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Home My WebLink About203-202 e e XHVZE Image Project Well History File Cover Page 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. c;(,03 - ~Q~ Well History File Identifier Organizing (done) o Two-sided /I 111111111" 111111 RE~AN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. , o Other, NolType: o Poor Quality Originals: o Other: NOTES: Date i3/0 0 Date d-8/ O~ ~ x 30 = ~O + I Date ~J?)tJ (0 BY: ~ Project Proofing BY: ~ Scanning Preparation BY: ~ '- Production Scanning Stage 1 h:J- (Count does include cover sheet) ~YES Page Count from Scanned File: BY: Page Count Matches Number in Scanning prjParation: ~ Date: ;;A/3/ofo If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 11111111111" 111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: 151 VVt{J 1//111/1111111 "III rnP 151 = TOTAL PAGES fa I (Count does not include cover sheet) 151 rnf 111111/1111111 /1111 151 NO Y11 P YES NO 151 "'"1/1111I11 11111 11I11111111111 /1111 151 Quality Checked //I "III/III" 1/11I 10/6/2005 Well History File Cover Page. doc • • --~,.. .~;~- -5. MICROFILMED 03101/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc 03/13/07 Schlumberger NO. 4179 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503M2838 A TTN: Beth d03-;)O'd Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Orion Well Job# Log Description Date BL Color CD L-213 11212849 CH EDIT USIT PDC-GR - 04/27/06 1 W-204 11630451 CEMENT BOND & IMAGE LOG 02102/07 1 W-205L2 11626070 RSTIWFL 02/05/07 1 S-213A 11628755 MEMORY GLS 02/14/07 1 V-105 11626370 IPROFILEIWFL 01129/07 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered 1'1 ,\ r~ ,;" ~¡ ')007 n '\ .,~ L" I Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503-2838 ATTN. Beth 'ì I I i . BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received by: C!'Ijf·t $CANNED APR 0 3 2007 ('..'- \.:<_.; )..,6 J~ tI\ DATA SUBMITTAL COMPLIANCE REPORT 1/3/2006 Permit to Drill 2032020 Well Name/No. PRUDHOE BAY UN POL W-205L2 Operator BP EXPLORATION (ALASKA) INC >p~ )..." ~ .\.~~.3 API No. 50-029-23165-61-00 MD 10670 ~ TVD 5093 - Completion Date 12/28/2003"'- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No ~-^._- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, AZI DEN, NEU, ABI Well Log Information: Log/ Data Type Þ Electr Digital Dataset Med/Frmt Number Name C Lis 13320 Induction/Resistivity Run No Log Log Scale Media ~ D Wrd Directional Survey Directional Survey /-og I nd uction/Resistivity JV¡Þ 25 Blu ,...kog I nd uction/Resistivity f"Vf:> 25 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? - Y IN' Daily History Received? Formation Tops Analysis Received? ~ Comments: I . Compliance Reviewed By: --..-'t() ,..... Current Status 1-01L UIC N ~--~ Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH/ . Start Stop CH Received Comments 6900 1 0625 Open 1 0/17/2005 GR RHO DRHO NPHI RES (LIS format + .pds graphics MDITVD) 0 10670 1/26/2004 0 10670 1/26/2004 6900 10625 Open 1 0/17/2005 GR RHO DRHO NPHI RES 6900 10625 Open 10/17/2005 GR RHO DRHO NPHI RES Sample Set Number Comments 0N (J;/N . Date: )- J~ N~Co SGblumllellgel' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description W-205L 1 40009936 OH LDWG EDIT OF LWD ADN & IMP W-205L 1 40009936 MD VISION SERVICE W-205L 1 40009936 TVD VISION SERVICE W-205L 1 PB1 40009936 OH LDWG EDIT OF LWD ADN & IMP W-205L 1 PB1 40009936 MD VISION SERVICE W-205L 1 PB1 40009936 TVD VISION SERVICE W-205L2 40009937 OH LDWG EDIT OF LWD ADN & IMP W-205L2 40009937 MD VISION SERVICE W-205L2 40009937 TVD VISION SERVICE W-209 10980560 SBHP SURVEY 12/14/03 12/14/03 12/14/03 12/14/03 12/14/03 12/14/03 12/21/03 12/21/03 12/21/03 8/14/05 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: /7 D(;t-~\- NO. 3498 Company: Alaska Oil & Gas Cons Camm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Date BL Color CD Schlumberger-DCS 2525 Gambel! St, Suite 400 Anchorage. Ap995 -2838 ILL ATTN: Beth 1\ Received by: U ~1... ^~^- 10/13/05 . . ~'¡JL . STATE OF ALASKA ._ ALAS~ AND GAS CONSERVATION COMI\WION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD, GR, RES, PWD, AZI DEN, NEU, ABI CASING, liNER AND CEMENTING RECORD SETTING DEPTH MO SETTING DEPTH TíIO HOLE Top -aOTTOM Top BOTTOM SIZE Surface 108' Surface 108' 48" 29' 3985' 29' 3180' 13-1/2" 26' 6930' 26' 5031' 9-7/8" 6925' 10631' 5029' 5094' 6-3/4" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3703' NSL, 1196' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 3846' NSL, 3148' EWL, SEC. 22, T11 N, R12E, UM (OBs) Total Depth: 1836' NSL, 3389' EWL, SEC. 15, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5958680 Zone- ASP4 TPI: x- 616390 y- 5958889 Zone- ASP4 Total Depth: x- 616575 y- 5962162 Zone- ASP4 18. Directional Survey a Yes 0 No 22. WVPER FT. 215.5# 45.5# 29.7# 12.6# GRADE A53 L-80 L-80 L-80 20" x 34" 10-3/4" 7-5/8" 4-1/2" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7003' - 7044' 5054' - 5063' 7054' -10587' 5065' - 5096' 26. Date First Production: March 1, 2004 Date of Test Hours Tested PRODUCTION FOR 3/11/2004 4 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED .-... Press. 300 1500 24-HoUR RATE""" 27. One Other 5. Date Comp., Susp., or Aband. 12/28/2003 6. Date Spudded 12/22/2003 7. Date T.D. Reached 12/23/2003 8. KB Elevation (ft): KBE = 80.90' 9. Plug Back Depth (MD+ TVD) 10670 + 5093 10. Total Depth (MD+TVD) 10670 + 5093 11. Depth where SSSV set (Nipple) 2584' MD 19. Water depth, if offshore N/A MSL 24. SIZE 4-1/2", 12.6#, L-80 Revised: 03/23/04, Put on Production 1b. Well Class: a Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-202 13. API Number 50- 029-23165-61-00 14. Well Name and Number: PBU W-20SL2 15. Field / Pool(s): Prudhoe Bay Field / Polaris Pool Ft Ft 16. Property Designation: ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD Uncemented Slotted Liner 897 sX PF 'L', 352 sx Class 'G" 561 sx Class 'G' Uncemented Slotted Liner AMouNt PUllED TUBING RECORD DEPTH SET (MD) 6895' PACKER SET (MD) 6770' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 110 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Injection Oll-BBl GAs-McF WATER-BBl 408 51 -0- Oll-BBl 2,450 GAs-McF 304 WATER-BBl -0- CHOKE SIZE I GAS-Oil RATIO 1760 124 Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 , JGINAL CONTINUED ON REVERSE SIDE ¡\~ îùC4 ~.8fl MAM2 ~ t,\;.t '. 28.· GEOLOGIC MARKERS. 29. ..... ~JRMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff Zone OBa 6928' 5030' None Schrader Bluff Zone OA 9750' 5095' Schrader Bluff Zone OBa 9823' 5095' ~ 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Af\.Ì,( ~ Title Technical Assistant 203-202 Date Oo·~3 -0<-{ PBU W-205L2 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Michael Triolo, 564-5774 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". OQlGINAL Form 10-407 Revised 12/2003 __ STATE OF ALASKA ALASK~AND GAS CONSERVATION COMr4aION WELL COMPLETION OR RECOMPLETION REPOR"1rND LOG 1a. Well Status: IS! Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20MC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3703' NSL, 1196' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 3846' NSL, 3148' EWL, SEC. 22, T11N, R12E, UM (08a) Total Depth: 1836' NSL, 3389' EWL, SEC. 15, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049' y-.. 59!5_~f3_s..0~ Zone-u~~~~~__ TPI: x- 616390 y- 5958889 Zone- ASP4 Total Depth: x- 616575 y- 5962162' Zone---ÄSP4-~ 18. Directional Survey IS! Yes 0 No 21. Logs Run: MWD, GR, RES, One Other 5. Date Comp., Susp., or Aband. 12/28/2003 . 6. Date Spudded '"1--ì . 12t.W'2003 ' ßb 7. Date T.D. Reached 12/23/2003 ' 8. KB Elevation (ft): KBE = 80.90' 9. Plug Back Depth (MD+ TVD) 10670 + 5093 10. Total Depth (MD+TVD) 10670 + 5093 11. Depth where SSSV set (Nipple) 2584' MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" x 34" 10-3/4" 7-5/8" 4-1/2" PWD, All DEN, NEU, ABI CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE Top BOTTOM Top BOTTOM SIZE Surface 108' Surface 108' 48" 29' 3985' 29' 3180' 13-1/2" 26' 6930' 26' 5031' 9-7/8" 6925' 10631' 5029' 5094' 6-3/4" 22. WT. PER FT. 215.5# 45.5# 29.7# 12.6# GRADE A53 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7003' - 7044' 5054' - 5063' 7054' - 10587' 5065' - 5096' 26. Date First Production: Not on Production Yet Date of Test Hours Tested 24. SIZE 4-1/2", 12.6#, L-80 25. 1 b. Well Class: IS! Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-202 13. API Number 50- 029-23165-61-00 14. Well Name and Number: PBU W-205L2 15. Field 1 Pool(s): Prudhoe Bay Field / Polaris Pool Ft 16. Property Designation: Ft ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) t/10~&-N ~;ffJ¿,:;::ff CEMENTING RECORD Uncemented Slotted Liner 897 sx PF 'L', 352 sx Class 'G" 561 sx Class 'G' Uncemented Slotted Liner AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6895' PACKER SET (MD) 6770' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 110 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-BBL GAs-McF WATER-BBL 27. CORE DATA IMJ Q l\ìno.~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach '3ëþ'à'rcrlê M1æ't, If' necessary). Submit core chips; if none, state "none"...__.. . ..w..... ; ï .,- j L?~:?~·_Ej .,'. l¡:::';~":;~:::~,,\ ~.' ¡ ""ÞLJ ¡ L:·::=:::..:=·:·~::.:Û R , G \ N A L CONTINUED ON REVERSE SIDE PRODUCTION FOR TEST PERIOD .. CALCULATED ....... 24-HoUR RATE"'" OIL-BBL Flow Tubing Casing Pressure Press. None Form 10-407 Revised 12/2003 GAs-McF WATER-BsL I GAS-OIL RATIO OIL GRIEe~/E: CHOKE SIZE Alaska m¡ & Gas: CO!ìS Anchorage fEB 0 '!ª\[\\ tV.~ , \~BfL tJ\v 28. GEOLOGIC MARKER. NAME MD TVD Schrader Bluff Zone OBa 6928' 5030' Schrader Bluff Zone OA 9750' 5095' Schrader Bluff Zone OBa 9823' 5095' 29. 'eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RE JAN '2 f-\la3ka 01\ 8r. Gas 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~. ~ Title Technical Assistant PBU W-205L2 203-202 Well Number Date ot· ~9..oC{ Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Michael Triolo, 564-5774 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 u¡ It\ IAL \ \'\J .. · '. Well: Field: API: Permit: W-205L 1 & L2 Prudhoe Say Unit 50-029-23165-60 & -61 203-201 & 203-202 Accept: Spud: Release: Rig: 12/1 0/03 12/14/03 12/28/03 Nabors 9ES PRE-RIG WORK 11130/03 WELL SHUT IN UPON ARRIVAL. DRIFT NEW 1.5" CT WI 0.937" STEEL BALL. MU BAKER MHA WI 2.5" JSN. RIH AND JET TUBING WI HOT CRUDE. TAGGED TOP OF PARRAFIN PLUG AT 3008' CTMD AND MELTED THROUGH VARIOUS PLUGS DOWN TO 3970' CTMD. 12/01/03 CONTINUE JETTING TUBING AND MANDRELS WI HOT CRUDE TO 6580' CTMD. PLACED WELL IN TEST AND RIH TO 10,145 WHERE LOCKUP OCCURED. FLAGGED COIL AT 10,100' CTMD FROM PROD LOGGING RUN AND POOH. MU PDS M GR/CCL STP AND RIH TO 6500' CTMD' AND WAIT FOR WELL TO STABILIZE. MADE STP STOP COUNTS AT 6500', 7600', 8100', 8600', 9100', 9600', 10090'; CTMD. LOGGED STP UPIDOWN PASSES AT 30 & 60 FPM. AVERAGE TEST RATE = 917 BPD GFR, 862 BOPD, 2.89 MM GL, 1.2 MM FORMATION GAS, 418 PSI, 59 DEG F. FLAGGED COIL AT 7500' CTMD, AND MADE JEWLERY LOG UP TO 6200'. PULLED SURFACE SAMPLES FROM LIQUID LEG OF TEST SEPARATOR. MADE +30 FT CORRECTION TO TIE-IN TO SWS DENSITY NEUTRON 23-AUG-03 TO 06-SEP-03, RUN #5. LAY DOWN PDS TOOLS AND MU BAKER 2.50" IBP (1-3/8" JDC FN, 2 X 0.53' RUBBER ELEMENT, 5500# PULL RELEASE, OAL=11.58') AND RIH TO FLAG. RESET COUNTER TO CEL @ 7525' AT FLAG. 12/02/03 DROP BALL, WAIT 3 HOURS FOR TEMPERATURE STABILIZATION, AND SET BAKER 2.50" IBP AT 7610'. TAG IBP WI3K, PLUG SET. POOH CHASING OUT AT 80% W/1% KCL TO 2500'. FREEZE PROTECT FROM 2500' TO SURFACE. PRESSURE TEST IBP TO 1000 PSI- PASS. FP FLOWLINE W/15 BBLS 60/40 MEOH. RDMO. WELL LEFT SHUT IN. JOB COMPLETE. 12/03/03 ATTEMPT TO SET CATCHER, FAILED DUE TO PARAFIN. LRS PUMPED 300 BBLS HOT CRUDE DOWN lA, RETURNS UP TUBING. DRIFT TO TT @ 6650' WI 3.70 GAUGE RING & 4 1/2" BRUSH. SET 4 1/2" XN CATCHER SUB @ 6534' SLMD. RIH TO PULL SPMG. 12/04103 PULL 1" SPMG FROM STA. # 1. @ 6508' MD. BK LATCH. (LEFT POCKET OPEN). PULL 1" SIO FROM STA. #2. @ 6306' MD. 22/64" PORT. BK LATCH. FIRST ENERGY PUMPED 60 BBL. OF METHANOL TO CLEAR UP HYDRATES. PULL 1" DOME FROM STA. # 4. @ 3015' MD. 16/64" PORT. BK LATCH. SET DGLV STA. #4. BK LATCH. SET DGLV STA. #2. BK LATCH. SHIFT OPEN BAKER CMD SLIDING SLEEVE. PULL XN CATCHER SUB (EMPTY). 12/06/03 LOG SLIM CEMENT BOND LOG. TOOL = 44.2 FT X 1.69" MAX 00. SET DOWN AT 7180' MD (HAW) AND LOG UP TO 6100' MD. ON DESCENT TO LOG REPEAT SECTION OF 4.5" TUBING, TOOL GOT STUCK IN GLM AT 6196 FT. PUMPED 45 BBLS CRUDE DOWN lA, THROUGH SLIDING SLEEVE. RETURNS TO FLOWLlNE- PULLED 1850 LBS (1200 LBS OVER) AND TOOL CAME FREE. TUBING PUNCHER (2ND RIH) = 22.4 FT X 1.69" MAX 00. INTERVAL SHOT = 6454-6456 FT MD. WHP BEFORE AND AFTER SHOT = 200 PSI. lAP BEFORE AND AFTER SHOOT = 300 PSI. 12/07/03 A 3 5/8" CHEMCIAL CUTTER WAS RUN TO CUT THE PREMIER PACKER @ 6440'. DEPTHS FOR CUT ZONE GIVEN BY BAKER. TO NOT TAGGED. WELL WAS LEFT SHUT IN. PAD OPERATOR NOTIFIED. T/I/O= 1601300/40 CIRC-OUT TUBING & IA. (PRE-RIG) PUMPED DOWN THE IA TAKING RETURNS TO THE FLOWLINE; 5 BBL NEAT MEOH SPEAR, 367 BBLS SEAWATER, 5 BBLS MEOH, 105 BBLS DIESEL. U-TUBE TO FREEZE PROTECT. BLEED DOWN TUBING & IA. FREEZE PROTECT FLOWLINE WITH 15 BBLS NEAT MEOH. FINAL WHP'S=O/OIO. Legal Name: W-205 Common Name: W-205 Test Date 8/26/2003 8/27/2003 8/28/2003 8/26/2003 9/5/2003 12/21/2003 LOT LOT LOT LOT FIT FIT Test Type Test Depth (TMD) (ft) 4,414.0 (ft) (ft) 3,985.0 (ft) 7,618.0 (ft) 6,956.0 (ft) BP Leak-Off Test Summary Test Depth (TVD) (ft) 3,190.0 (ft) (ft) 3,190.0 (ft) 5,184.0 (ft) 5,031.0 (ft) AMW···· (ppg) 9.20 (ppg) (ppg) 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) Suñace Pressure (psi) 825 (psi) (psi) 825 (psi) 684 (psi) 750 (psi) Leak Off Pre$$u~:(aHP) (psi) 2,350 (psi) (psi) 2,350 (psi) 3,162 (psi) 3,154 (psi) Page 1 of 1 EMW (ppg) 14.18 (ppg) (ppg) 14.18 (Ppg). 11.74 (ppg) 12.07 (ppg) . Printed: 12/29/2003 9:47:07 AM . . BP Operations Summary Report Page 1 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of 12/10/2003 03:00 - 05:30 2.50 MOB P PRE Release rig from V-202 at 03:00 hrs on 12-10-03. Held PJSM with Rig Crew & Peak. Move camp, mud pits and shop to W Pad. RID Drill Floor. Move rig off V-202 well. 05:30 - 07:00 1.50 MOB P PRE Lower Cattle chute. Lay down 9ES derrick & prepare sub-base for rig move. 07:00 - 10:30 3.50 MOB P PRE Move rig off V-Pad location onto Spine road. Rig in transit, arrived on W-Pad @ 10:30 hrs with no problems. 10:30 - 14:00 3.S0 RIGU P PRE Lay mat's & herculite. Move rig's sub base & spot over W-205, level rig. Spot pit module & cuttings tank. Spot camp. 14:00 - 16:00 2.00 RIGU P PRE PJSM. Raise derrick. Hook-up power,water, steam and mud lines. Accept Rig at 16:00 hrs on December 10, 2003. 16:00 - 21 :30 5.50 RIGU P PRE Take on seawater in pits. RlU cellar & rig floor. Load 4" DP in pipe shed. 21 :30 - 22:30 1.00 WHSUR P DECOMP RIU circulating lines from rig floor to Production Tree for reversing out diesel freeze protection from 4.5" tubing & 4.5" x 7-S/8" annulus. 22:30 - 23:30 1.00 WHSUR P DECOMP RIU DSM Lubricator. Pull BPV from tubing hanger. UD DSM lubricator. Pressure on well reading 0 psi. 23:30 - 00:00 0.50 WHSUR P DECOMP SAFETY- Held PJSM with rig crew & service personnel regarding the displacement of the diesel freeze protect & decompletion of well. 12/11/2003 00:00 - 01 :30 1.50 WHSUR P DECOMP Purge HP circulating lines from rig to production tree with seawater. Test to 3500 psi. Line up to reverse out. All returns routed through C/K manifold. Pump 50 bbl seawater@ 4.7S bpm wI 575 psi down 4.5" x 7-5/8" annulus taking diesel returns & contaminated fluid to cuttings tank. Stop pumping & line up to pump down the 4.5" tubing. Pump 117 bbl down tubing @ 4.75 bpm wI 200 psi. Recover 63 bbl diesel & SO bbl contaminated fluid. Monitor well. Well static. 01 :30 - 02:00 0.50 WHSUR P DECOMP Blow down all circulating lines & C/K manifold. RID 2" HP hose coming off Flare line to cuttings tank. Secure Flare line outlet with bull plug. 02:00 - 02:30 O.SO WHSUR P DECOMP Install TWCV in 4.5" tubing hanger. Test from below to 1000 psi. 02:30 - OS:OO 2.50 WHSUR P DECOMP PJSM. N/D CIW 4-1116" 5m Production Tree & adapter flange. Inspect TCII threads in hanger-OK. 05:00 - 07:30 2.50 BOPSUR. P DECOMP N/U 13-5/8" Sm BOP stack & related equipment. 07:30 - 08:00 O.SO BOPSUR P DECOMP MIU cross-over sub on 4" DP test joint. Screw into tubing hanger. RlU to test BOP. 08:00 - 12:00 4.00 BOPSU¡;P DECOMP Test BOPE to 2S0 psi Low / 3S00 psi High, Annular 250 psi Low / 3SOO psi High. Witnessed of test waived by Chuck Scheve, AOGCC. 12:00 - 12:30 0.50 BOPSUR.P DECOMP RID BOP test equipment. Blow down TDS & all surface lines. 12:30 - 13:30 1.00 BOPSURP DECOMP RlU DSM lubricator & pull TWCV. RID same. FMC back out lock down screws on 11" tubing spool. 13:30 - 14:30 1.00 PULL P DECOMP RlU to puIl4.S" Tubing string. MIU TDS into 4.S" Tubing Landing Joint. Pull 11" x 4.5" tubing hanger free with 1 oak, pull hanger above rotary table. Monitor well. No flow, well static. 14:30 - 16:30 2.00 PULL P DECOMP Break circulation & stage up pumps slowly to 5.8 bpm w/1 00 psi. No gas or oil observed coming from well while circulating. Circulated a total of 253 bbl. Flow check. Well static. Pump slug. Printed: 12/29/2003 9:47:18 AM .., .. -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations, 12/11/2003 16:30 - 23:30 7.00 PULL P DECOMP POOH. UD 11" x 4.5" tubing hanger, 152 Joints of 4.5" 12.6# L-SO IBT-M tubing & related completion jewelry. 100% recovery of all items. 23:30 - 00:00 0.50 PULL P DECOMP RID tubing handling equipment. Clean up rig floor. 12/12/2003 00:00 - 01 :00 1.00 PULL P DECOMP Clear & clean Rig Floor. 01 :00 - 02:00 1.00 BOPSURP DECOMP RlU & test Lower pipe rams (2-7/S" x 5" VBR) TO 25013500 PSI. Witness of test waived by Chuck Scheve-AOGCC. RID test equipment. Run & install wear bushing. 02:00 - 02:30 0.50 CLEAN P DECOMP Place BOT mills on rig floor. Load Pipe Shed with MWD & other BHA componets. 02:30 - 04:00 1.50 CLEAN P DECOMP Slip & cut 40' of drill line. Re-set & test e-Q-M. Service TDS. 04:00 - 04:15 0.25 CLEAN P DECOMP P/U 9 joints of 4" DP & rack in derrick. 04:15 - 04:30 0.25 CLEAN P DECOMP SAFETY- Held PJSM with Rig Crew, Baker & Schlumberger Service personnel on picking up clean out BHA. 04:30 - 06:30 2.00 CLEAN P DECOMP MIU 6-314" Mill assembly. Shallow test MWD. Take on 9.2# MOBM while MIU BHA. 06:30 - 13:00 6.50 CLEAN P DECOMP TIH with 6-3/4" Mill assembly picking up 4" DP from pipe shed. Tag-up @ 7523'. P/U 140k SIO 101k 13:00 - 14:00 1.00 CLEAN P DECOMP Pump HV sweep & circulate hole clean with seawater from 7523' w/ 270 gpm @ 900 psi. Reciprocate drill string while circulating. 14:00 - 15:30 1.50 CLEAN P DECOMP Pump spacer. Displace hole with 9.2 ppg MOBM @ 275 gpm wI 1640 psi FCP. Reciprocate drill string once MOBM reached bit. 15:30 - 16:30 1.00 CLEAN P DECOMP POOH to 6695'. 16:30 - 21 :00 4.50 EVAL P DECOMP M/U TDS. Break circulation. Circulate & logging down with MWD-GR from 6750' to 7500' to comfirm RA Tag positions for calculating space-out requirements for whipstock. ( Circ rate 270 gpm wI 1600 psi). 21 :00 - 00:00 3.00 CLEAN P DECOMP Flow Check-0K. Pump slug. POOH for Whipstock. P/U = 135k S/O = 95k Rot = 113k Torque = 5400 FtLb 12/13/2003 00:00 - 00:30 0.50 CLEAN P DECOMP Finish POOH with 4" DP to BHA. 00:30 - 02:00 1.50 CLEAN P DECOMP POOH with 4" HWDP & 4-3/4" DC. UD 6.75" Mills & MWD tool. 02:00 - 03:00 1.00 CLEAN P DECOMP P/U 4.5" Memory Pressure gauge. Break connections on pup jt & UD same. 03:00 - 03:15 0.25 STWHIP P WEXIT SAFETY- Held PJSM with Rig Crew & Service company personnel regarding whipstock handling & running procedures. 03:15 - 05:30 2.25 STWHIP P WEXIT M/U Baker 7-5/S" Whipstock assembly #1. Orient MWD with whipstock. 05:30 - 10:00 4.50 STWHIP P WEXIT TIH with 7-5/S" Whipstock assembly on 4" DP t07460'. P/U = 140k S/O = 95k 10:00 - 11:00 1.00 STWHIP P WEXIT MIU TDS. Estabish circulation. Orient whipstock 15 deg LHS. Stab dummy seal assembly into tie-back sleeve @ 7523'. Set down 20 k to set whipstock anchor. PU 5k over to verify anchor set. Set down 40k to shear whipstock lug. Test 7-5/S" casing to 1000 psi for 10 minutes-OK. 11:00-14:30 3.50 STWHIP P WEXIT Mill Window in 7-5/S" casing from 7173' to 71S5' and drill 12' of new hole to 7197'. RPM = 120 Torque = 5-7k FtLb GPM = 270 @ 1840 psi Printed: 1212912003 9:47:18AM . . BP Operations Summary Report page30f 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2003 11 :00 - 14:30 3.50 STWHIP P WEXIT Rotate Wt = 113k 14:30 - 16:00 1.50 STWHIP P WEXIT Pump hi-vis sweep. Circulate hole clean with 350 gpm @ 2175 psi. Work Mills through Window with pumps, then withouts pumps. Window clean & clear. 16:00 - 16:30 0.50 STWHIP P WEXIT Perform FIT. Pressure up on formation to 760 psi with 9.2 ppg MOBM @ 5116' TVD = 12.0 ppg EMW. Pumped 1.2 bbl mud. Bleed-back volume = 1 bbl. Flow check. Well static. Pump slug 16:30 - 19:00 2.50 STWHIP P WEXIT POOH with 4" DP to top of BHA. 19:00 - 20:30 1.50 STWHIP P WEXIT Continue POOH with BHA. LID MWD & Milling assembly. 20:30 - 21 :00 0.50 STWHIP P WEXIT Clean rig floor. 21:00-21:30 0.50 STWHIP P WEXIT MIU ported sub. Flush out BOP's. UD sub. 21 :30 - 21 :45 0.25 DRILL P PROD1 SAFETY- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. 21 :45 - 23:30 1.75 DRILL P PROD1 MIU 6-3/4" Steerable Drilling assembly. Test MWD-OK. 23:30 - 00:00 0.50 DRILL P PROD1 TIH with 6-3/4" BHA picking up 4" DP from pipe shed. 12/1412003 00:00 - 02:30 2.50 DRILL P PROD1 Continue TIH with 6.750" Steerable Drilling assembly picking up 4" DP (108 Jts) to 4095'. 02:30 - 04:00 1.50 DRILL P PROD1 Finish TIH with 4" DP from derrick to 7150'. 04:00 - 05:00 1.00 DRILL P PROD1 MIU TDS. Establish circulation. Circulate bottoms-up w/250 gpm @ 2525 psi. PIU = 130k SIO = 98k. Take SPR's & take ECD benchmark reading. Had 10.56 ppg ECD @ 250 GPM + 60 RPM. 05:00 - 05:30 0.50 DRILL P PROD1 Stop pumps. Slack-off to 7188'. Stage pumps to 250 gpm. Wash down through undergauge hole F/7188'-7197'. 05:30 - 00:00 18.50 DRILL P PROD1 Drill 6-3/4" directional hole from 7197' to 8568'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 5-15k RPM = 60 Torque off Btm = 6.7k FtLb, Torque on Btm = 9k FtLb GPM = 275 @ 3100 psi on Btm w/100-300 psi Diff Pressure. P/U 135k SIO 81k ROT 108k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8568' = 10.5, Actual ECD = 11.3 NOTE: The AIM tool failed at 7822'. Landed wellbore into Obc sand @ 7310' MD/5131' KBTVD. At 8052' came out the bottom of Obc Lower sand. Build to 94 deg. Regain Obc contact @ 8190', Then drilled out the top of zone @ 8290'. Rotate & slide as required. Regained Obc contact @ 8400'. ART = 3.17 Hrs AST = 6.03 Hrs Survey/Connection = 9.30 Hrs Drilling Time last 24 Hrs= 9.20 hrs 12/1512003 00:00 - 11 :00 11.00 DRILL P PROD1 Drill 6-3/4" directional hole from 8568' to 9284'. Slide as required to maintain inclination & azimuth. Take survey every 30'. Printed: 12/29/2003 9:47:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ... .. BP Operations Summary Report W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 From -To Hours Task Code NPT Phase Description of· Operations 12/1512003 00:00 - 11 :00 11:00 -13:30 13:30 - 19:00 19:00 - 19:15 19:15 - 20:30 20:30 - 21 :00 21 :00 - 22:30 22:30 - 23:00 23:00 - 00:00 12/16/2003 00:00 - 01:00 01 :00 - 02:30 02:30 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 12:00 12:00 - 00:00 11.00 DRILL P 2.50 DRILL N 5.50 DRILL N 0.25 DRILL N 1.25 DRILL N 0.50 DRILL N 1.50 DRILL N 0.50 DRILL N 1.00 DRILL N 1.00 DRILL N 1.50 DRilL N 2.00 DRILL N 2.00 DRilL N 1.00 DRILL N 1.00 DRilL N 3.50 DRILL N 12.00 DRILL N PROD1 WOB = 15-20k RPM = 60 Torque off Btm = 6k FtLb, Torque on Btm = 10k FtLb GPM = 275 @ 3100 psi on Btm wI 100-300 psi Diff Pressure. P/U 158k SIO 62k ROT 109k DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAl PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 9284' = 10.62, Actual ECD = 11.11 ART = 3.9 Hrs AST = 2.35 Hrs Survey/Connection = 4.75 Hrs Drilling Time last 24 Hrs= 6.25 hrs Note: Due to a unaccceptable amount of pay zone drilled in the l1 lateral a decision was made by BP Drilling department to perform a Open Hole sidetrack at +1-8200' MD. Pump HV Sweep & circulate hole clean (3.8 x Btm-up vol) from 9284' with 300 gpm @ 3170 psi. Reciprocate & rotate drill string (80 RPM) while circulating. ECD after circulating: Calculated ECD = 10.62 Actual ECD = 10.68. P/U 142k S/O 85k POOH. Encountered intermittent tight hole from 8755' to 8000'. Passed through window @ 7173' with no problems. Continue POOH to top of BHA. SAFETY- Held PJSM with Rig Crew & SWS personnel regarding UD BHA & unloading RA sourse. POOH. Stand back Jars. Unload RA sourse. UD BHA #3. Clean Rig Floor of excess MOBM generated from trip. MIU New 6-3/4" Security FM3643 PDC Bit & BHA #4 (Note: BHA #4 consist of all fresh tools ). AIM-MWD-VPWD-ADN. Orient MWD. PJSM. Load RA source. TIH to 1100'. Shallow test MWD. MWD Tool transmitting incorrect survey data. Trouble shoot problem. Unable to rectify problem. POOH from 1100' to change out MWD tool. MWD Tool failure- POOH to BHA. PJSM. Download RA sourse. Change out MWD tools. M/U BHA #5. Orient MWD to Mud-motor. load RA sourse. TIH to 735'. Shallow test MWD-OK. Continue TIH with 6-3/4" Steerable Drilling asembly on 4" DP to 6800'. Slip & cut 30' of drill line. Reset & check C-O-M. Checks Brakes. Service TDS. TIH to 7100'. Establish circulation. CBU. Orient Bit to 14 deg lHS. Stop pumps. Slack off & pass through window with no problems. TIH to 8100'. Break circulation. Stage pumps to 275 gpm wI 2700 psi. Orient TF to low side for Open Hole Sidetrack. Wash down to 8180'. Start trenching from 8180'-8200'. Drill 6-3/4" directional hole (L 1-ST #01) from 8200' to 9098'. Slide as required to maintain inclination, azimuth & pay zone Printed: 12/29/2003 9:47:18 AM ..... . BP Operations Summary Report Page 50t 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2003 12:00 - 00:00 12.00 DRILL N DPRB PROD1 contact. Take survey every 30'. WOB = 15-20k RPM = 60 Torque off Btm = 6.9k FtLb, Torque on Btm = 9.3k FtLb GPM = 275 @ 3150 psi on Btm w/100-300 psi Diff Pressure. P/U 148k SIO 77k ROT 105k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 9098' = 10.50, Actual ECD = 11.05 ART = 3.25 Hrs AST = 5.05 Hrs SurveylConnection = 4.7 Hrs Drilling Time last 24 Hrs= 8.30 hrs 12/1712003 00:00 - 02:30 2.50 DRILL N DPRB PROD1 Drill 6-3/4" directional hole (L 1-ST #01) from 9098' to 9284'. Slide as required to maintain inclination, azimuth & pay zone contact. Take survey every 30'. 02:30 - 18:00 15.50 DRILL P PROD1 Drill 6-3/4" directional hole (L 1-ST #01) from 9284' to 10680' TD. Slide as required to maintain inclination, azimuth & pay zone contact. Take survey every 30'. WOB = 15-20k RPM = 60 Torque off Btm = 10k FtLb, Torque on Btm = 12k FtLb GPM = 275 @ 3150 psi on Btm w/100-300 psi Diff Pressure. P/U 148k S/O 78k ROT 105k Backream every stand at 275 gpm and 40-60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 10530' = 10.64 , Max ECD = 11.40 ART = 4.34 Hrs AST = 3.36 Hrs SurveylConnection = 10.30 Hrs Drilling Time last 24 Hrs= 7.70 hrs 18:00 - 21:30 3.50 DRILL P PROD1 Circulate & condition mud/hole (4 x Btm-up vol) from 10680' with 295 gpm @ 3335 psi. Reciprocate & rotate drill string (80 RPM) while circulating. Calculated ECD @ 10680' = 10.86 , Actual ECD = 11.25 prior to trip P/U 165k-No pump, S/O 82k-No pump 21 :30 - 00:00 2.50 DRILL P PROD1 POOH for wiper trip to 8451' (Midnight depth). Hole slick from bottom up to 10385', encountered drag increase with intermittent tight hole to from 10385' to 8451'. Tight spots seem to correspond to slid intervals. 12/18/2003 00:00 - 01:00 1.00 DRILL P PROD1 Continue POOH for wiper trip from 8451' to 7185'. Had normal drag F /8451' -8200'. 01 :00 - 03:30 2.50 DRILL P PROD1 Fill drill string. TIH to 8158'. Orient TF to LS. Continue TIH entering l1 ST #01 @ 8200'. Finish TIH to 10623' with no problems. 03:30 - 07:30 4.00 DRilL P PROD1 Establish circulation. Precautionary wash to bottom @ 10680' with no problems. Circulate bottoms-up with 250 gpm @ 2730 Printed: 12/2912003 9:47:18 AM ~- - ". .- BP Operations Summary Report Page 6 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/18/2003 03:30 - 07:30 4.00 DRILL P PROD1 psi + 80 RPM (Had a large volume of drill cuttings come over shakers on Btm-up). Pump HV sweep. Circulate & condition mud/hole (4 x Btm-up) with 300 gpm @ 3310 psi. Reciprocate & rotate drill string (80 RPM w/9.4-10K Torq) while circulating. P/U 150k S/O 76k with pumps Calculated ECD @ 10680' = 10.80 , Actual ECD = 11.07 07:30 - 11 :00 3.50 DRILL P PROD1 Flow check. Well static. Pump slug. POOH to 7160' with no problems. 11 :00 - 12:00 1.00 DRILL N RREP PROD1 Held PJSM. Change out air boot sealing element on bell-nipple. 12:00 - 13:30 1.50 DRILL P PROD1 Break circulation. Stage pumps to 275 gpm. Orient TF to 14 deg LHS. Stop pumping. Slide bit down past window & place circulation sub at 7185'. Drop ball-rod. Break circulation. Open circ sub with 2300 psi. Stage pumps to 550 gpm with 3470 psi. Wash whipstock face 10 minutes. Pull circ sub above whipstock. Pump HV sweep. Circulate hole clean from 7160' with 550 gpm @ 3470 psi. 13:30 - 16:30 3.00 DRILL P PROD1 Flow check. Well static. Pump slug. POOH to BHA. 16:30 - 16:45 0.25 DRILL P PROD1 SAFETY- Held PJSM with rig crew & SWS personnel on removing RA sourse & UD BHA. 16:45 - 18:00 1.25 DRILL P PROD1 Remove RA sourse from ADN tool. UD BHA. 18:00 - 18:30 0.50 DRILL P PROD1 Clean rig floor & removing excess directional equipment. 18:30 - 19:00 0.50 STWHIP P PROD1 SAFETY-- Held PJSM with rig crew, SWS & Baker personnel regarding M/U Whipstock retrieving tool (WSRT) & BHA. 19:00 - 20:00 1.00 STWHIP P PROD1 MIU L 1 WSRT & BHA. Shallow test MWD-OK. 20:00 - 22:30 2.50 STWHIP P PROD1 TIH with WSRT & BHA on 4" DP to 7100'. 22:30 - 23:00 0.50 STWHIP P PROD1 Break circulation. Stage pumps to 255 gpm w/1470 psi. Orient WSRT to 14 deg LHS. PIU Wt 150k SIO Wt 95k. Slack off on drill string to 7177'. P/U & engage Whipstock. Pull & release whipstock with 200k string weight. P/U another 40k to pull seals out of bottom tie-back receptacle. Pull whipstock up to 7149'. Monitor well-static. 23:00 - 00:00 1.00 STWHIP P PROD1 Circulate bottoms up from 7149'. Flow check. Well static. Pump slug. 12/19/2003 00:00 - 03:30 3.50 STWHIP P PROD1 POOH with 4" DP to BHA. 03:30 - 06:30 3.00 STWHIP P PROD1 Stand back 4" HWDP & 4-3/4" DC. UD MWD, Whipstock retrieving tool, L 1 Whipstock & 3.5" DP space-out assembly. 100% recovery of all Whipstock & downhole tools. Clear & clean rig floor. 06:30 - 07:00 0.50 BOPSURP PROD1 MIU Ported sub on 4" DP. RIH & flush BOP stack. Pull wear bushing 07:00 - 11 :30 4.50 BOPSUR P PROD1 RIU to test BOP's with 4" DP. Set test plug. Test BOP's & all surface related equipment to 250/3500 psi. RID test equipment. All test were API. Witness of test waived by Lou Grimaldi-AOGCC. 11 :30 - 12:30 1.00 CASE P LNR1 RIU to run 4.5" Slotted liner. 12:30 - 12:45 0.25 CASE P LNR1 SAFETY- Held PJSM with rig crew & BOT personnel regarding running liner & P/U Hook Hanger assembly. 12:45 - 16:30 3.75 CASE P LNR1 MIU 4-112" Float Shoe (Bent) Jt + 82 Jts of 4-112" 12.6#, L-80, IBT-M slotted liner & BOT Flanged Hook Hanger assembly. Total length = 3471.72' P/U WI = 75k SIO Wt = 68k 16:30 - 17:00 0.50 CASE P LNR1 RID 4.5" Liner running equipment. Install DP elevators on TDS. Printed: 12/2912003 9:47:18AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/1912003 17:00 -19:00 19:00 -19:30 19:30 - 20:00 20:00 - 20:45 20:45 - 21 :30 21 :30 - 22:00 22:00 - 00:00 12120/2003 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 09:30 09:30 - 12:00 12:00 - 12:15 12:15 - 13:30 13:30 -19:30 . . Page Tof 13 BP Operations Summary Report W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours Task Code NPT Phase 2.00 CASE P LNR1 0.50 CASE P LNR1 0.50 CASE P LNR1 0.75 CASE P LNR1 0.75 CASE P LNR1 0.50 CASE P LNR1 2.00 CASE P LNR1 1.00 CASE P LNR1 1.00 CASE P LNR1 1.00 CASE P LNR1 1.00 CASE P LNR1 0.50 CASE P LNR1 5.00 CASE N 2.50 CASE P LNR1 LNR1 0.25 CASE P TIEB1 1.25 CASE P TIEB1 6.00 CASE P TIEB1 Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations TIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 7120'. P/U Wt = 124k SIO Wt = 85k M/U TDS. Establish circulation. Circulate one drill pipe volume wI 166 gpm @ 575 psi. Slack off on drill string with EOT @ 7170'. Rotate string @ 5 rpm. RIH slowly to 7173', observed torque increase. Stop rotating. Continue TIH. Tag up on lower Tie-back sleeve @ 7530'. POOH to 7120' (Attempt #1). Apply 1/4 turn RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #2). Apply 1/4 tum RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #3). Apply 1/4 tum RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #4). Apply 1/4 tum RHT in string. TIH with the 4-112" liner sucessfully entering the L 1 lateral @ 7185'. Continue TIH to 8050'. Apply 1/2 turn RHT in string. TIH. Enter L 1 ST #01 lateral @ 8200'. Continue TIH with 4-112" Slotted liner on 4" DP to 9350' (Midnight depth). Continue TIH with 4-112" Slotted liner on 4" DP in the L 1 ST #01 lateral from 9350' to 10565'. P/U Wt = 165k S/O Wt = 80k M/U TDS into 4" DP. Slack off slowly to put shoe at 10640'. Set down 20k on Hook Hanger. Verify Hook Hanger properly engaged in the window - OK. Drop 29/32" ball & pump on seat. Pressure up to 3000 psi to release HR-running tool. Continue pressuring up to 4500 psi & shear ball seat. P/U Drill string & verify HR-running tool released. Lost 25k string wt. Continue picking up on string & place HR-running tool @ 7120' (48' above Hook Hanger@ 7168'). Circulate bottoms up from 7120' w/210 gpm @ 670 psi. Flow check. Well static. Pump slug. Blow down TDS. POOH with 4" DP to 4730'. Note: A glob of hydraulic slush rained out of the derrick & hit a crew member in the back of the neck. The crew member was not injured and declined visiting the PA for examination. SAFETY- Shut down tripping operations. Perform inspections on IDS service loops & derrick. No damaged equipment observed but the TDS Hydraulic service loop had a developed a twist which could cause it to hang up in the derrick. Change out TDS hydraulic service loop. Finish POOH. UD Baker's Hook Hanger HR-Running tool. Clear rig floor of excess equipment. SAFETY- Held PJSM with Rig Crew & BOT service personnel on picking up & running the ZXP-LEM assembly. MIU and run mule shoe Jt + 7 Jts of 4-112", 12.6#, L-80 tubing (Tail pipe to tie back into OBd Liner top packer @ 7524'). M/U LEM and ZXP Packer assembly. Total length = 400.14'. RID Tubing handling equipment. P/U 46k S/O 45k TIH with 4.5" tail-pipe + LEM-ZXP packer assembly on 4" DP to 7485'. Passed through Hook Hanger@ 7168' with no Printed: 1212912003 9:47:18 AM / - ,., .. BP Operations Summary Re.port P/U 140k SIO 94k PIU 20'. Circulate bottoms up with 300 gpm @ 1600 psi. Flow check. Well static. Pump slug. Blow down TDS & surface equipment. POOH with 4" DP to 4000' (Midnight depth). Slip & cut 20' of drill line. Reset & test C-O-M. Service TDS & rig. Finish POOH. UD ZXP packer running tool. Clean rig floor. SAFETY- Held PJSM with rig crew & BOT Service Rep on picking up & running Whipstock. M/U Baker 7-5/S" (L2) Whipstock assembly. Orient MWD with whipstock. Finish MIU BHA. Shallow test MWD-OK. TIH with 7 -5/S" (L2) Whipstock assembly on 4" DP to 6S37'-whipstock depth. P/U Wt = 145k SIO Wt = 90k M/U TDS. Estabish circulation. Orient whipstock 13 deg LHS. Stab dummy seal assembly into (l1) tie-back sleeve @ 7135'. Set down 20 k to set whipstock anchor. PU 5k over to verify anchor set. Set down 40k to shear whipstock lug. Top of whipstock @ 6930'. WEXIT Circulate bottoms-up from 6930' w/ 250 gpm @ 1365 psi. Test 7-5/S" casing to 1000 psi for 10 minutes-OK. WEXIT Mill Window in 7-5/S" casing from 6930' to 6942' and drill 14' of new hole in the L2lateral to 6956'. - -- WOB = 4-7k RPM= 110 Torque = 5-7k FtLb GPM = 275 @ 1700 psi Rotate Wt = 113k WEXIT Pump a 50 bbl Hi-vis sweep. Circulate hole clean F/6956' with 275 gpm @ 1700 psi (Circ 2 x Btm-up). Work Mills through Window with pumps, then withouts pumps. Window clean & clear. WEXIT Perform FIT. Pressure up on formation to 750 psi with 9.2 ppg MOBM @ 5031' TVD = 12.07 ppg EMW. Pumped 0.9 bbl mud. Flow check. Well static. Take SPR's. Pump slug. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date Høurs Task Code NPT Phase 12/2012003 13:30 - 19:30 6.00 CASE P TIEB1 19:30 - 20:30 1.00 CASE P TIEB1 20:30 - 22:00 1.50 CASE P TIEB1 22:00 - 00:00 2.00 CASE P TIEB1 12/21/2003 00:00 - 01 :30 1.50 CASE P TIEB1 01 :30 - 02:30 1.00 CASE P TIEB1 02:30 - 02:45 0.25 STWHIP P WEXIT 02:45 - 05:30 2.75 STWHIP P WEXIT 05:30 - OS:OO 2.50 STWHIP P WEXIT OS:OO - OS:30 0.50 STWHIP P WEXIT OS:30 - 09:30 1.00 STWHIP P 09:30 - 13:00 3.50 STWHIP P 13:00 - 14:00 1.00 STWHIP P 14:00 - 14:30 0.50 STWHIP P Page 8 Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations problems. PIU Wt = 143k S/O Wt = 9Sk Slack off on work string with the 4.5" mule shoe entering the lower tie back sleeve at 7524' with no problems. Continue slacking off on string to set the LEM into the hook hanger collet @ 716S' with the 4.5" mule shoe at 7535'. Land LEM with 30k. P/U 10k to verify set, then slack off 20k & park pipe. Drop the 29132" setting ball and pump onto seat. Pressure up to 3300 psi to set ZXP packer. Continue pressuring up to blow ball seat, ball seat sheared at 4750 psi. PIU 10', verify packer set. Slack back down on packer with 50k. PIU with 15k on packer. Rotate at 15 rpm for one minute with rotating dogs engaging ZXP Tie back sleeve. Note: Top of L1 ZXP Tie-back sleeve @ 7135' Printed: 1212912003 9:47:18 AM ~ .. BP Operations Summary Report Page 9.of13. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 12/21/2003 14:30 - 18:00 3.50 STWHIP P WEXIT POOH with 4" DP to top of BHA. 18:00 - 19:30 1.50 STWHIP P WEXIT Continue POOH with BHA. UD MWD & Milling assembly. Clean & clear Rig Floor. 19:30 - 20:00 0.50 STWHIP P WEXIT M/U ported sub. Flush out SOP's. UD sub. 20:00 - 20:15 0.25 DRILL P WEXIT SAFETY- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. 20:15 - 21 :30 1.25 DRILL P WEXIT M/U 6-3/4" Steerable Drilling assembly. Test MWD-OK. 21 :30 - 00:00 2.50 DRILL P WEXIT TIH with 6-3/4" Steerable Drilling assembly on 4" DP to 4300'. 12/22/2003 00:00 - 01:00 1.00 DRILL P WEXIT Finish TIH with 6-3/4" Steerable Drilling asembly on 4" DP F/ 4300' to 6890'. 01 :00 - 02:00 1.00 DRILL P WEXIT MIU TDS. Establish circulation. Circulate bottoms-up w/190-250 gpm @ 1300-1975 psi. PIU = 133k S/O = 95k. Take SPR's & take ECD benchmark reading. Had 10.36 ppg ECD @ 250 GPM + 60 RPM. 02:00 - 02:30 0.50 DRILL P WEXIT Stop pumps. Slack-off passing through 7-5/8" window (6930'-6942') with no problems. Tag up @ 6950'. Stage pumps to 250 gpm. Wash & ream down through undergauge hole F/ 6950' to 6956'. 02:30 - 00:00 21.50 DRILL P PROD2 Drill 6-3/4" directional hole in the L2 lateral from 6956' to 8786'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 6k FtLb, Torque on Btm = 10k FtLb GPM = 275 @ 2800 psi on Btm wI 100-120 psi Diff Pressure. P/U 146k S/O 82k ROT 109k Backream every stand at 250 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8786' = 10.50 ppg, Actual ECD = 10.85 ppg Landed wellbore into Oba sand @ 6967' MD/5044' KBTVD. ART = 2.46 Hrs AST = 8.09 Hrs Survey/Connection = 10.95 Hrs Drilling Time last 24 Hrs= 10.55 hrs 12/2312003 00:00 - 20:30 20.50 DRILL P PROD2 Drill 6-3/4" directional hole in the L2 lateral from 8786' to TO at 10670'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 10-15k RPM = 60 Torque off Stm = 9.5k FtLb, Torque on Stm = 10-11k FtLb GPM = 275 @ 3000 psi on Btm w/1oo-120 psi Diff Pressure. P/U 146k SIO 78k ROT 109k Backream every stand at 250 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 10670' = 10.53 ppg, Actual ECD = 10.97 ppg Printed: 1212912003 9:47:18 AM ...,. - " - SF> Operations Summary Report 10 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/23/2003 00:00 - 20:30 20.50 DRILL P PROD2 ART = 7.01 Hrs. AST = 3.34 Hrs. Drilling Time last 24 Hrs= 10.35 hrs 20:30 - 22:30 2.00 DRILL P PROD2 Circulate & condition mud/hole (2.5 x Btm-up vol) from 10670' with 300 gpm @ 3200 psi. Reciprocate & rotate drill string (80 RPM) while circulating. Calculated ECD @ 10670' = 10.68, Actual ECD = 10.90 prior to trip 22:30 - 00:00 1.50 DRILL P PROD2 Monitor well - static. POH for wiper trip to window. Pull 5 stands, slug DP and continue POH. Pulled 5-10k over string weight off bottom. P/U 160k S/O 88k No Pumps 12/24/2003 00:00 - 01 :00 1.00 DRILL P PROD2 Continue short trip. intermittent drag of 5-15k throughout trip. Pulled 25k over at 7965',7923',7645', wipe through without any problems. P/U 163k S/O 84k 01 :00 - 01 :30 0.50 DRILL P PROD2 Monitor well - static. Pump out from 7075' to 6982'. 275 gpm @ 2388 psi. 01 :30 - 02:30 1.00 DRILL P PROD2 RIH to 10580'. No problems on trip in. 02:30 - 04:30 2.00 DRILL P PROD2 Wash last stand to TD at 10670'. Circulate & condition mudlhole (2 x Btm-up vol) from 10670' with 275 gpm @ 2940 psi. Reciprocate & rotate drill string (80 RPM) while circulating. Calculated ECD @ 10670' = 10.68, Actual ECD = 10.90 prior to POH 04:30 - 07:00 2.50 DRILL P PROD2 Monitor well- static. POH to 7167'. Orient to 13 degrees left. Continue POH to 6889, bringing BHA and bit inside casing. RIH placing circ sub at the base of the whipstock. 07:00 - 08:00 1.00 DRILL P PROD2 Drop ball and rod and pump onto seat, circ sub sheared at 2100 psi. Circulate across whipstock face to clean retrieval slot. 500 gpm at 3000 psi. Stand back 3 stands bringing bit inside of casing at 6889'. Pump hi-vis sweep, 500 gpm at 3000 psi while reciprocating DP at 60 rpm. 08:00 - 11 :30 3.50 DRILL P PROD2 Continue POH P/U 145k S/O 93k 11 :30 - 12:00 0.50 DRILL P PROD2 PJSM with Anadril and all rig personnel on unloading RA source and laying down BHA. 12:00 - 13:00 1.00 DRILL P PROD2 LD BHA #7 13:00 - 13:30 0.50 DRILL P PROD2 Clean and clear rig floor 13:30 - 14:00 0.50 STWHIP P PROD2 PJSM with Baker, Anadril and all rig personnel on making up whipstock retrieval BHA. 14:00 - 15:00 1.00 STWHIP P PROD2 MU whipstock retrieving tool and BHA, orient. RIH with collars and HDP from derrick. Shallow test MWD. 15:00 -17:00 2.00 STWHIP P PROD2 RIH with DP to 6900' 17:00 - 17:30 0.50 STWHIP P PROD2 Fill DP. Orient retrieving tool 13 degrees left. 135 klbs up, 95 klbs down. Slack off while circulatingto top of whipstock at 6930', continue down putting retrieval tool below whipstock face. PU and engage retrieval slot, jar 4 times to release Printed: 12/2912003 9:47:18 AM ,... - "- -' Page 110f 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 12/24/2003 17:00 - 17:30 0.50 STWHIP P PROD2 17:30 - 18:30 1.00 STWHIP P PROD2 18:30 - 22:00 3.50 STWHIP P PROD2 22:00 - 00:00 2.00 STWHIP P PROD2 12/2512003 00:00 - 00:30 0.50 STWHIP P PROD2 00:30 - 01:00 0.50 CASE P LNR2 01:00 - 01 :30 0.50 CASE P LNR2 01 :30 - 05:00 3.50 CASE P LNR2 05:00 - 05:30 05:30 - 08:00 0.50 CASE P 2.50 CASE P LNR2 LNR2 08:00 - 08:15 0.25 CASE P LNR2 08:15 - 08:30 0.25 CASE P LNR2 08:30 - 08:45 0.25 CASE P LNR2 08:45 - 09:00 0.25 CASE P LNR2 09:00 - 13:15 4.25 CASE P LNR2 13:15 - 13:45 0.50 CASE P LNR2 13:45 - 14:15 0.50 CASE P LNR2 14:15 -15:00 0.75 CASE P LNR2 15:00 - 16:00 1.00 CASE P LNR2 16:00 - 19:30 3.50 CASE P LNR2 19:30 - 20:30 1.00 CASE P TIEB2 20:30 - 21:00 0.50 CASE P TIEB2 21:00 - 22:00 1.00 CASE P TIEB2 22:00 - 00:00 2.00 CASE P TIEB2 12/2612003 00:00 - 02:00 2.00 CASE P TIEB2 02:00 - 02:15 0.25 CASE P TIEB2 Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 12/10/2003 12/28/2003 Description of Operations whipstock anchor. PU pulling seal assembly out of tie back sleeve. PU 30', 7k increase in PU weight. Monitor well- static. CBU, 300 gpm at 1900 psi. Monitor well - static. Slug DP and POH with whipstock P/U 150k LD retrieving BHA and whipstock assembly. Clean and clear rig floor. RIU to run 4.5" slotted liner. PJSM with rig crew & BOT personnel regarding running liner & PU Hook Hanger assembly. MIU 4-112" Float Shoe (Bent) Jt + 87 Jts of 4-112" 12.6#, L-80, IBT-M slotted liner & BOT Flanged Hook Hanger ass'y. Total length = 3708.83' P/U Wt = 75k SIO Wt = 62k RID 4.5" Liner running equipment. Install DP elevators on TDS. RIH with 4-1/2"12.6# Slotted liner assembly on 4" DP to 6936'. Circ DP vol with liner shoe at window. Rotate 5 RPM @ window looking for torque increase - saw slight increase as if window hooked with bent shoe jt. RIH but tag up on liner top of L 1 at 7135'. Attempt #1. POH above window and put 1/4 turn in pipe. Work turn down. RIH looking for window. Tag up on L 1 liner top again. Attempt #2. POH above window and put next 1/4 turn in pipe. Work turn down. RIH looking for window. Exit window successfully into L2. Attempt #3. Continue RIH with liner on DP into open hole. 160 klbs up. 85 klbs down. Engage hook hanger on bottom of window on first attempt. PU 20' above and rotate string 1/2 turn. Run in and run hook 10' below btm of window - OK. Pull up, re-orient hook hanger and re-engage bottom of window on second try - OK. Shoe at 10631'. Top of hook hanger at 6925'. Drop 29/32" ball in DP and circ down on seat at 4 then 2 bpm with 1020 stks. Pressure up to 3200 psi to release from hook hanger - OK. PU Wt = 135 klbs. Pressure up to 4500 psi with mud pump then BOP test pump and shear out ball seat - OK. PU 30' and CBU, 300 gpm at 1300 psi. Monitor well - static. Cut and slip 26' of drill line. Inspect brakes and drawworks. Monitor well - static. slug DP and POH with liner running tool. PIU Wt = 138k SIO Wt = 100k RU liner running equipment. PJSM with BOT and all rig personnel on MU and running ZXP Packer and LEM assembly. MU and run ZXP Packer and LEM assembly Continue RIH with ZXP Packer/LEM assembly on DP. MU top drive to each stand to prevent MOBM from running over. Continue RIH with ZXP Packer/LEM assembly Reduce running speed and pass mule shoe through hook hanger assembly. Establish string weights; 138 klbs up, 95 klbs Printed: 1212912003 9:47:18 AM ,., . BP Operations Summary Report Page 12 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date From"To Task Code NPT Phase Description of Operations 12/26/2003 02:00 - 02:15 0.25 CASE P TIEB2 down. Continue RIH with mule shoe in tie-back sleeve and engaging LEM in hook hanger. PU 10k over string weight verifying LEM is engaged. 02:15 - 03:00 0.75 CASE P TIEB2 Drop ball and pump onto seat at 4 bpm, 839 psi. Pressure up to 3000 with rig pump. RU test pump and continue pressuring up to 3300 psi to set packer. Continue pressuring up to 4500 psi to blow ball seat. 03:00 - 04:30 1.50 CASE N RREP TIEB2 Rotary hose failed at 4500 psi. The job was stopped a safety assessment was conducted. The rotary hose was rigged down. A head pin with TIW valve was rigged up on the DP. 04:30 - 05:00 0.50 CASE P TIEB2 Continue pressure up with the test pump to 5000 psi to blow out ball seat. 05:00 - 05:30 0.50 CASE P TIEB2 Reciprocate 20' while circulating and conditioning mud for displacement. 05:30 - 07:30 2.00 CASE P TIEB2 Displace well to 9.3 ppg brine. Pumped the following sweeps: 20 bbls LVT-200 base oil 20 bbls viscosified 9.3 ppg brine 50 bbls 9.3 ppg brine with 4 drums Safe Surf 0 25 bbls viscosified 9.3 ppg brine Follow the sweeps with 279 bbls 9.3 ppg brine until clean returns. 430 gpm, 2020 psi. 07:30 - 08:00 0.50 CASE P TIEB2 Blow down and RD circulating lines. 08:00 - 09:30 1.50 CASE P TIEB2 Load MOBM on trucks. Clean MOBM from rotary table, sumps, shakers and trough. 09:30 - 17:30 8.00 CASE P TIEB2 POH laying down DP 17:30 - 20:30 3.00 CASE P TIEB2 RIH with 4-3/4" DC's and 40 stands of DP from derrick 20:30 - 22:00 1.50 CASE P TIEB2 CBU to flush MOBM from DP. 420 gpm, 1265 psi. 22:00 - 00:00 2.00 CASE P TIEB2 Monitor well - static, Slug DP and POH laying down. 12/27/2003 00:00 - 03:00 3.00 CASE P TIEB2 Continue POH laying down DP 03:00 - 04:00 1.00 CASE P TIEB2 Clean and clear rig floor of MOBM. 04:00 - 04:30 0.50 RUNCOJI./N RREP COMP PJSM with rig personnel on installing new rotary hose. 04:30 - 12:30 8.00 RUNCOJI./N RREP COMP Bring new rotary hose to the floor and install. 12:30 - 13:00 0.50 BOPSUR P COMP Pull wear bushing. Make dummy run with landing joint. 13:00 -15:00 2.00 RUNCOfvP COMP Change out bails and elevators. RU I-wire spooling unit and completion equipment. 15:00 - 15:30 0.50 RUNCOfvP COMP PJSM with Centrilift, Camco, Tubel, BOT and all rig personnel on running completion with Phoenix and Tubel gauges, I-wire and clamps. 15:30 - 00:00 8.50 RUNCOfvP COMP Run 4-1/2", 12.6#, L-80 completion and all associated jewelry per running order. 12/2812003 00:00 - 01 :00 1.00 RUNCOfvP COMP Continue Run 4-112", 12.6#, L-80, IBT-M completion. Ran 159 jts plus jewelry, PU spaceout joints. 01 :00 - 02:30 1.50 RUNCOfvP COMP Space out tbg string. MU spacer pup. Install 1 foot of blast rings on pup jt below tubing hanger body and lock in place with stop ring. LD spaceout jts. MU hanger and landing joint. 02:30 - 05:00 2.50 RUNCOfvP COMP MU I-wire to tbg hanger. Install and test Tubel receiver. Test all swagelok fittings to 5000 psi. Land tbg. RILDS. Muleshoe on tailpipe landed at 6901' (9' inside L TP). 05:00 - 06:30 1.50 RUNCOfvP COMP Reverse circulate in 4 bbls corrosion inhibited brine followed by 180 bbls clean brine to place the corrosion inhibited brine Printed: 1212912003 9:47:18 AM .... .. Page 13 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES NPT Phase 12/2812003 05:00 - 06:30 06:30 - 08:30 1.50 RUNCOrvP 2.00 RUNCOrvP COMP COMP 08:30 - 09:30 1.00 RUNCOrvP COMP 09:30 -10:00 0.50 RUNCOrvP COMP 10:00 - 11:00 1.00 BOPSUR.P COMP 11:00-13:30 2.50 WHSUR P COMP 13:30 - 14:30 1.00 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 -15:30 0.50 WHSUR P COMP 15:30 - 16:00 0.50 WHSUR P COMP 16:00 - 17:00 1.00 WHSUR P COMP 17:00 - 18:00 1.00 WHSUR P COMP 18:00 - 19:30 1.50 WHSUR P COMP 19:30 - 20:30 1.00 WHSUR P COMP 20:30 - 21 :00 0.50 WHSUR P COMP Start: 12/10/2003 Rig Release: 12/28/2003 Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations between the bottom GLM and the top of the packer. Drop ball & rod. Pressure up to 4200 psi to set packer. Bleed pressure to 3500 psi and hold for 30 minutes for tbg test. Bleed tbg pressure to 2000 psi and pressure up annulus to 3500 psi, hold for 30 minute for annular and packer test. Bleed both tbg and annulus pressure to 0 psi. Pressure up annulus, DCK valve sheared at 2600 psi. Establish circulation; 2bpm. 600 psi. RD circulating equipment. Break out landing joint. Install TWC. pressure test to 1000 psi. RD casing equipment, CO bails, blow down lines. ND BOPE NU tree and adapter flange Pressure test ports in tbg hanger used for I-Wire and Tubel gauge to 5000 psi RU DSM and pull TWC through lubricator. RU Little Red to freeze protect PJSM with Little red and all rig personnel on pumping diesel. Pump 110 bbl diesel down the annulus to freeze protect well at 2bpm. ICP = 400 psi FCP = 875 psi Allow diesel to U-tube. Final tbg and inner annulus pressure = 225 psi RU DSM and install BPV through lubricator, Test BPV to 1000 psi with Little Red. Install VR plugs in tbg spool outlets. Secure well. Install gauges. RELEASE RIG @ 21 :00 Printed: 12/2912003 9:47:18 AM TREE = FMC4-1/6" SM WB.U-EAD = FMC GEN S ACTUATOR = KB. ELEV = BF. B.EV = KOP= Max Angle = Datum MD = Datum TVD = . 80.90' S4.50' 300' 91 @ 8481' 5713' 4500' SS 120# OONIJJCTOR H 10-3/4"CSG.40#, L-BO, 10 =9.95" H 3985' Minimum ID == 2.750" @ 7627' 4-1fl" HES XN NIPPLE W-205 From DRLG W-205 L 1 W-20 5 L2 ~NOTES: \08 . a!" ~ L 14.S"PHOENX œOiRGE-ffiESS SUB,ID = 3.8S" H ~ ~ I I 14.8'A-NXML~D=3.æ3' H gtff IZ T"œl...""m Go"",. D' 'j:: TA~ HI =- ¥t 17-S/8" x S.5' BKR ZXP PACKffi, 10 = S.5' Ii 6892' IBKR I-UGHES HOOKWALL HGR, 10 = S.64" H 6925' ~ IRA TAGH 7119' 17-S/8" x S.5" BKR ZXPPACKER, ID = S.5' H 7135' IBKR I-UGHES HOOKWALL HGR, 10= S.64" H IRA TAG ~ 7491 ÆRFORA TON SUM\1ARY REF LOG: ANGLE AT TOP PERF: 67 @ 7201' Note: Refer to Production DB for historical perf data SIZE SA" 1NTERv' AL OpnlSqz DATE 4-1/2" SLTD OBA 7003- ~ l09ð7 12/28/03 4-1/2" SLTD OBC 7246 - ~ 10S9'1 12/2<Y03 4-1/2" SLTD OBD 7700 - ~ \fA,Jfi'1 09/07/03 r~ 17 S/8" CSG. 26#, L-80, ID = 6.276" H 7618' ~ ~ 10520' I "1" ~ ~~ \0<..'70 DATE 09/09/03 09/13/03 09/29/03 10112/03 12/28103 REV BY OOMf\léNTS JDM'KK ORIGINAL OOM>LEllON RWUKK GL V C/O .LJITLH Mn 10& Nipple Correction KCFffiP FBTD Correction JI\C ADD L 1 & L2 DUE RBI BY ~ "-5 S'l , ~ H4-1/2" HESX NP, D =3.813" 1 GAS LIFT Mð,f'ÐRELS DBI TYPE VL V LATCH PORT 45 KBG-2 ~ BK-S 0 57 KBG-2 ~Y BK-S 0 60 KBG-2 DCK2 BS< DATE 12/28/03 12/28/03 12/28/03 IL ST MJ I TVD 3 SOu. 2503 2 ,'tCf" 4831 1 ~q) 4888 eø7?!1- &?tr' H4-1/2"BKRCMJSLEEVE,ID=3.813" I ~ ~ H7.62S"X4.S"BKRPRMA<R,ID=3.87S" 'fJC'1 I -i85C7' H4-1/2"I-ESXNP,D=3.813"1 ~ 68* H4-1/Z' HESX NP,ID=3.813" I .Jç>~ ~ H4-112" MAle Shoe I :t¡ - - - - - - - ~ - - - - - - - --, I 7" WNrx:JN @ 6930' -' _ sboL..ctt Jº~3J ,.1J>- ctt.lOJ!?Þ I 7003' -1 0631' 6-314" OBA LATERAL , Ð = 3.958" I 7143' "'H4-1/Z' MAle Shoe I ·~S~~~ _~~ ~C?~~. _ _ ::t:JO ~I ,0000 1 L\ 7"WNXJN@7173' ....... I ----------------- 7246' -10640' 6-314" OBC LATERAL, Ð = 3.958" x 7700' -1 0667' 6-314" OBD LATERAL, Ð = 3.958" OOWMENTS ORION LNIT WELL: W-20S, W-20S L 1, W-20S L2 PERMrr N:>: 203116 (203) (201) AA N:>: SO-029-23165-00 (60) (61) SEC21, T11N, R12E. 3703' foSL & 1196' WB. I 7525' H7.625" X S.5' BKRZXPLI>R TOPPKR, 10 = 4.810" L 7535' ......H4-1/2.. Mule Shoe I ~ 7531' H5-1/2" X4-1/2"XO,ID= 3.9S8" 1 I 7627' H4-1/Z' HESXNNIP, ID= 2.7SO" I I I 7610' CTM H 2.S"IBP I I I I I I I ~ U BP exploration (Alaska) . . W-205L2 Survey Report S umberger Report Date: 24-Dec-Q4 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 1.560' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: W-PAD I W-205 TVD Reference Datum: Rotary Table Well: W·205 TVD Reference Elevation: 80.90 ft relative to MSL Borehole: W-205L2 Sea Bed I Ground Level Elevation: 52.40 ft relative to MSL UWVAPI#: 500292316561 Magnetic Declination: 25.221' Survey Name I Date: W-205L2/ December 24, 2003 Total Field Strength: 57559.764 nT Tort f AHD I DOli ERD ratio: 327.857" /8140.20 ft 16.747 / 1.595 Magnetic Dip: 80.809' Grid Coordinate System: NAD27 Alaska State Planes. Zone 04, US Feet Declination Date: December 25. 2003 Location LatILong: N 70 17 45.811. W 149 5 33.633 Magnetic Declination Model: BGGM 2003 Location Grid NÆ Y/X: N 5958680.130 ftUS, E 612048.970 ftUS ,¡ North Reference: True North / Grid Convergence Angle: +0.85420613' Total Carr Ma9 North -> True North: +25.221' Grid Scale Factor: 0.99991426 local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Alon9 Hole I NS EW I DLS I Build Rate I Walk Rate I Northin9 Easting Latitude Lon9itude Depth Section Departure (ft) ( de9) ( deg) (ft) (ft) (ft) (It) (ft) (It) (deg/loolt) (deg/1ooft) (deg/looft) (ltUS) (ftUS) 0.00 0.00 0.00 0.00 ·80.90 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5958680.13 612048.97 N 70 1745.811 W 149533.633 138.20 0.07 88.07 138.20 57.30 0.01 0.08 0.00 0.08 0.05 0.05 0.00 5958680.13 612049.05 N 70 1745.811 W 149533.630 239.52 0.61 54.75 239.52 158.62 0.33 0.68 0.32 0.59 0.55 0.53 -32.89 5958680.45 612049.55 N 70 1745.814 W 149533.616 300.39 2.25 63.08 300.37 219.47 1.10 2.20 1.04 1.92 2.71 2.69 13.68 5958681 .20 612050.87 N 70 1745.821 W 149 5 33.577 390.94 5.17 82.77 390.72 309.82 2.57 8.00 2.36 7.55 3.47 3.22 21.74 5958682.60 612056.48 N 70 17 45.834 W 149533.413 ------------ 483.11 6.93 92.96 482.38 401.48 3.07 17.69 2.60 17.22 2.23 1.91 11.06 5958682.98 612066.15 N 70 17 45.837 W 149533.131 576.06 8.31 96.29 574.50 493.60 2.38 30.01 1.57 29.50 1.56 1.48 3.58 5958682.14 612078.44 N 70 17 45.827 W 149 532.773 671.50 10.95 97.11 668.59 587.69 0.93 45.98 -0.31 45.35 2.77 2.77 0.86 5958680.50 612094.32 N 70 17 45.808 W 149532.311 765.37 13.56 93.83 760.31 679.41 -0.37 65.90 -2.14 65.19 2.88 2.78 -3.49 5958678.96 612114.17 N 70 1745.790 W 149 5 31.733 859.95 15.67 90.40 851.83 770.93 -0.55 89.75 -2.97 89.02 2.41 2.23 -3.63 5958678.48 612138.02 N 701745.782 W 149531.038 954.66 18.74 90.44 942.29 861.39 0.01 117.76 -3.18 117.03 3.24 3.24 0.04 5958678.70 612166.03 N 70 1745.780 W 149530.222 1050.16 23.91 88.55 1031.22 950.32 1.32 152.48 ·2.81 151.75 5.46 5.41 -1.98 5958679.58 612200.73 N 70 1745.783 W 149529.210 1144.14 27.46 91.14 1115.91 1035.01 2.48 193.20 -2.76 192.46 3.96 3.78 2.76 5958680.24 612241.44 N 70 1745.784 W 149 5 28.023 1238.39 29.92 90.46 1198.58 1117.68 3.09 238.44 -3.38 237.70 2.63 2.61 -0.72 5958680.30 612286.67 N 70 1745.778 W 149526.704 1333.55 33.56 88.26 1279.50 1198.60 5.06 288.49 ·2.77 287.74 4.01 3.83 -2.31 5958681.65 612336.70 N 70 1745.784 W 149525.246 1427.00 38.84 92.23 1354.89 1273.99 6.21 343.65 -3.13 342.89 6.18 5.65 4.25 5958682.12 612391.84 N 70 1745.780 W 149523.639 1521.98 43.73 92.85 1426.24 1345.34 5.12 406.30 -5.92 405.47 5.17 5.15 0.65 5958680.26 612454.45 N 70 1745.753 W 149521.814 1616.01 45.76 92.04 1493.02 1412.12 4.11 472.49 -8.73 471.60 2.24 2.16 -0.86 5958678.43 612520.61 N 70 1745.725 W 149519.887 1709.89 45.49 93.10 1558.68 1477.78 2.93 539.59 -11.74 538.64 0.86 -0.29 1.13 5958676.42 612587.67 N 70 1745.695 W 149517.933 1803.35 44.15 92.96 1624.97 1544.07 1.24 605.47 -15.22 604.42 1.44 -1.43 -0.15 5958673.92 612653.50 N 70 1745.661 W 149516.016 1898.67 42.83 93.34 1694.12 1613.22 -0.58 671.07 -18.83 669.92 1.41 -1.38 0.40 5958671.29 612719.04 N 70 17 45.626 W 149514.106 1992.58 42.02 93.80 1763.44 1682.54 -2.80 734.42 -22.77 733.15 0.92 -0.86 0.49 5958668.29 612782.32 N 70 17 45.587 W 149512.263 2087.21 41.64 93.69 1833.96 1753.06 -5.21 797.53 -26.89 796.13 0.41 -0.40 -0.12 5958665.11 612845.34 N 70 17 45.546 W 149510.428 2182.02 42.33 93.42 1904.43 1823.53 -7.42 860.95 -30.82 859.43 0.75 0.73 -0.28 5958662.12 612908.69 N 70 17 45.507 W 14958.583 2276.41 41.86 93.01 1974.47 1893.57 -9.24 924.23 -34.37 922.60 0.58 -0.50 -0.43 5958659.52 612971.90 N 70 1745.472 W 14956.741 2371.24 43.94 92.92 2043.93 1963.03 -10.83 988.78 -37.71 987.07 2.19 2.19 -0.09 5958657.14 613036.40 N 70 1745.440 W 149 5 4.863 2465.72 44.80 90.69 2111.47 2030.57 -11.10 1054.84 -39.78 1053.09 1.88 0.91 -2.36 5958656.05 613102.45 N 70 1745.419 W 14952.938 2560.07 44.84 89.82 2178.40 2097.50 -9.58 1121.34 -40.08 1119.60 0.65 0.04 -0.92 5958656.75 613168.94 N 701745.416 W 14951.000 2654.53 44.98 90.34 2245.30 2164.40 -7.86 1188.03 -40.17 1186.28 0.42 0.15 0.55 5958657.65 613235.62 N 70 1745.415 W 149459.056 2750.20 44.95 90.82 2312.99 2232.09 -6.71 1255.64 -40.86 1253.89 0.36 -0.03 0.50 5958657.97 613303.22 N 70 1745.408 W 149457.085 2845.05 44.48 90.47 2380.39 2299.49 -5.64 1322.37 -41.61 1320.62 0.56 -0.50 -0.37 5958658.22 613369.95 N 70 1745.401 W 149455.140 2940.21 44.54 87.54 2448.26 2367.36 -2.67 1389.08 -40.45 1387.30 2.16 0.06 -3.08 5958660.37 613436.60 N 70 1745.412 W149453.197 3034.42 44.39 87.64 2515.49 2434.59 1.90 1455.07 -37.67 1453.24 0.18 -0.16 0.11 5958664.13 613502.48 N 701745.439 W149451.275 3129.22 44.11 87.91 2583.40 2502.50 6.27 1521.22 -35.11 1519.34 0.36 -0.30 0.28 5958667.68 613568.53 N 701745.464 W 149449.348 3221.57 44.52 88.27 2649.48 2568.58 10.17 1585.74 -32.96 1583.82 0.52 0.44 0.39 5958670.79 613632.96 N 70 1745.485 W 149447.469 3315.03 44.46 88.48 2716.15 2635.25 13.81 1651.23 -31.10 1649.29 0.17 -0.06 0.22 5958673.62 613698.39 N 70 17 45.503 W 149445.561 3409.53 44.42 88.46 2783.62 2702.72 17.38 1717.40 -29.33 1715.43 0.04 -0.04 -0.02 5958676.38 613764.49 N 70 1745.521 W 149443.633 3504.53 44.80 88.89 2851.25 2770.35 20.74 1784.11 -27.79 1782.13 0.51 0.40 0.45 5958678.91 613831.16 N 70 17 45.536 W 149441.689 3598.91 45.06 89.18 2918.07 2837.17 23.67 1850.77 -26.67 1848.77 0.35 0.28 0.31 5958681.03 613897.77 N 70 1745.547 W 149439.746 3694.74 46.75 88.01 2984.75 2903.85 27.24 1919.59 -24.97 1917.57 1.97 1.76 -1.22 5958683.75 613966.53 N 70 1745.563 W 149437.741 3788.33 46.72 88.Q7 3048.90 2968.00 31.43 1987.74 -22.64 1985.68 0.06 -0.03 0.06 5958687.10 614034.59 N 701745.586 W 149 4 35.756 3882.04 48.58 88.49 3112.02 3031.12 35.39 2056.99 -20.56 2054.90 2.01 1.98 0.45 5958690.20 614103.77 N 70 1745.606 W 149433.738 3935.59 49.24 88.61 3147.22 3066.32 37.50 2097.35 -19.54 2095.25 1.24 1.23 0.22 5958691.82 614144.09 N 70 1745.616 W 149432.562 4029.51 47.87 88.73 3209.38 3128.48 41.05 2167.75 -17.91 2165.63 1.46 -1.46 0.13 5958694.51 614214.44 N 701745.632 W 149430.511 4125.83 47.53 88.86 3274.21 3193.31 44.49 2238.99 -16.41 2236.86 0.37 -0.35 0.13 5958697.07 614285.63 N 70 17 45.646 W 149 4 28.435 4219.70 47.06 88.57 3337.87 3256.97 47.91 2307.97 -14.86 2305.82 0.55 -0.50 -0.31 5958699.64 614354.55 N 70 1745.661 W 149 4 26.424 4313.18 47.50 90.07 3401.29 3320.39 50.60 2376.65 -14.05 2374.49 1.27 0.47 1.60 5958701.48 614423.19 N 70 17 45.669 W 149424.423 4408.39 49.25 90.60 3464.53 3383.63 52.11 2447.82 -14.47 2445.65 1.88 1.84 0.56 5958702.12 614494.35 N 70 17 45.665 W 149422.349 4502.06 49.19 90.52 3525.71 3444.81 53.35 2518.74 -15.17 2516.58 0.09 -0.06 -0.09 5958702.48 614565.27 N 70 17 45.658 W 149420.281 4596.92 48.95 90.38 3587.86 3506.96 54.74 2590.41 -15.73 2588.24 0.28 -0.25 -0.15 5958702.99 614636.93 N 70 17 45.652 W 149418.193 SurveyEditor Ver 3.1 RT -SP3.03-H F2.03 Bld( d031 rt-546 ) W-205\W-205\W-205L2\W-205L2 Generated 1/23/2004 1 :23 PM Page 1 of 4 . . r Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Lat~ude longitude Depth Sect ion Departure (ft) ( OOg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (degl1ooft) (deg/1ooft) (deg/1OOft) (ftUS) (nUS) 4692.21 48.79 90.24 3650.54 3569.64 56.30 2662.19 -16.12 2660.02 0.20 -0.17 -0.15 5958703.67 614708.70 N 70 17 45.648 W 149416.101 4786.94 48.40 89.75 3713.19 3632.29 58.24 2733.24 -16.11 2731.07 0.57 -0.41 -0.52 5958704.73 614779.74 N 70 17 45.648 W 149414.030 4881.27 47.90 89.49 3776.13 3695.23 60.62 2803.50 -15.65 2801.33 0.57 -0.53 -0.28 5958706.25 614849.98 N 70 17 45.652 W 149411.982 4976.33 47.54 89.45 3840.08 3759.18 63.19 2873.84 -15.00 2871.66 0.38 -0.38 -0.04 5958707.94 614920.28 N 70 17 45.658 W 14949.932 5070.70 47.15 89.05 3904.02 3823.12 65.98 2943.24 -14.09 2941.06 0.52 -0.41 -0.42 5958709.89 614989.66 N 70 17 45.667 W 14947.909 5164.92 46.92 88.98 3968.24 3887.34 69.05 3012.19 -12.90 3010.00 0.25 -0.24 -0.07 5958712.10 615058.56 N 70 17 45.678 W 14945.900 5260.11 47.44 91.19 4032.94 3952.04 70.84 3082.00 -13.01 3079.81 1.79 0.55 2.32 5958713.03 615128.36 N 70 17 45.677 W 14943.865 5353.62 47.09 90.56 4096.40 4015.50 71.66 3150.69 -14.06 3148.48 0.62 -0.37 -0.67 5958713.00 615197.04 N 70 17 45.666 W 14941.863 5448.04 46.84 90.99 4160.84 4079.94 72.60 3219.70 -15.00 3217.49 0.43 -0.26 0.46 5958713.10 615266.05 N 70 17 45.657 W 149359.852 5542.45 47.35 93.52 4225.11 4144.21 71.76 3288.85 -17.72 3286.58 2.04 0.54 2.68 5958711.40 615335.16 N 70 17 45.630 W 149357.838 5637.51 48.32 97.51 4288.94 4208.04 66.88 3359.30 -24.51 3356.69 3.27 1.02 4.20 5958705.66 615405.35 N 70 17 45.563 W 149355.795 5730.86 48.49 102.79 4350.93 4270.03 56.46 3429.09 -36.81 3425.36 4.23 0.18 5.66 5958694.39 615474.20 N 70 1745.441 W 149353.793 5827.15 48.36 104.32 4414.83 4333.93 41.49 3501.12 -53.69 3495.38 1.20 -0.14 1.59 5958678.56 615544.46 N 70 17 45.275 W 149351.752 5922.20 47.21 99.09 4478.72 4397.82 29.07 3571.49 -67.99 3564.26 4.25 -1.21 -5.50 5958665.29 615613.54 N 70 17 45.134 W 149349.745 6018.20 47.43 95.71 4543.81 4462.91 21.89 3642.06 -77.07 3634.23 2.60 0.23 -3.52 5958657.25 615683.63 N 70 1745.044 W 149347.706 6113.56 49.51 92.20 4607.04 4526.14 18.95 3713.43 -81.96 3705.42 3.51 2.18 -3.68 5958653.42 615754.88 N 70 17 44.996 W 149345.631 6207.77 51.06 88.79 4667.25 4586.35 20.32 3785.89 -82.56 3777.87 3.23 1.65 -3.62 5958653.90 615827.32 N 70 17 44.990 W 149343.519 6301.13 54.14 83.06 4723.98 4643.08 27.67 3860.02 -77.22 3851.78 5.89 3.30 -6.14 5958660.34 615901.14 N 70 17 45.042 W 149341.365 6393.40 55.11 76.89 4777.43 4696.53 42.79 3935.23 -64.11 3925.80 5.55 1.05 -6.69 5958674.55 615974.95 N 70 1745.170 W 149339.207 6486.61 56.60 71.66 4829.77 4748.87 65.73 4012.36 -43.19 4000.01 4.91 1.60 -5.61 5958696.58 616048.82 N 70 17 45.376 W 149337.044 6582.21 60.06 67.40 4879.97 4799.07 96.28 4093.70 -14.69 4076.17 5.24 3.62 -4.46 5958726.20 616124.55 N 70 17 45.656 W 149334.824 6676.53 63.26 62.27 4924.76 4843.86 133.64 4176.69 20.64 4151.24 5.87 3.39 -5.44 5958762.64 616199.08 N 70 17 46.003 W 149332.635 6771.35 64.85 57.71 4966.26 4885.36 178.28 4261.94 63.28 4225.03 4.64 1.68 -4.81 5958806.38 616272.22 N 70 1746.422 W 149330.483 6865.05 65.91 55.97 5005.30 4924.40 226.80 4347.12 109.88 4296.33 2.03 1.13 -1.86 5958854.03 616342.81 N 70 17 46.880 W 149328.404 6865.05 65.91 55.97 5005.30 4924.40 226.80 4347.12 1 09.88 4296.33 0.00 0.00 0.00 5958854.03 616342.81 N 70 1746.880 W 149328.404 .¡ 6930.00 67.45 54.05 5031.01 ,- 4950.11 262.32 4406.76 144.08 4345.19 3.60 2.37 -2.96 5958888.96 616391.15 N 70 1747.216 W 149326.980 6942.00 69.32 53.58 5035.43 4954.53 269.15 4417.92 150.67 4354.19 16.00 15.58 -3.92 5958895.68 616400.05 N 70 1747.280 W 149326.717 6962.61 71.26 53.58 5042.38 4961.48 281.09 4437.32 162.19 4369.80 9.41 9.41 0.00 5958907.42 616415.49 N 70 1747.394 W 149326.262 6994.21 73.52 53.59 5051.94 4971.04 299.62 4467.44 180.07 4394.04 7.15 7.15 0.03 5958925.66 616439.45 N 70 1747.569 W 149325.555 7024.74 77.87 53.59 5059.49 4978.59 317.82 4497.01 197.62 4417.84 14.25 14.25 0.00 5958943.57 616462.99 N 70 1747.742 W 149324.861 7056.34 82.71 53.59 5064.81 4983.91 336.98 4528.15 216.10 4442.90 15.32 15.32 0.00 5958962.42 616487.77 N 70 1747.923 W 149324.130 7087.49 86.33 53.59 5067.79 4986.89 356.05 4559.15 234.50 4467.85 11.62 11.62 0.00 5958981.19 616512.44 N 70 1748.104 W 149323.403 7119.10 90.41 53.60 5068.69 4987.79 375.48 4590.74 253.25 4493.28 12.91 12.91 0.03 5959000.31 616537.58 N 701748.289 W 149322.661 7150.12 93.82 53.60 5067.54 4986.64 394.55 4621.74 271.65 4518.23 10.99 10.99 0.00 5959019.07 616562.25 N 70 17 48.469 W 149321.934 7181.03 94.92 50.83 5065.19 4984.29 414.09 4652.56 290.53 4542.58 9.62 3.56 -8.96 5959038.31 616586.32 N 70 17 48.655 W 149321.224 7212.23 94.85 49.93 5062.53 4981.63 434.55 4683.64 310.35 4566.53 2.88 -0.22 -2.88 5959058.49 616609.96 N 70 17 48.850 W 149320.525 7243.28 93.41 50.73 5060.29 4979.39 454.96 4714.61 330.12 4590.36 5.30 -4.64 2.58 5959078.61 616633.50 N 70 1749.044 W 149319.830 7274.04 90.53 50.15 5059.24 4978.34 475.18 4745.35 349.70 4614.06 9.55 -9.36 -1.89 5959098.54 616656.90 N 70 1749.236 W149319.139 7305.55 88.23 49.15 5059.58 4978.68 496.22 4776.86 370.09 4638.07 7.96 -7.30 -3.17 5959119.29 616680.60 N 70 1749.437 W 149318.439 7336.79 87.44 47.77 5060.76 4979.86 517.55 4808.08 390.80 4661 .44 5.09 -2.53 -4.42 5959140.34 616703.66 N 70 1749.640 W 149317.757 7368.11 87.89 47.85 5062.03 4981.13 539.19 4839.37 411.81 4684.62 1.46 1.44 0.26 5959161.69 616726.52 N 70 17 49.847 W 149317.081 7398.68 88.44 48.38 5063.01 4982.11 560.20 4869.92 432.21 4707.37 2.50 1.80 1.73 5959182.43 616748.96 N 701750.047 W 149316.418 7429.72 89.02 47.91 5063.70 4982.80 581.53 4900.96 452.92 4730.49 2.40 1.87 -1.51 5959203.47 616771.76 N 70 17 50.251 W 149315.744 7460.94 89.60 48.07 5064.08 4983.18 603.05 4932.17 473.81 4753.68 1.93 1.86 0.51 5959224.71 616794.64 N 701750.456 W 149315.067 7491.34 89.30 47.43 5064.37 4983.47 624.09 4962.57 494.25 4776.18 2.32 -0.99 -2.11 5959245.48 616816.84 N 701750.657 W149314.411 7523.12 87.72 47.17 5065.19 4984.29 646.26 4994.34 515.79 4799.53 5.04 -4.97 -0.82 5959267.37 616839.86 N 70 17 50.869 W 149313.730 7554.68 88.13 47.60 5066.34 4985.44 668.24 5025.88 537.15 4822.74 1.88 1.30 1.36 5959289.06 616862.74 N 70 17 51.079 W 149313.053 7585.56 88.75 47.63 5067.18 4986.28 689.66 5056.75 557.96 4845.54 2.01 2.01 0.10 5959310.21 616885.23 N 70 17 51.283 W 149312.388 7615.98 89.33 47.53 5067.69 4986.79 710.78 5087.16 578.47 4867.99 1.93 1.91 -0.33 5959331 .05 616907.37 N 70 17 51.485 W 149311.733 7646.90 89.06 46.17 5068.12 4987.22 732.53 5118.08 599.62 4890.55 4.48 -0.87 -4.40 5959352.53 616929.61 N 70 17 51.693 W149311.075 7678.04 88.58 43.24 5068.76 4987.86 755.25 5149.21 621.74 4912.45 9.53 -1.54 -9.41 5959374.98 616951.17 N 70 17 51.910 W 149310.436 7709.28 88.30 39.27 5069.61 4988.71 779.27 5180.44 645.21 4933.04 12.74 -0.90 -12.71 5959398.75 616971.41 N701752.141 W 14939.836 7739.98 89.54 37.10 5070.19 4989.29 803.90 5211.14 669.34 4952.01 8.14 4.04 -7.07 5959423.15 616990.02 N 70 17 52.378 W 14939.282 7771.11 90.43 34.75 5070.20 4989.30 829.60 5242.27 694.55 4970.27 8.07 2.86 -7.55 5959448.63 617007.90 N 70 17 52.626 W 14938.749 7802.12 88.95 33.16 5070.37 4989.47 855.78 5273.27 720.27 4987.59 7.00 -4.77 -5.13 5959474.60 617024.83 N 70 17 52.879 W 14938.244 7833.61 88.78 30.90 5070.99 4990.09 882.91 5304.76 746.95 5004.29 7.20 -0.54 -7.18 5959501.53 617041.13 N 70 1753.141 W 14937.757 7864.51 88.47 30.13 5071.73 4990.83 909.94 5335.65 773.57 5019.97 2.69 -1.00 -2.49 5959528.38 617056.41 N 70 17 53.403 W 14937.299 7896.10 87.89 27.36 5072.74 4991.84 938.03 5367.22 801.25 5035.16 8.95 -1.84 -8.77 5959556.28 617071.18 N 70 17 53.675 W 14936.856 7927.21 88.20 25.41 5073.80 4992.90 966.24 5398.32 829.10 5048.97 6.34 1.00 -6.27 5959584.33 617084.58 N 70 17 53.949 W 14936.453 7957.98 87.89 23.85 5074.85 4993.95 994.54 5429.07 857.05 5061.79 5.17 -1.01 -5.07 5959612.47 617096.98 N 70 17 54.223 W 14936.078 7989.01 87.75 20.75 5076.03 4995.13 1023.53 5460.07 885.74 5073.55 9.99 -0.45 -9.99 5959641.32 617108.31 N 70 17 54.505 W 149 3 5.735 8020.36 87.92 19.77 5077.21 4996.31 1053.20 5491 .40 915.13 5084.40 3.17 0.54 -3.13 5959670.87 617118.72 N 70 17 54.794 W 14935.418 8050.85 87.89 19.01 5078.33 4997.43 1082.21 5521 .87 943.87 5094.52 2.49 -0.10 -2.49 5959699.75 617128.41 N 70 17 55.077 W14935.123 8081.92 89.19 15.42 5079.12 4998.22 1112.11 5552.93 973.53 5103.71 12.29 4.18 -11.55 5959729.55 617137.15 N 70 17 55.369 W 14934.854 8113.42 88.54 13.50 5079.74 4998.64 1142.81 5584.42 1004.03 5111.57 6.43 -2.06 -6.10 5959760.15 617144.56 N 70 17 55.668 W 14934.624 8144.14 86.62 11.51 5081.04 5000.14 1172.94 5615.12 1033.99 5118.22 9.00 -6.25 -6.48 5959790.21 617150.76 N 70 17 55.963 W 14934.430 8175.35 86.93 9.40 5082.80 5001.90 1203.72 5646.28 1064.63 5123.87 6.82 0.99 -6.76 5959820.93 617155.95 N 701756.264 W 14934.265 8206.57 89.47 14.31 5083.78 5002.88 1234.42 5677.48 1095.16 5130.28 17.70 8.14 15.73 5959851.54 617161.91 N 70 17 56.565 W 14934.077 8237.21 91.42 17.55 5083.54 5002.64 1264.09 5708.12 1124.61 5138.69 12.34 6.36 10.57 5959881.12 617169.87 N 70 17 56.854 W 14933.831 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) W-205\W-205\W-205L2\W-205L2 Generated 1/23/2004 1 :23 PM Page 2 of 4 . . r M~suroo I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Buik! Rate I Walk Rate I Northing Easting L_ Longnude Depth Section Departure (It) ( deg) (deg) (ft) (ft) (ft) (ft) (It) (ft) (deg/100ft) (deg/1ooft) (dep'100ft) (ftUS) (ftUS) 8269.16 91.97 17.84 5082.60 5001.70 1294.77 5740.05 1155.04 5148.40 1.95 1.72 0.91 5959911.68 617179.12 N 70 1757.153 W 14933.548 8299.65 92.28 17.40 5081 .46 5000.56 1324.05 5770.52 1184.08 5157.62 1.76 1.02 -1.44 5959940.86 617187.91 N 70 1757.439 W 14933.278 8331.16 92.49 16.99 5080.15 4999.25 1354.37 5802.00 1214.15 5166.93 1.46 0.67 -1.30 5959971.06 617196.77 N 70 17 57.735 W 14933.006 8362.44 90.19 15.52 5079.42 4998.52 1384.61 5833.27 1244.17 5175.68 8.73 -7.35 -4.70 5960001 .21 617205.07 N 70 1758.030 W 14932.751 8393.00 88.95 15.76 5079.65 4998.75 1414.25 5863.83 1273.60 5183.92 4.13 -4.06 0.79 5960030.75 617212.87 N 7017 58.319 W 14932.510 8424.05 87.79 15.30 5080.53 4999.63 1444.37 5894.87 1303.50 5192.23 4.02 -3.74 -1.48 5960060.77 617220.73 N 70 17 58.613 W 14932.267 8454.99 87.31 14.53 5081.86 5000.96 1474.45 5925.78 1333.37 5200.18 2.93 -1.55 -2.49 5960090.75 617228.24 N 70 17 58.907 W 14932.035 8486.55 87.75 14.55 5083.22 5002.32 1505.17 5957.31 1363.89 5208.10 1.40 1.39 0.06 5960121.39 617235.70 N 70 17 59.207 W14931.803 8516.79 88.23 13.43 5084.28 5003.38 1534.68 5987.53 1393.22 5215.40 4.03 1.59 -3.70 5960150.81 617242.57 N 70 17 59.495 W14931.590 8548.02 88.37 11.37 5085.20 5004.30 1565.34 6018.75 1423.70 5222.11 6.61 0.45 -6.60 5960181.39 617248.82 N 70 17 59.795 W 14931.394 8579.49 88.92 9.15 5085.95 5005.05 1596.44 6050.21 1454.66 5227.71 7.27 1.75 -7.05 5960212.43 617253.96 N 70 18 0.100 W 14931.230 8610.23 88.99 7.92 5086.51 5005.61 1626.95 6080.94 1485.05 5232.27 4.01 0.23 -4.00 5960242.88 617258.06 N 70 18 0.399 W14931.096 8642.06 88.10 7.07 5087.32 5006.42 1658.59 6112.76 1516.60 5236.42 3.87 -2.80 -2.67 5960274.49 617261.74 N 70 18 0.709 W 14930.974 8673.58 88.13 5.74 5088.35 5007.45 1689.98 6144.27 1547.91 5239.94 4.22 0.10 -422 5960305.84 617264.79 N 70 181.017 W 14930.871 8704.14 88.40 5.00 5089.28 5008.38 1720.46 6174.81 1578.32 5242.80 2.58 0.88 -2.42 5960336.29 617267.19 N 70 181.316 W 14930.787 8735.38 88.95 1.50 5090.00 5009.10 1751.67 6206.04 1609.49 5244.57 11.34 1.76 -11.20 5960367.48 617268.50 N 70 181.622 W 14930.735 8765.93 90.19 1.42 5090.23 5009.33 1782.22 6236.59 1640.03 5245.34 4.07 4.06 -0.26 5960398.03 617268.82 N 70 181.923 W 14930.712 8796.78 88.40 0.08 5090.61 5009.71 1813.07 6267.44 1670.88 5245.75 7.25 -5.80 -4.34 5960428.87 617268.77 N 70 18 2.226 W 14930.699 8827.71 87.75 357.39 5091.65 5010.75 1843.94 6298.35 1701.78 5245.07 8.94 -2.10 -8.70 5960459.76 617267.62 N 70 18 2.530 W 14930.719 8859.06 87.89 354.83 5092.84 5011.94 1875.12 6329.68 1733.03 5242.94 8.17 0.45 -8.17 5960490.97 617265.03 N 70 182.837 W 14930.780 8890.48 89.16 352.76 5093.65 5012.75 1906.24 6361.09 1764.25 5239.55 7.73 4.04 -6.59 5960522.14 617261.17 N 70 18 3.144 W 14930.878 8921.88 88.92 350.38 5094.18 5013.28 1937.16 6392.48 1795.31 5234.94 7.62 -0.76 -7.58 5960553.12 617256.11 N 70 18 3.450 W 14931.012 8953.02 88.54 349.06 5094.87 5013.97 1967.63 6423.62 1825.94 5229.39 4.41 -1.22 -4.24 5960583.66 617250.10 N 70 18 3.751 W14931.173 8984.34 88.58 346.43 5095.66 5014.76 1998.03 6454.93 1856.53 5222.74 8.40 0.13 -8.40 5960614.15 617243.00 N 70 184.052 W 14931.366 9014.77 89.54 343.40 5096.15 5015.25 2027.17 6485.35 1885.91 5214.82 10.44 3.15 -9.96 5960643.40 617234.64 N 70 184.341 W 14931.597 9045.93 88.75 342.22 5096.62 5015.72 2056.68 6516.51 1915.67 5205.62 4.56 -2.54 -3.79 5960673.02 617224.99 N 70 184.634 W 14931.864 9077 .40 88.40 340.19 5097.40 5016.50 2086.17 6547.97 1945.45 5195.48 6.54 -1.11 -6.45 5960702.64 617214.42 N 70 184.927 W 14932.159 9108.24 87.89 337.56 5098.40 5017.50 2114.61 6578.79 1974.20 5184.37 8.68 -1.65 -8.53 5960731.22 617202.88 N 70 18 5.210 W 14932.483 9139.27 88.44 335.03 5099.39 5018.49 2142.65 6609.80 2002.60 5171.91 8.34 1.77 -8.15 5960759.43 617190.00 N 70 18 5.489 W 14932.845 9171.02 89.40 334.52 5099.99 5019.09 2170.99 6641.55 2031.31 5158.38 3.42 3.02 -1.61 5960787.93 617176.04 N 70 18 5.771 W 14933.239 9202.39 90.60 334.12 5099.99 5019.09 2198.88 6672.92 2059.58 5144.78 4.03 3.83 -1.28 5960816.00 617162.03 N 70 18 6.050 W 14933.635 9233.02 89.71 335.05 5099.91 5019.01 2226.18 6703.55 2087.25 5131.64 4.20 -2.91 3.04 5960843.46 617148.47 N 70 18 6.322 W 14934.018 9264.47 89.43 334.13 5100.15 5019.25 2254.21 6735.00 2115.66 5118.14 3.06 -0.89 -2.93 5960871.66 617134.56 N 70 18 6.601 W 14934.411 9295.86 89.43 334.66 5100.46 5019.56 2282.13 6766.39 2143.96 5104.58 1.69 0.00 1.69 5960899.76 617120.57 N 70 18 6.880 W 14934.806 9327.28 90.08 333.72 5100.59 5019.69 2310.04 6797.81 2172.25 5090.90 3.64 2.07 -2.99 5960927.83 617106.48 N 70 18 7.158 W 14935.204 9358.67 90.67 334.16 5100.39 5019.49 2337.85 6829.19 2200.44 5077.11 2.34 1.88 1.40 5960955.82 617092.27 N 70 187.435 W 14935.605 9389.69 90.74 334.94 5100.01 5019.11 2365.48 6860.21 2228.45 5063.78 2.52 0.23 2.51 5960983.62 617078.52 N 70 187.711 W 14935.993 9421.04 90.80 335.40 5099.58 5018.68 2393.56 6891 .56 2256.90 5050.62 1.48 0.19 1.47 5961011.87 617064.94 N 70 18 7.991 W 14936.377 9452.71 90.94 335.23 5099.10 5018.20 2421.96 6923.23 2285.67 5037.39 0.70 0.44 -0.54 5961040.44 617051.29 N 70 188.274 W 14936.762 9483.09 90.84 334.88 5098.63 5017.73 2449.15 6953.60 2313.22 5024.58 1.20 -0.33 -1.15 5961067.79 617038.07 N 70 18 8.545 W14937.135 9514.39 89.81 335.88 5098.45 5017.55 2477.23 6984.90 2341.67 5011.54 4.59 -3.29 3.19 5961096.04 617024.61 N 70 18 8.825 W 14937.514 9546.22 89.81 335.73 5098.56 5017.66 2505.90 7016.73 2370.70 4998.50 0.47 0.00 -0.47 5961124.87 617011.13 N70189.110 W 14937.894 9577.14 89.78 335.65 5098.67 5017.77 2533.72 7047.65 2398.88 4985.77 0.28 -0.10 -0.26 5961152.86 616997.99 N 70 18 9.388 W 14938.265 9608.43 90.26 335.82 5098.66 5017.76 2561.89 7078.94 2427.41 4972.91 1.63 1.53 0.54 5961181.18 616984.71 N 70 18 9.668 W 14938.639 9639.79 91.11 336.82 5098.28 5017.38 2590.25 7110.30 2456.12 4960.32 4.18 2.71 3.19 5961209.71 616971.69 N 70 18 9.951 W 14939.006 9670.24 91.46 337.31 5097.60 5016.70 2617.96 7140.74 2484.16 4948.45 1.98 1.15 1.61 5961237.56 616959.41 N 70 18 10.227 W 14939.351 9701 .89 91.77 337.89 5096.71 5015.81 2646.87 7172.38 2513.41 4936.40 2.08 0.98 1.83 5961266.63 616946.92 N 70 18 10.514 W 14939.702 9733.24 91.66 338.11 5095.77 5014.87 2675.59 7203.71 2542.46 4924.66 0.78 -0.35 0.70 5961295.50 616934.75 N 70 18 10.800 W 149310.044 9762.55 91.28 337.63 5095.02 5014.12 2702.42 7233.01 2569.61 4913.62 2.09 -1.30 -1.64 5961322.47 616923.31 N 701811.067 W 149310.365 9794.44 89.71 338.13 5094.74 5013.84 2731.62 7264.90 2599.15 4901.61 5.17 -4.92 1.57 5961351.83 616910.86 N 70 1811.358 W 149310.714 9825.64 87.55 335.96 5095.49 5014.59 2760.00 7296 09 2627.86 4889.45 9.81 -6.92 -6.96 5961380.36 616898.27 N 70 18 11.640 W 149311.069 9856.77 87.82 336.07 5096.75 5015.85 2788.06 7327.20 2656.28 4876.81 0.94 0.87 0.35 5961408.58 616885.21 N 70 1811.920 W 149311.437 9887.76 88.95 337.61 5097.62 5016.72 2816.20 7358.17 2684.76 4864.62 6.16 3.65 4.97 5961436.88 616872.60 N 70 18 12.200 W149311.791 9918.35 89.36 336.54 5098.07 5017.17 2844.04 7388.76 2712.93 4852.71 3.75 1.34 -3.50 5961464.86 616860.27 N 70 18 12.477 W 149312.138 9949.74 89.91 336.87 5098.27 5017.37 2872.52 7420.15 2741.76 4840.30 2.04 1.75 1.05 5961493.50 616847.43 N 70 18 12.761 W 149312.500 9981.02 90.29 337.51 5098.22 5017.32 2901.01 7451.43 2770.60 4828.17 2.38 1.21 2.05 5961522.15 616834.88 N 70 18 13.044 W 149312.853 10011.75 90.67 336.39 5097.96 5017.06 2928.95 7482.16 2798.87 4816.14 3.85 1.24 -3.64 5961550.24 616822.43 N 70 18 13.323 W 149313.203 10043.59 89.50 338.16 5097.91 5017.01 2957.97 7514.00 2828.24 4803.84 6.66 -3.67 5.56 5961579.42 616809.69 N 70 18 13.611 W 149313.561 10074.79 88.68 338.67 5098.41 5017.51 2986.65 7545.19 2857.25 4792.36 3.09 -2.63 1.63 5961608.25 616797.79 N 70 18 13.897 W 149313.895 10105.40 88.88 339.30 5099.06 5018.16 3014.91 7575.80 2885.81 4781.39 2.16 0.65 2.06 5961636.65 616786.39 N 70 18 14.178 W 149314.215 10136.32 87.82 339.18 5099.95 5019.05 3043.50 7606.70 2914.71 4770.43 3.45 -3.43 -0.39 5961665.38 616775.01 N701814.462 W 149314.534 10167.39 87.65 338.13 5101.18 5020.28 3072.10 7637.75 2943.63 4759.13 3.42 -0.55 -3.38 5961694.12 616763.28 N 70 18 14.747 W 149314.862 10198.87 89.06 339.34 5102.08 5021.18 3101.10 7669.21 2972.95 4747.72 5.90 4.48 3.84 5961723.27 616751.43 N 70 18 15.035 W 149315.195 10230.37 90.32 339.70 5102.25 5021.35 3130.30 7700.71 3002.46 4736.70 4.16 4.00 1.14 5961752.60 616739.97 N 70 18 15.325 W 149315.515 10261.47 90.74 339.60 5101.96 5021.06 3159.15 7731.81 3031.62 4725.89 1.39 1.35 -0.32 5961781.59 616728.72 N701815.612 W 149315.830 1 0292.22 90.94 338.82 5101.51 5020.61 3187.59 7762.56 3060.36 4714.97 2.62 0.65 -2.54 5961810.17 616717.38 N 70 18 15.895 W 149316.148 10323.68 91.11 339.18 5100.95 5020.05 3216.64 7794.01 3089.73 4703.70 1.27 0.54 1.14 5961839.36 616705.68 N 70 1816.184 W 149316.476 10354.69 91.32 338.95 5100.29 5019.39 3245.28 "l825.02 3118.69 4692.62 1.00 0.68 -0.74 5961868.15 616694.17 N 70 18 16.469 W 149316.799 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rl-546) W-205\W-205\W-205L2\W-205L2 Generated 1/23/2004 1 :23 PM Page 3 of 4 . . r Measur~ I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Latitude Long~ude Depth Section Departure (It) ( deg) (deg) (It) (It) (It) (It) (It) (It) ( deg/1oo It) ( deg/1oo It ) ( deg/1 00 It ) (nUS) (ftUS) 10385.56 91.73 337.61 5099.47 5018.57 3273:63 7855.88 3147.35 4681.20 4.54 1.33 -4.34 5961896.64 616682.32 N 70 18 16.751 W 149317.131 10417.21 90.67 338.80 5098.81 5017.91 3302.68 7887.52 3176.73 4669.45 5.03 -3.35 3.76 5961925.84 616670.14 N 70 18 17.040 W 149317.473 10447.90 90.32 339.51 5098.54 5017.64 3331.05 7918.21 3205.41 4658.53 2.58 -1.14 2.31 5961954.35 616658.80 N 70 18 17.322 W 149317.791 10478.90 90.39 338.31 5098.35 5017.45 3359.66 7949.21 3234.34 4647.38 3.88 0.23 -3.87 5961983.10 616647.21 N 70 18 17.606 W149318.116 10510.27 90.67 338.93 5098.06 5017.16 3388.54 7980.57 3263.55 4635.94 2.17 0.89 1.98 5962012.13 616635.34 N 70 18 17.894 W 149318.449 10541 .43 91.29 338.29 5097.53 5016.63 3417.23 8011.73 3292.55 4624.58 2.86 1.99 -2.05 5962040.97 616623.55 N 701818.179 W 149318.780 10572.55 91.73 339.52 5096.71 5015.81 3445.94 8042.84 3321.58 4613.39 4.20 1.41 3.95 5962069.82 616611.92 N 701818.465 W149319.106 10611.34 92.66 339.50 5095.22 5014.32 3481 .87 8081.60 3357.89 4599.82 2.40 2.40 -0.05 5962105.92 616597.82 N701818.822 W 149319.501 10670.00 92.66 339.50 5092.50 5011.60 3536.17 8140.20 3412.77 4579.30 0.00 0.00 0.00 5962160.49 616576.48 N 701819.362 W 149320.098 LeQal Description: NorthinQ (VI [ftUS] EastinQ (XI [ftUS] Surface: 3703 FSL 1197 FEL S21 T11 N R12E UM 5958680.13 612048.97 BHL: 1834 FSL 1890 FEL S15 T11 N R12E UM 5962160.49 616576.48 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546) W-205\W-205\W-205L2\W-205L2 Generated 1/23/2004 1 :23 PM Page 4 of 4 1'K~Þ\"\ ~ SCHLUMBERGER Survey report Client... ... .............: BP Exploration (Alaska) Inc. Field........ ... .........: Polaris Well. . . . . . . . . . . . . . . . . . . . .: W-205 L2 API number.... ..... .... ..: 50-029-23165-61 Engineer... ... ...........: Etienne Roux RIG: . . . . . . . . . . . . . . . . . .. . .: NABORS 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 52.40 ft KB above permanent. ......: N/A Top Drive ft DF above permanent.......: 80.90 ft ----- Vertical section origin---------------- Latitude (+N/S-).. .......: 0.00 ft Departure (+E/W-).. .... ..: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).... .....: N 70 17 45.811 Departure (+E/W-). .......: W 149 5 33.633 Azimuth from rotary table to target: 1.56 degrees [(c)2003 IDEAL ID8 1C_01J 24-Dec-2003 03:41:21 Spud da t e. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys...: MD of first survey... ....: MD of last survey... .....: (9ê)S" ÐC)'d- Page 1 of 8 21-Dec-03 24-Dec-03 195 0.00 ft 10670.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2003 Magnetic date............: 20-Dec-2003 Magnetic field strength. . : 1151.21 HCNT Magnetic dec (+E/W-).....: 25.23 degrees Magnetic dip.. ...........: 80.81 degrees ----- MWD survey Reference Reference G....... .......: Reference H.... ..... .....: Reference Dip....... .....: Tolerance of G.... .......: Tolerance of H.. .........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.21 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 25.23 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.23 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 RECEIVED ¡ . ,.., 6IY\(H \.... L, (.\JV4 pj~<\\kQ OJ! ~ r.:~ f"",..,. Cl\ttlrm.w.r..... ~,...:,,/ht:ii ..,.a"O~~~VUU;), \4UUi~1 ¿~r~,:~,~ 'J -i;\J hY~~4* ~1J¥ SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 2 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ......----- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Surface Tie In 2 138.20 0.07 88.07 138.20 138.20 0.01 0.00 0.08 0.08 88.07 0.05 MWD IFR MSA - 3 239.52 0.61 54.75 101.32 239.52 0.33 0.32 0.59 0.67 61.68 0.55 MWD IFR MSA - 4 300.39 2.25 63.08 60.87 300.37 1.10 1. 04 1. 92 2.18 61. 42 2.71 MWD IFR MSA 5 390.94 5.17 82.77 90.55 390.72 2.57 2.36 7.55 7.91 72.62 3.47 MWD IFR MSA 6 483.11 6.93 92.96 92.17 482.38 3.07 2.60 17.22 17.42 81. 42 2.23 MWD IFR MSA . - 7 576.06 8.31 96.29 92.95 574.50 2.38 1. 57 29.50 29.54 86.95 1. 56 MWD IFR MSA - 8 671. 50 10.95 97.11 95.44 668.59 0.93 -0.31 45.35 45.36 90.39 2.77 MWD IFR MSA - 9 765.37 13 .56 93.83 93.87 760.31 -0.37 -2.14 65.19 65.22 91. 88 2.88 MWD IFR MSA - 10 859.95 15.67 90.40 94.58 851. 83 -0.55 -2.97 89.02 89.07 91.91 2.41 MWD IFR MSA 11 954.66 18.74 90.44 94.71 942.29 0.01 -3.18 117.03 117.08 91.56 3.24 MWD IFR MSA - 12 1050.16 23.91 88.55 95.50 1031.22 1.32 -2.81 151.75 151. 77 91.06 5.46 MWD IFR MSA 13 1144.14 27.46 91. 14 93.98 1115.91 2.48 -2.76 192.46 192.48 90.82 3.96 MWD IFR MSA - 14 1238.39 29.92 90.46 94.25 1198.58 3.09 -3.38 237.70 237.73 90.81 2.63 MWD IFR MSA - 15 1333.55 33.56 88.26 95.16 1279.50 5.06 -2.77 287.74 287.76 90.55 4.01 MWD IFR MSA 16 1427.00 38.84 92.23 93.45 1354.89 6.21 -3.13 342.89 342.90 90.52 6.18 MWD IFR MSA - 17 1521.98 43.73 92.85 94.98 1426.24 5.12 -5.92 405.47 405.52 90.84 5.17 MWD IFR MSA - 18 1616.01 45.76 92.04 94.03 1493.02 4.11 -8.73 471.60 471.68 91.06 2.24 MWD IFR MSA - 19 1709.89 45.49 93.10 93.88 1558.68 2.93 -11.74 538.64 538.76 91. 25 0.86 MWD IFR MSA - 20 1803.35 44.15 92.96 93.46 1624.97 1.24 -15.22 604.42 604.61 91. 44 1.44 MWD IFR MSA 21 1898.67 42.83 93.34 95.32 1694.12 -0.58 -18.83 669.92 670.19 91.61 1.41 MWD IFR MSA . - 22 1992.58 42.02 93.80 93.91 1763.44 -2.80 -22.77 733.15 733.51 91.78 0.92 MWD IFR MSA - 23 2087.21 41. 64 93.69 94.63 1833.96 -5.21 -26.89 796.13 796.58 91. 93 0.41 MWD IFR MSA 24 2182.02 42.33 93.42 94.81 1904.43 -7.42 -30.82 859.43 859.98 92.05 0.75 MWD IFR MSA 25 2276.41 41.86 93.01 94.39 1974.47 -9.24 -34.37 922.60 923.24 92.13 0.58 MWD IFR MSA 26 2371.24 43.94 92.92 94.83 2043.93 -10.83 -37.71 987.07 987.79 92.19 2.19 MWD IFR MSA - 27 2465.72 44.80 90.69 94.48 2111. 47 -11.10 -39.78 1053.09 1053.84 92.16 1. 88 MWD IFR MSA - 28 2560.07 44.84 89.82 94.35 2178.40 -9.58 -40.08 1119.60 1120.31 92.05 0.65 MWD IFR MSA - 29 2654.53 44.98 90.34 94.46 2245.30 -7.86 -40.17 1186.28 1186.96 91.94 0.42 MWD IFR MSA - 30 2750.20 44.95 90.82 95.67 2312.99 -6.71 -40.86 1253.89 1254.55 91. 87 0.36 MWD IFR MSA [(c)2003 IDEAL ID8 1C_01l SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 3 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2845.05 44.48 90.47 94.85 2380.39 -5.64 -41. 61 1320.62 1321.27 91.80 0.56 MWD IFR MSA - 32 2940.21 44.54 87.54 95.16 2448.26 -2.67 -40.45 1387.30 1387.89 91. 67 2.16 MWD IFR MSA 33 3034.42 44.39 87.64 94.21 2515.49 1. 90 -37.67 1453.24 1453.73 91.49 0.18 MWD IFR MSA - 34 3129.22 44.11 87.91 94.80 2583.40 6.27 -35.11 1519.34 1519.74 91. 32 0.36 MWD IFR MSA - 35 3221.57 44.52 88.27 92.35 2649.48 10.17 -32.96 1583.82 1584.16 91.19 0.52 MWD IFR MSA 36 3315.03 44.46 88.48 93.46 2716.15 13.81 -31.10 1649.29 1649.58 91. 08 0.17 MWD IFR MSA . - 37 3409.53 44.42 88.46 94.50 2783.62 17.38 -29.33 1715.43 1715.68 90.98 0.04 MWD IFR MSA - 38 3504.53 44.80 88.89 95.00 2851.25 20.74 -27.79 1782.13 1782.34 90.89 0.51 MWD IFR MSA - 39 3598.91 45.06 89.18 94.38 2918.07 23.67 -26.67 1848.77 1848.96 90.83 0.35 MWD IFR MSA - 40 3694.74 46.75 88.01 95.83 2984.75 27.24 -24.97 1917.57 1917.73 90.75 1. 97 MWD IFR MSA 41 3788.33 46.72 88.07 93.59 3048.90 31. 43 -22.64 1985.68 1985.81 90.65 0.06 MWD IFR MSA - 42 3882.04 48.58 88.49 93.71 3112.02 35.39 -20.56 2054.90 2055.01 90.57 2.01 MWD IFR MSA - 43 3935.59 49.24 88.61 53.55 3147.22 37.50 -19.54 2095.25 2095.34 90.53 1.24 MWDIFR MSA 44 4029.51 47.87 88.73 93.92 3209.38 41.05 -17.91 2165.63 2165.70 90.47 1.46 MWD IFR MSA - 45 4125.83 47.53 88.86 96 .32 3274.21 44.49 -16.41 2236.86 2236.92 90.42 0.37 MWD IFR MSA 46 4219.70 47.06 88.57 93.87 3337.87 47.91 -14.86 2305.82 2305.87 90.37 0.55 MWD IFR MSA 47 4313 .18 47.50 90.07 93.48 3401.29 50.60 -14.05 2374.49 2374.53 90.34 1.27 MWD IFR MSA 48 4408.39 49.25 90.60 95.21 3464.53 52.11 -14.47 2445.65 2445.70 90.34 1.88 MWD IFR MSA 49 4502.06 49.19 90.52 93.67 3525.71 53.35 -15.17 2516.58 2516.62 90.35 0.09 MWD IFR MSA 50 4596.92 48.95 90.38 94.86 3587.86 54.74 -15.73 2588.24 2588.29 90.35 0.28 MWD IFR MSA 51 4692.21 48.79 90.24 95.29 3650.54 56.30 -16.12 2660.02 2660.07 90.35 0.20 MWD IFR MSA . - 52 4786.94 48.40 89.75 94.73 3713.19 58.24 -16.11 2731.07 2731.12 90.34 0.57 MWD IFR MSA - 53 4881.27 47.90 89.49 94.33 3776.13 60.62 -15.65 2801.33 2801.38 90.32 0.57 MWD IFR MSA 54 4976.33 47.54 89.45 95.06 3840.08 63.19 -15.00 2871.66 2871.70 90.30 0.38 MWD IFR MSA - 55 5070.70 47.15 89.05 94.37 3904.02 65.98 -14.09 2941.06 2941.09 90.27 0.52 MWD IFR MSA 56 5164.92 46.92 88.98 94.22 3968.24 69.05 -12.90 3010.00 3010.02 90.25 0.25 MWD IFR MSA 57 5260.11 47.44 91.19 95.19 4032.94 70.84 -13.01 3079.81 3079.84 90.24 1. 79 MWD IFR MSA - 58 5353.62 47.09 90.56 93.51 4096.40 71.66 -14.06 3148.48 3148.52 90.26 0.62 MWD IFR MSA - 59 5448.04 46.84 90.99 94.42 4160.84 72.60 -15.00 3217.49 3217.53 90.27 0.43 MWD IFR MSA - 60 5542.45 47.35 93.52 94.41 4225.11 71.76 -17.72 3286.58 3286.63 90.31 2.04 MWD IFR MSA [(C)2003 IDEAL ID8_1C_01] SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 4 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5637.51 48.32 97.51 95.06 4288.94 66.88 -24.51 3356.68 3356.77 90.42 3.27 MWD IFR MSA - 62 5730.86 48.49 102.79 93.35 4350.93 56.46 -36.81 3425.36 3425.56 90.62 4.23 MWD IFR MSA 63 5827.15 48.36 104.32 96.29 4414.83 41. 49 -53.69 3495.38 3495.79 90.88 1. 20 MWD IFR MSA 64 5922.20 47.21 99.09 95.05 4478.72 29.07 -67.99 3564.26 3564.91 91.09 4.25 MWD IFR MSA - 65 6018.20 47.43 95.71 96.00 4543.81 21.89 -77.07 3634.23 3635.05 91. 21 2.60 MWD IFR MSA 66 6113.56 49.51 92 .20 95.36 4607.04 18.95 -81.96 3705.42 3706.33 91. 27 3.51 MWD IFR MSA . - 67 6207.77 51. 06 88.79 94.21 4667.25 20.32 -82.56 3777.87 3778.77 91.25 3.23 MWD IFR MSA - 68 6301.13 54.14 83.06 93.36 4723.98 27.67 -77.22 3851.78 3852.55 91.15 5.89 MWD IFR MSA 69 6393.40 55.11 76.89 92 .27 4777.43 42.79 - 64.11 3925.80 3926.33 90.94 5.55 MWD IFR MSA 70 6486.61 56.60 71. 66 93.21 4829.77 65.73 -43.19 4000.00 4000.24 90.62 4.91 MWD IFR MSA - 71 6582.21 60.06 67.40 95.60 4879.97 96.28 -14.69 4076.17 4076.20 90.21 5.24 MWD IFR MSA - 72 6676.53 63.26 62.27 94.32 4924.76 133.64 20.64 4151. 24 4151.29 89.72 5.87 MWD IFR MSA - 73 6771.35 64.85 57.71 94.82 4966.26 178.28 63.28 4225.03 4225.51 89.14 4.64 MWD IFR MSA - 74 6865.05 65.91 55.97 93.70 5005.30 226.80 109.88 4296.33 4297.74 88.54 2.03 MWD IFR MSA - 75 6930.00 67.45 54.05 64.95 5031.01 262.32 144.08 4345.19 4347.58 88.10 3.60 Top of Window 76 6942.00 69.32 53.58 12.00 5035.43 269.15 150.67 4354.19 4356.80 88.02 16.00 Bottom of Window 77 6962.61 71. 26 53.58 20.61 5042.39 281.09 162.19 4369.81 4372.81 87.87 9.41 MWD Incl. Only 78 6994.21 73.52 53.59 31. 60 5051.94 299.62 180.07 4394.04 4397.73 87.65 7.15 MWD Incl. Only 79 7024.74 77.87 53.59 30.53 5059.49 317.82 197.62 4417.84 4422.26 87.44 14.25 MWD Incl. Only 80 7056.34 82.71 53.59 31. 60 5064.81 336.97 216.10 4442.90 4448.16 87.22 15.32 MWD Incl. Only 81 7087.49 86.33 53.59 31.15 5067.79 356.05 234.50 4467.85 4474.00 87.00 11.62 MWD Incl. Only . 82 7119.10 90.41 53.60 31. 61 5068.69 375.48 253.25 4493.28 4500.41 86.77 12.91 MWD Incl. Only 83 7150.12 93.82 53.60 31.02 5067.54 394.55 271.65 4518.23 4526.39 86.56 10.99 MWD IFR MSA 84 7181.03 94.92 50.83 30.91 5065.19 414.08 290.53 4542.58 4551.86 86.34 9.62 MWD IFR MSA 85 7212.23 94.85 49.93 31. 20 5062.53 434.55 310.35 4566.53 4577.06 86.11 2.88 MWD IFR MSA 86 7243.28 93.41 50.73 31.05 5060.29 454.96 330.12 4590.36 4602.22 85.89 5.30 MWD IFR MSA - 87 7274.04 90.53 50.15 30.76 5059.24 475.18 349.70 4614.06 4627.30 85.67 9.55 MWD IFR MSA 88 7305.55 88.23 49.15 31.51 5059.58 496.22 370.09 4638.07 4652.82 85.44 7.96 MWD IFR MSA - 89 7336.79 87.44 47.77 31. 24 5060.76 517.55 390.80 4661.44 4677.79 85.21 5.09 MWD IFR MSA - 90 7368.11 87.89 47.85 31.32 5062.03 539.19 411.81 4684.63 4702.69 84.98 1.46 MWD IFR MSA [(c)2003 IDEAL ID8 1C_01J SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 5 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 7398.68 88.44 48.38 30.57 5063.01 560.20 432.21 4707.37 4727.17 84.75 2.50 MWD IFR MSA - 92 7429.72 89.02 47.91 31. 04 5063.70 581. 53 452.92 4730.49 4752.12 84.53 2.40 MWD IFR MSA - 93 7460.94 89.60 48.07 31. 22 5064.08 603.05 473.81 4753.68 4777.24 84.31 1. 93 MWD IFR MSA 94 7491.34 89.30 47.43 30.40 5064.37 624.09 494.25 4776.18 4801.69 84.09 2.32 MWD IFR MSA 95 7523.12 87.72 47.17 31. 78 5065.20 646.26 515.79 4799.53 4827.17 83.87 5.04 MWD IFR MSA 96 7554.68 88.13 47.60 31.56 5066.34 668.24 537.15 4822.74 4852.56 83.64 1. 88 MWD IFR MSA . - 97 7585.56 88.75 47.63 30.88 5067.18 689.66 557.96 4845.54 4877.56 83.43 2.01 MWD IFR MSA - 98 7615.98 89.33 47.53 30.42 5067.69 710.78 578.47 4867.99 4902.24 83.22 1. 93 MWD IFR MSA - 99 7646.90 89.06 46.17 30.92 5068.12 732.53 599.62 4890.55 4927.17 83.01 4.48 MWD IFR MSA - 100 7678.04 88.58 43.24 31. 14 5068.76 755.25 621.74 4912.45 4951.64 82.79 9.53 MWD IFR MSA 101 7709.28 88.30 39.27 31. 24 5069.62 779.27 645.21 4933.04 4975.05 82.55 12.74 MWD IFR MSA 102 7739.98 89.54 37.10 30.70 5070.19 803.90 669.34 4952.01 4997.04 82.30 8.14 MWD IFR MSA - 103 7771 . 11 90.43 34.75 31.13 5070.20 829.60 694.55 4970.27 5018.57 82.05 8.07 MWD IFR MSA - 104 7802.12 88.95 33.16 31.01 5070.37 855.78 720.27 4987.59 5039.33 81.78 7.00 MWD IFR MSA - 105 7833.61 88.78 30.90 31.49 5070.99 882.91 746.95 5004.29 5059.73 81.51 7.20 MWD IFR MSA 106 7864.51 88.47 30.13 30.90 5071.74 909.94 773.57 5019.97 5079.23 81. 24 2.69 MWD IFR MSA 107 7896.10 87.89 27.36 31. 59 5072.74 938.03 801.25 5035.16 5098.51 80.96 8.95 MWD IFR MSA - 108 7927.21 88.20 25.41 31.11 5073.80 966.24 829.10 5048.97 5116.60 80.67 6.34 MWD IFR MSA - 109 7957.98 87.89 23.85 30.77 5074.85 994.54 857.05 5061.79 5133.83 80.39 5.17 MWD IFR MSA - 110 7989.01 87.75 20.75 31.03 5076.03 1023.53 885.74 5073 .55 5150.29 80.10 9.99 MWD IFR MSA 111 8020.36 87.92 19.77 31. 35 5077.22 1053.20 915.13 5084.40 5166.10 79.80 3.17 MWD IFR MSA . 112 8050.85 87.89 19.01 30.49 5078.33 1082.21 943.87 5094.52 5181. 22 79.50 2.49 MWD IFR MSA - 113 8081.92 89.19 15.42 31. 07 5079.12 1112.11 973.53 5103.71 5195.73 79.20 12.29 MWD IFR MSA - 114 8113.42 88.54 13.50 31. 50 5079.75 1142.81 1004.03 5111. 57 5209.25 78.89 6.43 MWD IFR MSA - 115 8144.14 86.62 11.51 30.72 5081.04 11 72 . 94 1033.99 5118.22 5221. 62 78.58 9.00 MWD IFR MSA 116 8175.35 86.93 9.40 31. 21 5082.80 1203.72 1064.63 5123.87 5233.31 78.26 6.82 MWD IFR MSA - 117 8206.57 89.47 14.31 31.22 5083.78 1234.42 1095.16 5130.28 5245.87 77.95 17.70 MWD IFR MSA - 118 8237.21 91.42 17.55 30.64 5083.54 1264.09 1124.61 5138.69 5260.31 77.66 12.34 MWD IFR MSA 119 8269.16 91.97 17.84 31. 95 5082.60 1294.77 1155.04 5148.40 5276.37 77.36 1. 95 MWD IFR MSA 120 8299.65 92.28 17.40 30.49 5081.47 1324.05 1184.08 5157.62 5291.79 77.07 1. 76 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01J SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 6 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (de g) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 8331.16 92.49 16.99 31. 51 5080.16 1354.37 1214.15 5166.93 5307.66 76.78 1.46 MWD IFR MSA 122 8362.44 90.19 15.52 31. 28 5079.43 1384.61 1244.17 5175.68 5323.12 76.48 8.73 MWD IFR MSA 123 8393.00 88.95 15.76 30.56 5079.65 1414.25 1273.60 5183.92 5338.08 76.20 4.13 MWD IFR MSA - 124 8424.05 87.79 15.30 31.05 5080.54 1444.37 1303.50 5192.23 5353.35 75.91 4.02 MWD IFR MSA - 125 8454.99 87.31 14.53 30.94 5081.86 1474.45 1333.37 5200.18 5368.41 75.62 2.93 MWD IFR MSA 126 8486.55 87.75 14.55 31. 56 5083.22 1505.17 1363.89 5208.10 5383.73 75.33 1.40 MWD IFR MSA . - 127 8516.79 88.23 13.43 30.24 5084.28 1534.68 1393.22 5215.41 5398.29 75.04 4.03 MWD IFR MSA - 128 8548.02 88.37 11. 37 31.23 5085.21 1565.34 1423.70 5222.11 5412.70 74.75 6.61 MWD IFR MSA - 129 8579.49 88.92 9.15 31. 47 5085.95 1596.44 1454.66 5227.71 5426.33 74.45 7.27 MWD IFR MSA - 130 8610.23 88.99 7.92 30.74 5086.51 1626.94 1485.05 5232.27 5438.94 74.15 4.01 MWD IFR MSA 131 8642.06 88.10 7.07 31.83 5087.32 1658.59 1516.60 5236.42 5451. 63 73.85 3.87 MWD IFR MSA 132 8673.58 88.13 5.74 31. 52 5088.36 1689.98 1547.91 5239.94 5463.79 73.54 4.22 MWD IFR MSA - 133 8704.14 88.40 5.00 30.56 5089.28 1720.46 1578.32 5242.80 5475.22 73.25 2.58 MWD IFR MSA 134 8735.38 88.95 1. 50 31. 24 5090.01 1751.67 1609.49 5244.57 5485.98 72.94 11.34 MWD IFR MSA - 135 8765.93 90.19 1.42 30.55 5090.24 1782.22 1640.03 5245.35 5495.76 72.64 4.07 MWD IFR MSA 136 8796.78 88.40 0.08 30.85 5090.61 1813.07 1670.88 5245.75 5505.43 72.33 7.25 MWD IFR MSA - 137 8827.71 87.75 357.39 30.93 5091.65 1843.94 1701. 78 5245.07 5514.23 72.02 8.94 MWD IFR MSA - 138 8859.06 87.89 354.83 31. 35 5092.85 1875.12 1733.03 5242.94 5521.94 71.71 8.17 MWD IFR MSA 139 8890.48 89.16 352.76 31. 42 5093.66 1906.24 1764.25 5239.55 5528.60 71.39 7.73 MWD IFR MSA - 140 8921.88 88.92 350.38 31. 40 5094.18 1937.16 1795.31 5234.94 5534.24 71.07 7.62 MWD IFR MSA 141 8953.02 88.54 349.06 31. 14 5094.87 1967.63 1825.94 5229.39 5539.00 70.75 4.41 MWD IFR MSA . - 142 8984.34 88.58 346.43 31.32 5095.66 1998.03 1856.53 5222.74 5542.90 70.43 8.40 MWD IFR MSA - 143 9014.77 89.54 343.40 30.43 5096.16 2027.17 1885.91 5214.83 5545.36 70.12 10.44 MWD IFR MSA - 144 9045.93 88.75' 342.22 31.16 5096.62 2056.68 1915.67 5205.62 5546.91 69.80 4.56 MWD IFR MSA - 145 9077.40 88.40 340.19 31.47 5097.41 2086.17 1945.45 5195.48 5547.78 69.47 6.54 MWD IFR MSA 146 9108.24 87.89 337.56 30.84 5098.41 2114.61 1974.20 5184.37 5547.54 69.15 8.68 MWD IFR MSA - 147 9139.27 88.44 335.03 31.03 5099.40 2142.65 2002.60 5171.91 5546.08 68.83 8.34 MWD IFR MSA - 148 9171.02 89.40 334.52 31.75 5100.00 2170.99 2031.31 5158.38 5543.93 68.51 3.42 MWD IFR MSA - 149 9202.39 90.60 334.12 31.37 5100.00 2198.88 2059.58 5144.79 5541.72 68.18 4.03 MWD IFR MSA - 150 9233.02 89.71 335.05 30.63 5099.91 2226.18 2087.25 5131.64 5539.89 67.87 4.20 MWD IFR MSA [(c)2003 IDEAL ID8 1C_01J SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 7 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 9264.47 89.43 334.13 31. 45 5100.15 2254.21 2115.66 5118.15 5538.18 67.54 3.06 MWD IFR MSA - 152 9295.86 89.43 334.66 31.39 5100.46 2282.13 2143.96 5104.58 5536.54 67.22 1. 69 MWD IFR MSA - 153 9327.28 90.08 333.72 31.42 5100.60 2310.04 2172.25 5090.90 5534.97 66.89 3.64 MWD IFR MSA 154 9358.67 90.67 334.16 31.39 5100.39 2337.85 2200.44 5077 .11 5533.44 66.57 2.34 MWD IFR MSA - 155 9389.69 90.74 334.94 31.02 5100.01 2365.48 2228.45 5063.78 5532.44 66.25 2.52 MWD IFR MSA 156 9421. 04 90.80 335.40 31. 35 5099.59 2393.56 2256.90 5050.62 5531.94 65.92 1.48 MWD IFR MSA . - 157 9452.71 90.94 335.23 31. 67 5099.11 2421. 96 2285.67 5037.39 5531.69 65.59 0.70 MWD IFR MSA 158 9483.09 90.84 334.88 30.38 5098.64 2449.15 2313.22 5024.58 5531. 49 65.28 1.20 MWD IFR MSA 159 9514.39 89.81 335.88 31. 30 5098.46 2477.24 2341. 67 5011.54 5531.63 64.96 4.59 MWD IFR MSA 160 9546.22 89.81 335.73 31.83 5098.56 2505.90 2370.70 4998.50 5532.20 64.63 0.47 MWD IFR MSA 161 9577.14 89.78 335.65 30.92 5098.67 2533.72 2398.88 4985.77 5532.86 64.31 0.28 MWD IFR MSA - 162 9608.43 90.26 335.82 31. 29 5098.66 2561.89 2427.41 4972.91 5533.73 63.98 1. 63 MWD IFR MSA - 163 9639.79 91.11 336.82 31.36 5098.29 2590.25 2456.12 4960.32 5535.10 63.66 4.18 MWD IFR MSA - 164 9670.24 91. 46 337.31 30.45 5097.61 2617.95 2484.16 4948.45 5536.99 63.34 1. 98 MWD IFR MSA - 165 9701.89 91.77 337.89 31. 65 5096.71 2646.87 2513.41 4936.40 5539.43 63.02 2.08 MWD IFR MSA 166 9733.24 91. 66 338.11 31.35 5095.77 2675.59 2542.46 4924.66 5542.24 62.69 0.78 MWD IFR MSA - 167 9762.55 91. 28 337.63 29.31 5095.02 2702.42 2569.61 4913.62 5544.96 62.39 2.09 MWD IFR MSA - 168 9794.44 89.71 338.13 31.89 5094.75 2731.62 2599.15 4901.61 5548.10 62.06 5.17 MWD IFR MSA - 169 9825.64 87.55 335.96 31. 20 5095.49 2760.00 2627.86 4889.45 5550.89 61.74 9.81 MWD IFR MSA - 170 9856.77 87.82 336.07 31.13 5096.75 2788.06 2656.28 4876.81 5553.29 61. 42 0.94 MWD IFR MSA 171 9887.76 88.95 337.61 30.99 5097.62 2816.20 2684.76 4864.62 5556.30 61. 11 6.16 MWD IFR MSA . - 172 9918.35 89.36 336.54 30.59 5098.08 2844.04 2712.93 4852.71 5559.57 60.79 3.75 MWD IFR MSA 173 9949.74 89.91 336.87 31.39 5098.28 2872.52 2741.76 4840.30 5562.89 60.47 2.04 MWD IFR MSA - 174 9981. 02 90.29 337.51 31. 28 5098.22 2901. 01 2770.60 4828.17 5566.64 60.15 2.38 MWD IFR MSA - 175 10011.75 90.67 336.39 30.73 5097.96 2928.95 2798.87 4816.14 5570.36 59.84 3.85 MWD IFR MSA 176 10043.59 89.50 338.16 31. 84 5097 . 92 2957.97 2828.24 4803.84 5574.57 59.51 6.66 MWD IFR MSA - 177 10074.79 88.68 338.67 31. 20 5098.41 2986.65 2857.25 4792.36 5579.48 59.20 3.09 MWD IFR MSA - 178 10105.40 88.88 339.30 30.61 5099.06 3014.91 2885.82 4781.39 5584.77 58.89 2.16 MWD IFR MSA - 179 10136.32 87.82 339.18 30.92 5099.95 3043.50 2914.72 4770.43 5590.40 58.58 3.45 MWD IFR MSA - 180 10167.39 87.65 338.13 31.07 5101.18 3072.10 2943.63 4759.13 5595.92 58.26 3.42 MWD IFR MSA [(c)2003 IDEAL IDS 1C_01J SCHLUMBERGER Survey Report 24-Dec-2003 03:41:21 Page 8 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 181 10198.87 89.06 339.34 31. 48 5102.09 3101.10 2972.95 4747.72 5601. 72 57.95 5.90 MWD IFR MSA - 182 10230.37 90.32 339.70 31. 50 5102.26 3130.30 3002.46 4736.70 5608.13 57.63 4.16 MWD IFR MSA - 183 10261. 47 90.74 339.60 31.10 5101. 97 3159.15 3031. 62 4725.89 5614.69 57.32 1. 39 MWD IFR MSA - 184 10292.22 90.94 338.82 30.75 5101. 52 3187.59 3060.36 4714.97 5621.10 57.01 2.62 MWD IFR MSA - 185 10323.68 91.11 339.18 31.46 5100.96 3216.64 3089.73 4703.70 5627.72 56.70 1. 27 MWD IFR MSA 186 10354.69 91. 32 338.95 31.01 5100.30 3245.28 3118.69 4692.62 5634.44 56.39 1. 00 MWD IFR MSA . - 187 10385.56 91. 73 337.61 30.87 5099.48 3273.63 3147.35 4681.20 5640.88 56.09 4.54 MWD IFR MSA - 188 10417.21 90.67 338.80 31.65 5098.81 3302.68 3176.73 4669.45 5647.60 55.77 5.03 MWD IFR MSA - 189 10447.90 90.32 339.51 30.69 5098.55 3331.05 3205.41 4658.53 5654.79 55.47 2.58 MWD IFR MSA 190 10478.90 90.39 338.31 31. 00 5098.36 3359.66 3234.34 4647.38 5662.07 55.16 3.88 MWD IFR MSA 191 10510.27 90.67 338.93 31.37 5098.07 3388.54 3263.55 4635.94 5669.45 54.86 2.17 MWD IFR MSA - 192 10541.43 91. 29 338.29 31.16 5097.53 3417.23 3292.55 4624.58 5676.94 54.55 2.86 MWD IFR MSA 193 10572.55 91.73 339.52 31. 12 5096.71 3445.94 3321.58 4613.39 5684.73 54.25 4.20 MWD IFR MSA 194 10611.34 92.66 339.50 38.79 5095.23 3481.87 3357.89 4599.82 5695.06 53.87 2.40 MWD IFR MSA 195 10670.00 92.66 339.50 58.66 5092.50 3536.17 3412.77 4579.30 5711.13 53.30 0.00 proj ected to TD [(c)2003 IDEAL ID8_1C_01J . ~C3 -:dO:;).. . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-205 L2 Date Dispatched: 23-Jan-04 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECEIV:D {"1/\I\ A it,·: ~ ;' ~c:;V": ,..;. ;;:; t.. 0 t._v '7 Received By: ~Q\~ /,,::b~ ~.t'/V~ ,Ala5Ka OU & Gas Cons. Oommislkm t¡í\r;t¡~e Please sign and return to: Drilling & Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose l@slb.com Fax: 907-561-8417 LWD Log DeliveryVl.l, 10-02-03 Schlumberger Private . . I ~ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OILAl\ID GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit W-205L2 BP Exploration (Alaska), Inc. Pennit No: 203-202 Surface Location: 3703' NSL, 1196' WEL, Sec. 21, T11N, R12E, UM Bottomhole Location: 1870' NSL, 3427' EWL, Sec. 15, T11N, R12E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations unt il all 0 ther required p ennits a nd approvals ha ve been is sued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. The pennit is for a new wellbore segment of existing well PBU W-205, Pennit No 203-116, API 50-029-23165. Production should continue to be reported as a function ofthe original API number stated above. 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 tenns and conditions of this pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). R' Sincerely, BY ORDERnOJI THE COMMISSION DATED thi~~ day of December, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section \¡;.fGA- 1'L-/;¡toO'S o Drill iii Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3703' NSL, 1196' WEL, SEC. 21, T11N. R12E, UM Top of Productive Horizon: 4077' NSL, 3464' EWL, SEC. 22, T11N, R12E, UM (OBa) Total Depth: 1870' NSL, 3427' EWL, SEC. 15, T11N, R12E, UM . STATE OF ALASKA . ALASKA ~ AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: a Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 10659 TVD 5111 7. Property Designation: ADL 028263 iii Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU W-205L2 12. Field / Pool(s): Prudhoe Bay Field / Polaris Pool 8. Land Use Permit: 13. Approximate sp~.. . Decem~r~03 14. Distance to Nearest Property: 20,460' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: X-612049 y-5958680 Zone-ASP4 16. Deviated Wells: Kickoff Depth G.¡:¡$iI19 PrOgram Size CasinQ 4-112" 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 80.9 feet W-203 is 660' away at top OA 17. Anticipated pressure (see 20 MC 25.035) t"" Max. Downhole Pressure: 2228 psig. Max. Surface Pressure: 1723 psig Qtlanti'~9fC~I'!'1!i1nt (c.f. or sacks) CouplinQ LenQth MD TVD MD TVD (includinQ staQe data) IBT 3729' 6930' 5031' 10659' 5111' Uncemented Slotted Liner 91 6955 ft Maximum Hole Angle Hole 6-3/4" WeiQht 12.6# Grade L-80 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):IEffectiveDepthMD(ft):EffectiveD epth TVD 10670 5224 NIA 10670 5224 . .' , Cemlilnt VolumE! .' ',' ,," '," ' Structural Conductor 108' 20" x 34" 260 sx Arctic Set (Approx.) 108' 108' Surface 3956' 10-3/4" 897 sx PF 'L', 352 sx Class 'G' 3985' 3180' Intermediate 7592' 7-5/8" 561 sx Class 'G' 7618' 5184' Production Liner 3152' 4-1/2" Uncemented Slotted Liner 7517' - 10669' 5176' - 5224' Liner 3497' 4-1/2" Uncemented Slotted Liner 7177' - 10674' 5113' - 5188' Perforation Depth MD (ft): 4-1/2" Slotted Section: 7700' - 10667' & perfOration Depth TVD (ft): 5189' - 5224' 4-1/2" Slotted Section: 7177' -10674' 5113' - 5188' 20. Attachments 0 Filing Fee 0 BOP Sketch a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Michael Triolo, 564-5774 Printed N7m.e Lo II Crane ....:..r ". Title Senior Drilling Engineer . Prepared By Name/Number: Signature cz,<:-C.--eA I~- Phone 564-4089 Date 12-/-..::.3 Terrie Hubble, 564-4628 I Commission Use Only Permit To Drill I API Number: I Permit Approval ·l¡~\',À... ..0 I See cover.letter for Number:2 03' -202- 50-029-23165-61-00 Date: '1\ ') Cl other reqUirements Conditions of Approval: Samples Required DYes rgJ No Mud Log RequiredD"E" Æ\Jr:eh~ Hydrogen Sulfide Measures 0 Yes 181 No Directional Survey ReqlììÆ .~. \l1:riV Other: Tëst goPE to '~çoo fÇ ( . DEe - 2 ZOO3 Approved By: Form 10-401 Revised 3/2003 Originsl Signed By Sarah Patin Alaska Oil & Gas Cons. Commistion J3Y ORDER OF Anchorage . r¡'ì 1\ ý; ~OMtyt1SSfqN~",\ I ¡'tHE COMMISSION Date ¡ ;;;ì ' ') 0:' U ~ \ I \J I i ~ r\ L Submit I, Duplicate Well Plan Summarv " Greater Prudh..2.~ BayW-205 L 1 & L2 Permit I Well Name: I W-205 L 1 and W-205 L2 Surface Location: 3,703' FSL, 1,196' FEL, Sec. 21, T11 N, R12E X = 612,048.97 Y = 5,958,680.13 W-205 L 1 OBc Target Start: 4,170' FSL, 1,741' FEL, Sec. 22, T11 N, R12E X = 616,776.04 Y = 5,959,219.64 Z = 5,058' TVDss W-205 L 1 OBc Target End: 1,869' FSL, 1,852' FEL, Sec. 15, T11 N, R12E X=616,613 Y=5,962,196 Z=5,101'TVDss W-205 L2 OBa Target Start: 4,071' FSL, 1,816' FEL, Sec. 22, T11 N, R12E X = 616,702.44 Y = 5,959,125.52 Z = 4,976' TVDss W-205 L2 OBa Target End: 1,869' FSL, 1,852' FEL, Sec. 15, T11N, R12E X = 616,613 Y = 5,962,196 Z = 5,030' TVDss I Type of Well (producer or injector): I AFE Number: I PLD5M1066 I Schrader OBc and OBa Horizontal Sidetrack Producer KBE = 80.90' I Rig: 1 Nabors 9ES I Estimated Start Date: I Dec. 51n 2003 I OBcMD I OBa MD 10,674' 10,659' Target Estimates: Estimated Reserves OBa IOBc: Expected Initial Rate OBa IOBc: Expected 6 month avg OBa IOBc: Current Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool: Original Well API #: Sidetrack API OBc #: Sidetrack API OBa #: Well Type: Current Status: H2S: Cement: BHP: BHT: Is this well frac'd? I Operating days to complete: 116.38 II Well TVDrkb: TO 15,1881 Well TVDrkb: TO 5,111 1910 II KOP I 910 KOP Max Inc. Max Inc. 7,202 6,955 Expected reserves 1.3 mmbbl Production rate: 1,865 bid Production rate: 1,135 bid -20,460' to the nearest PBU boundary line Top OA: 660' away from W-203 TD: 580' away from W-201 50-029-23165-00 50-029-23165-60 50-029-23165-61 Schrader OBd Horizontal Producer See attached Pre-rig completion schematic for details o ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) 7 -%" casing cemented 700' MD over Schrader Ma sands. Pumped -122 bbls of 15.6 ppg Class G cement. Plug bumped as per plan, expected TOC:-5,320' MD OBa: 2,125 psi @ 4,969' TVDss (8.22 ppg EMW). Actual from MDT's OBc: 2,228 psi @ 5,050' TVDss (8.48 ppg EMW). Actual from MDT's OBd: 2,248 psi @ 5,099' TVDss (8.48 ppg EMW). Actual from MDT's 101.5 of @ 5,099' TVDss (Estimated) No Draft Permit 11/25/03 Mechanical Condition W-205 Wellhead: Cellar Box Height: Nabor 9ES: Tubing: Liner: Casing Tbg. Hanger: Tree: Open Perfs: Casing Fluids: Materials Needed Production Liner: 2 x Production Liners: CQmpletion: As Contingency As Contingency As Contingency As Contingency As Contingency As Contingency " Greater Prudh~ Bay W-202 L 1 & L2 Permit FMC Gen 5 System Above MSL = 52.40' KB / MSL = 80.90' 4-16", 12.6#, L-80, IBT-M with planned chemical cut packer @ 6,440' MD. 4-16",12.6# L-80 liner top @ 7,517' MD. Surface: 10-%",45.5#, L-80, BTC to 3,985' MD (Burst: 5,210; Collapse: 2,470) Intermediate: 7-%",29.7#, L-80, BTC-M to 7,618' MD (Burst: 6,890 ; Collapse: 4,790) Liner: 4-16",12.6#, L-80, IBT from 7,517 -10,669' MD (Burst: N/A ; Collapse: N/A) FMC 11" x 4- W' with standard BPV profile Cameron 4-1/16" 5M 4-16" slotted liner in OBd sand (planned to be isolated with IBP at Pr-rig work) SW with diesel cap down to -2,200' TVD Amount 7,300' 183 each 2 each 2 each 2 assemblies Amount 6,900' 1 each 1 each 2 each 1 each 4 each 1 each 6900' 1 each Surface and Anti-Collision Issues Description 4 Y:/', 12.6#, L-80, IBT-Mod Slotted Liner 4 16" x 5 %" x 8" Straight Blade Centralizers 7-%" x 4-16" Baker ZXP Liner Top Packer 4-W' Halliburton Float Shoes Baker Level 3 Hookwall Hangers with LEM ..... De.scription 4-16" 12.6Ib/ft, L-80, BTC-M tubing Baker PRM Production Packer 7-%" X 4-16" Halliburton XN-Nipple (3.725" 10) Halliburton X-Nipple (3.813" 10) 4-W' Baker CMD Sliding Sleeve Camco 4-W' X 1" KBG-2 Gas Lift Mandrels Phoenix pressure gauge I-wire for the Phoenix gauge 4-W' WLEG or half-muleshoed joint of 4-16" IBT-M tubing Surface Shut-in Wells: W -203 and W -12 do not need to be shut-in for the rig move on and off W -205. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: I Well Name I Ctr-Ctr Distance I None Mud Program Reference MD 6-%" Production Hole Mud Properties: Interval/Density (ppg) I Stability Interval 9.2 650 - 900 I Allowable Deviation I Precautionary Comment I LVT-200 MOBM (Versa-Pro) YP I Oil : H20 Ratio I PV I API Filtrate I 18 - 25 80 : 20 15 - 20 4 - 5.5 MBT <6 2 Draft Perm it 11/25/03 Well Control " Greater Prudt:!2.e Bay W-202 L 1 & L2 Permit Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,228 psi @ 5,050' TVOss (8.48 ppg EMW). Actual from MDT's · Maximum surface pressure: 1,723 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/f!) · Planned BOP test pressure: · Planned completion fluid: 3,500 psi (7-%" casing has been tested to 3,500 psi) Estimated 9.2 ppg Brine / 6.8 ppg ~iesel 5,000 psi Working Pressure (entire stack and valves 3,500/250 psi Rams & Valves 3,500/250 psi Annular Disposal · NO ANNULAR INJECTION ON THIS WELL. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Formation Markers OA 4,891 Tops from W-205 original 2,157 8.48 Estimated OBa 4,948 Tops from W-205 original 2,115 8.22 Psi from MDT OBb 4,978 Tops from W-205 original 2,195 8.48 Estimated OBe 5,031 Tops from W-205 original 2,218 8.48 Psi from MDT OBd 5,093 Tops from W-205 original 2,246 8.48 Psi from MDT CasingfTubing Program Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. MD 1 TVDrkb MD I TVDrkb 6-3,4" 4- W' slotted 12.6# L-80 IBT 3,497 7,177' / 5,113' 10,674' /5,188' 6-3,4" 4-Y2" slotted 12.6# L-80 IBT 3,729 6,930' / 5,031' 10,659' / 5,111' Tubing 4-W'solid 12.6# L-80 IBT-M 6,901 29' / 29' 6,930' /5,031' 4 %" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. Bit Recommendations BHA Number Prod. Prod. Hole Size and Section 6-3,4" 6-3,4" Depths (MD) Bit Type Nozzles K-Revs Hours 7,177' -10,674' 6,930' - 10,659' Hycalog OSX146H + GJV Hycalog OSX146H + GJV 6x10 6x10 3 Draft Perm it 11/25/03 Survey and Logging progrJII Greater Prudh,2e Bay W-202 L 1 & L2 Permit I 6-3,4" Hole Sections: I Geosteer through Schrader OBc and OBa sands While Drilling: MWD / GR / Res / PWD / Azi. Den / Neu / ABI (Den/Neu recorded only) Motors and Required Doglegs BHA# 1 & 2 Motor Size and Motor Required 4-3,4" Anadrill A475M4560XP Mud motor, with 1.5" ABH with 6.75" stabilizer (AIM) Flow Rate 250-300 gpm RPMs 60-80 Required Doglegs Maximum build: 10.0°/100' 4 Draft Permit 11/25/03 Greater Prudhoe Bay W-202 L 1 & L2 Permit . ...., .,' DrilhnQ Hazards and Contin'Qencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be underpressured based on the MDT samples. a. OBa: 2,125 psi @ 4,969' TVOss (8.22 ppg EMW). Actual from MDT's b. OBc: 2,228 psi @ 5,050' TVOss (8.48 ppg EMW). Actual from MDT's c. OBd: 2,248 psi @ 5,099' TVOss (8.48 ppg EMW). Actual from MDT's II. Hydrates and Shallow gas A. Gas hydrates will not be present on this well as the zones which contain hydrates are already cased off in this well. III. Lost Circulation/Breathing A. Lost circulation is unlikely within the Schrader interval. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's Le. Seabee. IV. Kick Tolerance/lntegrity Testing A. The 10-%" casing has been cemented to surface. B. The 7-%" casing has been cemented with 15.61b/gal tail cement to 700' MO above the Ma sand -5,320' MD. C. The Kick Tolerance for the production hole laterals is infinite with 9.2 ppg mud, 11.5 ppg FIT, and an 8.4 ppg pore pressure. If the FIT is less then 11.5 ppg EMW, then the kick tolerance will be < infinite. D. Integrity Testing 7-%-in Window 7-% -in Window 20-ft minimum from top window 20-ft minimum from top window FIT FIT 11.5 minimum 11.5 minimum V. Stuck Pipe A. We do not expect stuck pipe, B. There could be slight differential sticking across the reservoir while running the slotted liners. Keep the liners moving as much as possible and run one centralizer per joint to help with standoff. VI. Hydrogen Sulfide A. W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W-12: less than 8 ppm b. W-203: 0 ppm C. Adjacent producers at TO: a. W -200: 0 ppm O. The maximum recorded level of H2S on the pad was under 20 ppm. VII. Faults There are no seismically visible faults to cross while drilling the laterals. It is possible to encounter sub-seismic faults along the proposed well path. If a fault throws us out of section steer up as fast as possible to determine where we are within the section. This will make it easy to lowside OH sidetrack to get back on course. CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 5 Draft Permit 11/25/03 Greater Prudhoe Bay W-202 L 1 & L2 Permit Drill a!d Complete Procedure s!tmary Planned Pre-Riq Work: 1. CTU Work: a. Please have PE discuss this job with Donn Schmohr prior to rig-up. b. Run in hole with nozzle. Hot oil tubing to remove paraffin. Tag for fill in slotted horizontal liner. Do not take excessive risks to reach TD. Consult with Donn Schmohr if significant fill is found and before attempting any fill clean-out. i. On 11/20/03 an attempt to hot oil the tubing resulted in lock-up at 28 Bbls. However, after soaking, the well was successfully POP'd and tested. Hot oiling is likely required to successfully run logs and chemically cut the tubing. ii. It is desirable to ascertain whether sand fill is occurring in liner. This would be useful information for future multilateral screen designs. iii. Since this well was drilled with oil based mud to prevent formation damage, we are reluctant to introduce water onto the formation for a clean-out. Any fill clean-out would probably need to be with diesel or under- balanced with gas lift or nitrogen. c. Run memory production logs as follows: i. Verify that well is in test prior to logging. Save trend data for log analysis. ii. Make up PDS 1-11/16" memory GR-Spinner-Temperature-Pressure log. · The objective of the logs are to determine how much length of lateral is productive in a Schrader Bluff well. · Note there is an undersized 2.75" XN nipple in the 4-1/2" liner at 7627'. Cautiously approach XN nipple. · Consult with PDS to choose proper centralizers (to get into 2.75" XN) and spinner (2-1/8" in-line or 2-1/8" x 4-1/2" folding). · Don't want to take excessive risks of losing a fish to obtain production logs. iii. Record 10 min. stop counts in 4-1/2" tubing at 6500' and 4-1/2" liner at 7600',8100',8600',9100',9600', 10100',10500'. iv. Make three round trip flowing passes of the slotted liner from 7630' to 10500' (one trip each at 30, 60, and 90 fpm). · Log flowing passes up to, but not thru XN nipple at 7627', to prevent damaging logging tool or losing a fish. d. Set 2-1/2" Baker Inflatable Bridge Plug in the solid 4-1/2" liner at - 7600' MD. i. The objective of the IBP is to protect the OBd lateral interval from sidetracking and drilling damage as well as provide drilling well control. The IBP will have to be retrieved back through multi-lateral junctions with ID's of 3.560". ii. The IBP should be set in the solid 4-1/2" liner (7550' - 7627' MD) above the 2.75" XN (7627' MD), but below the liner tie-back sleeve and cross-overs. Drilling will later set a whipstock in the liner top tie-back sleeve. e. Liquid pack the tubing and inner annulus with seawater and freeze protect each to 2500' with diesel. f. Pressure test IBP to 1000 psi. g. Shut-in production wing valve and inner annulus valves. 2. Slickline Work: a. Pull SPMG from GLM #1 at 6508'. b. Open sliding sleeve at 6416'. i. If sliding sleeve won't open, then in Step 3c, below, insert a circulating valve instead of a dummy. The objective is to get a circulation point as deep as possible. c. Pull LGLV and dummy-off GLM #2 at 6306'. d. Pull LGLV and dummy-off GLM #4 at 3015'. 3. Electric Line Work: a. Consult with Baker prior to rig-up to identify from the Driller's Tally the desired cut zone for the Baker Premier packer. i. A generic Baker Premier Packer schematic will be sent to the Wireline & Completion Coordinator. ii. A similar cut on well V-202's packer did not immediately result in the ability to circulate around the packer. Thus on this well, it is recommended to punch the tailpipe and open the sliding sleeve above the packer. 6 Draft Permit 11/25/03 '.,,,...., " , Greater Prudl],ge Bay W-202 L 1 & L2 Permit b. Consult with SChlumbel prior to rig-up to verify that the right TubifÌ1:¡r'uncher charge is chosen to perforate the 4-1/2" tubing, but not the 7-5/8" casing. c. Run SCMT-GR-CCL-Jewelry Log from maximum allowable depth (_730 at 7150') to 6100' (above packer). i. The objective of this log is to correlate the jewelry for chemical cutting of the Baker Premier packer and punching the tubing tail and to identify if any cementing defects exist in the sidetrack intervals. d. Punch tubing tail from 6449' - 6451 " ie 2' -4' feet below the packer. i. Schlumberger Tubing Puncher Charge, 4 JSPF, 2', 00 phasing, decentralized. ii. The objective of punching the tubing tail is to allow the gas bubble behind the tailpipe to migrate to the surface and be bled off safely. We do not want to punch the casing. e. Chemically cut the Baker Premier packer as per Baker's instructions. i. There is a 14" cut zone for this packer. Baker has a well tally and spreadsheet for this in their slope shop. ii. The objective of cutting the packer is to allow the packer to be pulled without milling. 4. Other Work: a. Bleed gas off the IA and tubing and lubricate in diesel to liquid pack each. b. PPPOT-IC & PPPOT-T. c. Set BPV in wellhead. d. Remove the wellhouse and level the pad in preparation for the rig move. Drillinq Riq Return Operations: 1. MIRU Nabors 9ES. Circulate out diesel freeze protection over to seawater. Verify the well is dead. 2. Set TWC. Nipple down tree. Nipple up and test BOPE. 3. Pull and lay down the 4- W' tubing and Baker PRM packer. 4. MU clean-out BHA with 4" DP and flat bottom mill (or used bit) / Upper Watermelon String Mill / boot baskets / GR / etc. RIH to OBd liner top packer, tag top of liner tie back sleeve, circulate and condition wellbore as required. Pump hot oil to remove excess paraffin if needed. 5. Clean pits for displacement. Displace over to 9.2 ppg Versapro MOBM. POOH to near OBc window depth, log into top OBc (RA marker) with GR, log across the OBa window as well. POOH, LD cleanout assembly. 6. PU the 7-%" whipstock assembly. Set the whipsock on the OBd liner top packer such that the top of the window is near the top of the OBc sand (planned KOP: 7,177' MD). Orient whipstock to highside. Shear off Whipstock & mill window. Perform FIT. POOH 7. RIH with 6-%" drilling assembly (with MWD / GR / Res / Azimuthal Den recorded / Neu recorded / AIM) to whipstock. Directionally drill to 6-%" TD. Planned TD is 10,674' MD. Circulate and condition mud and perform wiper trip. POOH. 8. Pull whipstock #1. 9. Run and set 4-W' slotted liner and hook hanger, POOH and LD liner running string. 10. Run Baker Hook Hanger Lateral Entry Module #1 with ZXP liner top packer, POOH 11. PU the 7-%" whipstock assembly. Set the whipsock on the OBc liner top packer such that the top of the window is near the top of the OBa sand (planned KOP: 6,930' MD). Orient whipstock to highside. Shear off of Whipstock and mill window. Perform FIT. POOH 12. RIH with 6-%" drilling assembly (with MWD / GR / Res / Azimuthal Den recorded / Neu recorded / AIM) to whipstock. Directionally drill to 6-%" TD. Planned TD is 10,659' MD. Circulate and condition mud and perform wiper trip. POOH. 13. Pull whipstock #2. 14. Run 4-W' slotted liner and hook hanger, POOH and LD liner running string. 15. Run Baker Hook Hanger Lateral Entry Module #2 with ZXP liner top packer. 16. Clean pits for displacement. Displace over to 9.3 ppg KCL brine. POOH 17. MU 4-W' 12.6# BTM-M, L-80 completion assembly and RIH. See completion schematic for details. 18. Land tubing hanger and run in lockdown screws. 19. Reverse in brine with Corexit to protect the annulus. 20. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 21. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 22. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7-%" casing annulus valves. 23. Install BPV. Secure the well and rig down / move off Nabors-9ES. Post-Riq Work: 7 Draft Perm it 11/25/03 1. MIRU slickline. Pull the ball anld / RHC plug. 2. Pull out DCK-1 shear valve, install GLV in all of the other mandrels as per the PE. Greater Prudh.Q.e Bay W-202 L 1 & L2 Permit Job 1: MIRU: Critical Issues: ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ W-203 and W-12 will not need to be shut in at the surface prior to the W-205 rig move. The well houses may not need to be removed off of W -203 and W -12 depending on how comfortable the rig team feels moving over W -205. All surface flowlines and gas lift lines will not need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearby Wells W-203 W-12 Distance to Target Well 34.97 34.94 Rig N9ES Wellhead Separation 4.97 4.94 *N9ES requires minimum 15' centers, well houses must be removed & wells shut-in at surface if within 30' of target well* ~ W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: W -12: less than 8 ppm W-203: 0 ppm Adjacent producers at TD: W-200: 0 ppm ~ The maximum recorded level of H2S on the pad was under 20 ppm. .""..<- """-.'.--qµ>' Job 2: Decompletion Critical Issues ~ Premier Packer: The inner sleeve of the Baker Premier packer at 7,517' MD has been cut during the pre-rig work and should be ready to pull out of the hole with the tubing. The packer will require -30K Ibs overpull at the packer in order to release the slips and element. Ensure Baker representative is on location prior to pulling tubing hanger. ~ Tubing Condition: The 4-Y2" tubing was run back in September 2003 so it should be in very good condition. Limit over-pull on tubing string to 80% of tensile strength (4-Y2" = 230,400 Ibs tube and IBT connection is equal to 100% of the tube strength), and if the tubing will not pull free on initial attempt, it may be necessary to RU e-line to make a second cut on the packer and or the tubing directly above the packer. ~ Wellhead: The wellhead is a FMC Gen 5 USH with 10-3,4" mandrel casing hanger, a 7-%" mandrel casing hanger and a 4-Y2" tubing hanger with 4-Y2" TClllift threads. ~ NORM Testing: NORM test all retrieved well head and completion equipment even though there should be little scale. Send tree to APC Valve shop for repair and/or refurbishment or have the tree inspected in the cellar area if convenient. Send the adapter flange and tubing hanger to Tool Services for inspection. Send the tubing to Tuboscope to inspect the threads and redope. The tree and tubing hanger should be re-used on this well if possible. The tubing should also be reused on this well if possible. ~ Tubel Pressure Gauge: It is planned to rerun this downhole gauge with the re-completion of this well, therefore it is extremely important to handle the sub very delicately. When it is pulled out of the ground it will need to be refurbished with new batteries and checked out by Tubel Technologies Inc. prior to rerunning it. ~ Fluid Level: Monitor the well to ensure the fluid column is static, prior to pulling the completion. The OBd lateral will be isolated with a pressure tested IBP set in the tubing below the liner top packer at 7,600' MD by coil. Thus, there should be no problem with losses during the decompletion and or drilling of the subsequent laterals. It is possible that the reservoir pressure within the OBd sand section has been reduced below the MDT recorded pressure due to offtake. 8 Draft Permit 11/25/03 " Greater Prudl12.e Bay W-202 L 1 & L2 Permit Job 3: Mill OBc Window Hazards and Contingencies: ~ Equipment Measurements: Verify measurements of all assemblies prior to picking up ~ Whipstock Orientation I Depth: The whipstock should be oriented to ± 150 left of high side. This will allow for a better window and allow for easier access into the window with the bent joint on the end of the 4-W' liner. Exact window depth to be based off of actual logs. Depth control will be very critical on this window. This window will require space out tubulars below the whipstock to allow the whipstock to land out on the ZXP liner top packer used on the OBd lateral. A discussion will need to take place to determine the best way to gain accurate depth control for the window setting depth. Planned depth is 7,177' MD (5,113' TVD) with RA tag @ 7,119' MD.. ~ Window Milling: It is critical to have a smooth uniform full length window. Extra time spent on the window milling will be well worth it when it comes time to land out the hook hanger. Follow the BOT representative during the milling of the window. ~ Whipstock Setting: On past wells, only one shear was observed during the whipstock setting procedure. This introduced some uncertainty as to whether or not the slide was oriented correctly. The most likely explanation for this is that on high angle wells cased hole friction may cause the 15-20K bottom trip and the 35K whipstock shear to occur simultaneously. ~ FIT: An FIT of 11.5 ppg EMW is required at the 7-%" window. This will cover the expected normal ECD range for this section. The kick tolerance for the 6-%" open hole section would be an infinite influx assuming a kick from the Schrader anywhere along the lateral. This is a worst case scenario based on an 8.8 ppg pore pressure gradient, a fracture gradient of 11.5 ppg at the 7-%" window, and 9.2 ppg MOBM in the hole. .-. 0'_" Job 4: Drill 6-%" Lateral COBc Sand) Critical Issues ~ MOBM: The production interval will be drilled with a 9.2 ppg VersaPro MOBM. This fluid has been utilized before on past wells, however it has inherent HSE issues associated with its handling and thus all safety procedures should be refreshed. Review the BP MOC, the Nabors Hazard Analysis, and the MI drilling fluids program prior to utilizing this fluid. ~ Geosteering: Geosteering in this lateral interval is expected to be the most challenging aspect of this well. Anadrill AIM will be used and should help mitigate some of this challenge. A 1.50 bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this interval. There will be a rigsite geologist on location to help with interpretations. o The OBd sand lateral has already been drilled on this well thus providing some dip and faulting information for this lateral. The directional plan reflects this knowledge but should only be used as a guide and real time adjustments will need to be made to stay within the sand. If for whatever reason we become lost, steer up as hard as possible to determine where within section we are. Once we are able to determine where we are, then we can go back and OH sidetrack. ~ Surveying: Survey density is critical to achieve vertical positional certainty. It is recommended to survey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This survey density should alleviate the errors associated with vertical section creep. ~ ECD/Hole Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings will tend to dune up at the window due to hole geometry. Planned ECD hard line 12.0 ppg EMW. ~ Target Constraint: The West side of the polygon is defined as a hard line due to proximity to a fualt. The North, South and East sides of the polygon are defined by reservoir off-take considerations and are not strict hard lines. Job 5: Retrieve Whipstock #1 9 Draft Permit 11/25/03 Critical Issues: ~ Orientation of Retrieval Hook: When scribing to align the MWD to the hook remember that the orientation of the hook will need to be 1800 from the orientation of the whipstock. ~ Whipstock Retireval: This whipstock must be retrieved in order to land the hook hanger in the window. Extra time should be taken in order to ensure successful retrieval of the whipstock with the hook due to potential problems associated with the back-up retrieval methods. ~ Magnet: We will run a Baker string magnet in the assembly to help clean up any metal left behind after the milling and drilling of this lateral to ensure that we do not get hung up high while running the Hook and the LEM. . Greater Prudl],g"e Bay W-202 L 1 & L2 Permit Job 6: Run 4-%" Slotted Liner with Hook Han~er and LEM(OBc Sand) Critical Issues ~ Liner to bottom: It is imperative that we get this liner near bottom to allow for proper placement of the Hook Hanger. Liner near bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reserves possible for this section length. If problems are encountered while RIH with the liner stop and POOH and make a cleanout run with a hole opener. ~ Centralizer Placement (5-%" OD): o See centralizer strategy on page 4. Do not run any on the first two joints. ~ 4-%" Rams: Keep VBR's in. Can also utilize annular if necessary. ~ Have a Baker completion specialists onsite to engineer and supervise this liner job. 4 W', 12.6#, L-80 IBT 100% 80% ID (drift) 3.833 Collapse N/A N/A Burst N/A N/A Tensile 288,OOOlbs 230,400 Ibs ~ Connection make-up information: 4-%" IBT - makeup to position Job 7: Mill OBa Window Hazards and Contingencies: ~ Equipment Measurements: Verify measurements of all assemblies prior to picking up ~ Whipstock Orientation I Depth: The whipstock should be oriented to ±15° left of high side. This will allow for a better window and allow for easier access into the window with the bent joint on the end of the 4-W' liner. Exact window depth to be based off of actual logs. Depth control will be very critical on this window. This window will require space out tubulars below the whipstock to allow the whipstock to land out on the ZXP liner top packer used on the OBc lateral. A discussion will need to take place to determine the best way to gain accurate depth control for the window setting depth. Planned depth is 6,930' MD (-5,031' TVD) with RA tag @ 6,876' MD. ~ Window Milling: It is critical to have a smooth uniform full length window. Extra time spent on the window milling will be well worth it when it comes time to land out the hook hanger. Follow the BOT representative during the milling of the window. ~ Whipstock Setting: On past wells, only one shear was observed during the whipstock setting procedure. This introduced some uncertainty as to whether or not the slide was oriented correctly. The most likely explanation for this is that on high angle wells cased hole friction may cause the 15-20K bottom trip and the 35K whipstock shear to occur simultaneously. ~ FIT: An FIT of 11.5 ppg EMW is required at the 7-%" window. This will cover the expected normal ECD range for this section. The kick tolerance for the 6-%" open hole section would be an infinite influx assuming a kick from the Schrader anywhere along the lateral. This is a worst case scenario based on an 8.8 ppg pore pressure gradient, a fracture gradient of 11.5 ppg at the 7-%" window, and 9.2 ppg MOBM in the hole. 10 Draft Permit 11/25/03 Job 7: Drill 6-%" Lateral (OBa S.) Greater Prud~,e Bay W-202 L 1 & L2 Permit \ " " , Critical Issues ~ MOBM: The production inteNal will be drilled with a 9.2 ppg VersaPro MOBM. This fluid has been utilized before on past wells, however it has inherent HSE issues associated with its handling and thus all safety procedures should be refreshed. Review the BP MOC, the Nabors Hazard Analysis, and the MI drilling fluids program prior to utilizing this fluid. ~ Geosteering: Geosteering in this lateral inteNal is expected to be the most challenging aspect of this well. Anadrill AIM will be used and should help mitigate some of this challenge. A 1.50 bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this inteNal. There will be a rigsite geologist on location to help with interpretations. o The OBd and OBc sand laterals have already been drilled on this well thus providing some dip and faulting information for this lateral. The directional plan reflects this knowledge but should only be used as a guide and real time adjustments will need to be made to stay within the sand. If for whatever reason we become lost, steer up as hard as possible to determine where within section we are. Once we are able to determine where we are, then we can go back and OH sidetrack. ~ Surveying: SUNey density is critical to achieve vertical positional certainty. It is recommended to sUNey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This sUNey density should alleviate the errors associated with vertical section creep. ~ ECD/Hole Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings will tend to dune up at the window due to hole geometry. Planned ECD hardline 12.0 ppg EMW. ~ Target Constraint: The North end of the polygon is defined as a hard line due to proximity to a large fault. The West, South and East sides of the polygon are defined by reseNoir off-take considerations and are not strict hard lines. ""«.~~.""·.W~".~ ~~,. Job 8: Retrieve Whipstock #2 Critical Issues: ~ Orientation of Retrieval Hook: When scribing to align the MWD to the hook remember that the orientation of the hook will need to be 1800 from the orientation of the whipstock. ~ Whipstock Retireval: This whipstock must be retrieved in order to land the hook hanger in the window. Extra time should be taken in order to ensure successful retrieval of the whipstock with the hook due to potential problems associated with the back-up retrieval methods. ~ Magnet: We will run a Baker string magnet in the assembly to help clean up any metal left behind after the milling and drilling of this lateral to ensure that we do not get hung up high while running the Hook and the LEM. -".~.,."=,..,,,,.,.,« ._~A Job 9: Run 4-112" Slotted Liner with Hook Hanqer and LEM(OBa Sand) Critical Issues ~ Liner to bottom: It is imperative that we get this liner near bottom to allow for proper placement of the Hook Hanger. Liner near bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reseNes possible for this section length. If problems are encountered while RIH with the liner stop and POOH and make a cleanout run with a hole opener. ~ Centralizer Placement (5-%" OD): o See centralizer strategy on page 4. Do not run any on the first two joints. ~ 4-112" Rams: Keep VBR's in. Can also utilize annular if necessary. ~ Have a Baker completion specialists onsite to engineer and supeNise this liner job. 4112",12.6#, L-80 IBT-M 100% ID (drift) 3.833 Collapse N/A Burst N/A I Tensile 288,000 Ibs Draft Permit 11/25/03 11 Greater Prudl)ge Bay W-202 L 1 & L2 Permit '- 80% N/A " Ñ/ A 1230,4001bs ~ Connection make-up information: 4-%" IBT - makeup to position Job 12: Run 4·"W' Completion: Critical Issues ~ Thread Dope: SOL 2000 NM or SOL 2000 is the SP approved thread compound for Carbon API connections. All 1ST -M pipe should arrive on location with one of these two thread compounds. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. ~ Shear Valve: We will run a DCK shear valve in the GLMdirectly above the production packer to utilize for freeze protecting after the production packer is set. ~ Phoenix Pressure Gauge: A downhole pressure gauge with control lines will be run on this well. Ensure that a Saker Centrilift hand and a Schlumberger completions hand (Cameo) is on location prior to PU tubing to allow them time to get all of their equipment in order and confirm its working condition. o HSE: Sheaves hung in the derrick and I-wire spools will be utilized during the running of the completion, make sure that this non-routine operation is discussed in length at the PJSM with all relevant personnel prior to PU completion. o Place 1 cannon clamp per joint for the first 10 joints followed by 1 clamp per every 2 joints to surface. o Test the I-wire connection at regular intervals while running in the hole. If the I-wire is damaged in any way contact ODE. ~ Tubel Pressure Gauge: It is planned to rerun this downhole gauge with this completion. When it is pulled out of the ground it will need to be refurbished with new batteries and checked out by Tubel Technologies Inc. prior to rerunning it. No I-wire is needed with this gauge, however it will be necessary to install a receiver for the downhole gauge to the tubing just below the tubing hanger and run a control line from the receiver through a control line port in the tubing hanger. ~ Contact the Field AOGCC Rep with 24 hours of notice to witness the tubing and annulus pressure tests. """"""'>WI..".,........"". Job 13: ND/NUlRelease Riq: Critical Issues ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. 12 Draft Perm it 11/25/03 ..-. PRE-RIG -DECOMPLETI. W-205 OBd Only ~ TREE: FMC 4-1/16" 5M Orig KB elev (N-9ES) = 28.5' WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI?" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" x 4-1/2" tubing hanger with control line ports 11" X 4-1/16" Adaptor Flange ... 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 109' ---- Halliburton X-Nipple (3.813" ID) I 2,620' MD I .A .... 10-3/4",45.5# L-80 BTC Csg @ 3,985' MD All Mandrels dummied off. 2,500' TVD, 2 & 4 joints above the sliding sleeve, & just above WLEG 7-5/8",29.7#, L-80. BTC-I\II Casing Drift: 6.75" Casing 10: 6.875" 4.5" Baker CMD sliding sleeve with 3.813" ID ..' Opened for circulation 7-5/8" X 4-1/2" Baker PRM Packer Holes punched in the tubing below the packer for trapped gas ?alliburton X-Nipple (3.813" ID) Halliburton XN-Nipple (3.725" ID) --- 4-1/2", 12.6 I blft , L-80, BTC-M Coupling 00: 5.2" DriftllD: 3.833"/3.958" DATE 7/1/2003 12/1/2003 .' 4.5" WLEG I -6,589' I ,----- 9.2 PPG Versapro MOBM below Completion Tubel Downhole Pressure gauge Halliburton XN-Nipple (2.75" ID) -7,627' -~··"·-'·;jlñ~ ~ :'.~¡HJ 6-3/4" OBd Lateral7,618 -10,669'1 Baker ZXP Liner ToplTie back Sleeve @ 7,517' MD Baker 2.5" Inflatable Bridge Plug @ 7,600' MD 7-5/8" Casing Shoe @ 7,618' MD- REV. BY COMMENTS GI6J},te;: MIK TRIOLO MIK TRIOLO OBd Lateral Completion OBd Pre-Rig Decompletion Schematic Polaris WELL: W-205 API NO: 50-029-23165-00 TREE: FMC 4-1/16" 5M GenS T .& packoff wI with control line ports Orig KB alav (N-9ES) ::: 28.5' A. 20" X 34" 215.5 Iblft, AS3 ERW Insulated 109' halliburton X-Nipple (3.813"ID) I 4-1/2", 12.6 Iblft, L-80, BTC-M .;II. 10.. 10-3/4",45.5# L-80 BTC 3,985' MD 7-5/8" X 5-112" Baker PRM Packer Halliburton X-Nipple (3.613" ID) 4.5" WLEG I Baker ZXP Liner Top Packer 8. Hanger @ 6,900' MD 9.2 PPG Versapro MOBM below Completion 6-3/4" OBa Lateral Hookwan in 7-5/8" Wen Inclination Baker ZXP Liner Top Packer 8. Hanger @ 7,147' MD 6-3/4" OBe latera! I Baker Hookwall Window in 7-5/8" Welllnc!ination Baker ZXP Liner Top Packer 8. Hanger@ 7,517' MD 7 -5/8", Drift: ID: 6.875" Raker 2.5" Inflatable Bridge Plug @ 7,600' M L-80, BTC-M 7-5/8" Shoe 7,618' MD ;¿ 6-3/4" OBd Lateral DATE REV. BY COMMENTS APi NO: 50-029-23165..00 50..029-23165-60 !\III.. 50-029-23165-61 121112003 MIl< TRIOLO level 3 Multi-Lateral, 4-1/2" GL Completion W-205L2 (P4) Proposal Schlumberuer Report Date: November 24, 2003 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 1.560° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 It, E 0.000 It Structure I Slot: W-PAD 1 W-205 Feasibility 8' tudy TVD Reference Datum: Rotary Table Well: W-205 TVD Reference Elevation: 80.9 It relative to MSL Borehole: Plan W-205L2 OBa Sea Bed 1 Ground Level Elevation: 47.830 It relative to MSL UWUAPI#: 500292316561 Magnetic Declination: 25.233° Survey Name I Date: W-205L2 (P4) 1 November 24, 2003 Total Field Strength: 57558.945 nT Tort 1 AHD I DDII ERD ratio: 251.763° 18128.12 It 16.630 11.59C Magnetic Dip: 80.808° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 15, 2003 e Location LatlLong: N 70.29605863, W 149.09267577 Magnetic Declination Model: BGGM 2003 Location Grid N/E YIX: N 5958680.130 ItUS, E 612048.970 ItUS North Reference: True North Grid Convergence Angle: -+D.85420613° Total Corr Mag North·> True North: +25.233° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head I Comments Measured Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latitude Longitude Depth Section (II) (deg) (deg ) (II) (II) (II) (II) (II) (deg/100 II) (deg/100 II) (deg/100 fI) (deg) (flUS) (flUS) Top Whipstock 6929.71 67.45 54.06 5030.90 4950.00 262.16 143.92 4344.98 3.60 2.38 -2.95 O.OOG 5958888.80 616390.94 N 70.29644839 W 149.05749611 Base Whipstock 6941.71 69.37 54.06 5035.32 4954.42 268.95 150.4 7 4354.01 16.00 16.00 0.00 O.OOG 5958895.48 616399.87 N 70.29646626 W 149.05742293 KOP Crv 11/100 6954.71 69.37 54.06 5039.90 4959.00 276.35 157.61 4363.86 0.00 0.00 0.00 -1.28G 5958902.76 616409.61 N 70.29648575 W 149.05734314 7000.00 74.35 53.95 5053.99 4973.09 302.58 182.90 4398.67 11.00 11.00 -0.25 -1.24G 5958928.56 616444.04 N 70.29655478 W 149.05706119 7100.00 85.35 53.71 5071.59 4990.69 362.73 240.91 4478.01 11.00 11.00 -0.24 -1.20G 5958987.74 616522.49 N 70.29671313 W 149.05641854 7200.00 96.34 53.48 5070.12 4989.22 424.14 300.16 4558.36 11.00 11.00 -0.23 -1.21G 5959048.18 616601.95 N 70.29687487 W 149.05576767 End Crv 7231.20 99.78 53.41 5065.75 4984.85 443.21 318.56 4583.17 11.00 11.00 -0.23 O.OOG 5959066.95 616626.48 N 70.29692509 W 149.05556666 Crv 11/100 7238.73 99.78 53.41 5064.4 7 4983.57 447.79 322.98 4589.12 0.00 0.00 0.00 -177.61G 5959071.46 616632.37 N 70.29693716 W 149.05551845 7300.00 93.04 53.13 5057.63 4976.73 485.51 359.38 4637.89 11.00 -10.99 -0.46 -177.64G 5959108.57 616680.58 N 70.29703651 W 149.05512339 W-205 OBa T2 7327.67 90.00 53.00 5056.90 4976.00 502.72 376.00 4660.00 11.00 -10.99 -0.45 -97.83G 5959125.52 616702.44 N 70.29708188 W 149.05494431 7400.00 88.92 45.12 5057.58 4976.68 551.55 423.36 4714.59 11.00 -1.49 -10.90 -97.76G 5959173.68 616756.31 N 70.29721116 W 149..06 End Crv 7436.37 88.38 41.15 5058.44 4977.54 578.74 449.88 4739.44 11.00 -1.48 -10.90 O.OOG 5959200.57 616780.76 N 70.29728358 W 149. 70 Crv 6/100 7692.54 88.38 41.15 5065.67 4984.77 776.07 642.70 4907.95 0.00 0.00 0.00 -90.45G 5959395.86 616946.37 N 70.29781005 W 149.0 524 7700.00 88.38 40.70 5065.88 4984.98 781.83 648.33 4912.84 6.00 -0.05 -6.00 -90.43G 5959401.56 616951.17 N 70.29782542 W 149.05289568 7800.00 88.34 34.70 5068.75 4987.85 862.52 727.38 4973.94 6.00 -0.04 -6.00 -90.26G 5959481.51 617011.08 N 70.29804127 W 149.05240048 7900.00 88.32 28.70 5071.66 4990.76 948.92 812.38 5026.44 6.00 -0.02 -6.00 -90.09G 5959567.28 617062.30 N 70.29827340 W 149.05197490 8000.00 88.32 22.70 5074.59 4993.69 1040.10 902.41 5069.77 6.00 0.00 -6.00 -89.91G 5959657.94 617104.28 N 70.29851928 W 149.05162359 W-205 OBa Tgt 2.5 8044.93 88.33 20.00 5075.90 4995.00 1082.35 944.24 5086.12 6.00 0.01 -6.00 -90.53G 5959700.00 617120.00 N 70.29863351 W 149.05149098 8100.00 88.30 16.69 5077.52 4996.62 1135.04 996.48 5103.44 6.00 -0.05 -6.00 -90.43G 5959752.49 617136.54 N 70.29877619 W 149.05135041 8200.00 88.27 10.69 5080.52 4999.62 1232.72 1093.55 5127.09 6.00 -0.04 -6.00 -90.25G 5959849.89 617158.74 N 70.29904134 W 149.05115836 End Crv 8221.36 88.26 9.41 5081.16 5000.26 1253.83 1114.57 5130.82 6.00 -0.02 -6.00 O.OOG 5959870.96 617162.15 N 70.29909875 W 149.05112807 Crv 6/100 8588.35 88.26 9.41 5092.30 5011.40 1617.22 1476.45 5190.79 0.00 0.00 0.00 -87.59G 5960233.67 617216.72 N 70.30008728 W 149.05064039 8600.00 88.29 8.71 5092.65 5011.75 1628.77 1487.95 5192.63 6.00 0.25 -6.00 -87.57G 5960245.19 617218.38 N 70.30011870 W 149.05062547 Well Design Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) W-205IW-205IPlan W-205L2 OBa1W-205L2 (P4) Generated 11/24/2003 10:08 AM Page 1 of 2 I Comments Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Lat~ude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg/100 ft) (deg/100 ft) (deg) (ftUS) (ftUS) W-205 OBa T3 8680.23 88.50 3.90 5094.90 5014.00 1708.67 1567.64 5201.43 6.00 0.26 -6.00 -87.96G 5960325.00 617226.00 N 70.30033639 W 149.05055371 8700.00 88.54 2.71 5095.41 5014.51 1728.42 1587.37 5202.57 6.00 0.22 -6.00 -87.93G 5960344.74 617226.85 N 70.30039029 W 149.05054437 8800.00 88.77 356.72 5097.76 5016.86 1828.29 1687.30 5202.08 6.00 0.22 -6.00 -87.79G 5960444.64 617224.86 N 70.30066328 W 149.05054783 8900.00 89.01 350.72 5099.70 5018.80 1927.30 1786.64 5191.14 6.00 0.24 -6.00 -87.67G 5960543.79 617212.45 N 70.30093467 W 149.05063582 9000.00 89.25 344.72 5101.22 5020.32 2024.34 1884.29 5169.89 6.00 0.25 -6.00 -87.58G 5960641.11 617189.74 N 70.30120151 W 149.05080739 End Cry 9078.63 89.46 340.01 5102.11 5021.21 2098.58 1959.21 5146.08 6.00 0.26 -5.99 O.OOG 5960715.66 617164.82 N 70.30140621 W 149.05099980 Crv 6/100 9368.50 89.46 340.01 5104.86 5023.96 2368.17 2231.59 5047.00 0.00 0.00 0.00 60.03G 5960986.52 617061.70 N 70.30215054 W 149.05180076 W-205 OBa 14 9373.29 89.6(} 340.26 5104.90 5024.00 2372.63 2236.10 5045.37 6.00 3.00 5.20 61.25G 5960991.00 617060.00 N 70.30216286 W 149.05181393 End Cry 9377.89 89.73 340.50 5104.93 5024.03 2376.92 2240.44 5043.82 6.00 2.89 5.26 O.OOG 5960995.31 617058.39 N 70.30217470 W 149.05182642 TO I 4-112" Lnr 10658.66 89.73 340.50 5110.90 5030.00 3572.14 3447.74 4616.34 0.00 0.00 0.00 O.OOG 5962196.00 616613.00 N 70.30547370 W 149.0.50 Leqal Description: Northinq IY) [ftUS] Eastinq IX) [ftUS] Surface: 3703 FSL 1197 FEL S21 T11 N R12E UM 5958680.13 612048.97 W-205 OBa T2 : 4077 FSL 1816 FEL S22T11N R12E UM 5959125.52 616702.44 W-205 OBa Tgt 2.5: 4645 FSL 1388 FEL S22 T11N R12E UM 5959700.00 617120.00 W-205 OBa T3: 5268 FSL 1272 FEL S22 T11N R12E UM 5960325.00 617226.00 W-205 OBa T4: 657 FSL 1426 FEL S15 T11 N R12E UM 5960991.00 617060.00 TO 14-1/2" Lnr I BHL: 1869 FSL 1852 FEL S15 T11N R12E UM 5962196.00 616613.00 e WellOesign Ver 3.1 RT-SP3.03-HF2.03 Bld( do31 rt-546 ) W-205\W-205\Plan W-205L2 OBa\W-205L2 (P4) Generated 11/24/2003 10:08 AM Page 2 of 2 4800 g 0 0 ':'I: g ~ II Q) ro 5200 () (f) 0 > I- ,.,........"...HH..'" -205 WEll MagoeticF'arameters Model- BGGM 2003 W-205L2 (P4) Dip- 80.808' Mag Dec' +25.233' 400 .....,.,......,....,...... 800 KOP Cry 11/109 Cry 11/100 ¡ ~ 'T / /T·~n ¡t"'. '-, . ~ . . . Base WhipStock Top WhiPStOCk --......:..,.. ~., ·~..-'fi'Pn:r"~·"·....·.....··· 400 800 FIELD I StßaceLocalion Date: Dacember15, 2003 Lat N701745.811 FS: 57558,90T Lon: W149533.633 1200 \~n~'· Prudhoe Bay Unit - WOA NAD27 Alaska Slate PlanólS, Zone 04, US Feet Northing' 5958680.13 nus Grid Conv: +0.65420613' Easling" 612048.97 n.US Scale Fact; 0.9999142£22 1600 2000 Schlumbørgør · . . ..;........."....H......................,.....................................,......",."........,. · . . · . . · . . · . . · - . · . . · . . · . . · . . · . . · . · . · . · . · . · . · . · . - . · . STRUCTURE W-PAD MisœRaneous Slot W-205 Plan: W-205l2 (P4) 2400 ..............."........ W.20508"(\ VEnd Cry Cry 6/100 ~ ou: ..~ 1200 1600 2000 2400 Vertical Section (ft) Azim = 1.56', Scale = 1 (in):400(ft) Origin = 0 N/-S, 0 E/-W .........."..,.......', ·..r···.. ..>."..................,..,.......... ~~Mi rœon r~\ TVD Ref: Rotary Table (80.90 ft above MSl) SNy Date: November 24, 2003 2800 ."...",_." ""....."..... 2800 e 3200 3600 ..........''1'',... TD /4-1/2" Ln\ . W·205L1 (P4) : . ~:. 4800 5200 ............................' W-205 e 3200 3600 WELL W-205L2 (P4) MagneticParameters Model: BGGM 2003 Dip: SO.808· Mag Dee: +25.233· ^ ^ ^ Z g o o ~ g ~ II () õi () en en V V V e e FIELD Schlumbørgør Prudhoe Bay Unit - WOA STRUCT1JRE W-PAD Surface Location Date: December 15, 2003 La!: N70 17 45.811 FS: 57558.9nT Lon: W149533.633 NAD27 Alaska State Planes, Zone 04. US Feet Northing: 5958680.13n.uS GridConv: +0.85420613· Easting: 612048.97ftUS Scale Fact 0.9999142622 ..."""'~ Slot: W-205 Plan: W-205L2(p4) 4000 4500 5000 5500 3500 TD /4-1/2" ~nr -. ··m.· .-r~~,~:r. ..H.H.....................H..;...............,.......H :N _Ii, ~., ....í ...H....j.. 3000 \ ...........<............... ........."....... ···H...."···........,·· · . «.............;;..........................«.........«.......... 2500 · . ····..·..,·····..··....··..··....·······..··..1······....····· 2000 · . : EndCrv _7\ - '~. : W·205DBaT4 :' · .,' !¡:~='~\I\~l'~ · . .. . . . · .. · ¡ \ ¡ · . · . · . · . W·205 DBa T3 1500 . ... ...................."-...."............,, ·....··..¡...·.....·......·....··....···....··r·....····........·.......···....··¡............. '.----... ! ¡ --N rrv 6/100 1000 End Cry · . · . · . . .........><H........."........................................"......;,...................... · . . · . . · . . · . . · . . · . . · . . · . . · . . .<..~............"..........."'..... .,,~....u. :KDP Cry 11/100 Bte Whipstock top Whipstock 500 o W-205 : 4000 4500 5000 <<< W Scale = 1 (in):500(ft) E >>> 5500 3500 3000 2500 2000 1500 1000 500 o TVD Ref: Rotary Table (SO.90 II: above MSl) Slvy Date: November 24, 2003 e e BPX AK Anticollision Report Date: 11/24/2003 Time: 10:33:29 BP Amoco Prudhoe Bay PB W Pad W-205 Plan W-205L2 OBa Company: Field: Reference Site: Reference Well: Reference Wellpath: Page: Well: W-205, True North W-205 80.9 Db: ~y~~ Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Co-ordinate(NE) Reference: Vertical (TVD) Reference: NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 6929.71 to 10645.40 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 11/19/2003 Validated: No Planned From To Survey ft ft 138.20 6929.71 Survey #1 (138.20-10619.86) (2) 6929.71 10658.66 Planned: Plan #4 V1 Version: 2 Toolcode Tool Name MWD+IFR+MS MWD+IFR+MS MWD + IFR + Multi Station MWD + IFR + Multi Station Casing Points TVD ft 2766.10 5030.90 5110.90 Diameter in Hole Size in Name MI> ft 3385.00 6929.71 10658.66 10.750 7.625 4.500 13.500 9.875 6.750 103/4" 7-5/8" 4 112" Summary 1< Site Offset Wellpath Well Reference :VII> ft 6929.71 6929.71 Offset MD ft 8350.00 8350.00 Ctr-Ctr No-Go Distance Area ft ft 1812.48 171.80 1812.48 171.69 Allowable Deviation ft 1640.67 1640.78 > Well path Warn~ PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad W-01 W-01 W-02 W-02 W-03 W-03 W-04 W-05 W-05 W-05 W-06A W-06 W-07 W-08 W-08 W-09 W-10 W-10 W-11 W-12A W-12 W-15 W-15 W-15 W-15 W-16 W-16 W-17 W-18 W-19 W-19 W-19 W-200PB1 W-200 W-201 W-203 W-203 W-203 W-205 W-205 W-207 W-207 Plan#3 W-01A VO Plan: W-01 V3 W-02 V4 W-02A V20 W-03 V4 W-03A V1 W-04 V1 Plan W-05A (Rotary) VO Plan#2 W-05L 1 VO Plan: W-05 V3 W-06A V2 W-06 V1 W-07 V1 W-08 V1 W-08A V11 W-09 V1 W-10 V3 W-10A V4 W-11 V1 W-12A V3 W-12 V1 W-15 V1 6929.71 W-15A V10 6929.71 W-15PB1 V6 6929.71 W-15PB2 V1 6929.71 W-16 V3 6929.71 W-16L1 V3 6929.71 W-17 V1 7034.53 W-18 V1 6929.71 Plan#11 W-19AL 1 V1 Pia W-19 V2 W-19A V1 W-200PB1 V7 W-200 V6 W-201 V4 W-203 V9 W-203L 1 V7 W-203L2 V3 Plan W-205L 1 OBc V2 PI W-205 OBd V6 W-207 V10 W-207PB1 V2 Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Out of range Out of range Out of range FAIL: Major Risk ./ FAIL: Major Risk Pass: Major Risk Out of range 6929.71 6929.71 6929.71 6929.71 6929.71 9900.00 2795.95 203.05 2592.90 10150.00 3503.35 157.72 3345.63 11300.00 5411.77 178.17 5233.60 11300.00 5404.14 178.26 5225.88 11300.00 5404.14 178.26 5225.88 6929.71 6929.71 9850.00 3610.65 180.96 3429.69 9850.00 3615.43 180.90 3434.53 8400.00 8400.00 8400.00 8400.00 8750.00 8750.00 7200.00 9600.00 1807.33 1807.33 1807.33 1807.33 2844.26 2844.26 1367.59 5013.03 110.16 110.16 110.16 110.16 100.39 100.39 148.93 86.09 1697.17 1697.17 1697.17 1697.17 2743.87 2743.87 1218.66 4926.94 10592.78 4300.00 3709.73 85.08 3624.65 6949.99 6949.99 7300.00 6950.00 0.40 71.35 -70.95 6950.00 0.40 71.35 -70.95 7800.00 1916.40 155.99 1760.41 e BPX AK Anticollision Report e Company: BP Amoco Date: 11/24/2003 Time: 10:33:29 Page: 2 Field: Prudhoe Bay Reference Site: PB W Pad Co-ordinate(NE) Reference: Well: W-205, True North Reference Well: W-205 Vertical (TVD) Reference: W-205 80.9 Reference Wellpath: Plan W-205L2 OBa Db: Sybase Summary < --- Offset Well path -------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well MD MD Distance Area Deviation Warning ft ft ft ft ft PB W Pad W-209 W-209 V9 7631.87 7150.00 1337.84 107.12 1230.72 Pass: Major Risk PB W Pad W-209 W-209PB 1 V6 Out of range PB W Pad W-20 W-20 V1 6929.71 8550.00 3720.49 95.72 3624.77 Pass: Major Risk PB W Pad W-211 W-211 V8 Out of range PB W Pad W-212 W-212 V12 Out of range PB W Pad W-215 W-215 V7 9505.99 7550.00 1095.94 85.84 1010.10 Pass: Major Risk PB W Pad W-215 W-215PB1 V2 Out of range PB W Pad W-21 W-21 V3 Out of range PB W Pad W-21 W-21A V12 9028.15 13100.00 3873.35 84.38 3788.97 Pass: Major Risk PB W Pad W-22 W-22 V1 6929.71 8850.00 4906.90 100.20 4806.70 Pass: Major Risk PB W Pad W-23 W-23 V3 Out of range PB W Pad W-23 W-23A V5 Out of range PB W Pad W-24 W-24 V1 Out of range PB W Pad W-25 W-25 V1 Out of range PB W Pad W-26A W-26A V6 Out of range PB W Pad W-26 W-26 V1 Out of range PB W Pad W-27 W-27 V1 Out of range PB W Pad W-29 W-29 V1 Out of range PB W Pad W-30 W-30 V1 Out of range PB W Pad W-31 W-31 V1 Out of range PB W Pad W-32 W-32 V5 Out of range PB W Pad W-32 W-32A PB1 V12 Out of range PB W Pad W-32 W-32A V3 Out of range PB W Pad W-34 W-34 V1 Out of range PB W Pad W-34 W-34A V1 Out of range PB W Pad W-34 W-34APB1 V1 Out of range PB W Pad W-35 W-35 V1 Out of range PB W Pad W-36 W-36 V1 Out of range PB W Pad W-37 W-37 V3 Out of range PB W Pad W-37 W-37 A V3 Out of range PB W Pad W-38 W-38 V2 Out of range PB W Pad W-38 W-38A V1 0 Out of range PB W Pad W-39 Plan#4 W-39A VO Plan: Out of range PB W Pad W-39 W-39 V1 Out of range PB W Pad W-400 W-400 V5 Out of range PB W Pad W-40 W-40 V1 Out of range PB W Pad W-42 W-42 V1 Out of range PB W Pad W-44 W-44 V1 Out of range -147 ··100 ··50 -0 50 100 -147 Field: Site: Well: Wellpath: Prudhoe Bay PB W Pad W-205 Plan W-205L2 OBa o 147 270- 180 14, Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ft/in] e 90 e PERMIT TO DRILL 20 MC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. e e TRANSWT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ ;0£4 {û-zoS¿ L PTD# 208 - 2.02- CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL v (If API Dum ber last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing wen~ -2.05 Permit No,~$ ~ //~ API No. $0- 02. '1- ¿ 3/bS Productionsbould continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates Tbe permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. AIJ dry ditcb sample sets submitted to tbe Commission must be in no greatertban 30' sample intervaJs from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 Well Name: PRUDHOE BAY UN POL W-205L2 PTD#: 2032020 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 Administration 1 P.e(lTJitfee attaçhe.d. . . . . . . . . . . . . . . . . Yß$ . . . . . . . . . . . . .. ....................... ..................... 2 Lease number appropriate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yß$ . 3 .U.nlque welLnamß.and OUlTJb.er . . . . . . . _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ . . _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ 4 WeUJocatßd inad.efine~pool . . . . . . . . . . . . . .Ye$ . 5 WeJlJocatßd proper distance. from driJling unitb.oundal)' . . . Yß$. 6 WeJlJocatßd proper _distance. from other welJs. . _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . Yes . . _ . 7 .Sutfiçientaçreage.ayailable [ndJilliog unjt . . . . . . . . . . Yß$ . 8 Jtdßviated, js weJlbore platincJuded . . . . . . . . . . . . . . Yß$ . 9 .Operator onl~ affeçted party. . . . . . . . . . . . . . . . . . . . . . . . . . . Yß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 _Operator bas.appropriate.tlond inJorçe _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ . _Yß$ _ _ _ _ . _ . . . . _ _ . . _ _ _ _ _ _ . . . . . . . . . _ _ _ _ _ _ _ _ . . _ _ . . _ . . _ _ . _ . _ _ . . _ . _ _ . _ _ _ _ _ _ _ _ _ _ . . _ . . 11 Pß(lTJit can be issued without conservation order. . Yes . . . . _ _ . . . . . . .. ........ . . . . . . Appr Date 12 pßUTJit can be issued wjthout ad.lTJinist(ative.approvaJ . . . . . . . . . . . . . _ . . . . . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _. ... _ . _ . . . . . . _ . _ _ . . _ . . . . _ . . . . . . . _ . . . . . . . . . . RPC 12/2/2003 13 Can permit be approved before 15-day wait Yes 14 WellJocatßdwithinareaandstrataauthorizedby.lnjectiooOrdß(# (PutlOtl in.commßnts) (For. Yß$.............. _................................ _. _. ........ ....... 15 _AJI welJs_ witJ1tn .1l4_llJiLe_area_of reyiew idßotified (For servjc.e well onl~>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yß$ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ . _ _ _ _ _ _ _ . . _ . . _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ 16 PJe-produced injector; ~urationof pre-production Iß$s than 3 months (For.service well onJy) . . No. . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . .. .... 17 .ACMP. Finding.of Con.ststency. h.a$ bee.n .issued_ forJhi$ pr.oieçt . . . . _ _ . _ . No 18 .C.ondu.ctor stringpJov[ded . . . . . . . . . . . . _ . . . . . . . . . . . . . . _ _ . . . _ . . . . . . NA _ 19 _S.urfaœ.casing.pJotec.ts alLknown USOWs . . . . . . . . . .NA 20 .CMTv.oladequateJoçircuLate.onconduçtor.&$UJtC$g....................... .NA 21 .CMT vol. adequ.ateJo tie-in Jong .string to.surf çsg. . . . . NA 22CMTwill coyera]l knownproductiye horizons No . . . . . Slotte.d, . . . _ . . . _ . . . . . . . .. _. _ . . . . . . . . . . . . .. ....... 23Ca$ing designs ad.eQua.te for C,T, B&.perllJafr.ost . . . . . . . . . . . _ . . . . . _ . . . . . . . . Yes . . . _ _ . 24 .A~equate.tan.kage.oJ re_serye pit. . Yß$ . . . 1\1 a b.o rs. 9.ES , . . 25 Ra. re-~rilt bas. a. 10A03 fOJ abandonlTJent beßO apPJoved . . . . .NA _ Multilateral.. . 26 A~equate.wellbore separatio_n.proposed. . _ _ _ . _ . _ . . . . . . . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . Yß$ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ . . _ _ _ . _ _ . _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ . _ 27 Jtdivecter Jequired, does jtmeet reguJations. . . .. _........................ NA _ . . Sidetraçk. . . . . _ . . . . _ . . . . . . . . . . _ _ _ _ . . _ . . . . Appr Date 28DJilliogfJuidprograllJ$cMmat[c&eq.uipJi$tadequate_......... _.............. Yßs... . Max MW.9,2PP9. . _ _.... ... _... _.. . _ _.. _ _ _.... WGA 12/3/2003 29 _BOPE$,.d.o.they meetreguJation . . . . . . . . . . . Yß$ . . . . . . .. .................. _ . . 30 .BOPEpress raiing appropriate;.testto.(puJ psig tn.comment$). . . . . _ . . . . . . . . . . . . . . Yes. Testt03500.psi-MSF' 1723 psi. . . . _ . . 31 .Ghoke.llJanifold çOITJPJies w/APL RF'-53 (May 84>. . _ _. Yß$ . 32 Work Will occ.ur withoutoperation .sbutdown. . . . . _ . _ . . Yßs . 33 Js presence. of H2S gas. prob.able. . . . . . _ . _ . _ . . . No. 34 MechanicaLcondition of wells wlthin ,ð.OR yerified (For.s.ervjc;e welJ only). . . . _ . . . . . . . . . NA _ . . _ . . Engineering Geology Appr RPC Date 12/3/2003 Geologic Commissioner: Ðr~ Program DEV On/Off Shore On ~ D Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 PerlTJitcan be lssued w!o. hydrogen.s.ulfide meas.ures. _ . . . . . . . . . . . . _ _ . . . . . . . . . Yßs. . . . . . . . . . _ . . 36 .D.ata.PJeseoted on. pote.ntial oveJpressure .ZOnes. _ . . . . .NA . . . . . . . . . . . . . . . . . . . . . 37Sßismicanalysjs. of shaJlow gas zones . . . . . . . . . . .NA . . . . . . . . . . _ . . . . _ _ . . . _ . . . . . . . _ . _ . . . . . . . . . . . . . . . _ . . . . . . . . . 38 .Sßabed .condjtioo $urvey.(if off-sh.ore) . . . _ _ . . . . NA . . . . . . . . . _ . . . . . _ . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . 39 . Contact namelphoneJor.wee~ly progress.report$ [exploratpl)'onIYl. .. _ _. _ . . . NA . . . . . . . . - - - - - - - - - - -- - - - - - - - - - - Date: Engineering Commissioner: Date Public 1('..... ~ commissioner~~..3 J ~J 3 j J