- - - , 0 --- 0 -- - - 0 -, 0 ~ 0 0 0 ~ 0 ~ ,~ D `~ ~ ~ '~ -2500 N -2600 -200 -2800 -2900 - -3000 0 0 0 0 ~ ~ 38 ^ 37 ^ 35 ^ 34 ^ 10 ^ 9 ^ 8 ^ 7 ^ 6 ^ Z~1~84 ~ 3 ^ 2 ^ 1 ^ u 39 11 12 13 14 15 16 17 18 46 19 20 ^ 33 ^ 32 ^ 31 ^ 30 ^ 29 ^ 210i z-10r i 28 SPARE-D j SPARE-C SPARE-B ^ ^ 103i SPARE-A ^ ^ P-504A __ - ^ P-5048 r ^ 21 ^ 22 ^ 23 ^ 24 ^ 25 ^ 26 ^ Slot 1 Slot 2 ^ Slot 4 j Z-100 ^ __ __ . - ^ ^ ^ ^ ^ ^ ^ Z-101 ^ ^ ^ ^ ^ NOTES Z-PAD ~' z a J CL 18 1 Z-PAD 19 KUPARUK PIPELINE /~ 20 T11N I VICINITY MAP N.T.S. ,~~ A~ ~Q'°° 0°° ~,°° °° *e 49~ ~ o~ °°°°°°°°°°°°°°°°°°°°°°°°°°°°° °°°°°°°°°°°°°°°°°°°°°°°°°°°°° '~,°°° Richard F. Allison ' ° 1(0608 °°° ° °°°~4 ~ESS ioi~w- `' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 1,2005. 1. REFERENCE FIELD BOOK: W005-20 PGS. 7-8. 2. DATES OF SURVEY: DECEMBER 1, 2005. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD '27. 4. PAD AVERAGE SCALE FACTOR IS 0.999911213. 5. HORIZONTAL CONTROL [S BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 6. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. LEGEND ~ AS-BUILT WELL CONDUCTOR ^ EXISTING WELL CONDUCTOR LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 108 Y=5,959,100.20 N= 2,205.86 70'17'51.732" ' " 70.2977033' 54 0 4,305' FSL ' X= 599,099.16 E= 1,870.19 149'11 50.925 149.1974792' ' 3,578 FEL r. xooerl. °•~•°° K~ (~ CHECKED: JJ }~„ III DATE: R/~•/ IIIUnJ 12/02/05 " DRAWING: ~~~j1~((~~~~\\(~(~~~\\ FRees woz e6-0e GPB WOA Z-PAD SHEET: 6~ ISJUI°JOO ~0 JOB N0: scA~E: AS-BUILT CONDUCTOR 1 aF t 0 12 02 ISSUm FOR INFORMAnaN KNH JJ EMOV'~ 1WD w°9°RYFY°R5 WELL Z-108 °" ~' "~,~,'""" t"=tee' N0. DATE __ REVISION BY CNK .wa.°"•cc ww, TERRtE L H Ugg Bo oXP~~RgTION A _. NcHORgGE '4K 9 51g 6s C Mastercard C ORDE OFHE ~2 heck„ 89-6/7252 243 DA TE I ~ " a~ r Asst National ~ ~ Q~ choraye 8a k Alaska AK 99501 ~ ~ , MEMO Z , I __ ~, i 25 2.00060,.. 9 q l 4 ~., 6227.., i 55611 02t~~ s •\ • • r: TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE IiYCLUDED IN TRANSMITTAL LETTER WELL NAME ®~ ~/~. ~~ __[IL~ PTD# ~. O .S ` 2 G CHECK WHAT APPLIES A.DD-ON S "CLUE" j (OPTIONS) MULTI ~ The permit is for a new wellbore segment of LATERAL existing well , ~ Permit No, API No. (If API number ~ Production should continue to be reported as last two (2) digits ' a function of .the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all ~p~ i records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (~0 70/80) from records, data and togs acquired i for well (name on permit). SPACIlV G EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.05. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Comnanv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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