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206-075
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-217 PRUDHOE BAY UN ORIN L-217 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 L-217 50-029-23312-00-00 206-075-0 W SPT 4475 2060750 1500 885 888 885 882 589 612 617 617 4YRTST P Kam StJohn 10/13/2022 4 Yr AOGCC MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-217 Inspection Date: Tubing OA Packer Depth 6 2401 2311 2297IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221013183632 BBL Pumped:3 BBL Returned:2.5 Tuesday, December 13, 2022 Page 1 of 1 Im Pr~' W II Hi it C •r P age o~ect a story F e o e age 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. ~p - ~ ~ S Well History File Identifier Organizing (done> ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIII II II III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color 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/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ Q $ /s/ Scanning Preparation ~ x 30 = ~ o + ~~ =TOTAL PAGES__ ~~ -~ (Count does not include cover sheet) BY: / Maria 1 Date: ~ 1 1 U. I i°'~Q /sl - V Production Scanning Stage 7 Page Count from Scanned File: ~ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ J ~ V ~ /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. II I II'I II I II II I 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 ~^ '~~. ~ _ R w~[ ~' r :y; :E. t':~ of .:~ i~. Z~t~~~~ ~', ~~ ~~ , .. »W'.. ~~ MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~chl~nherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # - 'T1 t{ ~; ~, ., ~ ,,P r~9. ~~ .i!. `~ ~ ~~ ~ ~~ LOO Deccflntinn NO. 5447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 995D1 ~~ ~ q. t~ t,_.. -- ~a~ vma venter LH2-1 Alaska Data & Consulting Services 900 E. BenSOn BIVd. 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~:.~,~"„~4~''~e~:;:.~; `;~'',` ``• -' ~~~~ ~ bp ~,~~~~I~~~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 6 5 2009 ~IasYc~ ~il ~C Gas Cons. Gommisgior~ Anchorage ~~`~'~Q/~~ ~ ~, ! ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- 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 Ezplaation (Alaska ) Mc. ~ Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report ot Sundry Operations (10-404) Date L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion i~hibitod sealant date ft bbls (t na al L-Ot 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2,8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA ~-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5f612009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 1-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA i NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 1-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L420 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 1-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 1-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 I S" ~ `~-- DATA SUBMITTAL COMPLIANCE REPORT 7i7i2oos Permit to Drill 2060750 Well Name/No. PRUDHOE BAY UN ORIN L-217 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23312-00-00 MD 8793 TVD 4843 Completion Date 7/15/2006 Completion Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Current Status WAGIN UIC Y Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, GR / RERS 1 PWD, NEU / AZI /DEN /Caliper, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type MediFrmt Number Name Scale Media No - --- - D Asc Directional Survey t Directional Survey Cement Evaluation 5 Col 1 C Las 14489 Casing collar locator D C Lis 15258 InductionlResistivity 15258 InductionlResistivity 15258 Induction/Resistivity 25 Blu 25 Blu We11 Cores/Samples Information: Name ADDITIONAL INFORMA~ON Well Cored? Y(~/~I ~ Chips Received? ~7td~-~ Analysis 1'LL~Ii Received? (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 0 8793 Open 9/14!2006 - 0 8793 Open 9/14/2006 3000 8650 Open 7/25/2006 USCT Evaluation, 6.05' Gauge Ring/Junk Basket 13-Jul-2006 2984 8656 Case 2/20/2007 GRCH, CCL w/Graphics 65 8799 Open 7/3/2007 LIS Veri, GR, ROP, FET, DRHO, NPHI w/Graphics PDF, TIF 108 8793 Open 7/3/2007 TVD Vision Service 10-Ju1- 2006 108 8793 Open 7/3/2007 MD Vision Service 10-Ju1- 2006 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~' +" Formation Tops 'Q/ N r Comments: DATA SUBMITTAL COMPLIANCE REPORT 7i7i2oos Permit to Drill 2060750 Well Name/No. PRUDHOE BAY UN ORIN L-217 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23312-00-00 MD 8793 TVD 4843 Completion Date 7/15/2006 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: Date: o71oz1o7 ,, 1I kJ Schl~ua~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 89503-2838 ATTN: Beth Well Job # log Description N0.4326 Company: Alaska Oil & Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Date BL Color CD L-214A 40013220 OH EDIT MWD/LWD 03/14106 2 1 L-217 40073757 OH EDIT MWD/LWD 07/10/08 2 1 L-250L2 400t2593 OHEDl7MWD/LWD 11/24/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY 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: ~ 1.L a0~o-OAS ~ ~Sc7S~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh Received by: r- ~~ N 02/12/2007 Schtumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.4133 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Date BL Color CD L-217 11212874 CH EDIT USIT PDC-GR 07N 3106 1 2.103 PB2 40011520 OH EDIT MWDILWD 02115105 2 1 V-111 P81 V-111 PB2 40009265 40009265 OH EDIT MWDILWD OH EDIT MWDILWD 07/16103 07/26103 6 2 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPV EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508-4254 ~ f~~ k ,'.I i; -. ..E~--' Date Delivered: ~~• ~ ~ ~~~ s Schlumberger•DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2038 ATTN: Beth Received - - ~Ep 2 9 2006 ~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION CO SION Alaska Oil ~ Gas~~.LC@i~@7MTI~~TION OR RECOMPLETION REPORT AND LOG Anchorage Revised: 09/28/06, Put on Injection 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC 2s.1os 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/15/2006 12. Permit to Drill Number 206-075 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/3/2006 13. API Number 50-029-23312-00-00 4a. location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/10/2006 14. Well Name and Number: PBU L-217 2579 FEL, SEC. 34, T12N, R11 E, UM FSL, 3662 Top of Productive Horizon: 2818' FSL, 1975' FEL, SEC. 27, T12N, R11 E, UM 8. KB Elevation (ft): 78.1' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 3603' FSL, 1747' FEL, SEC. 27, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 8705 + 4802 Ft Schrader Bluff 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583253 y- 5978301 Zone- ASP4 10. Total Depth (MD+TVD) 8793 + 4843 Ft 16. Property Designation: ADL 028239 TPI: x- 584866 y- 5983838 Zone- ASP4 Total Depth: x- 585085 y- 5984626 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, GR / RES / PWD, NEU / AZI /DEN /Caliper, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DERTH MD SETTING D EPTH TVQ' HOLE AMOUNT SIZE WT. PER FT. GRADE TOP < BOTTONF< TpP BOTTOM SIZE CEMENTING REGORD PULLED 20" 90# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3999' 29' 2760' 12-1 /4" 805 sx AS Lite, 143 sx'G', TJ: 211 sx AS Lite 7" 26# L-80 25' 8783' 25' 4838' 8-3/4" 94 sx LiteCrete 398 sx Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECGRD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 8478' 8000' & 8147' & MD TVD MD TVD 8263' & 8367 8020' - 8128' 4484' - 4533' 8162' - 8188' 4549' - 4561' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8280' - 8330' 4605' - 4628' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 8392' - 8514' 4657' - 4713' Freeze Protect w/ 125 Bbls of Diesel 26. PRODUCTION TEST Date First Production: September 2, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or~swater (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~ ~~ ~G ~ ~ Z00~ None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE i8. GEOLOGIC MARK 29. ORMATION TESTS ~ Include and brie ummarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4270' 2871' None Ugnu MA 7004' 4036' Ugnu M61 7101' 4079' Ugnu MB2 7266' 4151' Ugnu MC 7447 4231' Schrader Bluff NA 7531' 4269' Schrader Bluff NB 7585' 4293' Schrader Bluff NC 7658' 4326' Schrader Bluff NE 7684' 4337' Schrader Bluff OA 7873' 4420' Schrader Bluff OBa 8022' 4485' Schrader Bluff OBa 8047' 4496' Schrader Bluff OBb 8063' 4503' Schrader Bluff OBc 8283' 4606' Schrader Bluff OBd 8395' 4658' Schrader Bluff OBe 8542' 4726' Schrader Bluff OBf 8629' 4767' Base Schrader Bluff (OBf) 8725' 4811' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed SondraN tewman __sitle Technical Assistant Date l~- )' (~(_o PBU L-217 206-075 Prepared By Name/Number. Sondra Stewman, 564-4750 Drilling Engineer: Brandon Peltier, 564-5912 Well Number Permit N . / A royal No. INSTRUCTIONS GeNew-~: 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. IreM 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). Irenr 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 MEMORANDUM To~ Jim Regg P.I. Supervisor r`~4~'G; ' ~~ °'~~''r' FROiVt: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, September l8, 2006 StiBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-217 PRUDHOE BAY UN ORIN L-217 Src: Inspector NON-CONFIDENTIAL ~~ ` ~/ G.~ Reviewed ByJ_ P.I. Suprv ~_i ~~ Comm Well Name: PRUDHOE BAY UN ORIN L-217 Insp Num: miUJ060913122548 Rel Insp Num API Well Number 50-029-23312-00-00 Permit Number: 206-075-0 Inspector Name: Jeff Jones Inspection Date: 9/11/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-zv iType Inj. i w ~ TVD ~ aa7s I, IA sso ~ zooo~ _t9~ I93s 2 70 06 70 06 50 , SPT P.T. ~TypeTeSt ~ ~ Test pSl I li00 OA 380 520 ~ 530 530 Interval INITAL P/F P ~' Tubing'., iooo 00 ' Iooo tooo ' ~ Notes 1.1 bbls methanol pumped. 1 well house inspected; no exceptions noted. Monday, September i 8, 2006 Page 1 of 1 :liLL - } t ,8„ 'UVFILHF~D= FrsiG . __ A cTUA Tt7R _ _._. In BF F7FV- Kt~P Jup' Max Angie ~ ~~M ~aG" @ 37fl0' ~~~ DaEum MD = xx;cx' Datum T~ID ° xxxx 3S 3~2"~X 1-`lf~" MMG•UIf IiVHICH /~i~E _ ~ ~'" W~1~E~'F7_C10D MANdRELS. 3~- 6Q3' -~ s=(!2" HES x rllP, RL} = 2.813" -sJS° csG, 44#; L-84, ID = a.s3s° ~s2~' 7° 26# ~-ao Tc a :~ 7° 26# ~-ac BTC-b1 xo it 5601' ?" (41ARKF_R JOINT W! RA TAG 7007' IIAARKER Jt71NTV1Y1 RA TAG I~ 78Si" 3.5" X 1.5°` MMG-W GI...IIA PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERP 64° @ 8020' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnJSgz DATE 4-112" 5 8020 - 8128 O 07!15/06 4-1I2" 5 8162 - 8188 O 07115!06 4-1r2" 5 8280 - 8330 O 07/15/06 4-112" 5 8392 - 8514 O 07!15!06 3-1!2" 78t;. 9.2~, I_-30, .8037 I7p1, fD = 2~~2" ~'~ `~ L~ 3`::1;35., r' cs a, 26#, L-3t~, IIa = 6.276~ 8783' V1tA1'FRFI n~f1'~A s LIFT t~tAN13RCLS ST MD TV D DEV TY PF_ V LYY LA Tr H PtORT DATE 8 7888 , 64 MAAG DMY RK Q 48121 J06 7 8426 64 (v~G-~JV DY RK 0 r?7i1$J416' 5 ~ _ 62 h'~ttG-W ... RK 8i `~;,~i1ci: 5 =. ; ~ ~ 4557 I~2 Pi1tu~G-Vtl DNiY RK 4 47/151Q6 4 ~ ~ ~:.., .v 3'f MMG-W , ~~ i ~ RK Y8 ...:'6 3 4b 1 b 32 I+AIt1IG-L+~J DMY RK 4 471 i SJfl& 2 8343 4834 62 MMG-W RK 4 gat 7t; 1 - ,' Fs2 MMG-~fil RK ~ ~.8?. ~~vu 7979' 3-1 f2" HES XNIP, ID = 2.813" 8000' 7" X3-1/2" BKR PREMIER PKR, ID = 2.87" ~$ ~' ~ 7" X 3-1!2" BKR PREMIER PKR, 1D = 2.87" $'~ 69" '~3=112" HE.i X R1EP, ID = 2_x13"~ 82A~8' 3-112" HES X NIP, ID = 2.813" $263' 7" X3-112" BKR PREMIER PKR, ID = 2.87" $367'.._ ~ T X 3-1 '2' BKR PREMIER PKP, ID ~ 2.87" 83$4' 3-1/2" HES X NIP, ID = 2.813" wJRHC-m plug s;:~„:~' 3-1 J2"' HES X NIP, ID = 2.813'" w JR.HC-m p#u ~i^, ~ 3 S;2" HES XNIP, 3L3 = 2.313:' 8a:;?~ ~' 3-112„ V+ILEG, iD - 2.92" ~~.. ..DATE. REV BY COIIlIC~tEhTfS DA TE.... REV BY CC1P41~VIEhITS (}~rJ13J06 BJP Prapased Campleti©n Ver. 1.4 47J15Y06 AM Final rig revsion 07!17!96 DAVJPJC DRLG E3RAFT UPCIATES 48Y24Y4ii [vISS/PA G GLtJ CYO (43!21 J46) 48!29!46 JCMfPAG GLV GO ORIpN UNIT WELL: L-2171 PERMIT Na: 2A5-475 API Nb: 54.42-23;312-flp SEy 34, T12N, R11 E, 2579' I`SL ~ 3&82' FEI_ BP Explora#iar~ (Alaska} N Q J SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Orion Well .....................: L-217 API number ...............: 50-029-23312-00 Engineer .................: M. St. Amour RIG :...................... Nabors 9ES 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 49.60 ft N/A (Topdrive) 78.10 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: 16.63 degrees 10-Jul-2006 13:10:44 Page 1 of 5 Spud date ................: 03-Jul-2006 Last survey date.........: 10-Jul-06 Total accepted surveys...: 96 MD of first survey.......: 0.00 ft MD of last survey........: 8793.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 02-Jul-2006 Magnetic field strength..: 57579.58 GAMA Magnetic dec (+E/W-).....: 24.18 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57579.50 GAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.18 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.18 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 • • k' SCHLUMBERGER Survey Report 10-Jul-2006 13:10:44 Page 2 of 5 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) (f t) (f t) (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 2 100.00 0.31 81.57 100.00 100.00 0.11 0.04 0.27 0.27 81.57 0.31 BP _GYD CT DMS 3 171.00 0.69 67.49 71.00 171.00 0.47 0.23 0.85 0.88 74.81 0.56 BP _GYD CT DMS 4 264.00 1.07 72.82 93.00 263.99 1.30 0.70 2.20 2.31 72.29 0.42 BP _GYD CT DMS 5 358.00 1.24 76.43 94.00 357.97 2.30 1.20 4.03 4.20 73.40 0.20 BP GYD CT DMS 6 445.00 1.11 65.82 87.00 444.95 3.33 1.77 5.71 5.98 72.81 0.29 BP _GYD CT DMS 7 539.00 1.18 78.78 94.00 538.93 4.37 2.33 7.49 7.84 72.74 0.28 BP - GYD CT DMS • 8 633.00 1.67 80.45 94.00 632.90 5.43 2.74 9.79 10.17 74.35 0.52 BP _GYD CT DMS 9 728.00 1.49 60.63 95.00 727.86 6.93 3.58 12.23 12.74 73.69 0.60 BP _GYD CT DMS 10 820.00 2.61 31.71 92.00 819.81 9.81 5.95 14.38 15.56 67.52 1.62 BP GYD CT DMS 11 912.00 4.82 16.66 92.00 911.61 15.70 11.43 16.59 20.14 55.42 2.61 BP _GYD CT DMS 12 1007.00 8.72 19.65 95.00 1005.93 26.89 22.04 20.15 29.87 42.43 4.12 BP _GYD CT DMS 13 1041.84 10.26 19.25 34.84 1040.29 32.63 27.46 22.06 35.23 38.78 4.42 BP _MWD+IFR+MS 14 1136.75 13.38 19.15 94.91 1133.18 52.04 45.82 28.45 53.93 31.84 3.29 BP _MWD+IFR+MS 15 1232.61 16.47 15.04 95.86 1225.79 76.72 69.43 35.62 78.03 27.16 3.41 BP MWD+IFR+MS 16 1327.93 19.71 16.60 95.32 1316.39 106.30 97.89 43.72 107.21 24.07 3.44 BP _MWD+IFR+MS 17 1424.00 25.53 16.03 96.07 1405.03 143.24 133.34 54.08 143.89 22.07 6.06 BP _MWD+IFR+MS 18 1519.27 30.41 16.99 95.27 1489.15 187.91 176.16 66.80 188.40 20.77 5.14 BP _MWD+IFR+MS 19 1614.97 33.53 16.68 95.70 1570.33 238.57 224.65 81.47 238.97 19.93 3.26 BP _MWD+IFR+MS 20 1710.56 37.34 15.70 95.59 1648.20 293.98 277.87 96.89 294.28 19.22 4.03 BP MWD+IFR+MS 21 1806.85 40.66 14.86 96.29 1723.02 354.55 336.32 112.85 354.75 18.55 3.49 BP _MWD+IFR+MS • 22 1902.72 45.08 15.29 95.87 1793.26 419.73 399.28 129.81 419.85 18.01 4.62 BP _MWD+IFR+MS 23 1998.15 49.40 16.16 95.43 1858.04 489.77 466.70 148.82 489.85 17.69 4.58 BP _MWD+IFR+MS 24 2093.54 52.17 16.24 95.39 1918.34 563.67 537.67 169.43 563.73 17.49 2.90 BP _MWD+IFR+MS 25 2189.15 55.09 17.59 95.61 1975.03 640.64 611.30 191.85 640.70 17.42 3.26 BP MWD+IFR+MS 26 2284.62 60.24 17.06 95.47 2026.08 721.27 688.29 215.85 721.34 17.41 5.41 BP _MWD+IFR+MS 27 2380.68 61.90 17.39 96.06 2072.55 805.34 768.59 240.75 805.41 17.39 1.75 BP _MWD+IFR+MS 28 2476.21 62.61 17.21 95.53 2117.02 889.88 849.31 265.89 889.95 17.38 0.76 BP _MWD+IFR+MS 29 2571.56 63.10 16.97 95.35 2160.52 974.72 930.41 290.82 974.80 17.36 0.56 BP _MWD+IFR+MS 30 2666.65 63.23 17.08 95.09 2203.45 1059.57 1011.54 315.67 1059.65 17.33 0.17 BP MWD+IFR+MS SCHLUMBERGER Survey Report 10-Jul-2006 13:10:44 Page 3 of 5 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 2763.93 61.67 16.86 97.28 2248.44 1145.81 1094.03 340.84 1145.89 17.30 1.62 BP MWD+IFR+MS 32 2859.06 63.14 16.65 95.13 2292.51 1230.12 1174.76 365.14 1230.20 17.27 1.56 BP _ MWD+IFR+MS 33 2954.70 64.72 15.53 95.64 2334.54 1316.02 1257.30 388.95 1316.08 17.19 1.96 BP _ _MWD+IFR+MS 34 3050.02 67.46 15.87 95.32 2373.17 1403.14 1341.18 412.53 1403.19 17.10 2.89 BP MWD+IFR+MS 35 3145.95 66.06 15.52 95.93 2411.02 1491.27 1426.04 436.37 1491.31 17.01 1.50 BP _ MWD+IFR+MS 36 3241.76 65.89 15.33 95.81 2450.02 1578.76 1510.39 459.65 1578.79 16.93 0.25 BP _MWD+IFR+MS 37 3337.69 65.29 14.76 95.93 2489.67 1666.08 1594.75 482.32 1666.09 16.83 0.83 BP _MWD+IFR+MS 38 3433.75 65.76 15.21 96.06 2529.47 1753.48 1679.21 504.93 1753.48 16.74 0.65 BP _MWD+IFR+MS 39 3528.50 64.97 15.20 94.75 2568.96 1839.58 1762.32 527.52 1839.58 16.66 0.83 BP _MWD+IFR+MS 40 3624.19 66.70 14.89 95.69 2608.13 1926.84 1846.63 550.18 1926.84 16.59 1.83 BP MWD+IFR+MS 41 3720.13 66.69 14.57 95.94 2646.09 2014.91 1931.84 572.58 2014.91 16.51 0.31 BP _MWD+IFR+MS 42 3815.84 65.92 14.25 95.71 2684.55 2102.48 2016.73 594.39 2102.50 16.42 0.86 BP _MWD+IFR+MS 43 3910.72 65.07 14.24 94.88 2723.90 2188.74 2100.40 615.64 2188.77 16.34 0.90 BP _MWD+IFR+MS 44 3944.19 66.02 14.01 33.47 2737.76 2219.18 2129.95 623.07 2219.21 16.31 2.91 BP _MWD+IFR+MS 45 4030.89 66.08 14.47 86.70 2772.96 2298.34 2206.75 642.56 2298.40 16.23 0.49 BP MWD+IFR+MS 46 4085.92 66.36 14.60 55.03 2795.15 2348.67 2255.50 655.20 2348.73 16.20 0.55 BP _MWD+IFR+MS 47 4181.80 65.77 16.26 95.88 2834.05 2436.28 2339.97 678.51 2436.36 16.17 1.70 BP _MWD+IFR+MS 48 4277.29 65.26 17.00 95.49 2873.62 2523.18 2423.24 703.38 2523.26 16.19 0.88 BP _MWD+IFR+MS 49 4372.57 64.66 17.04 95.28 2913.95 2609.50 2505.78 728.65 2609.57 16.21 0.63 BP _MWD+IFR+MS 50 4468.30 64.61 18.15 95.73 2954.96 2695.99 2588.23 754.80 2696.05 16.26 1.05 BP MWD+IFR+MS 51 4564.31 64.41 18.77 96.01 2996.28 2782.61 2670.44 782.24 2782.65 16.33 0.62 BP _MWD+IFR+MS 52 4660.59 64.64 18.42 96.28 3037.69 2869.48 2752.82 809.95 2869.50 16.40 0.41 BP _MWD+IFR+MS 53 4755.78 65.10 17.86 95.19 3078.11 2955.63 2834.72 836.78 2955.64 16.45 0.72 BP _MWD+IFR+MS 54 4851.22 66.42 18.42 95.44 3117.30 3042.62 2917.41 863.88 3042.63 16.49 1.48 BP _MWD+IFR+MS 55 4946.78 66.65 18.63 95.56 3155.35 3130.23 3000.53 891.73 3130.23 16.55 0.31 BP MWD+IFR+MS 56 5042.24 64.73 19.17 95.46 3194.65 3217.15 3082.83 919.91 3217.15 16.61 2.08 BP _MWD+IFR+MS 57 5138.10 64.88 17.93 95.86 3235.45 3303.84 3165.06 947.50 3303.84 16.67 1.18 BP _MWD+IFR+MS 58 5233.79 66.19 17.33 95.69 3275.08 3390.92 3248.07 973.88 3390.93 16.69 1.48 BP _MWD+IFR+MS 59 5329.61 65.71 17.24 95.82 3314.13 3478.42 3331.62 999.87 3478.42 16.71 0.51 BP _MWD+IFR+MS 60 5425.52 65.65 17.10 95.91 3353.63 3565.81 3415.12 1025.68 3565.82 16.72 0.15 BP MWD+IFR+MS • SCHLUMBERGER Survey Report 10-Jul-2006 13:10:44 Page 4 of 5 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Disp1 -------- -------- 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) -------- (f t) -------- (f t) --------- (deg) ------ 100f) ----- type (deg) ----- ------ -- 61 - -- -- 5521.81 ------ 65.37 ------- 17.32 ------ 96.29 -------- 3393.55 -------- 3653.44 -------- 3498.83 -------- 1051,60 --------- 3653.44 ------ 16.73 ----- 0.36 - BP ---- ------ _MWD+IFR+MS 62 5617.29 65.87 17.13 95.48 3432.96 3740.40 3581.89 1077.35 3740.41 16.74 0.55 BP _MWD+IFR+MS 63 5712.52 65.23 17.86 95.23 3472.38 3827.08 3664.57 1103.41 3827.09 16.76 0.97 BP _MWD+IFR+MS 64 5808.37 65.36 17.90 95.85 3512.44 3914.13 3747.44 1130.15 3914.15 16.78 0.14 BP _MWD+IFR+MS 65 5904.01 65.33 17.97 95.64 3552.33 4001.03 3830.14 1156.91 4001.05 16.81 0.07 BP MWD+IFR+MS 66 5999.77 65.31 18.07 95.76 3592.32 4088.02 3912.88 1183.83 4088.04 16.83 0.10 BP _MWD+IFR+MS 67 6095.24 64.99 18.47 95.47 3632.44 4174.61 3995.15 1210.99 4174.65 16.86 0.51 BP - MWD+IFR+MS 68 6190.32 63.93 16.71 95.08 3673.43 4260.38 4076.92 1236.92 4260.42 16.88 2.01 BP _MWD+IFR+MS 69 6286.63 62.98 16.72 96.31 3716.47 4346.54 4159.43 1261.70 4346.58 16.87 0.99 BP _MWD+IFR+MS 70 6382.44 62.89 16.86 95.81 3760.07 4431.86 4241.11 1286.34 4431.90 16.87 0.16 BP _MWD+IFR+MS 71 6477.90 63.33 16.70 95.46 3803.24 4517.00 4322.63 1310.92 4517.04 16.87 0.48 BP _MWD+IFR+MS 72 6573.52 63.37 16.45 95.62 3846.13 4602.46 4404.54 1335.30 4602.50 16.87 0.24 BP _MWD+IFR+MS 73 6669.16 63.59 17.38 95.64 3888.84 4688.03 4486.41 1360.20 4688.07 16.87 0.90 BP _MWD+IFR+MS 74 6764.64 63.69 17.41 95.48 3931.23 4773.58 4568.05 1385.78 4773.62 16.88 0.11 BP _MWD+IFR+MS 75 6860.51 63.91 17.64 95.87 3973.56 4859.59 4650.08 1411.68 4859.63 16.89 0.31 BP _MWD+IFR+MS 76 6955.77 64.14 16.09 95.26 4015.28 4945.22 4732.03 1436.52 4945.27 16.89 1.48 BP _MWD+IFR+MS 77 7051.09 64.13 15.96 95.32 4056.86 5030.99 4814.47 1460.20 5031.03 16.87 0.12 BP _MWD+IFR+MS 78 7147.44 64.04 16.30 96.35 4098.97 5117.64 4897.72 1484.28 5117.68 16.86 0.33 BP _MWD+IFR+MS 79 7242.93 63.87 16.56 95.49 4140.90 5203.44 4980.00 1508.54 5203.47 16.85 0.30 BP _MWD+IFR+MS 80 7338.98 63.98 17.00 96.05 4183.12 5289.71 5062.60 1533.45 5289.75 16.85 0.43 BP _MWD+IFR+MS 81 7434.19 63.20 17.09 95.21 4225.47 5374.98 5144.13 1558.4 5 5375.02 16.85 0.82 BP _MWD+IFR+MS 82 7529.45 63.28 17.26 95.26 4268.36 5460.03 5225.40 1583.56 5460.08 16.86 0.18 BP _MWD+IFR+MS 83 7625.56 63.71 17.37 96.11 4311.25 5546.03 5307.51 1609.16 5546.08 16.87 0.46 BP _MWD+IFR+MS 84 7721.53 63.78 17.71 95.97 4353.70 5632.09 5389.57 1635.10 5632.14 16.88 0.33 BP _MWD+IFR+MS 85 7817.18 63.94 17.62 95.65 4395.84 5717.95 5471.39 1661.16 5718.00 16.89 0.19 BP MWD+IFR+MS 86 7912.70 64.17 17.04 95.52 4437.64 5803.83 5553.39 1686.74 5803.89 16.90 0.60 BP _MWD+IFR+MS 87 8008.03 64.66 17.14 95.33 4478.80 5889.81 5635.57 1712.01 5889.88 16.90 0.52 BP _MWD+IFR+MS 88 8103.72 62.54 16.61 95.69 4521.35 5975.52 5717.58 1736.89 5975.58 16.90 2.27 BP _MWD+IFR+MS 89 8199.38 61.43 16.18 95.66 4566.28 6059.96 5798.60 1760.73 6060.03 16.89 1.23 BP _MWD+IFR+MS 90 8295.43 61.99 16.11 96.05 4611.80 6144.54 5879.84 1784.25 6144.60 16.88 0.59 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 10-Jul-2006 13:10:44 Page 5 of 5 --- --- 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) -------- (f t) --------- (deg) ------ 100f) ----- type (deg) ----- ------ 91 -------- 8390.76 ------ 62.44 ------- 16.12 ------ 95.33 -------- 4656.24 -------- 6228.87 -------- 5960.87 -------- 1807.66 --------- 6228.93 ------ 16.87 ----- 0.47 ----- ------ BP_MWD+IFR+MS 92 8486.71 62.35 16.08 95.95 4700.70 6313.90 6042.56 1831.24 6313.95 16.86 0.10 BP_MWD+IFR+MS 93 8582.48 62.34 15.70 95.77 4745.15 6398.72 6124.15 1854.46 6398.77 16.85 0.35 BP_MWD+IFR+MS 94 8677.92 62.35 15.19 95.44 4789.45 6483.24 6205.63 1876.97 6483.28 16.83 0.47 BP_MWD+IFR+MS 95 8720.18 62.46 15.05 42.26 4809.03 6520.68 6241.79 1886.74 6520.71 16.82 0.39 BP_MWD+IFR+MS 96 8793.00 62.46 15.05 72.82 4842.70 6585.22 6304.14 1903.51 6585.25 16.80 0.00 Projected to TD [(c)2006 IDEAL ID10 2C O1] • ~~ • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No L-217 Installation/Rig Nabors 9ES Dispatched To: AOGCC Library Date Dispatched: 16-Aug-06 Dispatched By: Melyssa Schaaf Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division ~~ , 1~ /. 2525 Gambell Street, Suite 400 ~ 1 C ~- V ~ Anchorage, Alaska 99501 nroselC~slb.com fax:907-561-8317 LWD Log Delivery V1.1,10-02-03 ap ~,- ~Z ~ STATE OF ALASKA ALAS •IL AND GAS CONSERVATION COM ISSION RECEIVED AU G 1 5 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LO~aska Oil & Gas Cons. Commission Anchorage 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAACZS.,os zoAACZS.1,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/15/2006 12. Permit to Drill Number 206-075 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/3/2006 13. API Number 50-029-23312-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/10/2006 14. Well Name and Number: PBU L-217 2579 FSL, 3662 FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2818' FSL, 1975' FEL, SEC. 27, T12N, R11 E, UM 8. KB Elevation (tt): 78.1' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 3603' FSL, 1747' FEL, SEC. 27, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 8705 + 4802 Ft Schrader 81uff 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583253 y- 5978301 Zone- ASP4 10. Total Depth (MD+TVD) 8793 + 4843 Ft 16. Property Designation: ADL 028239 TPI: x- 584866 y- 5983838 Zone- ASP4 Total Depth: x- 585085 y- 5984626 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, GR / RES / PWD, NEU / AZI /DEN /Caliper, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO SETTING D EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 90# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3999' 29' 2760' 12-1 /4" 805 sx AS Lite, 143 sx'G', TJ 211 sx AS Lite 7" 26# L-80 25' 8783' 25' 4838' 8-3/4" 94 sx LiteCrete 8 sx Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 8478' 8000' & 8147' & MD TVD MD TVD 8263' & 8367' 8020 - 8128' 4484' - 4533' 8162' - 8188' 4549' - 4561' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 82$0' - 8330' 4605' - 4628' DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED 8392' - 8514' 4657' - 4713' Freeze Protect w/ 125 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of it as or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". S BF~ AUG ~ 6 1006 ~OM.PL~TI01~ None _ y~ATE Form 10-407 •I'Ce~2003 n ~ONTINUED ON REVERSE SIDE ORIGINH~ 28. ~ GEOLOGIC MARK 29. ORMATION 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 4270' 2871' None Ugnu MA 7004' 4036' Ugnu MB1 7101' 4079' Ugnu MB2 7266' 4151' Ugnu MC 7447' 4231' Schrader Bluff NA 7531' 4269' Schrader Bluff NB 7585' 4293' Schrader Bluff NC 7658' 4326' Schrader Bluff NE 7684' 4337 Schrader Bluff OA 7873' 4420' Schrader Bluff OBa 8022' 4485' Schrader Bluff OBa 8047' 4496' Schrader Bluff OBb 8063' 4503' Schrader Bluff OBc 8283' 4606' Schrader Bluff OBd 8395' 4658' Schrader Bluff OBe 8542' 4726' Schrader Bluff OBf 8629' 4767' Base Schrader Bluff (OBf) 8725' 4811' 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. O ~ / Signed Terrie Hubble Title Technical Assistant Date ~~~ip PBU L-217 206-075 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Brandon Peltier, 564-5912 INSTRUCTIONS GeNew-~: 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. IreM 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 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: L-217 Common Name: L-217 -- _ _ _ __ __ _ , Test Date Test Type ~ _ _ --- --~ Test Depth (TMD) i Test Depth (TVD) - AMW T Surface Pressure ~ Leak Off Pressure (BHP) EMW 7/9/2006 LOT 3,998.0 (ft) 2,759.0 (ft) 8.80 (ppg) 668 (psi) 1,929 (psi) 13.46 (ppg) Printed: 7/17/2006 1:51:08 PM BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: L-217 Common Well Name: L-217 Spud Date: 7/3/2006 Event Name: DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations ~- 7/1/2006 20:00 - 00:00 4.00 RIGD P PRE RDMO L-51. Bridle up the derrick and prep the rig floor to move. LD the cattle chute and the derrick. Disconnect from the pits. Move the surface stack from the drillers side ti the off drillers side. Raise the cellar doors. MU the target "T's" to the diverter line. 7/2/2006 00:00 - 04:00 4.00 MOB P PRE Move the sub off of L-51. Move and spot the surface stack on L-217 conductor. Lay mats and herculite. Move the sub and spot over L-217. Rig accepted at 0400 hours 04:00 - 11:00 7.00 RIGU P PRE Raise the derrick and the chute and pin in place. Hold PJSM and RU diverter line with crane. Move in and spot the pit complex. 11:00 - 12:00 1.00 RIGU P PRE Change out the riser nipple from 16" to 20". 12:00 - 14:30 2.50 RIGU P PRE Start taking on water and mixing spud mud. NU the riser and MU the Dresser sleeve. Install 4" valves. 14:30 - 16:00 1.50 RIGU P PRE RU the rig floor and changeout the quill. 16:00 - 17:00 1.00 RIGU P PRE Service the top drive, blocks, draw works and crown. 17:00 - 21:00 4.00 RIGU P PRE PU 105 joints of 4" HT40 DP and stand back in the derrick 35 stands. 21:00 - 22:00 1.00 RIGU P PRE PU 24 joints of 4" HW DP and stand back 8 stands. 22:00 - 23:00 1.00 RIGU P PRE Bring BHA components to the rig floor. 23:00 - 23:30 0.50 RIGU P PRE MU jar stand, collar stand and stand back 23:30 - 00:00 0.50 DIVRTR P PRE Test the diverter system. Witness of the test was waived by John Crisp of the AOGCC. 7/3/2006 00:00 - 01:30 1.50 RIGU P PRE Pre-spud meeting held during the pre-tour meeting. PU BHA#1 as per Directional driller. 01:30 - 02:30 1.00 RIGU P PRE RU Halliburton E-line and Gyrodata gyro. Fill lines and check for leaks -good. 02:30 - 11:30 9.00 DRILL P SURF Spud L-217 and drill ahead directionally to 361'. POH to the drill collars and MU jar stand. RIH to 361' without seeing any fill. Drill 12-1/4" ahead directionally taking gyro surveys every 100' to 1,101', PU - 75k, SO - 72k, ROT - 72k, 1,485 psi on, 1,190 psi off, 80 rpm, 9k TO on, 2.4k TO off, AST - 1.97, ART - 2.87 11:30 - 12:00 0.50 DRILL P SURF RD Gyrodata and Halliburton E-line. 12:00 - 00:00 12.00 DRILL P SURF Drill 12-1/4" ahead directionally from 1,101' to 2,631', PU - 90k, SO - 75k, ROT - 80k, 2,800 psi on, 2,630 psi off, 80 rpm, 6k TO on, 3k TO off, AST - 7.13, ART - 1.97 7/4/2006 00:00 - 09:00 9.00 DRILL P SURF Drill 12-1/4" ahead directionally from 2,631' to TD a! 4,005' MD, 2,762' TVD. PU - 101 k, SO - 71 k, ROT - 85k, 632 gpm, 3,250 psi on, 3,110 psi off, 80 rpm, 8-9k TO on, 4.5k TO off. AST - 2.36 hrs, ART - 3.4 hrs. Had hydrates from 1,950' to TD. 09:00 - 10:00 1.00 DRILL P SURF Circulate bottoms up ~ 650 gpm, 3,380 psi, 100 rpm, 4k TO, ROT - 85k, MW - 9.5 ppg. 10:00 - 14:30 4.50 DRILL P SURF Short trip out by backreaming from 4,005 to 1,101'. 632 gpm, 3,220 psi, 80 rpm, 4k TO. 14:30 - 15:00 0.50 DRILL P SURF Pump out without rotating and circulate bottoms up from 1,101' to 1,006'. Pulled one stand HWDP without pumping to 914'. PU - 80k, SO - 70k. 15:00 - 16:00 1.00 DRILL P SURF Trip in hole from 914' to 3,971' without problem. Wash last stand down to 4,005'. 16:00 - 18:30 2.50 DRILL P SURF Circulate 3-1/2 bottoms up C~ 660 gpm, 3,475 psi, RWT - 85k, 100 rpm, 4k TO. 18:30 - 00:00 5.50 DRILL P SURF POOH to run surface casing from 4,005' to 3,397'. No pipe Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Legal Well Name: L-217 Common Well Name: L-217 Event Name: DRILL+COMPLETE Start: 7/1/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To ' Hours I Task I Code ! NPT I Phase 7/4/2006 18:30 - 00:00 - r 5.50 DRILL ~ P SURF 7/5/2006 00:00 - 01:30 i 1.501 DRILL I P 01:30 - 02:00 0.50 DRILL P 02:00 - 04:00 2.00 CASE P 04:00 - 05:00 1.00 CASE P 05:00 - 20:00 15.00 CASE P 20:00 - 00:00 4.00 CASE P 7/6/2006 00:00 - 04:00 4.00 CASE P 04:00 - 04:30 0.50 CEMT P 04:30 - 08:30 4.00 CEMT P 08:30 - 09:00 0.50 CEMT P 09:00 - 11:30 2.50 CEMT N 11:30 - 14:30 I 3.001 CEMT I P SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF CEMT SURF SURF Page 2 of 10 Spud Date: 7/3/2006 End: 7/15/2006 Description of Operations displacement. No overpull or swabbing indications but hydrates breaking out at bell nipple. Continue POH by pumping out of hole ~ 3 bpm, 300 psi without rotation from 3,397' to 550' with correct pipe displacement. Pulled tight at 550', 460', and 360'. Indications showed that obstruction was not at bit but possibly on side of pipe or stabilizers. Backream through tight spots and circulated a bottoms up from 362' to 270' ~ 450 gpm, 600 psi, 85 rpm, 5k TO. Returned large amount of big and small pieces of wood back to shakers. Continue POH from 270' without pumping or problems. Laydown BHA #1. Clear and clean rig floor. Rig up to run 9-5/8" casing. Make hanger dummy run. Pickup and make up shoe track with Baker-Lok. Check floats - OK. Continue running in hole with 9-5/8" 40# L-80 BTC casing to 580'. 9,200 fUlbs make up torque using Best-O-Life lubricant. Hit obstruction ~ 580'. Wash and work pipe through obstruction from 580' to 1,356'. 170 gpm, 260 psi. Returning sand, pea gravel, and wood chunks over shakers. Indications showed that each bowspring centralizer was catching on obstruction. Cut number of centralizers from 25 to 19. Once last centralizer was past 580' pipe went down OK. Continue running in hole with 9-5/8" casing, washing down each joint from 1,356' to 2,425' without problem. 278 gpm, 450 psi. Washed down each joint due to 500+ vis mud returns. Continue running in hole washing down 9-5/8" casing from 2,425' to 3,967' without problem. 256 gpm, 540 psi. Make up landing joint with fluted hanger. Land casing on depth C~3 3,998'. *Ran total of 98 joints 9-5/8" 40# L-80 BTC casing. Shoe ~ 3,998'. Tops: Float collar ~ 3,913' TAM Port Collar ~ 1,004' Rig down casing fill up tool, install cementing head. Circulate and condition mud in preparation for cement job. Stage pumps up to 8 bpm, 570 psi. Drop vis to 50 and YP to 14. Reciprocate pipe 15 ft strokes. PU - 150k, SO - 85k. PJSM with all involved personel for cement job. Switch to Dowell. Pump 5 bbls water. Pressure test lines to 3,500 psi - OK. Bleed off pressure and attempt to pump MudPush. Pump truck broke down. Switch back to rig. Circulate while waiting on Dowell pump truck change out. 5 bpm, 235 psi. PU - 190k, SO - 90k. Switch to Dowell. Pump 5 bbls water. Pressure test lines to 3,500 psi - OK. Bleed off pressure. Start MudPush, pipe started sticking. Attempt to land on ring. Work down to within 1 foot above ring then left pipe stationary. Pumped 70 bbls 10.3 ppg MudPush C~ 5 bpm, 338 psi ICP, 210 psi FCP. Shut down and drop bottom plug. Pump 488 bbls 10.7 ppg Arctic Set Lite lead slurry ~ 6 bpm, 333 psi ICP, 439 FCP. Mix and pump 70 bbls 15.8 ppg Class "G" tail slurry followed by 15 bbls Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Legal Well Name: L-217 Common Well Name: L-217 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date 7/6/2006 From - To ~ Hours ~ Task ~ Code ! NPT -+ -- ___ 11:30 - 14:30 3.00 CEMT P ~~ 14:30 - 15:00 0.50 CEMT P 15:00 - 16:00 1.00 CEMT P 16:00 - 18:00 2.00 CEMT P 18:00-22:00 4.00 CEMT P 22:00 - 00:00 2.00 CEMT P 7/7/2006 00:00 - 01:30 1.50 CEMT P 01:30 - 02:00 0.50 CEMT P 02:00 - 02:30 0.50 CEMT P 02:30 - 03:00 0.50 CEMT P 03:00 - 04:00 1.00 CEMT P 04:00 - 05:00 1.00 DIVRTR P 05:00 - 06:30 1.50 DIVRTR P 06:30 - 12:00 5.50 CEMT P 12:00 - 13:00 1.00 CEMT P 13:00 - 15:00 2.00 CEMT P 15:00 - 16:30 I 1.501 CEMT I P Page 3 of 10 Spud Date: 7/3/2006 Start: 7/1 /2006 End: 7/15/2006 Rig Release: 7/15/2006 Rig Number: Phase Description of Operations SURF 16.3 ppg Durastone Blend slurry C~? 4.5 bpm, 411 psi ICP, 3 bpm, 242 psi FCP. Shut down and drop top plug and kick out with 10 bbls water. Had full returns while pumping MudPush and both slurrys. Switch to rig and displace cement ~ 8 bpm 530 psi ICP, 709 psi FCP. Started losing returns after 20 bbls away. Slow pump rate to 3 bpm, 603 psi ICP, 791 FCP. Had partial returns at tail end of displacement. Bump plug with 1425 psi @ calculated displacement of 287 bbls, 95% pump effeciency. Bleed off pressure, check floats - OK. CIP 14:15 hr. Lost 232 bbls of mud during displacement. SURF Rig down cement head, blowdown circulating lines. SURF Break out top pup joint of split landing joint. Rig down casing equipment, change out bales. SURF Pick up and make up TAM shifting tool. Run in hole on 4" drill pipe to 1,004'. PU & SO - 55k. Jay in and slack off 5k. Pick up 5k over to verify tool in slot. Test cups to 1,000 psi - OK. Bleed off pressure to 400 psi and shift tool open with pressure bleeding off to verify. SURF Circulate @ 3 bpm, 250 psi with partial returns. Attempted to reestablish circulation by pumping at different rates, up to 7 bpm, 560 psi with no change in returns. Pumped remaining mud on location for total of 937 bbls 9.2 ppg, 40 vis mud. Held PJSM while pumping. SURF Switch to Dowell for top job. Pump 5 bbls water. Pressure test lines to 1,500 psi - OK. Pump Arctic Set Lite 10.7 ppg cement with first 20 bbls containing 2 ppb CemNet and remaining slurry with 1 ppb CemNet.. Pumped first 62 bbls ~ 2.5 bpm, 200 psi ICP, 275 psi FCP. Pumped next 18 bbls ~ 2 bpm, 250 psi ICP & FCP. Pumped remaining cement with job continuing over to next tour ~ 1 bpm, 225 psi with no change in pressure and very minimal returns. SURF Continue cement top job without returns through TAM collar C~ 1 bpm, 225 psi for total of 260 bbls cement. Clear drill pipe with 9 bbls water. CIP @ 01:30 hr. SURF Pick up 7k over DP string weight and shift TAM sleeve closed. Pressure test TAM collar to 1,000 psi - OK. Jay out of TAM collar. Re-test to 1,000 psi - OK. Pick up 10' and blow out choke ~ 2,500 psi. SURF Circulate bottoms up with water C~ 340 gpm, 255 psi. SURF Rig down surface pumping equipment. SURF POH with TAM shifting tool and laydown same. SURF Make up split landing joint pup joint, back out of hanger. Flush out Diverter stack. SURF Nipple down Diverter system. Secure same in cellar. SURF Pick up and make up 1" CS Hydril pipe. Run in hole and work pipe down to 237'. Start washing pipe down from 237' to 300' 48 gpm, 400 psi. Plugged off at 300'. 'Note: All work string measurements are from wellhead. SURF POH with 1"cement work string and clear pipe. SURF Run in hole with cement work string, washing down to 352' ~ 48 gpm, 400 psi SURF PJSM. Pump 5 bbls water. Pressure test lines to 3,000 psi - Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-217 L-217 Spud Date: 7/3/2006 DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 NABOBS 9ES Rig Number: Date From - To Hours ~ Task I, Code NPT 7/7/2006 15:00 - 16:30 1.50 ~ CEMT ~ P 16:30 - 18:00 I 1.501 CEMT I P 18:00 - 20:30 I 2.501 CEMT I P 20:30 - 21:00 I 0.50 C CEMT I P 21:00 - 22:00 I 1.001 WHSUB I P 22:00 - 23:30 I 1.501 W HSUB I P 23:30 - 00:00 0.50 DIVRTR P 7/8/2006 00:00 - 03:30 3.50 BOPSU P 03:30 - 04:00 0.50 BOPSU P 04:00 - 08:00 4.00 BOPSU P 08:00 - 08:30 0.50 BOPSU~ P 08:30 - 09:30 1.00 BOPSU N SFAL 09;30 - 10:30 1.00 BOPSU N SFAL 10;30 - 12:00 1.50 WHSUB N SFAL 12:00 - 15:30 I 3.501 W HSUB N SFAL 15:30 - 17:00 I 1.50 (BOPSUR N I SFAL 17:00 - 18:00 I 1.001 BOPSUp N I SFAL 18:00 - 20:30 2.50 DRILL P 20:30 - 22:30 2.00 DRILL P 22:30 - 00:00 1.50 DRILL P Phase ~ Description of Operations SURF OK. Pump additional 55 bbs water ~ 1.4 bpm, 450 psi. Mix and pump 10.7 ppg Arctic Set Lite slurry ~ 1.2 bpm, 450 psi. With 16 bbls of cement away, hole packed off and lost returns. SURF Rig down and wash out cement lines. Unable to retrieve work string. Run in hole to 120' with remaining 4 joints of work string and rig up Dowell. SURF Establish circulation. Mix and pump 130 bbls 10.7 ppg Arctic Set Lite slurry. 1st 94 bbls @ .9 bpm, 40 psi ICP, 90 psi FCP. Last 30 bbls pumped C~2 1.9 bpm, 290 psi ICP, 320 psi FCP. Started returning 10.1 ppg to surface with 54 bbls away. 10.2 ppg with 64 bbls away. 10.5 ppg with 94 bbls away. 10.6+ ppg with 130 bbls away. Clear surface lines with water. Observe level of cement before rigging down Dowell - OK. CIP ~ 19:50 hr. Top Job completed. SURF Rig down Dowell. POH with 120' work string. Able to retrieve 2 joints from previous run. Left total of 9 joints 1 " CS Hydril pipe in 9-5/8" annulus. 6 joints left on location. SURF Make up landing joint to casing hanger. Install emergency slips. Pick up casing string to 100k (1/4 inch pipe movement). Set weight on slips, 70k without blocks. Laydown landing joint. 'Note: Hanger only 8 inches high. SURF PJSM. Make up casing head and tubing spool. Test metal to metal seal to 1,000 psi - OK. SURF Change out 20" riser nipple to 16" riser nipple. SURF Nipple up ROPE. SURF Rig up to test. SURF Pressure test BOPE. 250 psi low pressure, 4,000 psi high pressure for 5 minutes each. Annular preventer tested at 250psi / 3,500 psi. Witnessing of test waived by AOGCC rep Jeff Jones. Tesf witnessed by SP WSLs Robert French, Brian Buzby and NAD Toolpushers Roy Hunt, Kelly Cozby. SURF Rig down test equipment. Attempt to pull test plug - No Go. SURF Circulate on top of plug and attempt to pull test plug with same results. SURF Nipple down BOP stack. SURF Remove rocks and aluminum metal shavings from top of test plug. Recovered appx. a coffee can full of metal. Attempt to pull test plug. Plug moved up 4 inches without coming out. SURF Nipple down tubing spool and pull out test plug. Examination of casing head revealed scarred seal area where 7" pack-off would seat on next casing run. Change out casing head, nipple up tubing spool. Test casing head metal to metal seal to 1,000 psi - OK. SURF Nipple up BOP stack. Flush out stack and function pipe rams and hydril. Install test plug. SURF Pressure test flanged connections between casing head and tubing spool, and between tubing spool and BOP stack to 250 psi / 4,000 psi - 5 min - OK. Pull test plug and rig down test equipment. Install wear bushing. PROD1 Pick up drill pipe singles out of pipe shed to 3,255'. PROD1 POH racking back drill pipe from 3,255' to surface. PROD1 PJSM. Pick up and make up 8.75" directional drilling assembly. (BHA #2) Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date !From - To 7/9/2006 ~ 00:00 - 00:30 00:30 - 01:00 01:00 - 02:30 L-217 L-217 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Start: 7/1 /2006 Rig Release: 7/15/2006 Rig Number: Hours ! Task Code NPT Phase 0.50 DRILL P PROD1 0.50 DRILL P PROD1 1.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 07:00 1.50 REMCM N 07:00 - 08:00 1.00 DRILL P 08:00 - 10:00 2.00 DRILL P 10:00 - 11:00 I 1.001 DRILL I P 11:00 - 11:15 0.25 DRILL P 11:15 - 11:30 0.25 DRILL P 11:30 - 12:00 0.50 DRILL P 12:00 - 12:30 0.50 DRILL P 12:30 - 00:00 11.50 DRILL P 7/10/2006 100:00 - 11:00 I 11.00) DRILL I P CEMT I SURF PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 Page 5 of 10 Spud Date: 7/3/2006 End: 7/15/2006 Description of Operations RIH with BHA #2 on HWDP to 1,022'. *'Checked cement level in conductor. Unable to establish firm depth but was somewhere between 80' to 200'. Notified AOGCC rep Jeff Jones and received order to perform another top job prior to drilling out casing. Notified engineer and related service companies.** Shallow hole test MWD ~ 600 gpm, 910 psi - OK Continue running in hole with BHA #2 picking up drill pipe out of pipe shed from 1,022' to 2,341'. Pick up Ghost Reamer and continue picking up drill pipe in hole to 2,622' Run in hole with drill pipe out of derrick from 2,622' to 3,771' Cut and slip drilling line 60'. Inspect brake linkage - OK. Service topdrive. Circulate bottoms up ~ 500 gpm, 1,890 psi. PU - 110k, SO - 67k. Prepare for surface cement top job #3 while waiting for Dowell. Weld entry nipple into conductor pipe. Pressure test 9-5/8" 40# L-80 BTC casing to 3,500 psi - 30 minutes - 0 pressure loss. Wash down from 3,771' to top of cement ~ 3,893'. Drill cement and shoe track from 3,893' to within 10' from top of shoe to 3,988'. 458 gpm, 1,650 psi on, 1,460 psi off, 50 rpm, 5.6k TO on, 5k TO off, 10k WOB. 'Float collar was on depth ~ 3,913'. "'Dowell pumped 10.7 ppg Arctic Set Lite cement ~ 2 bpm filling casing from the top. Returned good cement with 30 bbls pumped. Pumped additional 5 bbls and shut down. CIP C~? 09:17 hr, 7/9/2006. Cementing was done out of the critical path while the rig continued with cleaning out the shoe track to within 10 ft of casing shoe. Displace well from 9.2 ppg spud mud to 8.8 ppg LSND mud. Pump 50 bbls water, 40 bbls high vis spacer, followed by LSND mud. 457 gpm, 1,650 psi, 50 rpm, 4.4k TO. Drill remaining cement, shoe, and rathole to 4,005'. 580 gpm, 1,210 psi, 70 rpm, 3.7k TO. PU - 111 k, SO - 72k, RT - 87k. Drill 20' of new hole from 4,005' to 4,025'. 580 gpm, 1,210 psi, 70 rpm, 3.7k TO. PU - 111 k, SO - 72k, RT - 87k. Circulate bottoms up. Perform LOT: 3,998' MD, 2,759' TVD, 668 psi surface pressure, 8.8 ppg MW for an EMW of 13.46 PPg• Obtain ECD benchmarks and slow pump rates. CECD rotating - 9.31 ppg, CECD without rotating - 9.25 ppg. Directionally drill 8 3/4" production hole from 4,025' to 6,647'. 580 gpm, 2,570 psi on, 2,310 psi off, 100 rpm, 7.8k TO on, 5.4k TO off, PU - 132k, SO - 77k, RT - 101 k. CECD - 9.85 ppg, AECD - 10.36 ppg. AST - .6 hr, ART - 4.3 hrs. Backream every stand up C~ drilling rate and ream down @ 75% drilling rate. Pumped (3) high vis sweeps @ 4,530', 5,020', and 6,000'. First 2 sweeps returned a 50 % increase in cuttings. Third sweep observed no increase. Directionally drill from 6,647' to TD C~? 8,793' MD, 4,843' TVD. Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Page 6 of 10 Legal Well Name: L-217 Common Well Name: L-217 Spud Date: 7/3/2006 Event Name: DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours , Task Code NPT Phase - I -- 7/10/2006 100:00 - 11:00 I 11.00 I DRILL P I I PROD1 11:00 - 12:30 I 1.501 DRILL I P I I PROD1 12:30 - 20:30 I 8.001 DRILL I P I I PROD1 20:30- 21:00 I 0.501 DRILL. i P I ~ PROD1 21:00 - 22:30 1.501 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 7/11/2006 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:00 0.50 DRILL P PRODi 01:00 - 02:00 1.00 BOPSU P PROD1 02:00 - 03:00 1.00 BOPSU P PROD1 03:00 - 05:00 I 2.001 CASE I P I I RUNPRD 05:00 - 11:30 6.501 CASE P RUNPRD 11:30 - 12:00 0.50 CASE P RUNPRD 12:00 - 13:30 1.50 CASE P RUNPRD 13:30 - 14:00 I 0.501 CASE I P I I RUNPRD 14:00 - 21:30 I 7.501 CASE I P I I RUNPRD 21:30 - 22:30 ~ 1.00 ~ CASE ~ P ~ I RUNPRD Description of Operations TD ~ 11:00 hr, 7/10/2006 585 gpm, 3,440 psi on, 3,220 psi off, 100 rpm, 9.7k TO on, 8.2k TO off, PU - 160k, SO - 90k, RT - 112k, WOB 20k. CECD 10.22 ppg, AECD - 11.02 ppg. AST - .52 hrs, ART - 6.38 hrs. Pumped high vis sweep C~ 7,000' with 50% increase in cuttings over shaker. Pumped weighted high /vis sweep C~ 8, i 50' with 25% increase of cuttings back to shakers. Pump and circulate out 30 bbl 2 Ib over weighted /high vis sweep ~ 580 gpm, 3,195 psi, 100 rpm, 6.5k TO. Had 10% increase of cuttings back to shakers. 9.2 ppg MW. Monitor well - OK. Backream out of hole to shoe from 8,793' to 3,968'. 580 gpm, 3,100 psi, 100 rpm, 7-8k TO. Worked through minor tight spots ~ bit depths of 7,450', 7,340', and 7,280', Ghost reamer depths of 5,109', 4,999', and 4,939'. Alt tight spots cleaned out without problem. Pump and circulate out 30 bbl 2 Ib over weighted /high vis sweep C~3 580 gpm, 1,940 psi, 80 rpm, 4k TO. Had clay balls returning before bottoms up and 50% increase of cuttings back to shakers with sweep back to surface. Circulate shakers clean. 9.2 ppg MW. Monitor well - OK. Pump dry job. POH from 3,968' to BHA ~ 259'. PJSM. Lay down JAR stand, drill collars, pull nuclear source. Lay down remainder of BHA #2. Clear and clean rig floor. Flush BOP stack with jet sub. Pull wear bushing. Change top rams from 3.5" x 6" VBR's to 7". Test door seals to 3,500 psi - OK. Rig up to run 7" 26# L-80 BTC-M x TCII production casing. Make dummy run with 7" fluted casing hanger. PJSM. Pick up and make up 7" shoe track with Baker-Lok. Fill pipe and check floats - OK. Continue running in hole with BTC-M casing to 3,181'. 80 fpm running speed without any mud losses. Fill every joint and top off every 10 joints with casing fill-up tool. 8,800 fUlbs MU TO using Best-O-Life 2000 thread lubricant. installing 2 centralizers floating between stop ring in mid joint on each joint for 55 jts. 1 centralizer full floating for next 35 joints for total of 146 centralizers and 50 stop rings. Rig up TCII equipment. Continue running in hole with 7" BTC-M X TCII casing from 3,181' to 3,985'. 80 fpm running speed without any mud losses Fill every joint and top off every 10 joints with casing fill-up tool. Torque turn connections to 10,100 ft/Ibs using Jet Lube lubricant. Break circulation, stage pumps up to 6 bpm, 320 psi and circulate 1 1/2 annulus volume. No increase in cuttings throughout circulation. No mud losses. PU - 128k, SO - 88k. Continue running in hole from 3,985' to 8,783'. 40 fpm running speed without any mud losses or problems. Fill pipe every joint, break circulation every 5 joints, circulate down every 15 joints for 5 minutes. Break circulation with casing- fill-up tool, stage pumps up to 6 Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Legal Well Name: L-217 Common Well Name: L-217 Event Name: DRILL+COMPLETE Start: 7/1/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To ' Hours ~ Task Code ~ NPT Phase -- 7/11/2006 ~ 21:30 - 22:30 1.00 ~ CASE P (RUNPRD 22:30 - 23:00 0.50 CEMT P RUNPRD 23:00 - 00:00 1.00 CEMT P RUNPRD 7/12/2006 100:00 - 01:30 I 1.501 CEMT I P I I RUNPRD 01:30 - 03:00 1.501 CEMT P RUNPRD 03:00 - 04:00 ~ 1.00 ~ CEMT ~ P ~ ~ RUNPRD 04:00 - 05:00 1.00 WHSUR P RUNPRD 05:00 - 06:00 1.00 CASE P RUNPRD 06:00 - 07:00 1.00 BOPSU P RUNPRD 07:00 - 08:00 1.00 BOPSU P RUNPRD 08:00 - 08:30 0.50 80PSUF~ P RUNPRD 08:30 - 09:00 0.50 EVAL P RUNPRD 09:00 - 10:00 1.00 PERFO P OTHCMP 10:00 - 12:00 2.00 PERFO P OTHCMP 12:00 - 13:00 1.00 PERFO~ P OTHCMP 13:00 - 13:30 0.50 PERFO P OTHCMP 13:30 - 18:00 4.50 PERFO P OTHCMP Page 7 of 10 Spud Date: 7/3/2006 End: 7/15/2006 Description of Operations bpm, 580 psi for 1 bottoms up. No increase in cuttings with bottoms up. No mud losses. PU - 225k, SO - 96k. Able to reciprocate pipe in 15' strokes. Rig down casing fill-up tool, rig up cementing head. Continue circulating and conditioning mud for cement job @ 6 bpm, 550 psi. No mud losses. PU - 225k, SO - 96k. Reciprocate pipe 15' strokes. Held cementing PJSM with crew coming on ~ midnight during pretour. Continue circulating and conditioning mud for cement job @ 6 bpm, 550 psi. No mud losses. PU - 225k, SO - 96k. Reciprocate pipe in 15' strokes. No mud losses. Switch to Dowell. Pump 5 bbls water, test lines to 4,000 psi - OK. Pump 40 bbls MudPush II 10.3 ppg. Shut down and drop bottom plug. Mix and pump 55 bbls 11.0 ppg Lite Crete lead cement followed by 83 bbls 15.8 ppg class "G" tail cement. Shut down and wash out lines to rig floor. Switch to rig and kick out top plug with 333 bbls 8.5 ppg seawater. First 270 bbls pumped C~ 6 bpm, 280 psi ICP, 1,080 psi FCP. Next 50 bbls pumped ~ 4 bpm 1,000 psi ICP, 1,318 psi FCP. Final 13 bbls pumped ~ 2 bpm, 1,152 psi ICP, 1,176 FCP. Bumped plug @ calculated displacement of 95%. CIP @ 02:50 hr. Attempted to bring up pressure to 4,000 psi for casing pressure test, but threads between cementing head and landing joint started leaking at 2,000 psi. Bleed off pressure and tightened threads 1 full turn. Attempt casing test with same results. "No mud losses during entire casing run, circulating and cementing jobs. Reciprocated casing throughout job until 288 bbls of displacement away. Rig down cementing head and casing running equipment. Lay down landing joint. "Top filled 9 5/8" x 20" annulus with 4.6 bbls 11.0 ppg Lite Crete cement (Out of critical path) Install 7" x 9 5/8" pack-off. Test same to 5,000 psi - OK. Pressure test 7" casing to 4,000 psi - 30 minutes - OK. Change top rams from 7" to 3.5" x 6" VBR's. Rig up to test rams. Test top and bottom rams with 3.5" test joint to 250 psi low / 4,000 psi high - 5 minutes each - OK. Pull test plug, install wear bushing Perform LOT on 7" x 9 5/8" annulus. 3,998' MD, 2,759' TVD 9.3 ppg MW, 420 psi leak-off pressure, 12.23 ppg EMW. Establish injection rate by pumping away 5 bbls 9.3 ppg mud 3 bpm, 800 psi. 400 psi SIP. Pick up pert gun tools to rig floor and rig up to run pert guns. PJSM. Pick up and make up 4.5" 5 SPF 4505PJ pert gun assembly with bumper sub and slimpulse MWD and 8 stands HWDP to 1,323'.. Run in hole with pert guns on 4" drill pipe from 1,323' to 2,089'. Shallow hole test MWD. 250 gpm, 490 psi - OK. Continue running in hole from 2,089' to 7,007' (MW D depth) to verify top RA tag. 250 gpm, 760 psi, PU - 120h, SO - 86k. "Injected 130 bbls of 9.3 ppg mud down 7" annulus C~ 3 bpm, 850 psi followed by 100 bbls dead crude ~ 2 bpm, 950 psi. 700 psi SIP. Injection and freeze protecting done out of critical Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: L-217 Common Well Name: L-217 Spud Date: 7/3/2006 Event Name: DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: i Date From - To Hours Task ;Code NPT i -- - -_ .-- 7/12/2006 ~ 8:00 - 19:00 1.00 PERFO~ P 19:00 - 20:00 20:00 - 22:30 22:30 - 23:30 23:30 - 00:00 7/13/2006 00:00 - 00:30 00:30 - 01:30 01:30 - 07:30 07:30 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 21:00 21:00 - 00:00 1.00 PERFO P 2.50 PERFO P 1.00 PERFO P 0.50 PERFO P 0.50 PERFO P 1.00 PERFO P 6.00 PERFO P 2.50 PERFO P 0.50 PERFO P 1.50 PERFO P Phase Description of Operations OTHCMP path** OTHCMP Continue running in hole from 7,007' to 7,861' (MWD depth) to verify top RA tag. 250 gpm, 800 psi. OTHCMP Run in hole from 7,861' to float collar @ 8,704'. PU - 170k, SO - 82k. OTHCMP Log up for gun tie-in and position guns on depth for firing with bottom pert ~ 8,514' and top pert ~ 8,020'. OTHCMP Displace well from 8.5 ppg seawater to 9.0 ppg brine. 250 gpm, 730 psi.. Held PJSM on firing guns while circulating. OTHCMP Work through fire sequence per Schlumberger pert rep. Had good indication of guns firing. There was an initial 4 bbls loss to the hole after the guns were fired. OTHCMP POH 7 stands to 7,926', above perfs. No overpull. OTHCMP Circulate bottoms up ~ 270 gpm, 890 psi. With bottoms up the rigs H2S alarms went off. Driller and derrick hand put on air packs and checked with hand held gas detectors which showed maximum units C~3 17 ppm. All other hands went to safe briefing area and positive head count was done. Returned to rig when all clear was given. OTHCMP POH with pert guns laying down drill pipe from 7,926' to 700' with guns 200' below rotary table. Hole taking appx. 4 bph over displacement. OTHCMP PJSM on laying down pert guns. Lay down pert guns. All guns fired. OTHCMP Lay down gun running equipment and clear floor. OTHCMP Run in hole with remaining drill pipe out of derrick to 1,625'. *Lost 24 bbls of 9.0 NaCI brine from midnight. 1.00 PERFO P OTHCMP Lay down drill pipe from 1,625' to surface. 1.00 EVAL P OTHCMP PJSM with SLB W L. Rig up for wireline junk baskeUguage ring runs and USIT 2.00 EVAL P OTHCMP JB/GR run #1 with 6.125" GR. Could not get past 8,103'. POH and empty basket. Recovered cement and pert gun debris. 2.00 EVAL P OTHCMP JB/GR run #2 with same GR. Could not get past 8,110'. Had to work up for appx 10 minutes to pull free. POH and empty basket. No recovery in basket. 1.00 EVAL P OTHCMP Change out guage ring to 6.05". Change out weak point above rope socket. 1.50 EVAL P OTHCMP JB/GR run #3 with 6.05 GR. Able to go to PBTD ~ 8,704'. POH and empty basket. Only recovered amount to cover bottom of coffee cup. 0.50 EVAL P OTHCMP Lay down GR/ JB and rig up USIT logging tools. 3.00 EVAL P OTHCMP USIT log. RIH to 8,704' and log up with logging tool depth starting ~ 8,652' 7/14/2006 00:00 - 01:00 01:00 - 01:30 01:30 - 02:00 02:00 - 04:00 'Lost 16 bbls of 9.0 ppg NaCI brine from noon. 40 bbls total loss for well. 1.00 EVAL P OTHCMP Continue USIT log to 2,994'. POH. 0.50 EVAL P OTHCMP Rig down SLB WL. 'USIT log showed good cement covering. pert depths. Good cement up to 5,200'. Cement strung out from 5,120' to 3,980'. 0.50 BUNCO RUNCMP Pull wear bushing. Make tubing hanger dummy run. 2.00 BUNCO RUNCMP Rig up to run 3.5" completion. Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: L-217 Common Well Name: L-217 Spud Date: 7/3/2006 Event Name: DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code NPT Phase Description of Operations ~ ~_- 7/14/2006 04:00 - 04:30 0.50 BUNCO RUNCMP PJSM. Discussed new modifications made to skate. (Pad eye on front of skate, new pipe buggy with shroud) Took extra time to discuss what new hazards that might come about with new equipment.) 04:30 - 18:30 14.00 BUNCO RUNCMP Run in hole with 3.5" completion string per running detail, Baker-Lok connections below 1st packer. Torque turn connections to 2,300 fUlbs using Jet Lube Seal Guard lubricant. Ran in hole to 8,449' without problems. Pick up and make up tubing hanger and landing joint. Ran total of 255 jts 3.5" 9.2# L-80 TCII tubing. 4 space-out pups, 2 in jewelry, 2 under last joint of tubing. 18:30 - 19:30 1.00 BUNCO RUNCMP Land tubing on depth ~ 8,477'. PU - 95k, SO - 60k (with 35k blocks included). Run in tubing hanger lockdown screws, drop roller ball/rod assembly down tubing. Lay down landing joint. " 1-5/16" ball with 1.375" fishing neck. WLEG Q 8,477 Tops: *Note: All equipment is 3.5" X-Nipple #1 C~? 8,455' X-Nipple #2 w/ RHC-M Plug C~ 8,434' GLM #1 @ 8,405' X-Nipple #3 ~ 8,384' Baker Premier Packer #1 ~ 8,367' GLM #2 @ 8,343' GLM #3 ~ 8,304' Baker Premier Packer #2 C~J 8,263' X-Nipple #4 @ 8,248' GLM #4 ~ 8,219' GLM #5 @ 8,180' X-Nipple #5 @ 8,169' Baker Premier Packer #3 ~ 8,146' GLM #6 @ 8,118' GLM #7 ~ 8,026' Baker Premier Packer #4 @ 8,000' X-Nipple #6 C~3 7,979' GLM #8 w/ DCR-1 SV & RKP latch C~3 7,888' X-Nipple #7 C~ 3,503' "4 Perf intervals (5 SPF) @ (8,392' to 8,514'), (8,280' to 8,330'), (8,162' to 8,188'), (8,020' to 8,128'). 19:30 - 21:00 1.50 BUNCO RUNCMP Set packers by pumping down tubing to 4,200 psi. Had pressure indications of all 4 packers setting one at a time. Hold pressure for 30 minutes for tubing test - OK - no psi loss. Bleed tubing pressure down to 2,200 psi, then pressure up on tubing annulus to 4,000 psi for casing test. 30 min - OK - 40 psi loss. Bleed annulus pressure to 0 psi, bleed tubing pressure to 0 psi. Pressure up on annulus and shear out DCR valve with 2,950 psi. Confirm pumpability by pumping a few barrels each direction through valve. 21:00 - 21:30 0.50 BUNCO RUNCMP Install 2-way check valve in tubing hanger and test same from below to 3,500 psi - 5 minutes - OK. 21:30 - 00:00 2.50 BOPSU P RUNCMP Nipple down BOP's and secure same in cellar. 7/15/2006 00:00 - 01:00 1.00 WHSUR P RUNCMP Prep wellhead and tubing hanger. Nipple up tree adapter and test seals to 5,000 psi - OK. Printed: 7/17/2006 1:51:13 PM BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: L-217 Common Well Name: L-217 Spud Date: 7/3/2006 Event Name: DRILL+COMPLETE Start: 7/1/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To Hours ~ Task Code', NPT Phase ~ Description of Operations 7/15/2006 01:00 - 02:30 1.50 WHSUR P RUNCMP Nipple up tree and test same to 5,000 psi - OK. 02:30 - 04:00 1.50 W HSUR P RUNCMP Rig up DSM lubricator. Pump open actuator valve on tree. Pull 2-way check valve. Install VR in lower annulus. Rig down DSM 04:00 - 04:30 0.50 WHSUR P RUNCMP Rig up to reverse circulate. Pressure test lines to 2,500 psi. 04:30 - 07:30 3.00 W HSUR P RUNCMP Pump 250 bbls fresh NaCI 9.0 ppg brine down tubing annulus followed by 125 bbls of inhibited brine treated with 25 gal of inhibitor C~ 3 bpm, 510 psi. 07;30 - 09:00 1.50 WHSUR P RUNCMP PJSM with LRHOS. Pressure test lines to 3,500 psi. Reverse circulate 125 bbls of 90 deg heated diesel ~ 2 bpm, 500 psi ICP, 800 FCP. 09:00 - 10:00 1.00 WHSUR P RUNCMP U- tube diesel back to tubing. Tubing - 100 psi SIP, OA - 100 psi SIP 10:00 - 10:30 0.50 WHSUR P RUNCMP Rig down circulating lines 10:30 - 12:00 1.50 WHSUR P RUNCMP Rig up DSM lubricator on tree. Install back pressure valve. Test valve to 1,000 psi from below - OK. Rig down DSM lubricator. 12:00 - 14:00 2.00 RIGD P RUNCMP Remove OA safety valves, install OA VR Plug. Clean cellar area. Empty mud pits of remaining fluid. Secure well. "Release rig from L-217i operations ~ 14:00 hr, 7/15/2006 for move to L-204, AFE # ORD5M361 i." Printed: 7/17/2006 1:57:13 PM by ;~ ~~~~ :~ ~~W ;~r . ~. i* ~_ L-217 Su Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / N-P Well: L-217 Borehole: L-217 UWI/API#: 500292331200 Survey Name /Date: L-217 /July 10, 2006 Tort /AHD / DDI / ERD ratio: 113.973° / 6592.77 ft / 6.135 / 1.361 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.35068611, W 149.32406809 Location Grid NIE Y/X: N 5978301.340 ftUS, E 583252.540 ftUS Grid Convergence Angle: +0.63657465° Grid Scale Factor: 0.99990787 Re Scblumberger Vertical Section Azimuth: 16.630° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 78.10 ft relative 1o MSL Sea Bed /Ground Level Elevation: 49.60 ft relative to MSL Magnetic Declination: 24.016° Total Field Strength: 57619.496 nT Magnetic Dip: 80.881 ° Declination Date: July 08, 2006 • Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +24.016° Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Fasting Latitude Longitude Depth Section Departure ft de de ft ft tt tt tt tt tt de 00 tt ttUS ttUS H I t U.UU U.VV U.UU -/tS.IU V.VV V.UV V.UU V.VU U.VV V.UU V.VV D`J/83V 1.34 D83ZDZA4 IV /U.3DV0801 I VV d4`J.3L4V06V`J First GYD GC SS 100.00 0.31 81.57 21.90 100.00 0.11 0.27 0.27 0.04 0.27 0.31 5978301.38 583252.81 N 70.35068621 W 149.32406592 171.00 0.69 67.49 92.90 171.00 0.47 0.89 0.88 0.23 0.85 0.56 5978301.58 583253.39 N 70.35068674 W 149.32406117 264.00 1.07 72.82 185.89 263.99 1.30 2.31 2.31 0.70 2.20 0.42 5978302.07 583254.73 N 70.35068802 W 149.32405024 358.00 1.24 76.43 279.87 357.97 2.30 4.21 4.20 1.20 4.03 0.20 5978302.58 583256.55 N 70.35068938 W 149.32403540 445.00 1.11 65.82 366.85 444.95 3.33 5.99 5.98 1.77 5.71 0.29 5978303.17 583258.23 N 70.35069093 W 149.32402173 539.00 1.18 78.78 460.83 538.93 4.37 7.86 7.84 2.33 7.49 0.28 5978303.75 583260.00 N 70.35069246 W 149.32400728 633.00 1.67 80.45 554.80 632.90 5.43 10.20 10.17 2.74 9.79 0.52 5978304.19 583262.30 N 70.35069360 W 149.32398861 728.00 1.49 60.63 649.76 727.86 6.93 12.79 12.74 3.58 12.23 0.60 5978305.05 583264.73 N 70.35069588 W 149.32396879 820.00 2.61 31.71 741.71 819.81 9.81 16.02 15.56 5.95 14.38 1.62 5978307.45 583266.85 N 70.35070235 W 149.32395139 912.00 4.82 16.66 833.51 911.61 15.70 21.94 20.14 11.43 16.59 2.61 5978312.96 583269.00 N 70.35071734 W 149.32 Last GYD GC SS 1007.00 8.72 19.65 927.83 1005.93 26.89 33.14 29.87 22.04 20.15 4.12 5978323.60 583272.44 N 70.35074632 W 149.32 First MWD+IFR+MS 1041.84 10.26 19.25 962.19 1040.29 32.63 38.88 35.23 27.46 22.06 4.42 5978329.04 583274.30 N 70.35076112 W 149.323 8 1136.75 13.38 19.15 1055.08 1133.18 52.04 58.32 53.93 45.82 28.45 3.29 5978347.47 583280.48 N 70.35081128 W 149.32383710 1232.61 16.47 15.04 1147.70 1225.80 76.72 83.00 78.03 69.43 35.62 3.41 5978371.15 583287.38 N 70.35087577 W 149.32377892 1327.93 19.71 16.60 1238.29 1316.39 106.30 112.59 107.21 97.89 43.72 3.44 5978399.70 583295.17 N 70.35095352 W 149.32371315 1424.00 25.53 16.03 1326.93 1405.03 143.24 149.52 143.89 133.34 54.08 6.06 5978435.26 583305.13 N 70.35105038 W 149.32362909 1519.27 30.41 16.99 1411.05 1489.15 187.91 194.19 188.40 176.16 66.80 5.14 5978478.21 583317.37 N 70.35116735 W 149.32352581 1614.97 33.53 16.68 1492.23 1570.33 238.57 244.86 238.97 224.65 81.47 3.26 5978526.86 583331.50 N 70.35129983 W 149.32340673 1710.56 37.34 15.70 1570.10 1648.20 293.98 300.27 294.28 277.87 96.89 4.03 5978580.24 583346.33 N 70.35144522 W 149.32328147 1806.85 40.66 14.86 1644.92 1723.02 354.55 360.85 354.75 336.32 112.85 3.49 5978638.86 583361.63 N 70.35160490 W 149.32315196 1902.72 45.08 15.29 1715.16 1793.26 419.73 426.06 419.85 399.28 129.81 4.62 5978702.00 583377.90 N 70.35177690 W 149.32301419 1998.15 49.40 16.16 1779.94 1858.04 489.77 496.11 489.85 466.70 148.82 4.58 5978769.62 583396.15 N 70.35196108 W 149.32285991 2093.54 52.17 16.24 1840.24 1918.34 563.67 570.01 563.73 537.67 169.43 2.90 5978840.80 583415.98 N 70.35215495 W 149.32269251 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-P\L-217\L-217\L-217 Generated 8/9/2006 11:18 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft tt tt tt tt ft ft de 100 tt ttUS ftUS 21139.15 55.09 1 / .59 1896 .93 1975 .03 640 .64 646.99 640.70 611.30 191 .135 3.16 59/13914.68 583437. 57 N 70.35135613 W 149.31151054 2284 .62 60.24 17 .06 1947 .98 2026 .08 721 .27 727.62 721.34 688.29 215 .85 5.41 5978991.92 583460. 71 N 70. 35256643 W 149.32231564 2380. 68 61.90 17 .39 1994 .45 2072 .55 805 .34 811.69 805.41 768.59 240 .75 1.75 5979072.48 583484. 71 N 70. 35278580 W 149.32211349 2476. 21 62.61 17 .21 2038 .92 2117 .02 889 .88 896.24 889.95 849.31 265 .89 0.76 5979153.47 583508. 95 N 70. 35300632 W 149.32190934 2571. 56 63.10 16 .97 2082 .42 2160 .52 974 .72 981.09 974.80 930.41 290. 82 0.56 5979234.83 583532. 98 N 70. 35322788 W 149.32170688 2666. 65 63.23 17 .08 2125 .35 2203 .45 1059 .57 1065.94 1059.65 1011.54 315. 67 0.17 5979316.23 583556. 92 N 70. 35344952 W 149.32150515 2763. 93 61.67 16 .86 2170 .34 2248 .44 1145 .82 1152.18 1145.89 1094.03 340. 84 1.62 5979398.99 583581. 17 N 70. 35367487 W 149.32130072 2859. 06 63.14 16 .65 2214 .41 2292 .51 1230 .12 1236.49 1230.20 1174.76 365. 14 1.56 5979479.97 583604. 57 N 70. 35389541 W 149.32110337 2954. 70 64.72 15 .53 2256 .44 2334 .54 1316 .02 1322.40 1316.08 1257.30 388. 95 1.96 5979562.76 583627. 46 N 70. 35412090 W 149.32091007 3050. 02 67.46 15 .87 2295 .07 2373 .17 1403 .14 1409.53 1403.19 1341.18 412. 53 2.89 5979646.89 583650. 10 N 70. 35435005 W 149.32071857 3145. 95 66.06 15 .52 2332 .92 2411 .02 1491 .27 1497.67 1491.31 1426.04 436. 37 1.50 5979732.00 583673. 00 N 70. 35458187 W 149.322 3241. 76 65.89 15 .33 2371 .93 2450 .03 1578 .76 1585.18 1578.79 1510.39 459. 65 0.25 5979816.60 583695. 34 N 70. 35481232 W 149.320 9 3337. 69 65.29 14 .76 2411 .57 2489 .67 1666 .08 1672.54 1666.09 1594.75 482. 32 0.83 5979901.20 583717. 07 N 70. 35504278 W 149.32015172 3433. 75 65.76 15 .21 2451 .37 2529 .47 1753 .48 1759.96 1753.48 1679.21 504. 93 0.65 5979985.89 583738. 74 N 70. 35527350 W 149.31996811 3528. 50 64.97 15 .20 2490 .86 2568 .96 1839 .58 1846.09 1839.58 1762.32 527. 52 0.$3 5980069.24 583760. 40 N 70. 35550054 W 149.31978465 3624. 19 66.70 14 .89 2530 .03 2608 .13 1926 .84 1933.39 1926.84 1846.63 550. 18 1.83 5980153.79 583782. 12 N 70. 35573086 W 149.31960060 3720. 13 66.69 14 .57 2567 .99 2646 .09 2014 .91 2021.50 2014.91 1931.84 572. 58 0.31 5980239.24 583803. 57 N 70. 35596366 W 149.31941863 3815. 84 65.92 14 .25 2606 .45 2684 .55 2102 .48 2109.14 2102.50 2016.73 594. 39 0.86 5980324.36 583824. 44 N 70. 35619555 W 149.31924146 3910. 72 65.07 14 .24 2645 .80 2723 .90 2188 .74 2195.48 2188.77 2100.40 615. 64 0.90 5980408.26 583844. 75 N 70. 35642415 W 149.31906890 3944. 19 66.02 14 .01 2659 .66 2737 .76 2219 .18 2225.94 2219.21 2129.95 623. 07 2.91 5980437.88 583851. 85 N 70. 35650486 W 149.31900851 4030. 89 66.08 14 .47 2694 .86 2772 .96 2298 .34 2305.18 2298.40 2206.75 642. 56 0.49 5980514.89 583870. 49 N 70. 35671467 W 149.31885018 4085. 92 66.36 14 .60 2717 .05 2795 .15 2348 .67 2355.54 2348.73 2255.50 655. 20 0.55 5980563.76 583882. 58 N 70. 35684783 W 149.31874752 4181. 80 65.77 16 .26 2755 .95 2834 .05 2436 .28 2443.17 2436.36 2339.97 678. 51 1.70 5980648.48 583904. 95 N 70. 35707860 W 149.31855815 4277. 29 65.26 17 .00 2795 .52 2873 .62 2523 .18 2530.07 2523.26 2423.24 703. 38 0.88 5980732.01 583928. 89 N 70. 35730607 W 149.31835613 4372. 57 64.66 17 .04 2835 .85 2913 .95 2609 .50 2616.40 2609.57 2505.78 728. 65 0.63 5980814.82 583953. 24 N 70. 35753157 W 149.31815087 4468. 30 64.61 18 .15 2876 .86 2954 .96 2695 .99 2702.90 2696.05 2588.23 754. 80 1.05 5980897.55 583978: 47 N 70. 35775681 W 149.31793847 4564. 31 64 .41 18.77 2918.18 2996.28 2782.61 2789.56 2782.65 2670.44 782. 24 0.62 5980980.05 584004.99 N 70.35798138 W 149.31771555 4660. 59 64 .64 18.42 2959 .59 3037.69 2869.48 2876.48 2869.50 2752.82 809 .95 0.41 5981062.73 584031.79 N 70.35820643 W 149.31 4755. 78 65 .10 17.86 3000 .01 3078.11 2955.63 2962.66 2955.64 2834.72 836 .78 0.72 5981144.91 584057.70 7 N 70.35843015 W 149.31 4851. 22 66 .42 18.42 3039 .20 3117.30 3042.62 3049.68 3042.63 2917.41 863 .88 1.48 5981227.90 584083.88 N 70.35865607 W 149.31 4946. 78 66 .65 18.63 3077 .25 3155.35 3130.23 3137.34 3130.23 3000.53 891 .73 0.31 5981311.31 584110.80 N 70.35888312 W 149.31682604 5042 .24 64 .73 19.17 3116 .55 3194.65 3217.15 3224.33 3217.15 3082.83 919 .91 2.08 5981393.91 584138.06 N 70.35910795 W 149.31659714 5138 .10 64 .88 17.93 3157 .35 3235.45 3303.84 3311.07 3303.84 3165.06 947 .50 1.18 5981476.43 584164.73 N 70.35933259 W 149.31637296 5233. 79 66 .19 17.33 3196 .98 3275.08 3390.92 3398.17 3390.93 3248.07 973 .88 1.48 5981559.72 584190.18 N 70.35955935 W 149.31615865 5329. 61 65 .71 17.24 3236 .03 3314.13 3478.42 3485.67 3478.42 3331.62 999. 87 0.51 5981643.55 584215.25 N 70.35978759 W 149.31594741 5425. 52 65 .65 17.10 3275 .53 3353.63 3565.82 3573.07 3565.82 3415.12 1025. 68 0.15 5981727.32 584240.12 N 70.36001570 W 149.31573777 5521. 81 65 .37 17.32 3315 .45 3393.55 3653.44 3660.70 3653.44 3498.83 1051. 60 0.36 5981811.30 584265.11 N 70.36024437 W 149.31552710 5617. 29 65 .87 17.13 3354 .86 3432.96 3740.40 3747.66 3740.41 3581.89 1077. 35 0.55 5981894.64 584289.94 N 70.36047128 W 149.31531785 5712. 52 65 .23 17.86 3394 .28 3472.38 3827.08 3834.35 3827.09 3664.57 1103. 41 0.97 5981977.60 584315.07 N 70.36069714 W 149.31510610 5808. 37 65 .36 17,90 3434 .34 3512.44 3914.13 3921.43 3914.15 3747.44 1130. 15 0.14 5982060.75 584340.88 N 70.36092353 W 149.31488885 5904. 01 65 .33 17,97 3474 .23 3552.33 4001.03 4008.35 4001..05 3830.14 1156. 91 0.07 5982143.73 584366.73 N 70.36114944 W 149.31467135 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-P\L-217\L-217\L-217 Generated 8/9/2006 11:18 AM Page 2 of 3 Comments Measured ficlination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n tt tt tt tt tt de 100 tt ttUS ftUS 5`Jy`J.// b5.31 IiS.U/ 3b74.LL 3byY.JL 4UtStS.VL 4Uy5.:Sb 4VLSiS.Ub :SylL.25t5 6095.24 64.99 18.47 3554.34 3632.44 4174.61 4181.99 4174.65 3995.15 6190.32 63.93 16.71 3595.33 3673.43 4260.39 4267.78 4260.42 4076.92 6286.63 62.98 16.72 3638.37 3716.47 4346.54 4353.93 4346.58 4159.43 6382.44 62.89 16.86 3681.97 3760.07 4431.86 4439.25 4431.90 4241.11 6477.90 63.33 16.70 3725.14 3803.24 4517.00 4524.39 4517.04 4322.63 6573.52 63.37 16.45 3768.03 3846.13 4602.46 4609.85 4602.50 4404.54 6669.16 63.59 17.38 3810.74 3888.84 4688.03 4695.43 4688.07 4486.41 6764.64 63.69 17.41 3853.13 3931.23 4773.58 4780.98 4773.62 4568.05 6860.51 63.91 17.64 3895.46 3973.56 4859.59 4867.00 4859.64 4650.08 6955.77 64.14 16.09 3937.18 4015.28 4945.22 4952.64 4945.27 4732.03 7051.09 64.13 15.96 3978.76 4056.86 5030.99 5038.41 5031.03 4814.47 7147.44 64.04 16.30 4020.87 4098.97 5117.64 5125.07 5117.69 4897.72 7242.93 63.87 16.56 4062.80 4140.90 5203.44 5210.86 5203.48 4980.01 7338.98 63.98 17.00 4105.02 4183.12 5289.71 5297.14 5289.75 5062.61 7434.19 63.20 17.09 4147.37 4225.47 5374.98 5382.41 5375.02 5144.13 7529.45 63.28 17.26 4190.26 4268.36 5460.03 5467.47 5460.08 5225.40 7625.56 63.71 17.37 4233.15 4311.25 5546.04 5553.48 5546.08 5307.51 7721.53 63.78 17.71 4275.60 4353.70 5632.09 5639.54 5632.15 5389.58 7817.18 63.94 17.62 4317.74 4395.84 5717.95 5725.41 5718.01 5471.39 7912.70 64.17 17.04 4359.54 4437.64 5803.83 5811.30 5803.90 5553.39 8008.03 64.66 17.14 4400.70 4478.80 5889.81 5897.29 5889.88 5635.57 8103.72 62.54 16.61 4443.25 4521.35 5975.52 5982.99 5975.58 5717.59 8199.38 61.43 16.18 4488.18 4566.28 6059.97 6067.44 6060.03 5798.60 8295.43 61.99 16.11 4533.70 4611.80 6144.54 6152.02 6144.60 5879.84 8390.76 62.44 16.12 4578.14 4656.24 6228.88 6236.36 6228.93 5960.87 8486.71 62.35 16.08 4622.60 4700.70 6313.90 6321.38 6313.95 6042.56 8582.48 62.34 15.70 4667.05 4745.15 6398.72 6406.21 6398.77 6124.15 8677.92 62.35 15.19 4711.35 4789.45 6483.24 6490.75 6483.28 6205.63 Last MWD+IFR+MS 8720.18 62.46 15.05 4730.93 4809.03 6520.68 6528.20 6520.71 6241.79 1 1 t5:t.25:i 1210.99 1236.92 1261.70 1286.34 1310.92 1335.30 1360.20 1385.78 1411.68 1436.52 1460.20 1484.28 1508.54 1533.45 1558.45 1583.56 1609.16 1635.10 1661.16 V.IU byCZZZb./b 0.51 5982309.32 2.01 5982391.36 0.99 5982474.14 0.16 5982556.08 0.48 5982637.86 0.24 5982720.02 0.90 5982802.16 0.11 5982884.07 0.31 5982966.37 bt54JyZ./Z IV /U.3b 13/b4i3 VV 14`J.3144DZbZ 584418.96 N 70.36160020 W 149.31423192 584443.98 N 70.36182358 W 149.31402120 584467.83 N 70.36204899 W 149.31381982 584491.57 N 70.36227212 W 149.31361952 1686.74 1712.01 1736.89 1760.73 1784.25 1807.66 1831.24 1854.46 1876.97 1886.74 1.48 5983048.59 0.12 5983131.28 0.33 5983214.78 0.30 5983297.33 0.43 5983380.19 0.82 5983461.98 0.18 5983543.52 0.46 5983625.90 0.33 5983708.24 0.19 5983790.33 0.60 5983872.60 0.52 5983955.05 2.27 5984037.33 1.23 5984118.60 0.59 5984200.09 0.47 5984281.36 0.10 5984363.30 0.35 5984445.14 0.47 5984526.86 0.39 5984563.11 TD (Projected) 8793.00 62.46 15.05 4764.60 4842.70 6585.22 6592.77 6585.25 6304.14 1903.51 0.00 5984625.65 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mull-station 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 : 2579 FSL 3662 FEL S34 T12N R11 E UM 5978301.34 583252.54 BHL : 3602 FSL 1746 FEL S27 T12N R11 E UM 5984625.65 585085.72 584515.24 N 70.36249480 W 149.31341976 584538.70 N 70.36271856 W 149.31322161 584562.69 N 70.36294222 W 149.31301923 584587.36 N 70.36316523 W 149.31281135 584612.34 N 70.36338931 W 149.31260082 584636.27 584659.03 584682.18 584705.52 584729.51 584753.60 584777.81 584802.49 584827.51 584852.65 584877.32 584901.68 584925.64 584948.58 584971.19 584993.70 585016.36 585038.68 585060.28 585069.65 N 70.36361318 W 149.31 N 70.36383838 W 149.31 N 70.36406580 W 149.312 1 N 70.36429059 W 149.31181345 N 70.36451623 W 149.31161098 N 70.36473894 W 149.31140780 N 70.36496094 W 149.31120362 N 70.36518524 W 149.31099552 N 70.36540942 W 149.31078465 N 70.36563293 W 149.31057282 N 70.36585691 W 149.31036482 N 70.36608142 W 149.31015939 N 70.36630546 W 149.30995708 N 70.36652676 W 149.30976326 N 70.36674869 W 149.30957203 N 70.36697003 W 149.30938168 N 70.36719319 W 149.30918995 N 70.36741606 W 149.30900108 N 70.36763865 W 149.308800 N 70.36773742 W 149.30 585085.72 N 70.36790775 W 149.30860221 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-P\L-217\L-217\L-217 Generated 8/9/2006 11:18 AM Page 3 of 3 ?FLEE = 4-1 f8" WELLHEAI3- F'MG A CT UA TOR = NA _ KB. ELEV = 78.10' BF. ELEV = KOP= 28.5it' - 600'. Max Ang~ = 66° ~ 3704' Daturtt MD = xx x x' Dawt1>TVD= x~ncx' SS ~ FdCDTES: GLM'S ~ 8TA #1- #7 ARE ~~ 1-1/2" MMC~W WMGN ARE ~~yy ~~++ ~~ryy pp pp """"' ~ 1 ~ ~ WATEf~1.C3L1L3 MAN[~REt S. ~~~~ L„d~i.B ~.lf`~ti~~ ~~{}~' ~ 3-117' HES X NIP, ID = 2.813" 9-518" CSG, 40#, L-BQ, ID =8.8;15" -~__y$~~5 7" 26# L-80 TC II x 7" 26# L-80 BTC-M XO jt 5601' Minimum ID =2.8'!3" ~ ~3~55' 3-1t2" NES X NIPPLE P' MARKER Jt)INT W! RA TAG ?~T MARKER Jt3INT WI RA TAG WATERFL.QOD/GA5 <.ETMANDRELS ST MD TV D DEV TYPE V LV !-ATt~I PL?RT C~4'1'E 8 7888 ~1 ' - 64 MMG DCR-/ RKP ^~ 07115106 7 8026 .t-1~;T 64 Iu1hAG-W Dt.NU{ RK U #37115106 6 8118 4.~_%~ 62 h~U1G-W DL~iA RK 0 07J15/t}6 5 81 £1T3 4557 62 NlU1G-1N to RK 0 07115f06 4 132 9 ~~ 7e, ~a2 AAMC-~JV [DUI F2K 0 07t1t06 3 8 4616 62 Mt~AG-W DI:k4A RK 0 07115/06 2 8343 4634. 62 fdMG-W t~A RK 0 U7115106 1 8405 4663 62 M+A~-V4f L+I RK 0 07115/06 7979' ~ 3-1 /2" HES X NIP, ID = 2.813" $QQQ' 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3.5" x 1.5" MMG-W GLM 8147" LI 7" X 3-1 J2" BKR ER PKR, ~ = 2.87.' $169' ~~ 3-112" HES X NIP, ID = 2.813" PERFt3RA11CTN SUMMARY REF LLIG: ANGI..E AT TOP PERF: 64° ~ $OZd Note: Beier to Production DB Air hiet~ric~ perfdata sly SPF INr1=RVAl OptySgz DATE. 4.5" 5 8020-8128 ~~serr C}711 SlO6 4.5" 5 81625188 07115/06 A-~' S 82E30533fl open 07115!06 *1.5" 5 83925514 c/per, 07t151t>6 j 3-112" TBG, 9.2#, L-80, .0487 bpt, ID = 2.992" 1 PBTD 7" CS G. 2&~, L-84, Id = 6.276" I 8477' ~ 11705" 8783' 8248' -~ 3-1/2" HES X NIP, ID = 2.813" 826$' 7" X3-112" BKR PREMIER PKR, ID = 2.87" 8367' ~,~ ~ 7"X3-112" BKR PREMIER PKR, ID = 2.87" $384' 3-1l2" HES X NIP, ID = 2.813" w/RHGm plug g.1;T q.• 3-112" HES X N~', ID = 2.813" w IRHC-in pig 8455' 3-112" HES X NIP, lp = 2.813" ~#~I7>3' 3-1/2., VvLEG, ID = 2.992" PATE RElJ BY COMMENTS [14TE REV BY CbMMERlTS O6'13I06 BJP Proposed Campichon Ver. 1.0 D7~'15.~06 AM Hnal ~Ig ievsion 07117/06 DAVlPJC DRl_G DRAFT' UPDATES f3RK3N UN€f WELL:. Iw-217"r Pt32MIT tso: 2C3$-075 API No: 50-029-43312-DO SEC 34, T12N, R11 E 2575' FSL &36+;'12' FEL BP Exploration {Alaska] Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 3873 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99507 Field: Orion Date BL Color CD PLEASE ACKNOWLEDGE RECEIPT BY 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: ~ /~,~//~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth j Received by: 07/18/08 • L-2171 Surface Casing and Cement Subject: I_-217i Surface Casing and Cement From: ''Peltier, Brandon" <Brandon.Peltier@bp.com> Date: Fri, 07 Jul 2fJ06 11:03:40 -0800 To: "'V:5'iJ, AD'J'J Drlg Rig 9es" <NSUADWDrIgRig9es@bp.com>, Winton_aubest@ad~rin.state.ak.us, jeffJones@admin.state.ak.us Winten~Jeff Here is a brief account of what has occurred over the last couple of days on t_-217i, rig 9ES. !:Ne c{rillcd our surf hole to 'TD (4005'), short tripped, circulated, and POOH. At 550 we experienced some tight hole arul had some o rer-pull. We circulated there and had wood over the shakers. After the hole cleaned up, we t_D the 13HA and rigged up to run casing. We did not experience any lost returns while drilling the surface hole. 4?Ve began having trouble getting the casing down at 600'. It appeared the centralizers where haning up on >ornething de~~rr7 hole (wood, gravel, rock?) The casing had to be worked down (pumping and setting weight) to ~-13t>rJ' before we ~~ould run to TD w/o problem. At 1300' the top centralizer had worked past 600'. There were full returns during the entire casing running operation. After the casing was on bottom, we circulated and rec.iprc;cated vvhile drz:pt~ing the mud funnel vis from 300 to 50 sec/qt, keeping the weight at 9.5ppg. ~j~=e rir~ sec ~~p tc~ purr~p cement, but the cement pump truck broke down. We waited ~3 hours for a new prt~tpF:r. 'r'Vith the r~iEevr pump truck we began pumping cement. All the cement was pumped (575 bbls 15.8 G + 10 ;' i',SL) dovwn the .--,:;ing and we swapped over to displace the casing w1 mud using the rig pumps. After about 2ta bbls irra the d~apiacement we began losing returns, then no returns for the remainder of the cement job. The purrip pressures indicated good cement lift and the top plug bumped on calculated strokes. We ran in wit"s Df'' and opened tyre 2nd stage TAM collar (1000') and circulated w/ mud. There were little to no returns fhough 4ve purni?ed up tc 7 bpm and a total of 930 bbls away. We pumped another 260 bbls of cement w/ no returns or cement to surface. Currently ;7i7hat; @ 1'I :30~.m) we are preparing to pump another 260 bbls of 10.7 ASL through 1" DP into the 9-5/8" x 12-1/4" annulus. bNe have that DP at 300' and and are working to get it as deep as possible before cemer tinrl. According to tare Gft pressures frarn the first stage cement job, we may have cement up to -~,]0-ts!7~ ,but uerac;iced-off above that. "'lease; '~t)ntac'~ me ii a=ru have any other questioros. -~ hank ~~ou. ~t"c'~p1f,~p1"II ~i~~ti~t' E?P Exr!nration (A!a~':caj, inc. Op+=rations Drilling Engineer C.~F'i=3 i=<otary D°fling (9U'7) r ~t8-7838 (Mobii~) l~?rair~~~ri. ~::itier(zaN.cti,~,~ 1 of 1 7/7/2006 11:15 AM • FRANK H. MURKOWSKI, GOVERNOR Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7~" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion Schrader Bluff Oil Pool, PBU L-217 BP Exploration (Alaska) Inc. Permit No: 206-075 Surface Location: 2579' FSL, 3662' FEL, SEC. 34, T12N, R1 lE, UM Bottomhole Location: 3455' FSL, 1812' FEL, SEC. 27, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~ay of June, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF A SKA ' ALA, OIL AND GAS CONSERVATION COMI~ION ~~~4 ~~'' PERMIT TO DRILL 20 AAC 25.005 `w 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is pr d` r: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-217 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8615 TVD 4820 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 2579' FSL 3662' FEL T12N R11 E UM ~ SEC 34 7. Property Designation: ADL 028239 Schrader Bluff , , , , . , Top of Productive Horizon: 2730' FSL, 2028' FEL, SEC. 27, T12N, R11 E, UM 8. Land Use Permit: 13. Approximate d D te: Jun 24, 006 Total Depth: 3455' FSL, 1812' FEL, SEC. 27, T12N, R11 E, UM ~ 9. Acres in Property: 2560 14. Distance to rest Property: 2580' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583253 y-5978301 Zone-ASP4 10. KB Elevation Plan (Height above GL): 78.1 feet 15. Distance to Nearest Well within Pool: 220' 16. Deviated Wells: Kickoff Depth: 600 feet Maximum Hole Angle: 65 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2145 Surface: 1671 ~ 18. Casin Pro ram: Specifications Top - Settin Depth -Bottom Quanti of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 90# A-53 Weld 80' Surface Surface 80' 80; 260 sx Arctic Set A rox. 12-1 /4" 9-5/8" 40# L-80 BTC 3976' Surface Surface 3976' 2763' 573 sx AS Lite, 411 sx Class 'G' ~ 8-3/4" 7" 26# L-80 TCII/BTC-M 8615' Surface Surface 8615' 4820' 118 sx LiteCrete, 388 sx Class 'G' 19. PRESENT WELL GONQITION SUMMARY (To be completed for Redril l 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... Length Size ^~ - Cement Volume MD _ :TVD Conductor /Structural Surface Intermediate Production Liner 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. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature -~'~ Phone 564-4166 Date .~ 0,3 ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,~Qi('- API Number: 50- pZ - .Z ..~ j,Z. Permit Approval Date: See cover letter for other requirements Conditions of Approval: 11 If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales'~(~ T~ S r (~t~ (7 ~ ~-~ L~. ~ D D ,~Q ~C Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes,~`No /lG>, ~. 'j' t ~„e,r„ ~, ,e.,~,{ Q ~~ ~ ~ ~ ~ ~t,~p ~ , HZS Measures: Yes ^ No ' ectio al Survey Req'd: Yes ^ No Other: uj Prtr SKG<.k.f fn Zo r4>-~-t z s . o ~ ~ C G~) L! ~ l a-L }'~~e ~ C f we. t s ~~y Dire d . n PPROVED BY THE COMMISSIO Date/" ~fi ''~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ ~ ~ ~ ~/ ~ Submit In Duplicate ~ ~ Well Name: L-217i Well Plan Summary T e of Well (producer or injector): Injector Surface Location: SEC. 34, T12N, R11 E, UM, AK, 2579' FSL & 3662' FEL X = 583,252 Y = 5,978,301 L-217 Target Start: SEC. 27, T12N, R11 E, UM, AK, 2730' FSL & 2028' FEL X = 584,815 Y = 5,983,750 Z = 4,340 TVDss ~(s/Or L-217 Target End: SEC. 27, T12N, R11 E, UM, AK, 3455' FSL & 1811',PQEL X = 585,022 Y = 5,984,477 Z = 4,742 TVDss AFE Number: xxxxxxxxx Rig: Nabors 9ES GL: 49.6' RT: 28.5' Spud Date: June 24, 2006 O eratin days to complete: 14.83 TD: 8,615' TVD: 4,820' Max Inc: 64.8 RTE: 78.1' Well Design: Grassroots, Ultra Slim Hole, Orion Field, Schrader Bluff Horizon, Slant WAG Injector Well Information Distance to Nearest Property: 2580 ft to PBU boundary Distance to Nearest Well in Pool: 220' to L-250L1 at Nb level, and 450' to L-250 at OA level API Number: 50-029-XXXXX Current Status: Conductor Set Conductor: Conductor Set Estimated BHP: 2145 PSI C«~ 4742' TVD SS (8.7 PPG EMW) Estimated BHT: 85 deg F C 6710' TVD SS Reference Documents Directional Plans: L-217 (P5) Proposal Statement of Requirements: L-217 SOR locked 5/4/2006 ~ L-217i Permit to Drill Page 1 • Formation Markers and Estimated Pore Pressures Est. Formation Tops Est. Formation Tops Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (MD) (TVDss feet (Yes/No) (Psi (pp9 EMW) G1 -260 +/-50' No 117 8.7 SV6 -890 +/-50' No 401 8.7 Fault 1 -1160 +/-150' MD No SV5 1666 -1480 +/-50' No 666 8.7 SV4 1837 -1600 +/-50' Poss. H drates 720 8.7 Base Permafrost -1675 +/-50' No 754 8.7 SV3 2319 -1965 +/-50' Gas H drates 884 8.7 SV2 2684 -2135 +/-50' Gas H drates 961 8.7 SV7 3459 -2465 +/-50' Gas H drates 1109 8.7 Surf Cs 3977 -2685 1208 8.7 UG4 4188 -2770 +/-50' Thin coal 1247 8.7 UG4A 4246 -2800 +/-50' Heavy Oil betty 2800 and 2900' SS 1260 8.7 Fault 2 -3100 +/-150' MD UG3 5034 -3135 +/-50' No -Wet sands 1411 8.7 UG1 6162 -3625 +/-50' Heavy Oil betty 3810 - 3960' SS 1631 8.7 Ma 6916 -3965 +/-15' Heavy Oil betty 3960 - 3990' SS 1784 8.7 Mb1 7005 -4000 +/-15' Heavy Oil betty 4000 - 4050' Ss 1800 8.7 Mb2 7171 -4075 +/-15' Heavy Oil betty 4075 - 4130' SS 1834 8.7 Mc 7337 -4150 +/-15' No -Wet sands 1868 8.7 Na 7426 -4190 +/-15' Yes 1886 8.7 Nb 7482 -4215 +/-15' Yes 1880 8.2-8.6 NC 7548 -4250 +/-15' Yes 1870 8.2-8.6 Ne 7570 -4260 +/-15' Yes 1917 8.7 Nf 7681 -4305 +/-15' No 1937 8.7 OA 7758 -4340 +/-15' Yes 1850-1950 8.2-8.6 OBa 7886 -4400 +/-15' Yes 1975 8.6 OBb 7992 -4450 +/-15' Yes 1995 8.6 OBc 8109 -4505 +/-15' Yes 2020 8.6 OBd 8216 -4555 +1-15' Yes .2040 8.6 OBe 8365 -4625 +/-15' Yes 2060 8.6 OBf 8450 -4665 +/-15' Yes 2075 8.6 OBf_Base 8546 -4710 +/-15' No 2095 8.6 T.D. 8615 -4742 No 2115 8.6 L-217i Permit to Drill Page 2 • • 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 4,000 psi. Due to anticipated surface pressures not exceeding 3,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOPE regular test frequency for L-217 will be 14 days. Function test BOPE every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section (8-3/4" Hole) • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Leak Off Test - 8-3/4" hole • .Kick Tolerance: • Planned completion fluid: Disposal 2145 psi - Schrader OBf sands (8.7 ppg EMW C~ 4742' TVDss) 1671 psi -Based on a full column of gas C~ 0.10 psi/ft 4,000 psi/250 psi Rams ~ 2,500 psi/250 psi Annular 4,000 psi 10.8 ;ppg minimum EMW LOT 20' from 9 5/8" shoe ~' 51 b~ls with a 8.8 ppg mud with 10.8 ppg LOT Estimated 9.0 ppg Brine / 6.8 ppg Diesel • 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: Naul 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 Casina/Tubina Program Hole Size Csg / Tb O.D. WUFt Grade Conn :Burst si Collapse si Length Top MD / TVD Bottom MD / TVD 42" 20" 90# A-53 Weld 80 GL 80 12-'/a" 9 5/a" 40# L-80 BTC 5,750 3,090 3976 GL 3976/2763 8-3/a" 7" 26# L-80 TC-II 7,240 5,410 5476 GL 5476/3401 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 3139 5476/3401 8615/4820 Tubin 3-'/z" 9.2# L-80 TC-II 10160 10530 8336 GL 8336/4689 Mud Program: 12 ~/a" Surface Hole Mud Properties: Spud - FrPShwatPr Muct Interval Densit Funnel Vis PV YP FL Chlorides PH Surf -Base Perm 8.8 - 250-300+ 30-55 50-70 NC-8.0 <1000 9.0-9.5 Base Perm - TD 9. -9.6 225-250 30-55 45-60 8.0 <1000 9.0-9.5 t3 3/a" Production Flole Mud Properties: Interval Density PV Surface shoe to TD 8.8 - 9.2 8-16 Survev and Loaaina Program: Freshwater Mud (LSND) YP FL pH LGS % MBT 18-24 N/C 9-10 < 6.0 < 20 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean (900'). L-118 and L-201 will be within 50' of the surface hole at 2343' and and 2599' md, respectively. See close approach well list for more details. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-~/a" Hole Section: Sam le as re uired b well site Geolo ist MWD /LWD: GR / Res / PW D (Real time and recorded), Neu/Azi-Den/Caliper (recorded) -MAD asses should be run over an Mb-OBd sands where BHA slidin has occurred. O en Hole: None Cased Hole: USIT in PDC Mode - to from PBTD to surface casin shoe L-217i Permit to Drill Page 3 • Surface and Anti-Collision Issues Well name Well Current Production Precautions/Risk Separation status Priority Based Information L-2121 (adjacent surface 15' at surface online - PW Medium location in'ector L-216i (adjacent surface 30' at surface online - PW Medium location in~ector L-202 (adjacent surface 30' at surface Online- 2070 BOPD 2000 psi C~ 4400' SS location Producer L-118 (Minor Risked at 44' at 2343' and online - 640 BOPD 2688 psi C~1 6600' SS 1 /200 Producer L-200 (Passes Major Risk) 151' at 5854' online - 1128 BOPD 1913 psi @ 4400' SS and Producer L-250 (Passes Major Risk) 58' at 739' and online - 1563 BOPD 1980 psi C«~ 4460' SS Producer L-212i, L-216i, and L-202 will need to be shut-in and have their well houses removed before the rig can move onto L-217i. Wells within a'/a mile of this injection well at the top of the reservoir Well Name Distance/Sand Annulus Inte rit Comments oe i,-Z Full returns during cement job. Calculated TOC at 4765' MD, Z 450 feet at OA which is above the Ma. Slotted liner completion in adjacent L-250 Producer level roduction well; no erforations in this interval in L-217i. 2`0~ ~~ ' Full returns during cement job. Calculated TOC at 4765' MD, 220 feet at Nb which is above the Ma. Slotted liner completion in adjacent L-250L1 Producer level roduction well; no erforations in this interval in L-217i. Full returns during cement job. Calculated TOC at 5770' MD, X04 vat 1230 feet at top Nb which is above the Mao No perforations in this interval in L- L-200 Producer: level 217i. Zo4° ~s 1215 feet at top Na Top of cement found by USIT log at 6170' MD; which is above L-216i In~ector level. the Ma. No perforations in this interval in L-217i. Close Approach Well List (Center to Center distance <100'): Well Name Ctr-Ctr Distance ft Reference MD ft Allowable Deviation ft Precautionary Comment L-103 53 867 38 Use Travelin C tinder G ro L-118 44 2343 21 Pass: Minor Risk 1/200 L-119 93 509 84 Use Travelin C tinder G ro L-201 82 2599 22 Use Travelin C- tinder G ro L-202 29 829 15 Use Travelin C tinder G ro L-212 15 579 6 Use Travelin C tinder G ro L-215 58 454 50 Use Travelin C tinder G ro L-216 30 254 26 Use Travelin C tinder G ro L-250 57 739 44 Use Travelin C tinder G ro L-118 will require temporary subsurface isolation while drilling the intermediate section. This well has failed the Major Risk scan due to the proximity and uncertainty of the well bore surreys. A Tolerable Collision Risk Worksheet was completed for this well and resulted in a TCR = 1/12. The well passed a Minor Risk Collision ~ scan of 1/200. This well will have a tubin tail lu , be fluid acked, and shut-in as art of the Pre-Ri work. .-'~f L-217i Permit to Drill Page 4 • Cement Calculations: Surface Casin Cement Calculations Hole Size: 12-1/4" Surface Casin : 9-5/8" 40# Conductor: 20" 90# Tem : 40 de F This cement job is planned for one stage, but a TAM will be on location if hole conditions indicate its use is necessary. The cement job will be accomplished with two slurries: Lead: 250% excess in permafrost, 40% below permafrost, brought to surface. Tail: 40% excess, brou ht 1000' above shoe. 2544.8 cu ~~`~'4,44 cu 573. ~~_..._ Total Lead 453.2 bbls ft ~ . ,~..-v--~ -~- 10.7 ASL G + adds 1.15 cu 410.9 15.8ppgG+ Total Tail 84.2 bbls 472.5 cu ft "~~ s s s DURASTONE + adds 9-$/8" Casing Centralizer Placement a) Run (25) 9-5/6" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,000' MD above the shoe. b) Run 2Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 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. Surface BBLS Slurry bbl/ft Ft. Of Top of Cmt Cement BBLS + Pipe Length Excess Calculations• Excess Shoe 0.0758 3976 3896 80 0 6.1 6.1 O en Hole Tail 0.0558 3976 2976 1000 40 55.8 78.1 O en Hole Lead 0.0558 2976 1837 1139 40 63.5 88.9 Open Hole Lead Permafrost 0.0558 1837 80 1757 250 98.0 343.0 Casin &Casin 0.2655 80 0 80 0 21.2 21.2 Production Casin Cement Calculations Hole Size: 8-3/4" Production Casin : 7" 26# Surface Casin : 9-5/8" 40# Tem : 85 de F This casing string is planned to be c nted in one stage using two slurries. Lead: 30% excess brought within _000,'-of the surface casing shoe. 4~t'l(o Tail: 30% excess_ brouaht to 500' over the Ma (6915' mdl_ Intermediate Slurry Calculations: bbl/ft Ft. Of Pipe Top of Cmt Cement Length % Excess BBLS BBLS + Excess Shoe 0.0383 8615 8535 80 0 3.1 3.1 O en Hole Tail 0.0268 8615 6400 2215 30 59.3 77.1 O en Hole Lead 0.0268 6400 4976 1424 30 38.1 49.6 Casin &Casin 0.0282 0 0 0 0 0.0 0.0 Total Lead 49.6 bbls 278.3 cu ft 4.44 cu ft/sk 62.7 sks 11.0 Crete + Latex Total Tail 80.2 bbls 450.1 cu ft 1.15 cu ft/sk 391. sks 15.8 G+ Latex 7" String Centralizer Placement may,/ a) Run two floating straight blade centralizers and a stop ring centered on every joint of casing from TD to 500' over the Ma sands. b) Above the Ma, run one centralizer per joint, floating across the entire joint up to 1000' below the surface casing shoe. L-2171 Permit to Drill Page 5 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Schrader in the Polygon 1 A fault block is expected to be normal to sub-normally pressured at 8.2- 8.7 PP9 EMW. Hydrates and Shallow gas A. Gas Hydrates are present at L-pad and have been encountered in wells throughout the SV4, SV3, SV2, and SVi. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of L Pad fault. • Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. • While running production casing L-104 had losses with no returns. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-s/8" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma and lead within ~. 1000' of the surface casing shoe. C. The Kick Tolerance for the surface casing i~5lbls with 8.8ppg mud, 10.8 ppg LOT, and an 8.8 ppg pore pressure. ~.F' D. Integrity Testing Test Point Test De th Test a EMW Ib/ al 9-s/B-in shoe 20-ft minimum from 9 5/--in shoe LOT 10.8 minimum V. Stuck Pipe A. We do not expect stuck pipe it the hole is kept adequately clean. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 5- 30 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the water flood matures. Recent H2S data from the ad is as follows: Well Name H2S Reading Date L-201 SHL 5 11/14/02 L-106 Highest on Pad 0 4/29/06 VII. Faults A. Two faults are expected to be crossed. No losses are expected to be associated with these faults. Details are listed below for reference: Fault #1: 1251' MD 1160' TVDss Throw: -60' W Uncertainty: +/- 150' MD Fault #2: 4952' MD 3100' TVDss Throw: -50' S Uncertainty: +/- 150' MD VIII. Anti-Collision Issues NOT all wells pass Major Risk criteria. L-118 Failed the Major Risk criteria, but passes a 1/200 Minor Risk scan. Gyro will need to be run to 900' or as conditions dictate for clean directional measurements due to the surface proximity to neighboring well bores. CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-217i Permit to Drill Page 6 • ~ L-2171-Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. 3. Shut-in, fluid pack, and TTP L-118 prior to moving onto well because of sub-surface close approach risk. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-'/a" drilling assembly with MWD/GR and directionally drill surface hole to base of permafrost and trip for a new BHA. RIH and drill the remainder of the surface hole to TD. actual surface hole TD will be -100' TVD below the top of the SV1 sands (3976' MD). CBU, short trip, RIH to TD BS, en POOH and lay down BHA. 4. Run and cement the 9-5/B", 40.0 Ib/ft. surface casing urface. A TAM Port Collar may be run as a contingency. ~ 5. ND diverter spool and NU casing /tubing head. NU BOPE and test to 4,000 psi. ~ 6. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den-caliper/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 5/8" casing to 3,500 psi for 30 minutes. 7. Drill shoe track and displace nueFfo new 8.8 ppg LSND mud. 8. Drill new formation to 20' below 9-5/d' shoe and perform LOT. 9. Drill ahead to Production hole Target TD (8,615' MD). 10. Circulate one BU, back-ream out of hole to run casing. 11. Run and cement the 7" production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. ~ Freeze protect the 7" x 9 5/8" annulus. 12. PU DPC guns and RIH w/ --225' of 4.5" Power Jet 5 spf, pert guns (total TCP gun assembly length to be -450') with ~.. Anadrill LWD GR/CCL for gun correlation. Tag PBTD, Circulate over to 9.0 brine. 13. Space out pert guns utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, Gently tag TD and w/ guns on bottom. Pull back to shooting depth & confirm cement compressive strength is at least 1,000 psi. Perforate OBa, OBb, OBc, and OBd. POOH standing DP back. 14. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 15. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. ~ 16. Run the 3-y/z", L-80 TCII completion with a 7" x 3-'/z" straddle packer assembly and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OBa perfs. 17. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 18. Install FMC TWC. Nipple down the BOPE. Be sure the tree is equipped with a Leo Surface Safety Valve before accepting it and hanging it in the cellar. Nipple up and test the tree to 5,000 psi. 19. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oiler, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 20. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/s" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 21. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. 6. Return L-118 to operating capacity (may be done during rig-ops). L-217i Permit to Drill Page 7 • • Variance Request ~.,- a Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse ofi operations. Re uest 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 ofi 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement afiter 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 ofi 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 function pressure-tested, before the next welibore 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 to 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 WOAKOVERS: 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 ofi 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 ofi the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; Cellar Elevation = xx' Nabors 9ES RKB = ml 4-1/2", 12.6 Ib/ft, L-80, TCI Drift / ID : 3.833"/3.958" 4-12" X 3-1/2" TCII XO 3-1/2", 9.3 Ib/ft, L-80, TCII Drift / ID : 2.867"/2.992" 7' Short Joint & RA Tag Top Ma sand (6916') 7° Short Joint & RA Tag Above Top OA (7758') RA Tag in 3-1 /2" (7772') OBa sand Perfs: 7886-7956' OBb sand Perfs: 7992-8027' OBc sand Perfs: 8110-8131' OBd sand Perfs: 8216-8336' THE C 4-1/16" 5M / WELL EAD: FMC Gen 5 System 11", SM csg.head w/ 7" mandrel hanger & packoff 11" x 11", SM, tbg spool w/ 11" x 4-1 /2° tubing hanger 11" X 4-1/16" Adaptor Flange 20" X 34" 80' A53 ERW Insulated 3400' 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3,976' 9-5/8", 40 #/ft, L-80, BTC 4976' 5476' 7782' 7841 ' 7862' 7889` 7918` 7939` 7969' 8015' 8045' 8066' 8095` 8122` 8151 ` 8172` 8202' 8218' 8260' 8289' 8310` 8331' Top of Cement TCII above and BTC-mod below Camco 3-1/2" x 1-1 /2" MMG GLM w/ DCR Shear valve pinned to 2,500 3-1 l2" 'X' Landing Nipple with 2.813" seal bore. 7" x 3-1/2" Baker 'PRM' Production Packer Camco 3-1/2" x 1-1/2" MMG-W GLM 3-1/2" 'X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1/2" MMG-W GLM 7" x 3-1 /2" Baker 'PRM' Production Packer Camco 3-1/2" x 1-1/2" MMG-W GLM 3-1/2" 'X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1/2" MMG-W GLM 7" x 3-1 /2" Baker 'PRM' Production Packer Camco 3-1/2" x 1-1/2" MMG-W GLM 3-1/2" `X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1/2" MMG-W GLM 7" x 3-1 /2" Baker 'PRM' Production Packer 3-1/2" `X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 'i-1/2" MMG-W GLM 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3-112" 'X' Landing Nipple with 2.813" seal bore. 3-1/2" WireLine Entry Guide 8,575' 7", PBTD 8,615' 7", 26 #/ft, L80, Date ~ Rev By ~ Comments 4/28/2006 BJP Proposed Completion Ver 1.1 "L-2171 Proposed Completion ~P~at~r~.~rr~'1~1~~ .Bav WELL: L-217i API NO: 50-029-xxxxx ~ PLANT GRID I I I I I I I I I I I I I I i i i i / i - ------ ----------- ---- ----- I I I L-PAD I i i ~ I ^ N-L (NWE-1) I mama N N N VI I L-1111 ^ ~ ~ N-A (NWE-2) = I L-2181 I L-114 ^ ^ L-124 I L-50 ^ ~ L-1121 I L-02 ~ L-121 ^ I ~ L-1231 I ^ L-122 L-110 ^ I ^ L-2111 L-SI ^ I ^ L-1151 L-116 ^ I ^ L-117 I L-109 ^ ^ L-118 L-SL ^ ^ L-250 L-01 ^ ^ L-200 L-107 ^ L-03 ^ KID 50 L-202 L-2121 rn L-2131^ o~ N L-2171 L-203 L-1081 ^ h it L-2161 L-1051 ^ ° ^ L-1031 L-106 ^ ~ " ^ L-21St SLOT L-SU ^ ^ L-201 L-10a ^ ^ L-11si L-2141 ^ ^ L-2101 L-102 ^ N~ Y ^ L-120 SKID 506 SKID 513 //~ i i EGEND RENAMED CONDUCTOR ^ EXISTING CONDUCTOR ~ 34 ~ ; ~~~- .. L-PAD _r ~~ ~ \~'~... - PROJECT ~ ~~ ~~ ~ T12N ~i AREA I T11N I ~ iR }_ W I ~~ =~ ~ ~ ~.. 3 2 I ~, '~r~'~'~',1' I ,;, ,; VICINITY MAP i N.T.S. I I I WELL N0. L-2171 REVISION NOTE I I THIS AS-BUILT DRAWING IS A RE-ISSUE OF I A PREVIOUS CONDUCTOR AS-BUILT FOR WELL I L-SPARE DATED 8/26/2004. WELL L-SPARE I IS BEING RENAMED TO WELL L-2171. I I I I ~E OF A~ ~P°°°°°° °qs~r I I I °°°°°°°°°°°°°°°°°°°°°°°°°°°°° I I °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° I ° I ~ °°° Richard F. Allison I ~ ° °° I 10608 I °° I ,q~,,~~ "~'ESS10Wa- I I SURVEYORS CERTIFICATE I I HEREBY CERTIFY THAT I AM I PROPERLY REGISTERED AND LICENSED I TO PRACTICE LAND SURVEYING IN I 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 MAY 02, 2006. NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 2. BASIS OF HORIZONTAL LOCATION [S WOA L-PAD OPERATOR MONUMENTATION. 3. BASIS OF ELEVATION IS WOA L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BPX M.S.L. (MEAN SEA LEVEL) DATUM. 4. MEAN PAD SCALE FACTOR IS 0.999907827. 5. DATE OF SURVEY: AUGUST 26 & 27,2004. 6. REFERENCE FIELDBOOK: W004-11 PGS 54-59. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATE POSITION DMS POSITION D.DD BOX ELEV. OFFSETS L-2171 Y=5,978,301.34 N 10,000.09 70'21'02.470" ° 70.3506861' 49 6, 2,579' FSL ' X= 583,252.54 E 5,264.77 149'1926.645 149.3240681' FEL 3,662 (~ CHECKED:JACOBS by O I I DATE: ~~UJn 5/02/06 DRAWING: WOA L-PAD SHEET: FR806 WOL 03-00 ~ ~(~(~O~a doB No: AS-BUILT CONDUCTOR B S 02 0 [SSUm FOR INFORMATION ~N JJ U ~UU SCALE: 1 OF 1 NO. DATE REVISION BY CHK ~~ ~~ oaw 1'= 150• WELL L-2171 by Schlumberger L-217 (P5) Proposal Repoli Date: April 19, 2006 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 16.630° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA L-PAD I N-P St Vertical Section Origin: N 0.000 ft, E 0.000 ft d TVD Reference Datum: Rotary Table ~ Well: Plan L-217 (N-P) ~ ~ ~~ ND Reference Elevation: 78.10 ft relative to MSL Borehole: ~ Plan L-217 ~~si ~ Sea Bed 1 Ground Level Elevation: 49.60 ft relative to MSL UWIIAPHf: 50029 Magnetic Declination: 24.237° Survey Name 1 Date: L-217 (P5) I April 19, 2006 Total Field Strength: 57579.121 nT Tort 1 AHD 1 DDI 1 ERD ratio: 67.916° 16425.75 ft 15.892 / 1.33E Magnetic Dip: 80.856° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: May 08, 2006 Location LaVLong: N 70.35068611, W 149.32406809 Magnetic Declination Model: BGGM 2005 location Grid fllE YIX: N 5978301.340 ftUS, E 583252.540 ftUS North Reference: True North Grid Convergence Angle: +0.63657465° Total Corc Mag North -> True North: +24.237° Grid Scale Factor. 0.99990787 Local Coordinates Referenced To: Well Head Measured Vertical Comments Inclination Azimuth Sub-Sea ND ND NS EW DLS Tool Face Build Rate Walk Rate Northing Fasting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 100 ft de de 1100 ft de 1100 ft ftUS ftUS Klt U. UU U.UU 1/ ./5 -/tf.lU U. UU U.UU U.UU U. UU U.UU 1/./5M V.UU V.VU Dy/rfSV"I.S4 OrfJZOY. A4 N/U.3DUUC0"Il VV"14y AZ4U62fUy KOP Bld 1.5/100 600. 00 0.00 17 .75 521. 90 600. 00 0. 00 0.00 0. 00 0.00 17.75M 0.00 0.00 5978301 .34 583252. 54 N 70. 35068611 W 149. 32406809 Bld 3.5/100 700. 00 1.50 17 .75 621. 89 699. 99 1 .31 1.25 0. 40 1.50 17.75M 1.50 0.00 5978302 .59 583252. 93 N 70. 35068951 W 149. 32406485 800. 00 5.00 17 .75 721. 71 799. 81 6. 98 6.65 2. 13 3.50 17.75M 3.50 0.00 5978308 .01 583254. 59 N 70. 35070426 W 149. 32405082 900. 00 8.50 17 .75 821. 00 899. 10 18 .73 17.84 5. 71 3.50 O.OOG 3.50 0.00 5978319 .24 583258. 05 N 70. 35073484 W 149. 32402174 1000. 00 12.00 17 .75 919. 39 997. 49 36 .51 34.78 11. 13 3.50 O.OOG 3.50 0.00 5978336 .24 583263. 29 N 70. 35078113 W 149. 32397770 1100. 00 15.50 17 .75 1016. 51 1094. 61 60 .27 57.42 18. 38 3.50 O.OOG 3.50 0.00 5978358 .95 583270. 28 N 70. 35084296 W 149. 32391889 1200. 00 19.00 17 .75 1112. 00 1190. 10 89 .92 85.65 27. 42 3.50 O.OOG 3.50 0.00 5978387 .29 583279. 00 N 70. 35092010 W 149. 32384551 1300. 00 22.50 17 .75 1205. 50 1283. 60 125 .33 119.39 38. 22 3.50 O.OOG 3.50 0.00 5978421 .14 583289. 43 N 70. 35101227 W 149. 32375783 1400. 00 26.00 17 .75 1296. 66 1374. 76 166 .39 158.50 50. 74 3.50 O.OOG 3.50 0.00 5978460 .38 583301. 51 N 70. 35111912 W 149. 32365620 1500. 00 29.50 17 .75 1385. 14 1463. 24 212 .94 202.84 64. 93 3.50 O.OOG 3.50 0.00 5978504 .87 583315. 21 N 70. 35124024 W 149. 32 97 1600. 00 33.00 17 .75 1470. 62 1548. 72 264 .80 252.24 80. 74 3.50 O.OOG 3.50 0.00 5978554 .44 583330. 47 N 70. 35137520 W 149. 3 9 SV5 1665. 71 35.30 17. 75 1525. 00 1603. 10 301. 68 287.37 91. 99 3.50 O.OOG 3.50 0.00 5978589. 69 583341. 32 N 70. 35147117 W 149. 32 0 1700. 00 36.50 17 .75 1552. 77 1630. 87 321 .78 306.52 98. 12 3.50 O.OOG 3.50 0.00 5978608 .90 583347. 24 N 70. 35152348 W 149. 32327154 1800. 00 40.00 17 .75 1631. 29 1709. 39 383 .67 365.47 116. 99 3.50 O.OOG 3.50 0.00 5978668 .05 583365. 45 N 70. 35168454 W 149. 32311832 SV4 1837. 84 41.32 17. 75 1660. 00 1738. 10 408. 32 388.96 124. 51 3.50 O.OOG 3.50 0.00 5978691. 62 583372. 71 N 70. 35174869 W 149. 32305729 1900. 00 43.50 17 .75 1705. 89 1783. 99 450 .23 428.88 137. 29 3.50 O.OOG 3.50 0.00 5978731 .68 583385. 04 N 70. 35185776 W 149. 32295353 2000. 00 47.00 17 .75 1776. 28 1854. 38 521 .22 496.51 158. 93 3.50 O.OOG 3.50 0.00 5978799 .53 583405. 93 N 70. 35204251 W 149 .32277777 2100. 00 50.50 17 .75 1842. 20 1920 .30 596 .38 568.10 181. 85 3.50 O.OOG 3.50 0.00 5978871 .37 583428. 05 N 70. 35223810 W 149 .32259170 2200 .00 54.00 17 .75 1903. 42 1981 .52 675 .42 643.39 205. 95 3.50 O.OOG 3.50 0.00 5978946 .92 583451. 31 N 70. 35244379 W 149 .32239601 2300. 00 57.50 17 .75 1959. 69 2037 .79 758 .05 722.11 231. 15 3.50 O.OOG 3.50 0.00 5979025 .90 583475. 63 N 70. 35265882 W 149 .32219143 SV3 2319. 37 58.18 17. 75 1970. 00 2048. 10 774. 45 737.73 236. 15 3.50 O.OOG 3.50 0.00 5979041. 57 583480. 46 N 70. 35270150 W 149. 32215083 2400 .00 61.00 17 .75 2010. 81 2088 .91 843 .96 803.94 257. 34 3.50 O.OOG 3.50 0.00 5979108 .02 583500. 91 N 70. 35288239 W 149 .32197873 WeIlDesign Ver SP 1.0 Bld(doc40x_56) N-P\Plan L-217 (N-P)\Plan L-217\L-217 (P5) Generated 4/19/2006 2:12 PM Page 1 of 2 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft d de ft ft ft ft ft de 100 ft de de 1100 ft de 1100 ft ftUS ftUS ~.rvs.o/iuu L9L0.0/ bc .w i/ ./b LUL4.44 GIVL .b4 iSb`J .U/ bZ/ .t5b Zbb .UV J.bU -Z4.lLCi 3.5U U.UU 5`J/y13Z.U1 bS35U25.3U IV/U.3DZ`J4//Z VV14y .3G1y1b5/ 2500.00 64 .29 16 .62 2056.71 2134 .81 932 .78 888.73 283 .82 3.50 -23.61 G 3.20 -1.59 5979193.09 583526.44 N 70.35311402 W 149 .32176377 End Crv 2516.59 64 .82 16 .36 2063.84 2141 .94 947 .77 903.10 288 .07 3.50 O.OOG 3.21 -1.55 5979207.50 583530.53 N 70.35315327 W 149 .32172924 SV2 2683.84 64. 82 16. 36 2135.00 2213. 10 1099. 12 1048 .33 330. 70 0.00 O.OOG 0.00 0.00 5979353.18 583571.54 N 70.35355001 W 149. 32138307 SV1 3459.43 64. 82 16. 36 2465.00 2543. 10 1800. 99 1721 .79 528. 39 0.00 O.OOG 0.00 0.00 5980028.73 583761.72 N 70.35538982 W 149. 31977757 9-5/8" Csg Pt 3976.49 64. 82 16. 36 2685.00 2763. 10 2268. 91 2170 .76 660. 19 0.00 O.OOG 0.00 0.00 5980479.10 583888.51 N 70.35661635 W 149. 31870708 UG4 4188.01 64. 82 16. 36 2775.00 2853. 10 2460. 33 2354 .43 714. 10 0.00 O.OOG 0.00 0.00 5980663.34 583940.38 N 70.35711811 W 149. 31826911 UG4A 4246.77 64. 82 16. 36 2800.00 2878. 10 2513. 50 2405 .45 729. 08 0.00 O.OOG 0.00 0.00 5980714.52 583954.78 N 70.35725749 W 149. 31814745 UG3 5034.10 64. 82 16. 36 3135.00 3213. 10 3226. 00 3089 .12 929. 77 0.00 O.OOG 0.00 0.00 5981400.31 584147.85 N 70.35912514 W 149. 31651703 Drp 3/100 5933.74 64 .82 16 .36 3517.78 3595 .88 4040 .13 3870 .30 1159 .08 0.00 175.27G 0.00 0.00 5982183.91 584368.44 N 70.36125915 W 149 .31465371 5984.53 63 .30 16 .50 3540.00 3618 .10 4085 .81 3914.11 1172 .00 3.00 153.21 G -2.99 0.28 5982227.86 584380.88 N 70.36137883 W 149 .31 2 End Drp 5988.17 63 .20 16 .56 3541.64 3619 .74 4089 .05 3917 .22 1172 .92 3.00 O.OOG -2.68 1.51 5982230.98 584381.76 N 70.36138733 W 149 .3'I~2 UG1 6161.99 63. 20 16. 56 3620.00 3698. 10 4244. 21 4065. 94 1217. 13 0.00 O.OOG 0.00 0.00 5982380.17 584424.31 N 70.36179361 W 149. 31418194 Ma 6916.14 63. 20 16. 56 3960.00 4038. 10 4917. 37 4711. 20 1408. 94 0.00 O.OOG 0.00 0.00 5983027.46 584608.92 N 70.36355630 W 149. 31262298 M61 7004.87 63. 20 16. 56 4000.00 4078. 10 4996. 57 4787.11 1431. 51 0.00 O.OOG 0.00 0.00 5983103.61 584630.64 N 70.36376367 W 149. 31243956 Mb2 7171.23 63. 20 16. 56 4075.00 4153. 10 5145. 06 4929. 45 1473. 82 0.00 O.OOG 0.00 0.00 5983246.40 584671.37 N 70.36415250 W 149. 31209563 Mc 7337.58 63. 20 16. 56 4150.00 4228. 10 5293. 55 5071. 79 1516. 13 0.00 O.OOG 0.00 0.00 5983389.18 584712.09 N 70.36454133 W 149. 31175168 Na 7426.31 63. 20 16. 56 4190.00 4268. 10 5372. 75 5147. 70 1538. 69 0.00 O.OOG 0.00 0.00 5983465.33 584733.81 N 70.36474870 W 149. 31156824 Nb 7481.76 63. 20 16. 56 4215.00 4293. 10 5422. 24 5195. 15 1552. 80 0.00 O.OOG 0.00 0.00 5983512.93 584747.38 N 70.36487831 W 149. 31145359 Nc 7548.30 63. 20 16. 56 4245.00 4323. 10 5481. 64 5252. 08 1569. 72 0.00 O.OOG 0.00 0.00 5983570.04 584763.67 N 70.36503384 W 149. 31131600 Ne 7570.48 63. 20 16. 56 4255.00 4333. 10 5501. 44 5271. 06 1575. 36 0.00 O.OOG 0.00 0.00 5983589.08 584769.10 N 70.36508569 W 149. 31127014 Nf 7681.39 63. 20 16. 56 4305.00 4383. 10 5600. 43 5365. 95 1603. 57 0.00 O.OOG 0.00 0.00 5983684.27 584796.25 N 70.36534490 W 149. 31104082 Drp 3/100 7718.10 63 .20 16 .56 4321.55 4399 .65 5633 .21 5397 .36 1612. 91 0.00 -180.OOG 0.00 0.00 5983715.78 584805.24 N 70.36543071 W 149 .31096491 End Drp /Target 7758.19 62 .00 16 .56 4340.00 4418 .10 5668 .80 5431 .48 1623. 05 3.00 O.OOG -3.00 0.00 5983750.00 584815.00 N 70.36552391 W 149 .31088246 OA 7758.21 62. 00 16. 56 4340.01 4418. 11 5668. 82 5431. 50 1623. 06 0.00 O.OOG 0.00 0.00 5983750.02 584815.00 N 70.36552396 W 149. 31088242 OBa 7886.00 62. 00 16. 56 4400.00 4478. 10 5781. 64 5539. 65 1655. 20 0.00 O.OOG 0.00 0.00 5983858.51 584845.95 N 70.36581939 W 149. 31062106 Oeb 7992.50 62. 00 16. 56 4450.00 4528. 10 5875. 68 5629. 78 1682. 00 0.00 O.OOG 0.00 0.00 5983948.93 584871.73 N 70.36606562 W 149. 31040321 OBc 8109.65 62. 00 16. 56 4505.00 4583. 10 5979. 12 5728. 94 1711. 47 0.00 O.OOG 0.00 0.00 5984048.40 584900.10 N 70.36633648 W 149. 31016358 OBd 8216.16 62. 00 16. 56 4555.00 4633. 10 6073. 15 5819. 07 1738. 27 0.00 O.OOG 0.00 0.00 5984138.82 584925.89 N 70.36658271 W 149. 30 2 8365.26 62 .00 16 .56 4625.00 4703 .10 6204 .80 5945 .27 1775. 78 0.00 O.OOG 0.00 0.00 5984265.41 584961.99 N 70.36692743 W 149 .3 1 OBe 8365.28 62. 00 16. 56 4625.01 4703. 11 6204. 82 5945. 29 1775. 78 0.00 O.OOG 0.00 0.00 5984265.43 584962.00 N 70.36692748 W 149. 309 67 OBf 8450.46 62. 00 16. 56 4665.00 4743. 10 6280. 03 6017. 38 1797. 21 0.00 O.OOG 0.00 0.00 5984337.75 584982.63 N 70.36712442 W 149. 30946642 OBf Base 8546.31 62. 00 16. 56 4710.00 4788. 10 6364. 67 6098. 50 1821. 33 0.00 O.OOG 0.00 0.00 5984419.13 585005.84 N 70.36734603 W 149. 30927034 8615.11 62. 00 16. 56 4742.30 4820. 40 6425. 41 6156. 73 1838. 64 0.00 O.OOG 0.00 0.00 5984477.54 585022.49 N 70.36750509 W 149. 30912959 TD / 7" Lnr Pt 8615.26 62 .00 16 .56 4742.37 4820 .47 6425 .54 6156 .85 1838. 67 0.00 O.OOG 0.00 0.00 5984477.66 585022.53 N 70.36750542 W 149 .30912929 WeIlDesign Ver SP 1.0 Bld(doc40x_56) N-P\Plan L-217 (N-P)\Plan L-217\L-217 (P5) Generated 4/19/2006 2:12 PM Page 2 of 2 ~P Schlumberger WELL FIELD STRULTURC L-217 (P5) Prudhoe Bay Unit - WOA L-PAD Magn&K Parameters SWace Laalnn NPD?> AlasYa SWIe Plalws. Zune Oa. US Fael Mwwllanepus MoOal: BGGM T005 Dip 80 BSti" Dale: May O6. ?COfi Lat. N]O Zt Z[]0 NoMng 59 /6:f01.J[ftU5 GM Cq.v. .O6J651[65" Sbr. N~P NU ReI Rdary TaEle x]6.10 fta6pve MSLI Mag Dec .?r Z]/' FS S]Sy91nT Lon. Wt[919 T6615 Easung Se]2535a ftUS Scale F.x1099990]B]3a PNn L-2t]~P51 Srvy Data AyrY 19. ?00fi 0 800 1600 2400 3200 4000 4800 5600 6400 800 1600 O O C 2400 I I N d5 U 3200 4000 4800 ............. ~ ....RTE....................:..................................:.................................. ~. KOP Bld 1.5H00 Bld 3.SN 00 Crv 3.SH00 ..-..-.._[.-..-.._.._.. .. -..-..-Y.-.._.. .._.._.._.._.._..y..-.._.._..-.._.._..-..-..r..-..-..-..-..-..-..-..-.y..-..-.._..-..-.._.._..-.1_..-..-.._..-..-..-..-..-1.-..-..-..-..-..-..-..-..K..-..-..-..-..-..-..-..-..r.._.._..~..~ a•• End Crv .-..-..- -..-..-..-..-..-..-..-. ._..-..-..-..-. -..-..-..-..-..-..-..-..T. -..-..-..-..-..-..-.. .-..-..-..-..-..-..-..- ..-..-..-..-..-..-..-..- -..-..-..-..-..-..-..-. -..-..-..-..-..-.. -..- _..-..-..- ..-..-..-j.-..-..-..-..-..-.._.._.. _Y._.._.._ _.._.._.._..y.._.._.._..-..-..-.._.._..r.._.._.._.._.._.._..-..-.~5...-..-..-..-..-..-..-..-.1-..-..-..-..-..-..-..-..-1.-..-..-..-..-..-..-..-..w.-..-..-..-..-..-..-..-.. ~..-..-..-..-.. .... ...... ...... 9-518" Csg Pt ..-..-..-i.-..-..-..-..-..-..-..-..~.-..-..-..-..-..-..-..-..i..-..-.._.. _.._.. _.. Y.. _.._ .._.._.._.._..-..-..-.r..-..-..-..-..-..-..-..-.i-..-..-..-..-..-..-..-..-1.-..-..-..-..-..-..-..-..~..-..-..-..-..-..-..-..-..J.._.._.._ y++,...+.+.,.+:,.++ \w\5~\\Y'[\Y\\YNW\Y\\Y\\rl\1YNW\\Ly\LNY\IYNYNY\\YNYi\+a\\V\\r\\YNY\\Y\\Y\\YN~\w++'{'.+'i'.+u++'++++~'.+w\~+++e+\+a+~ \YL\\w\~\W\\Y++a'.l'++'~+++u++ti'..+++ti'.+'+'.»\'.+'+l+'+++L\\Y\\Y\\Y\fYNYNY\\Lp\Yl\Y\\Y1W\\Y\\Y\\YNS~++~ Drp 3/100 End Drp _.._ .:.._ .L.1Q9.._..-..-..-..:.. .. .._.._.._:._.._.._.._.._.._.._.._..~._.. _.. _.. _.._.. _.._.. _...~.._.. _.. _.._.._..-..-.. _.. r.. _.. _.. _.. _.. _.._..-..-..... _.. _..-.. _.. _.. _.._.. _.:-.. _.. _.. _.. _..-..-..-..-~.-..-..-..-..-. Ocpl.TUgal.-.. t d .. _.. _.. _ ~._.._.._.._.._.._.. _.._.. y.-.. _.. _.._.. _.. _.._.. _.. y.. _..-..-.._..-.._.. _..-.. r.. _..-..-..-.._..-..-..-......-.....-..-..-..-..-..-.~-..-..-..-..-..-..-..-..-~. _.. _.. _.. _..-.. _.. _.. _.. ~.. . _.. _.. _.. _.. _.. _.. T.. _.. _.. _..-.. ..-..-..-[.-..-..-..-..-..-..-..-..-i._.._..-..-.._..-..-.._..~.._..-.._..-..-.._.._.._..4.._.._.._.._.._.._.._.._.r.._.._.._..-..-..-..-..-.7-.._..-.._.._.._.._.._.._I._.._.._.. _..-.._.. _.. _.. ~.. _.._ _.. _.. _.. _.. _.. i.. _.. _.. _.._.. .-..-..- -..-..-..-..-..-..-..-. -..-..-..-..-..-..-..-.y..-..-..-..-..-..-..-..-.*..-..-..-..-..-..-..-..- .-..-..-..-..-..-..-.. ..-..-..-..-..-..-..-..- ..-..-..-..-.._..-.._. _.._.._.._ - _.._.._ _.._..-..- -i.- .~.. .~.. _ -./- -1.- .~. w.rwrrwJwrrwuwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrRrrwrrwrrwrrwrrwrrwrrwrrwrrgrrwrrwrrwrrwrrwrrwwwrrwrrrrrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwrrwywrrwrrwrrwrrwrrwwwrrwrrw~rw:rw»w:+.~:rw»w:rw: f v •• ••- TD / 7" Lnr Pt, ~1~~P5) rw 0 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 16.63°, Scale = 1(in):800(ft) Origin = 0 NI-S, 0 E/-V 5600 6dQ0 0 800 1600 2400 3200 4000 4800 ' by Schlumherger WELL FIELD STRUCTURE L-217 (P5) Prudhoe Bay Unit - WOA L-PAD Magnerk Parameters SuRace Loratwn NA02] Alaska SNIe Planes. Zone 06. US Feet MlscelWneous Motley. BGGM 2005 Dip 9095fi' pale. May O9. 2006 Lal: N'0 2t 2610 NwiFiny. 59]8]01 N RUS Grb Conv •083fi5]466' Slol: N-P i•/D Rel Rolary Table 1]6.10 M1 above MSL) Mag Der •241]]" FS'. 515]91 nT Lon. W149 1916 WS Easliny: 5632515411US Swle Fx1:099990]9]3a Plan: L~21]IP51 Srvy Oala Apn119. 200fi -800 0 800 1600 2400 5600 4800 4000 n n n Z 0 0 3200 c a~ m U V ~ 2400 v 1600 800 5600 4800 4000 3200 2400 1600 800 -800 0 800 1600 2400 c« W Scale = 1(in):800(ft) E »> BP Alaska Anticollision Report Company: BP Amoco Date: 4/19!2006 Time: 14:27:34 Page: t Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinat e(NN:) Refe rence: Well: Plan L-217 (N-P), True North Reference Well: Plan L-217 (N-P) Vertical (fVD) Refere nce: L-217 plan N-P 78.1 Reference Wellpath: Plan L-217 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Refe rence: Principal Plan & PLANNED PROGRAM ' ', Interpolation Method: MD + Stations Interval: 5.00 ft Erro r Model: ISCWSA Ellipse ', Depth Range: 28.50 to 8615.26 ft Scan Method: Trav Cylinder No rth Maximum Radius:10000.00 ft .. _ - - -- - Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath ~ Date: 3/31/2006 Validated: No Version: 2 i Planned From To Survey Toolcode Tool Name ~ 28.50 1000A0 Planned: Plan #5-5 V1 GYD-GC-SS Gyrodata gyro single shots ~, 1000.00 2400.00 Planned: Plan #5-5 V1 MWD MWD -Standard 1000.00 8615.26 Planned: Plan #5-5 V1 MWD+IFR+MS MWD +IFR + Mu lti Station Casing Points MD 'fVD UiamEter Hule Size Name ft ft in in 3976.49 2763.10 9.625 12.250 9 5/8" ~, 8615.09 4820.39 7.000 8.750 7" ', Summary -- O ffset Wellpath - - ---~ Reference Offset ' Ctr-Ctr No-Go ,111owahle Site yYell Wellpath - MD MD Distance .Area Deviation Warnii ' ~~ ft ft ft ft ft I I - ~_ 8 - 0 ~ 6 6 1 PB L Pad L-02 L 02A V5 7 .4 720.00 199.28 .82 1 18 7.47 Pass: Major Risk PB L Pad L-02 L-02AP61 V2 717.41 720.00 199.28 11.82 187.47 Pass: Major Risk ~ PB L Pad L-02 L-02P61 V21 716.66 725.00 199.27 11.81 187.47 ~ Pass: Major Risk PB L Pad L-03 L-03 V5 806.69 820.00 143.38 14.86 128.52 Pass: Major Risk '; PB L Pad L-101 L-101 V4 1486.71 1555.00 193.28 27.72 165.56 Pass: Major Risk ' PB L Pad L-102 L-102 V2 279.10 280.00 217.30 4.51 212.79 Pass: Major Risk ', PB L Pad L-102 L-102P61 V10 279.10 280.00 217.30 4.60 212.70 Pass: Major Risk i PB L Pad L-102 L-102PB2 V2 279.10 280.00 217.30 4.60 212.70 Pass: Major Risk PB L Pad L-103 L-103 V23 867.17 865.00 52.86 14.25 38.61 Pass: Major Risk PB L Pad L-104 L-104 V7 388.99 390.00 200.27 6.56 193.71 Pass: Major Risk ', ' PB L Pad L-105 L-105 V4 569.24 570.00 190.57 10.35 180.21 Pass: Major Risk ' PB L Pad L-106 L-106 V14 968.90 990.00 153.34 16.48 136.86 Pass: Major Risk PB L Pad L-107 L-107 V14 355.63 355.00 183.54 7.59 175.95 Pass: Major Risk ~~ i PB L Pad L-108 L-108 V18 784.53 795.00 160.30 14.04 146.26 Pass: Major Risk ', PB L Pad L-109 L-109 V12 346.69 345.00 213.45 7.16 206.29 Pass: Major Risk i PB L Pad L-110 L-110 V11 300.99 300.00 241.77 5.53 236.24 t Pass: Major Risk ~ PB L Pad ~ L-111 L-111 V24 281.89 280.00 321.88 5.05 316.83 Pass: Major Risk ! PB L Pad L-112 L-112 V8 366.04 370.00 222.29 7.66 214.62 Pass: Major Risk PB L Pad L-114 L-114 V15 716.84 725.00 292.05 11.50 280.55 Pass: Major Risk ', PB L Pad L-114 L-114A V4 716.84 725.00 292.05 11.50 280.55 Pass: Major Risk ' PB L Pad ~ L-115 L-115 V7 708.01 710.00 139.91 11.94 127.98 Pass: Major Risk ', PB L Pad L-116 L-116 V10 811.42 830.00 216.50 13.13 203.37 Pass: Major Risk PB L Pad ~ L-117 L-117 V11 718.44 720.00 133.00 11.68 121.32 Pass: Major Risk ~ i, PB L Pad L-118 L-118 V9 2343.68 2370.00 44.37 22.52 21.84 Pass: Minor 1/200 - ~~, ! PB L Pad L-119 L-119 V9 509.17 510.00 93.56 8.64 84.92 Pass: Major Risk PB L Pad L-120 L-120 V8 293.98 295.00 122.33 5.09 117.24 Pass: Major Risk PB L Pad L-121 L-121 V14 226.68 225.00 263.42 4.13 259.29 Pass: Major Risk I~ PB L Pad L-121 L-121 A V1 226.68 225.00 263.42 4.13 259.29 Pass: Major Risk ' PB L Pad L-122 L-122 V5 371.09 370.00 175.89 6.17 169.72 Pass: Major Risk PB L Pad L-123 L-123 V5 401.80 400.00 191.86 7.45 184.41 Pass: Major Risk i, PB L Pad L-123 L-123P61 V3 401.80 400.00 191.86 7.45 184.41 Pass: Major Risk ', '~, PB L Pad L-124 L-124 V13 663.64 665.00 230.54 11.76 218.78 Pass: Major Risk ', PB L Pad L-124 L-124P61 V5 663.64 665.00 230.54 11.76 218.78 Pass: Major Risk PB L Pad L-124 L-124P62 V4 663.64 665.00 230.54 11.76 218.78 Pass: Major Risk '; PB L Pad L-200 L-200 V7 5854.06 5780.00 151.58 120.45 31.12 Pass: Major Risk PB L Pad L-200 L-200L1 V3 5854.06 5780.00 151.58 120.45 31.12 Pass: Major Risk ' ' PB L Pad L-200 L-200L2 V6 5854.06 5780.00 151.58 120.45 31.12 Pass: Major Risk I PB L Pad L-201 L-201 V6 2599.62 2475.00 82.78 60.63 22.15 , Pass: Major Risk ' PB L Pad L-201 L-201 L1 V9 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk ~, PB L Pad L-201 L-201 L1 P61 V10 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk BP Alaska Anticollision Report Company: BP AmOOO 'Date: .4/19/2006 Time: 14:27:34 Pale: 2 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(N1';) Reference: Well: Pla n L-217 (N-P), True North Reference Well: Plan L-217 (N-P) Vertical (TVD) Reference: L-217 plan N-P 78.1 Reference Wellpath: Plan L-217 Db: Oracle i Summary <- - -Offset Wellpath - Reference Offset Ctr-Ctr No-Go 411owable Site Well Wellpath MU MD Distance Area Deviation Warning ft ft ft ft ft PB L Pad L-201 L-201 L2 V5 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk ' ', PB L Pad L-201 L-201 L3 V2 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk ', PB L Pad L-201 L-201 L3P61 V6 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk ', PB L Pad L-201 L-201 PB1 V12 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk PB L Pad L-201 L-201 P62 V3 2599.62 2475.00 82.78 60.63 22.15 Pass: Major Risk ' '~ PB L Pad L-202 L-202 V5 829.27 830.00 29.56 14.04 15.52 Pass: Major Risk PB L Pad L-202 L-202L1 V7 829.27 830.00 29.56 14.04 15.52 Pass: Major Risk ', PB L Pad L-202 L-202L2 V6 829.27 830.00 29.56 14.04 15.52 Pass: Major Risk ', '~, PB L Pad L-202 L-202L3 V6 829.27 830.00 29.56 14.04 15.52 Pass: Major Risk ', PB L Pad L-210 L-210 V6 233.80 235.00 105.23 4.01 101.22 Pass: Major Risk ', PB L Pad L-210 L-210PB1 V8 233.80 235.00 105.23 4.01 101.22 Pass: Major Risk !, ' PB L Pad L-211 L-211 V6 664.65 665.00 149.11 11.63 137.48 Pass: Major Risk ', ~, PB L Pad L-211 L-211 P61 V6 664.65 665.00 149.11 11.63 137.48 Pass: Major Risk !, PB L Pad L-212 L-212 V11 579.61 580.00 15.98 9.83 6.15 Pass: Major Risk PB L Pad L-212 L-212P61 V9 579.61 580.00 15.98 9.83 6.15 Pass: Major Risk PB L Pad L-212 L-212P62 V2 579.61 580.00 15.98 9.83 6.15 Pass: Major Risk ' '~, PB L Pad L-214 L-214 V9 513.24 515.00 203.80 9.32 194.48 Pass: Major Risk ', PB L Pad L-214 L-214A V4 513.24 515.00 203.80 9.32 194.48 Pass: Major Risk ', ~, PB L Pad L-215 L-215 V7 454.68 455.00 58.87 8.30 50.57 Pass: Major Risk ' PB L Pad L-215 L-215PB1 V4 454.68 455.00 58.87 8.30 50.57 Pass: Major Risk PB L Pad L-215 L-215P62 V2 454.68 455.00 58.87 8.30 50.57 Pass: Major Risk '~, PB L Pad L-216 L-216 V6 254.69 255.00 30.48 4.47 26.01 Pass: Major Risk '~ PB L Pad L-218 L-218 V4 625.50 625.00 247.07 10.80 236.26 Pass: Major Risk ', PB L Pad L-250 L-250 V4 739.06 740.00 57.76 13.07 44.68 Pass: Major Risk j ~~ PB L Pad L-250 L-250L1 V14 739.06 740.00 57.76 13.07 44.68 Pass: Major Risk ' ~, PB L Pad L-250 L-250L2 V10 739.06 740.00 57.76 13.07 44.68 Pass: Major Risk ' ', PB L Pad L-250 L-250P61 V3 739.06 740.00 57.76 13.13 44.62 Pass: Major Risk PB L Pad L-50 L-50 V1 501.79 500.00 285.44 8.68 276.76 Pass: Major Risk PB L Pad L-50 L-50P61 V4 501.79 500.00 285.44 8.68 276.76 Pass: Major Risk ' PB L Pad NWE1-01 L-100 V2 281.08 280.00 374.67 4.93 369.73 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 281.08 280.00 374.67 4.93 369.73 Pass: Major Risk ' PB L Pad Plan L-04 (S-L) Plan L-04 V3 Plan: Pla 667.93 670.00 206.60 12.56 194.04 Pass: Major Risk ', PB L Pad Plan L-204 (S-U) Plan L-204 V3 Plan: PI 379.49 380.00 195.99 7.21 188.78 Pass: Major Risk ', PB L Pad Plan L-213 (S-Q) Plan L-213 V6 Plan: PI 379.99 380.00 181.31 8.42 172.88 Pass: Major Risk ~ PB L Pad Plan L-51 (S-B) Plan L-51 V3 Plan: Pla 629.47 630.00 308.85 13.29 295.56 Pass: Major Risk ~ PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 795.51 815.00 256.55 15.15 241.40 Pass: Major Risk ' i ', ~ Field: Prudhoe Bay ', 'i I, Site: PB L Pad ', Well: Plan L-217 (N-P) Wellpath: Plan L-217 58 I80 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre [o Centre Separation [IOOtVin] ' ! Target: L-217 Tgt e 1: Plan L-217 (N-P) Based on: Planned Program Vertical Depth: 4320.00 ft below Mean Sea Level Local +N/-S: 5431.46 ft Local +E/-W: 1623.05 ft Longitude: 149_°18'39.177W Radius: 150 ft __ ~ _ _ _ _ - _- __ %5 8 C 5~C 5 4- C ~C 82C 0 0 0 0 0 0 0 0 ~ co ~ o ~--~, • • TERRIE L NUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 "Mastercard Check" ANCHORAGE, AK 99519-6612 First National Bank Alaska Anchorage, AK 99501 MEMO ~~'Ld~ ~: L 2 5 2 0 0 0 6 0 ~: 9 9 14 ~~~ 6 2 2 7 ~~~ 1 5 5 6 ~~• 0 2 7 3 ss-si~zs2 273 DATE ~ (,l ~~ r: TRANSMITTAL LETTER CHECKLIST WELL NAME ~~CA ~~-~~,7 PTD# -Z06' --~ ~ S' Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No. 50- - - API number are , between 60-69) ~ Production should continue to be reported as a function of the ~ original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent i upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or ~ from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25106 C:\jody\transmittal_checklist _._. a11tLL °E~t°dIT CHECKL[ST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL,- 640135 _ Well Name: PRUDHO_E BAY UN GRIN L-217 Program SER_ Well bore seg PTD# 2060750 Company BP EXPLORATION !ALASKA) INC Initial Classffype SER 1 PEND GeoArea Unit OnlOff Shore On Annular Disposal Administration 1 Permit fee attached. - Yes - '2 Lease number appropriate Yes 3 .Unique well name and number Yes ~ 4 Well located an a defined pool Yes I5 Well-located proper distance-from. drilling unit boundary Yes - - - 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit - - Yes - - 8 If deviated, is wellbore plat included Yes - 9 Operator Only affected party Yes _ 10 Operator has appropriate-bond in force _ - Yes _ - 11 Permit can be issued without conseruationorder- - - - Yes 12 Permit. can be issued without administrative approval - Yes Appr Date 13 Can permit be approved before 15-day wait Yes RPC 5!3012006 14 Well located within area and strata authorized by Injection Order # (put 10# in-comments). (For Yes AIO 26 15 All wells within 114 mile area of review identified (For sereice_well only) - - - Yes - L-250, L-250L1, L-200, L-216i 16 Pre-produced injector; duration ofpre-production less. than 3 months (For service well. only) NA- - ' ACMP_Findng of Consistency has been issued-for this protect NA 18 Conductor siring provided Yes 20" @ 80'. Engineering 19 Surface casing. protects all_known USDWs Yes 20 CMT vol adequate-to circulate on conductor & surf csg _ Yes - Adequate excess, ',21 CMT vol adequate to tie-in long string to urf csg No I22 CMT will cover all known productive horizons Yes - - - 23 Casing designs adequate for C, T, B &. permafrost. Yes 24 Adequate tankage_or reserve pit Yes - Nabors 9ES, ',25 If a re-drill, has a-1.0-403 for abandonment been approved NA - _ New well 26 Adequate wellbore separation.proposed- Yes - - - 27 If diverter required, does it meet regulations - - - - Yes - 28 .Drilling fluid program schematic & equip list adequate- Y_es Max. MW 9,6 ppg, Appr Date 129 BOPEs, do they meet regulation Yes WGA 5/31/2006 30 BOPE-press rating appropriate; iest to (put prig in comments)- Yes Test to 4000-psi. MSP 1671 psi.. I31 Choke-manifold complieswlAPI-RP-53 (May 84) Yes - . - ~32 I Work wilt occur without operation shutdown_ _ - Yes - _ - - '33 Is presence of H2S ga@ probable - - No , - Not an H2S pad.. '34 Mechanical conditiori of wells within AOR verified (Focservice well only) Yes - - - - Cmk records of all AOR wells reviewed. _.. 35 - - -- .Permit-can be issued wlo hydrogen sulfide measures - - - No Geology 36 Data presented ogpotential overpressure zones.... NA X37 Seismic analysis. ofshallow gaszones- - _ NA_ _ _ _ _ Appr Date II38 .Seabed condition survey-(ifoff-shore) - NA- - RPC 5/3012006 X39 Contact namelphone far weekly_progress reports [exploratory only] - - - - NA- . - Geologic Date: Engineering Da te Commissioner: ioner: Com m i ss / Public / 'oner~,Dat~e ~ ~ r ~ ~
