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Home My WebLink About202-172MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-08 PRUDHOE BAY UNIT PSI-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 PSI-08 50-029-23114-00-00 202-172-0 W SPT 8014 2021720 2004 2166 2165 2165 2165 151 482 480 480 4YRTST P Matt Herrera 6/4/2022 4 Year MIT-IA Performed to 2750 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-08 Inspection Date: Tubing OA Packer Depth 338 2760 2750 2747IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220604121016 BBL Pumped:4.1 BBL Returned:4.1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:47:22 -08'00' • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 05,2018 TO: Jim Regg ?elf �jigie., P.I.Supervisor SUBJECT: Mechanical Integrity Tests 1 7 BP EXPLORATION(ALASKA)INC. I PSI-0811 FROM: Austin McLeod PRUDHOE BAY UNIT PSI-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,) NON-CONFIDENTIAL Comm I Well Name PRUDHOE BAY UNIT PSI-08 API Well Number 50-029-23114-00-00 Inspector Name: Austin McLeod Permit Number: 202-172-0 Inspection Date: 6/2/2018 Insp Num: mitSAMl80602143833 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-08 Type Ind + W 'TVD 8014 `ITubing 795 797 797 - 650 628 - 2021720 1T e Test SPT Testpsi 2004 --- YP - IA zaz zsoo - 2486 - 2461 2457 BBL Pumped:p I 2.8 EBBE Returned: 2.8 OA 272 556 • 540 529 523 Interval 4YRTST P/F P ✓ Notes: MIT-IA } SCANNED JUN 2 2 LU Ir Tuesday,June 05,2018 Page 1 of 1 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :QO~ - 17:l Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 11- RESCAN DIGITAL DATA ~skettes.NO.~ 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: BY: Helen ~~ 0 Other::¡ Date: I ¡ 3 ð-- s- 1 Isl ~p NOTES: Project Proofing BY: Helen Maria Date:j 13 n5 /5/ vvrP Scanning Preparation ~ x 30 = 0fj 4 . +21.:- = TOTA,L PAGES?! l} \Count d. o~s not n..clude cover sheet) 11\11..'0 Date: I lð 05~ /5/ r ,~, . BY: Helen Maria Production Scanning 1 Stage 1 Page Count from Scanned File: <is 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES . , Helen~ Date: I 'ß' 05" YES NO NO /sl v¡,1P BY: Stage 1 BY: If NO in stage 1 page(s) discrepancies were found: BY: Helen Maria Date: /5/ 1 1 Date: /5/ Quality Checked 1111111111111111111 Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 %OWED JAN a ++ *V / . Mr. Tom Maunder Alaska „� r Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �, 5� Anchorage, Alaska 99501 Cara. 4ncnWrr®gb Subject: Corrosion Inhibitor Treatments of GPB PSI t 79. Dear Mr. Maunder, ps _,. ® s Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB PSI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbis ft na gal PSI -01 2021450 50029231040000 NA 1 NA 5.10 10/25/2010 PSI -05 2031390 50029231740000 NA 1 NA 5.95 10/24/2010 PSI -06 2020790 50029230820000 NA 12.3 NA 45.90 10/25/2010 PSI -07 2031480 50029231770000 NA 1.2 NA 6.80 10/24/2010 PSI -08 2021720 .,50029231140000 NA 1.3 NA 6.80 10/23/2010 PSI -09 2021240 '50029230950000 NA 1.9 NA 12.80 10/23/2010 • PSI -10 2021590 50029231100000 NA 0.7 NA 3.40 10/23/2010 , r MEMORANDUM Toy Jim Regg P.I. Supervisor ~~~ 7~Z~~(O FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI-08 PRUDHOE BAY UNIT PSI-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~n Comm Well Name: PRUDHOE BAY UNIT PSI-08 Insp Num: mitJJ100721173157 Rel Insp Num: API Well Number: 50-029-23114-00-00 Permit Number: 202-172-0 Inspector Name: Jeff Jones Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PSI-08 • Type Inj W ~TVD ~ 8014 '~IA 675 2610 ' 2590 ~ 2585 ~ P.T.D 2021720 ~TypeTest sPT Test psi I 2004 / i ~A 250 500 500 500 Interval4YRTST p~ P Tubing 1860 1860 1860 1860 Notes: 2.9 BBLS methanol pumped. 1 well inspected; no exceptions noted. Monday, July 26, 2010 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe_brooks~alaska.gov; tom_maunder~alaska.gov; doa.aogcc.prudhce.bay~alaska .gov OPERATOR: BP Exploration (Alaska}, Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / PSI Pad DATE: 7/4/10 OPERATOR REP: _Jerry Murphy AOGCC REP: Jeff Jones packer Pretest Initial 15 Min. 30 Min. Well PSI-06 T In'. W TVD 7,8 2' Tubi 1,820 1,810 1,810 1,810 Interval P.T.D. 2020790 T test P Test 1968 550 2,610 2,585 2,585 P!F Notes: MIT-IA to 2600 ps+ for 4 year UIC OA f 80 360 360 360 Pum 3.1 bbls MEOH to achieve test Well PSI-08 T In'. W TVD 8,014' Tuts 1,860 1,860 1,860 1,860 Interval P.T.D. 2021720 T test P Test 2003.5 Casi 675 2,610 2,590 2,585 P/F Notes: MIT-IA to 2600 psi for 4 year UIC OA 250 500 500 500 Pum 2.9 bbis MEOH to achieve test Well PSI-09 T In. W TYD 8,034' Tu ' 1,660 1,660 1,660 1,665 Interval P.T.D. 2021240 T test P Test 2008.5 0 2,40D 2,340 2,365 P/F Notes: MIT-IA to 2400 psi for 4 year UIC OA 0 80 60 80 Pum 3 bbls MEOH to achieve test 45 Min. Well T In'. TVD T 1,660 Interval P.T.D. T test Test C 2,365 P/F Notes: Extended PSI-09 test for 15 minutes OA 80 Weil PSI-10 T In'. W TVD 8,056' T 1,750 1,750 1,760 1,760 Interva P.T.D. 2021590 T test P Test 2014 Casi 0 2,500 2,485 2,480 P/F Notes: MIT-IA to 2500 psi for 4 year UIC OA 0 250 250 250 Pumped 3.7 bbls MEOH to achieve test psi _ _ _ TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring ~"~4 °~: `„ : G~• t~ ~! ~ ;' ~. ~' ~ ~) ' ~; P =Standard Pressure Test R = Interr~l Radioactive Tracer Survey A =Temperature Anomaly Survey D = Differential Temperature Test ~~ P ~~~ ~(7 P ~~~~7 P ~ ~(~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V = Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11 /27107 MIT PBU PSI-06 08 09 10 07-04-10.x1s PTP'~ ~-l>:l-- t1~ e e .I j,... ~ 11 z;n o(v ~ /J"l/\, t f-:;"'T i , (' Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I East Dock - PSI 07/16/06 Jack Winslow Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIPSI-06 I Type Inj. I W TVD I 7,S72' Tubing 3,750 3,750 3,750 3,750 Interval I 4 PTD.2020790 I Type test I P Test psil 2000 Casing 330 2,000 2,000 2,000 P/FI P Notes: MIT-IA for Reg Camp. OA 10 10 10 10 Chuck Scheve declined to witness Well I PSI-OS I Type Inj. I W I TVD. I S,015' Tubingl 1,000 1,000 1,000 1,000 Interval I 4 P.T.D.12021720 I Type test I P I Test psi! 2010 Casing SOO 2,000 2,000 2,000 P/FI P Notes: MIT-IA for Reg. Compo OA790 950 950 950 Chuck Scheve declined to witness Weill I Type Inj.1 TVD I Tubingl Intervai! P.TD.I I Type test I Test psil Casing P/FI Notes: OAI Weill I Type Inj.1 I TVD I Tubing I Interval I P.TD.I I Type test I I Test psi I Casing I P/F[ Notes: OA I Weill I Type Inj.1 I TVD I Tubing IntervalT P.T.D.I I Type test I I Test psil Casing P/F[ Notes: OA ;/ TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) 2006·0716_MIT _PBU_PSI-06.xls e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc /8 AJ~~- DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 \ t.f Permit to Drill 2021720 Well Name/No. PRUDHOE BAY UNIT PSI-08 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23114-00-00 MD 13177 ." TVD 8633"" Completion Date 1 0/18/2002 Completion Status 1 ~~»- Current Status 1WINJ ~/ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, USIT, NEW, BHC Sonic Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr .~ Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments d..og" te'é'~ent Evaluation 5 Col 1 10770 12725 Case 10/14/2002 EDJ/ Directional Survey 0 13177 Open 10/9/2002 ~ ~iC 5 Col 10770 12725 Case 10/14/2002 rõQ tG~mma Ray 5 Blu 9500 13083 Case 11/8/2002 with Jewelry f /Temperature 5 Blu 9500 13083 Case 11/8/2002 with Jewelry Log A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/19/2002. Mfg Wressure 5 Blu 9500 13083 Case 11/8/2002 with Jewelry ~g v'Casing collar locator 5 Blu 9500 13083 Case 11/8/2002 with Jewelry JW! L/ ,.Æ1ìrectional Survey 0 13177 Open 10/9/2002 MWD ED {" Directional Survey 0 13177 Open 10/9/2002 MWD ..J..eg"" Co86ñlc r¥O 2 Blu 12150 13180 Open 11/8/2002 ED 0 (/'11678 LIS Verification (7 51 13144 Open 3/26/2003 log Þv.-y t"1\ Cement Evaluation 5 Col 10770 12725 Case 1 0/24/2002 Rpt Directional Survey 0 817 Open 10/9/2002 GYRO Rpt Directional Survey 0 13177 Open 10/9/2002 ;çt£ Directional Survey 0 817 Open 10/9/2002 GYRO t:Ás Verification 51 13144 Open 3/26/2003 ED C . ()J~(286 Gamma Ray 12109 13179 Open 11/8/2002 u.og .........son ic tv'\ ì) 2 Blu 12150 13180 Open 11/8/2002 ED C Tf ....A'2189 LIS Verification 1-4 113 1 3177 Case 1 0/27/2003 DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Permit to Drill 2021720 Well Name/No. PRUDHOE BAY UNIT PSI-08 MD 13177 TVD 8633 Completion Date 10/18/2002 ED C Pdf r,12189 Rate of Penetration ED C Pdf /i 12189 Induction/Resistivity ED C Pdf /12189 Density ED C Pdf \"'12189 Neutron Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? '-Y-¡-N- Analysis Received? -¥-f'N--- Comments: Compliance Reviewed By: ~ Interval Start Stop Operator BP EXPLORATION (ALASKA) INC Completion Status 1WINJ 25 1-4 25 25 25 1-4 1-4 1-4 Sent Received Daily History Received? Formation Tops 113 113 113 113 Current Status 1WINJ 13177 Case 1 0/27/2003 13177 Case 10/27/2003 13177 Case 10/27/2003 13177 Case 10/27/2003 Sample Set Number Comments @N fùN API No. 50-029-23114-00-00 UIC Y ROP, DGR, EWR - MWO ROP, DGR, EWR - MWD DGR, SLD, CNP - MWD DGR, SLO, CNP - MWD .~ Date: ;z:; ~i ) ) [)OC)- J7~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 October 17, 2003 RE: MWD Formation Evaluation Logs: PSI -08, AK-MW-22145 PSI-OS: Digital Log Images 50-029-23114-00 1 CD Rom J & \'6~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99508 Date: .., ~ Signed~~(ð~~ ~.~ Or-T f')"7 ;..n....! c... ¡ ~~~Ç\\~ . " ') ) Dl09-/7cJ J /07f WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 25, 2003 RE: MWD Formation Evaluation Logs PSI-08, AK-MW-22145 1 LDWG formatted Disc with verification listing. API#: 50-029-23114-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~ RECEIVED MAR 2 6 2003 Alaska œ & Gas Cons. CommiIeion Anchorage ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X 1413' FNL, 4379'FEL, Sec. 15,T11N,R15E, UM At top of productive interval 4755' FNL,3955'FEL,Sec.04,T11N, R15E,UM At effective depth 4691' FNL,4003'FEL,Sec.04,T11N, R15E, UM At total depth 4672' FNL,4016'FEL,Sec.04,T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 708025, 5966170) (asp's 702957, 5973251) (asp's 702907, 5973314) (asp's 702893, 5973333) 13177 feet 8633 feet Plugs (measured) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 51 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number PSI-08 9. Permit number / approval number 202-172 10. API number 50-029-23114-00 11. Field / Pool Prudhoe Bay Oil Pool Effective depth: measured 13081 feet Junk (measured) true vertical 8540 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 113' 20" 260 sx Arctic Set (aprox) 147' 147' Surface 6417' 13-3/8" 1473 sx AS III Lite, 528 6451' 4628' sx Class 'G' Intermediate 12695' 9-5/8" 618 sx Class 'G' 12726' 8196' Liner 561' 7" 189 sx Class 'G' 12616' - 13177' 8090' - 8633' Perforation depth: measured Open Perfs 12760'-12820',12900'-12920',12960'-13080' RECEIVED true vertical Open Perfs 8229'-8287', 8364'-8384', 8422'-8539' DEC 1 9 2002 Tubing (size, grade, and measured depth) 7-5/8" 29.7# L-80 @ 1997' MD. 7-5/8" x 7" XO @ 1991\1a$ki~i~G;§9W1~~mission 7-5/8" 29.7# L-80 @ 12458' MD. 7-5/8" x 7" XO @ 12458'. 7" 26~-cm9~Qf2585'. Packers & SSSV (type & measured depth) 7" X 9-5/8" Baker SABL-3 Packer @ 12536' MD. 7" X 9-5/8" BKR ZXP LNR TOP PKR W/TIEBACK SLV @ 12623'. 7" Camco DB NIP @ 1998'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 98,698 Prior to well operation 11/15/2002 Subsequent to operation 11/29/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the fO~egO~ is true and correct to the best of my knowledge. A4v ~~ Title: Technical Assistant DeWayne R. Schnorr Casing Pressure Tubing Pressure 2321 2019 107,525 16. Status of well classification as: Form 10-404 Rev 06/15/88 . Suspended - Service WATER INJECTION Date December 04, 2002 p'e:~::I:':a:~::~::~5174 ~ ) PSI-OS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/01/2002 11/02/2002 11/04/2002 11117/2002 12/03/2002 12/03/2002 NEW WELL POST: AC-FLUID LEVEL NEW WELL POST: AC-MITIA NEW WELL SUPPORT: AC-MONITOR NEW WELL POST: PERFORATING TESTEVENT --- IN] PRESS, PSI: 1,617 TYPE: PW VOL: 88,986 NEW WELL POST: SSSV C/O OR STROKE EVENT SUMMARY 11/01/02 TIIIO = 1100180/220, IA FL @ SURFACE POST INJECTION START-UP. 11/02/02 T/I/O=1175/80/220 MITIA TO 2100 PSI. PASSED (AOGCC WITNESSED, JEFF JONES). INITIAL IA FL AT SURFACE. MITIA LOST 20 PSI IN THE FIRST 15 MINUTES AND GAINED 20 PSI IN THE SECOND 15 MINUTES FOR A TOTAL LOSS OF 0 PSI IN 30 MINUTES. PUMPED 4 BBLS OF 60/40 METHANOL DOWN THE IA. FINAL WHP's = 1175/150/220. 11/04/02 T/I/O= 1325/101120 (POST MITIA) 11/17/02 PERFORATED 129001-12920' AND 12760'-128201 WITH 3318 POWERJET 3406,6 SPF. CORRELATE USING SWS BHCS DATED 8-21-02 & SWS JEWELRY LOG DATED 15-0CT-2002. CORRELATE TO JEWELRY FROM 12700'-12450'. TUBING PRESSURE INCREASED TO 400 PSI ON LAST GUN RUN. DID NOT TAG TD. 12/03/02 TESTEVENT --- INJECTION PRESSURE, PSI: 1,617 TYPE: PW VOL: 88,986 BWPD. 12/03/02 SET 6" INJECTION VALVE @ 19711 SLM (SER# HTS-0643, DB6 LOCK, 49" OAL, SITP-O). TAG ON PANEL WI ISSSV INFO. NO CLOSURE TEST DONE DUE TO PRESSURE @ 0 PSI, TATTLE TAIL SPRING ON RUNNING TOOL INDICATES GOOD SET «< WELL LEFT SI »> Fluids Pumped BBLS 4 4 8 DIESEL FOR SURFACE PRESSURE TEST (3 TESTS) 60/40 METHANOL WATER TOTAL ADD PERFS 11/17/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING 3-3/8" 3406-PJ, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 127601 - 12820' 12900' - 12920' Page 1 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned IBI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3867' NSL, 4379' WEL, SEC. 15, T11N, R15E, UM At top of productive interval 524' NSL, 3955' WEL, SEC. 04, T11 N, R15E, UM At total depth 608' NSL, 4016' WEL, SEC. 04, T11 N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 51' ADL 034631 12. Date Spudd;d 13. Date T.D. Rea9hed 14. Date Camp., Susp., or Aband. 9/4/2002 9/20/2002 10/18/2002 .¡ 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13177 8633 FT 13081 8540 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, USIT, NEW, 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 12960' - 13080' 8422' - 8539' ''I. 23. CASING SIZE 20" X 34" 13-3/8" 9-5/8" WT. PER FT. 91.51#' 68# 47# 26# 7" 27. Date First Production October 29, 2002 Date of Test Hours Tested ) ') STATE OF ALASKA. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well Gas Cap Injection 7. Permit Number 202-172 8. API Number 50-029-23114 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number PSI-OS 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1998' MD 1900' (Approx.) GRADE H-40 L-80 L-80 L-80 BHC Sonic CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 113' 42" ,260 sx Arctic Set (Approx.) 34' 6451' 16" 1473 sx AS III Lite, 528 sx 'G' 31' 12726' 12-1/4" 618 sx Class 'G' 12616' 13177' 8-1/2" 189 sx Class 'G' AMOUNT PULLED 25. TUBING RECORD DEPTH SET (MD) PACKER SET (MD) MD TVD SIZE 7-5/8",29.7#, L-80 x 7",26#, L-80 12585' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 138 Bbls Diesel 12536' 26. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF CHOKE SIZE GAS-OIL RATIO WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. sUb'Rf~f'l V E D No core samples were taken. NO\I I 8 2002 28. Form 10-407 Rev. 07-01-80 NOV 0 5 2002 RBDMS 8FL Alaska on & Gas Cons. Commission Anchorage GÝ Submit In Duplicate " ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SV4 SV3 SV2 SV1 Ugnu 4 Ugnu 4A Ugnu 3 Ugnu 1 West Sak 2 West Sak 1 CM3 CM2 CM1 HRZ LCU / Top Zone 3 Zone 2C Zone 28 Zone 2A Zone 1 8 Zone 1 A Kavik 4247' 5052' 5437' 6179' 7188' 7282' 7707' 8914' 9986' 10366' 10756' 11864' 12084' 12544' 12756' 12814' 12859' 12960' 12988' 13026' 13111' 3495' 3908' 4108' 4491' 4996' 5043' 5258' 5889' 6430' 6617' 6810' 7441' 7613' 8022' 8225' 8281' 8325' 8422' 8450' 8486' 8569' RECEIVED NOV 0 5 2002 Alaska Oil & G AnaCshCons. Commission Drage 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TeffieHubble ~ ~ Title Technical Assistant Date II'Dc.¡.o~ PSI-08 202-172 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No./ Approval No. Drilling Engineer: Rob Tirpack, 564-4166 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Leak-Off Test Summary Page 1 of 1 Legal Name: PSI-08 Common Name: PSI-08 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 9/11/2002 FIT 6,451.0 (ft) 4,630.0 (ft) 9.00 (ppg) 736 (psi) 2,901 (psi) 12.06 (ppg) 9/19/2002 FIT 12,725.0 (ft) 8,195.0 (ft) 9.00 (ppg) 425 (psi) 4,256 (psi) 10.00 (ppg) 9/20/2002 FIT 12,725.0 (ft) 8,195.0 (ft) 9.00 (ppg) 555 (psi) 4,386 (psi) 10.30 (ppg) 9/23/2002 FIT (ft) (ft) (ppg) (psi) (psi) 10.30 (ppg) ,~ ~' Printed: 9/30/2002 9:06:09 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Operations Summary Report PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E ) Page 1 of 14 Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/3/2002 06:00 - 22:00 16.00 MOB P PRE Blow down steam lines and water. Disconnect interconnects. Unplug electrical service. PJSM. Move support modules: pump room, motor complex, pits. Move pipe shed complexes. Move matting boards. Hook up cats. Move sub complex off of PSI-10. Move sub to PSI-08. Move matting boards and spot sub over PSI-08. Spot water tanks and pipe shed. Spot pits, motors, and pumps. Spot cuttings tank and fuel tank and build berms. RU lines on rig. 22:00 - 00:00 2.00 MOB P PRE RU pipe skate. Clean floor and hall ways. Load pipe shed with DP. Take on mud. Repair broken bolt on TO. Tighten bolts on hydril to mud cross and tighten lock downs on conductor. PU stand of pipe and check level of sub. Jack and shim sub. 9/4/2002 00:00 - 01 :00 1.00 RIGU P PRE Accept rig at 00:01 on 9/4/02. Replace boot in flow line. Double check berms and interconnect hook ups. 01 :00 - 03:00 2.00 BOPSUR P SURF NU riser and flow line. Hook up turn buckles. 03:00 - 03:30 0.50 DIVRTR P SURF Drop diverter line to clear water injection flow line. RU floor to PUDP. 03:30 - 07:00 3.50 DRILL P SURF PJSM. Rabbit and pick up 93 joints of 5" DP. 07:00 - 08:00 1.00 DIVRTR P SURF Function test diverter and knife valve. Witness of test waived by Jeff Jones of AOGCC. 08:00 - 10:00 2.00 DRILL P SURF PU HWDP and jars, 6 steel DCs, 3 NM DCs and stand back in derrick. 10:00 - 11 :30 1.50 DRILL P SURF Bring tools to rig floor. PJSM with slickline and rig up for gyro. Hook up blower hose to top drive. 11 :30 - 12:30 1.00 DRILL P SURF Pre spud meeting with both crews. 12:30 - 15:00 2.50 DRILL P SURF Pick up BHA and orient motor to MWD. 15:00 - 00:00 9.00 DRILL P SURF Drill from 113' to 627'. Run slickline gyro due to magnetic interference. AST=4.0, ART=0.25. 9/5/2002 00:00 - 17:30 17.50 DRILL P SURF Drill 16" directional hole from 627' to 1,707'. Slickline gyro to 1,000' due to magnetic interference. AST= 10.85, ART=0.25. Not achieving required build rate. 17:30 - 18:30 1.00 DRILL P SURF CBU. 18:30 - 20:00 1.50 DRILL P SURF POH. Hole in good shape. No tight spots, no swabbing. 20:00 - 00:00 4.00 DRILL P SURF LD UBHO sub. Change choke size in MWD pulser and pressure drop sub. Change out motor stabilizer and bit. 9/6/2002 00:00 - 01 :00 1.00 DRILL P SURF RIH to 1,670'. Wash to 1,707'. 01 :00 - 00:00 23.00 DRILL P SURF Drill from 1,707' to 3,454' building angle. AST= 7.1 hrs, ART=2.4 hrs. 9/7/2002 00:00 - 08:30 8.50 DRILL P SURF Drill from 3,454' to 4,391'. 08:30 - 09:00 0.50 DRILL P SURF Change swab out on #2 pump. 09:00 - 09:30 0.50 DRILL P SURF Drill from 4,391' to 4,486'. Lost 500 psi DP pressure. Suspect choke on MWD washed out. No problems with MWD. 09:30 - 10:30 1.00 DRILL P SURF Circulate bottoms up st 800 gpm, 100 rpm. 10:30 - 13:00 2.50 DRILL P SURF POH from 4,486' to 1,662'. No swabbing. Hole in good condition. 13:00 - 13:30 0.50 DRILL P SURF Lubricate rig. 13:30 -15:00 1.50 DRILL P SURF RIH to 4,486'. Wash last stand down, no fill. No tight spots. 15:00 - 00:00 9.00 DRILL P SURF Drill from 4,486' to 5,237'. Daily drilling times: AST=4, ART=7.1. 9/8/2002 00:00 - 15:30 15.50 DRILL P SURF Drill from 5,237' to section TO at 6,464'. AST=1.0, ART=10. 15:30 - 17:00 1.50 DRILL P SURF Circulate low visco sweep and circulate hole clean. 17:00 - 18:30 1.50 DRILL P SURF POH from 6,464' to 4,486'. No tight spots. 18:30 - 19:00 0.50 DRILL P SURF RIH to 6,464'. Hole in good shape. Printed: 9/30/2002 9:06:20 AM '> ) BP EXPLORATION Operations Summary Report Page 2 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/8/2002 19:00 - 21 :00 2.00 DRILL P SURF Circulate hole clean. Spot 100 bbl barofiber and EZ glide pill. Pump dry job. 21 :00 - 00:00 3.00 DRILL P SURF POH to run casing. 9/9/2002 00:00 - 03:30 3.50 DRILL P SURF POH and stand back DCs and flex collars. Down load MWD. LD MWD and motor. 03:30 - 05:30 2.00 CASE P SURF RU to run casing. 05:30 - 06:00 0.50 CASE P SURF PJSM with crew and casing hand on running casing. 06:00 - 20:30 14.50 CASE P SURF MU 13 3/8" float shoe and float collar. Baker loc first 3 connections. Check floats, OK. Run 133/8",68#, L-80, BTC casing. Circulate and work casing in the hole from 2,340' to 3,600'. Continue to run casing w/o problems. MU hanger and landing joint. Land casing at 6,451'. 20:30 - 22:00 1.50 CASE P SURF Circulate bottoms up and condition mud. Stage up rate to 9 bpm. 22:00 - 22:30 0.50 CASE P SURF RD Franks fill up tool. MU cement head. 22:30 - 00:00 1.50 CASE P SURF Circulate and condition mud. Stage rate up to 12 bpm, 855 psi. 9/10/2002 00:00 - 02:00 2.00 CASE P SURF Circulate and condition mud to 44 visc and YP 12. Hold PJSM with Peak drivers and cementers while circulating. 02:00 - 07:00 5.00 CEMT P SURF Pump 5 bbls of water. Pressure test cement lines to 3,000 psi. Pump 10 bbls of water, 66 bbls of 10.2 ppg Mud Push spacer, drop bottom plug, pump 1,165 bbls (1473 sx) of 10.7 ppg Arctic set lite III cement, pump 110 bbls (529 sx) of 15.8 ppg class G tail cement. Drop top plug. Switch to rig pumps and displace cement at 12 bpm. Slow displacement to 6 bpm with 30 bbls left in displacement. Slow rate to 3 bpm and bump plug to 2,600 psi. CIP 06:50. Bleed off pressure and check floats. Floats holding. 100 bbl cement returns. 07:00 - 09:00 2.00 CEMT P SURF Wash out flow line and surface stack. RD casing tools. 09:00 - 15:00 6.00 CEMT P SURF Nipple down 20" diverter and 16" diverter line. 15:00 - 16:00 1.00 CEMT P SURF Install FMC big bore split unihead. and test seal to 1,000 psi for 10 minutes. 16:00 - 20:00 4.00 CEMT P SURF NU BOP. 20:00 - 00:00 4.00 CEMT P SURF Test BOPE to 250 psi /4,000 psi as per BP policy and AOGCC regulations. Witness of test waived by Chuck Sheve of AOGCC. 9/11/2002 00:00 - 01 :00 1.00 CEMT P SURF Continue to test BOPE. 01 :00 - 02:00 1.00 CEMT P SURF RD testing equipment. Install wear bushing. 02:00 - 03:00 1.00 CEMT P SURF Inspect torque tube and top drive. Tighten turn buckle. 03:00 - 05:00 2.00 DRILL P SURF LD steel drill collars out of derrick. 05:00 - 06:00 1.00 DRILL P INT1 PU 30 joints of 5" DP and rack in derrick. 06:00 - 08:30 2.50 DRILL P INT1 PU 12 1/4" BHA. Test adjustable gauge stabilizer and load MWD. 08:30 - 09:00 0.50 DRILL P INT1 Pick up NM flex DCs and HWDP out of derrick. 09:00 - 15:30 6.50 DRILL P INT1 Single in hole to 6,286'. 15:30 - 16:30 1.00 CASE P INT1 Test 13 3/8" casing to 3,500 psi for 30 minutes. 16:30 - 19:00 2.50 DRILL P INT1 Drill 13 3/8" float collar and displace to 9.0 ppg LSND mud while drilling firm cement in shoe track and float shoe. Clean out 16" rat hole to 6,464'. 19:00 - 19:30 0.50 DRILL P INT1 Drill 20' of new formation from 6,464' to 6,484'. 19:30 - 20:00 0.50 DRILL P INT1 Circulate hole to 9.0 ppg in and out. 20:00 - 21 :30 1.50 DRILL P INT1 Perform base line ECD. Perform FIT test to 12.0 ppg EMW. 21 :30 - 23:00 1.50 DRILL P INT1 Slip and cut drilling line. 23:00 - 00:00 1.00 DRILL P INT1 Drill from 6484' to 6568'. ART=0.9, AST=O. Printed: 9/30/2002 9:06:20 AM ') BP EXPLORATION Operations Summary Report Page 3 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/12/2002 00:00 - 20:00 20.00 DRILL P INT1 Directional Drill Ahead From 6,568' To 8,829' - Weight On Bit 5K To 20K With Pump Rate At 203 Strokes Or 850 GPM - Off Bottom Pump Pressure At 2950 Psi. & On Bottom Pump Pressure At 3200 Psi. - Top Drive RPM At 80 - Off Bottom Torque At 17K & On Bottom Torque At 19K - String Rotating Weight At 170K - With Pump Off Drag Up At 245K And Drag Down At 135K Actual Slide Time = 2.39 Hours Actual Rotating Time = 9.41 Hours 20:00 - 21 :00 1.00 DRILL P INT1 Circulate Hi-Vis Sweep For Short Trip 21 :00 - 00:00 3.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH With 5" Drill Pipe To 8,442' - Start To Swab Connect Top Drive And Pump Out Of The Hole To 13 3/8" Casing Shoe - Attempt To Pull Pipe With Out Pumping At Different Spots Still Wanting To Swab (Pump Out Of Hole) 9/13/2002 00:00 - 00:45 0.75 DRILL P INT1 Continue To Pump To Casing Shoe - Monitor Well Bore (Static) 00:45 - 01 :45 1.00 DRILL P INT1 Circulate Across Top Of Hole With Trip Tank System - Service Can-Rig Top Drive, Traveling Blocks And Crown Sheaves 01 :45 - 02:30 0.75 DRILL P INT1 Hold Pre-Job Safety Meeting - RIH From (6,366') 13 3/8" Casing Shoe With 5" Drill Pipe From Mast To 8,737' (No Problems) 02:30 - 03:00 0.50 DRILL P INT1 Connect Top Drive Break Circulation And Wash Last Stand To Bottom At 8,829' (No Fill) 03:00 - 08:00 5.00 DRILL P INT1 Directional Drill Ahead From 8,829' To 9,391' - Weight On Bit 15K With Pump Rate At 203 Strokes Or 850 GPM - Off Bottom Pump Pressure At 3100 Psi. & On Bottom Pump Pressure At 3300 Psi. - Top Drive RPM At 80 - Off Bottom Torque At 17K & On Bottom Torque At 18K - String Rotating Weight At 175K- With Pump Off Drag Up At 230K And Drag Down At 140K 08:00 - 09:30 1.50 DRILL P INT1 Circulate 25 BBL La-Vis And 50 BBL Hi-Vis Sweep Around 09:30 - 18:30 9.00 DRILL P INT1 Directional Drill Ahead From 9,391' To 10,614' - Weight On Bit 15K To 20K With Pump Rate At 215 Strokes Or 900 GPM - Off Bottom Pump Pressure At 3900 Psi. & On Bottom Pump Pressure At 4150 Psi. - Top Drive RPM At 80 - Off Bottom Torque At 18K & On Bottom Torque At 23K - String Rotating Weight At 195K - With Pump Off Drag Up At 250K And Drag Down At 155K 18:30 - 20:00 1.50 DRILL N SFAL INT1 Work Drill String While Changing Out Liner And Swab On NO.1 Emsco Mud Pump 20:00 - 20:30 0.50 DRILL P INT1 Drill Ahead From 10,614' To 10,628' 20:30 - 21 :30 1.00 DRILL N RREP INT1 90 Degree Elle To Stand Pipe Mud Manifold Washed Out Preventing MWD And Pump Pressure Read Outs - Stand Back Stand Of 5" Drill Pipe And Work Drill String 90' - Install Jumper Hose And Isolate Problem - Test Line And Make Up Stand 21 :30 - 00:00 2.50 DRILL P INT1 Directional Drill Ahead From 10,628' To 10,800' - Weight On Bit 15K To 20K With Pump Rate At 215 Strokes Or 900 GPM - Off Bottom Pump Pressure At 3925 Psi. & On Bottom Pump Pressure At 4100 Psi. - Top Drive RPM At 80 - Off Bottom Torque At 18K & On Bottom Torque At 23K - String Rotating Weight At 195K - With Pump Off Drag Up At 250K And Drag Down At 155K 9/14/2002 00:00 - 07:30 7.50 DRILL P INT1 Directional Drill Ahead From 10,800' To 11,363' - Weight On Printed: 9/30/2002 9:06:20 AM ") BP EXPLORATION Operations Summary Report Page 4 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OB PSI-OB DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/14/2002 00:00 - 07:30 7.50 DRILL P INT1 Bit 15K To 20K With Pump Rate At 203 Strokes Or 850 GPM - Off Bottom Pump Pressure At 4000 Psi. & On Bottom Pump Pressure At 4200 Psi. - Top Drive RPM At 80 To 100 - Off Bottom Torque At 18K & On Bottom Torque At 23K - String Rotating Weight At 190K - With Pump Off Drag Up At 240K And Drag Down At 150K 07:30 - 09:30 2.00 DRILL P INT1 Circulate And Condition Mud Pump La-Vis And Hi-Vis Weighted Sweep Around While Rotating And Reciprocating Drill String 09:30 - 13:00 3.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH Well Swabbing - Pump Out Of The Hole To 8,733'- Attempt To Pull Pipe With Out Pumping Every 5 Stands (No Good) 13:00 - 14:00 1.00 DRILL P INT1 RIH With 5" Drill Pipe From Mast To 11,269' With No Problems - Connect Top Drive And Break Circulation - Wash And Ream To Bottom At 11,363' (No Fill) 14:00 - 16:00 2.00 DRILL P INT1 Directional Drill Ahead From 11,363' To 11,457' (Draping Angle) 16:00 - 17:00 1.00 DRILL N RREP INT1 Rotate And Reciprocate Drill String - Replace Swab And Liner In NO.2 Emsco Mud Pump 17:00 - 00:00 7.00 DRILL P INT1 Directional Drill Ahead From 11,457' To 11,662' - Weight On Bit 15K To 20K With Pump Rate At 203 Strokes Or 850 GPM - Off Bottom Pump Pressure At 4000 Psi. & On Bottom Pump Pressure At 4200 Psi. - Top Drive RPM At 80 To 100 - Off Bottom Torque At 18K & On Bottom Torque At 21 K - String Rotating Weight At 200K - With Pump Off Drag Up At 250K And Drag Down At 155K *NOTE* Increase Mud Weight With Spike Fluid To 10.5 PPG During This Phase 9/15/2002 00:00 - 06:30 6.50 DRILL P INT1 Directional Drill Ahead From 11,662' To 11,842' While Dropping Angle And Checking For Flow On Connections - Weight On Bit 1 OK To 15K With Pump Rate At 191 Strokes Or 800 GPM - Off Bottom Pump Pressure At 3700 Psi. & On Bottom Pump Pressure At 4050 Psi. - Top Drive RPM At 100- Off Bottom Torque At 14K & On Bottom Torque At 19K - String Rotating Weight At 200K - With Pump Off Drag Up At 250K And Drag Down At 160K 06:30 - 07:00 0.50 DRILL P INT1 Encounter Gas Breaking Out At Bell Nipple - Monitor Well - Mud Weight Cut At Shakers To 9.1 PPG (Non-Pres. Scale) 07:00 - 09:00 2.00 DRILL P INT1 Circulate And Increase Mud Weight From 10.5 PPG To 10.8 PPG 09:00 - 21 :30 12.50 DRILL P INT1 Directional Drill Ahead From 11,842' To 12,332' While Dropping Angle And Checking For Flow On Connections - Weight On Bit 17K To 20K With Pump Rate At 180 Strokes Or 750 GPM - Off Bottom Pump Pressure At 4000 Psi. & On Bottom Pump Pressure At 4150 Psi. - Top Drive RPM At 100- Off Bottom Torque At 17K & On Bottom Torque At 22K - String Rotating Weight At 220K - With Pump Off Drag Up At 280K And Drag Down At 175K *NOTE* - Increase Mud Weight To 10.9 PPG While Drilling 21 :30 - 22:00 0.50 DRILL N RREP INT1 Hold Pre-Job Safety Meeting - Change Out Swab On No.1 Printed: 9/30/2002 9:06:20 AM ) -) BP EXPLORATION Operations Summary Report Page 5 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/15/2002 21 :30 - 22:00 0.50 DRILL N RREP INT1 Emsco Mud Pump 22:00 - 00:00 2.00 DRILL P INT1 Directional Drill Ahead From 12,332' To 12,417' 9/16/2002 00:00 - 05:30 5.50 DRILL P INT1 Directional Drill Ahead From 12,417' To 12,735' While Dropping Angle And Checking For Flow On Connections - Weight On Bit 17K To 20K With Pump Rate At 180 Strokes Or 750 GPM - Off Bottom Pump Pressure At 4000 Psi. & On Bottom Pump Pressure At 4150 Psi. - Top Drive RPM At 100- Off Bottom Torque At 17K & On Bottom Torque At 22K - String Rotating Weight At 220K - With Pump Off Drag Up At 280K And Drag Down At 175K 05:30 - 08:00 2.50 DRILL P INT1 Circulate Hole Clean And Condition Mud While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) 08:00 - 09:00 1.00 DRILL P INT1 POH To 11,320' With 5" Drill Pipe Stand Back In Mast (No Problems) 09:00 - 09:30 0.50 DRILL P INT1 RIH To 12,682' With 5" Drill Pipe (No Problems) - Connect Top Drive And Break Circulation - Wash To Bottom At 12,735' No Fill 09:30 - 12:00 2.50 DRILL P INT1 Circulate Low-Vis And Hi-Vis Weighted Sweep Around - 60 Maximum Units Of Gas At Bottoms Up 12:00 - 18:00 6.00 DRILL P INT1 Hold Pre-Job Safety Meeting - POH (SLM) With 5 Stands 5" Drill Pipe With No Problems Hole Taking Correct Amount Of Fluid For Steel Displacement - Monitor Well (Static) - Pump Dry Job And Blow Down Top Drive - Continue To POH To 13 3/8" Casing Shoe With No Problems - Shut Down And Observe Well (Static) - POH With 5" Drill Pipe Standing Back In Mast 18:00 - 19:00 1.00 DRILL P INT1 Stand Back 3 Stands Of 5" HWDP - Hold Pre-Job Safety Meeting - Lay Down 2 Joints Of HWDP, 8" Drilling Jars, And Flex Drill Collars 19:00 - 19:30 0.50 DRILL P INT1 Down Load Sperry Sun MWD / LWD Tools 19:30 - 20:30 1.00 DRILL P INT1 Pump Fresh Water Thru MWD Tools And Mud Motor - Drain Motor And Remove 12 1/4" PDC Bit - Lay Down MWD Tools And Mud Motor 20:30 - 21 :00 0.50 DRILL P INT1 Clear Rig Floor Of 12 1/4" Drilling Tools And Equipment 21 :00 - 21 :30 0.50 CASE P INT1 Hold Pre-Job Safety Meeting - Rig Up And Pull Wear Ring - Install Lower FMC Test Plug - Rig Up BOP Testing Equipment 21 :30 - 22:30 1.00 CASE P INT1 Hold Pre-Job Safety Meeting - Open Doors On Top BOP Gate And Remove Ram Blocks And Change To 9 5/8" - Close Doors 22:30 - 23:00 0.50 CASE P INT1 Hold Pre-Job Safety Meeting - Test Top Gate Door Seals And To 1,500 Psi. - Rig Down Testing Equipment - Pull Test Plug And Lay Down Test Joint 23:00 - 00:00 1.00 CASE P INT1 Hold Pre-Job Safety Meeting - Remove Short Set Of Elevator Links - Pick Up And Make Up GBR Franks Fill Up Tool 9/17/2002 00:00 - 02:00 2.00 CASE P INT1 Hold Pre-Job Safety Meeting - Install Long Set Of Elevator Links And 350 Ton Elevators - Make Dummy Run With FMC Flutted Hanger With Landing Joint - Install 350 Ton Slips- Bring Ridgid Blade Centrilizers, Cement Head, Safety Valve Cross Over, And Pup Joints To Rig Floor 02:00 - 02:30 0.50 CASE P INT1 Hold Pre-Job Safety Meeting With BP Drilling Foreman, Nabors Toolpusher And All Personal Regarding Up Coming Casing Running Operation 02:30 - 08:00 5.50 CASE P INT1 Pick Up 9 5/8" Shoe Track And Float Equipment - Fill With Mud To Check Floats - Continue To RIH With 95/8" 471b. L-80 BTC-M Casing Per Program Printed: 9/30/2002 9:06:20 AM ) \ t BP EXPLORATION Operations Summary Report Page 6 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2002 08:00 - 08:30 0.50 CASE P INT1 Center BOP Stack So Casing Would Not Hit And Damage Well Head Profile 08:30 - 12:00 3.50 CASE P INT1 Continue To RIH With 156 Joints Of 95/8" 471b. L-80 BTC-M Casing Per Program To 13 3/8" Casing Shoe 12:00 - 14:00 2.00 CASE P INT1 Insert Franks Fill Up Tool- Break Circulation - Stage Up Pump Rate - Circulate Surface To Surface With No Losses - Up Weight At 270K And Down Weight At 180K - 4.5 BPM With 1,000 Psi 14:00 - 16:30 2.50 CASE P INT1 Continue To RIH With 183 Joints Of 95/8" 471b. L-80 Casing - Start To Loose Returns At 7,550' - Reduce Running Speed And Continue To RIH With 204 Joints To 8,440' (Lost Total Returns) 16:30 - 18:00 1.50 CASE P INT1 Insert Franks Fill Up Tool - Work Casing String To Regain Circulation On The Up Stroke - Establish Circulation And Stage Up Pump Rate To 5.5 BPM At 750 Psi. - Formation Breathing Giving Back Fluid 18:00 - 22:00 4.00 CASE P INT1 RIH With 214 Joints (Staging In Hole) Of 95/8" 471b. L-80 Casing - Break Circulation - RIH With 250 Joints Of 9 5/8" Casing To 10,342' 22:00 - 00:00 2.00 CASE P INT1 Break Circulation Stage Mud Pumps Up To 6 BPM With 900 Psi. While Reciprocating Casing String Up Weight At 455K And Down Weight At 200K - Break Circulation With 498 BBLS Fluid In Active System At 22: 12 Hours - Stroke Casing Up And Have 34% Flow - Slack Off Casing String And Have 20% Flow - Shut Pumps Down At 22:40 Hours With 453 BBLS In Active System (45 BBL Loss) - Well Breathing At 22:52 Hours 472 BBLS In Active System (19 BBL Gain) - Reduce Pump Rate To 3.5 BPM At 625 Psi. And Continue To Reciprocate Casing String And Condition Mud Viscosity Coming Out At 170 And Mud Weight At 11.3 PPG 9/18/2002 00:00 - 03:00 3.00 CASE P INT1 Continue To Circulate And Condition Mud At 3.5 BPM 29% Flow With No Losses - Stage Up Pump Rate To 5 BPM At 667 Psi. - Shut Down Pumps 03:00 - 03:30 0.50 CASE P INT1 (Monitor Well) Well Breathing 22% Flow With Pumps Off At 03:00 Hours Flow Decreased To 9% Flow At 03:30 -Total Mud For 30 Minutes At Given Back 53 BBLS. Flow Pit Volume Time 22% 575 BBLS 03:00 19% 595 BBLS 03:05 16% 608 BBLS 03:10 13% 616 BBLS 03:15 10% 620 BBLS 03:20 10% 623 BBLS 03:25 10% 627 BBLS 03:30 9% 628 BBLS 03:32 03:30 - 05:00 1.50 CASE P INT1 RIH With 274 Joints Of 95/8" Casing To 11,317' At Reduced Rate Very Slow While Monitoring Returns Well Starting To Swab Down 05:00 - 05:30 0.50 CASE P INT1 Break Circulation At 11,317' - Attempt To Work Casing String Up At 550K (No Good) - Currently 200 Feet Into Drop Section Of Well - Circulate 25 BBLS At 4.5 BPM With 15% Returns - Printed: 9/30/2002 9:06:20 AM ) ) BP EXPLORATION Operations Summary Report Page 7 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/18/2002 05:00 - 05:30 0.50 CASE P INT1 Discontinue Circulating Due To Inability To Move Casing 05:30 - 07:30 2.00 CASE P INT1 RIH With 306 Joints Slowly With 5% Returns To Flow Line - Make Up Space Out Pups - Pick Up Joint 307 And RIH To 12,692' 07:30 - 08:30 1.00 CASE P INT1 Install FMC Flutted Hanger And Landing Joint RIH To Bottom At 12,375' And Land Hanger In Well Head Profile 08:30 - 09:30 1.00 CASE P INT1 Hold Pre-Job Safety Meeting - Rig Down Franks Casing Fill Up Tool-Install Cement Head Adaptor And Cement Head - Make Up Circulation Hose 09:30 - 12:00 2.50 CASE P INT1 Break Circulation At 3 BPM Showing 2% Returns Through Flow Meter - Flow Gradually Increased To 29% Before Stabilizing With Losses At 141 BBLS. -Increase Pump Rate Slowly To 6 BPM With No Losses 12:00 - 12:30 0.50 CASE P INT1 Shut Down Mud Pumps - (Monitor Well) - Load Cement Plugs In Cement Head - Total Mud Given Back From Well 26 BBLS. 12:30 - 14:00 1.50 CASE P INT1 Continue To Circulate Staging Up Rate 10 BPM - At 10 BPM Losses At 2 BPM - Reduce Pump Rate To 6 BPM And Monitor Well No Losses And No Gain - Shut Down And Monitor Well Bore (Static) *Note* Start Batch Mixing Mud Push And Cement Slurry 14:00 - 16:30 2.50 REMCM-P INT1 Hold Pre-Job Safety Meeting Regarding Up Coming Cement Job With All Personal - Turn Over To Dowell - Pump 10 BBL. Fresh Water - Test Lines At 3,500 Psi. - Pump 80 BBLS. CW-100 - Pump 50 BBLS. 12.5 PPG. Mud Push XL Spacer- Drop Bottom Plug - Pump 132 BBLS. Batch Mixed 15.8 PPG Class "G" GASBLOCK Tail Cement Slurry At 6 BPM - Drop Top Plug - Flush Dowell Cement Lines With 10 BBLS. Water- Shut Down And Swap To Rig Pumps For Displacement- Displace With 925 BBLS. Of 10.9 PPG Mud At 11.5 BPM- Slow Pumps To 2 BPM Did Not Bump Plug - Bleed Pressure To 0 Psi. And Check Floats (Floats OK) - Cement In Place At 16:20 Hours 16:30 - 17:30 1.00 REMCM-P INT1 Hold Pre-Job Safety Meeting - Rig Down Dowell Cement Head - Back Out 9 5/8" Landing Joint And Lay Down Same - Rig Down Casing Tools And Clear Rig Floor 17:30 - 18:30 1.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Change Bales To Short Set - Pick Up 5" Drill Pipe Elevators - Service Top Drive Grabber And Install Lower IBOP Valve 18:30 - 20:00 1.50 DRILL P PROD1 Pick Up Joint Of 5" Drill Pipe - Make Up Pack Off Running Tool Install 9 5/8" Pack Off - RIH And Set - Energize And Test At 5,000 Psi. For 10 Minutes (Test Good) 20:00 - 21 :30 1.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Open Doors On Top BOP Gate And Remove Ram Blocks And Change To 41/2" X 7" Variables - Close Doors 21 :30 - 22:30 1.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Install Upper Test Plug And Rig Up Testing Equipment - Fill BOP Equipment With Water 22:30 - 00:00 1.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular At 250 Psi. Low And 2,500 Psi. High - Test Upper And Lower Pipe Rams, Blind Rams, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves, Manual And HCR Valves On The Choke And Kill Lines At 250 Psi. Low And Printed: 9/30/2002 9:06:20 AM ) ) BP EXPLORATION Operations Summary Report Page 8 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/18/2002 22:30 - 00:00 1.50 DRILL P PROD1 4,000 Psi. High - Perform Accumulator Test 9/19/2002 00:00 - 02:30 2.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Continue To Test BOP And Related Equipment 02:30 - 03:00 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Rig Down Testing Equipment - Remove Test Plug - Install Short Bowl Protector (1.0. 8.625) And Energize Lock Down Studs - Test Stand Pipe To 4,000 Psi. (Test Good) 03:00 - 04:00 1.00 DRILL P PROD1 Service Top Drive, Traveling Blocks, And Crown Sheaves 04:00 - 07:00 3.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Bring BHA No.4 Bit And Tools To Rig Floor - Pick Up And Make Up 81/2" Smith Bit And Sperry Sun BHA - Orient MWD/LWD Tools And Initialize Same - Connect Top Drive And Surface Test MWD And Sperry Motor - Hold Pre-Job On Radioactive Source -Install Source And RIH - Continue To Pick Up BHA 07:00 - 12:00 5.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - RIH With 5" Drill Pipe From Mast - Connect Top Drive And Fill Drill String As Needed *Note* Hold Pre-Job Safety Meeting - While RIH With BHA No.4 On Drill Pipe - Rig Up And Pumped Down 13-3/8" x 9-5/8" Annulus Established Injectivity Rate At 2 BPM With 800 Psi. - Rig Up Little Red - Test Lines To 4,000 Psi. Bull Head 133 BBLS. Of Dead Crude Oil Down Annulus To Freeze Protect 12:00 - 13:00 1.00 DRILL P PROD1 Preform Mast Inspection 13:00 - 13:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Continue To RIH With 5" Drill Pipe From Mast To 12,277' 13:30 - 15:30 2.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Slip And Cut 127 Feet Of 1 3/8" Drill Line - Adjust Draw Works Mechanical Brakes - Install Top Drive Blower Hose 15:30 - 16:00 0.50 DRILL P PROD1 RIH With 5" Drill Pipe From Mast To 12,330' - Tag Up On Cement Stringer - POH With Stand Of 5" Drill Pipe To 12,277' 16:00 - 17:00 1.00 DRILL P PROD1 Connect Top Drive Break Circulation - Hold Pre-Job Safety Meeting - Prepare And Test 9 5/8" Casing To 3,500 Psi. Hold For 30 Minutes (Test Good) - Bleed Preasure To 0 Psi. 17:00 - 19:00 2.00 DRILL P PROD1 Drill Cement Stringers From 12,330' To 12,637' - Tag Casing Wiper Rubbers At 12,637' - Drill Wiper Rubbers And Tag Float Collar At 12,639' - Drill Cement To 12,682' 19:00 - 21 :30 2.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Pump 8% "EP" Mud Lube Pill Followed Up With Displacement Of 9.0 PPG BaradrilN Mud - Clean Possom Belly And Under Shakers 21 :30 - 23:30 2.00 DRILL P PROD1 POH To 12,450' - Mad Pass Log For Correlation At 180 Feet Per Hour From 12,450' To 12,682' 23:30 - 00:00 0.50 DRILL P PROD1 Continue To Drill Cement From 12,682' Tag Top Of Float Shoe At 12,724' (Bottom At 12,725') - Wash And Ream 12 1/4" Rat Hole From 12,725' To 12,735' - Drill 8 1/2" New Hole To 12,755' 9/20/2002 00:00 - 00:30 0.50 DRILL P PROD1 Wash And Ream From Casing Shoe To 12,755' - Obtain Slow Pump Rates 00:30 - 02:30 2.00 DRILL P PROD1 Circulate Second "EP" Mud Lube Sweep And Bottoms Up For Formation Integrity Test - Verify 9.0 PPG Mud In And Out 02:30 - 03:00 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Pull Bit In 9 5/8" Casing Shoe Closed Pipe Rams And Performed FIT. Printed: 9/30/2002 9:06:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/20/2002 9/21/2002 Date ) ) BP EXPLORATION Operations Summary Report PS 1-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E 02:30 - 03:00 From - To Hours Task Code NPT Phase PROD1 03:00 - 03:30 03:30 - 06:30 06:30 - 09:30 09:30 - 13:00 13:00 - 15:00 15:00 - 20:00 20:00 - 00:00 00:00 - 03:00 03:00 - 07:00 0.50 DRILL P 0.50 DRILL P PROD1 3.00 DRILL P PROD1 3.00 DRILL P PROD1 3.50 DRILL P 2.00 DRILL P PROD1 PROD1 5.00 DRILL P PROD1 4.00 DRILL P PROD1 3.00 EVAL P PROD1 4.00 EVAL P PROD1 Page 9 of 14 Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Description of Operations Strokes Pmp'd 2 4 6 8 10 12 14 16 17 Pressure 42 psi 110 psi 179 psi 243 psi 311 psi 375 psi 448 psi. 517 psi. 553 psi. Held Test F/10 minutes w/28 Psi. Pressure Loss. MW 9.0 ppg, Csg Shoe TVD 8,195' Pressure 553 psi = 10.30 PPG. EMW. Bleed Pressure To 0 Psi. - Open Pipe Rams Lay Down Pup Joint Pick Up And Stand Back 1 Stand 5" Drill Pipe For 81/2" Hole Section Drill 8 1/2" Hole Section From 12,755' To 12,935' - Weight On Bit 30K To 35K - With Pump Rate At 131 Strokes Or 554 GPM - Off Bottom Pump Pressure At 2150 Psi. & On Bottom Pump Pressure At 2400 Psi. - Top Drive RPM At 100 - Off Bottom Torque At 29K & On Bottom Torque At 27K - String Rotating Weight At 200K - With Pump Off Drag Up At 365K And Drag Down At 155K Hole Attempting To Pack Off - Unable To Rotate Drill String Fast Enough To Clean Hole Due To High Torque - Pump Glass Beads Around While Mixing "EP" Mud Lube Sweep - Pump Out Of The Hole To Casing Shoe - Pump 50 BBLS Water To Clean Casing And 50 BBL Of "EP" Weighted Sweep Around - Torque Reduced From 29K To 14K - Work Back To Bottom At 12,935' Drill 8 1/2" Hole Section From 12,935' To 13,177' Pump Up Survey - Circulate 70 BBL. Hi-Vis Sweep - Monitor Well Bore (Static) - Spot 30 BBL. Logging Pill In Open Hole Hold Pre-Job Safety Meeting - POH Slow To 9 5/8" Casing Shoe (12,653') With "NO" Problems - Monitor Well Bore (Static) - Pump Dry Job - Drop Rabbit With Slick Line Tail Attached - Blow Down Top Drive - POH With 5" Drill Pipe Stand Back In Mast Hold Pre-Job Safety Meeting - Lay Down 5" HWDP, Drilling Jars, And Flex Drill Collars - Pump Fresh Water Thru Sperry Sun MWD / LWD And Mud Motor - Hold Pre-Job Safety Meeting - Remove Radio Active Sources From Logging Tools - Down Load Data From MWD / LWD And Lay Down - Drain Motor And Break Off 8 1/2" Drill Bit - Lay Down Motor And Clear Rig Floor Hold Pre-Job Safety Meeting With Schlumberger - Rig Up Schlumberger - Pick Up BHC Sonic Tools And RIH To TO At 13,177' - Log Open Hole Section And Repeat - POH And Lay Down Tools Make Up USIT Logging Tools - RIH And Log From 95/8" Casing Shoe (12,725') Up To Top Of Cement *NOTE* Good Cement From: Printed: 9/30/2002 9:06:20 AM ) ') BP EXPLORATION Operations Summary Report Page 10 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PS 1-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/21/2002 03:00 - 07:00 4.00 EVAL P PROD1 12,490' To 12,328' (162') 12,206' To 12,060' (136') POH With E-Line And Lay Down USIT Tools - Rig Down Schlumberger - Clear Rig Floor 07:00 - 08:00 1.00 CASE P COMP Hold Pre-Job Safety Meeting - Rig Up To Run 7" 26 lb. L-80 Liner 08:00 - 09:30 1.50 CASE P COMP Hold Pre-Job Safety Meeting - Pick Up Shoe Track And Check Floats - Continue To RIH With 13 Joints Of 7" 26 lb. L-80 BTC Mod Casing Per Program - Change Elevators To 5" Pick Up Baker Liner Hanger And ZXP Packer With Running Tool - Verify That Liner Wiper Plug In Baker Liner Hanger 09:30 - 10:30 1.00 CASE P COMP Hold Pre-Job Safety Meeting - Rig Down Casing Equipment And Clear Rig Floor - RIH With 1 Stand - Circulate 7" Liner Volume *NOTE* Liner Weight At 18K When Full Of Mud 10:30 - 18:00 7.50 CASE P COMP Continue To RIH (Slow) With 5" Drill Pipe From Mast To 9 5/8" Casing Shoe - Fill Every Ten Stands *NOTE* Verify Top Of Cement In The 133/8" X 20" Annulus- Cement Is At The 4" Outlets On Conductor Casing 18:00 - 18:30 0.50 CASE P COMP Pick Up And Torque Baker Cementing Head - Lay Head On Lay Down Machine - Rig Up Circle Chart Recorder 18:30 - 19:30 1.00 CASE P COMP Connect Top Drive And Break Circulation - Circulate And Condition Mud At 3 BPM Stage Pump Rate Up To 8 BPM With 620 Psi. - Up Weight 303K And Down Weight At 165K 19:30 - 20:00 0.50 CASE P COMP RIH To 13,170' With 7" Liner On 5" Drill Pipe From Mast 20:00 - 20:30 0.50 CASE P COMP Pick Up And Make Up Baker Plug Draping Head - Connect Circulating Lines -Break Circulation And Wash Down Tag Bottom At 13,177' 20:30 - 21 :30 1.00 CASE P COMP Circulate And Stage Up Pump Rate To 8 BPM With 950 Psi. - Reciprocate 7" Liner While Batch Mixing Cement 21 :30 - 22:00 0.50 CEMT P COMP Shut Down And Turn Over To Dowell- Pump 5 BBL Fresh Water - Pressure Test Surface Equipment At 4,000 Psi. (Test Good) - Reciprocate Liner - Pump 30 BBLS CW-100 - 30 BBLS 10.0 PPG Mud Push XL Spacer - 40 BBLS 15.8 PPG Class "G" Gas Block Cement Slurry - Shut In Plug Draping Head And Flush Cement Lines 22:00 - 22:30 0.50 CEMT P COMP Drop Drill Pipe Wiper Dart And Displace With 9.0 PPG BaradrillN Mud At 10 BPM With Rig Pumps - Slow Rate And Observe Latch Up Of Liner Wiper Plug Sheared At 1,200 Psi. - Continue To Displace And Bump Plug Final Circulating Pressure At 1,740 Psi. With 242 BBLS Away - Cement In Place At 22:37 Hours 22:30 - 23:00 0.50 CEMT P COMP Pressure Up To 4,000 Psi. - Slack Off 20K And Verify That Liner Hanger Set - Bleed Pressure To 0 Psi. And Check Floats (OK) - Rotate 20 Turns The Right And Release Liner- Pressure Up To 1,000 Psi. Pick Up And Unsting Cups - Observe Pressure Drop And Pump 20 BBLS A 10 BPM - Reduce Pump Rate To 7 BPM - Set Down 70K And Set ZXP Packer. 23:00 - 00:00 1.00 CEMT P COMP Circulate 1.5 Times Annular Volume At 11 BPM 1,220 Psi. - 5 Printed: 9/30/2002 9:06:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Summary Report PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Page 11 of 14 Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/21/2002 23:00 - 00:00 1.00 CEMT P COMP BBL. Cement Back To Surface 9/22/2002 00:00 - 00:30 0.50 CEMT P COMP Hold Pre-Job Safety Meeting - Rig Down Baker Cement Head And Circulating Lines - Pump Dry Job - Blow Down Top Drive 00:30 - 06:00 5.50 CLEAN P COMP Hold Pre-Job Safety Meeting - POH With Baker Liner Running Tool- Stand 5" Drill Pipe Back In Mast - Clean And Lay Down Running Tool - Clear Rig Floor 06:00 - 07:00 1.00 CLEAN P COMP Bring Casing Scrapers & Cross Overs To Rig Floor - Change Slips, Elevators, And Iron Ruffneck Heads To Accept 31/2" Pipe 07:00 - 07:30 0.50 CLEAN P COMP Pick Up 61/8" Bit, 7" Casing Scraper, Cross Overs, (15) Joints Of 31/2" HWDP, (1) Pup Joint And RIH With Same 07:30 - 13:30 6.00 CLEAN P COMP Change Slips, Elevators, And Iron Ruffneck Heads To Accept 5" Pipe - Pick Up 9 5/8" Scrapers And Cross Overs - RIH With 7" And 9 5/8" Casing Scrapers On 5" Drill Pipe From Mast - Travel Thru Top Of 7" Liner Top At 12,615' With No Problems - Continue To RIH (Slow) Thru Liner Tag Cement At 13,062' 13:30 - 14:00 0.50 CLEAN P COMP Connect Top Drive And Break Circulation - Wash And Ream At 10 BPM With 1,600 Psi. From 13,062' To 13,081' 14:00 -17:00 3.00 CLEAN P COMP Hold Pre-Job Meeting - Spot Trucks For Displacement - Pump 25 BBL Barazan Spacer, 50 BBLS Hot Diesel, 25 BBLS Barazan Spacer, 50 BBL Dirt Magnet, 25 BBL Hi-Vis Sweep Followed By 8.4 PPG Sea Water At 10 BPM - 98 Final NTU 17:00 - 17:30 0.50 CLEAN P COMP Shut Down And Flush Kill Line, Choke Line, And Choke Manifold Blow Down Same 17:30 - 18:30 1.00 CLEAN P COMP Make Up Head Pin And Circulating Line - Rig Up Circle Chart Recorder - Pressure Test Casing And Liner To 4,000 Psi For 30 Minutes (Test Good) 18:30 - 19:00 0.50 CLEAN P COMP Pump Dry Job And Blow Down Top Drive 19:00 - 00:00 5.00 CLEAN P COMP Hold Pre-Job Safety Meeting - POH Laying Down 160 Joints Of 5" Drill Pipe 9/23/2002 00:00 - 00:30 0.50 CLEAN P COMP Hold Pre-Job Safety Meeting - Service And Inspect Can-Rig Top Drive, Traveling Blocks, And Lay Down Machine 00:30 - 05:00 4.50 CLEAN P COMP Hold Pre-Job Safety Meeting - Continue To POH Laying Down 5" Drill Pipe To BHA 05:00 - 07:00 2.00 CLEAN P COMP Change Slips, Elevators, And Iron Ruffneck Heads To Accept 3 1/2" Pipe - Lay Down 9 5/8" Casing Scraper And Cross Overs - 15 Joints Of 3 1/2" HWDP - 7" Casing Scraper 07:00 - 07:30 0.50 RUNCOIVP COMP Clear Rig Floor - Pull Wear Bushing And Break Down FMC Running Tool 07:30 - 08:30 1.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Bring Casing Tools To Rig Floor And Rig Up To Run 7" Tail Pipe Assembly 08:30 - 09:30 1.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - RIH With 7" Completion Tail Pipe And Baker Lock Connection Between 7" TC-11 Pup Joints- Pick Up Baker SABL-3 Packer And Polished Bore Receptacle - Make Up HES "R" Nipple Assembly 09:30 - 1 0:30 1.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Change Eleavtors And Slips To Accept 75/8" Tubing - Rig Up Scaffolding For Tong Operator 1 0:30 - 00:00 13.50 RUNCOIVP COMP Pick Up And RIH With 240 Joints Of 75/8" 29.70 lb. L-80 STL Tubing Per Well Program - While Monitoring Returns To Trip Tank. Record The Following Up And Down Weights. 3,000 Feet - 128K Up And 125K Down Printed: 9/30/2002 9:06:20 AM ) ) BP EXPLORATION Operations Summary Report Page 12 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PS 1-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2002 10:30 - 00:00 13.50 RUNCOIVP COMP 6,000 Feet - 182K Up And 157K Down 9,000 Feet - 250K Up And 175K Down 9/24/2002 00:00 - 04:00 4.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting With Crew Members Coming On Tour - Continue To Pick Up And RIH With 308 Joints Of 75/8" 29.70 lb. L-80 STL Tubing - Pick Up (2) Each Pup Joints For Space Out - Pick Up Joint No. 309 And RIH 04:00 - 05:00 1.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Remove 200 Ton 75/8" Elevators And Install 5" Drill Pipe Elevators - Pick Up (1) Single Of 5" Drill Pipe And (1) 15' Pup Joint With Cross Overs - RIH To 12,589' Wire Line Entry Guide Depth 05:00 - 07:00 2.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Rig Up Schlumberger - Make Up Collar Locator Tools And RIH - Verify That 7" X 4 1/2" RBX Reducer With RHC-M Plug Seated In "R" Nipple Located At 12,564' Tag Up At 12,563' Wire Line Measurement - POH With E-Line And Rig Down Schlumberger 07:00 - 09:30 2.50 RUNCOIVP COMP Drop Ball And Rod - Make Up Floor Valve, Head Pin, And Circulating Hose - Rig Up Circle Chart Recorder - Place Baker SABL-3 Packer On Setting Depth @ (Top 12,535' - Bottom 12,540') Wire Line Entry Guide @ 12,584' - Clear Non Essential Personal From Rig Floor During Packer Setting Process - Pressure Up To 500 Psi - Continue Up To 1,000 Psi And Hold Pressure For 5 Minutes - Increase Pressure To 1,750 Psi. - Slack Off On Completion String (Packer Not Set) - Bleed Pressure To 0 Psi. And Reposition Baker Packer On Setting Depth - Pressure Up To 1,750 Psi. And Slack Off On Completion String (Packer Not Set) - Bleed Pressure To 0 Psi. And Reposition Packer - Pressure Up To 2,000 Psi. Slack Off 40K (Packer Set) - Continue To Pressure Up To 2,500 Psi. And Hold For 15 Minutes - Bleed On Tubing To Pressure To 0 Psi. - Pressure Test Annulus To 1,000 Psi. Hold For 15 Minutes No Returns From Tubing After Pressure Build Up - Bleed Pressure Off Annulus - Work To Shear Out Of PBR - Normal Up Weight @ 330K Continue To Pick Up Tubing String To 400K To Shear PBR (NO GOOD) - Apply 1,000 Psi. Down Tubing And Pick Up Completion String To 400K To Shear PBR (NO GOOD) - Apply 1,500 Psi. Down Tubing And Pick Up Completion String To 390K Shear Off PBR 09:30 - 11 :00 1.50 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Place Single Of Drill Pipe In Mouse Hole And Lay Down 15' Pup Joint - Make Up FMC Tubing Hanger With Pup - Install 7" NSCC X 4 1/2" IF Crossover Pick Up Single Of Drill Pipe With Circulating Lines 11 :00 - 13:00 2.00 RUNCOIVP COMP With Seals Above PBR Circulate Hi-Vis Sweep Around To Remove Haul Road Dirt - Final NTU At 68 13:00 - 14:30 1.50 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Line Up Equipment To Reverse Circulate Inhibited Sea Water And Diesel - Reverse Circulate 178 Barrels Inhibiated Seawater At 5 BPM - Pressure Test Little Reds Lines To 4,000 Psi. And Pump 138 Barrels Of Diesel At 3 BPM 14:30 - 16:00 1.50 RUNCOIVP COMP U-Tube Annulus To Tubing Thru Kill Line - Drain BOP Stack 16:00 -17:00 1.00 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Land FMC Tubing Hanger And Energize Lock Down Studs 17:00 - 18:30 1.50 RUNCOIVP COMP Hold Pre-Job Safety Meeting - Record On Pressure Chart The Printed: 9/30/2002 9:06:20 AM ) ) BP EXPLORATION Operations Summary Report Page 13 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-08 PSI-08 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/24/2002 17:00 - 18:30 1.50 RUNCOIVP CaMP Test On Tubing For 30 Minutes At 4,000 Psi. - Bleed To 2,200 Psi. - Pressure Test Annulus At 4,000 Psi. For 30 Minutes - Bleed Annulus To 0 Psi. And Bleed Tubing To 0 Psi. *NOTE* The AOGCC Plans To Witness A Test After Injection Process Started And Warmed Up. 18:30 - 19:30 1.00 RUNCOIVP CaMP Hold Pre-Job Safety Meeting - Back Out Land Joint And Break Off Cross Over - Pick Up T-Bar And Install Cameron Two Way Check Valve - Test Two Way Check Valve To 1,000 Psi. - RIH With Landing Joint Stop Above Tubing Hanger - Pump Down Kill Line And Landing Joint And Float Out Diesel From BOP Equipment 19:30 - 21:00 1.50 RUNCOIVP CaMP Flush Mud Lines, Choke Lines, And Kill Lines With Fresh Water - Close Annular Element And Blow Air Into Kill Line Pushing Fluid Up Landing Joint - Open Annular And Lay Down Landing Joint 21 :00 - 00:00 3.00 RUNCOIVP CaMP Hold Pre-Job Safety Meeting - Open Doors On BOP Gates And Remove Ram Blocks - Grease Up Ram Cavities And Close Doors 9/25/2002 00:00 - 04:00 4.00 RUNCOIVP CaMP Hold Pre-Job Safety Meeting - Continue To Remove Ram Blocks And Nipple Down 13 5/8" BOP Stack And Related Equipment - Set BOP On Stand And Secure 09:00 - 00:00 15.00 DEMOB P POST Nabors Rig 27E Released From Well PSI-08 At 0900 Hours On 09/25/02 - Slip 128 Feet 1 3/8" Drill Line On To Draw Works- Remove Top Drive Blower Hose - Remove All Handling Tools From Rig Floor - Remove Kelly Hose And Cementing Stand Pipe - Remove Lay Down Machine Skate Rail - Remove IBOP Valves From Top Drive And Power Wash - Remove Pump Liners And Valve Seats And Complete Maintance On Emsco Pumps - Power Wash Mast Lower Section And Clean Mud System 04:00 - 06:30 2.50 RUNCOIVP CaMP Hold Pre-Job Safety Meeting - Nipple Up FMC Adapter Flange And 7 1/16 5M Production Tree 06:30 - 07:30 1.00 RUNCOIVP CaMP Hold Pre-Job Safety Meeting - Test Adaptor Flange Void And Production TreeTo 5,000 Psi. For 10 Minutes 07:30 - 08:30 1.00 RUNCOIVP CaMP Hold Pre-Job Safety Meeting With Drill Site Maintenance - Rig Up And Pull Two Way Check Valve And Install Back Pressure Valve 08:30 - 09:00 0.50 RUNCOIVP CaMP Remove Otis Flange And Upper Valve From Tree For Clearance When Pulling Sub Base From Well- Pick Up Tools And Equipment From Cellar - Secure Well Head And Tree Nabors Rig 27E Released From Well PSI-08 At 0900 Hours On 09/25/02 9/26/2002 00:00 - 12:00 12.00 DEMOB P POST Hold Pre-Job Safety Meeting - Power Wash "C' Section Wind Walls - Remove Electrical And Hydraulic Service Loops From Can Rig Top Drive - Cover Goose Neck Opening, Spark Arrester, And Blower Hose Opening - Grease Balyor Elmago Brake 12:00 - 00:00 12.00 DEMOB P POST Remove Flow Line Section And Clean Out Solids - Remove Ram Blocks From Sub Base Landings - Move Pipe Sheds And Stage At End Of Pad - Power Wash Celler Area - Continue To Printed: 9/30/2002 9:06:20 AM ) "')- / BP EXPLORATION Operations Summary Report Page 14 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OB PSI-OB DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 9/3/2002 Rig Release: 9/26/2002 Rig Number: 27E Spud Date: 9/4/2002 End: 9/26/2002 Date From - To Hours Task Code NPT Phase Description of Operations 9/26/2002 12:00 - 00:00 12.00 DEMOB P POST Clean Mud Pit System - Remove Matting Board Ramps At Tools Slide And Dry Sack Room - Load Out Matting Boards From Under Casing House- Remove FMC Quick Connect From 21 1/4" Diverter Spool And Grease Flanges 9/27/2002 00:00 - 12:00 12.00 DEMOB P POST Hold Pre-Job Safety Meeting - Change Oil In Rotary Table And Clean Out Under Same - Continue To Clean Celler Area - Preform Stack Out Procedures On Mud Pit System - Preform Zoniallnspection On Mast And Dress Out Mast To Lay Down 12:00 - 00:00 12.00 DEMOB P POST Prepare Top Drive And Lay Down Same - Frame In Hall Ways - Preform Stack Out Procedures On NO.1 And NO.2 0399 Prime Movers 9/28/2002 00:00 - 12:00 12.00 DEMOB P POST Continue With Demolilization And Cleaning Of Nabors Rig 27E - Unbolt Top Drive Carrier From Mast And Lower To Rig Floor- Remove Cattle Shoot And Load Out Same 12:00 - 00:00 12.00 DEMOB P POST Lay Top Drive On Floor Peak Crane Unable To Pick Due To Computer Logic On Whip Line And Main Load Line - Prepare Mast To Lay Over String Up Bridal Line's - Blow Down Mud Pit System - Disconnect Cuttings Tank - Transport Two Pipe Shed Units And Mud Pump Room To Nabors Yard 9/29/2002 00:00 - 00:00 24.00 DEMOB POST CONTINUE DEMOBILIZATION. INSPECT BRIDLE LlNE- SOME DAMAGE. TAKE PHOTOS & SEND TO TOWN. WAIT ON GO AHEAD. OPEN DOORS AND HATCHES ON ROOF. SKID MOTOR COMPLEX FOR WORKING ROOM. LAY OVER DERRICK. UNPIN & LAY DOWN DERRICK BOARD. UNSPOOL DRILLING LINE. BLOW DOWN STEAM, SUCK OUT HOT WELL & WATER TANKS. PREPARE MOTORS & PITS FOR MOVE TO YARD. 9/30/2002 00:00 - 0.00 DEMOB POST Printed: 9/30/2002 9:06:20 AM ') ) Well: Field: API: Permit: PSI-08 Prudhoe Bay Unit 50-029-23114-00 202-172 Rig Accept: 09/04/02 Rig Spud: 09/04/02 Rig Release: 09/25/02 Drilling Rig: Nabors 27E POST RIG WORK 10/08/02 PULLED BALL& ROD. PULLED 4 1/2" "RHC-M" PLUG BODY. PULLED 7" X 4 1/2" NIPPLE REDUCER. DRIFTED TO 13,046' WLM WI 11' X 3.50 DUMMY GUN. RAN SAMPLE BAILER TO 13,076 MD (13,046' WLM), OBTAINED SAMPLE OF CEMENT, TURNED SAMPLE IN TO BP OFFICE. LEFT WELL SHUT IN. 1 0/14/02 PERFORMED ONE TEMPERATURE PASS FROM 9500' TO TD (13082'). STOP COUNTS TAKEN AT TD PRESSURE = 3750.6 PSI, TEMP = 169.0 DEGF. LOGGED UP JEWELRY PASS FROM TD TO 9500'. 10/15/02 PERFORMED TWO TEMPERATURE PASSES AT 40 FPM DOWN FROM 9500' TO TD (13085').15 MIN STOP COUNT TAKEN @ 13000' (PRESS = 3867.8 PSI, TEMP = 167.8 DEGF). LOGGED JEWELRY PASS FROM TD TO 9500'. 1 0/18/02 PERFORATE 13020-13080 IN TWO RUNS WI 3 3/8" (6 SPF) 30 FOOT HSD GUNS. TAGGED TD @ 13,082' MD. - AT SURFACE WI ALL SHOTS FIRED. NO PRESSURE CHANGE WITH PERFORATIONS. WILL CONTINUE WI IPERFS IN AM. WELL SHUT IN - DSO NOTIFIED. 1 0/19/02 RIH WI TWO 30-FOOT 33/8" HSD 6-SPF GUNS. PERFORATED FROM 12960'-13020'. ALL SHOTS FIRED. RIH WI TEMPIPRESS TOOLSTRING FOR SBHP. OBTAINED PRESSURE FOR 75 MINUTES @ 13000'MD=8640'TVD. TÄGGED TD ON ALL RUNS @ 13082' MD. LEFT WELL SHUT IN AND NOTIFIED DSO OF WELL STATUS. 11/02102 T/I/O=1175/80/220 MITIA TO 2100 PSI PASSED (AOGCC WITNESSED, JEFF JONES); INITIAL IA FL AT SURFACE. MITIA LOST 20 PSI IN THE FIRST 15 MINUTES AND GAINED 20 PSI IN THE SECOND 15 MINUTES FOR A TOTAL LOSS OF 0 PSI IN 30 MINUTES. PUMPED 4 BBLS OF 60/40 METHANOL DOWN THE IA. FINAL WHP'S = 1175/150/220 ) .> ata-J~ 08-0ct-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well PSI-08 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment( s) RECEIVED OCT 0 9 Alaska O¡.; & Gas Cons. Commi$8ion Anchcf8gld Sperry-Sun Drilling Services North Slope Alaska BPXA Lisburne PSI (East Dock) PSI-DB. Gyro Job No. AKF022145, Surveyed: 20 September, 2002 Survey Report 7 October, 2002 Your Ref: API 500292311400 Surface Coordinates: 5966169.23 N, 708024.82 E (70018' 39.3442" N, 148018' 50.9414" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 966169.23 N, 208024.82 E (Grid) Surface Coordinates relative to Structure: 122.48 N, 267.31 E(True) Kelly Bushing: 51.0Off above Mean Sea Level Elevation relative to Project V Reference: 51.00ff Elevation relative to Structure: 51.00ff 5pt:11.......''-'Y-SUI1 ORIL.LING SEAVlê:és A Halliburton Company DEF N T VE Survey Ref: svy11306 Sperry-Sun Drilling Services. Survey Report for Lisburne PSI (East Dock) - PSI-OB Gyro Your Ref: API 500292311400 Job No. AKF022145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -51.00 0.00 O.OON 0.00 E 5966169.23 N 708024.82 E 0.00 Tolerable Gyro 168.00 0.250 257.000 117.00 168.00 0.08S 0.36W 5966169.14 N 708024.47 E 0.149 0.13 260.00 0.500 260.000 209.00 260.00 0.20S 0.95W 5966169.01 N 708023.88 E 0.272 0.36 359.00 1.500 306.000 307.98 358.98 0.49 N 2.42 W 5966169.65 N 708022.39 E 1.220 1.75 .~. 446.00 2.300 304.000 394.93 445.93 2.13 N 4.79W 5966171.23 N 708019.97 E 0.923 4.43 537.00 4.200 306.000 485.78 536.78 5.11 N 9.00W 5966174.09 N 708015.68 E 2.091 9.24 628.00 6.900 326.000 576.36 627.36 11.61 N 14.75 W 5966180.42 N 708009.75 E 3.607 17.83 817.00 8.000 318.000 763.76 814.76 30.79 N 29.90 W 5966199.18 N 707994.07 E 0.799 42.20 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 326.400° (True). Magnetic Declination at Surface is 26.325°(04-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 817.00ft., The Bottom Hole Displacement is 42.92ft., in the Direction of 315.840° (True). Survey tool proaram for PSI-DB Gvro _. From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 817.00 814.76 Tolerable Gyro --.----'------------"--------- 7 October, 2002 - 17:09 Page 2 of 2 DrillQuest 3.03.02.002 ) afB~ 7J~ 08-0ct-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well PSI-08 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD , M D (if applicable) 13,177.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED OCT 0 9 2002 AlaaIœ or; & Gas Cons Co .. Anchorag~ mmlhion Sperry-Sun Drilling Services ~o~, North Slope Alaska BPXA Lisburne, PSI (East Dock) PSI-DB Job No. AKZZ22145, Surveyed: 20 September, 2002 Survey Report 7 October, 2002 .--" Your Ref: API 500292311400 Surface Coordinates: 5966169.23 N, 708024.82 E (70018' 39.3442" N, 148018' 50.9414" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 966169.23 N, 208024.82 E (Grid) Surface Coordinates relative to Structure: 122.48 N, 267.31 E{True) Kelly Bushing: 51.00ft above Mean Sea Level Elevation relative to Project V Reference: 51.00ft Elevation relative to Structure: 51.00ft 5pE1"""Y-!SUI! OAtL.LING SeAVac:eS A Halliburton Company DEFN, rVE Survey Ref: svy11331 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-OB Your Ref: API 500292311400 Job No. AKZZ22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 817.00 8. 000 318.000 763.76 814.76 30.79 N 29.90 W 5966199.18 N 707994.07 E 42.20 AK-6 BP_IFR-AK 954.71 6.530 326.180 900.37 951.37 44.42 N 40.68 W 5966212.51 N 707982.93 E 1.303 59.51 1048.91 6.900 328.170 993.92 1044.92 53.68 N 46.64 W 5966221.60 N 707976.71 E 0.464 70.52 1143.94 7.450 336.460 1088.21 1139.21 64.18 N 52.11 W 5966231.94 N 707970.95 E 1 .232 82.29 ~ 1238.72 7.650 335.080 1182.17 1233.17 75.53 N 57.22 W 5966243.15 N 707965.52 E 0.285 94.58 1332.93 9.790 330.740 1275.28 1326.28 88.21 N 63.78 W 5966255.64 N 707958.62 E 2.375 108.77 1427.06 10.540 332.760 1367.94 1418.94 102.85 N 71.63 W 5966270.05 N 707950.36 E 0.882 125.30 1521.38 12.490 331.690 1460.35 1511.35 119.50 N 80.42 W 5966286.45 N 707941.12 E 2.080 144.04 1615.99 11 .200 332.260 1552.95 1603.95 136.64 N 89.55 W 5966303.33 N 707931.52 E 1.369 163.36 1709.96 10.840 338.620 1645.19 1696.19 152.94 N 97.02 W 5966319.43 N 707923.60 E 1.348 181.08 1805.38 13.220 337.660 1738.51 1789.51 171.39 N 104.44 W 5966337.66 N 707915.67 E 2.503 200.55 1898.10 14.220 330.110 1828.59 1879.59 191.07 N 114.14 W 5966357.07 N 707905.43 E 2.210 222.32 1992.32 13.710 331 .170 1920.02 1971.02 210.89 N 125.30 W 5966376.57 N 707893.73 E 0.606 244.99 2083.13 18.440 329.380 2007.26 2058.26 232.69 N 137.81 W 5966398.01 N 707880.62 E 5.237 270.07 2129.80 21.240 326.070 2051.15 2102.15 246.06 N 146.29 W 5966411.14 N 707871.77 E 6.462 285.90 2178.25 22.730 328.850 2096.08 2147.08 261.35 N 156.03 W 5966426.16 N 707861.61 E 3.750 304.03 2272.28 24.410 331.610 2182.26 2233.26 293.99 N 174.67 W 5966458.27 N 707842.08 E 2.137 341 .53 2366.18 26.120 326.960 2267.19 2318.1 9 328.40 N 195.17 W 5966492.09 N 707820.63 E 2.789 381.53 2458.88 28.350 325.960 2349.61 2400.61 363.74 N 218.61 W 5966526.78 N 707796.21 E 2.456 423.95 2551.78 31 .680 324.410 2430.04 2481.04 401.87 N 245.17 W 5966564.16 N 707768.62 E 3.680 470.40 2645.29 34.720 323.130 2508.28 2559.28 443.15 N 275.44 W 5966604.58 N 707737.21 E 3.336 521.54 ~ 2740.22 37.520 318.150 2584.97 2635.97 486.33 N 310.96 W 5966646.76 N 707700.50 E 4.272 577.16 2833.28 42.830 315.510 2656.05 2707.05 530.04 N 352.07 W 5966689.32 N 707658.20 E 5.991 636.32 2928.83 46.380 317.480 2724.07 2775.07 578.72 N 398.22 W 5966736.70 N 707610.72 E 3.987 702.40 3022.72 49.550 320.740 2786.94 2837.94 631.45 N 443.82 W 5966788.14 N 707563.68 E 4.248 771.55 3116.61 52.180 325.980 2846.22 2897.22 689.88 N 487.20 W 5966845.35 N 707518.70 E 5.155 844.23 3205.85 56.050 330.030 2898.53 2949.53 751.20 N 525.43 W 5966905.59 N 707478.78 E 5.684 916.46 3304.25 58.880 331 .120 2951.45 3002.45 823.45 N 566.17 W 5966976.68 N 707436.05 E 3.024 999.19 3397.55 59.130 327.390 2999.51 3050.51 892.17 N 607.05 W 5967044.24 N 707393.29 E 3.437 1079.04 3492.92 58.750 327.490 3048.71 3099.71 961.03 N 651.02 W 5967111.85 N 707347.43 E 0.408 1160.73 3587.91 57.730 327.580 3098.71 3149.71 1029.17 N 694.37 W 5967178.77 N 707302.20 E 1.077 1241.48 3684.32 59.010 326.760 3149.27 3200.27 1098.14 N 738.88 W 5967246.48 N 707255.80 E 1.512 1323.56 3777.17 58.260 327.520 3197.60 3248.60 1'164.74 N 781.90 W 5967311.86 N 707210.96 E 1.068 1402.83 3871.41 57.940 327.390 3247.40 3298.40 1232.18 N 824.94 W 5967378.09 N 707166.07 E 0.359 1482.82 3964.27 57.020 326.600 3297.32 3348.32 1297.84 N 867.59 W 5967442.54 N 707121.62 E 1.223 1561.12 ..~..._-_.~_._----_._-.,~._------._-_._~--~~------ ---^-'-"_U~'--._.>-.._-'-"~'----_._'._" ..._-._--_._.~.~-- ----.---..--- 7 October, 2002 - 17:08 Page 20f6 DríllQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-08 Your Ref: API 500292311400 Job No. AKZZ22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (01100ft) 4057.71 59.380 325.920 3346.56 3397.56 1363.87 N 911.70W 5967507.33 N 707075.69 E 2.600 1640.52 4151.25 58.340 326.350 3394.93 3445.93 1430.35 N 956.31 W 5967572.54 N 707029.26 E 1.179 1720.58 4245.67 59.850 326.450 3443.42 3494.42 1497.83 N 1001.14 W 5967638.75 N 706982.57 E 1.602 1801.59 4335.31 58.370 326.520 3489.44 3540.44 1561.96 N 1043.61 W 5967701.68 N 706938.34 E 1.652 1878.52 4431.41 59.420 327.460 3539.09 3590.09 1630.96 N 1088.44 W 5967769.41 N 706891.62 E 1.377 1960.79 .-. 4525.62 61.410 326.140 3585.60 3636.60 1699.50 N 1133.30 W 5967836.69 N 706844.88 E 2.438 2042.71 4618.36 60.060 326.160 3630.93 3681.93 1766.69 N 1178.36 W 5967902.60 N 706797.97 E 1.456 2123.61 4712.52 59.300 326.360 3678.47 3729.47 1834.28 N 1223.51 W 5967968.92 N 706750.97 E 0.828 2204.89 4805.67 58.590 326.610 3726.52 3777.52 1900.81 N 1267.57 W 5968034.20 N 706705.08 E 0.796 2284.69 4900.45 56.980 326.930 3777.05 3828.05 1967.89 N 1311.52 W 5968100.03 N 706659.30 E 1.723 2364.88 4995.23 58.210 327.220 3827.84 3878.84 2035.05 N 1355.01 W 5968165.97 N 106613.96 E 1.323 2444.89 5088.41 59.610 328.540 3875.95 3926.95 2102.63 N 1397.43 W 5968232.35 N 706569.69 E 1.931 2524.65 5182.46 59.400 327.490 3923.68 3974.68 2171.37 N 1440.35 W 5968299.87 N 706524.87 E 0.988 2605.66 5277.00 58.860 326.790 3972.19 4023.19 2239.53 N 1484.38 W 5968366.79 N 706478.97 E 0.854 2686.80 5371.59 57.450 328.4 70 4022.10 4073.10 2307.39 N 1527.40 W 5968433.42 N 706434.09 E 2.121 2767.13 5465.76 59.030 328.980 4071.67 4122.67 2375.82 N 1568.97 W 5968500.68 N 706390.64 E 1.740 2847.13 5560.51 59.250 329.100 4120.27 4171.27 2445.57 N 1610.81 W 5968569.24 N 706346.89 E 0.256 2928.38 5655.04 59.240 328.030 4168.61 4219.61 2514.88 N 1653.17 W 5968637.35 N 706302.62 E 0.973 3009.55 5750.51 58.930 327.770 4217.66 4268.66 2584.27 N 1696.70 W 5968705.50 N 706257.19 E 0.400 3091.43 5843.42 58.790 328.010 4265.70 4316.70 2651.62 N 1738.97 W 5968771.67 N 706213.07 E 0.268 3170.92 5939.06 58.990 327.370 4315.12 4366.12 2720.83 N 1782.74 W 5968839.63 N 706167.40 E 0.610 3252.79 6031.84 58.920 327.740 4362.97 4413.97 2787.91 N 1825.38 W 5968905.51 N 706122.91 E 0.350 3332.26 ,"-" 6126.65 58.060 329.260 4412.52 4463.52 2856.82 N 1867.62 W 5968973.22 N 706078.78 E 1.640 3413.03 6218.89 59.450 328.270 4460.37 4511.37 2924.25 N 1908.51 W 5969039.49 N 706036.04 E 1.764 3491.82 6312.66 60.310 327.390 4507.42 4558.42 2992.90 N 1951.70 W 5969106.92 N 705990.96 E 1 .225 3572.91 6406.01 59.400 328.030 4554.30 4605.30 3061.14 N 1994.82 W 5969173.94 N 705945.97 E 1.141 3653.61 6492.00 59.290 327.510 4598.14 4649.14 3123.72 N 2034.28 W 5969235.40 N 705904.80 E 0.536 3727.56 6585.77 59.710 326.940 4645.74 4696.74 3191.65 N 2078.01 W 5969302.09 N 705859.19 E 0.689 3808.35 6680.54 60.320 325.560 4693.10 4744.10 3259.89 N 2123.62 W 5969369.05 N 705811.72 E 1.416 3890.43 6768.79 60.840 326.350 4736.45 4787.45 3323.59 N 2166.65 W 5969431.53 N 705766.93 E 0.977 3967.29 6867.19 60.090 326.270 4784.96 4835.96 3394.82 N 2214.14 W 5969501.42 N 705717.49 E 0.765 4052.91 6959.27 60.520 326.960 4830.57 4881.57 3461.61 N 2258.15 W 5969566.96 N 705671.64 E 0.801 4132.89 7055.42 60.460 327.010 4877.93 4928.93 3531.78 N 2303.75 W 5969635.84 N 705624.13 E 0.077 4216.56 7150.64 59.480 324.450 4925.59 4976.59 3599.90 N 2350.15 W 5969702.65 N 705575.85 E 2.545 4298.99 7238.26 59.500 323.670 4970.08 5021.08 3661.02 N 2394.46 W 5969762.51 N 705529.87 E 0.767 4374.41 ----------.- .- -.--~--_._~.--~>----_. 7 October, 2002 - 17:08 Page 3 of6 DrillQllest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-D8 Your Ref: API5002923114Ø0 Job No. AKZZ22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7337.25 60.010 323.740 5019.94 5070.94 3729.94 N 2445.08 W 5969830.01 N 705477.36 E 0.519 4459.83 7432.06 61.510 325.150 5066.25 5117.25 3797.24 N 2493.17 W 5969895.95 N 705427.42 E 2.046 4542.51 7525.50 59.860 325.920 5112.00 5163.00 3864.41 N 2539.28 W 5969961.82 N 705379.46 E 1.906 4623.97 7619.68 58.270 327.040 5160.41 5211.41 3931.75N 2583.90 W 5970027.90 N 705333.00 E 1.972 4704.75 7713.84 57.000 325.190 5210.82 5261.82 3997.78 N 2628.23 W 5970092.67 N 705286.86 E 2.138 4784.27 .- 7807.88 57.160 324.920 5261.93 5312.93 4062.48 N 2673.44 W 5970156.10 N 705239.87 E 0.295 4863.19 7902.98 57.330 324.750 5313.38 5364.38 4127.87 N 2719.50 W 5970220.18 N 705192.01 E 0.234 4943.14 7996.39 57.220 323.880 5363.88 5414.88 4191.69 N 2765.34 W 5970282.71 N 705144.42 E 0.792 5021.67 8090.16 56.150 324.840 5415.38 5466.38 4255.37 N 2811.01 W 5970345.10 N 705097.02 E 1.426 5099.98 8185.14 57.370 323.450 5467.44 5518.44 4319.75 N 2857.54 W 5970408.17 N 705048.72 E 1.774 5179.35 8280.70 59.530 325.040 5517.45 5568.45 4385.84 N 2905.11 W 5970472.91 N 704999.34 E 2.668 5260.72 8375.67 60.010 324.250 5565.26 5616.26 4452.76 N 2952.59 W 5970538.49 N 704950.02 E 0.879 5342.73 8467.38 59.900 324.990 5611 . 18 5662.18 4517.48 N 2998.55 W 5970601.92 N 704902.28 E 0.709 5422.08 8562.66 59.420 324.960 5659.31 5710.31 4584.82 N 3045.75 W 5970667.92 N 704853.24 E 0.505 5504.29 8656.01 59.490 326.050 5706.75 5757.75 4651.08 N 3091.28 W 5970732.90 N 704805.89 E 1.008 5584.67 8748.89 59.340 326.860 5754.01 5805.01 4717.72 N 3135.46 W 5970798.29 N 704759.88 E 0.768 5664.63 8845.13 59.370 325.420 5803.07 5854.07 4786.47 N 3181.59 W 5970865.74 N 704711.86 E 1.288 5747.42 8939.68 59.720 323.150 5850.99 5901.99 4852.64 N 3229.17 W. 5970930.56 N 704662.47 E 2.102 5828.86 9033.50 60.030 323.340 5898.08 5949.08 4917.66 N 3277.73 W 5970994.21 N 704612.13 E 0.374 5909.89 9125.15 60.420 323.280 5943.59 5994.59 4981.45 N 3325.26 W 5971056.65 N 704562.85 E 0.429 5989.32 9219.69 59.120 323.960 5991 .19 6042.19 5047.21 N 3373.71 W 5971121.05 N 704512.60 E 1.509 6070.91 9314.20 58.380 324.150 6040.22 6091.22 5112.62 N 3421.14 W 5971185.12 N 704463.37 E 0.802 6151.64 ~ 9408.31 58.970 324.260 6089.15 6140.15 5177.83 N 3468.16 W 5971249.00 N 704414.57 E 0.635 6231.97 9503.10 59.340 324.500 6137.75 6188.75 5243.98 N 3515.55 W 5971313.82 N 704365.35 E 0.447 6313.30 9596.87 59.830 324.520 6185.22 6236.22 5309.82 N 3562.50 W 5971378.33 N 704316.60 E 0.523 6394.12 9690.49 60.090 324.550 6232.09 6283.09 5375.83 N 3609.52 W 5971443.01 N 704267.77 E 0.279 6475.12 9784.79 59.920 324.840 6279.23 6330.23 5442.48 N 3656.72 W 5971508.33 N 704218.74 E 0.322 6556.76 9878.79 60.310 324.520 6326.07 6377.07 5508.98 N 3703.84 W 5971573.50 N 704169.80 E 0.509 6638.22 9972.47 60.940 324.820 6372.02 6423.02 5575.58 N 3751.05 W 5971638.77 N 704120.76 E 0.728 6719.82 10066.54 60.590 324.050 6417.96 6468.96 5642.36 N 3798.79 W 5971704.19 N 704071.19 E 0.805 6801.86 10162.11 60.280 324.420 6465.12 6516.12 5709.81 N 3847.38 W 5971770.27 N 704020.75 E 0.468 6884.92 10257.50 60.190 324.380 6512.47 6563.47 5777.14 N 3895.58 W 5971836.24 N 703970.70 E 0.101 6967.68 10350.00 60.370 324.300 6558.33 6609.33 5842.40 N 3942.41 W 5971900.18 N 703922.08 E 0.209 7047.96 10444.17 60.090 324.180 6605.09 6656.09 5908.74 N 3990.18 W 5971965.17 N 703872.49 E 0.317 7129.64 10538.40 60.760 324.980 6651.60 6702.60 5975.52 N 4037.68 W 5972030.61 N 703823.17 E 1.025 7211.55 --_.-_.--------~------+-_.+------------------ 7 October, 2002 - 17:08 Page 4 of6 DrillQllest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI..()8 Your Ref: API 500292311400 Job No. AKZZ22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. AZim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10631.61 60.530 325.380 6697.29 6748.29 6042.22 N 4084.06 W 5972096.00 N 703774.95 E 0.448 7292.78 10722.27 60.070 325.840 6742.21 6793.21 6107.20 N 4128.54 W 5972159.72 N 703728.69 E 0.672 7371.52 10817.55 59.870 325.510 6789.89 6840.89 6175.33 N 4175.06 W 5972226.53 N 703680.30 E 0.366 7454.00 10909.26 60.220 325.520 6835.68 6886.68 6240.82 N 4220.05 W 5972290.76 N 703633.52 E 0.382 7533.45 .~ 11004.45 59.900 325.500 6883.19 6934.19 6308.81 N 4266.76 W 5972357.43 N 703584.94 E 0.337 7615.93 11098.27 59.600 325.640 6930.46 6981.46 6375.66 N 4312.58 W 5972422.98 N 703537.28 E 0.345 7696.96 11193.49 59.260 325.330 6978.89 7029.89 6443.21 N 4359.03 W 5972489.22 N 703488.98 E 0.454 7778.94 11286.46 57.860 326.720 7027.38 7078.38 6508.98 N 4403.36 W 5972553.74 N 703442.84 E 1.973 7858.25 11379.09 55.570 326.480 7078.21 7129.21 6573.62 N 4445.99 W 5972617.17 N 703398.45 E 2.482 7935.68 11473.80 54.450 325.960 7132.52 7183.52 6638.12 N 4489.12 W 5972680.45 N 703353.54 E 1.265 8013.27 11568.72 52.440 326.510 7189.05 7240.05 6701.50 N 4531.50 W 5972742.63 N 703309.42 E 2.168 8089.51 11661,91 48. 740 327.100 7248.21 7299.21 6761.73 N 4570.92 W 5972801.75. N 703268.35 E 4.000 8161.50 11755.12 45.680 326.550 7311.52 7362.52 6818.98 N 4608.34 W 5972857.94 N 703229.36 E 3.311 8229.89 11850.26 42.590 326.960 7379.79 7430.79 6874.38 N 4644.66 W 5972912.31 N 703191.51 E 3.262 8296.13 11945.15 39.680 325.800 7451.25 7502.25 6926.36 N 4679.20 W 5972963.32 N 703155.55 E 3.170 8358.55 12039.04 36.830 326.420 7524.97 7575.97 6974.61 N 4711.62 W 5973010.65 N 703121.80 E 3.063 8416.67 12133.66 32.960 325.760 7602.57 7653.57 7019.53 N 4741.80 W 5973054.71 N 703090.39 E 4.109 8470.79 12228.71 29.800 325.950 7683.70 7734.70 7060.48 N 4769.58 W 5973094.88 N 703061.49 E 3.326 8520.27 12321.45 26.430 326.710 7765.49 7816.49 7096.84 N 4793.82 W 5973130.56 N 703036.25 E 3.654 8563.97 12415.76 23.420 326.900 7851.00 7902.00 7130.09 N 4815.58 W 5973163.19 N 703013.58 E 3.193 8603.71 12511.50 19.700 326.460 7940.03 7991.03 7159.49 N 4834.90 W 5973192.05N 702993.46 E 3.889 8638.89 .--- 12606.06 17.090 325.190 8029.75 8080.75 7184.19 N 4851.64 W 5973216.27 N 702976.04 E 2.792 8668.72 12658.81 16.030 324.580 8080.31 8131.31 7196.49 N 4860.28 W 5973228.33 N 702967.05 E 2.036 8683.75 12760.11 14.780 323.970 8177.97 8228.97 7218.34 N 4875.99 W 5973249.73 N 702950.75 E 1.244 8710.64 12872.08 14.750 324.020 8286.24 8337.24 7241.42 N 4892.77 W 5973272.34 N 702933.34 E 0.029 8739.15 12966.44 14.220 323.510 8377.60 8428.60 7260.46 N 4906.71 W 5973290.99 N 702918.87 E 0.578 8762.73 13060.43 13.930 322.690 8468.77 8519.77 7278.74 N 4920.44 W 5973308.88 N 702904.64 E 0.374 8785.55 13113.95 13.450 325.250 8520.77 8571.77 7288.98 N 4927.89 W 5973318.91 N 702896.91 E 1 .444 8798.20 13177.00 13.450 325.250 8582.09 8633.09 7301.03 N 4936.25 W 5973330.72 N 702888.22 E 0.000 8812.86 Projected Survey 7 October, 2002 - 17:08 Page 50f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-08 Your Ref: AP15002923114Ò0 Job No. AKZZ22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 326.400° (True). Magnetic Declination at Surface is 26.325°(04-Sep-02) /'- Based upon Minimum Curvature type calculations, at a Measured Depth of 13177.00ft.,. The Bottom Hole Displacement is 8813.15ft., in the Direction of 325.937° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13177.00 8633.09 7301.03 N 4936.25 W Projected Survey Survey tool IJrogram for PSI-DB ,~ From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 817.00 0.00 817.00 814.76 13177.00 814.76 Tolerable Gyro(PSI-08 Gyro) 8633.09 AK-6 BP JFR-AK(PSI-08) --~------_.--._-._._._-~---- 7 October, 2002 - 17:08 Page 6 0'6 DrillQuest 3.03.02.002 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well PSI-08 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD I MD (if applicable) 13,177.00'MD ) a()d~ }Id. 08-0ct-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED OCT 0 9 2002 Alaska Oii & Gas Cons. Commil8ion AnchorBge Sperry-Sun Drilling Services ,~, North Slope Alaska BPXA Lisburne PS/(East Dock) PSI-08MWD Job No. AKMW22145, Surveyéd: 20 September, 2002 Survey Report 7 October, 2002 /~ Your Ref: API 500292311400 Surface Coordinates: 5966169.23 N, 708024.82 E (70'> 18' 39.3442" N, 148'> 18' 50.9414" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 966169.23 N, 208024.82 E (Grid) Surface Coordinates relative to Structure: 122.48 N, 267.31 E(True) Kelly Bushing: 51.00ft above Mean Sea Level Elevation relative to Project V Reference: 51.00ft Elevation relative to Structure: 51.00ft !I~"'-'Y-SUl1 DA.........fNG SEÀV'CèæS A Halliburton Company Survey Ref: svy11332 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-08 MWD Your Ref: API 500292311400 Job No. AKMW22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 817.00 8.000 318.000 763.76 814.76 30.79 N 29.90 W 5966199.18 N 707994.07 E 42.20 MWD Magnetic 954.71 6.530 325.970 900.37 951.37 44.41 N 40.70 W 5966212.49 N 707982.91 E 1.292 59.51 1048.91 6.900 328.280 993.92 1044.92 53.66 N 46.67 W 5966221.57 N 707976.68 E 0.486 70.52 1143.94 7.450 335.970 1088.21 1139.21 64.14 N 52.18 W 5966231.90 N 707970.88 E 1.163 82.30 ~ 1238.72 7.650 334.370 1182.17 1233.17 75.44 N 57.41 W 5966243.05 N 707965.34 E 0.306 94.61 1332.93 9.790 330.660 1275.28 1326.28 88.08 N 64.05 W 5966255.50 N 707958.35 E 2.348 108.81 1427.06 10.540 333.010 1367.94 1418.94 102.73 N 71.88 W 5966269.93 N 707950.12 E 0.910 125.34 1521.38 12.490 331.770 1460.35 1511.35 119.40 N 80.62 W 5966286.35 N 707940.92 E 2.084 144.07 1615.99 11.200 332.460 1552.95 1603.95 136.56 N 89.71 W 5966303.26 N 707931.36 E 1.372 163.39 1709.96 10.840 339.050 1645.19 1696.19 152.91 N 97.09 W 5966319.39 N 707923.53 E 1.393 181.09 1805.38 13.220 337.840 1738.51 1789.51 171.40 N 104.41 W 5966337.67 N 707915.70 E 2.508 200.54 1898.10 14.220 330.200 1828.59 1879.59 191.10 N 114.07 W 5966357.10 N 707905.50 E 2.230 222.30 1992.32 13.710 331.320 1920.02 1971.02 210.94 N 125.18 W 5966376.62 N 707893.84 E 0.613 244.97 2083.13 18.440 329.300 2007.26 2058.26 232.74 N 137.69 W 5966398.07 N 707880.74 E 5.244 270.05 2129.80 21.240 325.640 2051.15 2102.15 246.07 N 146.23 W 5966411.15 N 707871.83 E 6.561 285.88 2178.25 22.730 328.320 2096.08 2147.08 261.28 N 156.10 W 5966426.08 N 707861.55 E 3.707 304.01 2272.28 24.410 331.230 2182.27 2233.27 293.77 N 174.99 W 5966458.04 N 707841.76 E 2.173 341.53 2366.18 26.120 326.970 2267.19 2318.19 328.12 N 195.60 W 5966491.80 N 707820.21 E 2.657' 381.54 2458.88 28.350 326.100 2349.61 2400.61 363.50 N 219.00 W 5966526.52 N 707795.83 E 2.444 423.96 2551.78 31.680 324.740 2430.04 2481.04 401.73N 245.39 W 5966564.01 N 707768.39 E 3.658 470.41 2645.29 34.720 323.390 2508.27 2559.27 443.17 N 275.46 W 5966604.60 N 707737.19 E 3.346 521.56 .~~ 2740.22 37.520 318.240 2584.97 2635.97 486.45 N 310.85 W 5966646.89 N 707700.62 E 4.348 577.20 ! 2833.28 42.830 315.500 2656.05 2707.05 530.19 N 351.93 W 5966689.47 N 707658.34 E 6.013 636.36 2928.83 46.380 317.870 2724.07 2775.07 579.02 N 397.91 W 5966737.01 N 707611.02 E 4.103 702.48 3022.72 49.550 321.350 2786.94 2837.94 632.15 N 443.04 W 5966788.86 N 707564.44 E 4.355 771.70 3116.61 52.180 326.520 2846.22 2897.22 691.01 N 485.83 W 5966846.52 N 707520.03 E 5.106 844.41 3205.85 56.050 331.540 2898.54 2949.54 753.00 N 522.94 W 5966907.46 N 707481.22 E 6.289 916.58 3304.25 58.880 332.810 2951.46 3002.46 826.37 N 561.65 W 5966979.72 N 707440.50 E 3.075 999.11 3397.55 59.130 329.140 2999.52 3050.52 896.28 N 600.44 W 5967048.53 N 707399.78 E 3.382 1078.81 3492.92 58.750 329.650 3048.72 3099.72 966.59 N 642.04 W 5967117.67 N 707356.25 E 0.607 1160.40 3587.91 57.730 328.940 3098.72 3149.72 1036.04 N 683.28 W 5967185.94 N 707313.11 E 1.248 1241.06 3684.32 59.010 327.750 3149.28 3200.28 1105.91 N 726.36 W 5967254.59 N 707268.11 E 1.693 1323.09 3777.17 58.260 328.550 3197.61 3248.61 1173.25 N 768.20 W 5967320.75 N 707224.42 E 1.093 1402.34 3871.41 57.940 328.060 3247.41 3298.41 1241.32 N 810.23 W 5967387.63 N 707180.51 E 0.557 1482.30 3964.27 57.020 326.990 3297.33 3348.33 1307.38 N 852.27 W 5967452.50 N 707136.66 E 1.388 1560.58 -->-,-----._-- .~- 7 October, 2002 - 16:42 Page 20f6 DrillQl1est 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-OB MWD Your Ref: API 500292311400 Job No. AKMW22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4057.71 59.380 326.280 3346.57 3397.57 1373.69 N 895.95 W 5967517.58 N 707091.17 E 2.607 1639.99 4151.25 58.340 326.560 3394.94 3445.94 1440.39 N 940.23 W 5967583.03 N 707045.05 E 1.141 1720.05 4245.67 59.850 326.960 3443.43 3494.43 1508.15 N 984.63 W 5967649.53 N 706998.79 E 1.640 1801.06 4335.31 58.370 326.470 3489.45 3540.45 1572.46 N 1026.85 W 5967712.64 N 706954.81 E 1.716 1877.98 r"-"" 4431.41 59.420 327.380 3539.10 3590.10 1641.41 N 1071.75W 5967780.32 N 706908.02 E 1.361 1960.26 4525.62 61.410 326.180 3585.61 3636.61 1709.93 N 1116.63 W 5967847.58 N 706861.25 E 2.385 2042.18 4618.36 60.060 326.440 3630.95 3681.95 1777.25 N 1161.51 W 5967913.62 N 706814.52 E 1.4 76 2123.08 4712.52 59.300 327.980 3678.48 3729.48 1845.57 N 1205.53 W 5967980.70 N 706768.63 E 1.626 2204.35 4805.67 58.590 327.570 3726.53 3777.53 1913.08 N 1248.08 W 5968047.00 N 706724.22 E 0.850 2284.12 4900.45 56.980 328.310 3777.06 3828.06 1981.03 N 1290.65 W 5968113.75 N 706679.79 E 1.823 2364.28 4995.23 58.210 329.500 3827.85 3878.85 2049.55 N 1331.97 W 5968181.10 N 706636.59 E 1.676 2444.22 5088.41 59.610 330.300 3875.97 3926.97 2118.59 N 1371.98 W 5968249.00 N 706594.68 E 1.673 2523.86 5182.46 59.400 328.590 3923.70 3974.70 2188.37 N 1413.18 W 5968317.62 N 706551.57 E 1.582 2604.78 5277.00 58.860 327.880 3972.21 4023.21 2257.37 N 1455.89 W 5968385.40 N 706506.95 E 0.861 2685.89 5371.59 57.450 329.300 4022.12 4073.12 2325.93 N 1497.77 W 5968452.78 N 706463.19 E 1.962 2766.18 5465.76 59.030 329.770 4071.68 4122.68 2394.95 N 1538.37 W 5968520.64 N 706420.70 E 1.731 2846.12 5560.51 59.250 329.850 4120.28 4171.28 2465.25 N 1579.27 W 5968589.79 N 706377.87 E 0.243 2927.31 5655.04 59.240 328.740 4168.62 4219.62 2535.10 N 1620.75 W 5968658.46 N 706334.47 E 1.009 3008.44 5750.51 58.930 328.530 4217.67 4268.67 2605.03 N 1663.38 W 5968727.19 N 706289.92 E 0.376 3090.29 5843.42 58.790 328. 770 4265.72 4316.72 2672.95 N 1704.75 W 5968793.93 N 706246.68 E 0.268 3169.75 5939.06 58.990 328.210 4315.14 4366.14 2742.76 N 1747.55 W 5968862.53 N 706201.97 E 0.543 3251.58 ~, 6031.84 58.920 328.340 4362.98 4413.98 2810.37 N 1789.35 W 5968928.95 N 706158.31 E 0.142 3331.03 6126.65 58.060 329.870 4412.54 4463.54 2879.72 N 1830.85 W 5968997.13 N 706114.90 E 1.648 3411 .76 6218.89 59.450 329.220 4460.38 4511.38 2947.70 N 1870.83 W 5969063.98 N 706073.06 E 1.623 3490.50 6312.66 60.310 327 - 990 4507.44 4558.44 3016.93 N 1913.08 W 5969132.01 N 706028.90 E 1 .459 3571.55 6406.01 59.400 329.290 4554.32 4605.32 3085.86 N 1955.09 W 5969199.75 N 705985.00 E 1.549 3652.21 6492.00 59.290 328.710 4598.16 4649.16 3149.26 N' 1993.19 W 5969262.07 N 705945.16 E 0.594 3726.10 6585.77 59.710 328.860 4645.75 4696.75 3218.36 N 2035.06 W 5969329.98 N 705901.39 E 0.469 3806.83 6680.54 60.320 326.730 4693.12 4744.12 3287.81 N 2078.81 W 5969398.19 N 705855.73 E 2.050 3888.88 6768.79 60.840 327.080 4736.4 7 4787.47 3352.21 N 2120.78 W 5969461.41 N 705811.99 E 0.683 3965.75 6867.19 60.090 326.640 4784.98 4835.98 3423.90 N 2167.58 W 5969531.77 N 705763.22 E 0.856 4051.36 6959.27 60.520 327.680 4830.59 4881.59 3491.10 N 2210.96 W 5969597.74 N 705718.00 E 1.087 4131.34 7055.42 60.460 327.140 4877.95 4928.95 3561.60 N 2256.03 W 5969666.97 N 705671.00 E 0.493 4215.00 7150.64 59.480 324.860 4925.61 4976.61 3629.94 N 2302.12 W 5969734.01 N 705623.04 E 2.314 4297.43 7238.26 59.500 323.990 4970.09 5021.09 36~1.34 N 2346.03 W 5969794.17 N 705577.44 E 0.856 4372.87 ---~_._--,--._- --.._-~_._----'----~--'~'----'-'~------'----- 7 October, 2002 - 16:42 Page 30f6 DrillQlJest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) . PS/.(J8 MWD Your Ref: AP/500292311400 Job No. AKMW22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub.Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7337.25 60.010 323.680 5019.96 5070.96 3760.38 N 2396.50 W 5969861.78 N 705525.08 E 0.582 4458.30 7432.06 61.510 324.790 5066.27 5117.27 3827.51 N 2444.84 W 5969927.54 N 705474.89 E 1.883 4540.96 7525.50 59.860 326.450 5112.02 5163.02 3894.74 N 2490.85 W 5969993.47 N 705427.04 E 2.349 4622.42 7619.68 58.270 327.500 5160.43 5211.43 3962.46 N 2534.88 W 5970059.95 N 705381.15 E 1.940 4703.20 ,~ 7713.84 57.000 325.410 5210.84 5261.84 4028.75 N 2578.82 W 5970124.99 N 705335.39 E 2.309 4782.72 7807.88 57.160 325.580 5261.95 5312.95 4093.80 N 2623.53 W 5970188.78 N 705288.89 E 0.228 4861.65 7902.98 57.330 325.310 5313.40 5364.40 4159.67 N 2668.90 W 5970253.37 N 705241.72E 0.298 4941.62 7996.39 57.220 324.770 5363.90 5414.90 4224.07 N 2713.93 W 5970316.50 N 705194.93 E 0.500 5020.18 8090.16 56.150 325.670 5415.40 5466.40 4288.43 N 2758.63 W 5970379.59 N 705148.46 E 1.395 5098.52 8185.14 57.370 324.120 5467.47 5518.47 4353.41 N 2804.31 W 5970443.29 N 705100.99 E 1.874 5177.93 8280.70 59.530 325.660 5517.47 5568.47 4420.02 N 2851.14 W 5970508.58 N 705052.34 E 2.645 5259.33 8375.67 60.010 324.870 5565.28 5616.28 4487.46 N 2897.89 W 5970574.69 N 705003.74 E 0.879 5341.36 8467.38 59.900 325.640 5611.20 5662.20 4552.69 N 2943.13 W 5970638.64 N 704956.70 E 0.737 5420.74 8562.66 59.420 325.700 5659.33 5710.33 4620.59 N 2989.51 W 5970705.24 N 704908.46 E 0.507 5502.96 8656.01 59.490 326.570 5706.77 5757.77 4687.35 N 3034.31 W 5970770.73 N 704861.83 E 0.806 5583.35 8748.89 59.340 326.590 5754.03 5805.03 4754.09 N 3078.35 W 5970836.22 N 704815.96 E 0.163 5663.31 8845.13 59.370 326.210 5803.08 5854.08 4823.05 N 3124.17 W 5970903.89 N 704768.25 E 0.341 5746.11 8939.68 59.720 324.050 5851.01 5902.01 4889.91 N 3170.76 W 5970969.44 N 704719.82 E 2.004 5827.59 9033.50 60.030 323.760 5898.10 5949.10 4955.49 N 3218.57 W 5971033.66 N 704670.22 E 0.425 5908.66 9125.15 60.420 323.740 5943.61 5994.61 5019.64 N 3265.61 W 5971096.48 N 704621.42 E 0.426 5988.12 9219.69 59.120 324.690 5991.21 6042.21 5085.90 N 3313.37 W 5971161.39 N 704571.84 E 1.626 6069.74 F~ 9314.20 58.380 324.510 6040.24 6091.24 5151.76 N 3360.18 W 5971225.93 N 704523.23 E 0.800 6150.50 9408.31 58.970 325.050 6089.17 6140.17 5217.43 N 3406.54 W 5971290.30 N 704475.06 E 0.796 6230.86 9503.10 59.340 324.910 6137.77 6188.77 5284.08 N 3453.24 W 5971355.63 N 704426.53 E 0.410 6312.22 9596.87 59.830 325.680 6185.24 6236.24 5350.56 N 3499.28 W 5971420.80 N 704378.67 E 0.880 6393.07 9690.49 60.090 325.930 6232.11 6283.11 5417.59 N 3544.83 W 5971486.55 N 704331.28 E 0.361 6474.11 9784.79 59.920 325.850 6279.25 6330.25 5485.21 N 3590.63 W 5971552.88 N 704283.63 E 0.195 6555.77 9878.79 60.31 0 325.580 6326.09 6377.09 5552.55 N 3636.54 W 5971618.92 N 704235.87 E 0.484 6637.27 9972.47 60.940 325.330 6372.04 6423.04 5619.79 N 3682.83 W 5971684.85 N 704187.73 E 0.712 6718.89 10066.54 60.590 324.660 6417.98 6468.98 5687.03 N 3729.92 W 5971750.76 N 704138.80 E 0.724 6800.95 10162.11 60.280 325.370 6465.14 6516.14 5755.14 N 3777.58 W 5971817.52 N 704089.27 E 0.723 6884.06 10257.50 60.190 324.750 6512.49 6563.49 5823.02 N 3825.00 W 5971884.06 N 704039.98 E 0.572 6966.84 10350.00 60.370 324.820 6558.35 6609.35 5888.65 N 3871.33 W 5971948.38 N 703991.86 E 0.205 7047.14 10444.17 60.090 324.980 6605.11 6656.11 5955.52 N 3918.33 W 5972013.93 N 703943.02 E 0.332 7128.85 10538.40 60.760 325.730 6651.62 6702.62 6022.94 N 3964.92 W 5972080.03 N 703894.59 E 0.992 7210.79 7 October, 2002 - 16:42 Page 40f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - PSI-DS MWD Your Ref: API 500292311400 Job No. AKMW22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10631.61 60.530 326.160 6697.31 6748.31 6090.25 N 4010.41 W 5972146.05 N 703847.24 E 0.472 7292.03 10722.27 60.070 327.080 6742.23 6793.23 6156.01 N 4053.74 W 5972210.59 N 703802.11 E 1.017 7370.78 10817.55 59.870 327.040 6789.91 6840.91 6225.24 N 4098.59 W 5972278.55 N 703755.36 E 0.213 7453.26 10909.26 60.220 326.900 6835.70 6886.70 6291.86 N 4141.90 W 5972343.94 N 703710.22 E 0.404 7532.72 r-". 11004.45 59.900 325.940 6883.21 6934.21 6360.58 N 4187.53 W 5972411.37 N 703662.71 E 0.936 7615.20 11098.27 59.600 325.720 6930.48 6981.48 6427.63 N .4233.04 W 5972477.14 N 703615.35 E 0.379 7696.24 11193.49 59.260 325.760 6978.91 7029.91 6495.39 N 4279.20 W 5972543.59 N 703567.34 E 0.359 7778.22 11286.46 57.860 326.720 7027.40 7078.40 6561.33 N 4323.28 W 5972608.29 N 703521.45 E 1.745 7857.54 11379.09 55.570 327.150 7078.23 7129.23 6626.22 N 4365.53 W 5972671.98 N 703477.42 E 2.502 7934.96 11473.80 54.450 326.460 7132.54 7183.54 6691.15N 4408.00 W 5972735.71 N 703433.16 E 1.325 8012.55 11568.72 52.440 327.670 7189.07 7240.07 6755.13 N 4449.46 W 5972798.52 N 703389.94 E 2.352 8088.79 11661.91 48.740 327.330 7248.23 7299.23 6815.85 N 4488.14 W 5972858.14 N 703349.60 E 3.980 8160.76 11755.12 45.680 326.410 7311.54 7362.54 6873.13 N 4525.51 W 5972914.36 N 703310.66 E 3.362 8229.15 11850.26 42.590 326.320 7379.81 7430.81 6928.28 N 4562.20 W 5972968.48 N 703272.45 E 3.249 8295.40 11945.15 39.680 326.370 7451.27 7502.27 6980.24 N 4596.79 W 5973019.45 N 703236.44 E 3.067 8357.81 12039.04 36.830 326.700 7524.99 7575.99 7028.72 N 4628.85 W 5973067.03 N 703203.05 E 3.043 8415.94 12133.66 32.960 325.830 7602.59 7653.59 7073.74 N 4658.88 W 5973111.20 N 703171.78 E 4.124 8470.06 12228.71 29.800 325.970 7683.72 7734.72 7114.72 N 4686.63 W 5973151.39 N 703142.91 E 3.325 8519.54 12321.45 26.430 326.780 7765.51 7816.51 7151.09 N 4710.84 W 5973187.08 N 703117.70 E 3.657 8563.24 12415.76 23.420 327.400 7851.02 7902.02 7184.45 N 4732.44 W 5973219.83 N 703095.18 E 3.204 8602.97 12511.50 19.700 326.080 7940.05 7991.05 7213.88 N 4751.71 W 5973248.72 N 703075.11 E 3.918 8638.15 ~ 12606.06 17.090 325.090 8029.77 8080.77 7238.50 N 4768.55 W 5973272.86 N 703057.58 E 2.780 8667.98 12658.81 16.030 324.560 8080.33 8131.33 7250.79 N 4777.21 W 5973284.91 N 703048.59 E 2.030 8683.01 12760.11 14.780 324.470 8177.99 8228.99 7272.70 N 4792.83 W 5973306.38 N 703032.37 E 1.234 8709.90 12872.08 14.750 324.300 8286.26 8337.26 7295.90 N 4809.45 W 5973329.11 N 703015.11 E 0.047 8738.42 12966.44 14.220 323.720 8377.62 8428.62 7315.00 N 4823.32 W 5973347.81 N 703000.72 E 0.582 8762.00 13060.43 13.930 323.080 8468.79 8519.79 7333.35 N 4836.95 W 5973365.78 N 702986.59 E 0.350 8784.83 13113.95 13.450 325.770 8520.79 8571.79 7343.65 N 4844.32 W 5973375.87 N 702978.94 E 1 .490 8797.48 13177.00 13.450 325.770 8582.11 8633.11 7355.77 N 4852.57 W 5973387.76 N 702970.36 E 0.000 8812.15 Projected Survey ---- 7 October, 2002 - 16:42 Page 50f6 DrillQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Lisburne PSI (East Dock) - 1'SI-08 MWD Your Ref: API 500292311400 Job No. AKMW22145, Surveyed: 20 September, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 326.400° (True). ~ Magnetic Declination at Surface is 26.325°(04-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13177.00ft., The Bottom Hole Displacement is 8812.20ft., in the Direction of 326.587° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13177.00 8633.11 7355.77 N 4852.57 W Projected Survey Survey toolproQram for PSI-DB MWD 7~ From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 817.00 0.00 817.00 814.76 13177.00 814.76 Tolerable Gyro(PSI-08 Gyro) 8633.11 MWD Magnetic(PSI-08 MWD) 7 October, 2002 - 16:42 Page 60f6 DrlllQuest 3.03.02.002 Color Well Job# Log Description Date Blueline Sepia Prints PSI-01 r;>~ - ILl 5 22376 OH EDIT BHC/HRLA (PDC) 08/05/02 PSI-01 22376 BHC 08/05/02 1 PSI-01 22376 PEX-HRLA 08/05/02 1 PSI-01 22376 PEX-COMBO 08/05/02 1 PSI-01 22376 PEX-COMBO SSTVD 08/05/02 1 PSI-01 ,/ 22376 PEX-HCAL-CALlPER 08/05/02 1 PSI-08 ~~-lï d 22449 OH EDIT GR & BHC (PDC) 09/21/02 PSI-08 ~~ 22449 BHC-GR 09/21/02 1 PSI-08 22449 BHC-GR SSTVD 09/21/02 1 ScblumblPger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date Delivered: NOV 08 tOO? AJasica 011 Ii Gas Con~, Comminion AnchOf!~ 11/07/02 NO. 2539 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CD ~' 1 1 ~' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ReœiV~~ ) Scblumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Wøll P1-09 191n-/5£/ G-21 , '}5- J F;<- D.S. 12-12 I ~i-Q ?::: D.S. 15-22 J ~()-O~-Z G-09A L.. .'1. .~-'.~b~,.~ PSI-08 dI~..l-¡~ Color Date Blueline Søpia Prints CD 10/16/02 1 09/30/02 1 10/18/02 1 10/22/02 1 10/19/02 1 10/15/02 1 Job# Log Description PROD PROFILE W/DEFT LDL LDL LDL LDL JEWELRY W/TEMP & SBHPS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV 08 2002 Alaska Oi) & Gas Cons. Commission Anchorage 11/07/02 NO. 2539 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay '-" ~. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive~~~ ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner tl-th DATE: November 2, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPXA Petroleum Engineer~.Q9YÝ\ P..S. I.pad f]Y \\\,",°7 PSI-01, 08, 09, 10 FROM: Jeff Jones Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON. CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well PSI-01 Type Inj. S TV.D. 8040 Tubing 900 900 900 900 Interval P.T.D. 202145VType test P Test psi 2010 Casing 150 2090 2090 2085 P/F OA 200 450 450 450 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 70 deg. F TV.D. 8014 Tubing 1175 1340 1340 1350 Interval Test psi 2004 Casing 80 2110 2090 2110 P/F OA 220 420 420 420 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 72 deg. F Well PSI-08 Type Inj. S P.T.D. 202172~Type test P Well PSI-09 Type Inj. S TV.D. 8034 Tubing 1160 1000 1160 1150 Interval P.T.D. 20212481 Type test P Test psi 2009 Casing 380 2060 2060 2065 P/F . OA 380 560 560 560 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 76 deg. F Pretest Initial 15 Min. 30 Min. 45 Min. Well PSI-10 Type Inj. S TV.D. 8056 Tubing 850 850 850 850 850 Interval P.T.D. 202159v-rype test P Test psi 2014 Casing 0 2090 2085 2080 2080 P/F OA 320 580 580 580 580 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 74 deg. F Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details November 2, 2002: I traveled to BPXA's PSI Pad in the Prudhoe Bay Field to witness initial MIT's on water injection wells PSI -0 1, PSI-08, PSI -09 and PSI -10. Roland Johnson was the BPXA representative today and he performed the tests in a safe and proficient manner. The pre-test pressures were observed for 15 minutes and found to be stable. The standard annulus pressure test was then performed, with all four wells passing the MIT. Well PSI -10 was monitored an additional 15 minutes to further demonstrate integrity and the casing pressure stabilized at 2080 PSI. The four well houses were inspected with no exceptions noted. Summary: I witnessed successful MIT's on BPXA's Prudhoe Bay Field water injection wells PSI-Ol, PSI-08, PSI-09 and PSI -] O. Four well house inspections; no exceptions noted. .1.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 5 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU PSI 01,08,09,10 11-2-02 JJ.xls I ~ I ~ I ~ I ~ 11/4/2002 Se-Iullbepger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A TTN: Beth Well PSI-08 qO~-l ï ~ MPS-11 d.~- j ~ D.S. 3-09 J Î9 - nri d. 2-14/0-16 1 ~<O-/4 't Job# Log Description 22448 USIT 22447 SCMT 22019 CNTG(REPROCESSED) 22407 RST-SIGMA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECE\VED OCT 1 ðr 200L Alaaka O~ & Gas Cont-. c.:;mninion AncMœge Date 09/21102 08/29/02 12/19/01 07/31/02 NO. 2462 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott P Bay, M. Point BL Sepia CD Color 2 2 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A/herne ~- ~~~. 10/2/2002 '~ 1 1 ~. ~ Re: PSI-08 USIT Log ') '\ Subject: Re: PSI-08 USIT Log Date: Thu, 10 Oct 2002 13:39:56 -0800 From: Winton Aubert <Winton - Aubert@admin.state.ak.us> Organization: AOGCC To: "Cahalane, Ted WIt <CahalaTW@BP.com> Ted, pending successful MIT specified in approval for Permit to Drill #202-172, AOGCC hereby approves operations for well PSI-08. All permit stipulations apply. Winton Aubert AOGCC 793-1231 "Cahalane, Ted W" wrote: > Winton, > > I'm sending over the USIT log for PSI-OB. This is the last of the five PSI > injectors to be drilled in 2002. Here is the schematic from Drilling. > > We plan on perforating all available sands in the Ivishak formation from the > Kavik up to the LCU. The top perf will be approximately 12,755' . Please > review the log and let me know when you approve the well for injection. > Call me at 564-5596 if you need anything else or have questions. > > Thanks > > > «PSI-OB Schematic. ZIP» > > ------------------------------------------------------------------------ > > Name: PSI-OB Schematic. ZIP PSI-OB Schematic.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 > PSI-OS J. ~ 1017' , ~ :::; . ~ 2000' ~ ) TREE = 7-1/16"5KCIW WELLH!;AO = 13-5/8" 5K FMC ACTUA. TOR = KB-:~ËlËv ;;'-"-"-"'~'---'5T.6Õì BF:1[;8i.o;;--"..._-_._--__~._..m"3á~ ï(op;--'-""""--""""'-'I1î30Î 'Mix A"ngle-;~0^--6:r@452€f 'õitüm-1D ;--_0_--"--1"30 9~f .<~~_.,,","'.~< ,~~~~,~<~~~.~ .n "' ..........,,~~,,~~~,-~... Datum ìV D = 8500' SS 113-318" CSG, 68#, L-80, 10 = 12.400" H 6451' ~ Minimum ID = 5.770" @ 12571' 7" HES RN NIPPLE 17-518" TBG, 29.7#, .0459 bpf, 10= 6.875" H 12458' ~ . \ :8: & 17" TBG, 26#, .0383 bpf, 10 = 6.276" H 9768' J 1 PERFORATION SUv11\¡\l\ RY RB= LOG: ANGLE AT TOP PERF: I'bte: Refer to A"oductbn œ for historical perf data SIZE SFf= INlERVAL Opn/Sqz DA TE g 19-5/8"CSG,47#,L-80,10=8.681" H 12726' ~ 1 PBTO H 13090' I .~ T'Lt\R,26#,L-80,.0383bpf,10=6.276" H 1317T ~ OA TE REV BY COWMENfS 09/25/02 JL~KK ORIGINAL COWLEfION DA lE RBI BY ) I SAFETY NOTES: H 13-318" TA M PORT COLLAR I H7-5/8" X 7' XO, D = 6.276" I H 7" CAMCO œ NIP, D = 6.000" I H 7" X 7-518" XO, 10 = 6.276" I I 12458' H 7-518" X 7" XO, 10 = 6.276" I I 12469' H7" I-ES R NIP, D =5.963" 1 I 12495' H FER, 10 = 6.060" H 7" X 9-5/8" BKR SABL-3 PKR, D = 5.970" H7" HES R NIP, 10 = 5.963" I H7"HESRNNP, 10=5.770" 1 I 12536' 1 12560' I 12571' f 12585' H 7" WLEG, 10 = 6.276" I 1 ~ELMOTTNOTLOGGEO go I 12623' H7" X 9-5/8" BKR ZXP LNR TOP R<R WI TIEBA 0< SL V I ~ f LA¡V¡JG-fJ p#..fj I:T Sr¿¡-c....£ " I~ "ð - l~o8° , 2 ~Q S T~ /217 S '/- IL; 'J -¿.2-. COWMENlS ffiLDHOE SAY Ut\IT WELL: PSI-08 PERMIT No: 2021720 AA No: 50-029-23114 SEC 15, T11N, R15E, 3867 NSL, 437g WEL BP Exploration (Alaska) ) ~()Z - /71 PSI-OS Completion Design 1001000 bbls/day @2700psi injection pressure l.......m II!; , ':, g~" Packer@12~540'MD - ~ l' WLEG @ 12,585' MD '< i ~.-,';' Top of Liner TBR @ 12ß23' MD ...". : ;~:~ 9*5ISU 1 47#) L~80, STCM @ 12,7261 MD Top of Ivishak@ 12,755' MD: ,,' Tree: ß,.3/~ bore x7 ~ 1/6~ 5K, 625 Inlay, CIW Wellhead: 13--51811, 5K¡ Big Bore FMC 6,00" DB Nipple @ 2000' MD 7-5f~ , 29.7#, STal, ¡PCI Injection Tubing (w17D accessories) Tubing Detail: 12.585' MD 12;5731 MD 12ß62J MD ; r@ 12,540' MD ~ =1<.22 Anchor@ 12,5361 MD ~ "PBR Btm @ 12,519' MD ô PBR Top@ 12,495' MD Seal Assembly @ 12,492' MD " 'R'Nipple @, . 12,471' MD c X-Over to 7-5m" @ 12,459' MD " r'u, 2Cf X 34~ Insulated Conductor @ +1- ao! 1$..3/an, 68#, La80, BTC @ 6,4511 MD ~¡ ~ ' .u ~ -r ¡ 26#, L-BO¡ BTC-M @ 13,1771 MD 1,I:'-I.:r:.-,,~'I.,W;;fW_..--I1-¡'-'-)"J,-:M~-":.IIJ.-,-,N:. ,':1..\\, ,:'-o'-),;1(!rfJ-,~V,\fro,~'(K-'WW'Lf1_\W,W,mWrm'1iW~'ilfVKL«v.wv,'l~¥'_wrw-WM-'rmVW/~\"'@\o\('lfJ\Y¡W\':f'KA'<I1iW'_-'A!I.~.w;\WL.v,7 '-.-,^r:llII: HIIA'l!",!" ,. Date I Rev By : Comments PROJECT: GCWSI 'INN,VIIIIA'IMNff/Ift:/IX' ..\- ---'^\~!mJ!\W/INJ('Vl^WIIAr_" X,J--~--'IJNI'-:.",-''- ."''A-'I-'JIlIIIA'lIlJllIIllllllllII.--.-.'lIIlJNMWJfflJIIIJJIIIAVlIIIIlAtJAtIIA'lAt.----\ . .-'AWM-"flllllfl!lllllllll., 8.16.C2 ~ HST f COmplêli(ln D!:=ï19n WELL: pSl.oa 9.25.02 I RBT ~ Actual Depths API NO: 50-029.23114 ~ t ... . GPB Rotary Drilling ~lJ~1TŒ (ill TONY KNOWLES, GOVERNOR ATfllSIiA. OIL AND GAS CONSERVATION COMMISSION Brian Robertson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit PSI-08 BP Exploration (Alaska) Inc. Pennit No: 202-172 Surface Location: 3867' NSL, 4379' WEL, Sec. 15, TIIN, RISE, UM . Bottomhole Location: 715' NSL, 4008' WEL, Sec. 04, TIIN, RI5E, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to drill the above referenced service well. The pennit to drill does not exempt you from obtaining additional pennits or approval~required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. . In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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). Sincerely, (n M~. ./~~ C~~.O~hsli Taylor Chair BY ORDER OF THE COMMISSION DATED thi~day of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t.JGA- 1/11/01- - STATE OF ALASKA ....- ~ r¡t I ALASKJ~.. JL AND GAS CONSERVATION COM"'- )SION. ~~ ~-z- PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work II Drill [] Redrill 1 b. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen II Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 51.6' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034631 4. Location of well at surface 7. Unit or Property Name 3867' NSL, 4379' WEL, SEC. 15, T11 N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 604' NSL, 3934' WEL, SEC. 04, T11 N, R15E, UM PSI-08 ./ At total depth 9. Approximate spud date 7151 NSL, 4008' WEL, SEC. 04, T11N, R15E, UM 08/30/02 Amount $200,000.00 12. Distance to nearest property line 13. Distanoe to nearest well /' 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034632,1272' MD No Close Approach 2560 13069' MD /8592' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} . Kick Off Depth 300' MD Maximum Hole Angle 59 Maximum surface 3012 psig, At total depth (TVD) 8675' /3879 psig 18. Casin~ Program Specifications Setting Depth $Ize Trp Botom CasinQ Weight Grade Couolina Lenath MD TVD MD TVD 20" x 34" 91.51 #' H-40 Welded 781 Surface Surface 113' 113' 13-3/8" 68# L-80 BTC 6482' Surface Surface 6517' 4625' 9-5/8" 47# L-80 BTC-M 12626' Surface Surface 12661' 8208' 7" 26# L-80 BTC-M 508' 12561' 8105'" 13069' 8592' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 42" 16" 12-1/4" 8-1/2" Quantity of Cement (include staae data) ,260 sx Arctic Set (Approx.) 1434 sx AS III Lite, 603 sx 'G' 633 sx Class 'G' 140 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented ~Pr ~~':£ ~'I \:7 ,:~::" TVD Perforation depth: measured AJasKa & . A!1 r~ht) \1'2(\1::<- >~ ~t.1"6- C)Ñ ~~. '!> f ~vl~)"1'» Ñ~ '¡>'lÅC~~~" á=- ~k~ (.1..S-ù~ ~,.¡t: ...-,.op tv¡SH~, ~~ ~ true vertical 20. Attachments II Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch II Drilling Program II Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirpack, 564-4166 PreparedByName/Number: Terrie Hubb/e, 564-4628 21. 's~:~;~c:~~:e.fOÆ:~:i<~¿:;t~::~;~:~~~;~.::.:/..........:.. Date y (9-o~. Permit Number API Number APpro~.~t~ 1. . See cover letter 2ð 2..- / 7 .2- 50- OZ 7- .2."3/ I$' -:y.¡ ? I'O~ for other reQuirements Conditions of Approval: Samples Required 0 Yes mI No Mud Log Req Ired 0 Yes B No Hydrogen Sulfide Measures 0 Yes iii No Directional Survey Required ø Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~s+ BorE ~ t.þgo fSl i MI:ì') CQL. rl1Mrtd. Pey ZoAlk.15 .c...1 L (bJ) PCt(..tLu ~U- ~h~~~(.Ñt- wtc.iv~J. by orderðf Date -::7 ',r'1. :2 In.~ Approved By GnglOal SIgned' By Commissioner the commission - ð l7J 11 vrr Form 10-401 Rev. 12-01-85 Cammy Oechsli Taylor i I I~ L S~bmit In Triplicate -) I Well Name: I PSI-DB ) Drill and Complete Summary I Type of Well (producer or injector): I Injector - Water / Surface Location: (As Built) Target Location: Bottom Hole Location: x = 708,025 / Y = 5,966,169 3867' FSL, 900' FVVL, Sec. 15,T11N,R15E X = 702,975 / Y = 5,973,331 4676'FNL,1346'FVVL,Sec.04,T11N,R15E X = 702,898 / Y = 5,973,440 4565'FNL,1272'FVVL,Sec.04,T11N,R15E I AFE Number: 1 PBD4P1922 1 Estimated Start Date: 108/30/02 1 1 MD: 113,069' I I TVD: 18,592' I I RiQ: 1 Nabors 27e I Operating days to complete: 126.5 1 Ground Elevation: 117.1' I 1 RKB: 1 I Well DesiQn (conventional, slim hole, etc.): 1 Big Bore 1 Objective: I High rate water injection into Ivishak Gas Cap, Zones 3 through 1 Formation Markers Formation Tops M D TVDss Comments Base PF 1,957' -1,854' 8.6 ppg SV4 4,479' -3,511' 8.6 ppg SV3 5,256' -3,916' 8.6 ppg SV2 5,642' -4,117' 8.6 ppg SV1 6,364' -4,493' 8.6 ppg UG4 7,285' -4,973' 8.6 ppg UG3 7,707' -5,193' 8.6 ppg UG1 8,945' -5,838' 8.6 ppg VVest Sak 2 9,951' -6,362' 8.6 ppg VVest Sak 1 10,308' -6,548' 8.6 ppg CM3 10,697' -6,751' 8.6 ppg THRZ 12,477' -7,984' 8.6 ppg BHRZ/LCú 12,681' -8,175' 8.6 ppg TZ4 12,681' -8,175' 7.5 ppg; HC Bearing TZ3 12,695' -8,188' 7.5 ppg; HC Bearing TZ2 12,756' -8,246' 7.5 ppg; HC Bearing TZ2B 12,798' -8,285' 7.5 ppg; HC Bearing BSAD 13,012' -8,486' 7.5 ppg; HC Bearing TD 13,069' -8,540' 7.5 ppg; TLSB N/A -8,590' 8.6 ppg; HC Bearing Surface TD Criteria: Based on -100' TVD below SV1 Top Intermediate TD Criteria: Casing to be set above the BHRZfTZ3 transition TD Criteria: Based upon 50' TVD above TLSB PSI-08 VV ellPJan 8/16/02 I 1 51.6' I I I 10.0 / Page 2 ) ) / Grade Conn Length Top Btm MDITVD MDITVD H-40 Welded -78' GL -113' /113' Casin~lTubin~ Program Hole Size Csg/ WtlFt Tbg O.D. Insulated 20" 91.51# (34" 00) 16" 13-3/8" 68# L-80 BTC 6,482' GL 6,517'/4,625' 12-1/4" 9-5/8" 47# L-80 BTC-M 12,626' GL 12,661'/8,208' 8-1/2" 7" 26# L-80 BTC-M 508' 12,561 '/8,105' 13,069'/8,592' Tubing 7-5/811 29.7# L-80 STL 12,470' GL 12,470'/8,034' NOTE:' This well is pJannedwith the minimum allowed, 100' liner lap, the 9-5/8" shoe:will be located nearthe bottom of the HRZ, but with the planned completion, the.packer to injection zone distance will more than likely be greater than the 200' as per 20AAC 25.412 (b), but less than 250', Approval for 250' packer to. injection zone is .,/ requested. 42" Directional KOP: 1300' MO Maximum Hole Angle: Close Approach Well: Survey Program: -58.5° In intermediate section from 3240' to 11,194' No Close Approach Issues Standard MWO Surveys from surface to TO. Mud Pro~ram 16" Surface Hole Freshwater Spud Mud From Surface to -100' TVO below top SV1 Interval Density Viscosity (ppg) (seconds) 8.6 - 8.8 200-300 9.5 200-250 9.5 / 75-150 Initial Base Perm I nterval TO YP (lb/100ft2) 50-70 30-45 20-35 tauo (lb/100ft2) >8 >6 >6 APIFL (mls/30min) 35-55 30-40 16-30 12-1/4" Intermediate Hole I LSND From Surface Casing Shoe to BHRl Interval Density Plastic Viscosity (ppg) (cp) Initial to HRl 9.0-9.5 10-15 HRl to Tl4 9.8-10.0 ~ 10-15 YP tauo (lb/100ft2) (lb/100ft2) 25-30 4- 7 20-30 4-7 10' Gel API HTHP FL (mls/30min) 6-10 4-6/<12.0 10 10 8-1/2" Production Hole I BARADRILn From Intermediate Casing Shoe to TO Interval Density Plastic Viscosity YP tauo (ppg) (cp) (lb/100ft2) (lb/10Oft2) 8.8 10-15 17-25 3-5 10' Gel API HTHP FL (mls/30min) 4-6<12.0 Ivishak 10 PSI-08 WellPlan 8/16/02 pH 8.5-9.5 8.5-9.5 8.5- 9.5 pH 8.5-9.5 8.5-9.5 LGS 0/0 vol <5 <5 pH LGS % vol <5 8.5-9.5 Page 3 ) ) Drilling Parameters Hole Bit Nozzles GPM Annular Max ROP @ Max ROP @ Size Range Velocity 80 RPM's 100 RPM's 16" Smith MG02TQODPS 2X20;1 X16;1 X14 850 90 210 215 900 95 225 230 12-1/4" Hycalog DS103H+GJNU 11X10's 800 155 150 200 850 165 160 210 8-1 /2" Smith MF20TPS 3X16's 550 255 220 280 600 277 240 300 Integrity Testing Fracture gradient information from offsets are shown below: Well Name Formation TVDss Frac Gradient, PPG PSI-06 SV-1 4545' TVDss 13.4 ppg EMW East State Bay-1 SV-4? 2745' TVDss 12.1 ppg EMW L2-32 SV-4 3589' TVDss 12.5 ppg EMW / L3-01 SV-3 4009' TVDss 13.8 ppg EMW L3-05 SV-3 4032' TVDss 12.5 ppg EMW PSI-01 will be FIT'd to12.0 ppg EMW. This will provide a more than adequate kick tolerance of 114 bbls to drill to the planned well TD. Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. Below are the planned integrity test points. Test Point Depth Surface Casing Shoe 20' minimum below shoe Intermediate Casing Shoe 20' minimum below shoe Test Type FIT FIT EMW FIT to 12.0 ppg for a -113 bbl kick tolerance / 10.3 ppg EMW Well Evaluation ProQram ~ 16" Surface: Drilling: Open Hole: Cased Hole: Coring: Sampling: 12-1/4" Intermediate: Drilling: Open Hole: Cased Hole: Coring: Sampling: 8-1/2" Production: Drilling: Open Hole: Cased Hole: Coring: Sampling: PSI-08 Well Plan 8/16/02 MWD / GR - Recorded over entire interval. None None None None MWD / GR / Res / PWD- Realtime from 500' above BHRZ to section TD None USIT ./ None Cuttings Samples and Gas Detection - from 500' above BHRZ to section TD MWD I GR / Res I Neu- Realtime over entire interval BHC Sonic None None Cuttings Samples and Gas Detection - Entire Interval Page 4 -) Cement Program ) The following surface casing cement calculations are based upon a single stage job. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. Casing Size /13-3/8" Surface / Basis: Lead: Open hole volume + 400% excess in permafrost; 500/0 excess below permafrost. Lead TOC: To Surface. Tail: Open hole volume + 50% excess + 82' shoe track volume. Tail TOC: 1000' MD above 13-3/8" shoe (-5517' MD) Fluid Sequence & Volumes: Pre None Flush Spacer Lead Tail 75 bbls MudPUSH Viscosified Spacer weighted to 10.0 ppg 1132 bbl / 6356 fe / 1434 'Sks of Dowell ArticSET III-Lite at 10.7 ppg and 4.44 dIsk, BHST 45° / BHCT 52°, TT = 6.0 hrs 125 bbl /700 fe / 603 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk, BHST 90° / BHCT 86°, TT = 4 hrs Casing Size I 9-5/8" Intermediate Basis: Lead: None Tail: Open hole volume + 50% excess + 82' shoe track volume Tail TOC: 1500' above 9-5/8" shoe (-11,161' MD) Fluid Sequence & Volumes: Pre 10 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 50 bbls MudPUSH Viscosified Spacer weighted to 11.5 ppg None 132 bbl / 741fe / 633"'sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk, BHST 170° / BHCT 131°, TT = Batch Mix + 4.0 hrs Liner Size I 7" Production Basis: Lead: None Tail: Open hole volume + 500/0 Excess + 82' shoe track + 100' liner lap + 200' of 9-5/8" x 5" DP annulus volume. Tail TOC: -12,561' MD - Liner to:>. Fluid Sequence & Volumes: Pre 30 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail PSI-08 Well Plan 8/16/02 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None / 30 bbl / 168 fe / 140 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.16 cf/sk, BHST 181 ° / BHCT 137°, TT = Batch Mix + 3.5 hrs Page 5 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Surface Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 13-3/8" Casing Test pressure Intermediate Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test pressure Production Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Planned completion fluids . . . PSI-08 Well Plan 8/16/02 / 20", 2M Diverter (Hydril - MSP) 2080 psi (8.6 ppg @ 4652' TVD) 1615 psi (.10 psi/ft gas gradient to surface) N/A Function test 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3693 psi (8.6 ppg @ 8257' TVD) 2867 psi (.10 psi/ft gas gradient to surface) 113 bbls with a 12.0 ppg FIT qaJ{) \d~ Rams test to ~psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3879 psi (8.6 ppg @ 8675' TVD) 3012 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 4,000 psi/250 psi. Annular test to 2,500 psi/250 psi 4000 psi surface pressure 8.4 ppg Seawater 1 6.8 ppg Diesel Disposal Page 6 ) ) Drill and Complete Procedure Summary Pre-Ria Work: /1 1. Install 20" insulated conductor. 2. Weld an FMC landing ring for the FMC Big Bore wellhead on the 20" conductor. Install two 4" side outlet valves on the conductor pipe for surface cementing operations. Ria Operations: 1. MIHU Nabors 27e. I 2. Nipple up and function test divertersystem. PU 5" DP to drill surface hole and stand back in derrick. /'. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to approximately 6,517' MDl4,625' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 13-3/8", 68# surface casing back to surface-:' A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during pri~9!:Y. cemen~ operations. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to.ßð6CJ~Ot' ~ 6. MU 12-1/4" drilling assembly with MWD/GR/Res/PWD and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.0 ppg LSND drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Formation Integrity Test. 8. Drill ahead as per directional plan. Increase mud weight to 10.0 ppg prior to entering the HRl. Short trip as required. 9. TD the 12-1/4" interval in the Base of the HRl. Control drill the BHRl to aid in picking TD. , 10. Run and cement the 9-5/8",47# intermediate casing to 1500' above the top of the shoe./ Displace the 9-5/8" casing with 10 ppg LSND drilling mud during cementing operations and freeze protect the 13-3/8" X 9-5/8" annulus as required. / 11. MU 8-1/2" drilling assembly with MWD/GR/Res/Neu and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 12. Drill out shoe joints and 20' of new formation. Perform Formation Integrity Test to 10.3 ppg EMW. Displace hole over to 9.0 ppg BARADRILn fluid. ("'/ 13. Drill ahead as per directional plan to proposed TD at 13,069' MD / 8,592' TVD. The actual TD of the well will extend +/-60' TVD below the BSAD, but no deeper than 50' TVD above the TLSB. Short trip as required and condition hole for runnipg the 7" liner. 14. RU E-line. Run USIT log to determ~ bond quality and TOC. Make second E-line run with BHC Sonic/GR. 15. Run and cement the 7", 26# liner. The liner will extend up into the 9-5/8" casing -100' MD and will be fully cemented to the liner top. Displace cement with mud. POOH. 16. RIH with 9-5/8" and 7" ,98-sing scrapers. Tag PBTD, circ hole clean. Displace wellbore over to seawater. 17. Test wellbore to 4000 psi for 30 minutes. POH laying down drill pipe. 18. Run 7-5/8", IPC, Flush-joint, injection string with packer and tailpipe. / 19. Set packer with tubing tail at least 30' above liner hanger top. 20. Sheer out of PBR. PU and space out. Make up tubing hanger. 21. Circulate Freeze protection. Allow diesel to U-Tube in annulus. 22. Land Tubing hanger/sting back into PBR. 23. Pressure test tubing and annulus to 4000 psi for 30 mins. 24. Set TWC. Test to 1000 psi. 25. ND BOPE. NU tree and test to 5000 psi. 26. Set BPV, Secure well. RDMO. / Post-Ria Work: 1. Clean-up location as required. 2. Perforate and stimulate Ivishak intervals as required. 3. POI. PSI-08 WellPlan 8/16/02 Page 7 ) ) Job 1 :MIRU Hazards and Contingencies ~ The rig move will involve no surface close approach hazards with adjacent wells. The PSI-08 well will be drilled from an existing pad with five (5) other wells on the location: PSI-06, PSI-09, PSI-01, PSI-10, and East Bay State #1, an exploration well drilled in 11/74. EBS#1 was DST'd and then suspended with a CIBP @ 9300' MD and 100sx of cement. ~ H2S is not expected to be encountered during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. Job 2: Drill Surface Hole Hazards and Contingencies ~ No fault crossing are expected in the surface interval. ~ The nearest well is PSI-09, which is 30' center to center at surface and over 1300' center to center at surface casing point. ~ Gas hydrates have not been observed at the other wells on the pad: PSI-06, PSI-09, PSI-01, PSI-10, and East Bay State #1. Gas hydrates are not expected at PSI-08. ~ Two offset wells on the West Beach pad have experienced deeper gravel beds below the Permafrost. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ Abnormally pressured shallow gas has NOT been observed at other wells on the pad: PSI-06, PSI-09, PSI-01, PSI-10, and East Bay State #1. Abnormally pressured shallow gas is not expected at PSI-08. Job 3: Install 13-3/8" Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 4000/0 excess cement through the permafrost zone (and 50% excess below the permafrost) is planned. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. ~ Hole cleaning will be difficult in the 16" hole with 5" DP. Maintain adequate viscosity and high flow rates. Short trip as required. ~ Cementing practices on the surface casing should meet the below criteria. 1. Pipe reciprocation during cement displacement 2. Cement - Top of lead to surface 3. Cement - Top of tail >1000' MD above shoe using 500/0 excess. 4. Casing Shoe Set approximately -100'TVD below SV-1 sand. Job 4: Drill Intermediate/Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-08 wellpath in the intermediate hole. ~ The nearest well is PSI-09, which is 30' center to center at surface and over 2000' center to center at intermediate casing point. ~ Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. ~ Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. No increase in pore pressure was observed at PSI-06, PSI-09, or PSI-01, and is not expected at PSI-08. Check for flow after cutting the Ugnu. . PSI-08 Well Plan 8/16/02 Page 8 ) "\ ') ~ The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. ~ Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. ~ For adequate hole cleaning flow rates should be maintained in the 850 gpm range, particularly while drilling with higher RaP's (200'/hr). ~ The kick tolerance for the 12-1/4" open hole section would be 113 bbls assuming a kick while at the section TD (-12,661' MD 1 8,208' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. ~ Picking the 9-518" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 3 (7.5 ppg). Job 6: Install 9-5/8" Intermediate/Production Casina Hazards and Contingencies ~ Differential sticking is a concern across the Ugnu and West Sak sand intervals. Communicate individual responsibilities to all members of rig team and review connection 1 tripping practices to minimize the time the pipe is left stationary. ~ Verify the floats are holding priorto continuing operations. If floats are not holding, hold pressure and wait on cement. ~ Run USIT log to determine cement bond quality and TOC. State must approve cement integrity to allow injection. Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-08 wellpath in the production hole. ~ Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. ~ Extra vigilance is required to avoid swabbing. The Ivishak will be highly permeable and gas bearing. ~;.;,;.~ ..~ Job 8: Loa 8-1/2" Hole Hazards and Contingencies ~ Differential sticking is a concern in the Ivishak due to the low pore pressure. Keep tools moving at all times and monitor line tension. ~mmn....m~."._.......nn'L'" 'n_m.^m.___m.._n~!' .,.. ,.. ~"hnmn.~'.._'.(.' ,_,_mmV..__'- .,___m---"...._m_~~:; -~.., PSI-08 Well Plan 8/16/02 Page 9 ~) ) Job 9: Install 7" Production Liner Hazards and Contingencies þo> Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. þo> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 12: Run Completion Hazards and Contingencies þo> 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. þo> The injection tubing will be large diameter with flush joint connections. This job will be non-routine. Ensure all personnel are briefed of the potential hazards. Review all aspects of the operation withal! rig team members prior to starting the job. þo> Ensure personnel are clear of rig floor during packer setting and when shearing out of the PBR. There will be the potential for a sudden release of stored energy with the string to jump at surface. þo> Freeze protection operations will also be non-routine without a RP Shear valve in the injection string. Freeze protection will be done through the BOP stack and choke manifold. Take extra precaution to avoid spills. Ensure all lines are blown down to vac truck. Job 13: ND/NU/Release RiCl Hazards and Contingencies þo> 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. PSI-08 WellPlan 8/16/02 Page 10 ) ') PSI-OS Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were not observed at the other 5 wells on this pad, and are not expected at PSI-08. . Shallow gas was not observed at the other 5 wells on this pad, is not expected at PSI-08. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Intermediate Hole Section: . Fault crossings are not expected along the PSI-08 wellpath in the intermediate hole. . Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. . Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. This has not seen at other PSI wells and is not expected at PSI-08. . The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. . Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. . The kick tolerance for the 12-1/4" open hole section would be 113 bbls assuming a kick while at the section TD (-12,661' MD / 8,208' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. . Picking the 9-5/8" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 3 (7.5 ppg). Production Hole Section: . Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. . The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. H2S is not expected during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PSI PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION PSI-08 Well Plan 8/16/02 Page 11 EC1-0B Completion Desi(c'l 100,000 bbls/day @ 2700 psi injection pressure XOver #1- Tbg Hanger: 7" NSCC Box X 7-5/8" STL Pin 20" x 34" Insulated Conductor @ +/- 80' Tree: 6-3/8" bore x 7-1/6" 5K, 625 Inlay, CIW Wellhead: 13-5/8", 5K, Big Bore FMC 7" Camco 6.00" DB Nipple with Injection Valve at -2200' 7-5/8",29.7#, ST-L, IPC, Injection Tubing (w/7" accessories) 7" x 5.963" HES R Nipple 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG Note: All tailpipe and accessories to be TCII Date 8-1 6-02 Rev By RBT Completion Design Comments H ). j 13-3/8" TAM Port Collar @ +/- 1000' MD XOver #2&3-lnjection Valve: 7 -5/8" STL Box X 7" TCII Pin 7" TCII Box X 7-5/8" STL Pin 13-3/8",68#, L-80, BTC Surface Casing @ +/- 4625' TVD; 6517' MD XOver #4-Seal Assembly: 7 -5/8" STL Box X 7" TCII Pin / Packer set at +/- 12470' MD 7" x 9-5/8" Baker HMC Liner Hanger, ZXP Liner Top packer, and tieback sleeve 9-5/8",47#, L-80, BTC-M Intermediate Casing @+/- 8208' TVD; 12661' MD 7", 26#, L-80, BTC-M Injection Liner @ +/- 8592' TVD: 13069' MD PROJECT: GCWSI WELL: PSI-OS API NO: GPB Rotary Drilling LOCATED WITHIN PROTRACTED SEC. 15, T. 11 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS PSI-8 Y=5,966,169.23 N= 9,999.73 70.18'39.344" 70.3109289" 17.1' 3,867' FSL X= 708,024.82 E= 5,120.32 148.18'50.941" 148.3141503" 4,379' FEL Y= 5,966,189.90 N= 9,999.93 70.18'39.532" 70.3109811" 3,886' FSL PSI-10 X= 708,081.03 E= 5,180.21 148"18'49.286" 148.3136906" 17.2' 4,322' FEL ') ~. //,/./ .~//'/'~ ".~:, ,'~'~/ PRUDHOE BAY / ,.../,.//"" // /'/~'/~/ ~"./ ../',..// 0 0 ò p 0 C\¡ r- ---, z 8 S f3 a.. ,~ "' ."'.~' /'" ' r -~- I WF11NJECTlON / WEll FACilITY (EAST DOCK WEST PAD) ..J 0 ..J 00 W ..- == í <0 I m I e" I V5 I V5 ü5 ü5 ü5 z a.. a.. 0... a.. 0... ¡::: (f) . . + . + x w . I- ~ 4: ::E: <%: g èf, C\J ~ 8 C\J S .... g¡ NOTES: 1. DATE OF SURVEY: AUGUST 5 & 6, 2002. 2. REFERENCE FIELD BOOK: PB02-07 PAGES 47-48 & 50. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD27. 4. GEODETIC COORDINATES ARE NAD-27. 5. EAST DOCK FACILITY AVERAGE SCALE FACTOR IS 0.999949103. 6. HORIZONTAL CONTROL ESTABLISHED BY GPS STATIC OBSERVATIONS BASED ON DRILLSITE OPERATOR MONUMENT "DS-11A". 7. ELEVATIONS ARE ARCO MLLW BASED ON DRILLSITE 11 OPERATOR MONUMENT "DS-11A". a ~ "t5 š 'P ¡;;; 0.. !: :¡ f U1 <%: U1 to ~ U :J "t5 I: 0 U t: ~ -ð 0 ~ +> U1 d W c C I g ~ w C\J 0 ~ Q< ~ ~ t: ~ F. RObeut DRAWN: JACOBS l~ ]-- ~ i¡ ::::KED: ALLISON , 3/27/02 IÍÎfi¡f¡¡ DRAWING: FRB02 ED 03-00 ¡ BJg)~(JJ[~O JOB NO: J..C RFA =:=~ SCALE: 1"= 120' BY a-tK AHQtOOAŒ, IoU$(A "503 :>: u ,g +> U1 d W / 4: CJ ~ g 0 8/09/02 ISSUED FOR INFORMATION ;;:; NO, DATE RE't1SION )RUDHOE BAY --' PROJECT AREA I" ~ -- I L. I ~~. p. - . '------ ,- ~~~. '-' 'G. I ""'. LISBURNE 't DRILL SITE 3 , 22 I VICINITY MAP N.T.S. 21 LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 6, 2002. Obp GPB EAST DOCK WFl PAD AS-BUILT CONDUCTORS WELLS PSI-B, & PSI-10 SHEET: 1 OF 1 speI""'I""'Y-sur-, North Slope Alaska ORIL.L.ING A~'=~~~C::~ BPXA 0 1500 - 3000 - - ëi5 ~ .r::. 15. <l> 0 4500 -- ëõ <.) t <l> > 6000 - .:t::: g 7500 - L() II .c. u .S å) ëti u (f) 9000 - ~ .'"'''' ~ -. ^ "'^ ......... ^"'" lisburne PSI (East Dock) DrillQuest" PSI-OS WP05 Proposal Data for PSI-08 WP05 Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Well Well ft True North '-..... Begin 16" Hole Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 326.4000 -- Begin Dlr @ 1.5000/100ft: 300.OO1t MD, 300.00ft TVD Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E ~oooo Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 0.00 0.000 0.000 0.00 O.OON O.OOE 0.00 300.00 0.000 0.000 300.00 O.OON O.OOE 0.00 0.000 1600.00 End Dlr, Start Sail @ 24.033°: 1902.17ftMD,1855.60ftTVD 1902.17 24.033 326.400 1855.60 275.79 N 183.24 W 331.11 1.500 BPERMAFROST. 1905.6011 TVD 2121.15 24.033 326.400 2055.60 350.07 N 232.59 W 420.30 0.000 -------- 2630.55 34.221 326.400 2500.00 556.32 N 369.62 W 667.92 2.000 "~ Begin Dlr @ 2.oooo/100ft: 2121.15ft MD, 2055.6Oft TVD 3239.97 58.597 326.401 2917.03 921.20 N 612.04 W 1105.98 4.000 400.00 11193.66 58.597 326.401 7061.32 6575.72 N 4368.71 W 7894.66 0.000 Increase in Dlr Rate @ 4.oooo/100ft : 2630.55ft MD, 2500.00ft TVD 12477.44 20.084 326.349 8035.60 7240.77 N 4810.80 W 8693.25 3.000 End Dlr, Start Sail @ 58.597° : 3239.97ftMD,2917.03ftTVD 12680.81 20.084 326.349 8226.60 7298.91 N 4849.50 W 8763.08 0.000 13069.44 20.084 326.349 8591.60 7410.00 N 4923.45 W 8896.54 0.000 Current Well Properties - - - .SV1, 4544.6011 TVD Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates : RKB Elevation: PSI-08 5966169.23 N, 708024.82 E 122.48 N, 267.31 E 70018' 39.3442" N, 1480 18'50.9414" W North Reference: Units: 51.60ft above Mean Sea Level 51.60ft above Structure True North Feet (US) - - - _WEST SAK 2. 6413.6011 TYD 104e&.œ- - WEST SAt< 1. 6599.6011 TYD - - - - CM3. 6802.6011 TVD Begin Dlr @ 3.oooo/100ft : 11193.66ft MD, 7061.32ft TV - ~ 9 5/8" Casing ~ 12660.53ft MD C9 ~ 1200000 8207 55ft TVD End Dlr Start Sail @ 20.084° : 12477.44ftMD 8035.60ftTVD-- ~ Begin 8-1/2" Hole , '~ _THRZ. 8035.6011 TVD PSI.08 T1 DD Poly @ 95%: 8226.60ft TVD, 7298.91 N, 4849.50 W---- - BHRZlLCU/TZ4. 8226.6011 TVD N"""'" M",,,", ". - -TZ2CIBCGL 8291.6011 TVD TZ2B/23SB.. 8336.6011 TYD - -BSAO, 8537.6Oft TVO -rD. 8591.60ft TYO PSI-08 T2; 8591.60ft TVD. 7410.00 N. 4923.45 W ~/ 7'; Liner Total Depth: 13069.44ftMD,8591.60ftTVD 13069.44ft MD I I I 8591.60lt TVD 6000 7500 9000 Section Azimuth: 326.4000 (True North) - I 0 1500 Scale: 1 inch = 1500ft I 3000 I 4500 Vertical Section (Well) .-/ bp . ...) sper'lr"Y-sUf"'1 North Slope Alaska DRILL.IIIIG SEAVlc:és BPXA ill ""'M>unO<l C_~I\V - <D ~ 4000 - en 0) .~ ..c t 0 Z +-' Õ 0 0 II £: 0 .~ Q) 0 -æ 0 (fJ DrillQuesl 2.00.09.006 7000 6000 - 5000 - 3000 - 2000 - 1000 - ) lisburne PSI (East Dock) PSI-OS WP05 DrillQuest' Current Well Properties PSI...Q8 5966169.23 N, 708024.82 E 122.48 N, 267.31 E 70018' 39.3442" N, 148018' 50.9414. W Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates : RKB Elevation: 51.60ft above Mean Sea Level 51.60ft above Structure True North Feet (US) 7' Uner 13069.4411 MD 8591.6OIt TVD North Reference: Units: PSI-08 T2: 8591.6Oft TVD, 7410.00 N, 4923.45 W Total Depth: 13069.44ftMD,8591.6OftTVO - ------psl-oa T1: 8226.6Oft TVD, 7298.91 N, 4849.50 W ~------ -- Begin 8-112" Hole End Oir, Start Sail @ 20.084° : 12477.44ftMD,8035.60ftTVD -------- pSl-oa T1 DO Poly @ 95% .- -- - . PSI-DB T1 Geo Poly Begin Dir @ 3.0000/100ft: 11193.66ft MD, 7061.32ftTVD Proposal Data for PSI-OS WP05 Vertical Origin: ~~~;~~¡~~~;~~i¡S : North Reference: Well Well It True North Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 326.400" Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Northlngs Eastings Vertical Dogleg Depth Depth Section Rate 0.00 o. om OJ)(KI O.(K) O,(K) N (UK I E 0.00 3CXI.IK) O.!KKI O.(KKI 3(KtOO OJK) N (UKIE (UKI O.(KKI 1902.17 24.(133 32fo.4tKI 1~55.60 275.79 N 1!ß.24 W 331.11 1.5(K) 2121.15 24.0.33 326.4t)(1 2055.60 350m N 232.59 W 420.30 O.l)(K) 2630.55 34.221 326.4CK) 25(KI.()() 556.32 N 36<.1.62 W 667.92 2.0CK) 3239.97 5X.597 326.4t1l 2917.03 921.20 N 612.04 W I I05.9~ 4.1)(K) 1119:Hi6 5!ì.597 326.4t11 7061.32 6575.72 N 436~.71 W 7X94.66 O.lKK) 12477.44 20.0~4 326.349 X035.60 7240.77 N 4~IO.XO W X693.25 3.0(K) 1 26XO.X 1 20.0~4 326.349 X22(i.60 729~.91 N 4X49.50 W X7(i3.0X O.l)(K) 13069.44 20.0X4 326.349 X591.60 7410.00 N 4923.45 W !(X96.54 O.l)(KI Begin 12.1/4" Hol ~ 13 3/8" Casing~ 50000 6517.1211 MD 4624.6Oft TVD DFO ¡ End Dir, Start Sail @ 58.597" : 3239.97ftMD,2917.03ftTVD Increase in Dir Rate @ 4.0000/100ft : 2630.55ft MD, 25OO.00ft TVD Begin Oir @ 2.0000/100ft: 2121.15ft MD, 2055.6Oft TVD End Dir, Start Sail @ 24.033° : 1902.17ftMD,1855.6OftTVD Begin Dir @ 1.50001100ft: 3OO.00ft MD, 3OO.00ft TVD ------ \. Begin 16" Hole_~ I I -5000 -4000 Scale: 1 inch = 1 OOOft I I -3000 -2000 Eastings (Well) I -1000 0 Reference is True North . . SPeJ"1l""ly-sUl Nort" Slope JaSka PRIL-LING . SERVICSS BPXA " Ha'5t>~"<i#I C<I1IIpa"V Lisburne ..ll (East Dock) PSI-OS WP05 DrillQuest' Single Well Target Data for PSI-OS WP05 Measurement Units: ft Coordinate Target Point TVD Northings Easti ngs SSTVD Northi ngs Eastings Target Name Type ASPY ASPX Shape PSI-OS TI Emry Point 8226,60 7298.91 N 4849.50 W 8175.00 5973331.00 N 702975.00 E Polygon DD Poly @ 95~, 702802.81 E Boundary Point A 8226.60 7376.06 N 5019.61 W 8175.00 5973403.41 N B 8226.60 7 181.56 N 5025.30 W 8175.00 5973208.83 N 702802.51 E C 8226.60 7165.68 N 5016.30 W 8175.00 5973193.21 N 702811.95 E ) 8226.60 7160.75 N 4993.53 W 8175.00 5973188.91 N 702834.85 E E 8226.60 7159.71 N 4836.88 W 8175.00 5973192.21 N 702991.47 E F 8226.60 7166.97 N 4817.34 W 8175.00 5973200.0 I N 703010.80 E G 8226.60 7179.90 N 4806.47 W 8175.00 5973213.23 N 703021.31 E H 8226.60 7197.25 N 4801.74 W 8175.00 5973230.71 N 703025.55 E I 8226.60 7370.79 N 4795.73 W 8175.00 5973404.35 N 703026.75 E J 8226.60 7391.75 N 4796.05 W 8175.00 5973425.29 N 703025.85 E K 8226.60 7407.64 N 4805,(16 W 8175.00 5973440.92 N 703016.41 E L 8226.60 7412.57 N 4827.82 W 8175.00 5973445.22 N 702993.52 E M 8226.60 7413.60 N 4984.48 W 8175.00 5973441.91 N 702836.89 E N 8226.60 7406.35 N 5004.02 W 8175.00 5973434.12 N 702817.56 E 0 8226.60 7393.42 N 5014.89 W 8175.00 5973420.90 N 702807.05 E PSI-OS TI Gco Poly Entry Point 8226.60 7298.91 N 4849.50 W 8175.00 5973331.00 N 702975.00 E Polygon Boundary Point A 8226.60 7487.04 N 5104.38 W 8175.00 5973512.00 N 702715.00 E B 8226.60 7109.18N 5114.85 W 8175.00 5973134.00 N 7027 I 5.00 E C 8226.60 7098.38 N 4725.00 W 8 I 75.00 5973134.00 N 703105.00 E D 8226.60 7476.23 N 4714.53 W 8175.00 59735 I 2.00 N 703105.00 E PSI -OS T2 Entry Point 8591.60 7410.00 N 4923.45 W 8540.00 5973440.00 N 702898.00 E Point -'-"_._'-",_.._.~. .--- ._._----_._--+---- ...- "-----'-----'-----------'----'--'--------'----- -.---..--- .---.---- PSI-OS WP05 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip Dip Dir. Formation Name (ft) (ft) (ft) (Deg) (Deg) 1956.91 1905.60 1854.00 0.000 0.000 BPERMAFROST 4478.93 3562.60 3511.00 0.000 0.000 SV4 5256.21 3967.60 3916.00 0.000 0.000 SV3 5641.97 4168.60 411 7.00 0.000 0.000 SV2 6363.58 4544.60 4493.00 0.000 0.000 SVI 7284.80 5024.60 4973.00 0.000 0.000 UG4 7707.02 5244.60 5193.00 0.000 0.000 UG3 8944.90 5889.60 5838.00 0.000 0.000 UGl 9950.56 6413.60 6362.00 0.000 0.000 WEST SAK 2 10307.53 6599.60 6548.00 0.000 0.000 WEST SAK 1 1 0697. 13 6802.60 6751.00 0.000 0.000 CM3 12477.44 8035.60 7984.00 0.000 0.000 THRZ 12680.81 8226.60 8175.00 0.000 0.000 BHRZlLCUffZ4 12694.65 8239.60 8188.00 0.000 0.000 TZ3rrCGL 12756.41 8297.60 8246.00 0.000 0.000 TZ2C/BCGL 12797.93 8336.60 8285.00 0.000 0.000 TZ2B/23SB 13011.95 8537.60 8486.00 0.000 0.000 BSAD 13069.44 8591.60 8540.00 0.000 0.000 TD DrillQuest 2.00.09.006 H DATE CHECK NO. 8/01/02 H207034 VENDOR DISCOUNT NET H $100.00 207034 DATE INVOICE / CREDIT MEMO GROSS DESCRIPTION 08/01/02 . CK073102A Permit to Dril::'" Fee ~I.DB Pls contact Sondra Stewman X4750 for ckeck pickup THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ $100.00 TO THE ORDER OF Alaska Oil & Gas Conservation Corom 333 W 7th Ave, Ste 100 Anchorage, AK 99501 NOT VALID AFTER 120 DAYS III 2 0 ? 0 3 1.111 I: 0 I. ~ 2 0 3 a '1 5 I: 0 0 a I. I. ~ 'illl ;~.;.\: ~ :::.\:: :::::::::{ ::::~::::'::J./:..: !\::~.:~~:: ~\::~ ~":,::: ~.~ .:':";.: .:~~~-~::~:.....,......~:......::......¡:..... ~:~\~.~r+{?~\Ù~~i{:;~~\~ç::.; '-" ~/ ) '} ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /'Aa /'sf-01 PTD# :Zo.2--17~ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ,WELL PERMIT CHECKLIST COMPANY AP)¿ WELL NAME fAu Ps I - c> <6 PROGRAM: Exp - Dev - Redrll - Re-Enter --- Serv ~ Wellbore seg - FIELD & POOL 0 tjo/.5" ð INIT CLASS ¡-û//;;¡¡ GEOL AREA "8'lð UNIT# I/C..(ð ON/OFF SHORE ~ ~ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 10 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique wen name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Wetllocated proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ YIiz!o<- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . \ Y N 12. Permit can be issued without administrative approval.. . . . . l:tI N (Service Well Only) 13. W. ell located wlin area & strata authorized by injection order #!iL. (f). N (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . ., C!/ N ~.lVe- ENGINEERING 15. Conductor string provided. ..'.""'.'.".'" 0N 3<1" xlo" @ fl3;. 16. Surface casing protects all known USDWs. . . . . . . . . . . &~N -I- 17. CMT vol adequate to circulate on conductor & surf csg. . . . . éi! N. .eIJ..~. €~æç ç, 18. CMT vol adequate to tie~in long string to surf csg. . . Y 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N ~~: ~~:~n~a~:~~~~;~~~~:~~~~ ~it:: ~ ~ :~r~~fr.o~t.. : .' : .' .' : ~ ~ AkkJ)~ s t 7 t 22. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ¡..itA 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . . N I 25. D.rilling fluid program schematic & equip list adequate. . . . . J N M.. «-1é M li- I ð. 0 f P. í . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N It ~ L d 27. BOPE press rating appropriate; test to l../ooo psig. N Yh S (? ?;ofL P ~. JIhM. CtJ.j 1-e~ (' To.{).!) yst , A. /. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N V-iGI1 (" Ol. 29. Work wHl occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y tJjJ - A /\ n 31. Mechanical condition of wells within AOR verified. . . . . . . .¥-N- Ai ¡p A...{.. I k.... 1'\1,/1(.. . ;rCfN MI'9, Y N Y N APPR DATE ',APPR DATE (Service Well Only) GEOLOGY ~APPR DATE be:; ~;?'þ7 I'(E;Ploratory Only) Rey: 07/12/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . GEOLOGY: RPC~é""~ COMMISSIONER: COT 1 . DTS O~ 231°~ CommentsJlnstructions: RESERVOIR ENGINEERING JDH <ßt UIC ENGINEER JBR PETROLEUM ENGINEERING: TEM SFD WGA 'vJ6A- MJW G:\geology\permits\checklist.doc ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special" effort has been made to chronologically organize this category of information. ) ') <:90<9- J7~ //0í7)' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 24 12:49:56 2003 Reel Header Service name...... . . . . . . .LISTPE Date.................... .03/03/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/03/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA PSI-08 500292311400 BP Exploration Sperry Sun 24-MAR-03 (Alaska) Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22145 T. GALVIN W. DECKER MWDRUN 2 AK-MW-22145 T. GALVIN D. FERGUSON MWDRUN 3 AK-MW-22145 J. BOBBITT D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 15 llN 15E 3867 900 MSL 0) .00 51.00 17.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING OPEN HOLE BIT SIZE (IN) 16.000 12.200 8.500 CASING SIZE (IN) 20.000 13.375 9.625 DRILLERS DEPTH (FT) 113.0 6451.0 12724.0 ) ') PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR)/ UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ COMPENSATED NEUTRON POROSITY (CNP) ¡ AND STABILIZED LITHO-DENSITY (SLD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN PSI-08 ON 21 SEPTEMBER 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 12 NOVEMBER 2002. 7. MWD RUNS 1 - 3 REPRESENT WELL PSI-08 WITH API#: 50-029-23114-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13177/MD / 8633/TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX/ FIXED SNFA = SMOOTHED AVERAGE OF FAR DETECTOR/S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR/S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. (EXTRA SHALLOW SPACING) . (SHALLOW SPACING) . (MEDIUM SPACING) . (DEEP SPACING) . HOLE SIZE) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.50" MUD WEIGHT: 9.0 PPG MUD SALINITY: 15/500 PPM CHLORIDES FORMATION WATER SALINITY: 50/000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET PEF NCNT FCNT NPHI RHOB DRHO $ ) 1 ') clipped curves; all bit runs merged. .5000 START DEPTH 51.5 122.0 6401.5 6401.5 6401.5 6401.5 6401.5 12654.0 12656.0 12656.0 12737.5 12742.0 12742.0 STOP DEPTH 13144.0 13179.0 13135.0 13135.0 13135.0 13135.0 13135.0 13103.5 13095.0 13095.0 13095.0 13103.5 13103.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -. BASELINE 1.5 12111.0 12112.5 12117.5 12119.5 12124.5 12126.5 12129.5 12132.5 12134.0 12136.0 12139.5 12146.0 12149.5 12161.0 12163.5 12166.0 12176.5 12180.0 12182.5 12188.5 12190.0 12192.0 12196.5 12202.0 12206.0 12213.0 12216.0 12220.5 12224.5 12226.5 12230.5 12231.5 12234.0 12237.0 12243.0 12246.5 12254.5 12258.0 DEPTH GR 43.0 12102.5 12105.5 12110.0 12112.0 12118.0 12120.0 12122.5 12125.0 12128.5 12130.5 12134.0 12140.5 12143.0 12154.5 12158.0 12161.5 12170.5 12174.5 12177.5 12184.0 12185.0 12186.5 12190.0 12195.5 12200.0 12206.5 12210.0 12213.5 12218.5 12220.5 12223.0 12224.5 12226.5 12231.0 12237.0 12239.5 12247.0 12252.0 ) ) 12261.5 12264.0 12267.5 12269.0 12277.5 12280.5 12282.5 12291.0 12297.0 12304.0 12311.0 12313.0 12317.0 12320.0 12323.0 12326.0 12327.5 12335.0 12336.5 12338.0 12343.5 12344.5 12350.5 12356.0 12357.5 12359.5 12362.0 12367.5 12374.5 12380.0 12382.0 12387.0 12395.5 12397.5 12401.0 12402.5 12404.5 12407.0 12412.0 12416.5 12429.0 12433.5 12435.5 12438.0 12442.5 12445.0 12448.5 12450.5 12456.0 12463.5 12465.5 12470.5 12476.0 12480.0 12482.0 12485.0 12486.5 12491.0 12498.0 12503.5 12506.0 12508.5 12515.5 12522.0 12526.5 12531.5 12254.0 12256.5 12260.5 12263.5 12272.0 12275.0 12278.5 12287.5 12291.0 12295.5 12303.5 12305.5 12309.0 12311.5 12314.0 12316.5 12318.5 12327.5 12329.5 12330.5 12336.0 12339.0 12343.0 12349.0 12351.0 12352.5 12353.5 12362.5 12368.5 12374.0 12376.5 12380.0 12388.5 12390.0 12393.0 12395.0 12397.5 12399.0 12403.0 12409.0 12422.5 12427.0 12429.0 12431.5 12436.0 12438.0 12440.0 12441.0 12449.5 12458.0 12461.5 12466.5 12469.5 12473.5 12475.5 12477.5 12478.5 12481.5 12490.5 12496.5 12500.0 12503.5 12509.0 12515.5 12519.0 12524.0 ) ') 12533.5 12537.5 12540.5 12543.5 12547.0 12550.0 12553.0 12556.0 12557.5 12561.0 12564.0 12567.5 12573.0 12574.5 12578.5 12581.0 12583.0 12585.0 12587.0 12591.5 12594.0 12596.0 12599.0 12602.0 12608.5 12611.5 12617.0 12620.0 12622.5 12623.5 12626.5 12634.5 12637.0 12641.5 12643.5 12646.0 12651.0 12654.0 12657.0 12660.0 12661.5 12664.0 12667.0 12669.5 12671.5 12674.5 12677.0 12680.0 12681.5 12691.5 12696.0 12699.5 12703.5 12707.5 12711.5 12713.0 12715.0 12719.0 12725.0 12727.5 12729.0 12733.0 12735.5 12738.0 12739.0 12740.5 12527.0 12531.0 12534.0 12537.0 12540.0 12544.5 12547.0 12549.5 12552.0 12556.0 12558.5 12561.5 12567.5 12570.0 12573.0 12575.0 12578.0 12580.5 12583.0 12585.5 12587.5 12591.0 12593.0 12597.0 12602.5 12605.0 12610.0 12612.0 12615.0 12617.5 12620.5 12628.5 12630.5 12635.0 12637.0 12640.5 12645.0 12647.5 12651.5 12654.0 12657.0 12659.5 12662.0 12664.5 12666.5 12669.0 12671.5 12674.0 12677.0 12682.0 12694.0 12697.5 12700.5 12705.0 12709.5 12710.5 12713.0 12717.0 12723.0 12724.5 12726.5 12729.5 12732.5 12737.0 12738.5 12740.5 ) ') 12742.0 12744.0 12746.0 12747.0 12751.5 12756.0 12759.0 12760.5 12763.0 12769.0 12771.0 12776.5 12778.0 12785.5 12787.5 12790.0 12802.5 12806.5 12818.5 12820.5 12822.5 12830.0 12831.0 12832.5 12837.0 12841.0 12844.5 12852.0 12857.0 12861.5 12865.5 12868.5 12871.0 12875.0 12881.5 12883.0 12885.0 12891.0 12897.0 12904.0 12905.5 12922.5 12926.0 12929.0 12932.0 12934.5 12936.5 12940.0 12941.5 12942.5 12947.0 12949.0 12954.5 12957.0 12962.5 12966.0 12968.0 12970.0 12972.0 12977.5 12980.0 12987.0 12993.5 12995.0 12997.5 13002.5 12742.0 12743.5 12745.0 12747.0 12750.5 12757.0 12759.5 12761.0 12763.5 12769.5 12771.0 12774.0 12776.5 12784.0 12786.5 12788.5 12800.5 12803.0 12816.0 12819.0 12820.5 12828.5 12830.5 12832.5 12836.0 12840.5 12844.0 12851.5 12855.5 12860.0 12865.5 12867.0 12870.5 12874.0 12880.5 12881.5 12883.5 12890.0 12897.0 12903.5 12905.0 12923.0 12926.5 12929.0 12932.5 12934.5 12936.5 12940.0 12942.0 12944.0 12946.5 12948.5 12953.5 12956.5 12962.0 12966.5 12968.0 12970.0 12972.5 12978.0 12980.0 12987.5 12991.5 12994.0 12996.5 13000.5 ) ) 13007.0 13009.5 13011.5 13015.0 13017.5 13022.5 13025.5 13027.5 13032.0 13036.5 13039.5 13046.0 13051.5 13054.0 13055.5 13060.0 13064.0 13069.5 13079.5 13081.5 13093.0 13095.0 13099.5 13102.0 13104.0 13109.0 13112.0 13114.0 13115.5 13120.0 13125.0 13130.5 13133.0 13140.0 13143.0 13179.0 $ 13005.5 13007.5 13010.0 13014.5 13016.5 13021.5 13024.5 13027.0 13032.0 13033.5 13038.5 13045.0 13049.0 13052.5 13054.0 13058.5 13063.5 13070.0 13077.5 13080.5 13091.0 13092.5 13099.0 13101.0 13102.5 13107.5 13111.0 13113.5 13115.5 13119.0 13123.5 13130.0 13132.0 13138.5 13141.0 13177.0 # MERGED DATA PBU TOOL MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 43.0 2 6393.0 3 12647.5 MERGE BASE 6464.0 12735.0 13177.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 ) ) RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 51.5 13179 6615.25 26256 51.5 13179 ROP MWD FT/H 0.04 1125.18 203.924 26115 122 13179 GR MWD API 16.77 316.32 69.5748 26186 51.5 13144 RPX MWD OHMM 0.25 737.33 5.38315 13468 6401.5 13135 RPS MWD OHMM 0.3 2000 10.3282 13468 6401.5 13135 RPM MWD OHMM 0.08 2000 12.4226 13468 6401.5 13135 RPD MWD OHMM 0.61 2000 36.9388 13468 6401.5 13135 FET MWD HOUR 0.08 90.95 1.77754 13468 6401.5 13135 NPHI MWD pu-s 9.2 81.76 20.6028 716 12737.5 13095 FCNT MWD CNTS 417 1533 892.825 879 12656 13095 NCNT MWD CNTS 2286 4282 3289.76 879 12656 13095 RHOB MWD G/CM 1.949 2.898 2.29248 724 12742 13103.5 DRHO MWD G/CM -0.163 0.474 0.0294406 724 12742 13103.5 PEF MWD BARN 1.22 13.62 4.19372 900 12654 13103.5 First Reading For Entire File........ ..51.5 Last Reading For Entire File......... ..13179 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 File Type......... ..... ..LO Next File Name... ...... ..STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 File Type......... ..... ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 header data for each bit run in separate files. 1 .5000 START DEPTH STOP DEPTH ) GR ROP $ 43.0 113.5 6393.0 6464.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ............... . Down Optical log depth units......... ..Feet Data Reference Point.. ........... . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record............ . Undefined Absent value........... .....,.... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 08-SEP-02 Insite 66.37 Memory 6464.0 45.0 6464.0 .0 61.4 TOOL NUMBER 124725 16.000 113.0 SPUD MUD 9.40 185.0 9.2 1800 6.2 .000 .000 .000 .000 .0 97.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 ) ') GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 43 6464 3253.5 12843 43 6464 ROP MWD010 FT/H 0.04 1125.18 197.897 12702 113.5 6464 GR MWD010 API 16.77 110.63 54.0724 12701 43 6393 First Reading For Entire File........ ..43 Last Reading For Entire File........ ...6464 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPM RPS ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6393.0 6393.0 6393.0 6393.0 6393.0 6393.0 6420.5 STOP DEPTH 12689.5 12681.5 12681.5 12681.5 12681.5 12681.5 12735.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 16-SEP-02 Insite 66.37 Memory 12735.0 6464.0 12735.0 ) HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units..... "'" .Feet Data Reference Point.... ......... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 16.0 60.8 TOOL NUMBER 126027 67981 12.200 6451.0 LSND 10.80 48.0 9.0 900 2.8 2.100 1.060 2.900 1.910 65.0 136.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H Min 6393 0.27 Max 12735 830.42 Mean Nsam 9564 12685 215.267 12630 First Reading 6393 6420.5 Last Reading 12735 12735 -) ) GR MWD020 API 17.86 247 85.0497 12594 6393 12689.5 RPX MWD020 OHMM 0.78 57.77 3.47425 12578 6393 12681.5 RPS MWD020 OHMM 0.87 44.77 3.65819 12578 6393 12681.5 RPM MWD020 OHMM 0.08 111.08 3.94372 12578 6393 12681.5 RPD MWD020 OHMM 0.75 2000 11.9432 12578 6393 12681.5 FET MWD020 HOUR 0.08 80.79 1.78667 12578 6393 12681.5 First Reading For Entire File......... .6393 Last Reading For Entire File.......... .12735 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.... ...... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .03/03/24 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF FCNT NCNT RPD RPX RPM FET RPS GR ROP NPHI RHOB DRHO $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 12647.5 12650.0 12650.0 12677.5 12677.5 12677.5 12677.5 12677.5 12686.0 12720.5 12735.5 12742.0 12742.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): STOP DEPTH 13102.0 13092.5 13092.5 13134.0 13134.0 13134.0 13134.0 13134.0 13142.0 13177.5 13092.5 13102.0 13102.0 20-SEP-02 Insite 66.37 Memory 13177.0 ) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value................. .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 12735.0 13177.0 13.5 14.8 TOOL NUMBER 164580 134758 078940 151842 8.500 12724.0 BARADRIL-N 9.00 44.0 10.4 15000 3.4 .250 .130 .230 .180 70.0 143.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 ) ) NCNT MWD030 RHOB MWD030 DRHO MWD030 PEF MWD030 CNTS G/CM G/CM BARN 4 4 4 4 1 68 1 68 1 68 1 68 40 44 48 52 11 12 13 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12647.5 13177.5 12912.5 1061 12647.5 13177.5 ROP MWD030 FT/H 14.75 406.31 118.587 915 12720.5 13177.5 GR MWD030 API 18.4 316.32 73.2313 913 12686 13142 RPX MWD030 OHMM 0.25 1824.39 33.0445 914 12677.5 13134 RPS MWD030 OHMM 0.3 2000 98.0522 914 12677.5 13134 RPM MWD030 OHMM 0.34 2000 124.444 914 12677.5 13134 RPD MWD030 OHMM 0.61 2000 395.802 914 12677.5 13134 FET MWD030 HOUR 0.2 90.96 2.79756 914 12677.5 13134 NPHI MWD030 PU-S 9.2 81.76 20.9247 715 12735.5 13092.5 FCNT MWD030 CNTS 417 1533 885.746 886 12650 13092.5 NCNT MWD030 CNTS 2286 4282 3275.48 886 12650 13092.5 RHOB MWD030 G/CM 1.949 2.898 2.29164 721 12742 13102 DRHO MWD030 G/CM -0.163 0.474 0.0293329 721 12742 13102 PEF MWD030 BARN 1.22 13.62 4.31154 910 12647.5 13102 First Reading For Entire File........ ..12647.5 Last Reading For Entire File......... ..13177.5 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .03/03/24 Maximum Physical Record..65535 File Type................LO Next File Name.... .... ...STSLIB.005 Physical EOF Tape Trailer Service name...... ..... ..LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03 103 124 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03 103 124 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments........... ..... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ') )