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Home My WebLink About202-079MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-06 PRUDHOE BAY UNIT PSI-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/21/2022 PSI-06 50-029-23082-00-00 202-079-0 W SPT 7872 2020790 1968 2160 2160 2161 2163 66 140 137 135 4YRTST P Kam StJohn 11/6/2022 30 MinPretest Initial 15 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-06 Inspection Date: Tubing OA Packer Depth 41 2750 2723 2718IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221108203454 BBL Pumped:4.5 BBL Returned:4.5 Wednesday, December 21, 2022 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. ¿ [).2. - 079 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed 1111111111111111111 RESCAN ~olor Items: 0 Greyscale Items: DIGITAL DATA ~iskettes, No. ~ 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation BY: Helen ~ ¡~ x 30 = 1° + 0 Other:: Date: B :;s!ó if Isf rvrf . '1111111111111111111 Dateß % ó if Isl vvþ P J 3 = TOTAL PAGES /03 (Coun~~ not lr;lude cover ~'Àe~. tþ Date:'tJ/BSjDlf /s/ VVl 1111111111111111111 NOTES: BY: Helen ~ Project Proofing BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: / (J ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES Helen ~ Dat4 ~/64: If NO in stage 1, page(s) discrepancies were found: YES NO NO /s/ WI- P Stage 1 BY: BY: Helen Maria Date: /s/ I 11111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 JAN 2 4 NIT' o � December 21, 2010 a® Mr. Tom Maunder +s q. =a #i !.' Alaska Oil and Gas Conservation Commission AN 0 3 201 333 West 7 Avenue Anchorage, Alaska 99501 " °Si0 1i Subject: Corrosion Inhibitor Treatments of GPB PSI 'ret -i4e Dear Mr. Maunder, 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 bbls 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 4 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 MEMORANDUM To: Jim Regg ~ ~ ~j~j ~ 17 (lam P.I. Supervisor (L L FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 17, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI-06 PRUDHOE BAY UNIT PSI-06 Src: Inspector NON-CONFIDENTIAL Reviewed By:_ P.I. Suprv ;.1~k- Comm Well Name: PRUDHOE BAY UNIT PSI-O6 API Well Number: 50-029-23082-00-00 Insp Num: mitJJ100721172703 Permit Number: 202-079-0 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D Pst-o6 ~ Type Inj. ~' TVD 2020790',iTypeTest , SPT Te$t pSl 7s~z ~ 1968 ' ~ IA i sso QA 180 26IO ~ 360 zsss 360 2sas 360 - Interval aYRTST p~ P ~ Tubing Lazo Islo Isto Isto Notes: 3.1 BBLS methanol pumped. 1 well inspected; no exceptions noted. N:. h ~-_ ~.,~ _~ if .. Tuesday, August 17, 2010 Page 1 of 1 r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.txooks~a~ska_gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.hay~alaska.gov OPERATOR: FIELD !UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP F~cploration (Alaska), Inc. Prudhoe Bay /PBU / PS! Pad 7/4/10 Jerry Murphy Jeff Jones Packer Pretest Initial 15 Min. 30 Min. Well PSI-O6 T In_ W TVD 7,8 T - 1,820 1,810 1,810 1,810 Interval 4 P.T.D. 2020790 T test P Test 1968 550 2,610 2,585 2,585 P/F P Notes: MIT-IA to 2600 psi for 4 year UIC OA 180 360 360 360 Pum 3.1 bMs MEOH to achierre test ' Well PSI-08 T Iri . W TVD 8,014` Tuts 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2021720 T test P Test 23.5 Casi 675 2,610 2,590 2,585 P/F P Notes: MIT-IA to 2600 psi for 4 year UIC OA 250 500 500 500 Pum 2.9 bbls MEOH to achieve test Well PSI-09 T In'. W TVD 8,034' Tu ' 1,660 1,660 1,660 1,665 Interval 4 P.T.D. 2021240 T test P Test 2008.5 - 0 2.400 2,340 2,365 P/F P Notes: MIT-IA to 2400 psi for 4 year UIC OA 0 80 60 80 Pum 3 bbls MEOH to achieve test 45 Mme. Well T In'. TVD T 1,660 Interval P.T.D. T test Test 2,365 P/F Notes: Extended PSI-09 test for 15 minutes OA 80 Well PSI-10 T Iri. W TVD 8,05E T 1,750 1,750 1,760 1,760 Interval 4 P.T.D. 2021590 T test P Test - 2014 Casi 0 2,500 2,485 2,480 P/F P Notes: MIT-IA to 2500 psi for 4 year UIC OA 0 250 250 250 Pum 3.7 t~bls MEOH to achieve test ' ~ ~, 1.. TYPE INJ Codes TYPE TEST Codes _ D =Drilling Waste M =Annulus MontiOring ~" .~ "~i "~ ' ~~ ~J I ~ = ' j ° ~ ` ` G =Gas P =Standard Pressure Test ~' I =Industrial Wastewater R = Irrtemal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D = Differen~I Temper~ure Test "•Y'~ ~~~' ~'"~t~ ~~~~~ INTERVAL Codes I =Initial Test 4 =Fair Year Cycle V = Required uy Variance T =Test during Wakover O =Other (describe in notes) MIT Report Form BFL 11 /27/07 MIT PBU PSI-06 08 09 10 07-04-10.x1s pnv~ J;(i~- !Õt¡C¡ e e .---, .AI _'" -~ j ,'':/ ' : /71/1 !I::'-':> r~- i,,,,\ ~:. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test 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 OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / East Dock - PSI 07/16/06 Jack Winslow Packer Depth Pretest Initial 15Min. 30 Min. WeIlIPSI-06 1 Type Inj. I W TVD I 7,S72' Tubing 3,750 3,750 3,750 3,750 Interval 4 P.T,D,12020790 I Type test I P Test psil 2000 Casing 330 2,000 2,000 2,000 P/FI P Notes: MIT-IA for Reg Compo 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 PTD.12021720 Type test I P I Test psi I 2010 Casingl SOO 2,000 2,000 2,000 P/FI P Notes: MIT-IA for Reg. Camp. OA790 950 1950 950 Chuck Scheve declined to witness Weill I Type Inj.1 TVD I Tubing I Interval P.T.D.I I Type test I I Test psil I Casing I P/F Notes: I OAI I Weill Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill , Type Inj.1 I TVD I Tubing Interval p.T.D.1 Type test I I Test psi Casing P/FI 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 D = Other (describe in notes) .;,;<r'- ~'.M,,"~:r~~·;, 1,J)"".~\.,,¡;t,;.;... :3 .....'" ", ...."" 2006-0716_ MIT _PBU _PSI-OB.xls e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ¡g ~ ~,\,~ ~1 DATA SUBMITTAL COMPLrANCE REPORT 8/212004 Permit to Drill 2020790 MD 12145 ........ ---- Well Name/No. PRUDHOE BAY UNIT PSI-06 Operator BP EXPLORATION (ALASKA) INC )jJ¿í¿ API No. 50-029-23082-00-00 TVD 8598 / Completion Date 7/18/2002'/ Completion Status 1WINJ REQUIRED INFORMATION Samples No ---~- ------- Mud log Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, Acal, RES, US IT, AIT, HAlS, TlD, CNl, AMS-c Well Log Information: Log/ Data Digital Type Med/Fnnt cpt;g I Fog t:D I ' ¡ w- t.rJ ~l09 00g ~Og ¡ Rpt I ~g I ~ Uog ~g ~ Lt6g ¡¿g J/log [j íQPt "Rpt ~og J.lOg I lED D 1___- Electr Dataset Number Name Log Log Run Scale Media No 5 Blu 1 VínjectionPt()fil~ Pressure 5 5 Blu Blu l..11519 LlSVerificátiórt Directional Survey 1...- Gamma Ray 5 Blu 5 Blu 1 Blu 5 Col 25 Blu 2 Blu 25 Blu 5 Col 5 Blu DirectionalSUflléY gJS Verification See Notes V'taliperJog ~ectionalŠuiVøy ..£emênt Evaluation vT empèratu,.e LA1SVerificatio,,- ,../Directiona(S4Ï'Í/êY vSpinner '/ReservoirSatUfélttQh £....A1512 LIS Verification 5 5 Blu Blu ) J ~ -(Ai"\) 4. Current Status 1WINJ C;~ Directional Survey Yes (data taken from logs Portion of Master Well Data Maint) Interval OHI ~>../ Start Stop CH Received Comments ~50 12050 Case 12/10/2002 ~50 12050 Case 12/10/2002 01200 12057 Open 8/9/2002 114 12096 Case 2/18/2003 0 12145 Open 7/25/2002 MWD 4-1200 12057 Open 8/9/2002 Vf1200 12057 Open 8/9/2002 v1'1700 12049 Case 12/10/2002 0 12145 Open 7/25/2002 ./ èß'0000 11690 Case 8/9/2002 116 12095 Case 2/26/2003 ;,...11300 ~109 Open 9/13/2002 t-1'1300 12094 Open 9/13/2002 0 12145 Open 7/25/2002 £-11300 12094 Open 9/13/2002 00000 11690 Case 8/9/2002 L,.!)350 12050 Case 12/10/2002 114 12096 Case 2/18/2003 0 12145 Open 7/25/2002 LA350 12050 Case 12/1 0/2002 V§350 12050 Case 12/10/2002 116 12095 Case 2/26/2003 Platform Express Quad Combo Platform Express HCAl -~>' Platform Express MWD DATA SUBMITTAL COMPLIANCE REPORT 8/212004 Permit to Drill 2020790 Well Name/No. PRUDHOE BAY UNIT PSI-06 MD 12145 ~~-~- J . dl(og L:óg I ..k6g ,.,tog I Log ~ í g ¡ 'i.log VOg ~D I i ) , ~g C TVD 8598 Completion Date 7/18/2002 Casing collar locator t/Density vSeeNotes CGarnrnaR~y vCasing collar locator 11"11 027 See Notes 'vfemperatur~ ,leD C Tf I, ~D C Pds 1 [ i ILJD C Pds I i__- Well Cores/Samples Information: \)f2188 LlSVerification 42188 Rate of Penetration ) 2188 Induction/Resistivity Name Interval Stop Start Well Cored? ADDITIONAL INFORMATION Y~ Chips Received? .~ Analysis Received? ----- -- Comments: Y/N .--'- Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23082-00-00 Completion Status 1WINJ Current Status 1WINJ UIC Y 5 Blu 11200 12057 Open 8/9/2002 25 Blu (/1-1300 12094 Open 9/13/2002 Platform Express 25 Blu ð-t300 12094 Open 9/13/2002 Platform Express TCOM Subsea 25 Blu t/f1300 12094 Open 9/13/2002 Platform Express 25 Blu on 300 12136 Open 9/13/2002 5 Blu 11875 12020 Open 8/9/2002 25 Blu ¿'f'Î300 12109 Open 9/13/2002 Platform Express high "- resolution laterolog 5 Blu t...-11875 12020 Open 8/9/2002 5 Blu ví1875 12020 Open 8/9/2002 ~300 12109 Open 9/13/2002 LDWG Formatted Open hole edit of Wireline HRlAIPEX/BHC 25 Blu 9000~ 2033 Case 7/23/2003 Temperature Warm back Log PSP-PBMS 114 12145 Case 1 0/27/2003 25 114 12145 Case 1 0/27/2003 ROP, DGR, NGP, EWR - MWD 25 114 12145 Case 1 0/27/2003 ROP, DGR, NGP, EWR - MWD "- " Sent Sample Set Number Comments Received Daily History Received? è)N G/N Formation Tops DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2020790 Well Name/No. PRUDHOE BAY UNIT PSI-06 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23082-00-00 MD 12145 TVD 8598 Completion Date 7/18/2002 Completion Status 1WINJ Current Status 1WINJ UIC Q~-~.. Compliance Reviewed By: fiv Date: ~¥ ~,~ '1 ----- ~ -- ) .{JC$ -err! WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 17, 2003 RE: MWD Formation Evaluation Logs: PSI-06, AK-MW-22084 PSI-06: Digital Log Images 50-029-23082-00 1 CD Rom Jc9 \ O~ 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. Anchorage, Alaska 99508 Date: Signed~A\~"'~'~ OCT 2. -7' t~C!C,:) ~~~\n.~ ) ) dOé)-D7~ II 5/ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 19, 2003 RE: MWD Formation Evaluation Logs PSI-06, AK-MW-22084 1 LDWG formatted Disc with verification listing. API#: 50-029-23082-00 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: Si~~ Note: This data replaces any previous data for well PSI-06. RECEIVE C) FEB 262003 Ala5.ftlt or; & Gas Cort~. Co~!1 M~f3 ) ') Ó(Da-07<=¡ 1/5/ c¡ WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska February 17, 2003 RE: MWD Formation Evaluation Logs PSI-06, AK-MW-22084 1 LDWG formatted Disc with verification listing. API#: 50-029-23082-00 . .' ... . 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. Anchorage, Alaska 99508 Date: Si~(JO~ RECE'VED FEB 1 8 2003 A1a8ka œ & Ga& Cons. CoIßIni!ekm And1or196 12109102 Schlumberger NO. 2586 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ----. Well Job # Log Description Color Date BlueJine Sepia Prints CD 11/29/02 1 10/26/02 1 10/17/02 1 11/21/02 1 11/19/02 1 07/29/02 1 10/23/02 1 10/28/02 1 10/30/06 1 10/25/02 1 10/30/02 1 p.S.4-01 I ÎO-OyrJ. D.S. 1-20 r: d. ~ )4 to A-12 1 <g"n. IJ, H-14A .l9? -fý,~ PSI-06 ~CB-O- PSI-09 :::7IOC)- /dL NK-42 } ~-I 0'6 R-14 I ~-Dd d- D.S. 7-21 I ,.~- () ] C) D.S. 2-30B c7\ 00- I;:;' &J D.S.9-39 I q 1-0) ~ PRODUCTION PROFILE LDL PRODUCTION PROFILE LDL SBHP SURVEY BASE TEMP/JEWELRY LOG PROD PROFILE/DEFT LDL LDL LDL INJECTION PROFILE .~ PLEASE ACKNOWLEDGE RECEIPT BY SlqNI~ÂAtiQ. .REIURNINS;; ONE COpy EACH TO: BP Exploration (Alaska) Inc. R F ~ ~ , \¡ t. U Petrotectnical Data Center LR2-1 ~ ==. =- 900 E. Benson Blvd. Anchorage, Alaska 99508 t\ r. f'\ (',e) DEC 1 V LUIJ'- Schfumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth \'-.p Recóf~ ¿t ~~~ , Date Delivered: .-"1 n .....",,, ,,--. ,I' r'''''mm'I~Q'\Q'ì ÞJaaka UiÌ ~ l,;;;~ \.,ori~. ,-"",\ , II Q-~ , AJ¡J¡Cfbgt; Schlumberger 12/09/02 NO. 2588 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth A-11 PSI-06 PSI-01 .NK-27 D.S. 9-34A .Z-32B L 1 -NK-38 D.S.1-32 C-35A P1-08 D.S. 1-26A D.S. 9-28A Well I r'Õ 1- O?}9, dCB-Oil=1 aBi- jI-i.~ I ~'.::{. - Od ) J/~f?=~3~ I 4-/íO I !o-/d.í t ~ -dOO I ,j-Oq r I ¡'i-OJd- I 4.=3 -Dlj (~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job# Color Date Blueline Sepia Prints CD 11/16/02 1 11/11/02 1 11/19/02 1 11/29/02 1 11/11/02 1 11/11/02 1 11/27/02 1 11/07/02 1 11/25/02 1 11/07/02 1 11/08/02 1 11/10/02 1 '"--" Log Description INJECTION PROFILE INJECTION PROFILE SBHP PROD PROFILEIDEFT LDL MEM PSP PROD PROFILE/DEFT STATIC PRESSURE SURVEY GRAVEL PACK W/RST-C PSP LDL SBHP SURVEY PRODUCTION PROFILE PRODUCTION LOG --...-- 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: r~rt~rt\!I:;.D f\ T':: ¡V C.. -~ 7.o:=-~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATIN: Beth R~~~ f"t. "'Ar,!) ncl"' 11..) /U\:L I.JI-V " -. ¡- -, i~ 'n~ rr:mm¡ .I~n AJaska u¡.¡ & \,;85 ¡....G ,w. "',,;\ .. ,QQIY l\nchorage ) ) 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- Stratigraphie- SeNiee_X 1433' FNL,4436'FEL,Sec. 15,T11N, R15E, UM At top of productive interval 1357' FNL,4501'FEL,Sec.09,T11N, R15E, UM At effective depth 1304' FNL,4555'FEL,Sec.09,T11N, R15E, UM At total depth 1289' FNL,4573'FEL,Sec.09,T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 707968, 5966148) (asp's 702467, 5971355) (asp's 702411, 5971407) (asp's 702393, 5971422) 12145 feet 8598 feet Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 51 feet 7. Unnor Property name Prudhoe Bay Unit 8. Well number PSI-06 9. Permit number / approval number 202-079 10. API number 50-029-23082-00 11. Field / Pool Prudhoe Bay Oil Pool Plugs (measured) Tagged TD @ 12050' (11/19/2002). Effective depth: measured 12050 feet Junk (measured) Fish - Lost PKR W/ Tubing @ 11479' true vertical 8506 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 260 sx Arctic Set (aprox) 147' 147' Surface 6366' 13-3/8" 1376 sx Arctic Set III 6401' 4607' Lite, 606 sx Class 'G' Intermediate 11673' 9-5/8" 421 sx Class 'G' 11705' 8174' Liner 601' 7" 159 sx Class 'G' 11543' - 12144' 8019' - 8597' Perforation depth: measured Open Perfs 11770'-11830',11868'-11888', 11908'-11924', 11959'-11979', 11984'-12004', Open Perfs (continued) 12012'-12058' true vertical Open Perfs 8236'-8294', 8330'-8349', 8369'-8384', 8418'-8437', 8442'-8461', 8469'-8513' Tubing (size, grade, and measured depth) 7-5/8" 29.7# L-80 @ 2188' MD. 7-5/8" x 7" XO @ 2188'. 7" x 7-5/8" XO @ 2191'. 7-5/8" 29.7# L-80 @ 11313' MD. 7-5/8" x 7" XO @ 11313'. 7" 26# L-80 @ 11427'. 7" 26# L-80 tubing from 11479' to 11550' MD. R E C E' V ED Packers & sssv (type &. measured depth) 7" X 9-5/8" Baker SABL-3 Packer @ 11388' MD & @ 11510' MD. 7" Camco DB Nipple @ 2190'. 13. Stimulation or cement squeeze summary utC 0 4 2002 Intervals treated (measured) (see attached) . sio£l Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Carom\s R . D . A P d. I.. D l\nchorage 14. epresentatlve al v veraqe ro uctlon or nlectlon ata Oil-Bbl Gas-Mef Water-Bbl 37275 Prior to well operation 11/12/2002 Subsequent to operation 11/23/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A?!_. ~ J~ TItle: Technical Assis'anl DeWayne:S~~, ' CasinQ Pressure TubinQ Pressure 2666 2666 32629 16. Status of well classification as: Form 10-404 Rev 06/15/88 . , , ,\ " Suspended - Service WATER INJECTION RBDMS 8Fl Date December 04. 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE ~ 'J. \..o..w--' r" :ì 10/07/2002 10/14/2002 10/19/2002 1 0/21/2002 11/11/2002 11/13/2002 11/17/2002 11/19/2002 11/20/2002 12/01/2002 12/02/2002 12/03/2002 ') ) PSI-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS NEW WELL POST: AC-FLUID LEVEL INJECTIVITY TEST: AC-FLUID LEVEL NEW WELL POST: AC-MITIA NEW WELL POST: AC-MONITOR NEW WELL POST: INJECTION PROFILE NEW WELL POST: LOAD WELL TO SECURE PUT ON WATER INJECTION NEW WELL POST: PERFORATING; STATIC BOTTOM HOLE PRESSURE SURVEY NEW WELL POST: PERFORATING NEW WELL POST: SSSV C/O OR STROKE NEW WELL POST: SSSV C/O OR STROKE TESTEVENT --- INJ PRESS, PSI: 0 TYPE: PW VOL: 46,701 EVENT SUMMARY 10/07/02 T/I/0=VAC/0/120 TBG FL @ 7801 (for DSO). 10/14/02 T/I/O= SI/O/O IA FL NEAR SURFACE. (PRE MIT-IA). 10/19/02 MITIA PASSED TO 2240 PSI. (WITNESSED BY CHUCK SCHEVE OF THE AOGCC). PRESSURED UP ON IA FROM AN INITIAL 100 PSI TO 2260 PSI. STARTED TEST. AFTER 15 MINUTES THE IA PRESSURE WAS AT 2240 PSI AND AFTER 30 MINUTES THE PRESSURE WAS AT 2240 PSI. 10/21/02 T/I/O= 925/510/140 (OA Project) 11/11/02 LOGGED INJECTION PROFILE UP/DOWN PASSES FROM 118501-12025' AT 40, 80 AND 120 FPM WITH STOP COUNTS SPINNER DEPTH AT 12025',120101, 119831 AND 11940'. SPLITS: 119591-119791630/0,119841-12004127%,120121- 12057' 1 0%. PERFORMED RST W A TERFLOW STATIONS @ 11950" 11940' & 11930' AND FOUND ZERO UPFLOW (CHANNELING) BEHIND LINER. SHUT IN WELL AND LOGGED TEMPERATURE FROM 93501-TD 12051' AT 100 FPM PUH LOGGED TEMPERATURE DOWN 40 FPM FROM 116501-TD120511 AFTER WELL SHUT IN FOR .75 HRS AND AT 1.75 HRS, 2.75 HRS AND 3.75 HRS. OVERLAYED FOUR TEMPERATURE PASSES FOR WARMBACK SURVEY, NOTICED ZERO INJECTION ABOVE PERFORATIONS. «< TD 12051 »> «< DSO RETURN TO INJ »> 11/13/02 FREEZE PROTECT TUBING W/ 140 BBLS 60/40 METH AND FLOWLINE W/ 12 BBLS 60/40 Page 1 ') ) PSI-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/17/02 PUT ON WATER INJECTION. 11/19/02 11/20/02 RU FOR SBHPS. PBMS-A NOT CHARACTERIZED FOR PRESSURES BELOW 250 PSI. PRE-LUBRICATOR TEST LACKING VALIDITY AND NOT PRESENTED DUE TO ZERO WHP. SAT DOWN ON LOST PBR AT 114791 - ABLE TO WORK THROUGH, TAG TD 120501. TIE IN WITH SLB PEX QUAD COMBO LOG DATED21-JUNE-2002. WELL SHUT IN ON 13-MAY-2002. STATIC BHP&T @ 119601 MD, 83681 SSTVD (103.3 DEGF, 3338.9 PSI) STATIC BHP&T @ 120101 MD, 84181 SSTVD (75.1 DEGF, 3361.4 PSI) POOH, POST CHECK LUBRICATOR NOT PRESENTED DUE TO ZERO WHP. RU TO PERFORATE WITH HSD PERF GUNS - 3-3/8" PJ 3406 HMX - 6SPF - 60 DEG RANDOM. API SPECS WHEN SHOT IN 4.5" CASING: EHD = 0.45" & PEN = 38.6". PERFORATION INTERVAL: 119081-119241. STAND BACK UNIT FOR THE NIGHT. WILL BE BACK IN MORNING TO FINISH GUN RUNS. *** SHUT IN*** RU TO PERFORATE WITH HSD PERF GUNS - 3-3/8" PJ 3406 HMX - 6SPF - 60 DEG RANDOM. API SPECS WHEN SHOT IN 4.5" CASING: EHD = 0.45" & PEN = 38.6". DEPTHS REFERENCED TO SLB PEX QUAD COMBO LOG DATED 21- JUNE-2002. PERFORATION INTERVALS: 118681_118881, 117701-11830' + (DAY ONE PERFS: 119081-119241). PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 12/01/02 SET 7" A-1 6" SSSV W/ DB-6 LOCK @ 2161' SLM. (SERIAL #=(HTS-642), TL=49", SIP=2500 PSI) BLEED OFF 300 PSI FOR CLOSURE TEST. 12/02/02 COMPLETE CLOSURE TEST AFTER SETTING 7" A-I INJECTION SSSV (PASS) «< RETURNED WELL FOR INJECTION »> 12/03/02 TESTEVENT ---INJECTION PRESSURE, PSI: 0 TYPE: PW VOL: 46,701 BWPD. BBLS 4 155 159 Fluids Pumped DIESEL FOR SURFACE PRESSURE TEST (5 TESTS) 60/40 METHANOL WATER TOTAL Page 2 ) ) PSI-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 11/19 -20/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING 3-3/8" 3406-PJ, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 117701 - 11830' 118681 - 118881 119081 - 119241 Page 3 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 10/17/02, Put on Injection CEMENTING RECORD 260 sx Arctic Set (Approx.) 1376 sx AS III Lite, 606 sx 'G' Top Job: 243 sx AS III Lite 12-1/411 421 sx Class IG1 8-1/2" 159 sx Class IGI TUBING RECORD SIZE DEPTH SET (MD) 7-5/8,29.7#, L-80 x 7",26#, L-80 114271 711,26#, L-80 (Fish) 115501 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 138 Bbls of Diesel Acid Treatment: See Attached Well Service Reports 07/26/02 & 07/27/02 Freeze Protected with 136 Bbls of MeOH 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned Ia 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 'r.:r--', ~~~ -"~'tT 3848' NSL, 4436' WEL, SEC. 15, T11N, R15E, UM ¡tOCA ~~ At top of productive interval ~ ~' f.~.... .. 3923' NSL, 4501' WEL, SEC. 09, T11 N, R15E, UM ~ <: ... '" . .. ,) At total depth ~ "', '. . ., j 3992' NSL, 4573' WEL, SEC. 09, T11 N, R15E, UM !:~,.;\. . ":.' .,,:!:.~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 50.8' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/3/2002 6/20/2002 7/18/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 12145 8598 FT 12101 8555 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ACal, RES, US IT, AIT / HALS / TLD / CNL / AMS-c 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 34" X 2011 91.51# H-40 Surface 1121 42" 13-3/8" 68# L-80 35' 6401' 1611 9-5/811 1" 47# 26# L-80 L-80 32' 11543' 117051 121441 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/811 Gun Diameter, 6 spf MD TVD 11959' - 11979' 8418' - 8437' 11984' - 12004' 8442' - 8461' 12012' - 12038' 8469' - 8494' 12038' - 12058' 8494' - 8513' 25. MD TVD 11959' - 12058' 27. Date First Production October 2, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-BBl Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF WATER-BBl Classification of Service Well Gas Cap Injection 7. Permit Number 202-079 8. API Number 50- 029-23082-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number PSI-06 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1900' (Approx.) AMOUNT PUllED PACKER SET (MD) 113881 114791 CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ?8. No core samples were taken. OCT 2 3 RBOMS 8Fl c,f Form 10-407 Rev. 07-01-80 nr)~'r'\.~~~ lA' L; r\ i ~J ~ ~\~ l~\ L- OCT 2 1 2002 Alaska on & Gas Gons. COmmtsslon . Anchor.age Submit In Duplicate I . " ) 29. Geologic Markers Marker Name Measured Depth HRZ 11543' LCU 11736' Zone 3 11772' Zone 2C 11813' Zone 2B 11862' 22TS 11907' Zone 2A 11957' Zone 1 B 12004' Base Sadlerochit 12100' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8019' 8204' 8238' 8277' 8324' 8368' 8416' 8461' 8554' Summary of Daily Drilling Reports and Post Rig Work, Surveys, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble 4AW~ tIu~ Title Technical Assistant Date JO'/7'O~ PSI-06 202-079 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 ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor ~\Ñ Chairman DATE: October 19, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Ý .(ô~ BPX P.I. Supervisor {(J}- \f:::( ~,..o/' PSI Pad , (:)PSI..06 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well PSI-06 Type Inj. S T.V.D. 7872 Tubing 900 900 900 900 Interval I P.T.D. 202-079 Type test P Test psi 1968 Casing 100 2260 2240 2240 P/F f Notes: New well Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: 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) Tesfs Details I traveled to BPXs PSI Pad and witnessed the initial MIT on well PSI-06. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.ls performed: 1 Attachments: Number of Failures: 2 Total Time during tests: 1 hour cc: M IT report form 5/12/00 L.G. MIT PBU PSI-06 10-19-02 CS.xls 10/25/2002 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well PSI-06 PSI-06 PSI-06 PSI-06 PSI-06 PSI-06 PSI-06 aO~-()ïq ,/ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Color Date Blueline Sepia Prints CD 06/21/02 1 06/21/02 1 06/21/02 1 06/21/02 1 06/21/02 1 06/21/02 1 06/21/02 1 Job# Log Description 22347 OH EDIT HRLAlPEXlBHC 22347 PEX-HRLA 22347 PEX-NEUTRON DENSITY POROSITY 22347 PEX-QUAD COMBO 22347 PEX-SSTVD 22347 PEX-HCAL 22347 BHC RECEIVED SEP 1 3 2002 Alaska O~ & Gas Cons. Commission Anchorage 09/06/02 NO. 2396 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 Recei~ 6- 009.f" J l Fwd: PSI-06, 10-407, Pennit #202-079 J ') ,) Subject: [Fwd: PSI-06, 10-407, Permit #202-079] I)ate: Thu, 22 Aug 2002 09:45 :27 -0800 From: Steve McMains <steve - mcmains@admin.state.ak. us> To: Lisa Weepie <lisa_weepie@admin.state.ak.us> COULD YOU HANDLE THIS? -........'".........'''''.'''......''...........'''...''..''.......'............'''...'''"""''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''0''''''''''''.."."......,,,.........,.,,.,,...,,....,,..,,........,..............,.., """,,,,,,,,,.......................,,,.....,,..,,.......,,,........,..,,,.,,,,..,...m.,,,,,, "................."',,,.,,,........... Subject: PSI-06, 10-407, Permit #202-079 Date: Thu, 22 Aug 2002 12:34:01 -0500 From: "Hubble, Terrie L" <HubbleTL@BP.com> To: "McMains, Steve (AOGCC) (E-mail)..<Steve_McMains@admin.state.ak.us> h.i ,:;;teve, I have just learned that I mistakenly listed in field #22 for Logs Run, that a Dipole Sonic was run. Would you please cross that out. This log was not successfully run. Than ks ! Terrie Hubble GPB Drilling & Wells 564-4628, MB7-5, Cube 718 Steve McMains <steve mcmains@admin.state.ak.us> 1 of 1 8/22/20029:51 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned II 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 i.. ~"êÓ~;PL8iÕÑ1. rr;::;-"""i~~."~'''~:T 38481 NSL, 44361 WEL, SEC. 15, T11 N, R15E, UM t ¡).A. ."E , t lOCA I .i?~.j;} l At top of produc~ive interval ~1,~, /~ ~t>zt VEG1f.¡ID ¡ 3923 NSL,4501 WEL, SEC. 09, T11N, R15E, UM ~ V,;:r,'I::!q) \ ~S. "'.r1/). d J:.'. . 3~~~~~k~~~~731 WEL, SEC. 09, T11 N, R15E, UM t::~:I:~'~::J ì.~!;~~~~;} 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 50.8' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/3/2002 6/20/2002 7/18/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12145 8598 FT 12101 8555 FT II Yes 0 No 22. Type Electric or Other Logs Run ./ ~ MWD, GR, ACal, RES, USIT, AIT I HALS 1 TLD 1 CNL 1 AMS-c, DigPle"'Sonic .?3.. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 34" X 20" 91.51 # H-40 Surface 1121 42" 13-3/8" 68# L-80 351 64011 16" Classification of Service Well Gas Cap Injection 7. Permit Number 202-079 8. API Number 50- 029-23082-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number PSI-06 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1900' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 1376 sx AS III Lite, 606 sx IG1 Top Job: 243 sx AS III Lite 12-1/4" 421 sx Class IGI 8-112" 159 sx Class 'GI TUBING RECORD SIZE DEPTH SET (MD) 7-5/8,29.7#, L-BO x 7",26#, L-BO 11427' 7",26#, L-80 (Fish) 11550' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 138 Bbls of Diesel Acid Treatment: See Attached Well Service Reports 07/26/02 & 07/27102 Freeze Protected with 136 Bbls of MeOH 9-5/8" 7" L-80 L-80 321 11543' 11705' 12144' 47# 26# 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 11959' - 11979' 8418' - 8437' 119841 - 12004' 8442' - 8461' 12012' - 12038' 8469' - 8494' 12038' - 12058' 8494' - 8513' 25. MD TVD 119591 - 120581 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBl TEST PERIOD GAs-McF WATER-BBl Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBl GAs-McF WATER-BBl AMOUNT PULLED PACKER SET (MD) 11388' 11479' CHOKE SIZE GAS-Oil RATIO OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. ~qDMS BFL Form 10-407 Rev. 07-01-80 0 r) ~~ 1 i~ J i\ L . j ~. \ ~ tJ ~ i '\, J~ '/" ! -,' 0;;. ;;S'é GÝ SEP 2 3 2002 Submit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. HRZ 11543' 80191 LCU 11736' 8204' Zone 3 11772' 8238' Zone 2C 11813' 8277' Zone 2B 11862' 8324' 22TS 11907' 8368' Zone 2A 11957' 8416' Zone 1 B 12004' 8461' Base Sadlerochit 12100' 8554' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble /"fiAA.i...t.l ~ ~ Title Technical Assistant PSI-06 202-079 Well Number Permit No. / Approval No. Date œ~lS.O~ Prepared By Name/Number: Terrie Hubb/e, 564-4628 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 i: i: Legal Name: PSI-06 Common Name: PSI-06 Test Date 6/11/2002 6/20/2002 LOT FIT Test Type BPEXPLORATI0N Leak..O.ff..TestSlJrnmary Test Depth (TMD) (ft) 11 705.0 (ft) Test Depth {TV D) (ft) 8,175.0 (ft) AMW (ppg) 9.00 (ppg) Surface Pressure (psi) 425 (psi) Le¡:¡kOffPressure (BHP) (psi) 4,247 (psi) Page..1.....of1 EMW (ppg) 10.00 (ppg) "-- ~ Printed: 7/10/2002 12:19:04 PM ) ) BP EXPLORATION OperationsSuml11ary Report Page 1 Of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From '- To Hours Task Code NPT Phase Descri ptionof Operations 4/14/2002 18:00 - 00:00 6.00 MOB P PRE BREAK APART AND MOVE PIPE SHEDS, PUMPS TO TEXACO PAD - PULL BACK AND TURN MOTOR COMPLEX AROUND ON S-PAD 4/15/2002 00:00 - 03:30 3.50 MOB P PRE MOVE PUMPS, PITS AND PIPE SHEDS UNITS AND STAGE AT TEXACO PAD - REMOVE BOP FROM SUB 03:30 - 07:30 4.00 MOB P PRE MOVE SUB OFF WELL AND TURN AROUND, MOVE SUB TO WEST END OF S-PAD 07:30 - 11 :00 3.50 MOB P PRE MOVE MOTOR COMPLEX BY SUB - HOOK UP ELECTRICAL LINES FOR POWER 11 :00 - 20:00 9.00 MOB P PRE REMOVE BLOCK FROM TOP DRIVE, LAY DOWN TOP DRIVE ON TO RIG FLOOR, REMOVE TOP DRIVE FROM RIG FLOOR WITH PEAK 4600 CRANE 20:00 - 00:00 4.00 MOB P PRE PREPARE DERRICK AND RIG FLOOR TO LAY OVER DERRICK - MOVE TWO COMPLEXES FROM TEXACO PAD TO PRUDHOE - DEPART TEXACO PAD 2000 HRS 4/16/2002 00:00 - 10:00 10.00 MOB P PRE BRIDLE UP DERRICK TO BLOCK - SECURE WEIGHT BUCKETS - OPEN DOORS 10:00 - 12:00 2.00 MOB P PRE SAFETY MEETING WITH DRILL CREW - LOWER DERRICK ONTO DERRICK STAND - MAX WT 290k 12:00 - 00:00 12.00 MOB P PRE TIE UP LINES IN DERRICK - REMOVE DERRICK BOARD- RAISE AND PIN 'C' SECTION - UNBRIDLE DERRICK - SET CROWN ONTO TRUCK - UNPIN DERRICK LEGS AND SET SET ONTO TRUCK WITH 4600 CRANE - UNHOOK POWER FROM MOTOR COMPLEX - PREPARE TO MOVE DERRICK AND MOTOR COMPLEX TO PRUDHOE 4/17/2002 00:00 - 12:00 12.00 MOB P PRE FINISH MOVING DERRICK & MOTOR COMPLEX TO EAST DOCK - CLOSE DERRICK DOORS ON SUB - CHAIN DOWN SKATE SHOOT - CHAIN UP FLOW LINE 12:00 - 00:00 12.00 MOB P PRE MOVE MISCELLANOUS RIG EQUIPMENT TO EAST DOCK - HOOK UP TO SUB, TURN SUB AROUND ON S-PAD - DEPART S-PAD FOR EAST DOCK AT 1600 HRS - S-PAD TO EAST DOCK, 50 MILES 4/18/2002 00:00 - 12:00 12.00 MOB P PRE FINISHING MOVING SUB MODULE FOR MILNE POINT S-PAD TO EAST DOCT AT PRUDHOE, 50 MILES - MOVE BACK WHEELS OUT - LAY HERCULlTE & MATTING BOARD ON PSI #6 - 12:00 - 00:00 12.00 MOB P PRE HOOK UP AND MOVE SATILLlTE CAMP, WELDING SHOP, TRUCK SHOP, AND GENERATOR SET FROM S-PAD TO EAST DOCK, SET AND HOOK UP - MOVE SUB OVER PSI #6 WIND BLOWING 20-30 MPH WITH DRIFTING SNOW, -50 CHILL FACTORS PHONE SYSTEM AT EAST DOCK TO BE INSTALLED AM 4-19-02 4/19/2002 00:00 - 12:00 12.00 MOB P PRE PIN DERRICK TO SUB, LOWER 'C' SECTION & PIN, INSTALL & PIN DERRICK BOARD, MOVE PIT COMPLEX INTO POSITION, MOVE MOTOR COMPLEX INTO POSTION AND HOOK UP ELECTRICAL LINES 12:00 - 00:00 12.00 MOB P PRE STRING UP BRIDGE CRANE LINE IN SUB, SPOOL DRILL LINE ONTO DRUM, BURM UP AROUND RIG, PREPARE TO RAISE DERRICK 4/20/2002 00:00 - 00:00 24.00 MOB P PRE NIPPLE UP 13 5/8 5000# HYDRILL BOP STACK AFTER I YEARLY INSPECTION - SET BACK BOP STACK IN SUB- I Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION QperåtionsSummary. Rep.ort. Page 2 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From.- To Hours Task Code NPT Phase Description of Operations 4/20/2002 00:00 - 00:00 24.00 MOB P PRE STRING UP TUGGER LINES IN DERRICK - REPAIR MULE LINE ON DERRICK BOARD - NIPPLE UP 20" DIVERTER SPOOL TO FMC SO X 211/4" 2000# FLANGE - RAISE DERRICK AND PIN, CLOSE DOORS 4/21/2002 00:00 - 00:00 24.00 MOB P PRE UN-BRIDLE DERRICK - INSTALL MUD & CEMENT STAND PIPE - REMOVE ALL ROPES FROM DERRICK- RIG UP GEOLOGRAPH LINE -INSTALL FLOW LINE - SET TOP DRIVE ON RIG FLOOR - HANG & PIN PIPE SHOOT 4/22/2002 00:00 - 00:00 24.00 MOB P PRE Set matting boards and spot pipe shed, pits and motor complex -Spot back section of pipe shed and pumps - Pick up top drive and hang on block - Hook up service loop to top drive - Hook up service lines to each complex 4/23/2002 00:00 - 12:00 12.00 MOB P PRE HOOK UP BLOWER HOSE. MADE FINAL ADJUSTMENT ON TOP DRIVE. INSTALLED IBOPS. 12:00 - 00:00 12.00 MOB P PRE WORK ON GLYCOL LINES TO RADIATOR. INSTALL BLANK FLANGE ON CHOKE LINE. 4/24/2002 00:00 - 12:00 12.00 MOB P PRE ADJUST TORQUE TUBE RAILS. WORK ON MAN RIDERS. FIX LIGHT IN DERRICK. PUT CHARGE PUMPS BACK TOGETHER. 12:00 - 00:00 12.00 MOB P PRE REMOVE HYDRAULIC PUMPS FROM SUB. START INSTALLING NEW HYDDRAULlC PUMPS. WELDER WORKING ON MAN RIDER ON RIG FLOOR. CONTINUE CLEANING RIG. 4/25f2002 00:00 - 12:00 12.00 MOB P PRE WORK ON MANRIDER BRACKETS. INSTALL PULSATION DAMPNER ON #1 MUD PUMP. SERVICE DRAWWORKS. CONTINUE WORKING ON HYDRUALlC PUMPS. 12:00 - 00:00 12.00 MOB P PRE FINISH WORKING ON # 1 PUMP. ASSEMBLE #2 PUMP AND INSTALL ALL SUCTION LINES. CONTINUE WORKING ON MAN RIDER TUGGER. WORKING ON LIGHTS AND MULE LINE IN DERRICK. 4/26/2002 00:00 - 12:00 12.00 MOB P PRE WORK ON MAN RIDER AND TUGGER STANDS. PUT #2 PUMP TOGETHER. HOOK UP KOOMY LINES TO BOPS. HOOK UP IRON ROUGHNECK. TORQUE NUTS AND STUDS ON PULSATION DAMPENER. HOOK UP SUCTION LINES TO MUD PUMPS. WORK ON DERRICK LIGHTS. 12:00 - 00:00 12.00 MOB P PRE CONTINUE TO WORK ON HYDRAULIC PUMPS AND MAN RIDER STANDS. WORK ON STEAM TABLE AND SUPER SUCK LINES IN PITS. 4/27/2002 00:00 - 12:00 12.00 MOB P PRE WELDERS WORKING ON MAN RIDER AND HYDRAULIC PUMPS. WORKING ON LINES IN PITS. 12:00 - 00:00 12.00 MOB P PRE CONTINUE WORKING ON MAN RIDER AND HYDRAULIC PUMPS. 4/28/2002 00:00 - 12:00 12.00 MOB P PRE CONTINUED WORKING ON MAN RIDER AND HYDRAULIC UNIT. PLUMB IN GLYCOL TO RADIATOR. 12:00 - 00:00 12.00 MOB P PRE CONTINUED WORKING ON MAN RIDER AND GLYCOL LINES TO RADIATOR. 4/29/2002 00:00 - 00:00 24.00 MOB P PRE BLOW DOWN RIG AND CAMP. RIGGED UP LIGHT PLANT TO AVIATION LIGHT. RIG COLD STACKED. 5/31/2002 00:00 - 00:00 24.00 MOB P PRE Hold Pre-Job Safety Meetings For All Tasks - Work on Equalizers In Mud Pit System - Grease And Service Choke Manifold - Rig Up To Test Choke Manifold - Test Choke I Manifold At 250 Psi. Low Pressure And 5,000 Psi. High Pressure Hold Each Test For 5 Minute's As Required - Repair Printed: 7/10/2002 12:19:13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BPEXPLORATION Operations Summary Report Page 3 of 19 PS 1-06 PS 1-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/31/2002 00:00 - 00:00 24.00 MOB P PRE 4 Flange Leaks, Hook Up Electric Pressure Sensor, And Repair Hydraulic Transducer To Choke Control Panel - Function Test (2) Manual And (1) Hydraulic Operated Chokes - Continue To Install Man Riders And Function Test - Load Pipe Shed With 5" Drill Pipe - Test High Pressure Mud Line Back To Emsco Mud Pumps - Repair (1) Demeo Valve And Hook Up Electric Pump Pressure Sensor On Mud Manifold - Hook Up Purge Air To Drillers Console - Pump Water Thru Mud Cleaners, Mud Hoppers - Inventory Spill Van - Prep Centrifudge For Removal - Continue To Pick Up Rig And Prepare For Spud. 6/1/2002 00:00 - 00:00 24.00 MOB PRE Nipple Up 16" Hydraulic Knife Valve And Diverter Line - Install 21 1/4" Riser And Flow Line - Hook Up Turnbuckles And Fill Up Lines - Remove Alpha Lavel Centrifuge And Change Out With Swaco Centrifuge - Work On Plumbing, Electrical, And Solids Discharge Lines - Remove Tioga Heater From Top Of Motor Complex - Install Uni-Bolt Flange On Choke Line - Install Guards On Man Rider Winches - MPI (2) Winch Pedastel's And Load Test To Obtain Certification's *NOTE* Manrider On ODS Failed To Pass Test Due To Hydraulic Adjustments The Plan Is To Adjust In The A.M. - Finished Organizing Test Pump Room And Hydraulic Pump Room - Empty Mud Pits Of Water And Take On 600 Barrels Spud Mud - Install Shaker Screens On Solids Control Equipment - Change 6" Liners In Emsco Mud Pumps - Continue To Pick Up Rig And Organize. 6/2/2002 00:00 - 06:00 6.00 RIGU P PRE Finish Installing 6" Pump Liners - Organize And Arrange Rig Parts - Test BOP And Evacuation Alarms - Install Line Guide At Derrick Board Level For Man Riders - Work On EPOCH Equipment. Nabors Rig 27E Accepted For Well Work On PSI-06 On 06-02-2002 At 06:00 Hours 06:00 - 18:00 12.00 BOPSUR P SURF Continue To Work On Centrifuge Installation - Inspect And Certify Over Head Lifting Equipment With Johansen & Sons Service - Preform BP Rig Condition / Environmental Audit With BP HSE Representative Jeff Kilfoyle - Work On Draworks Brake Cooling Pump Hang Wind Sock On Pipe Shed. 18:00 - 21 :00 3.00 BOPSURP SURF Hold Pre-Job Safety Meeting - Hang Traveling Blocks Slip And Cut 144 Feet Of 1 3/8" Drilling Line - Slip Excess Back To Drilling Line Spool. 21 :00 - 00:00 3.00 BOPSURP SURF Lock Out Equipment And Preform Third Party Mast Inspection In Personal Basket - Bring Drilling Tools To Rig Floor For Top Hole Section And Remove Welding Equipment - Prepare To Pick Up 5" Drill Pipe And BHA 6/3/2002 00:00 - 05:30 5.50 BOPSUR P SURF Prepare Rig Floor And Pick Up 5" Drill Pipe From Pipe Shed & Stand Back In Mast For Top Hole Section - Drift Pipe As Required 05:30 - 06:00 0.50 BOPSUiP SURF Preform Diverter Function Test - Test Accumulator & Gas Alarms - Test Witnessed By AOGCC Representive John Crisp 06:00 - 11 :30 5.50 BOPSUR P SURF Continue To Pick Up 5" Drill Pipe And 5" HWDP With Jars From Pipe Shed And Stand Back In Mast 11 :30 - 13:00 1.50 BOPSURP SURF Install Flow Show Paddle In Flow Line - Clear Floor For BHA And Bring !6" Tools To Rig Floor - Rig Up Tongs And Floor Printed: 7/10/2002 12:19:13 PM ) ) BP EXPLORATION Operations Summary Report Page 4 of19 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/3/2002 11 :30 - 13:00 1.50 BOPSUR P SURF Equipment 13:00 - 18:00 5.00 BOPSURP SURF Pick Up 8" Flex Drill Collars And 8 " Steel Drill Collars And Stand Back In Mast - Make Up BHA NO.1 - Orient Motor & MWD - Initialize MWD Tool 18:00 - 19:00 1.00 BOPSUR N RREP SURF Hold Pre-Spud Meeting With BP Drilling Forman And All Personal Regarding Drilling Operation - Attempt To Circulate - Stand Back Double Of HWDP And Jars For Top Drive Inspection - Trouble Shoot Top Drive IBOP Valve Hoses Crossed. 19:00 - 19:30 0.50 BOPSUR P SURF Fill Conductor Pipe With Fresh Water And Check Surface Equipment For Leaks 19:30 - 21 :00 1.50 BOPSUR P SURF Spud Well At 19:30 Hours - Swap To Spud Mud After Conductor Cleaned Out Drill Ahead From 112' To 207' 21 :00 - 21 :30 0.50 BOPSUR N FLUD SURF Flow Line Plugging Up Work Pipe And Jet Same - Work To Get Circulation Rate Back To 900 GPM 21 :30 - 23:00 1.50 BOPSUR P SURF Drill Ahead From 207' To 300' (Kick Off Point) 23:00 - 00:00 1.00 BOPSUR P SURF POH wI HWDP & Jars RIH With Flex Drill Collars And Steel Drill Collars - Make Up Drilling Jars And Break Circulation (20 Foot Of Fill) 6/4/2002 00:00 - 00:30 0.50 BOPSUR P SURF Finish RIH w/ Drill Collars - Tag 20' Fill - Establish Circulation And Wash To Bottom At 300' 00:30 - 01 :30 1.00 BOPSUR P SURF Directional Drill Ahead From Kick Off Point At 300' To 461' 01 :30 - 02:30 1.00 BOPSUR P SURF Stand Back 5" HWDP & Jars - Pick Up Last Stand Of Steel Drill Collars And Run Back To Bottom 10' Fill- Establish Circulation And Wash To Bottom 02:30 - 00:00 21.50 BOPSURP SURF Directional Drill Ahead From 461' To 2,333' 6/5/2002 00:00 - 06:00 6.00 BOPSUR P SURF Directional Drill Ahead From 2,333' To 2,893' - Weight On Bit 20K To 45K With Pump Rate At 215 Strokes Or 915 GPM While Rotating And 750 GPM While Sliding - Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2500 Psi. - Top Drive RPM At 80 To 100 - Off Bottom Torque At 7K & On Bottom Torque At 10K - String Rotating Weight At 130K - With Pump On Drag Up At 150K And Drag Down At 11 OK 06:00 - 07:30 1.50 BOPSUR P SURF Pump Up Survey - Rotate And Circulate Sweep Around 07:30 - 10:00 2.50 BOPSUR P SURF POOH - Pulled 50K Over Normal Upward Drag At 2,770' Back Ream To 2,051' - Pull To HWDP With No Problems 10:00 - 10:30 0.50 BOPSUR P SURF Monitor Well At HWDP - POH To Drill Collars 10:30 - 11 :00 0.50 BOPSUR P SURF Service Can-Rig Top Drive, Crown Sheaves, And Traveling Blocks 11 :00 - 13:00 2.00 BOPSUR P SURF RIH Tight Spot At 614' - Wash Thru Area - Continue To RIH To 2,800' With No Problems - Establish Circulation And Wash Last Stand To Bottom. 12 ft. of Fill. 13:00 - 18:00 5.00 BOPSURP SURF Directional Drill Ahead From 2,893' To 3,362' - Weight On Bit 1 OK To 45K With Pump Rate At 215 Strokes Or 915 GPM - Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2450 Psi. - Top Drive RPM At 80 To 125 - Off Bottom Torque At 7K & On Bottom Torque At 15K - String Rotating Weight At 135K - With Pump On Drag Up At 160K And Drag Down At 115K 18:00 - 00:00 6.00 BOPSU1N RREP SURF Stand Back 2 Stands 5" Drill Pipe - Work Drill String And Repair Wash Out In 5" Mud Line Union - Let Cool For Test 6/6/2002 00:00 - 01 :30 1.50 I DRILL IN RREP SURF Complete Stand Pipe Welding Repair. Allow weld to cool. Printed: 7/10/2002 12: 19: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BPEXPLORATION OperatIons Summary Report PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: ) PageS of 19 Spud Date: 6/3/2002 End: 7/1/2002 Date From;. To Hours Task Code NPT Phase Description of Operations 6/6/2002 01 :30 - 02:00 0.50 DRILL N RREP SURF Test Mud Line to 5000 psi. - OK. 02:00 - 22:00 20.00 DRILL P SURF Directional Drill Ahead from 3361' to 5,422' - Weight On Bit 5K To 60K With Pump Rate At 213 Strokes Or 900 GPM While Rotating And 750 GPM While Sliding - Off Bottom Pump Pressure At 2750 Psi. & On Bottom Pump Pressure At 3000 Psi. - Top Drive RPM At 100 To 125 - Off Bottom Torque At 16K & On Bottom Torque At 20K - String Rotating Weight At 150K - With Pump On Drag Up At 195K And Drag Down At 120K 22:00 - 00:00 2.00 DRILL N RREP SURF Trouble Shoot Can-Rig Top Drive - Wires Burnt Going To GE Traction Motor - Repair & Function Test (OK) 6/7/2002 00:00 - 10:00 10.00 DRILL P SURF Directional Drill Ahead From 5,422' To 6,045' - Weight On Bit 25K To 45K With Pump Rate At 215 Strokes Or 900 GPM - Off Bottom Pump Pressure At 2700 Psi. & On Bottom Pump Pressure At 2900 Psi. - Top Drive RPM At 110 - Off Bottom Torque At 14K & On Bottom Torque At 17K - String Rotating Weight At 150K - With Pump On Drag Up At 200K And Drag Down At 125K 10:00 - 12:00 2.00 DRILL P SURF Torque Climbing - Running Close On And Off Bottom - Sweep Hole At 900 GPM And 125 RPM 12:00 - 17:30 5.50 DRILL P SURF Drill Ahead From 6,045' To 6,416' - Weight On Bit 25K To 45K With Pump Rate At 215 Strokes Or 900 GPM - Off Bottom Pump Pressure At 2900 Psi. & On Bottom Pump Pressure At 3100 Psi. - Top Drive RPM At 110 - Off Bottom Torque At 16K & On Bottom Torque At 15K To 20K - String Rotating Weight At 155K - With Pump On Drag Up At 220K And Drag Down At 120K 17:30 - 19:30 2.00 DRILL P SURF Circulate And Condition Mud While Pumping Sweep - Rotate And Reciprocate Drill String 19:30 - 00:00 4.50 DRILL P SURF Monitor Well (Static) - Hold Pre-Job Safety Meeting - POH With 15 Stands Of 5" Drill Pipe Standing Back In Mast - Pump Dry Job - Continue To POH (Wet Dry Job No Good) With 5" Drill Pipe And HWDP (SLM) Standing Back In Mast (Hole In Good Shape No Problems On Trip Out) 6/8/2002 00:00 - 04:00 4.00 DRILL P SURF Hold Pre-Job Safety Meeting - Stand Back 5" HWDP And Jars - Lay Down 8" Steel Drill Collars - Stand Back Flex Drill Collars - Flush MWD And Mud Motor With Fresh Water Lay Down Same 04:00 - 07:30 3.50 CASE P SURF Hold Pre-Job Safety Meeting - Clear And Clean Rig Floor- Make Dummy Run With Landing Joint And Flutted Hanger- Rig Up To Run Casing 07:30 - 23:00 15.50 CASE P SURF Run 133/8",68#, L-80, BTC Sutface Casing. Check Floats after 4 Jts.- OK. Circulate Annular Volume @ 2000". Tight @ 3633'. Circulate & Work Through Tight Hole to 3695'. Continue RIH. Wash last Jt. to Bottom @ 6401. 23:00 - 00:00 1.00 CASE P SURF Circulate & Condition Mud for Cement Job. Hold PJSM W/ Crew, SWS/Dowell, Peak & Baroid. 6/9/2002 00:00 - 02:00 2.00 CASE P SURF Hold Pre-Job Safety Meeting - Install Cementing Head Adapter Swedge And Dowell Schlumberger Cement Head - Make Up Circulating Lines - Break Circulation And Stage Pump Rate Up To 9 BPM With 570 Psi. 02:00 - 08:30 6.50 CASE P SURF Hold Pre-Job Safety Meeting With All Personal Regarding I Upcoming Cement Operation - Shut Down And Turn Over To I Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION Operations Summary. Report Page.6 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Descriþtion of Operations 6/9/2002 02:00 - 08:30 6.50 CASE P SURF Dowell Schlumberger - Pump 5 BBL. CW100 Spacer - Test Surface Equipment @ 4,000 Psi. - Pump Additional 5 BBL. CW100 Spacer - Drop Bottom Plug - Mix & Pump 70.1 BBLS. 10.2 PPG Mud Push Spacer wI 2 Gallon Red Dye @ 5.6 BPM & 270 PSI. - Batch Up & Mix Arctic Set Lite III 10.7 PPG Lead Cement w/ Yield Of 4.28 ft3/sk - Pump Rate @ 6 BPM w/ 230 PSI. - Total Lead Cement Slurry Pumped 1049.3 BBLS Or 1376 sacks - *NOTE* After Pumping 966 BBLS. Of Lead Slurry Lost Returns For Brief Period When 10.2 PPG. Mud Push Turned The Corner Regained Full Returns And More After Pumping 1017 BBLS (Estimated Total Loss At 33 Barrels)- Follow Up Lead Cement wI Type "G" 15.8 PPG. Tail Cement w/ Yield Of 1.16 ft3/sk - Tail Cement Job Was Pumped @ 5.6 BPM wI 400 Psi. With Full Returns - Total Tail Cement Pumped 125.2 BBLS. Or 605 Sacks - Drop Top Wiper Plug - Schlumberger Pumped 10 BBLS. Behind Plug To Clear Lines Shut Down And Turned Over To Rig For Displacement- Displaced @ 7 BPM wI 9.3 PPG. Spud Mud - Pumped 936 BBLS. To Bump Plug - No Cement Back To Surface - Final Circulation Pressure During Displacement @ 1776 PSI. - Continue To Pressure Up To 2,250 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 08:40 Hours. 08:30 - 11 :30 3.00 CASE P SURF Rig Down Cementing Head And Back Out Adapter Swedge - Clear Rig Floor Of Casing Tools - Change Bales To Short Set - Close Annular Element - Rig Up Casing Tongs And Back Out Pup Joint From Landing Joint Lay Down Same 11 :30 - 14:30 3.00 CASE P SURF Pick Up And Make Up TAM Port Collar Shifting Tool On 10 Foot 5" Drill Pipe Pup Joint - RIH To TAM Port Collar At 1,008' - Make Up Head Pin And Circulating Line 14:30 -15:30 1.00 CASE P SURF Record String Weights - Latch Into Port Collar Profile - Test Combo Tool To 1,000 Psi. - Bleed Pressure To 300 Psi. - Shift Port Collar To The Open Position 15:30 - 17:30 2.00 CASE P SURF Circulate 13 3/8" Annulus Clean For Cement Job - Super Suckers And Vac Trucks Loading Out Returns To Disposal Site. 17:30 - 19:00 1.50 CASE P SURF Hold Pre-Job Safety Meeting With All Personal Regarding Upcoming Cement Operation - Shut Down And Turn Over To Dowell Schlumberger - Pump 10 BBL. Water - Test Surface Equipment @ 2,000 Psi. - Pump Additional 1 0 BBL. Water wI 1 Gallon Red Dye @ 4.0 BPM & 275 PSI. - Batch Up & Mix ArcticSet Lite 11110.7 PPG Lead Cement wI Yield Of 4.28 ft3/sk - Pump Rate @ 4.5 BPM wI 350 PSI. - Total Lead Cement Slurry Pumped 185 BBLS Or 242 Sacks With Full Returns And 30 BBLS. 10.7 PPG ArcticSet Lite III Cement To Surface- Displace Drill Pipe With 20 BBLS. Fresh Water - Shut Down And Shift TAM Port Collar To The Closed Position - Pressure Test Port Collar To 1,000 Psi. - Bleed Pressure To 0 Psi. And Check For Back Flow (NONE Good Test) 19:00 - 19:30 0.50 CASE P SURF Un-Sting From Tam Port Collar - Pressure Up On 5" Drill Pipe I To 2,300 Psi. To Blow Bailin Choke Sub - Circulate Drill Pipe Clean 19:30 - 21:00 1.50 CASE P SURF POH With 5" Drill Pipe Standing Back In Mast & TAM Combo Printed: 7/10/2002 12: 19: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') BP EXPLORATION OperationsSuml11ary Report Page 70f 19 PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From'" To Hours Task Code NPT Phase Description of Operations 6/9/2002 19:30 - 21 :00 1.50 CASE P SURF Tool Assembly 21 :00 - 23:00 2.00 CASE P SURF Pick Up Casing Tongs - Start Pup Joint Into Landing Joint - Close Annular Element And Torque To 4,500 Foot Pounds - Back Out Right Hand ACME Thread Landing Joint And Lay Down - Clean And Clear Rig Floor Of All 13 3/8' Casing Tools 23:00 - 00:00 1.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Pull Master Bushings - Nipple Down 16" Diverter Line And 21 1/4" Diverter System 6/10/2002 00:00 - 02:00 2.00 DRILL P INT1 Nipple Down 16" Diverter Line And 21 1/4" Diverter System And Remove From Cellar 02:00 - 07:00 5.00 DRILL P INT1 Orient And Nipple Up FMC Big Bore Well Head Equipment - Test Metal To Metal Seal At 1,000 Psi. For 10 Min. (Good Test) - Install 13 5/8" 5M BOP Stack And Nipple Up Same 07:00 - 09:30 2.50 DRILL P INT1 Inspect 5" Rams In Lower Gate And Change Top Set Rams To 41/2" X 7" Variables - Tighten Blind Ram Doors - Continue To Nipple Up Riser, Flow Lines And Related Equipment. 09:30 - 17:30 8.00 DRILL P INT1 Install FMC Lower Test Plug And Rig Up To Test Bop - Test Witnessed By AOGCC Inspector Jeff Jones - Test Annular At 250 Psi. Low And 3,500 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 5,000 Psi. High - Test Pit PVT System And H2S And LEL Detectors - Perform Accumulator Test - Remove Test Plug 17:30 - 20:00 2.50 DRILL N RREP INT1 Top Drive IBOP Valve Failed BOP Test - Remove And Replace Valve 20:00 - 23:00 3.00 DRILL P INT1 Install Top Drive Blower Hose - Install Long Wear Ring And Energize - Bring Cuttings Bed Impellers To Rig Floor And SLM - Retest Top Drive IBOP Valve (Test Good) 23:00 - 00:00 1.00 DRILL P INT1 Pick Up BHA NO.2 And RIH 6/11/2002 00:00 - 01 :00 1.00 DRILL P INT1 Upload and test MWD. 01 :00 - 01 :30 0.50 DRILL P INT1 Pick up DCs, HWDP, and jars from derrick. 01 :30 - 04:00 2.50 DRILL P INT1 RIH picking up 5" DP from shed. Run cuttings bed impeller (CBI) every 4 stands. 04:00 - 05:00 1.00 DRILL P INT1 CBU. PJSM. 05:00 - 06:30 1.50 DRILL P INT1 Stripping drill. Pull back to dart valve. 06:30 - 10:00 3.50 DRILL P INT1 Continue to RIH with singles, running CBI every 4 stands. Tag up at 6,305'. 10:00 - 11 :30 1.50 DRILL P INT1 Circulate and condition mud. 11 :30 - 12:00 0.50 DRILL P INT1 RU to test casing. 12:00 - 13:00 1.00 DRILL P INT1 Test casing to 3,500 psi for 30 minutes. 13:00 - 14:00 1.00 DRILL N RREP INT1 Trouble shoot lube oil pump. 14:00 - 15:30 1.50 DRILL P INT1 Drill cement, float equipment, and rat hole to 6,416'. 15:30 - 16:00 0.50 DRILL P INT1 Drill from 6,416' to 6,440'. 16:00 - 16:30 0.50 DRILL P INT1 Displace well to 9.0 ppg LSND mud. 16:30 -18:00 1.50 DRILL P INT1 RU and perform LOT to 13.41 ppg EMW. Obtain base line PWD data. Clean hole ECD=9.39 at 850 gpm, 110 rpm. 18:00 - 00:00 6.00 DRILL P INT1 Drill from 6,440' to 6,819'. AST=1.75, ART=3.17. 6/12/2002 00:00 - 12:00 12.00 DRILL P INT1 DRILL FROM 6819' TO 7987' FLOW CHECK WELL AFTER PENETRATING UGNU FORMATION - WELL STABLE. DRILLING AHEAD AT 7567 HAD 1400 UNITS OF GAS, SHUT DOWN PUMPS & CHECKED FOR FLOW - WELL STABLE- CONTINUE DRILLING. GAS UNITS DISSIPATED TO < 100. Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Hours Task Code NPT Phase 6/12/2002 00:00 - 12:00 12.00 DRILL P INT1 12:00 - 21 :30 9.50 DRILL N RREP INT1 21 :30 - 00:00 2.50 DRILL P 6/13/2002 00:00 - 00:00 24.00 DRILL P 6/14/2002 00:00 - 00:00 24.00 DRILL P 6/15/2002 00:00 - 04:30 4.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 08:30 2.50 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 6/16/2002 08:30 - 10:00 1.50 DRILL P 10:00 - 00:00 14.00 DRILL P 00:00 - 05:00 5.00 DRILL P 05:00 - 07:30 2.50 DRILL P 07:30 - 08:00 0.50 DRILL P 08:00 - 12:00 4.00 DRILL P 12:00 - 14:00 2.00 DRILL P 14:00 - 17:30 3.50 DRILL P 17:30 - 20:00 2.50 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 00:00 2.00 CASE P 00:00 - 00:30 0.50 CASE P 00:30 - 08:00 7.50 CASE P 08:00 - 09:30 1.50 CASE P 09:30 - 15:00 5.50 CASE P 15:00 - 17:00 2.00 CASE P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 6/17/2002 17:00 - 19:30 19:30 - 22:00 22:00 - 23:00 23:00 - 00:00 2.50 CASE P 2.50 CASE P 1.00 CASE P 1.00 CASE P INT1 INT1 INT1 INT1 Page 8 of 19 Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 DRILLED INTERVAL WITH: 850 GPM @ 2350 PSI. TQ = 15K UP = 210K DN = 140K ROT = 170K. AST=1.45, ART=3.83 NOTICED LEAK FROM WEEP HOLE IN FLUID END OF # 2 MUD PUMP. PULLED LINER & WEAR PLATE ON # 2 PUMP. FOUND CRACK IN FLUID END. PROCEED TO PULL & REPLACE FLUID END. WHILE WORKING ON PUMP: POH TO SHOE. HOLE IN EXCELLENT SHAPE - SLICK - NO SWABBING. COMPLETE PUMP REPAIR. PRESSURE TEST PUMP #2 TO 3,500 PSI AND FLOW TEST TOOLS. RIH TO 7,987'. DRILL FROM 7,987' TO 8,234'. ART=0.75, AST=0.5. Drill from 8,234' to 9,731'. Begin directional work to drop angle. Add lubricant to aid sliding. Current lubricant concentration is 2 %. AST=5.75, ART=7.5. Drill from 9,731' to 10,668' dropping angle as per directional plan. Control drill while rotating to help drop angle. AST=12.90 hrs, ART=3.1. Drill from 10,668' to 10,950'. Background gas up to 600 to 900UConnection gas 2000 U. Weight up mud on the fly from 9.4 ppg to 10.0 ppg. Pump low vis / high vis sweep. Circulate hole clean. POH from 10,950' to 7,770'. Hole in good shape, no swabbing. Drag increased from 8,435' to 7,957', 25K over pull. Wiped once - clean and smooth. RIH from 7,770' to 10,950'. No hole problems. Drill from 10,950' to 11,514'. Daily drilling time: AST=7.25, ART=5.25. Drill from 11,514' to intermediate TD at 11,715'. Circulate hole clean with low vis sweep followed by high vis sweep at 820 gpm, 120 rpm. Spot 100 bbl casing running pill. Flow check. Well static. POH to 6,061 '. Hole in good shape. Slip and cut drilling line. Service top drive. Continue to POH. LD BHA. Down load MWD. Pull wear bushing. Install test plug. Change top rams to 9 5/8". Test door seals to 3,500 psi. PJSM. RU casing equipment. Make dummy run with landing joint. PJSM on running casing. Run 156 joints of 9 5/8", 47#, L-80, BTCM casing. Circulate one casing volume at 13 3/8" shoe. Continue to run casing to 10,312'. Circulate and move pipe during safety stand down and accident investigation. Floorman was injured while operation casing tongs. He was caught between the tongs and the guide rail for the top drive. See remarks. Run 9 5/8" casing to 11,705'. Land casing. Circulate and condition mud for cement job. RD Franks fill up tool. MU cement head. Cement job. Pump 10 bbls CW-100. Test lines to 3,500 psi. Pump 10 bbls CW-100, 50 bbls 11.5 ppg mud push spacer, 90 Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION OperationsSu mmaryReport Page 9 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/17/2002 23:00 - 00:00 1.00 CASE P INT1 bbls 15.8 ppg class G cement. 6/18/2002 00:00 - 02:30 2.50 CEMT P INT1 HELD PJSM, CONTINUED TO MIX & PUMP 93 BBLS (450 SX) 15.8 PPG PREMIUM CEMENT wI 2.00 gal/sk D600G GASBLOK, 0.30% BWOC D065 DISPERSANT, 0.15% BWOC D800 RETARDER, 0.20 gal/sk D47 ANTI FOAM AND 3.0% BWOC D174 EXPANDING ADDITIVE. PUMPED CEMENT AT THE FOLLOWING RATES: PUMPED RATE PRESSURE 23.0 BBLS 5.90 BPM 1,540 PSI 41.0 BBLS 6.00 BPM 1,490 PSI 60.0 BBLS 6.30 BPM 1,580 PSI 79.0 BBLS 6.40 BPM 1,540 PSI 90.0 BBLS 2.40 BPM 467 PSI CLEANED UP BEHIND PLUG. SWITCHED OVER TO RIG PUMPS DROPPED TOP PLUG DISPLACED CEMENT AT THE FOLLOWING RATES: PUMPED RATE PRESSURE 100.0 BBLS 9.00 BPM 500 PSI 200.0 BBLS 9.00 BPM 550 PSI 300.0 BBLS 9.00 BPM 750 PSI 400.0 BBLS 9.00 BPM 1,000 PSI 500.0 BBLS 9.00 BPM 1,000 PSI 600.0 BBLS 9.00 BPM 1,500 PSI 700.0 BBLS 9.00 BPM 1,750 PSI 785.0 BBLS Slw'd Pmps2.00 BPM 600 PSI 800.0 BBLS 2.00 BPM 950 PSI 869 BBLS 2.00 BPM 1,000 PSI WIPER PLUG BUMP'D w/ 869 BBLS PUMPED. PRESSURED UP TO 2,000 PSI TO BUMP PLUG, OK. CEMENT IN PLACE AT 0230 HRS. 1:1 RETURNS THROUGHOUT JOB. 02:30 - 04:30 2.00 CEMT P INT1 HELD PJSM. RID CASING EQUIPMENT. 04:30 - 06:30 2.00 CEMT P INT1 HELD PJSM. BROKE OUT AND L / D LANDING JT. RIGGED UP BAILS AND ELEVATORS. SET PACKOFF AND TESTED TO 5,000 PSI f/1 0 MINUTES, OK. 06:30 - 07:30 1.00 BOPSURP INT1 CHANGED UPPER PIPE RAMS TO 4-1/2" x 7" VARIABLES. 07:30 - 08:30 1.00 BOPSURP INT1 HELD PJSM. R I U TO TEST BOPE. 08:30 - 12:00 3.50 BOPSUR P INT1 TESTED BOPE. TESTED UPPER PIPE RAMS, BLIND RAMS, ANNULAR PREVENTER, VALVES, HCR, KILL LINE, CHOKE LINE, CHOKE MANIFOLD, UPPER AND LOWER IBOP AND FLOOR VALVES TO 3,500 PSI HIGH I 250 PSI LOW. ALL I TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD wI NO LEAKS OR PRESSURE LOSS. CHUCK SHEAVE wI AOGCC WAIVED WITNESSING TEST. 12:00 - 14:00 2.00 BOPSUî P INT1 LOWER PIPE RAMS FAILED TO TEST. HELD PJSM. Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION Operations Summary Report Page 1 Oaf 19 Legal Well Name: Com man Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PS 1-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Description of Operatiöhs 6/18/2002 12:00 - 14:00 2.00 BOPSUR P INT1 CHANGED OUT LOWER PIPE RAMS. 14:00 - 16:30 2.50 BOPSUR P INT1 TESTED LOWER PIPE RAMS TO 3,500 PSI HIGH 1250 PSI LOW. ALL TESTS HELD FOR 5 MIN. PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. TESTED KOMMEY UNIT, OK. RID BOPE TEST EQUIPMENT. 16:30 - 17:00 0.50 DRILL P INT1 RAN AND SET WEAR BUSHING. 17:00 - 18:30 1.50 DRILL P PROD1 HELD PJSM. M I U SMITH 8-1/2" MF20TDS BIT, SER# MJ2596, TO SPERRY'S 7" SPERRYDRILL LOBE 7/8 6.0 STG MUD MOTOR. SET PAD OFFSET AND BENT HOUSING TO .93 deg. M I U MWD TOOLS AND ORIENTED TO MOTOR. M I U PULSERS AND INSERTED INTO MWD. RIH wi MWD TO 300' BELOW ROTARY TABLE AND TESTED wi 550 GPM, GOOD PULSE 1,500 PSI - 1,600 PSI. M I U REMAINING BHA. WHILE MAKING UP BHA, R I U AND PMP'D DWN 13-3/8" x 9-518" ANNULUS AT 1.5 BPM, FORMATION BROKE DOWN AT 1,280 PSI. ESTABLISHED INJECTION RATE OF 5 BPM AT 1,680 PSI. R I U LITTLE RED, TST'D LINES TO 3,500 PSI. BULL HEADED 155 BBLS OF CRUDE OIL DOWN ANNULUS TO FREEZE PROTECT. 18:30 - 00:00 5.50 DRILL P PROD1 RIH wi DIRECTIONAL BHA ON 5" DP TO 8,000'. 6/19/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM. RIH wi Directional BHA on 5" DP to 11,620'. Filled DP every 3,000', 01 :00 - 01 :30 0.50 DRILL P PROD1 Broke Circulation, Pumped DP volume, 210 bbls, to clear air from Drill String. Pump Rate 550 gpm, SPP 3,000 psi. 01 :30 - 02:30 1.00 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Tested 9-5/8" Casing to 3,500 psi fl 30 minutes, OK. Bled down pressure, Opened Pipe Rams. 02:30 - 04:00 1.50 DRILL P PROD1 Broke Circulation, Worked and Rotated Drill string, RPM 90, Torque 25,500 ft I Ibs. Circulated Bottoms Up to Displace Thick Mud in hole. Rotated and Reciprocated Drill String. Pump rate 550 gpm, SPP 2,750 psi. After Circulating Bottoms Up, RPM 90, Torque 23,000 ft I Ibs. 04:00 - 06:00 2.00 DRILL P PROD1 Drilled Cement and Float Equipment from 11,620' - 11,692'. WOB 5,000# - 10,000#, RPM 90, Torque 23,000 ft I Ibs, Pump Rate 550 gpm, SPP 2,900 psi. MWD Tools Failed while Drilling. Sperry-Sun made Multiple Attempts to regain MWD Pulse, No Success. Decision made to stop Drilling out Shoe Track and to Displace Hole to New Mud at this point. 06:00 - 09:30 3.50 DRILL P PROD1 Pumped and Displaced Hole to New 9.0 ppg KCL Baradriln Mud. Pump Rate 550 gpm, SPP 2,900 psi. 09:30 - 15:00 5.50 DRILL N DFAL PROD1 POOH w/5" DP. PI U Weight 375,000# - 425,000#. Average Drag 75,000# from 11,692' to 9,500' 15:00 - 17:00 2.00 DRILL N DFAL PROD1 POOH wI Directional BHA. Broke out and LID Mud Motor, Changed out MWD Probe. 17:00 - 19:00 2.00 DRILL N DFAL PROD1 Held PJSM. M I U Smith 8-1/2" MF20TDS BIT, SER# MJ2596, TO Sperry's 7" SperryDrill Lobe 7/8 6.0 STG Mud Motor. Set Pad Offset and Bent Housing To .93 deg. M / U MWD Tools and Oriented To Motor. M / U Pulsars and Inserted into MWD. RIH wI MWD To 200' Below Rotary Table and Tested wI 550 GPM, Good Pulse 1,450 PSI - 1,500 PSI. M I U Remaining BHA. 19:00 - 19:30 0.50 DRILL P PROD1 Serviced Top Drive. 19:30 - 20:30 1.00 DRILL N DFAL PROD1 RIH wI Directional BHA on 5" DP to 3,500'. Printed: 7/10/2002 12:19:13 PM ~) ) BPEXPLORA TION Operations Summary Report Pag~ 11 of 19 Legal Well Name: PS 1-06 Common Well Name: PSI-06 Spud Date: 6/3/2002 Event Name: DRILL +COMPLETE Start: 5/31/2002 End: 7/1/2002 Contractor Name: NABORS Rig Release: 7/1/2002 Rig Name: NABORS 27ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations 6/19/2002 20:30 - 21 :00 0.50 DRILL N DFAL PROD1 Broke Circulation, Circulated Bottoms Up. Pump Rate 500 gpm, SPP 1,200 psi. RPM 55, Torque 4,500 ft I Ibs, String Weight Rotating 115,000#, String Weight Up 120,000#, String Weight Down 115,000#. 21 :00 - 22:00 1.00 DRILL N DFAL PROD1 RIH wi Directional BHA on 5" DP to 6,500'. 22:00 - 22:30 0.50 DRILL N DFAL PROD1 Broke Circulation, Circulated Bottoms Up. Pump Rate 500 gpm, SPP 1,500 psi. RPM 55, Torque 11,000 ft I Ibs, String Weight Rotating 140,000#, String Weight Up 155,000#, String Weight Down 115,000#. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 RIH wI Directional BHA on 5" DP to 9,300'. 6/20/2002 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 Held PJSM. RIH wI Directional BHA to 11,690'. 01 :30 - 02:00 0.50 DRILL N DFAL PROD1 Broke Circulation, Pump Rate 550 gpm, SPP 1,800 psi. Established Parameters, RPM 90, Torque 25,000 ft I Ibs, String Weight Rotating 190,000#, String Weight Up 290,000#, String Weight Down 190,000#. Pumped 25 bbl Lubetex Pill, Observed decrease in Torque from 25,000 ft I Ibs to 22,000 ft I Ibs. 02:00 - 03:00 1.00 DRILL P PROD1 Drilled Cement, Float Shoe and 20' of New Hole from 11,692' - 11,735'. WOB 15,000#, RPM 100, Torque 23,000 ft I Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,100 psi. Circulated Bottoms up to Clean the Hole and Condition Mud. Pump Rate 450 gpm, SPP 1,650 psi. MW in 9.0 ppg, MW out 9.0 ppg. 03:00 - 04:00 1.00 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Performed FIT. Strokes Pmp'd Pressure 5 110 psi 10 225 psi 15 325 psi 20 425 psi Held Test fl 10 minutes wi No Pressure Loss. MW 9.0 ppg, Csg Shoe TVD 8,175', Pressure 425 psi = 10.0 ppg EMW. Bled down Pressure, Opened Pipe Rams. 04:00 - 09:30 5.50 DRILL P PROD1 Drilled 8-1/2" Directional Hole by Rotating from 11,735' - 12,145'. WOB 15,000#-25,000#, RPM 90, MotorRPM 181, Torque 23,000 ft /Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,100 psi. Added Lubricant to Mud System to aid in Decreasing Torque. ART = 4.5 hrs. Connection Gas Max - 1,200 units. 09:30 - 10:30 1.00 DRILL P PROD1 Circulated fl Samples and to Clean Hole. Pump Rate 550 gpm, SPP 1,800 psi. 10:30 - 11 :00 0.50 DRILL P PROD1 Made Wiper Trip from 12,145' to 9-5/8" Casing Shoe at 11,705'. Maximum Overpu1l150,000#, Average Drag 100,000# 11 :00 - 11 :30 0.50 DRILL P PROD1 Serviced Rig. 11 :30 - 12:00 0.50 DRILL P PROD1 RIH to 12,145', No Fill. 12:00 - 14:00 2.00 DRILL P PROD1 Pumped and Circulated Around Hi-Vis Sweep. Pump Rate 450 gpm, SPP 1,700 psi. Circulated until Returns over Shaker were Clean. Pumped and Spotted 30 bbl Liner Pill on Bottom. 14:00 - 14:30 0.50 DRILL P PROD1 POOH wi 5" DP from 12,145' to 11,656'. Maximum Overpull 175,000#, Average Drag 125,000#. 14:30 - 16:30 2.00 DRILL P PROD1 Mixed and Pumped Around 25 bbl EP Mud Lube Pill. Pump Rate 550 gpm, SPP 2,000 psi. Dumped Lube Pill at Surface. .16:30 - 20:00 3.50 DRILL ( PROD1 POOH wI 5" DP from 11,656' to 510'. Maximum Overpull I 100,000#, Average Drag 25,000#. Calculated Fill - 85 bbls, I I Printed 7/10/2002 12: 19: 13 PM ) ) BPEXPLORATION Operations SUmmary Report Page 12 of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From.;, To Hours Task Code NPT Phase Description of Operations 6/20/2002 16:30 - 20:00 3.50 DRILL P PROD1 Actual Fill 175 bbls. Lost 90 bbls of Mud While POOH. Average Loss - 26 bbls I hr. 20:00 - 22:00 2.00 DRILL P PROD1 POOH, Broke out and L / D BHA. 22:00 - 00:00 2.00 DRILL P PROD1 Held PJSM wI Drill Crew and Schlumberger Logging Crew. R / U Schlumberger Logging Equipment. 6/21/2002 00:00 - 02:30 2.50 EVAL P PROD1 Held PJSM. RIH wI Schlumberger USIT Logging Tool to 11,690'. 02:30 - 05:00 2.50 EVAL P PROD1 US IT Logging Run from 11,690' to 10,000' 05:00 - 07:30 2.50 EVAL P PROD1 POOH wI USIT Logging Tool 07:30 - 08:00 0.50 EVAL P PROD1 Broke Out and L / D USIT Logging Tool. 08:00 - 09:30 1.50 EVAL P PROD1 Held PJSM wI Drill Crews and Schlumberger Logging Crew concerning Radioactive Sources w/ Next Logging Run. R I U PEX-BHC Tool. Cleared Rig Floor, Schlumberger Loaded Radioactive Sources. Lowered Tools through Floor. 09:30 - 11 :30 2.00 EVAL P PROD1 RIH wI PEX-BHC Tools to 12,145'. 11:30-13:00 1.50 EVAL P PROD1 PEX-BHC Logging Run from 12,145' to 11,300'. 13:00 - 14:30 1.50 EVAL P PROD1 POOH w/ PEX-BHC Logging Tool. 14:30 - 15:00 0.50 EVAL P PROD1 Broke Out and L / D PEX-BHC Tool. 15:00 - 15:30 0.50 EVAL P PROD1 R / D Schlumberger Logging Equipment. 15:30 - 16:30 1.00 CASE P PROD1 Held PJSM. R I U 7" Casing Running Equipment. 16:30 - 17:30 1.00 CASE P PROD1 M / U and RIH w/14 Joints 7" 26# BTC L-80 Liner. M / U Torque 7,500 ft/lbs. Filled Liner every 5 Joints. Baker Locked First 3 Joints. Float Shoe on Pin end of Jt #1, Float Collar on Pin end of Jt #2, Insert Landing Collar at Pin end of Jt #3. Total Length of Liner 581.12'. 17:30 - 18:30 1.00 CASE P PROD1 R / U 5" Handling Equipment. M / U Baker HMC Liner Hanger ZXP Liner Packer and C2 Running Tool to Liner. Circulated Liner Volume, 19 bbls. Pump Rate 7 BPM, SPP 150 PSI. Liner Weight Up 15,000#, Liner Weight Down 15,000#. R / D Liner Running Equipment. 18:30 - 00:00 5.50 CASE P PROD1 RIH w/7" Liner on 5" DP to 9,100', Filled DP every 10 Stands. Note: Average Mud Losses 12.5 bbl / hr. 6/22/2002 00:00 - 03:00 3.00 CASE P PROD1 Held PJSM. RIH w/7" Liner on 5" DP from 9,100' to 9-5/8" Casing Shoe at 11,705'. Broke out and L / D 1 Jt of 5" DP, P I U and M / U 15' 5" DP Pup Jt fl Space out. Due to Mud Losses, Slowed Running Speed to 5 minutes / Stand. 03:00 - 04:00 1.00 CASE P PROD1 Broke Circulation, Pump Rate 3 BPM, SPP 340 psi. String Weight Up 275,000#, String Weight Down 170,000#. 04:00 - 04:30 0.50 CASE P PROD1 RIH wI 7" Liner on 5" DP to 12,100'. Due to Mud Losses, Slowed Running Speed to 5 minutes / Stand. 04:30 - 05:30 1.00 CEMT P PROD1 M / U Cement Manifold, Slowly Broke Circulation. Pump Rate 3 BPM, SPP 450 psi. Washed Down Liner as a Precaution from 12,100' to 12,145'. Circulated 160 bbls, Pump Rate 3 BPM, SPP 450 psi. Due to Mud Losses, Liner was Not Reciprocated. 7" Liner Assembly Set As Follows: ITEM LENGTH DEPTH Float Shoe 1.65' 12,145.00' 1 Jt 7" 26# BTC Liner 41.25' 12,102.10' Float Collar 1.00' 12,101.10' 13 Jts 7" 26# BTC Liner 537.22' 11,563.88' HMC Liner Hanger 7.50' 11,556.38' ZXP Liner Packer 4.44' 11,551.94' Printed: 7/10/2002 12: 19: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ) BP EXPLORATION Operations Summary Report Page 13 of 19 PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 6/22/2002 04:30 - 05:30 From - To Hours Task Code NPT Phase 11,543.54' 05:30 - 07:00 07:00 - 07:30 Description of Operations 1.00 CEMT P PROD1 Liner Tie Back Sleeve 8.40' 1.50 CEMT P Average Mud Losses 12 bbl I hr. Held PJSM wi Dowell Crews, Rig Crews, Baker and Peak Truck Drivers. Shut Down Pumps and Checked String Weight, String Weight Up 275,000#, String Weight Down 170,000#. Switched over to Dowell. Pumped 3 bbls Water to flush lines. Shut in Cement Manifold and Tested Lines to 4,000 psi, OK. Pumped 30 bbls of CW 100 Chemical Wash at 5.0 bpm, 700 psi. Pumped 30 bbls of MudPush at 5 bpm, 675 psi. Pumped 34 bbls (160 sx) 15.8 ppg Premium Cement wI 0.30% bwoc Dispersant, 3.00% bwoc Latex Expanding Additive, 0.15% bwoc Retarder and 2.00 gallsk GASBLOK. Pumped Cement at the Following Rates: Pumped Rate Pressure 10.0 bbls 5.00 bpm 900 psi 20.0 bbls 5.00 bpm 760 psi 34.0 bbls 5.00 bpm 750 PSI Cleaned up and Flushed Cement Lines. Dropped DP Dart and Displaced wi 216 bbls of Mud at the Following Rates: Pumped Rate Pressure 40.0 bbls psi 80.0 bbls psi 120.0 bbls psi 160.0 bbls psi 190 bbls Slw'd Pmps 2.50 bpm psi Drill Pipe Dart Latched up wi 197 bbls Pumped, Pressure Increased to 1,350 psi, Wiper Plug Sheared, Pressure Decreased to 420 psi. Increased Pump Rate 200.0 bbls 4.00 bpm psi 210.0 bbls psi Wiper Plug Bumped wI 216 bbls Pumped. Pressured up to 1,250 psi to Bump Plug. Cement in Place @ 0700 Hrs. Increased Pressure to 3,500 psi to Set Baker Liner Hanger. Set Down 30,000# to Confirm Hanger Set. Released Pressure and Checked Floats, Bled Back 2.5 bbls, Floats Held. Released Dowell, Switched back to Rig Pumps. Rotated Drill String 20 Turns to Release Running Tool from Liner. Picked up on Drill String, 250,000# New Up Weight, Running Tool Released from Liner. Pumped 25 bbls at 10 bpm to contaminate Cement and Move Cement Up Hole. Set Down 70,000# on Liner Hanger, Observed Packer Pins Shearing and Setting ZXP Packer. Spudded on ZXP Packer wI 70,000# Twice to Ensure Packer Set. PROD1 7.00 bpm 540 7.25 bpm 570 7.25 bpm 540 7.25 bpm 450 220 725 4.00 bpm 725 0.50 CEMT P PROD1 Printed: 7/10/2002 121913 PM ) ') BP Operations Suml11åry Report Page 140f 19 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/22/2002 07:30 - 10:00 2.50 CEMT P PROD1 Circulated Bottoms up to Clear Hole of Excess Cement. Pump Rate 11.5 bpm, SPP 700 psi. Circulated back 5 bbls Cement contaminated Mud. Broke out and L / D Cement Manifold and Lines. 10:00 - 14:00 4.00 CEMT P PROD1 POOH w/ 5" DP. Cleaned, Broke out and LID Liner Running Tool. 14:00 - 15:00 1.00 CASE P PROD1 Held PJSM. Cleared and Cleaned Rig Floor. P I U Strapped and Calipered Clean out Tools. 15:00 - 18:30 3.50 CASE P PROD1 M I U Clean-Out BHA: 6-1/8" Bit - 7" Casing Scraper - Float Sub - 18 Jts 3-1/2" DP - XO - 9-5/8" Casing Scraper - XO - 9 Jts 5" HWDP - 6-3/4" OIL JARS - 2 Jts 5" HWDP. BHA LENGTH 921.29'. 18:30 - 23:00 4.50 CASE P PROD1 RIH w/ Clean-Out BHA on 5" DP to 12,008'. M I U Top Drive, Washed Down from 12,008' to 12,059'. Tagged up on Landing Collar at 12,059'. 23:00 - 00:00 1.00 CASE P PROD1 Circulated to Clean Hole. Pump Rate 8 BPM, SPP 1,550 psi. 6/23/2002 00:00 - 02:00 2.00 CASE P PROD1 Held PJSM. Circulated to Clean Hole, Pump Rate 8 bpm, SPP 1,550 psi. Reciprocated Drill String While Circulating. 02:00 - 06:00 4.00 CASE P PROD1 Held PJSM w/ Drill Crew, Baroid Mud Engr and Peak Truck Drivers on Displacement operation. Pumped 50 bbls Caustic Wash, 50 bbls Dirt Magnet and 30 bbl Hi-Vis Sweep. Pump Rate 8 bpm, SPP 1,550 psi. Switched over to Water Tanks and Displaced the Hole w/ 1,100 bbls of Clean Filtered Seawater. Pump Rate 8 bpm, 1,375 psi. 06:00 - 07:00 1.00 CASE P PROD1 Held PJSM. Closed Pipe Rams and Tested 7" Liner, Liner Top and 9-5/8" Casing to 3,500 psi f/ 30 minutes, OK. Bled down Pressure, Opened Pipe Rams. 07:00 - 07:30 0.50 CASE P PROD1 Blew down and R / D Test Equipment. 07:30 - 08:30 1.00 CASE P PROD1 POOH w/ 5" DP, Racked 40 Stands in Derrick. 08:30 - 15:30 7.00 CASE P PROD1 Held PJSM. POOH, Broke out and L / D 249 Jts of 5" DP. 15:30 - 17:00 1.50 CASE P PROD1 Held PJSM. Slipped and Cut 102' of Drilling Line. 17:00 - 19:00 2.00 CASE P PROD1 POOH, Broke out and LID Clean-Out BHA. 19:00 - 19:30 0.50 CASE P PROD1 Held PJSM wI Drill Crew, Baker and Casing Hand fl Running 7-5/8" Tubing. 19:30 - 22:00 2.50 CASE P PROD1 Cleared Rig Floor of 5" DP Equipment, R / U 7" Tubing Handling Equipment. 22:00 - 23:30 1.50 CASE P PROD1 P / U and M / U R Nipple Assembly, SABL-3 Packer Assembly, PBR Assembly and Upper R Nipple Assembly. All Assemblies are 7" 26# TC-II. M / U Torque 9,650 ft /Ibs. 23:30 - 00:00 0.50 CASE P PROD1 Changed out 7" Handling Equipment for 7-5/8" Equipment. 6/24f2002 00:00 - 20:00 20.00 RUNCOIVP COMP RIH with 7-5/8" 29.7# STL Flush Joint Tubing. Torque Turned each Connection. M / U Torque 5,000 ft I Ibs. Ran 289 jts. String Weight Up 315,000#, String Weight Down 215,000#. 20:00 - 22:00 2.00 RUNCOIVP COMP Tagged up w/ Tubing at 11,552', Tubing Tally Depth. Set Down wI 25,000#. Picked up to 315,000#, Repeated Set Down and Pick up 3 times to Verify Depth. Picked up 2' Above String P I U Weight for Packer Setting Depth. Dropped 1-7/8" Ball / Rod Assembly. R I U Circulating Head and Lines. 22:00 - 00:00 2.00 RUNCOI'Vf\J DFAL COMP Attempted to Pressure Up on Tubing. Ball / Rod Assembly not on Seat. Stroked Tubing String 3 times from 30' above String P I U Weight to 25,000# Set Down on Tubing. Reconfigured Tubing String to 2' Above String P I U Weight. Pressure Up on Tubing to 2,300 psi, Tubing String Jarred at 2,300 psi, Printed: 7/10/2002 12:1913 PM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES 6/24/2002 6/25/2002 Hours Task Code NPT Phase 22:00 - 00:00 2.00 RUNCOIVN DFAL COMP 00:00 - 01 :30 1.50 RUNCOIVN DFAL COMP 01 :30 - 02:30 1.00 RUNCOIVN DFAL COMP 02:30 - 04:00 1.50 RUNCOIVN DFAL COMP 04:00 - 05:00 1.00 RUNCOIVN DFAL COMP 05:00 - 08:30 3.50 RUNCOIVN DFAL COMP 08:30 - 09:00 0.50 RUNCOIVN DFAL COMP 09:00 - 10:00 1.00 RUNCOIVN DFAL COMP 10:00 - 18:30 8.50 RUNCOIVN DFAL COMP 18:30 - 23:00 4.50 RUNCOIVN DFAL COMP 23:00 - 00:00 1.00 RUNCOM\l DFAL COMP 6/26/2002 00:00 - 08:00 8.00 RUNCOM\l DFAL COMP 08:00 - 11 :30 3.50 RUNCOM\l DFAL COMP 11:30-12:00 0.50 RUNCOM\l DFAL COMP 12:00 - 13:00 1.00 RUNCOM\l DFAL COMP 13:00 - 13:30 0.50 RUNCOM\l DFAL COMP 13:30 - 19:00 5.50 RUNCOM\l DFAL COMP Page.150f19 Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Description of Operations Pressure dropped to 2,175 psi. Pressured up to 2,500 psi to Test Tubing. Pressure Loss of 500 psi in 5 minutes. Attempted Pressure Test Several Times with the same results. Opened Tubing side to Flow Line, Closed the Annular and Attempted to Test the IA. Pump Rate 2 BPM at 275 psi, Had Full Circulation. 9-5/8" SABL-3 did not Set. Discussed Packer Setting Situation wI Drilling Engineer in Anchorage POOH LID 2 Jts 7-5/8" Tubing. R I U Circulating Head and Lines. Attempted to Pressure up on Tubing. Pump Rate 3 bpm at 300 psi. Conformation that PBR has Sheared and Seals are Free of Barrel. Cleared Rig Floor, Prepared to R I U Slickline Unit. Held PJSM. R I U Slickline Equipment RIH wI 7" x 4-1/2" Reducing Sleeve on Slickline To 4,500' - POH wI Slick Line Left on Bottom: PBR Barrel - 2 x 7" Pup Jts - Anchor Seal Nipple - SABL-3 Packer - 2 x 7" Pup Jts - R Nipple - 7" Pup Jt. - RN Nipple - 7" Pup Jt - WLEG - Total Length 80.36, Apx Top of Fish 11,470'. Rig Down Haliburton Slick Line Tools And Unit Rig Up Circulating Lines And Pump 200 Barrels Of Seawater With 2% EP Mud Lube On Back Side Of 7 5/8" Tubing For Drag Reduction Hold Pre-Job Safety Meeting - Rig Up And Pull Completion String Lay Down Same - Arrange For Additional Personal And Thread Cleaning Compound From Tool Service. Remove Thread Protectors From Box And Pin End On 7 5/8" STL Flush Joint Tubing - Review MSDS And Have Pre-Job Safety Meeting - Clean And Inspect 120 Joints Of Tubing - Over Spray From Inside Plastic Coating On Seal Area Was Found On 29 Box Ends And 18 Pin Ends (See Digital Photos) - Very Poor Quality Control - Dress All Box Ends With Grant Prideco Representive Continue To POH With Completion String While Cleaning And Inspecting When Laid Down Continue To POH With Completion String While Cleaning And Inspecting When Laid Down Change Out 7 5/8" Tubing Handling Tools For 7" Tools - Pull 7" Tubing And Lay Down Same (Recovered R Nipple And Seal Assembly) - Top Of PBR I Fish At 11,470' - Rig Down Tubing Equipment And Clear Rig Floor Rig Up To Test BOP Equipment Install Saver Sub And Lower IBOP Valve On Can-Rig Top Drive Hold Pre-Job Safety - Set Test Plug Fill BOP Stack With Water 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 Printed 7/10/2002 12:19:13 PM ) ) BP EXPLORATION Operations Summary Report Pagè16of19 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From ~ To Hours Task Code NPT Phase Description of Operations 6/26/2002 13:30 - 19:00 5.50 RUNCOI'vI\I DFAL COMP Valves, Manual And HCR Valves On The Choke And Kill Lines At 250 Psi. Low And 3,500 Psi. High - Test Pit PVT System And H2S And LEL Detectors - Perform Accumulator Test - BOP Test Witness Waived By AOGCC Inspector John Spaulding 19:00 - 19:30 0.50 RUNCOI'vI\I DFAL COMP Remove Test Plug - Set Wear Bushing And Energize Lock Down Studs - Blow Down Choke Manifold And Surface Lines 19:30 - 20:30 1.00 RUNCOI'vI\I DFAL COMP Service Top Drive, Traveling Blocks, And Crown Sheaves 20:30 - 00:00 3.50 RUNCOI'vI\I DFAL COMP Hold Pre-Job Safety Meeting - Rig Up Haliburton Slick Line Unit - Make Up Tools - RIH With Balli Rod Retrieving Tool 6/27/2002 00:00 - 02:00 2.00 FISH N DFAL COMP RIH With Haliburton Ball And Rod Retrieving Tools - Taking Weight At 3,000' - Work To 3,600' - POH And Inspect Tools (EP Mud Lube Gumming Up Tools) RIH To Top Of PBR - Attempt To Work Inside Of PBR (No Good) 02:00 - 03:00 1.00 FISH N DFAL COMP POH With Haliburton Ball And Rod Retrieving Tools (Very Jerky To 7,200') 03:00 - 03:30 0.50 FISH N DFAL COMP Modify And Back Bevel Over Shot Guide 03:30 - 05:00 1.50 FISH N DFAL COMP RIH With No Problems - Work Tools Inside Of PBR To 10,510 - Pick Up And Slack Off Repeatedly Able To Get To 10,512'- Pull Up To 10,300' - EP Mud Lube Holding Tools Back Work To Get Back To PBR And Latch Up Balli Rod 05:00 - 05:30 0.50 FISH N DFAL COMP POH With Slick Line And Balli Rod Retrieving Tools (Recovered Ball And Rod) 05:30 - 07:00 1.50 FISH N DFAL COMP Break Down Slick Line Balli Rod Retrieving Tools - Rig Down .125 Slick Line Sheaves And Equipment 07:00 - 08:30 1.50 FISH N DFAL COMP Hold Pre-Job Safety Meeting - Rig Up Sheaves And Equipment Prepare Braided Line To RIH To Pull 4 1/2" Plug Body. 08:30 - 11 :30 3.00 FISH N DFAL COMP RIH With Braided Line To Pull 4 1/2" Plug Body (Unable To Get To Bottom) 11:30-13:00 1.50 FISH N DFAL COMP POH With Braided Line And 41/2" Plug Body Pulling Tools 13:00 - 13:30 0.50 FISH N DFAL COMP Break Down Tools And Remove 13' Of Weight Stems - Add 10' Of Roller Stem 13:30 - 15:30 2.00 FISH N DFAL COMP RIH With Braided Line To Pull 4 1/2" Plug Body (Unable To Get To Bottom Tools Stopped At 8,500') 15:30 - 17:00 1.50 FISH N DFAL COMP POH With Braided Line And 4 1/2" Plug Body Pulling Tools- Rig Down Haliburton Wire Line Unit 17:00 - 17:30 0.50 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - Pick Up And Make Up 8 1/2" Bit, 9 5/8" Casing Scraper, Bit Sub 17:30 - 18:30 1.00 CLEAN N DFAL COMP RIH With 5" HWDP And 40 Stands Of 5" Drill Pipe From Mast 18:30 - 21 :00 2.50 CLEAN N DFAL COMP Continue To RIH Picking Up Singles Of 5" Drill Pipe From Pipe Shed To 6,001' 21 :00 - 21 :30 0.50 CLEAN N DFAL COMP Make Up TIW Valve And Head Pin - Hold Pre Job Safety Meeting 21 :30 - 23:30 2.00 CLEAN N DFAL COMP Pressure Test Little Red Hot Oil Truck Surface Lines At 1,000 Psi. - Pump 50 BBLS. (Hot Diesel 130 Degrees) - Rig Down Little Red Hot Oil Lines And Turn Over To Rig - Make Up To Can Rig Top Drive - Reciprocate Clean Out String 90 Feet - Pump 25 BBLS. Viscous Spacer - 25 BBLS. Caustic Soda Pill - Followed With Seawater At 8 BPM - Circulate Until Clean Returns At Shaker Taking Diesel And Caustic To Slop Tank. 23:30 - 00:00 0.50 CLEAN N DFAL COMP Continue To RIH Picking Up Singles Of 5" Drill Pipe From Pipe Shed 6/28/2002 00:00 - 04:00 4.00 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - Continue To Pick Up Singles Of Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION Operations Summary>Réport Page 17 of.19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From '- To Hours Task Code NPT Phase Description.of Operations 6/28/2002 00:00 - 04:00 4.00 CLEAN N DFAL COMP 5" Drill Pipe From Pipe Shed And RIH To 11,394' 04:00 - 05:00 1.00 CLEAN N DFAL COMP Make Up TIW Valve And Head Pin - Hold Pre Job Safety Meeting - Rig Up Surface Circulating Lines - Service Rig, Can-Rig Top Drive, Traveling Blocks, And Crown Sheaves. 05:00 - 08:30 3.50 CLEAN N DFAL COMP Hold Pre Job Safety Meeting - Rig Up Surface Circulating Lines - Pressure Test Little Red Hot Oil Truck Surface Lines At 1,000 Psi. - Pump 60 BBLS. (Hot Diesel 130 Degrees) - Rig Down Hot Oil Lines And Turn Over To Rig - Make Up To Can Rig Top Drive - Reciprocate Clean Out String - Pump 25 BBLS. Viscous Spacer - 25 BBLS. Caustic Soda Pill - Followed With 300 Barrels Hot Seawater At 8 BPM And 900 Barrels Cold Seawater - Work Down To 11,479' Top Of PBR When Diesel At Bit - Circulate Until Clean Returns At Shaker Taking Diesel, Vis. Pill, And Caustic To Slop Tank. 08:30 - 13:00 4.50 CLEAN N DFAL COMP POH f/11 ,475' - Lay Down 9 5/8" Scraper, Bit Sub, And 8 1/2" Bit 13:00 - 14:00 1.00 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - Pump 3 BBLS. Diesel In BOP Stack - Rig Up Haliburton Slick Line Unit 14:00 - 15:30 1.50 CLEAN N DFAL COMP RIH With 41/2" Plug Catching Tools (GR) And 10' 2 5/8" Roller Stem (NO Problems Went Straight To Bottom) - Latch Up @ 11,508 (Wire Line Measurement) 15:30 - 16:30 1.00 CLEAN N DFAL COMP POH With 41/2" Plug - Lay Down 4 1/2" GR & Make Up 7" GS Tool 16:30 - 17:00 0.50 CLEAN N DFAL COMP RIH With 7" Insert Catching Tools (GS) And 10" 25/8" Roller Stem - Latch Up @ 11,508' Wire Line Measurement 17:00 - 18:00 1.00 CLEAN N DFAL COMP POH With 7" Sleeve 18:00 - 19:00 1.00 CLEAN N DFAL COMP Rig Down Slick Line Tools And Haliburton Unit - Clear Rig Floor 19:00 - 20:30 1.50 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - Pick Up And Make Up 5 1/2" Mill, Bumper Sub, Oil Jars - Pick Up 21 Joints Of 3 1/2" HWDP From Pipe Shed And RIH 20:30 - 21 :00 0.50 CLEAN N DFAL COMP Make Up Cross Over And 1 Stand 5" Drill Pipe From Mast - Circulate Surface To Surace To Flush Out HWDP At 6 BPM 21 :00 - 00:00 3.00 CLEAN N DFAL COMP Continue To RIH To 8,173' With 5" Drill Pipe From Mast 6/29/2002 00:00 - 00:30 0.50 CLEAN N DFAL COMP Service Top Drive, Traveling Blocks, And Crown Sheaves 00:30 - 02:00 1.50 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - Continue To RIH With 5" Drill Pipe From Mast To Top Of PBR At 11,479' - Travel Thru PBR With "NO Problems" And Continue To RIH Slowly Thru Liner - Tag Fill At 12,044' - Break Circulation And Wash To Top Of Landing Collar At 12,059' 02:00 - 07:30 5.50 CLEAN N DFAL COMP Reciprocate Clean Out String - Circulate Bottoms Up Dump 15' Fill Sediment To Slop Tank - Continue To Circulate Second Bottoms Up - Fluids Still Contaiminiated Mix And Pump Caustic Pill And Hi-Vis Sweep To Clean Well Bore. 07:30 - 10:00 2.50 CLEAN N DFAL COMP Hold Pre-Job Safety Meeting - POH Slowly Thru 7" Liner And Completion String Tubing Tail Pipe (Fish) - With 4 Stands Of 5" Heavy Wate Drill Pipe And 40 Stands Of 5" Drill Pipe 10:00 - 17:30 7.50 CLEAN N DFAL COMP POH Laying Down 234 Joints Of 5" Drill Pipe 17:30 - 19:30 2.00 CLEAN N DFAL COMP Slip And Cut 76 Feet Of 1 3/8" Drill Line - Change Out Iron Ruffneck Pipe Spinner And Repair Grease Line On Electro-Hoist II Draworks 19:30 - 20:00 , 0.50 CLEAN N DFAL COMP Lay Down 1 Joint 5" Drill Pipe, Cross Over, And 21 Joints Of 3 1/2" Heavy Wate Drill Pipe Printed: 7/10/2002 12:19:13 PM ) ) Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PSI-06 DRILL +COMPLETE NABORS NABORS 27ES Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Date From -To Hours Task Code NPT Phase Description of Operations 6/29/2002 20:00 - 20:30 0.50 CLEAN N DFAL CaMP Hold Pre-Job Safety Meeting - Lay Down Baker Oil Tools Oil Jars, Bumper Sub, Bull Nose Mill - Clear Rig Floor 20:30 - 23:00 2.50 RIGU N DFAL CaMP Hold Pre-Job Safety Meeting - Pull Short Wear Bushing And Install Test Plug - Change Rams In Top Gate To 7 5/8" - Test Door Seals At 3,500 Psi. - Pull Test Plug 23:00 - 00:00 1.00 RIGU N DFAL CaMP Hold Pre-Job Safety Meeting - Change Out 350 Ton Elevator Links To Long Set - Rig Up To Run 7" Tail Pipe And 7 5/8" 29.7 lb. Completion 6/30/2002 00:00 - 20:00 20.00 RUNCOI\IN DFAL CaMP Hold Pre-Job Safety Meeting - RIH With 7" Tubing Tail- Pick Up And Make Up SABL Packer - Pick Up Pup Joints And PBR - Change Elevators And Slips For 7 5/8" Tubing - Rig Up Scaffolding - Change Heads In Tongs - Pick Up 7 5/8" 29.7 lb. L-80 Tubing And RIH Per Program While Monitoring Returns To Trip Tank. Record The Following Up And Down Weights. 3,000 Feet - 125K Up And 115K Down 6,000 Feet - 180K Up And 155K Down 9,000 Feet - 260K Up And 180K Down 11,400 Feet - 320K Up And 215K Down 20:00 - 22:30 2.50 RUNCOI\IN DFAL CaMP Hold Pre-Job Safety Meeting - Make Up Joint No. 285 & RIH - Drop Ball And Rod - Pick Up Pup Joint And Place Packer On Depth - Wire Line Entry Guide @ 11,426' (Note Top Of 1 st PBR FISH @ 11,479') - Make Up Surface Circulating Lines & Head Pin - Reconfirm Packer On Setting Depth - Pressure Up Down Tubing To 2,500 Psi. To Set SABL Packer - Hold For 15 Minutes - Increase Pressure To 3,000 Psi And Hold For 5 Minutes - Bleed Pressure Off Tubing And Remove Pump In Line To Monitor Tubing - 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 @ 320K Continue To Pick Up Tubing String To 375K Apply 1,000 Psi. Down Tubing To Shear PBR (NO GOOD) - Pick String Up To 395K And Apply 1,000 Psi. (NO GOOD) - Slack Off String To 250K And Back Up To 400K Apply 1,000 Psi. (NO GOOD) - Consult With Anchorage ODE (Rod Tirpack) To Apply More Pressure For Up Ward Thrust At PBR - Pressure Up To 1,500 Psi. Down Tubing And Pick Up String Weight To 380K For PBR To Shear. 22:30 - 00:00 1.50 RUNCOM=> CaMP Hold Pre-Job Safety Meeting - Rig Down Surface Circulating Equipment & Head Pin - Back Out Pup Joint - Pull Single Of 7 5/8" Tubing (Joint 285) For Space Out And Lay Down Same - Change Elevators For 5" Drill Pipe 7/1/2002 00:00 - 02:30 2.50 RUNCOM=> CaMP Hold Pre- Job Safety Meeting - Make Up FMC Tubing Hanger - Install NSCC X 41/2" IF Crossover And Pick Up Single Of Drill Pipe - Make Up TIW Valve And Head Pin - Rig Up Manifold For Circle Chart Recorder - Install Circulating Hose - Line Up Equipment To Reverse Circulate Inhibited Sea Water (nd Diesel- Clear Rig Floor Of Casing Tools, Tongs, And Printed: 7/10/2002 12: 19: 13 PM ) ) BP EXPLORATION Operatiòns Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-06 PS 1-06 DRILL +COMPLETE NABORS NABORS 27ES Date From- To Hours Task. Code NPT Phase 7/1/2002 00:00 - 02:30 2.50 RUNCOrvP CaMP 02:30 - 05:30 3.00 RUNCOrvP CaMP 05:30 - 08:00 2.50 RUNCOrvP CaMP 08:00 - 09:00 1.00 RUNCOrvP COMP 09:00 - 12:00 3.00 WHSUR P COMP 12:00 - 16:30 4.50 WHSUR P CaMP 16:30 - 18:00 1.50 WHSUR P COMP Page 19 of 19 Start: 5/31/2002 Rig Release: 7/1/2002 Rig Number: Spud Date: 6/3/2002 End: 7/1/2002 Description of Operations Associated Equipment. Reverse Circulate 154 Barrels Inhibiated Seawater And 138 Barrels Of Diesel At 3 BPM - U-Tube Annulus To Tubing. Land Tubing And Energize Lock Down Studs - Record On Pressure Chart The Test On Tubing For 30 Minutes At 4,000 Psi. - Bleed To 2,500 Psi. - Pressure Test Annulus At 4,000 Psi. For 30 Minutes. *NOTE* Witness Of The Above Tests Were Waived By The AOGCC Representive Jeff Jones At The Present Time. The AOGCC Plans To Witness A Test After Injection Process Started And Warmed Up. Hold Pre-Job Safety Meeting - Rig Down Little Red Hot Oil Unit - Rig Down Circulating Equipment And Blow Down - Back Out Landing Joint And Lay Down Same - Pick Up "T" Bar And Install Two Way Check Valve. Hold Pre-Job Safety Meeting - Remove 7 5/8" Rams From Top BOP Gate And Install 4 1/2" By 7" Variables - Nipple Down Choke And Kill Lines - Remove Flow Line And Riser - Set BOP On Stand And Secure. Hold Pre-Job Safety Meeting - Nipple Up FMC Adapter Flange And 71/16 5M Production Tree - Test Adaptor Flange Void And Production TreeTo 5,000 Psi. For 10 Minutes - Suck Out Cellar - Confirm Top Of Cement In 13 3/8" X 20" Annulus. Hold Pre-Job Safety Meeting With Drill Site Maintenance - Rig Up And Pull Two Way Check Valve And Install Back Pressure Valve - Remove Otis Flange 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-06 At 1800 Hours On 07/01/02 Printed 7/10/2002 12: 19: 13 PM ) ) Well: Field: API: Permit: PSI-06 Prudhoe Bay Unit 50-029-23082-00 202-079 Rig Accept: 06/02/02 Rig Spud: 06/03/02 Rig Release: 07/01/02 Drilling Rig: Nabors 27E POST RIG WORK 07/15/02 RAN 4.39" BELL GUIDE & 2" RS PULLING TOOL TO 11,3691 SLM. TAP DOWN. POOH. DID NOT HAVE BALL & ROD. 07/16/02 PULLED BALL & ROD. RAN n PULLED 4-1/2" RHC-M n PULLED 7" RBX REDUCING NIPPLE -- DRIFT 3-3/8" DUMMY GUN & 1.75" SAMPLE BAILER, TAG HARD BOTTOM @ 12,0231 WLM. LEFT WELL SHUT IN. 07/18/02 LOGGED TEMPERATURE BASE PASS FROM 11200'-120591 TD @40 FPM AND JEWELRY LOG FROM TD-11200'. PERFORATED 12037.5'-12057.5' WITH 3 3/8" POWERJET 6 SPF, 38.6" PENE, .45" EH, 22.7 GMS. LDFN. 07/19/02 COMPLETED PERFORATING, 120121-12037.5', 11984'-12004', 119581-11978' REFERENCING PEX LOG. CHARGE TYPE: 3318 POWERJET 3406,6 SPF, EH 0.45", PENETRATION 38.6", GRAMS 22.7. LOGGED SBHP SURVEY @ 119931 MD = 84001 TVD SS. STOP COUNTS COMPLETED AFTER 60 MINUTES, PRESSURE 3532.5 PSI, TEMPERATURE 170.6 DEGF. WELL SHUT IN. 07/21/02 PERFORMED INJECTIVITY TEST. 07/26/02 RIH WITH 3.5" JSN. TAG TD AT 12042 CTMD. START PUMPING NH4CL. INITIAL INJECTIVITY IS 1 BIM AT 1500 PSI. FINAL INJECTIVITY IS 0.75 BIM AT 2154. INITIAL INJECTIVITY WITH 7.5 % HCL IS 0.75 BIM AT 2154. (SEE WELL SERVICE REPORT ATTACHED.) 07/27/02 CONTINUE PUMPING ACID. FINAL INJECTIVITY WITH 70/0 HCL IS 181M AT 1642 PSI. INITIAL INJECTIVITY WITH MUD ACID IS 1.2 81M AT 1686 PSI. FINAL INJECTIVITY WITH MUD ACID IS 1.4 BIM AT 1231 PSI. INITIAL INJECTIVITY WITH NH4CL IS 1.4 BIM AT 1231 PSI, FINAL INJECTIVITY IS 1.3 BIM AT 1480. POH. FRZ PROTECT TO 3000' WITH 50/50 MEOH, PERFORM SRT. FINAL INJECTIVITY DOWN BACKSIDE: 4.5 BPM/1950 PSI. NOTIFY DSO, ROMO. WELL LEFT SI. (SEE WELL SERVICE REPORT ATTACHED.) WELL SERVICE REPOR ) Page 1 of 1 ) WELL PSI-06 DATE 7/26/2002 AFE PBD4P1903 JOB SCOPE NEW WELL POST DAILY WORK ACID TREATMENT KEY PERSON DS-MOORE MIN ID 5.77" I DEPTH 11413 FT UNIT CTU #8 DAY SUPV PETTY NIGHT SUPV GOLDING TTL SIZE 7" DAILY SUMMARY rvfiru êtu #8. Rih With' 3.5" 'js'n. Tag TD at 12042 ctmd. Start pumping NH4CL. IniÜäl injëcthllty is is 1 b/m at 1500 psi. Firiäí injectivity is 0.75 b/m at 2154. Initial injectivity with 7.5 % HCL is 0.75 b/m at 2154. Job in progress... Init Tb~, lA, OAJ 0 J 0 I TIM E DEPTH TBG ..Ç!.~'N " .,1"5.".'..'..:01'.'.'.' ,,,.,..,, .'. 0 ...w'W., ""'w.",,,....'.., ..d... "n .." n " """U"'N'''. ,'" "M 16:00 0 ., '1~r2ÓW" 'M ""6'" W 10 BPM BBLS COMMENTS v v ,- v v vww'''''''''\W>'\''M'ove'to''''''ps'ï:Õ'S ...mV ...'.M.....N .....^...'''''...v V .. "MTRfT'iJniiihf"'Respot iânks an cf'eqUip'rTí e'ntd Lïewio Cîöse prox(mity'''' ~,L~i.g: ^,N '^ ....,.." ",,,,,,,,,.w.,,,,.,,,,.w...,,," ''''M"''^, "" '" , M ,,' ,. Safety meeting with CT'ers, cementers, and vac truck drivers. Discuss safe meeting area, sim ops with rig, acid handling, and pressLJrec;()I1~~r?il1~,sfor.lNeJL.. .. ... ." ................ .. Pr~~~~rE3 test sur1é:lcf? ~quipment low and high. (200/4009). .. RIH with 2" CTC, 2.25" chks, 2.25 stinger, 2.25" XO (2), 3.5" nozzle. . (QAkT) ..., ...., .... Wt ck at 9910 is 14.4 K. Tag TO at 12042 CTMD. Wt is 22k.'Pick up to top of perfs and hold ... saf€?ty meeting. with.ee~ple ~n..!oc~tiol1~. ... ..... ... . - . . 0 On line with 5 bbls NH4CL. SD and test lines to 4k. Good test. ""5" "Ê3âëk"ôrÏ"Üne with rèmafrîdër6fN'H4'cL .......'.N ......... ... ..... ..... . '.'."g'tr$~~Pto HCL. . ...,'.. ., ,............. .. ........ ... 31 NH4CL at nozzle. Reciprocate across perfs. . . 39 Bleed WHP to 1500. It appears to be trýing to lock up with the NH4CL water, Stop RIH and hang out. Drop WHP to 1715 and RIH ............................... ,.'w ".. ............... ............................. .. ... ,J~~ll)gJ~,~,urns fpr 2 bbl~. SI aoçt.ç9.I1Jin.~~.. ",' N"'" , 23:57 11398 2154 2306 0.75 56 Acid at nozzle. WHP starts to decrease. F~n~T~b~tl~~Al-~w;~~ ;í^"~2~~{~ r-",^w21 ~ ~_~_~~ntin~~£!!1-A<L~'CL.Job i'n pro:gress. . 19:52 20:13 0 0 ...... .......................... 21 :53 9910 22:16 12042 807 870 0 0 0 0 '--'??~4ã.~ . ""11.'~~Ø.'. .. ......N ,9... - 22:54 11936 836 -"2'3:'16" .." "'11 9"36"' .. '1444'" "'23:2~f'" '1'19'35" " N 1SÓÖ ., 23:32 12022 . 2081 .... ---......--....-. ...., .., ... 0 0 . 1söämo:é '" 2f6Õ" "".'.'.."""^T"..m'.... ""21'66 ... "1' . . .... ... 2380 0.75 -_.._._-----_..._.~~- I FLUID SUMMARY Aif fìuids accounted fo'r on 7/27/02 AWGRS report. SERVICE COMPANY - SERVICE DOWELL" ... . ....- ., ORBIS"v, .......v v v v v v PEAK' VECO W AR'EHOUSE SCHLUMBERGER HALLIBURTON LITTLE RED ..,PAIL Y ~OS.,T .. CUMUL TOTAL '$f3,249 . $13,249 " $900" ,., n w " '."'."N $900 $724 $1,636 $3,885 $8,032 $3,087 $6,237 $0 $28,990 $0 $2,616 $0 $1,960 $21,845 $63;620 V\ . .,,' .1,... TOTAL FIEL.DESTIMATE: .. .Iwellevent_awgs.asp'! IlJ=CB 1.b.b6576.b5lJ42~5Y714755C7 .b04A.b5AI72BOF70BlJ7lJ64lJ26YlJJ~/ 14/2002 WELL SERVICE REPOR ) ') Page 1 of 1 WELL PSI-06 DATE 7/27/2002 AFE PBD4P1903 JOB SCOPE NEW WELL POST DAILY WORK ACID TREATMENT KEY PERSON DS-SCARPELLA MIN ID 5.77 " I DEPTH 11413 FT UNIT CTU #8 DAY SUPV PETTY NIGHT SUPV GOLDING TTL SIZE 7" DAILY SUMMARY Continuedirom WSR of 7/26i02. Continue pumping acid. Final injectivlty w¡th¿% HCL is 1bïrn at"" 1642 psi. IniÜal injectivity'" with Mud Acid is 1.2 b/m at 1686 psi. Final injectivity with Mud Acid is 1.4 b/m at 1231 psi., Initial injectivity with NH4CI is 1.4 b/m at 1231 psi, final injectivity is 1.3 b/m at 1480. POH. Frz protect to 3000' with 50/50 meoh, perform SRT. Final injectivity down bckside: 4.5 bpm/1950 psi. Notify DSO, rdmo. **W ell left SI. ** Init Tb.R, lA, OA 1 1902 J TIME DEPTH TBG 00:01 0 . .V . .... .m..V -, "",,QQ;g9... J J~~ L.~w,,,J,~gg._'''M "g42~.... 00:31 12035 1810 2453 211 CTP 00:59 01:09 _..vA 01 :19 01:56 02:21 05:30 05:58 07:37 07:45 ...... v v.,.. 08:02 ',,,,' ^,,,,,,'.^M "'; ^ " 08:09 08:14 .v \. V. , 08:21 08:26 08:31 08:40 08 :46 09:50 ,11949 1766 11 994 1 642 ''''.'~_.v^...... 12027 1686 12027 1202 . . . 11950 1231 ........................"...... .m.'" ., 11 947 1480 ..n..." ". ... 11 947 1480 0 0 . ... . 0 ........v...v .V .....v v -, 0 1165 0 1700 P ...,1859 0 1920 mV v ^' . 0, 1915 0 1920 0 1950 0 1950 0 10 BPM BBLS COMMENTS Continued from WSR of 7/26Î02 64 Increase rate to 1 b.ïTi,'" '. . 89 Cö'ntlñ"U'êlõ^^rêêlp"ãc'ross^'pêrts':Töõkslike"u.pp(3r' (1195'8- f19'jãjä'ñ'd lower perfs (12012-12037) saw a slight break down with acid. No , , ch?nge noted in second interval. (11984-12004) 2380 1 116 RBIH. ......???§.... .'j.". ""1?6'.sÿV~p'JoMMA:. ,. .---:-. 2607 1.2 137 Increase rate to 1.2 b/m. 2219 1.2 176 Swap to NH4CL Increase rate to 1.3 b/m. 2665 . 1.4-... .?tq..N.H4.çÇ~L~.2.z,zl~. ..Ë}~al...i..QJ~.9vtivity with MA is 1.4.b/~ ~t.1..?~.f:', 2783 1.3 456 Swap to K9L tç displa.c~ NH:4CL from coil. 2780" . 1.4 ,,488 SP.pumping a.nd POH., 0 0 488 At surface. "..,. 'w" ""~. .m.'::'.~W~W~M~t :§!~:~J?:L.!DipJ~.g..J~/o, ~1..~cJ çJ,o~!1 b~cksid~. 0 1 25 Start SRT. O. . ......"{. fj" ... '''35' '1::'.5bpm' ''''''M " .. M , ~ , , 0 , . .. 2 .... ..... 45 .2...þpD1....... , ,Q. '" " "" ?':w9 , 'w,. "...,..~Q., ..?:,?....ÞP!n.... 0... . .. .~.... ...., .,}þpŒ):, .. . 0 3.5 90 .3:5 bpm. O. ...4.:9,. .. .t 25. ..4.:.9 b.Pr}'l (fTlax, rat(3,) ... .., ...., , '. .. ., " , " MM.Q, .. .,,,^,,..4,~,9.,, M"....,.J..?.Q.,..~!.':l.i§~,.!.I.\J..~h .O.?Q...þ'.þ.I.~ ?~~yt - switc~, to 50/59 .~~oh dO~!J..ÞS?~~.i.ge. , Finish frz protecting (pump 120 bbls). Steady 1788 psi @ 2bpm .....,.. ..Y.Yhi.!~...p.Y.r.np'i.Q.g '.....N .. ........ .....N , . F.y~~þl~c:é1P wqf1'tcgf!1~of! - 9all for DSO; . Pop off well. . . . RDMO, head to d~ill site 16. ....--......---....---- . v ~ V\ "". ..J....,Y ...." V W v " 'IV -", ""V V V v 1 q:05M.... , Q.. 10:45 0 13:00 0 Final Tbg,IA, OAl '1 '''''-r FLUID SUMMARY - . 50 bbls 9: 1 Mud Acid (Field titration is 9.1: 1.1) Acid includes 0.5% A-261, 8 ppt A-153, 4 ppt A-179, 0.2% F-103, 20 ppt L- 58. 305 bbls 3% NH4CL with 10% U-66 and 0.2% F-103. 184 bbls 1% KCL 136 bbls 50/50 MEOH 100 bbls 7.5% HCL (Field titration is 7.8%) Acid includes 20 ppt L-58; 0.20 % F-103, 0.5% A-261, 0.5% A-201. SERVICE COMPANY - SERVICE DOWELL PEAK VECO WAREHOUSE SCHLUMBERGER HALLIBURTON ORBIS LITTLE RED DAILY COST . ... .. ..... .... . . TOTAL FIELD ESTIMATE: $22,024 $724 $299 $2,680 $0 $0 $0 $0 . $25,7"27 CUMUL TOTAL $35,273 $2,360 $8,331 $8,917 $28,990 $2,616 $900 $1,960 $89,347 .../wellevent_awgs.asp'! ID=DEKH~ II FA2244636AEE9C57UKHF797 131257 F65E96HEA42ECA~L~/14/2UU2 ~ üd-07<=j 22-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well PSI-06 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 12,145.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED JUL 2 j 2002 Alaska Oil & Gas Cons. Commission Anchorage - North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI 6 PSI 6 - PSI-D6 Job No. AKZZ22084, Surveyed: 20 June, 2002 SURVEY REPORT 22 July, 2002 Your Ref: API 5002923082 Surface Coordinates: 5966148.95 N, 707967.83 E (70018' 39.1604" N, 1480 18' 52.6196" W) Kelly Bushing: 50. 80ft above Mean Sea Level ~ sper-'r"Y-SUf1 DRILLIN.G SERVIc:es A Halliburton Company D.' i:IN~ f(TI ~ ~ ..: ~ B . E -~7 _/ Survey Ref: svy11196 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-06 Your Ref: API 5002923082 Job No. AKZZ22084~ Surveyed: 20 June~ 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 0 Oft) 0.00 0.000 0.000 -50.80 0.00 0.00 N 0.00 E 5966148.95 N 707967.83 E 0.00 AK-6 BP _IFR-AK 114.00 0.000 0.000 63.20 114.00 0.00 N 0.00 E 5966148.95 N 707967.83 E 0.000 0.00 --' 205.74 0.030 181.500 154.94 205.74 0.02 S O.OOE 5966148.93 N 707967.83 E 0.033 -0.02 316.60 0.130 343.050 265.80 316.60 0.07 N 0.04W 5966149.02 N 707967.79 E 0.143 0.07 384.25 0.130 355.410 333.45 384.25 0.22 N 0.07W 5966149.17 N 707967.76 E 0.041 0.20 475.94 0.670 314.360 425.14 475.94 0.70 N 0.46 W 5966149.63 N 707967.35 E 0.631 0.82 562.88 1.390 311.890 512.06 562.86 1.76 N 1.61 W 5966150.66 N 707966.18 E 0.830 2.38 653.52 2.420 313.820 602.65 653.45 3.81 N 3.81 W 5966152.66 N 707963.92 E 1.138 5.39 752.21 3.550 311.970 701.21 752.01 7.30 N 7.58W 5966156.04 N 707960.05 E 1.149 10.52 847.41 4.570 312.220 796.17 846.97 11.82 N 12.58 W 5966160.42 N 707954.93 E ¡. 1.072 17.25 941.83 6.130 310.440 890.17 940.97 17.62 N 19.20 W 5966166.03 N 707948.15 E 1.661 26.04 1037.87 7.870 318.550 985.49 1036.29 25.87 N 27.46 W 5966174.05 N 707939.66 E 2.079 37.71 1131.57 10.020 323.930 1078.05 1128.85 37.27 N 36.51 W 5966185.20 N 707930.30 E 2.460 52.17 1227.27 11 .440 322.640 1172.08 1222.88 51 .55 N 47.17 W 5966199.17 N - 707919.25 E 1.505 69.80 1319.42 13.910 322.030 1261.97 1312.77 67.54 N 59.53 W 5966214.82 N 707906.45 E 2.684 89.85 1413.34 17.1 00 319.600 1352.46 1403.26 86.96 N 75.43 W 5966233.79 N 707890.02 E 3.465 114.82 1506.00 22.010 319.980 1439.75 1490.55 110.65 N 95.44 W 5966256.91 N 707869.37 E 5.301 145.72 1601.54 22.200 317.360 1528.27 1579.07 137.64 N 119.18 W 5966283.24 N 707844.89 E 1.051 181.59 1695.44 21.440 317.260 1615.44 1666.24 163.29 N 142.84 W 5966308.22 N 707820.52 E 0.810 216.46 1788.35 21.110 317.680 1702.02 1752.82 188.13 N 165.63 W 5966332.43 N 707797.05 E 0.391 250.14 ~/ 1883.05 21.530 317.740 1790.24 1841.04 213.60 N 188.80 W 5966357.24 N 707773.19 E 0.444 284.53 1978.45 23.410 315.680 1878.40 1929.20 240.12 N 213.81 W 5966383.06 N 707747.45 E 2.136 320.97 2071.15 28.540 314.980 1961.70 2012.50 268.97 N 242.36 W 5966411.11 N 707718.11 E 5.544 361.55 2164.86 33.140 314.850 2042.14 2092.94 302.88 N 276.38 W 5966444.06 N 707683.17 E 4.909 409.58 2259.20 33.980 315.480 2120.76 2171.56 339.86 N 313.14 W 5966480.01 N 707645.40 E 0.964 461.73 2354.60 36.670 313.470 2198.59 2249.39 378.48 N 352.52 W 5966517.52 N 707604.97 E 3.071 516.88 2450.14 35.270 314.280 2275.91 2326.71 417.36 N 392.97 W 5966555.27 N 707563.45 E 1.548 572.98 2544.04 35.960 314.170 2352.24 2403.04 455.50 N 432.16 W 5966592.31 N 707523.22 E 0.738 627.66 2639.01 41.250 313.260 2426.43 2477.23 496.42 N 474.99 W 5966632.02 N 707479.27 E 5.602 686.88 2728.89 47.070 311.710 2490.89 2541.69 538.65 N 521.17 W 5966672.97 N 707431.94 E 6.585 749.40 22 July, 2002.13:13 Page 2 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-06 Your Ref: API 5002923082 Job No. AKZZ22084~ Surveyed: 20 June~ 2002 BPXA North Slope Alaska lisburne PSI (East Dock) 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) (°/1 0 Oft) 2820.28 47.750 311.660 2552.74 2603.54 583.40 N 571.42 W 5966716.30 N 707380.47 E 0.745 816.58 2913.17 50.750 311.300 2613.36 2664.16 630.00 N 624.14 W 5966761.43 N 707326.48 E 3.243 886.81 3008.29 52.650 311.620 2672.31 2723.11 679.42 N 680.08 W 5966809.28 N 707269.20 E 2.015 961.31 - 3102.04 53.160 312.040 2728.86 2779.66 729.30 N 735.80 W 5966857.59 N 707212.12 E 0.651 1035.98 3196.57 53.310 313.140 2785.44 2836.24 780.54 N 791.54 W 5966907.27 N 707154.97 E 0.946 1111.64 3290.48 52.320 313.630 2842.20 2893.00 831.93 N 845.92 W 5966957.14 N 707099.20 E 1.133 1186.43 3379.50 52.530 315.260 2896.48 2947.28 881.33 N 896.28 W 5967005.13 N 707047.48 E 1.470 1256.97 3472.06 52.590 315.020 2952.75 3003.55 933.43 N 948.12 W 5967055.76 N 706994.22 E 0.216 1330.47 3569.17 54.380 314.400 3010.54 3061.34 988.33 N 1003.59 W 5967109.11 N 706937.25 E 1.913 1408.51 3662.99 54.680 313.200 3064.98 3115.78. 1041.21 N 1058.74 W 5967160.44 N 706880.66 E t 1.090 1484.90 3756.05 57.290 313.050 3117.03 3167.83 1093.94 N 1115.03 W 5967211.59 N 706822.93 E 2.808 1561.99 3850.22 55.660 314.520 3169.04 3219.84 1148.25 N 1171.71 W 5967264.31 N 706764.77 E 2.165 1640.47 3943.19 55.820 314.700 3221.38 3272.18 1202.21 N 1226.41 W 5967316.74 N 706708.59 E 0.235 1717.31 4037.43 56.570 315.450 3273.81 3324.61 1257,65 N 1281.71 W 5967370.63 N. 706651.78 E 1.035 1795.61 4130.12 56.450 315.700 3324.96 3375.76 1312.86 N 1335.82 W 5967424.31 N 706596.17 E 0.260 1872.91 4224.86 55.340 316.000 3378.08 3428.88 1369.14 N 1390.46 W 5967479.06 N 706539.99 E 1.201 1951.35 4316.74 54.520 316.550 3430.87 3481.67 1423.49 N 1442.44 W 5967531.95 N 706486.52 E 1.018 2026.52 4412.02 53.810 317.310 3486.65 3537.45 1479.91 N 1495.19 W 5967586.89 N 706432.23 E 0.987 2103.72 4505.16 56.440 317.630 3539.90 3590.70 1536.22 N 1546.83 W 5967641.74 N 706379.05 E 2.838 2180.05 4600.21 57.960 317.730 3591.39 3642.19 1595.29 N 1600.62 W 5967699.30 N 706323.64 E 1.602 2259.86 -~...-' 4693.67 58.030 317.560 3640.93 3691.73 1653.86 N 1654.02 W 5967756.37 N 706268.64 E 0.171 2339.02 4786.93 57.330 318.340 3690.79 3741.59 1712.38 N 1706.81 W 5967813.41 N 706214.26 E 1.031 2417.73 4879.34 57.090 318.930 3740.83 3791.63 1770.68 N 1758.15 W 5967870.27 N 706161.32 E 0.596 2495.25 4972.42 56.590 318.510 3791.75 3842.55 1829.24 N 1809.55 W 5967927.38 N 706108.31 E 0.657 2573.01 5067.77 56.820 319.390 3844.09 3894.89 1889.35 N 1861.89 W 5967986.01 N 706054.33 E 0.808 2652.51 5159.80 58.020 317.690 3893.65 3944.45 1947.45 N 1913.24 W 5968042.67 N 706001.40 E 2.030 2729.90 5257.60 58.930 316.470 3944.78 3995.58 2008.50 N 1970.01 W 5968102.12 N 705942.96 E 1.413 2813.21 5350.43 58.770 313.980 3992.81 4043.61 2064.89 N 2025.96 W 5968156.94 N 705885.47 E 2.302 2892.64 5444.46 58.930 312.550 4041.45 4092.25 2120.04 N 2084.55 W 5968210.45 N 705825.37 E 1.313 2973.08 5538.03 58.060 309.150 4090.36 4141.16 2172.21 N 2144.88 W 5968260.93 N 705763.62 E 3.234 3052.63 22 July, 2002 - 13:13 Page 30(7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-06 Your Ref: API 5002923082 Job No. AKZZ22084J Surveyed: 20 JuneJ 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 OOft) 5632.43 57.210 309.290 4140.89 4191.69 2222.63 N 2206.65 W 5968309.62 N 705700.48 E 0.909 3131.96 5724.98 56.280 309.890 4191.64 4242.44 2271.95 N 2266.29 W 5968357.27 N 705639.49 E 1.142 3209.02 55.990 310.230 4244.44 4295.24 2322.58 N 2326.51 W 5968406.21 N 705577.90 E 0.427 3287.41 ~/ 5819.73 5913.78 56.380 311.410 4296.78 4347.58 2373.66 N 2385.64 W 5968455.64 N 705517.37 E 1.122 3365.34 6006.88 56.640 310.860 4348.15 4398.95 2424.74 N 2444.12 W 5968505.07 N 705457.50 E 0.566 3442.81 6101.36 56.750 310.110 4400.03 4450.83 2476.00 N 2504.17 W 5968554.66 N 705396.05 E 0.674 3521.53 6195.25 58.120 310.310 4450.57 4501.37 2527.09 N 2564.60 W 5968604.05 N 705334.23 E 1.470 3600.39 6284.56 58.990 311.240 4497.16 4547.96 2576.85 N 2622.30 W 5968652.19 N 705275.18 E 1.318 3676.37 6340.55 59.500 310.940 4525.79 4576.59 2608.47 N 2658.56 W 5968682.80 N 705238.05 E 1.021 3724.38 6456.71 59.860 310.180 4584.43 4635.23 2673.67 N 2734.74 W 5968745.86 N 705160.'10 E 0.644 3824.36 6551.18 58.340 311.390 4632.95 4683.75 2726.62 N 2796.12 W 5968797.09 N 705097.28 E 1.948 3905.20 6646.96 57.080 312.600 4684.11 4734.91 2780.78 N 2856.29 W 5968849.57 N 705035.62 E 1.694 3986.05 6738.70 55.560 314.660 4734.99 4785.79 2833.44 N 2911.55 W 5968900.68 N 704978.93 E 2.497 4062.36 6836.41 53.010 315.870 4792.03 4842.83 2889.78 N 2967.39 W 5968955.45 N 704921.55 E 2.797 4141.69 6931.88 52.500 316.340 4849.81 4900.61 2944.55 N 3020.09 W 5969008.73 N 704867.36 E 0.663 4217.67 7025.82 52.220 316.710 4907.18 4957.98 2998.53 N 3071.27 W 5969061.28 N 704814.70 E 0.431 4292.03 7125.08 52.430 316.240 4967.84 5018.64 3055.49 N 3125.37 W 5969116.72 N 704759.04 E 0.430 4370.57 7218.21 51.630 317.040 5025.14 5075.94 3108.87 N 3175.78 W 5969168.68 N 704707.17 E 1.094 4443.95 7310.12 50.430 317.060 5082.94 5133.74 3161.17N 3224.47 W 5969219.61 N 704657.06 E 1.306 4515.36 7408.00 50.150 317.150 5145.48 5196.28 3216.33 N 3275.72 W 5969273.34 N 704604.30 E 0.295 4590.60 ~"..T 7505.25 50.580 318.410 5207.51 5258.31 3271.80 N 3326.04 W 5969327.38 N 704552.46 E 1.091 4665.40 7597.43 50.300 317.780 5266.22 5317.02 3324.69 N 3373.51 W 5969378.94 N 704503.54 E 0.608 4736.36 7692.76 50.740 318.380 5326.83 5377.63 3379.44 N 3422.67 W 5969432.31 N 704452.89 E 0.670 4809.83 7785.45 51.050 319.010 5385.30 5436.10 3433.47 N 3470.14 W 5969485.01 N 704403.94 E 0.625 4881.61 7880.46 51.250 318.610 5444.90 5495.70 3489.15 N 3518.87 W 5969539.32 N 704353.68 E 0.390 4955.43 7970.36 51 .160 318.440 5501.22 5552.02 3541.65 N 3565.27 W 5969590.51 N 704305.84 E 0.178 5025.37 8063.07 52.140 316.160 5558.75 5609.55 3595.07 N 3614.58 W 5969642.54 N 704255.08 E 2.199 5098.00 8157.07 52.480 316.220 5616.22 5667.02 3648.75 N 3666.08 W 5969694.77 N 704202.11 E 0.365 5172.37 8250.91 52.170 317.860 5673.58 5724.38 3703.10 N 3716.69 W 5969747,70 N 704150.01 E 1.422 5246.59 8344.68 52.670 319.390 5730.77 5781.57 3758.86 N 3765.81 W 5969802.08 N 704099.37 E 1.399 5320.75 22 July, 2002 - 13:13 Page 4 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-D6 Your Ref: API 5002923082 Job No. AKZZ22084~ Surveyed: 20 June~ 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 DOft) 8439.48 54.170 318.400 5787.26 5838.06 3816.22 N 3815.86 W 5969858.03 N 704047.75 E 1.791 5396.69 8530.28 55.590 318.010 5839.50 5890.30 3871.59 N 3865.36 W 5969912.01 N 703996.74 E 1.603 5470.84 8624.99 56.200 318.780 5892.60 5943.40 3930.22 N 3917.42 W 5969969.18 N 703943.07 E 0.932 5549.12 - 8718.06 56.420 319.460 5944.23 5995.03 3988.77 N 3968.11 W 5970026.31 N 703890.79 E 0.652 5626.35 8812.64 56.220 317.820 5996.68 6047.48 4047.85 N 4020.11 W 5970083.91 N 703837.17 E 1.458 5704.89 8907.25 56.11 0 318.480 6049.36 6100.16 4106.38 N 4072.54 W 5970140.98 N 703783.13 E 0.591 5783.35 9000.09 55.700 317.660 6101.40 6152.20 4163.58 N 4123.91 W 5970196.73 N 703730.20 E 0.854 5860.12 9093.89 55.700 317.130 6154.26 6205.06 4220.61 N 4176.37 W 5970252.29 N 703676.18 E 0.467 5937.54 9184.88 55.400 317.350 6205.73 6256.53 4275.70 N 4227.31 W 5970305.95 N 703623.74 E 0.385 6012.51 9279.22 54.140 316.470 6260.15 6310.95 4331.98 N 4279.95 W 5970360.74 N 70~569.56 E 1.538 6089.53 9371.41 53.980 315.260 6314.26 6365.06 4385.55 N 4331.92 W 5970412.85 N 703516.12 E 1.077 6164.15 9464.56 53.4 70 313.820 6369.38 6420.18 4438.22 N 4385.44 W 5970464.02 N 703461.16 E 1.361 6239.24 9557.10 51.660 312.090 6425.63 6476.43 4488.30 N 4439.21 W 5970512.59 N 703406.03 E 2.455 6312.67 9652.05 51.700 311.720 6484.51 6535.31 4538.05 N 4494.65 W 5970560.79 N - 703349.23 E 0.309 6387.06 9747.09 50.620 311.680 6544.11 6594.91 4587.30 N 4549.92 W 5970608.49 N 703292.62 E 1.137 6460.97 9839.88 49.570 312.510 6603.63 6654.43 4635.01 N 4602.74 W 5970654.72 N 703238.50 E 1.323 6532.06 9934.40 48.340 312.370 6665.70 6716.50 4683.11 N 4655.34 W 5970701.35 N 703184.58 E 1.306 6603.27 10028.22 47.310 313.050 6728.69 6779.49 4730.27 N 4706.44 W 5970747.07 N 703132.20 E 1.222 6672.75 10118.13 47.120 312.680 6789.76 6840.56 4775.16 N 4754.80 W 5970790.60 N 703082.61 E 0.369 6738.69 10212.65 44.670 313.380 6855.54 6906.34 4821.46 N 4804.42 W 5970835.51 N 703031.74 E 2.646 6806.51 -- 10305.43 41.800 313.910 6923.13 6973.93 4865.32 N 4850.41 W 5970878.08 N 702984.55 E 3.118 6870.04 10401.69 40.670 314.220 6995.52 7046.32 4909.44 N 4896.00 W 5970920.92 N 702937.75 E 1.193 6933.48 10494.13 40.780 312.730 7065.57 7116.37 4950.93 N 4939.76 W 5970961.19 N 702892.86 E 1.058 6993.77 10588.42 39.130 313.200 7137.85 7188.65 4992.20 N 4984.07 W 5971001.21 N 702847.42 E 1.779 7054.28 10685.01 37.280 313.980 7213.75 7264.55 5033.38 N 5027.34 W 5971041.18 N 702803.02 E 1.979 7114.00 10778.93 35.860 314.200 7289.18 7339.98 5072.31 N 5067.54 W 5971078.98 N 702761.77 E 1.518 7169.95 10876.17 34.450 315.670 7368.68 7419.48 5111.85 N 5107.18 W 5971117.40 N 702721.05 E 1.691 7225.94 10963.84 31.720 316.160 7442.13 7492.93 5146.21 N 5140.47 W 5971150.83 N 702686.81 E 3.129 7273.78 11058.08 29.950 315.180 7523.04 7573.84 5180.77 N 5174.22 W 5971184.44 N 702652.12 E 1.952 7322.08 11153.68 27.360 314.790 7606.93 7657.73 5213.18 N 5206.64 W 5971215.94 N 702618.82 E 2.716 7367.92 22 July, 2002 - 13:13 Page 50(7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-06 Your Ref: API 5002923082 Job No. AKZZ22084, Surveyed: 20 June, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) CO/100ft) 11247.64 25.310 312.360 7691 .13 7741.93 5241.93 N 5236.80 W 5971243.84 N 702587.87 E 2.465 7409.58 11343.36 21.330 311.920 7779.02 7829.82 5267.36 N 5264.89 W 5971268.48 N 702559.09 E 4.162 7447.42 11437.29 18.240 310.940 7867.39 7918.19 5288.41 N 5288.71 W 5971288.87 N 702534.70 E 3.308 7479.15 11531 .22 17.400 313.470 7956.81 8007.61 5307.70 N 5310.01 W 5971307.57 N 702512.87 E 1.216 7507.85 11624.64 16.630 313.000 8046.14 8096.94 5326.43 N 5329.92 W 5971325.73 N 702492.45 E 0.837 7535.18 - 11638.50 16.500 313.410 8059.43 8110.23 5329.13 N 5332.80 W 5971328.36 N 702489.49 E 1.261 7539.13 11741.82 16.950 315.710 8158.38 8209.18 5350.00 N 5353.98 W 5971348.63 N 702467.75 E 0.775 7568.85 11834.92 16.200 314.650 8247.61 8298.41 5368.84 N 5372.69 W 5971366.94 N 702448.52 E 0.869 7595.41 11928.73 15.680 313.270 8337.81 8388.61 5386.73 N 5391.23 W 5971384.31 N 702429.49 E 0.686 7621.17 12023.83 15.040 314.470 8429.52 8480.32 5404.18 N 5409.40 W 5971401.25 N . 702410.85 E 0.751 7646.35 12096.96 14.350 312.300 8500.25 8551.05 5416.92 N 5422.87 W 5971413.62 N 702397.03 E 1.207 7664.89 12145.00 14.350 312.300 8546.80 8597.60 5424.94 N 5431.68 W 5971421.39 N 702388.00 E 0.000 7676.79 Projected SUNey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI 6. Northings and Eastings are relative to PSI 6. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI 6 and calculated along an Azimuth of 314.960° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12145.00ft., . The Bottom Hole Displacement is 7676.79ft., in the Direction of 314.964° (True). -- 22 July, 2002 - 13:13 Page 60f7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI 6 - PSI-06 Your Ref: API 5002923082 Job No. AKZZ22084~ Surveyed: 20 June~ 2002 . North Slope Alaska BPXA lisburne PSI (East Dock) Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12145.00 8597.60 5424.94 N 5431.68 W Projected Survey Survey tool program for PSI 6 - PSI-06 From To Measured Vertical Measured Vertical Depth Depth Depth Depth . (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 12145.00 8597.60 AK-6 BP _IFR-AK -" 22 July, 2002 - 13:13 Page 70f7 DrillQuest 2.00.08.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well PSI-06 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) 12,145.00' MD aoa-07C¡ 22-Jul-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED II J! 2 ~ 0002 \..i 'v' ì- .~) L Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI 6 PSI 6 - PSI-6 MWD Job No. AKMW22084, Surveyed: 20 June, 2002 .~ SURVEY REPORT 22 July, 2002 Your Ref: API 500292308200 Surface Coordinates: 5966148.95 N, 707967.83 E (70018' 39.1604" N, 148018' 52.6196" W) Kelly Bushing: 50.80ft above Mean Sea Level sper:r-aY-SUI! DRILLING seRVices A Halliburton Company Survey Ref: svy11249 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW22084, Surveyed: 20 June, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 0 Oft) 0.00 0.000 0.000 -50.80 0.00 0.00 N 0.00 E 5966148.95 N 707967.83 E 0.00 MWD Magnetic 114.00 0.000 0.000 63.20 114.00 0.00 N 0.00 E 5966148.95 N 707967.83 E 0.000 0.00 205.74 0.030 182.830 154.94 205.74 0.02 S O.ODE 5966148.93 N 707967.83 E 0.033 -0.02 - 316.60 0.130 343.500 265.80 316.60 0.07 N 0.04W 5966149.02 N 707967.79 E 0.143 0.07 384.25 0.130 356.540 333.45 384.25 0.22 N 0.06W 5966149.17 N 707967.76 E 0.044 0.20 475.94 0.670 315.450 425.14 475.94 0.70 N 0.45 W 5966149.64 N 707967.36 E 0.631 0.81 562.88 1.390 312.540 512.06 562.86 1.78 N 1.58W 5966150.68 N 707966.20 E 0.830 2.38 653.52 2.420 314.200 602.65 653.45 3.86 N 3.76W 5966152.70 N 707963.96 E 1.138 5.39 752.21 3.550 312.330 701.21 752.01 7.37 N 7.52W 5966156.11 N 707960.11 E 1.149 10.52 847.41 4.570 312.330 796.17 846.97 11.91 N 12.50 W 5966160.50 N 707955.01 E 1.071 17.26 941.83 6.130 310.250 890.17 940.97 17.70 N 19.13 W 5966166.11 N 707948.22 E 1.665 26.04 1037.87 7.870 318.520 985.49 1036.29 25.94 N 27.40 W 5966174.12 N 707939.73 E 2.089 37.71 1131.57 10.020 323.950 1078.05 1128.85 37.33 N 36.44 W 5966185.26 N 707930.37 E 2.463 52.17 1227.27 11 .440 322.860 1172.08 1222.88 51.63 N 47.07 W 5966199.26 N - 707919.34 E 1 .499 69.79 1319.42 13.910 322.500 1261.97 1312.77 67.71 N 59.34 W 5966214.99 N 707906.64 E 2.682 89.83 1413.34 17.1 00 320.070 1352.46 1403.26 87.26 N 75.08 W 5966234.09 N 707890.37 E 3.465 114.78 1506.00 22.010 320.420 1439.75 1490.55 111.10 N 94.89 W 5966257.38 N 707869.89 E 5.300 145.65 1601.54 22.200 317.800 1528.27 1579.07 138.27 N 118.43 W 5966283.89 N 707845.62 E 1.051 181.50 1695.44 21.440 317.480 1615.44 1666.24 164.06 N 141.94 W 5966309.02 N 707821.40 E 0.819 216.37 1788.35 21.110 318.190 1702.02 1752.82 189.05 N 164.57 W 5966333.37 N 707798.09 E 0.451 250.03 --.,_/ 1883.05 21.530 318.190 1790.24 1841.04 214.71 N 187.53 W 5966358.38 N 707774.43 E 0.444 284.41 1978.45 23.410 315.980 1878.40 1929.20 241.39 N 212.37 W 5966384.37 N 707748.86 E 2.160 320.84 2071 .15 28.540 315.490 1961.70 2012.50 270.44 N 240.71 W 5966412.62 N 707719.72 E 5.539 361.42 2164.86 33.140 315.460 2042.14 2092.94 304.68 N 274.39 W 5966445.92 N 707685.11 E 4.909 409.45 2259.20 33.980 316.180 2120.76 2171.56 342.09 N 310.73 W 5966482.30 N 707647.75 E 0.985 461.59 2354.60 36.670 314.310 2198.59 2249.39 381.23 N 349.58 W 5966520.35 N 707607.83 E 3.039 516.74 2450.14 35.270 315.410 2275.91 2326.71 420.80 N 389.36 W 5966558.81 N 707566.97 E 1.614 572.86 2544.04 35.960 315.260 2352.24 2403.04 459.69 N 427.80 W 5966596.62 N 707527.46 E 0.741 627.54 2639.01 41.250 314.410 2426.43 2477.23 501.44 N 469.82 W 5966637.19 N 707484.30 E 5.598 686.77 2728.89 47.070 312.670 2490.89 2541.69 544.51 N 515.22 W 5966678.99 N 707437.72 E 6.614 749.33 22 July, 2002 - 13:19 Page 20f7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW22084, Surveyed: 20 June, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 OOft) 2820.28 47.750 311.540 2552.74 2603.54 589.62 N 565.14 W 5966722.70 N 707386.58 E 1.176 816.53 2913.17 50.750 312.520 2613.37 2664.17 636.74 N 617.40 W 5966768.35 N 707333.04 E 3.327 886.80 3008.29 52.650 312.710 2672.32 2723.12 687.28 N 672.33 W 5966817.35 N 707276.73 E 2.004 961.38 - 3102.04 53.160 311.980 2728.86 2779.66 737.65 N 727.60 W 5966866.17 N 707220.08 E 0.826 1036.08 3196.57 53.310 313.950 2785.44 2836.24 789.26 N 783.01 W 5966916.22 N 707163.27 E 1.677 1111.76 3290.48 52.320 315.160 2842.20 2893.00 841.74 N 836.32 W 5966967.21 N 707108.52 E 1.471 1186.57 3379.50 52.530 317.200 2896.49 2947.29 892.65 N 885.17 W 5967016.74 N 707058.28 E 1.831 1257.10 3472.06 52.590 316.150 2952.76 3003.56 946.11 N 935.59 W 5967068.79 N 707006.40 E 0.903 1330.56 3569.17 54.380 315.250 3010.54 3061.34 1001.96 N 990.10 W 5967123.10 N 706950.36 E 1.988 1408.59 3662.99 54.680 313.540 3064.99 3115.79 1055.41 N 1044.70 W 5967175.02 N 706894.31 E 1.518 1484.99 3756.05 57.290 312.930 3117.04 3167.84 1108.24 N 1100.89 W 5967226.27 N 706836.67 E 2.857 1562.09 3850.22 55.660 315.050 3169.06 3219.86 1162.74 N 1157.38 W 5967279.20 N 706778.70 E 2.553 1640.57 3943.19 55.820 314.960 3221.39 3272.19 1217.08 N 1211.71 W 5967332.01 N 706722.88 E 0.190 1717.41 4037.43 56.570 317.050 3273.83 3324.63 1273.41 N 1266.09 W 5967386.81 N 706666.96 E 2.007 1795.70 4130.12 56.450 316.230 3324.97 3375.77 1329.62 N 1319.16W 5967441.53 N 706612.35 E 0.749 1872.96 4224.86 55.340 315.910 3378.10 3428.90 1386.11 N 1373.58 W 5967496.49 N 706556.39 E 1.205 1951.39 4316.74 54.520 316.350 3430.89 3481.69 1440.32 N 1425.70 W 5967549.24 N 706502.79 E 0.975 2026.58 4412.02 53.810 317.290 3486.67 3537.47 1496.65 N 1478.56 W 5967604.08 N 706448.39 E 1.093 2103.78 4505.16 56.440 318.840 3539.92 3590.72 1553.49 N 1529.60 W 5967659.49 N 706395.79 E 3.136 2180.07 4600.21 57.960 318.720 3591.41 3642.21 1613.59 N 1582.25 W 5967718.10 N 706341.50 E 1.603 2259.78 - 4693.67 58.030 318.140 3640.95 3691.75 1672.88 N 1634.84 W 5967775.92 N 706287.29 E 0.532 2338.89 4786.93 57.330 318.790 3690.81 3741.61 1731.87 N 1687.10 W 5967833.44 N 706233.42 E 0.954 2417.55 4879.34 57.090 319.280 3740.85 3791.65 1790.53 N 1738.03 W 5967890.67 N 706180.89 E 0.516 2495.04 4972.42 56.590 318.380 3791.77 3842.57 1849.19N 1789.32 W 5967947.88 N 706127.99 E 0.971 2572.78 5067.77 56.820 319.650 3844.11 3894.91 1909.35 N 1841.59 W 5968006.57 N 706074.07 E 1.139 2652.28 5159.80 58.020 318.530 3893.67 3944.47 1967.95 N 1892.37 W 5968063.74 N 706021.68 E 1.659 2729.62 5257.60 58.930 316.730 3944.81 3995.61 2029.53 N 1948.56 W 5968123.74 N 705963.82 E 1.824 2812.89 5350.43 58.770 314.560 3992.83 4043.63 2086.34 N 2004.09 W 5968178.99 N 705906.73 E 2.008 2892.33 5444.46 58.930 313.320 4041.47 4092.27 2142.17 N 2062.03 W 5968233.20 N 705847.26 E 1.141 2972.78 5538.03 58.060 308.820 4090.38 4141.18 2194.58 N 2122.15W 5968283.91 N 705785.72 E 4.204 3052.35 --- --- 22 July, 2002 - 13:19 Page 3 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW22084~ Surveyed: 20 June~ 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 OOft) 5632.43 57.210 309.800 4140.92 4191.72 2245.09 N 2183.84 W 5968332.70 N 705722.66 E 1.257 3131.69 5724.98 56.280 310.980 4191.67 4242.47 2295.23 N 2242.79 W 5968381.19 N 705662.34 E 1 .465 3208.84 5819.73 55.990 310.480 4244.47 4295.27 2346.57 N 2302.41 W 5968430.86 N 705601.32 E 0.534 3287.30 -- 5913.78 56.380 311.900 4296.81 4347.61 2398.03 N 2361.20 W 5968480.67 N 705541.12 E 1.321 3365.26 6006.88 56.640 313.000 4348.18 4398.98 2450.43 N 2418.49 W 5968531.46 N 705482.40 E 1.024 3442.83 6101.36 56.750 311.540 4400.06 4450.86 2503.54 N 2476.92 W 5968582.94 N 705422.53 E 1.297 3521.70 6195.25 58.120 310.420 4450.60 4501.40 2555.42 N 2536.66 W 5968633.15 N 705361.37 E 1.772 3600.64 6284.56 58.990 310.920 4497.19 4547.99 2605.08 N 2594.45 W 5968681.18 N 705302.23 E 1.085 3676.62 6340.55 59.500 311 . 1 60 4525.82 4576.62 2636.67 N 2630.74 W 5968711.76 N 705265.08 E 0.983 3724.62 6456.71 59.860 310.890 4584.46 4635.26 2702.49 N 2706.39 W 5968775.46 N 705187.64 E 0.369 3824.66 6551.18 58.340 310.840 4632.98 4683.78 2755.53 N 2767.69 W 5968826.77 N 705124.89 E 1.610 3905.51 6646.96 57.080 313.650 4684.15 4734.95 2809.94 N 2827.63 W 5968879.51 N 705063.47 E 2.807 3986.37 6738.70 55.560 314.110 4735.02 4785.82 2862.85 N 2882.65 W 5968930.88 N 705007.00 E 1.709 4062.69 6836.41 53.010 316.910 4792.06 4842.86 2919.41 N 2938.26 W 5968985.87 N - 704949.85 E 3.496 4142.01 6931.88 52.500 316.340 4849.85 4900.65 2974.65 N 2990.45 W 5969039.65 N 704896.15 E 0.715 4217.97 7025.82 52.220 318.760 4907.22 4958.02 3029.53 N 3040.65 W 5969093.12 N 704844.45 E 2.062 4292.27 7125.08 52.430 317.340 4967.89 5018.69 3087.96 N 3093.17 W 5969150.06 N 704790.33 E 1.152 4370.72 7218.21 51.630 318.540 5025.19 5075.99 3142.46 N 3142.35 W 5969203.19 N 704739.66 E 1.330 4444.03 7310.12 50.430 318.690 5082.99 5133.79 3196.07 N 3189.60 W 5969255.4 7 N 704690.95 E 1.312 4515.35 7408.00 50.150 317.080 5145.53 5196.33 3251.93 N 3240.09 W 5969309.90 N 704638.93 E 1.297 4590.54 7505.25 50.580 318.520 5207.56 5258.36 3307.41 N 3290.39 W 5969363.97 N 704587.11 E 1 .223 4665.34 7597.43 50.300 319.120 5266.27 5317.07 3360.90 N 3337.18 W 5969416.14 N 704538.85 E 0.587 4736.24 7692.76 50.740 318.910 5326.88 5377.68 3416.44 N 3385.44 W 5969470.33 N 704489.08 E 0.492 4809.64 7785.45 51.050 320.520 5385.35 5436.15 3471.31 N 3431.94 W 5969523.88 N 704441.07 E 1.389 4881.32 7880.46 51 .250 320.100 5444.95 5495.75 3528.24 N 3479.20 W 5969579.49 N 704392.26 E 0.404 4954.99 7970.36 51 .160 318.510 5501.28 5552.08 3581.37 N 3524.88 W 5969631.33 N 704345.12 E 1.382 5024.85 8063.07 52.140 317.750 5558.80 5609.60 3635.50 N 3573.41 W 5969684.10 N 704295.11 E 1.237 5097.44 8157.07 52.480 316.070 5616.27 5667.07 3689.82 N 3624.22 W 5969736.99 N 704242.81 E 1.460 5171.78 8250.91 52.170 319.520 5673.64 5724.44 3744.82 N 3674.11 W 5969790.59 N 704191.42 E 2.928 5245.94 8344.68 52.670 321.750 5730.83 5781.63 3802.27 N 3721.24 W 5969846.71 N 704142.73 E 1.959 5319.88 ----- 22 July, 2002 - 13:19 Page 4 of7 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW22084~ Surveyed: 20 June~ 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 OOft) 8439.48 54.170 320.710 5787.32 5838.12 3861.62 N 3768.91 W 5969904.71 N 704093.43 E 1.811 5395.55 8530.28 55.590 317.770 5839.57 5890.37 3917.85 N 3817.40 W 5969959.58 N 704043.40 E 3.075 5469.60 8624.99 56.200 320.510 5892.68 5943.48 3977.16 N 3868.69 W 5970017.44 N 703990.48 E 2.480 5547.80 - 8718.06 56.420 318.600 5944.31 5995.11 4036.08 N 3918.93 W 5970074.96 N 703938.64 E 1.724 5624.98 8812.64 56.220 316.410 5996.76 6047.56 4094.11 N 3972.09 W 5970131.49 N 703883.89 E 1.938 5703.60 8907.25 56.110 318.050 6049.44 6100.24 4151.80 N 4025.45 W 5970187.68 N 703828.95 E 1 .445 5782.12 9000.09 55.700 317.760 6101.48 6152.28 4208.85 N 4076.99 W 5970243.28 N 703775.85 E 0.512 5858.90 9093.89 55.700 317.050 6154.34 6205.14 4265.89 N 4129.43 W 5970298.85 N 703721.85 E 0.625 5936.32 9184.88 55.400 317.870 6205.82 6256.62 4321.17 N 4180.16 W 5970352.70 N 703669.61 E 0.813 6011.28 9279.22 54.140 316.450 6260.24 6311.04 4377.68 N 4232.55 W 5970407.74 N 703615.67 E 1.815 6088.28 9371.41 53.980 316.170 6314.35 6365.15 4431.65 N 4284.11 W 5970460.26 N 703562.64 E 0.301 6162.90 9464.56 53.470 313.750 6369.47 6420.27 4484.71 N 4337.23 W 5970511.83 N 703508.06 E 2.165 6237.98 9557.10 51.660 314.340 6425.72 6476.52 4535.79 N 4390.05 W 5970561.43 N 703453.85 E 2.020 6311.45 9652.05 51.700 313.990 6484.59 6535.39 4587.69 N 4443.49 W 5970611.83 N - 703399.00 E 0.292 6385.94 9747.09 50.620 312.240 6544.20 6595.00 4638.29 N 4497.52 W 5970660.91 N 703343.59 E 1.830 6459.92 9839.88 49.570 313.740 6603.72 6654.52 4686.82 N 4549.59 W 5970707.98 N 703290.20 E 1.679 6531.05 9934.40 48.340 310.860 6665.80 6716.60 4734.79 N 4602.29 W 5970754.48 N 703236.19 E 2.641 6602.25 10028.22 47.310 313.650 6728.79 6779.59 4781.53 N 4653.75 W 5970799.77 N 703183.45 E 2.462 6671.69 10118.13 47.120 314.770 6789.87 6840.67 4827.54 N 4701.05 W 5970844.45 N 703134.90 E 0.938 6737.66 10212.65 44.670 313.950 6855.64 6906.44 4874.99 N 4749.56 W 5970890.54 N 703085.09 E 2.666 6805.52 10305.43 41.800 315.620 6923.23 6974.03 4919.74 N 4794.68 W 5970934.02 N 703038.75 E 3.330 6869.07 10401.69 40.670 314.100 6995.62 7046.42 4964.50 N 4839.64 W 5970977.52 N 702992.56 E 1.569 6932.51 10494.13 40.780 314.100 7065.68 7116.48 5006.47 N 4882.95 W 5971018.27 N 702948.10 E 0.119 6992.82 10588.42 39.130 313.270 7137.96 7188.76 5048.29 N 4926.73 W 5971058.87 N 702903.18 E 1.839 7053.35 10685.01 37.280 316.600 7213.86 7264.66 5090.45 N 4969.03 W 5971099.84 N 702859.73 E 2.866 7113.07 10778.93 35.860 315.130 7289.29 7340.09 5130.61 N 5007.99 W 5971138.91 N 702819.68 E 1.776 7169.01 10876.17 34.450 315.250 7368.79 7419.59 5170.33 N 5047.45 W 5971177.52 N 702779.14 E 1 .452 7225.00 10963.84 31.720 314.830 7442.24 7493.04 5204.20 N 5081.26W 5971210.44 N 702744.40 E 3.125 7272.85 11058.08 29.950 316.680 7523.16 7573.96 5238.78 N 5114.97 W 5971244.07 N 702709.74 E 2.131 7321.15 11153.68 27.360 314.110 7607.04 7657.84 5271.44 N 5147.12 W 5971275.83 N 702676.70 E 3.000 7366.97 22 July, 2002 - 13:19 Page 5 of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW220841 Surveyed: 20 Junel 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) 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) (°/1 OOft) 11247.64 25.310 311.630 7691.25 7742.05 5299.82 N 5177.64 W 5971303.35 N 702645.41 E 2.4 76 7408.62 11343.36 21.330 312.350 7779.13 7829.93 5325.15 N 5205.81 W 5971327.89 N 702616.55 E 4.169 7446.45 11437.29 18.240 310.240 7867.51 7918.31 5346.16 N 5229.66 W 5971348.23 N 702592.12 E 3.376 7478.17 ~" 11531.22 17.400 312.660 7956.93 8007.73 5365.17 N 5251.21 W 5971366.64 N 702570.05 E 1.192 7506.86 11624.64 16.630 314.230 8046.26 8097.06 5383.96 N 5271.06 W 5971384.87 N 702549.69 E 0.960 7534.18 11638.50 16.500 313.950 8059.55 8110.35 5386.71 N 5273.90 W 5971387.54 N 702546.78 E 1.101 7538.13 11741.82 16.950 316.080 8158.50 8209.30 5407.74 N 5294.91 W 5971407.99 N 702525.19 E 0.736 7567.86 11834.92 16.200 314.940 8247.73 8298.53 5426.69 N 5313.52 W 5971426.41 N 702506.07 E 0.878 7594.42 11928.73 15.680 313.130 8337.93 8388.73 5444.60 N 5332.03 W 5971443.80 N 702487.06 E 0.767 7620.17 12023.83 15.040 314.300 8429.64 8480.44 5462.01 N 5350.24 W 5971460.70 N 702468.38 E 0.748 7645.36 12096.96 14.350 312.180 8500.37 8551 .17 5474.72 N 5363.75 W 5971473.03 N 702454.52 E 1.196 7663.90 12145.00 14.350 312.180 8546.92 8597.72 5482.71 N 5372.57 W 5971480.78 N 702445.48 E 0.000 7675.79 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI 6. Northings and Eastings are relative to PSI 6. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI 6 and calculated along an Azimuth of 314.960° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12145.00ft., The Bottom Hole Displacement is 7676.24ft., in the Direction of 315.5810 (True). -' -.---- 22 July, 2002 - 13:19 Page 60f7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI 6 - PSI-6 MWD Your Ref: API 500292308200 Job No. AKMW22084, Surveyed: 20 June, 2002 .1 North Slope Alaska BPXA Lisburne PSI (East Dock) Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -- 12145.00 8597.72 5482.71 N 5372.57 W Projected Survey Survey tool program for PSI 6 - PSI-6 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth . (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 12145.00 8597.72 MWD Magnetic -' 22 July, 2002 - 13:19 Page 70f7 DrillQuest 2.00.08.005 Schlumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well NK-62 ,q Î,~!1lo M-20A / q " J q 9 D.S.1-22A J Cf4- J 55 MPJ-17 J l7..;:), ()~ GNI-02 L 7" ;;) ~~ R-17A J ~- J3F: G-12A J ~ - JO~ D.S.18-29B J Lf<g -0<09 D.S.1-16 I 7 f:j( -OtJ 'Y: PSI-06 riOd .07' J-08 J Î Î. 0 LJ 1 PSI-06 ~oa-OÎ9 A-01A ~o l: a t.:;). W-07 I 'iJC(- 0 / <1 R-17A I c.¡)f-¡ ~ <¡r BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 08/01/02 NO. 2276 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job# Log Description Color Date Blueline Sepia Prints CD 07/25/02 1 07/21/02 1 07/22/02 1 07/17/02 1 07/24/02 1 07/27/02 1 07/25/02 1 07/26/02 1 07/25/02 1 07/18/02 1 07/20/02 1 07/19/02 1 07/09/02 1 07/08/02 1 07/03/02 1 ~ PROD PROFILE/DEFT LDL SBHP STATIC/PRESS W/JEWELRY TEMP SURVEY STATIC/PRESS W/JEWELRY FLOWING BHP SURVEY SBHP PSP PROD PROF/DEFT/GHOST BASE TEMP SURVEY WEA THERFORD GLS SBHP PROD PROFILEIDEFT GLS GLS -' RECE\VED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth AUG 0 9 2002 Alaska Oit & Gas Cons. commission Ancrnøge Received~(>~ , 08/05/02 Scblumbergel' NO. 2287 Alaska Data & Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503.5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Color Date Blueline Sepia Prints CD 05/07/02 07/18/02 2 OS/21/02 2 ----- H-3SA aco- Cd 5 PSI-09 dQd- Jdc..l PSI-QS ~~- () 1 9 22254 MCNL 22325 PROCESSED DSI 22320 USIT .~ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received"...;: ll- OOO~ Dote Delivered: AUG 0 9 2002 Alaska Oil & Gii5 Cons. Commission Anchorage Mud Program tor PSI-06 ) ) Subject: Mud Program for PSI-06 Date: Mon, 10 Jun 2002 13 :51 :53 -0500 From: "Tirpack, Robert B" <TirpacRB@BP.com> To: "Tom Maunder (E-mail)..<tom-:maunder@admin.state.ak.us>. "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Tom, As per our discussion this morning, listed below is the information concerning the Ugnu pore pressure and the PSI-06 mud program. In the permit, I stated that PSI-06 would drill the Ugnu with 9.5 ppg mud. This was done to balance the possible elevated pore pressure from disposal at DS-4, which is located approximately 3 miles to the South-East of PSI-06. I based this on a reservoir model that was built many years ago for DS-4 disposal. I have since investigated this model and have very low confidence in it. I feel that we will not see any influence of disposal at PSI-06. To have 9.5 ppg MW for the Ugnu, we will have artificially weight the mud. Under natural MW progression we should be at 9.1-9.2 ppg when we cut the Ugnu. I would like to propose a change to the permit and drill into the Ugnu at a lower MW. The plan would be to drill 10-20' of the Ugnu, stop, and perform a flow-check. This will allow for determination of actual pore pressure in the area and allow us to drill the remaining intervals at a lower MW. Please call with any questions. Thanks, Rob Tirpack GPB Drilling Eng 907-564-4166 office 907-440-8633 cell tirpacrb@bp.com 1 of 1 6/1 0/2002 10:56 AM ) \ .~ J' ~~I~E : f !Æ~!Æ~~~!Æ AlASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, .ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit PSI-06 BP Exploration (Alaska), Inc. Permit No: 202-079 Sur. Loc. 3847' NSL, 4436' WEL, Sec. 15, TIIN, RISE, UM Btmhole Loc. 4043' NSL, 4633' WEL, Sec. 09, TIIN, RISE, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit PSI-06. . . The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; , and the mechanical integrity (MI) of the injeètion wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, cbe~~~ Chair BY ORDER OF THE COMMISSION DATED thislitl day of April, 2002 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department ofEnviro1U11ental Conservation w/o encl. ALASKA , STATE OF ALASKA . " t AND GAS CONSERVATION COMf\;. ,~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil B Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 51' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 034631 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number PSI-06 v" Number 2S100302630-277 9. Approximate spud d~~e I W ~ Q5/~ If/2.7f, ()'l- Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12138' MD I 8621' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 ~ 54 Maximum surface 2992 psig, At total depth (TVD) 8621' / 3855 psig Setting Depth Too Bottom MD TVD MD TVD Surface Surface 114' 114' Surface Surface 6203' 4563' Surface Surface 11699' 8208' 11549' 8067" 12138' 8621' VJ6A- ifl ¡I 0 '- 1 a. Type of work B Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3847' NSL, 4436' WEL, SEC. 15, T11 N, R15E, UM (As Staked) At top of productive interval 3954' NSL, 4542' WEL, SEC. 09, T11N, R15E, UM At total depth 4043' NSL, 4633' WEL, SEC. 09, T11 N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well /' ADL 034632,646' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couolina 34" x20" 91.51# H-40 Welded 13-3/8" 68# L-80 BTC 9-518" 47# L-80 BTC-M 7" 26# L-80 BTC-M 11. Type Bond (See 20 AAC 25.025) Hole 42" 16" 12-1/4" 8-112" Lenath 80' 6169' 11665' 589' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 1294 sx AS III Lite, 603 sx 'G' 434 sx Class 'G' 162 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 MD TVD RECEIVED APR Perforation depth: measured 1 2002 AfIIka(l I GII ConI. CanmiIion AncIItrIge true vertical 20. Attachments B Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Rob Tirpack, 564-4166 21. I ~erebY certify that the foregoing is IU~ XiJ¡Pfect to the best of my ~nowl~~ge . Signed Brian Robertson 4- '¡:JP' I Title. Semor Dnlllng Engineer V ' Commission. Use Only Permit Number API Number Approval Date See cover letter 20-2 - 07:9' 50- 02. 9 - 2.. 3C> ~ ¿ L1.I~ -0 (7\ for other requirements Conditions of Approval: Samples Required 0 Yes 18 No Mud Log Required m Yes 0 No Hydrogen Sulfide Measures JgJ Yes 0 No Directional Survey Required ŒI 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: Te~+- ~o~E- -þ '3Sfo p~.~ J ,- ~1.. ~(.,~Þ.J d. ~ M. 1: T ~ e.. e..ø'~~ 0 lLC'v~ t \ (¡P J y order of I I I ') Approved By Commissioner he commission Date '-i ~ I (~ .() {~ Form 10-401 Rev. 12-01-85 Orlg\na' SÏ1)ned By 0.. R ~ G I N: ., A L Submit In Triplicate Cammy Oechsli i I I Prepared By Name/Number: Terrie Hubble, 564-4628 Date 4-/'(01-. ') ) I Well Name: I PSI-06 Drill and Complete Summary I Type of Well (producer or injector): Injector - Water Surface Location: (As Staked) Target Location: Bottom Hole Location: x = 707,968 1 Y = 5,966,149 1432'FNL,843'FVVL,Sec. 15, T11N,R15E X = 702,424 1 Y = 5,971,386 1325'FNL, 737' FVVL,Sec.09, T11N,R15E X = 702,331 1 Y = 5,971,473 1235'FNL,646'FVVL,Sec.09, T11N, R15E I AFE Number: 4P1903 I RiQ: I Nabors 27e ./ I OperatinQ days to complete: 126.0 I Estimated Start Date: 105/1/02 I M D: 112, 138' I I I TVD: 18621' I I Ground Elevation: 117.5' I 1 RKB: I I Well DesiQn (conventional, slimhole, etc.): I Big Bore / I Objective: I High rate water injection into Ivishak Gas Cap, Zones 4 through 1 Formation Markers Formation Tops MD TVDss Comments Base PF 1,934' -1,820' 8.6 ppg SV4 4,381' -3,438' 8.6 ppg SV3 5,075' -3,847' 8.6 ppg SV2 5,417' -4,049' 8.6 ppg SV1 6,068' -4,433' 8.6 ppg UG4 6,948' -4,952' 9.5 ppg; Offset Cretaceous Injection UG4 7,866' -5,494' 9.5 ppg; Offset Cretaceous Injection UG1 8,444' -5,835' 9.5 ppg; Offset Cretaceous Injection West Sak 2 9,341' -6,364' 8.6 ppg West Sak 1 9,668' -6,557' 8.6 ppg CM3 9,988' -6,750' 8.6 ppg CM2 10,837' -7,380' 8.6 ppg CM1 11,119' -7,623' 8.6 ppg THRZ 11,504' -7,975' 8.6 ppg BHRZ/LCU 11,699' -8,158' 8.6 ppg TZ4 11,699' -8,158' 7.5 ppg; HC Bearing TZ3 11,736' -8,193' 7.5 ppg; HC Bearing TZ2 11,777' -8,231' 7.5 ppg; HC Bearing BSAD 12,071' -8,508' 7.5 ppg; HC Bearing TD 12,138' -8,571' 7.5 ppg; TLSB N/A -8,621' 8.6 ppg; HC Bearing Surface TD Criteria: Based on -80' TVD below SV1 Top Intermediate TD Criteria: Casing to be set in BHRZfTZ4 transition TD Criteria: Based upon 50' TVD above TLSB PSI-06 Permit to Drill 3/29/02 I I 51.0' I I I ~ / / Page 1 ') ) CasinQrrubinQ PrOQram Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 42" Insulated 20" 91.51 # H-40 Welded -80' GL -114'/114' (34" OD) 16" 13-318" 68# L-80 BTC -6169' GL 6203' 1 4563' / 12-1/4" 9-518" 47# L-80 BTC-M -11,665' GL 11,699' 1 8,208' 8-1/2" 7" 26# L-80 BTC-M -589' 11 ,549' 1 8,067' 12,138' 18,621' Tubing 7-5/811 29.7# L-80 STL -11,515' GL 11,549' 1 8,067' Directional KOP: I 300' MD Maximum Hole Angle: Close Approach Well: Survey Program: -540 In intermediate section from 2919' to 9811' PSI-06 passes BP Close Approach guidelines. The nearest well is East Bay State-1 which is -233' well-to-well at surface and L3-01 which is -2144' at the top of the Ivishak Standard MWD Surveys from surface to TD. Mud ProQram 16" Surface Hole I Freshwater Spud Mud From Surface to -80' TVD 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 VP (lb/100ft2) 50-70 30-45 20-35 tauo (lb/10Off) >8 >6 >6 API FL (mls/30min) 35-55 30-40 16-30 pH 8.5- 9.5 8.5- 9.5 8.5- 9.5 12-1/4" Intermediate Hole I LSND From Surface Casing Shoe to Top Ivishak Zone 4 Interval Density Plastic Viscosity VP (ppg) (cp) (lb/100ft2) Initial to HRZ 9.0-9.5 / 10-15 25-30 HRZ to TZ4 9.8-10.0 10-15 20-30 tauo (lb/10Off) 4-7 4-7 10' Gel API HTH P FL (mls/30min) 6-10 4-61<12.0 pH LGS % vol <5 <5 10 10 8.5-9.5 8.5-9.5 8-1/2" Production Hole I BARADRILn From Intermediate Casing Shoe to TD Interval Density Plastic Viscosity VP tauo 10' Gel API HTH P FL pH LGS (ppg) / (cp) (lb/10Ofe) (lb/100ft2) (mls/30min) % vol Ivishak 8.8 1 0-15 17 -25 3-5 10 4-6<12.0 8.5-9.5 <5 Integrity Testing / The 13-3/8" surface casing point is expected to provide a fracture gradient of 12.5 to 13.5 ppg EMW. Fracture gradient information from offset are shown below: Well Name Formation TVDss Frac Gradient, PPG 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-06 Permit to Drill 3/29/02 Page 2 ) ) The minimum expected fracture gradient of 12.5 ppg EMW will provide more than adequate kick tolerance (216 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 Surface Casing Shoe Depth 20' minimum below shoe Test Type LOT Intermediate Casing Shoe 20' minimum below shoe FIT EMW LOT - Require minimum of 11.0 ppg to achieve -50 bbl kick tolerance / 10.0 ppg EMW / Well Evaluation Pro~ram ~ 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: MWD 1 GR 1 ACal - Realtime over entire interval. None None None Gas Detection - Entire Interval MWD / GR 1 Res - Realtime from 500' above BHRZ to section TD None USIT None Cuttings Samples and Gas Detection - from 500' above BHRZ to section TD MWD 1 GR - Realtime over entire interval PEX (AIT/HALSITLD/CNLlAMS-c) with Dipole Sonic (c&s) None None Cuttings Samples and Gas Detectio'n - Entire Interval 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 113-3/8" Surface 1 Basis: Lead: Open hole volumo/+ 350% excess in permafrost; 50% 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 (-5203' MD) Fluid Sequence & Volumes: Pre None Flush Spacer Lead Tail 75 bbls MudPUSH Viscosjied Spacer weighted to 10.0 ppg 1023 bbl 157;44 fe 11294 sks of Dowell ArticSET III-Lite at 10.7 ppg and 4.44 disk, B~T 45° I BHCT 52°, TT = 6.0 hrs 125 bbl 1700 fe I 603 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 disk, BHST 90° I BHCT 86°, TT = 4 hrs PSI-06 Permit to Drill 3/29/02 Page 3 ) ) Casing Size 19-5/8" Intermediate Basis: Lead: None Tail: Open hole volume + 500/0 excess + 82' shoe t1ck volume Tail TOC: 1000' above 9-5/8" shoe (-10,699' MD) Flu id Sequence & Volumes: Pre 10 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 50 bbls MudPUSH Vi~cosified Spacer weighted to 11.5 ppg None I 90 b~1 / 503 fe / 434 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 + 50% Excess + 82' shoe track + 150' liner lap + 200' of 9-5/8" x 5" DP annulus volume. j Tail TOC: -11,549' MD (' TVD).- Liner top. Fluid Sequence & Volumes: Pre 30 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None ( 35 bbl / 190 ft~ 162 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 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. . 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 PSI-06 Permit to Drill 3/29/02 20", 2M Diverter (Hydril - MSP) 2041 psi (8.6 ppg @ 4563' TVD) 1585 psi N/A Function test 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril- GL) 3671 psi (8.6 ppg @ 8208' TVD) 2850 psi (.10 psi/ft gas gradient to surface) / 158 bbls Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure Page 4 ) ) Production Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Planned completion fluids 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3855 psi (8.6 ppg @ 8621 TVD) 2992 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 3,500 psi/250 psi. I Annular test to 2,500 psi/250 psi 3500 psi surface pressure 8.4 ppg Seawater / 6.8 ppg Diesel Disposal . 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 D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . PSI-06 Permit to Drill 3/29/02 Page 5 1 ') ,I Drill and Complete Procedure Summary Pre-RiQ Work: 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. RiQ Operations: 1. MIRU Nabors 27e. /' 2. Nipple up and function test diverter system. 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 6203' MD 1 4563' TVD. The actual surface hole TD will be +1-80' 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 primary cementing operations. 5. ND diverter system and NU casing 1 tubing head. NU BOPE and test to 3500 psi. ./ / 6. MU 12-1/4" drilling assembly with MWD/GR/Res 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 Leak Off Test. / 8. Drill ahead as per directional plan, in9'reasing mud weight to 9.6 ppg prior to entering the Ugnu intervals. Increase mud weight again to 10.0 ppg prior to entering the HRZ. Short trip as required. 9. TD the 12-114" interval in the)0p of Zone 4. Control drill across the BHRZ to see the top of Zone 4. 10. Run and cement the 9-5/8", 47# intermediate casing to 1000' 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 9-518" annulus as required. ./ 11. RU E-line. RIH with USIT. Log bottom 1000' MD of wellbore. Determine TOC. POH, RD E:.line. 12. MU 8-1/2" drilling assembly with MWD/GR and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. 13. Drill out shoe joints and 2~ of new formation. Formation Integrity Test will be the 10.0 ppg MW in the hole. Displace hole over to 8.8 ppg BARADRILn fluid. / 14. Drill ahead as per directional plan to proposed TD at 12,138' MD 1 8621' TVD. The actual TD of the well will extend +1-60' TVD below the BSAD, but no deeper than 50' TVD above the TLSB. Short trip as required and condition hole for running the 7" lin~ 15. Run and cement the 7",26# liner. The liner will extend up into the 9-5/8" casing -150' MD and will be fully cemented to the liner top. j>isplace cement with inhibited seawater. 16. Test wellbore to 3500 psi for 30 minutes. POH laying down drill pipe. 17. Run 7-5/8", IPC, Flush-joint, injection string. 18. Sting into 7" tie back sleeve. Set packer. 19. Sheer out of PBR. PU and space out. Make up tubing hanger. 20. Circulate Freeze protection. 21. Land Tubing hanger. Allow diesel to U- Tube in annulus. 22. Pressure test tubing and annulus to 3500 psi for 30 mins. 23. ND BOPE. NU tree and test to 5000 psi. 24. Set BPV, RDMO. Post-Riq Work: 1. Clean-up location as required. 2. Perforate and stimulate Ivishak intervals as required. 3. POI. PSI-06 Permit to Drill 3/29/02 Page 6 ) ) Job 1: MIRU Hazards and Contingencies )p> The rig move will involve no surface close approach hazards with adjacent wells. The PSI-06 well will be drilled from an existing pad with only one other well on the location: East Bay State #1, an exploration well drilled in 11/74. EBS#1 was DST'd and then suspended with a CIBP @ 9)ØO' MD and 100sx of cement. )p> 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. l1Ø)m,:mmm,,~¡,"'¡'.:':¡;¡¡imm~,wmm::J..W:-,:;;¡'-Å:¡'J'¡¡,;,~,I.;J¡;;;":p;,:¡¡.¡m¡¡¡.m,m!<),:wmm.Ol9mm,.,I}.I,:m,:mm;,~,m,,,»",,:m,:mm¡').IAAI.~Jmffl,*.wm,:;).:¡.)~¡.-¡,,~,.¡.;~m,:m~.t¡1J(;'¡'.-,I¡',-¡J;¡'¡¡;"I~\~:,I;mmm,:¡I.)wmmm,lJ,wm;.w,D.I:4;;ß¡;;;,I,o;¡,I;mmm;'lmMffmmJmmml¡.)fflml,:,I),:,;:'¡n:¡.,:m¡¡,I'.:m",:'¡;,il;~~mm.D,DJ.!m,:,lu~m,:U;)m,I<..-U.~,"'-AI;¡mmJm!m¡.-m.:;mm;';'..,I;,lmm.:mm;¡.¡,:¡>~:;;,:~, Job 2: Drill Surface Hole Hazards and Contingencies )p> No fault crossing are expected in the surface interval. ) )p> There are no close approach issues along the PSI-06 well path. which is -233' well-to-well at surface. )p> Gas hydrates were not observed at the only other well on the pad, East Bay State #1, but offset pads in the area have experienced gas hydrates. Preparations should be made to handle gas hydrates at PSI-06. Typically, hydrates are encountered near the base Permafrost and extend down to the SV1 sand. Associated Hydrate drilling problems can be minimized by pre-treating the mud system with Driltreat (Lecithin). Additional measures included reduced flow rates and keeping the mud temperature cool «60 degrees if possible). Refer to Baroid mud recommendations. » 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 zones have NOT been observed in offset wells and is not expected at PSI-06. The nearest well is East Bay State #1, ~1,1,,~I,~I,I.I.,,~!,WA:t;Inl..).a,a.a~:I,:,-;,-J-¡'-.,;.~:,.~'",-,~»m.I),O,:,I.l.,II.I..,ir'I,:;~'IJIAI.I.:;,r;'~.\I'm.a,IAlm,lmm,lI,U",I,\I;-AI,~~I.I'-,I~I';,I¡,I~I;,I,I.I',I-,I,\I.,I,\IMI.I,I,IImlm,I,'I.II,\lm,I,\~:,-,:.aI,I,r:,-,-,:,::"IA~m,I,\~:,:,';;,lm,I.l.I.D.;.D.I"rA:ml.l,I"I,~I.I,I,~,I.D.I.I.I,:,-,'-.D.I,\-AI,:,1;,-';':,1.1:,1,1,1';,1,\1,:1.\1,1,1,:,1),1.1.1,1.1),1,1,:,\1.1.1.1.11,1,\IAI,\:A:'-,~-,:AIA\\I;,~","-I,\~.,I,W.~~I,I..,:,I,IJ,~:,.IA.D.I.D.I,\~I,\CI,':'I,\I.lIAI,llm.l,I,:),I,:m,-;,I¡,I.u;.I~I¡,:..:"I;A,I.I.I.D.I.D.I.I.:,I,I,\I!),~lm-.l.-¡m¡mAI.\I,:,I.II,I,IAI,~1~,-.D.,.I.I,I,.I,,I.;lm~.Ic,I),:,-,-AI:.:,I':OØ:D.I,\IAI.I,I,w,~- Job 3: Install 13-3/8" Surface CasinQ Hazards and Contingencies / )p> It is critical that cement is circulated to surface for well integrity. 3500/0 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. )p> Hole cleaning will be difficult in the 16" hole with 5" DP. Maintain adequate viscosity and high flow rates. Short trip as required. )p> 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 -80'TVD below SV-1 sand. I. '1""1'" \\, ,1111 11111- ,nUlr- fl,1. _U.I Job 4: Drill Intermediate/Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-06 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. As a precaution, raise MW to 9.6 ppg before entering the Ugnu. Monitor well for any sign of overpressure. PSI-06 Permit to Drill 3/29/02 Page 7 ) ') ~ 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 103 bbls assuming a kick while at the section TD (-11,699' MD / 8208' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 11.5 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 HRZ/Zone 4 transition. . If HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing./ If too much of Zone 4 is drilled, LC could be encountered due to the low pore pressure in Zone 4 (7.5 ppg). ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. ~ralara_llll,a:I,!:_~a:a_:mll:mllamllll,lmm::llmll,II:1IC_'_UICllml:',IIIIO:UUmlmmlllll"III:llm,m"t«>:m:IIII:II:1:II:allll:aIII,IIClmla:Iwmmllllmlllllmllmammllll-l_I__111¡~.'''''I!'.'',''',(:I,!::m_I_:_I''I~~'+'''''''':r'¡l!,!lm:,I!I_lm.!.II,mll 1II1I111:llIll¡.llalll,I'I,1I1,:Ie+l+lml:III::,I: _mmlmm"lmll:III:I':II::III,mlmwmll::I::-P.A-LCL_--~. .'¡::":::::..>C11W...I.llmaCllllaamll,m:III'- -',1 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 / tripping practices to minimize the time the pipe is left stationary. ~ Verify the floats are holding prior to 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-06 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 pre~sure 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. » Drilling Close Approach: All offse wells pass BP Close Approach guidelines. Job 8: LoCI 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. PSI-06 Permit to Drill 3/29/02 Page 8 ) ) Job 9: Install 7" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. ~ 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. r-t'~'t_-.-..~..\,"'-"':I. ~~,~"";'¡"';'¡':,;'¡,~!MI,'-~:,,,\I,W;~,..-,r..+.;':';":'¡'N~ ~~,W\"""..ì¥l'1':'1:,\'-.,,\.' _Vffm~~'f_-----'-,w.¡;.;.,.,'"r;,~:;';'~-,~:'-,:.,.'-M4,;' ,,\'r'rn:~fÑ'i,...r,¡¡.¡..;.¡';"¡':';;.A-;'¡";;";*,~,,;.+,;,;,.,.;,;..,*"";';-A,.:,,~OO¡'~A~~I,~.,I.,",,~"~-';',';';';\,;,;,~"" -'-.\",~~r:r- Job 12: Run Completion Hazards and Contingencies ;;.. 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. ;;.. 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 with all rig team members prior to starting the job. ;;.. 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. ;;.. 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. ,. --II--::~::!llm~11m:m!'lnlm~:lnlml- .:. --1--:-- --'I'oII'1I11UlllmMo:nl.':! .11. '.1: .1_- ~:- _1:--:-----mll~:II:-: :--IIIII"II!I. "11',111111'~: .11 Job 13: ND/NU/Release RiQ Hazards and Contingencies ;;.. 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. i,,-m;",.I.-¡,IÁ',I,I~,;,'.I.-,:¡¡¡!,:I,ij,¡;,;.Jm,m.mmm,-;.J;:¡.;:mmm.,-,',.',-,:,-m-.a,-,-:¡,-¡'!,-.Io,I,-,;mm,.,-mm;,1m:m¡.;;mm~,wmmm¡';':.:mm,-,-¡p¡¡,I;m.-¡,I;,-,:¡.;m.;.I¡.;!mU",.lmmmAAlJI,lma¡.;,;:,-:;,-,-"-,-,-¡,,-:mm-,,I,,~;,-m¡,I,IJ¡,I,I¡~)¡',I¡';;I;.I.¡'mI,I,:!,\I,I,I.D,I,¡;;,-¡¡..-¡m,-,I,,-m¡,;,-.:mmlJ,-,lmmmm,l.l.I,I.I.I,IJW.I.I,:,I,I.I,I.I,IA).:)AAJ¡,-¡.I.:,-J,I,I.I,lm;,iI,,-.I,I,:;,Im;¡¡"'!,I;~,1,I.D.I,I,W,I,I!,I,\:,-:ß,-W¡::,-':¡¡',-¡,I"I,I;,I,lm,l;m.w;AAw>,"!;;'-,-:,-,-,-J;'\-,m.I,I,;.I;,IJ.D.~¡.w!,\:,-lIJm.I,I.,~:"-;¡,-,-¡'¡,-¡;,I,~.I,,:~m~m.1J PSI-06 Permit to Drill 3/29/02 Page 9 ) ') PSI-06 Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were not observed at the only other well on this pad, East Bay State #1, but offset pads in the area have experienced gas hydrates. Preparations should be made to handle gas hydrates at PSI-06. 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. . I ntermediate Hole Section: . Fault crossings are not expected along the PSI-06 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. As a precaution, raise MW to 9.6 ppg before entering the Ugnu. Monitor well for any sign of overpressure. . The directional plan has been built to minimize directional work and tangent angle in the HRl. With the current directional plan, raise MW to 10.0 ppg before entering the HRl 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 103 bbls assuming a kick while at the section TD (-11,699' MD / 8208' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 11.5 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 HRZ/lone 4 transition. If HRl is left open while drilling the Ivishak, hole problems can be encountered due to the HRl sloughing. If too much of Zone 4 is drilled, LC could be encountered due to the low pore pressure in lone 4 (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-06 Permit to Drill 3/29/02 Page 10 d 1500 3000 E ;¡:: 0 ~ .c ë- Q 'fl 4500 'E > ... ::> ¡:: 6000 7500 9000 COMPANY DETAILS REfERENCE INFORMATION UP Amoco Co-<>n\joaù> (N'EJ Refereoœ: Wen Ceme: PSI 6. Tm< North Verti<al (lVD) Refereoœ: RKB Est 50.00 Sect;oo (VS) Refereoœ: SIot- (O.OON.O.OOE) Measured Depth Refereoce: RKB Est 50.00 CakuIatioo Melboci Minimum Curvature Cal,ul.!ItOO M.:thCII:l: Mmimwn Cur..arl!re Error S)"$tem: ISCWSA $<an MCIOOð: T rav CyliOO:r North Frror Surface: Elliptical ~ C~-mg Warn;"" Me100ð: Kuie. Bas<d 0 A Stan Dir 1/100': 300' MD, 300'TVD Stan Dir 2/100': 600' MD, 599.86'TVD 8° End Dir : 1799.42' MD, 1750' TVD Stan Dir 3/100' : 2023.86' MD, 1950'TVD ~ B Penna frost -ç; . ~ ~ EndDir : 2919.15'MD,2625.4'TVD 0 1500 3000 4500 6000 Vertical Section at 314.95° [I 500ft/in] SURVEY PROGRAM Plan: PSI 6 wp06 (PS! 6/Plan PSI 6) D<pth Fm Depth To Survey,1'1an 30.00 1000.00 PIanœd: PSI 6 "J>06Vl 1000.00 12\38.41 PIanœd: PSI 6 "J>06 VI Tool Created By: Ken Allen Checked: Date: Date: 3/26/2002 CB-GYRO-SS MWD-'-IFR+MS Reviewed: Date: WElL DETAIlS Name ~NI-S Northing Longituœ Slot Easting Latituœ +EI-W PSI 6 103.70 210.00 5966148.85 707968.05 70"18"39.159N IWI8'52.6I3W N'A TARGET DETAILS Naiœ PSI 6 TI PSI 6 PolygonBH PSI 6 BH TVD Northing fasting Shape 702424.00 Point 70220850 Polygon 702314.57 Point ->Nf-S +EI-W 8208.00 5388.95 -5397.16 5971386.00 8621.00 5599.85 -5606.91 5971591.00 8621.00 5495.00 -55ill.70 5971489.05 SECTION DETAILS See MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec Target I 111.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 2 11111.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 r,IIII.OO 3.00 314.96 599.86 5.55 -5.56 1.00 314.96 7.85 4 1 ;"').42 26.99 314.96 1750.00 223.22 -223.53 2.00 0.00 315.91 5 -'".' 1.86 26.99 314.96 1950.00 295.19 -295.61 0.00 0.00 417.76 6 _"ll'). I 5 53.85 314.96 2625.40 701.60 -702.61 3.00 -0.01 992.93 7 ";"11.80 53.85 314.96 6691.65 4633.96 -4640.97 0.00 0.00 6558.37 8 11'''.''16 20.00 314.95 8025.00 5341.89 -5350.02 2.00 -180.00 7560.33 9 11,.-.1(.90 20.00 314.95 8208.00 5388.80 -5397.3 I 0.00 0.00 7626.94 PSI 6 TI -' IO I..:L'~!.41 20.00 314.95 8621.00 5495.00 -5503.70 0.00 0.00 7777.26 CASING DETAILS No. TVD MO Size Name I 2 3 4563.00 6203.55 I3 3/8" 8208.00 II698.90 95/8" 8621.00 12138.41 7" 13.375 9.625 7.000 FORMATION TOP DETAILS No. TVDPath MOPath Formation I 1870.00 1934.08 B Permafrost 2 3488.00 4381.34 SV4 3 3897.00 5074.63 SV3 4 4099.00 5417.03 SV2 5 4483.00 6067.95 SVI 6 5002.00 6947.70 UG4 7 5544.00 7866.43 UG3 8 5885.00 8444.45 UGI 9 6414.00 934I.I5 WS2 10 6607.00 9668.30 WSI II 6800.00 9988.14 CM3 12 7430.00 10836.78 CM2 I3 7673.00 II II9.00 CMl 14 8025.00 I 1504. I 6 THRZ 15 8208.00 II 698.90 BHRZJTSAD/LCUrrz4 16 8243.00 I 1736. I 5 TZ3rrCGL 17 8281.00 II 776.58 TZ2C1BCGL 18 8336.00 II835.1 I TZ2B/23SB --' 19 8558.00 12071.36 BSAD All TVD depths are ssTVD plus 50' for RKBE. W52 Stan Oir 21100' : 9811.8'MD, 6691.65'TVD ~'SI CM3 11900\ ° CMI ,1.11< End Oir : 11504.16' MD, 8025' TVD THRZ 'llf ~ ~~õrolLcurrZ4 ~ ,lIS" ----- TZ2CIBCGL ~TZ2B!23SB 120\0 \ BSAD 7" fotaIDepth: 12138.41' MO, 8621' TVD 7500 I 9000 bp 0 c ~ 0 g 3000 +' :;:: t:: ~ :;:: :í 0 CIJ COMPANY DETAII.S REFERENCE INFORMATION SURVEY PROGRAM Tool BPAmo.:l1 Co-ordina'" (NiE) Ref<rence: WeD Centre: PSI 6. True North Verti<.'31 (JVD) Rel<rence: RKB Est 50.00 Sectioo (VS) Rel<renœ: Slot - (O.OON.O.OOE) Measured Depth Reference: RKB Est 50.00 Cakulaoon Method: Minimum CUrvature Depth Fm Depth To Su,\'eyiPlao 30.00 1000.00 PIanoOO: PSI 6 wp06 VI 1000.00 12138.41 PIanoOO: PSI 6 wp06 VI CB-GYRO-SS MWD-'-IFR~MS Cak1Jlati..1f1 Mctt)(xi; Mmirnurn C'tuyature ~r: i1~~~~ ~~~~~~[)(1:r Nor1h Error Surra;;c:: El1tpucal ~ Casing WAmi"" 1>1<11>.,1: Rul..lla500 No. TVD 1 2 3 Total Depth: 12138.41' MD, 8621' TVD PSI 6 BH PSI 6 TI End Dir : 11504.16' MD, 8025' TVD PSI 6 wpO 7" 850 9 5/8" 80)0 , 750) 5000 ¡ Start Dir 2/100' : 9811.8' MD, 6691.65'TVD 4000 2000 -- --- - - ~--'+--7': -'S~21- 1000 ---- '- -5700 -5600 -5400 -5300 -5500 0 West(- )fEast(+) [I OOftlin] ---r-[ I I l -5000 I -4000 I -3000 -6000 CASING DETAILS MD Name 4563.00 6203.55 13 3/8" 8208.00 11698.90 95/8" 8621.00 12138.41 7" 5600:s ;¡:: 0 0 +' 5500:;:: t:: 0 ~ :;:: :í 5400 ~ -2000 West(-)Æast(+) [1000ftlin] Narœ +N'-S WELL DETAilS Northing lliting ~EI-W Size Created By: Ken Allen Checked: Re,;ewed: Plan: PSI 6 wp06 (PSI6IPlan PSI 6) Latituœ Dale: 3/26/2002 Dale: Dale: 13.375 9.625 7.000 TARGET DETAILS 707968.05 70"18"39.l59N 148"18"52.613W N'A Loogitud< Slot PSI 6 103.70 210.00 5966148.85 Narœ IVD -N'-S .;.EI-W Northing Easliog Shape PSI 6 11 8203.00 5388.95 -5397.16 5971386.00 702424.00 Point PSI 6 PolygooBH 8621.00 5599.85 -5606.91 5971591.00 70220350 Polygon PSI 6 BH 8621.00 5495.00 -5503.70 5971489.05 70231457 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E!-W DLeg TFaee VSec Target 1 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 600.00 3.00 314.96 599.86 5.55 -5.56 1.00 314.96 7.85 4 1799.42 26.99 314.96 1750.00 223.22 -223.53 2.00 0.00 315.91 5 2023.86 26.99 314.96 1950.00 295.19 -295.61 0.00 0.00 417.76 6 2919.15 53.85 314.96 2625.40 701.60 -702.61 3.00 -0.01 992.93 7 9811.80 53.85 314.96 6691.65 4633.96 -4640.97 0.00 0.00 6558.37 8 11504.16 20.00 314.95 8025.00 5341.89 -5350.02 2.00 -180.00 7560.33 -.-' 9 11698.90 20.00 314.95 8208.00 5388.80 -5397.31 0.00 0.00 7626.94 PSI 6 TI 10 12138.41 20.00 314.95 8621.00 5495.00 -5503.70 0.00 0.00 7777.26 All TVD depths are ssTVD plus 50' for RKBE. ~ ~50 EndDk . 2919.I5'MD.2625.4'TVD I Start Dir 3/100': 2023.86' MD, 1950'TVD End Dir : 1799.42' MD, 1750' TVD 2000 "\.. Start Dir 2/100' : 600' MD, 599.86'T" 150°"v Start Dir 11100" 300' MD 300'T 000 ., -1000 0 I 1000 FORMA nON TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 1870.00 3488.00 3897.00 4099.00 4483.00 5002.00 5544.00 5885.00 6414.00 6607.00 6800.00 7430.00 7673.00 8025.00 8208.00 8243.00 8281.00 8336.00 8558.00 1934.08 4381.34 5074.63 5417.03 6067.95 6947.70 7866.43 8444.45 9341.15 9668.30 9988.14 10836.78 11119.00 11504.16 11698.90 11736.15 11776.58 11835.11 12071.36 B PermaITost SV4 SV3 SV2 SV1 UG4 UG3 UGl WS2 WS1 CM3 CM2 CM1 THRZ BHRZITSADILCUffZ4 TZ3rrCGL TZ2C/BCGL TZ2B/23SB BSAD ~ ) BP Planning Report - Geographic çQmpany. Field: . Site; . Well:. . Wellpath. . Field: Dåte. . 3/26/2002. Tilrie.. 10:49:31. . CQ;'or4iït"te~E)1~.der~nçe: VVell:P$16; True N9r;th Yertiçal (TY))rR~fere~çe:. RKB Est5q~O. .. . S.e~tìòn (YS) Referel1ce: .. Well (O.OON;p.OOE,314;95Azi) Plan: . .... P$F6 wp06 . .. . . . BP Amoco . Lisburne .. . . . . East.Doc.k (PSI) .PSI6. .. PlanPSI6 Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: East Dock (PSI) ) Alaska, Zone 4 Well Centre BGGM2001 Site Position: Northing: 5966039.39 ft Latitude: 70 18 38.139 N From: Map Easting: 707761.01 ft Longitude: 148 18 58.739 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 20.00 ft Grid Convergence. 1.59 deg Well: PSI6 Slot Name: Surface Position: +N/-S 103.70 ft Northing: 5966148.85 ft Latitude: 70 18 39.159 N +E/-W 210.00 ft Easting: 707968.05 ft Longitude: 148 18 52.613 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 103.70 ft Northing: 5966148.85 ft Latitude: 70 18 39.159 N +E/-W 210.00 ft Easting: 707968.05 ft Longitude: 148 18 52.613 W Measured Depth: 30.00 ft Inclination: 0.00 deg Vertical Depth: 30.00 ft Azimuth: 0.00 deg Wellpath: Plan PSI 6 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: RKB Est 8/30/2001 57516 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 50.00 ft Plan: PSI6 wp06 Date Composed: Version: Tied-to: Principal: Yes Plan Section Information Well Ref. Point 0.00 ft Mean Sea Level 26.80 deg 80.85 deg Direction deg 314.95 3/26/2002 1 From Well Ref. Point MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 3.00 314.96 599.86 5.55 -5.56 1.00 1.00 0.00 314.96 1799.42 26.99 314.96 1750.00 223.22 -223.53 2.00 2.00 0.00 0.00 2023.86 26.99 314.96 1950.00 295.19 -295.61 0.00 0.00 0.00 0.00 2919.15 53.85 314.95 2625.40 701.59 -702.62 3.00 3.00 0.00 -0.01 9811.80 53.85 314.95 6691.65 4633.83 -4641.10 0.00 0.00 0.00 0.00 11504.16 20.00 314.95 8025.00 5341.74 -5350.18 2.00 -2.00 0.00 -180.00 11698.90 20.00 314.95 8208.00 5388.80 -5397.31 0.00 0.00 0.00 0.00 12138.41 20.00 314.95 8621.00 5495.00 -5503.70 0.00 0.00 0.00 0.00 Target PSI 6 T1 Section 1: Start Hold MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ') BP ) Planning Report - Geographic .çolnpaoy: BPAmQco. Date: 3/26/2002 ... ThIÚ~. . 10:49:31 .. .. Field: LisblÏrhe. . COiordiria~e(NE)~ef~rence.'vveH;p$16,.True North. . ~ite:.. . Ec:l~tDock(p$1) . 'Vertica,1 rI'VI)Reference:. RKBEst50;0 . ...... .WeUi . PSl6 .. . . Sectiori{VSjRefer~rice: Wen. (O;OON ;0,00E,314.95Azi) . WëlJpath: .. Plåh P$16. Plån: ... . . PSI6Wp06 . ... . Section 2: Start Build 1.00 ~MD Incl Azim ..TVD +N/-S +E/.;W. VS .. DLS. . Build.. Turn. TFO ft deg deg ft . ft ft ft ~ëg/1 OOft dëg/1 pOftdeg/tOOft deg 400.00 1.00 314.96 399.99 0.62 -0.62 0.87 1.00 1.00 0.00 0.00 500.00 2.00 314.96 499.96 2.47 -2.47 3.49 1.00 1.00 0.00 0.00 600.00 3.00 314.96 599.86 5.55 -5.56 7.85 1.00 1.00 0.00 0.00 Section 3: Start Build 2.00 MD Ind AzilÏl TVD .+N/,;,S +E/~W VS DLS . Build., Turn.. . TFÒ ft deg deg ft ft ft ft deg/100ft deg/1QOft deg/1QOft deg . . 700.00 5.00 314.96 699.61 10.48 -10.49 14.83 2.00 2.00 0.00 0.00 800.00 7.00 314.96 799.06 17.86 -17.89 25.28 2.00 2.00 0.00 0.00 900.00 9.00 314.96 898.08 27.70 -27.74 39.20 2.00 2.00 0.00 0.00 1000.00 11.00 314.96 996.56 39.97 -40.02 56.56 2.00 2.00 0.00 0.00 1100.00 13.00 314.96 1094.37 54.66 -54.73 77.35 2.00 2.00 0.00 0.00 1200.00 15.00 314.96 1191.39 71.75 -71.85 101.54 2.00 2.00 0.00 0.00 1300.00 17.00 314.96 1287.51 91.23 -91.35 129.10 2.00 2.00 0.00 0.00 1400.00 19.00 314.96 1382.62 113.06 -113.22 160.00 2.00 2.00 0.00 0.00 1500.00 21.00 314.96 1476.58 137.23 -137.42 194.20 2.00 2.00 0.00 0.00 1600.00 23.00 314.96 1569.29 163.70 -163.92 231.66 2.00 2.00 0.00 0.00 1700.00 25.00 314.96 1660.64 192.44 -192.70 272.33 2.00 2.00 0.00 0.00 1799.42 26.99 314.96 1750.00 223.22 -223.53 315.91 2.00 2.00 0.00 0.00 Section 4: Start Hold MD Incl Azim TVD +N/'-S +E/.;W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1 OOft. deg/1 Opftdeg/1 OOft deg 1900.00 26.99 314.96 1839.63 255.48 -255.83 361.55 0.00 0.00 0.00 0.00 2000.00 26.99 314.96 1928.74 287.54 -287.94 406.93 0.00 0.00 0.00 0.00 2023.86 26.99 314.96 1950.00 295.19 -295.61 417.76 0.00 0.00 0.00 0.00 Secti~n 5: Start DLS 3.00 TFO -0.01 MD Incl Azim TVD +N/.;S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1 OOftdeg/1 OOff deg 2100.00 29.27 314.96 2017.14 320.56 -321.01 453.66 3.00 3.00 0.00 -0.01 2200.00 32.27 314.96 2103.05 356.71 -357.21 504.81 3.00 3.00 0.00 -0.01 2300.00 35.27 314.96 2186.17 395.98 -396.54 560.40 3.00 3.00 0.00 -0.01 2400.00 38.27 314.96 2266.26 438.27 -438.90 620.25 3.00 3.00 0.00 -0.01 2500.00 41.27 314.96 2343.11 483.47 -484.16 684.22 3.00 3.00 0.00 -0.01 2600.00 44.27 314.96 2416.51 531.45 -532.21 752.12 3.00 3.00 0.00 -0.01 2700.00 47.27 314.96 2486.25 582.07 -582.91 823.77 3.00 3.00 0.00 -0.01 2800.00 50.27 314.95 2552.15 635.21 -636.13 898.97 3.00 3.00 0.00 -0.01 2900.00 53.27 314.95 2614.02 690.70 -691.72 977.52 3.00 3.00 0.00 -0.01 2919.15 53.85 314.95 2625.40 701.59 -702.62 992.93 3.00 3.00 0.00 -0.01 Section 6: Start Hold MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ff deg/100ff deg 3000.00 53.85 314.95 2673.09 747.71 -748.82 1058.21 0.00 0.00 0.00 0.00 3100.00 53.85 314.95 2732.09 804.76 -805.96 1138.95 0.00 0.00 0.00 0.00 3200.00 53.85 314.95 2791.08 861.81 -863.10 1219.70 0.00 0.00 0.00 0.00 3300.00 53.85 314.95 2850.07 918.86 -920.24 1300.44 0.00 0.00 0.00 0.00 3400.00 53.85 314.95 2909.07 975.91 -977.38 1381 . 19 0.00 0.00 0.00 0.00 3500.00 53.85 314.95 2968.06 1032.96 -1034.52 1461.93 0.00 0.00 0.00 0.00 3600.00 53.85 314.95 3027.06 1090.01 -1091.66 1542.67 0.00 0.00 0.00 0.00 3700.00 53.85 314.95 3086.05 1147.06 -1148.80 1623.42 0.00 0.00 0.00 0.00 3800.00 53.85 314.95 3145.04 1204.11 -1205.94 1704.16 0.00 0.00 0.00 0.00 3900.00 53.85 314.95 3204.04 1261.16 -1263.08 1784.91 0.00 0.00 0.00 0.00 4000.00 53.85 314.95 3263.03 1318.21 -1320.22 1865.65 0.00 0.00 0.00 0.00 4100.00 53.85 314.95 3322.03 1375.26 -1377.36 1946.40 0.00 0.00 0.00 0.00 4200.00 53.85 314.95 3381.02 1432.31 -1434.50 2027.14 0.00 0.00 0.00 0.00 4300.00 53.85 314.95 3440.01 1489.36 -1491.64 2107.89 0.00 0.00 0.00 0.00 4400.00 53.85 314.95 3499.01 1546.41 -1548.78 2188.63 0.00 0.00 0.00 0.00 4500.00 53.85 314.95 3558.00 1603.46 -1605.92 2269.38 0.00 0.00 0.00 0.00 ) BP Planning Report - Geographic ) CQJIlpany: BPAmoco .F:ield; . . Lisburne. .. . . Site: . . J;astQock (PSI) Well: PSI6. .. . 'Wellpatb: PlànPSI6.. Section 6: Start Hold Dåte:3/26/2002 . Time:. 10:49:31 . Ço:-oJ,"dinate(NEJR.eference: Wëll: .PSI. 6; True.. North V~r~ica;1 (I.'YO) ~eference: RKB Est50~0 . ..... . . Se~tiön(VS) Reference:. WeH(0;00N,O.00E,314.95Azi) Plan: .. . . . PSI6Wp06 .. MD ft 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9811.80 In cI . deg 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 Azim deg. . 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 314.95 TVD ft 3617.00 3675.99 3734.99 3793.98 3852.97 3911.97 3970.96 4029.96 4088.95 4147.94 4206.94 4265.93 4324.93 4383.92 4442.92 4501.91 4560.90 4619.90 4678.89 4737.89 4796.88 4855.87 4914.87 4973.86 5032.86 5091.85 5150.84 5209.84 5268.83 5327.83 5386.82 5445.82 5504.81 5563.80 5622.80 5681.79 5740.79 5799.78 5858.77 5917.77 5976.76 6035.76 6094.75 6153.75 6212.74 6271.73 6330.73 6389.72 6448.72 6507.71 6566.70 6625.70 6684.69 6691.65 +N/;'S ft 1660.51 1717.56 1774.61 1831.66 1888.71 1945.76 2002.81 2059.86 2116.91 2173.96 2231.01 2288.06 2345.11 2402.16 2459.21 2516.26 2573.31 2630.35 2687.40 2744.45 2801.50 2858.55 2915.60 2972.65 3029.70 3086.75 3143.80 3200.85 3257.90 3314.95 3372.00 3429.05 3486.10 3543.15 3600.20 3657.25 3714.30 3771.35 3828.40 3885.45 3942.50 3999.55 4056.60 4113.65 4170.70 4227.75 4284.80 4341.85 4398.90 4455.95 4513.00 4570.05 4627.10 4633.83 Section 7: Start DLS 2.00 TFO -180.00 MD Incl Azim TVD +N/-S ft deg deg ft ft 9900.00 52.08 314.95 6744.77 4683.57 10000.00 50.08 314.95 6807.59 4738.54 10100.00 48.08 314.95 6873.08 4791.93 10200.00 46.08 314.95 6941.17 4843.67 10300.00 44.08 314.95 7011.78 4893.70 . +E/;.W ft -1663.06 -1720.20 -1777.34 -1834.48 -1891.62 -1948.76 -2005.90 -2063.04 -2120.18 -2177.33 -2234.47 -2291.61 -2348.75 -2405.89 -2463.03 -2520.17 -2577.31 -2634.45 -2691.59 -2748.73 -2805.87 -2863.01 -2920.15 -2977.29 -3034.43 -3091.57 -3148.71 -3205.85 -3262.99 -3320.13 -3377.27 -3434.41 -3491.55 -3548.69 -3605.83 -3662.97 -3720.11 -3777 .25 -3834.40 -3891.54 -3948.68 -4005.82 -4062.96 -4120.10 -4177.24 -4234.38 -4291.52 -4348.66 -4405.80 -4462.94 -4520.08 -4577.22 -4634.36 -4641 .1 0 +E/-W ft -4690.93 -4745.98 -4799.46 -4851.28 -4901.39 VS ft 2350.12 2430.87 2511.61 2592.35 2673.10 2753.84 2834.59 2915.33 2996.08 3076.82 3157.57 3238.31 3319.06 3399.80 3480.55 3561.29 3642.03 3722.78 3803.52 3884.27 3965.01 4045.76 4126.50 4207.25 4287.99 4368.74 4449.48 4530.22 4610.97 4691.71 4772.46 4853.20 4933.95 5014.69 5095.44 5176.18 5256.93 5337.67 5418.42 5499.16 5579.90 5660.65 5741.39 5822.14 5902.88 5983.63 6064.37 6145.12 6225.86 6306.61 6387.35 6468.10 6548.84 6558.37 VS ft 6628.77 6706.57 6782.14 6855.37 6926.18 DLS Bûild Turn d~g/100ft. deg/100ft deg/10OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO d~g . 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS Build Turn TFO deg/100ft deg/1000 deg/1000 deg 2.00 -2.00 0.00 -180.00 2.00 -2.00 0.00 -180.00 2.00 -2.00 0.00 -180.00 2.00 -2.00 0.00 -180.00 2.00 -2.00 0.00 -180.00 ) BP ) Planning Report - Geographic COlÏ1p~ny: . BPAmoco . '. " Da.te:L .3/26/2002. . .. .Time: 10:413:31. ..... . Page; .4 . Field: . Lisburne. .. COcQrdinate(NEJliefererïce: Weli:Pß 1.6., True' North Site: .. . Eâ~tDòck(PSI) "er~iCål (rVDlRd~rence: RKBEst 5010 .., .. . Wen:. . PSl6 .. . SectioR(VS) Rêterence: . .Wèll(0;()ÖNiO~00E,314;95AZi) .. Wellpath:; Plah PSI ,6 . Plan: ' ...,. . . PSl6wþö6. . ... , Section 7: Start DLS 2.00 TFO -180.00 .MD .. bid AziD1 . TVD. +N/~S +E/"W. .DLS ,Build.. Turn. '.TFO V$ f't deg. .deg ft . ft .ft ft. deg/tOOft degOOOft qeg/100ft deg 10400.00 42.08 314.95 7084.81 4941.96 -4949.73 6994.48 2.00 -2.00 0.00 -180.00 10500.00 40.08 314.95 7160.18 4988.39 -4996.23 7060.19 2.00 -2.00 0.00 -180.00 10600.00 38.08 314.95 7237.80 5032.93 -5040.84 7123.23 2.00 -2.00 0.00 -180.00 10700.00 36.08 314.95 7317.57 5075.53 -5083.51 7183.53 2.00 -2.00 0.00 -180.00 10800.00 34.08 314.95 7399.40 5116.13 -5124.19 7241.00 2.00 -2.00 0.00 -180.00 10900.00 32.08 314.95 7483.19 5154.70 -5162.81 7295.58 2.00 -2.00 0.00 -180.00 11000.00 30.08 314.95 7568.82 5191.17 -5199.35 7347.21 2.00 -2.00 0.00 -180.00 11100.00 28.08 314.95 7656.21 5225.51 -5233.75 7395.81 2.00 -2.00 0.00 -180.00 11200.00 26.08 314.95 7745.24 5257.68 -5265.96 7441.34 2.00 -2.00 0.00 -180.00 11300.00 24.08 314.95 7835.81 5287.63 -5295.96 7483.73 2.00 -2.00 0.00 -179.99 11400.00 22.08 314.95 7927.79 5315.32 -5323.71 7522.94 2.00 -2.00 0.00 -179.99 11504.16 20.00 314.95 8025.00 5341.74 -5350.18 7560.33 2.00 -2.00 0.00 -179.99 Section 8: Start Hold MD II1ê1 .Aiim TVD +Nl;;S +El'-W VS DLS Build. . Turn . TFO .ft deg . deg ft ft ft ft deg/tOqftd~g/1 OOft . deg/tO{)ft dég 11600.00 20.00 314.95 8115.06 5364.90 -5373.37 7593.11 0.00 0.00 0.00 0.00 11698.90 20.00 314.95 8208.00 5388.80 -5397.31 7626.94 0.00 0.00 0.00 0.00 Section 9: Start Hold MD InCl Azhn TVD +N/~S +El;;W VS DLS Build Turn TFO ft deg deg. ft ft ft ft . deg/tOOft deg/1pOft. deg/tOOft . deg 11700.00 20.00 314.95 8209.03 5389.07 -5397.58 7627.31 0.00 0.00 0.00 0.00 11800.00 20.00 314.95 8303.00 5413.23 -5421.79 7661.51 0.00 0.00 0.00 0.00 11900.00 20.00 314.95 8396.97 5437.39 -5445.99 7695.72 0.00 0.00 0.00 0.00 12000.00 20.00 314.95 8490.94 5461.56 -5470.20 7729.92 0.00 0.00 0.00 0.00 12100.00 20.00 314.95 8584.91 5485.72 -5494.40 7764.12 0.00 0.00 0.00 0.00 12138.41 20.00 314.95 8621...00 5495.00 -5503.70 7777.26 0.00 0.00 0.00 0.00 Survey Map Map <'----Latitude .' ---> <--- Longitude.. .--> MD InCl Azim TVD +N/-S +E/-W . Northing Easting peg Min.. Sec Deg . Mirï See ft deg deg ft ft ft ft ft 30.00 0.00 0.00 30.00 0.00 0.00 5966148.85 707968.05 70 18 39.159 N 148 18 52.613 W 100.00 0.00 0.00 100.00 0.00 0.00 5966148.85 707968.05 70 18 39.159 N 148 18 52.613 W 200.00 0.00 0.00 200.00 0.00 0.00 5966148.85 707968.05 70 18 39.159 N 148 18 52.613 W 300.00 0.00 0.00 300.00 0.00 0.00 5966148.85 707968.05 70 18 39.159 N 148 18 52.613 W 400.00 1.00 314.96 399.99 0.62 -0.62 5966149.45 707967.42 70 18 39.165 N 148 18 52.631 W 500.00 2.00 314.96 499.96 2.47 -2.47 5966151.25 707965.51 70 18 39.184 N 148 18 52.685 W 600.00 3.00 314.96 599.86 5.55 -5.56 5966154.24 707962.34 70 18 39.214 N 148 18 52.775 W 700.00 5.00 314.96 699.61 10.48 -10.49 5966159.03 707957.27 70 18 39.262 N 148 18 52.919 W 800.00 7.00 314.96 799.06 17.86 -17.89 5966166.21 707949.68 70 18 39.335 N 148 18 53.135 W 900.00 9.00 314.96 898.08 27.70 -27.74 5966175.77 707939.56 70 18 39.432 N 148 18 53.422 W 1000.00 11.00 314.96 996.56 39.97 -40.02 5966187.69 707926.94 70 18 39.552 N 148 18 53.781 W 1100.00 13.00 314.96 1094.37 54.66 -54.73 5966201.97 707911.83 70 18 39.697 N 148 18 54.210 W 1200.00 15.00 314.96 1191.39 71.75 -71.85 5966218.58 707894.24 70 18 39.865 N 148 18 54.709 W 1300.00 17.00 314.96 1287.51 91.23 -91.35 5966237.51 707874.21 70 18 40.057 N 148 18 55.278 W 1400.00 19.00 314.96 1382.62 113.06 -113.22 5966258.73 707851.75 70 18 40.271 N 148 18 55.916 W 1500.00 21.00 314.96 1476.58 137.23 -137.42 5966282.21 707826.89 70 18 40.509 N 148 18 56.622 W 1600.00 23.00 314.96 1569.29 163.70 -163.92 5966307.94 707799.66 70 18 40.769 N 148 18 57.395 W 1700.00 25.00 314.96 1660.64 192.44 -192.70 5966335.87 707770.10 70 18 41.052 N 148 18 58.234 W 1799.42 26.99 314.96 1750.00 223.22 -223.53 5966365.79 707738.43 70 18 41.355 N 148 18 59.134 W 1900.00 26.99 314.96 1839.63 255.48 -255.83 5966397.13 707705.25 70 18 41.672 N 148 19 0.076 W 2000.00 26.99 314.96 1928.74 287.54 -287.94 5966428.29 707672.27 70 18 41.987 N 148 19 1.012 W 2023.86 26.99 314.96 1950.00 295.19 -295.61 5966435.73 707664.40 70 18 42.062 N 148 19 1.236 W 2100.00 29.27 314.96 2017.14 320.56 -321.01 5966460.38 707638.31 70 18 42.312 N 148 19 1.977 W 2200.00 32.27 314.96 2103.05 356.71 -357.21 5966495.51 707601.12 70 18 42.667 N 148 19 3.033 W ) BP Planning Report - Geographic Company: BPArnoco Field: . .Lisburne.. Site:< .Eå~tD()ck (PSI) Well;... '.PSI,'6 . }Vellp*b: . . Plan PSL6 Survey .MD ft 2300.00 ) .. Påge: Date: ..: 3/26/2002. ... Thn~: 10:49:31 . .. .. ço~ord¡nat~(NE)Reference:Well:,RS 1,6,TruëNorttl Vert~çal('rYJ)lReference:. .RKB Est50,Q . . .. . seCtìôn(VS)~efe¡'eJlêe: .. . Well (0,OQN;0:00E;<314;95Azi) . Plan: ... .. .... PSI6WpÖ6 . .. .. ..... .lncl deg 35.27 2400.00 38.27 2500.00 41.27 2600.00 44.27 2700.00 47.27 2800.00 50.27 2900.00 2919.15 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 53.27 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 53.85 2186.17 314.96 2266.26 314.96 2343.11 314.96 2416.51 314.96 2486.25 314.95 2552.15 314.95 2614.02 314.95 2625.40 314.95 2673.09 314.95 2732.09 314.95 2791.08 314.95 2850.07 314.95 2909.07 314.95 2968.06 314.95 3027.06 314.95 3086.05 314.95 3145.04 314.95 3204.04 314.95 3263.03 314.95 3322.03 314.95 3381.02 314.95 3440.01 314.95 3499.01 314.95 3558.00 314.95 3617.00 314.95 3675.99 314.95 3734.99 314.95 3793.98 314.95 3852.97 314.95 3911.97 314.95 3970.96 314.95 4029.96 314.95 4088.95 314.95 4147.94 314.95 4206.94 314.95 4265.93 314.95 4324.93 314.95 4383.92 314.95 4442.92 314.95 4501.91 314.95 4560.90 314.95 4619.90 314.95 4678.89 314.95 4737.89 314.95 4796.88 314.95 4855.87 314.95 4914.87 314.95 4973.86 314.95 5032.86 314.95 5091.85 314.95 5150.84 314.95 5209.84 ; M:.\pMap Northing . Easting. ft ; ft 5966533.68 707560.72 438.27 -438.90 5966574.78 707517.21 483.47 -484.16 5966618.70 707470.71 531.45 -532.21 5966665.33 707421.35 582.07 -582.91 5966714.53 707369.27 635.21 -636.13 5966766.16 707314.60 690.70 -691.72 5966820.10 707257.51 701.59 -702.62 5966830.68 707246.31 747.71 -748.82 5966875.50 707198.85 804.76 -805.96 5966930.94 707140.16 861.81 -863.10 5966986.39 707081.46 918.86 -920.24 5967041.83 707022.77 975.91 -977.38 5967097.27 706964.07 1032.96 -1034.52 5967152.72 706905.38 1090.01 -1091.66 5967208.16 706846.68 1147.06 -1148.80 5967263.60 706787.99 1204.11 -1205.94 5967319.04 706729.29 1261.16 -1263.08 5967374.49 706670.59 1318.21 -1320.22 5967429.93 706611.90 1375.26 -1377.36 5967485.37 706553.20 1432.31 -1434.50 5967540.81 706494.51 1489.36 -1491.64 5967596.26 706435.81 1546.41 -1548.78 5967651.70 706377.12 1603.46 -1605.92 5967707.14 706318.42 1660.51 -1663.06 5967762.58 706259.73 1717.56 -1720.20 5967818.03 706201.03 1774.61 -1777.34 5967873.47 706142.34 1831.66 -1834.48 5967928.91 706083.64 1888.71 -1891.62 5967984.35 706024.95 1945.76 -1948.76 5968039.80 705966.25 2002.81 -2005.90 5968095.24 705907.56 2059.86 -2063.04 5968150.68 705848.86 2116.91 -2120.18 5968206.13 705790.16 2173.96 -2177.33 5968261.57 705731.47 2231.01 -2234.47 5968317.01 705672.77 2288.06 -2291.61 5968372.45 705614.08 2345.11 -2348.75 5968427.90 705555.38 2402.16 -2405.89 5968483.34 705496.69 2459.21 -2463.03 5968538.78 705437.99 2516.26 -2520.17 5968594.22 705379.30 2573.31 -2577.31 5968649.67 705320.60 2630.35 -2634.45 5968705.11 705261.91 2687.40 -2691.59 5968760.55 705203.21 2744.45 -2748.73 5968815.99 705144.52 2801.50 -2805.87 5968871.44 705085.82 2858.55 -2863.01 5968926.88 705027.12 . <'-.. I..9ng;itlule . J)eg . Min. Seê 70 18 43.054 N 148 19 4.180 W 70 18 43.470 N 148 19 5.416 W 70 18 43.914 N 148 19 6.736 W 70 18 44.386 N 148 19 8.138 W 70 18 44.884 N 148 19 9.617 W 70 18 45.406 N 148 19 11.170 W 70 18 45.952 N 148 19 12.791 W 70 18 46.059 N 148 19 13.110 W 70 18 46.513 N 148 19 14.457 W 70 18 47.074 N 148 19 16.124 W 70 18 47.635 N 148 19 17.791 W 70 18 48.196 N 148 19 19.458 W 70 18 48.757 N 148 19 21.126 W 70 18 49.318 N 148 19 22.793 W 70 18 49.879 N 148 19 24.460 W 70 18 50.440 N 148 19 26.127 W 70 18 51.001 N 148 19 27.794W 70 18 51.562 N 148 19 29.462 W 70 18 52.123 N 148 19 31.129 W 7018 52.684 N 148 19 32.796 W 70 18 53.245 N 148 19 34.463 W 70 18 53.806 N 148 19 36.131 W 70 18 54.367 N 148 19 37.798 W 70 18 54.928 N 148 19 39.465 W 70 18 55.488 N 148 19 41.'133 W 70 18 56.049 N 148 19 42.800 W 70 18 56.610 N 148 19 44.468 W 70 18 57.171 N 148 19 46.135 W 70 18 57.732 N 148 19 47.803 W 70 18 58.293 N 148 19 49.470 W 70 18 58.854 N 148 19 51.138 W 70 18 59.415 N 148 19 52.806 W 70 18 59.976 N 148 19 54.473 W 70 19 0.537 N 148 19 56.141 W 70 19 1.098 N 148 19 57.809 W 70 19 1.659 N 148 19 59.476 W 70 19 2.220 N 148 20 1.144 W 70 19 2.781 N 148 20 2.812 W 70 19 3.341 N 148 20 4.479 W 70 19 3.902 N 148 20 6.147 W 70 19 4.463 N 148 20 7.815 W 70 19 5.024 N 148 20 9.483 W 70 19 5.585 N 148 20 11.151 W 70 19 6.146 N 148 20 12.819 W 70 19 6.707 N 148 20 14.487 W 70 19 7.268 N 148 20 16.155 W 2915.60 -2920.15 5968982.32 704968.43 70 19 7.828 N 148 20 17.823 W 2972.65 -2977.29 5969037.76 704909.73 70 19 8.389 N 148 20 19.491 W 3029.70 -3034.43 5969093.21 704851.04 70 19 8.950 N 148 20 21.159 W 3086.75 -3091.57 5969148.65 704792.34 70 19 9.511 N 148 20 22.827 W 3143.80 -3148.71 5969204.09 704733.65 70 19 10.072 N 148 20 24.495 W 3200.85 -3205.85 5969259.53 704674.95 70 19 10.633 N 148 20 26.163 W ) BP ') Planning Report - Geographic . .COO1P~ny: . BPAmocQ Date: 3/26/2002 . . . . T.il11.e: 10:49:31 .. . .Field: . Lisburne. . Ço:-ordir.ate(l'JE) l{ef~..ence:,^,en: PSI 6; True North Site: ' . Eåšt.DoCK (PSI) yerticar(T'V))}l{efereÏ1ce: . RKB Est50:0. . . .WeU: PSI 6 . Section (VS) Reference: .. Well (0.OON,Q.00E,31'4;95fQ:i) . W~lIpath: Plän PSI ,6 PlåÏ1: .. .. .. .. . PSI6wþ06 .. . . . Survey J.\1åp .. .l\iap . <:;.;.~;;Låtitude ~~ . . <~-Lol1gituØe MD . I Ï1e1 +E/'-W No..t~ing . Eäsöög.. .I>eg Min $ec Deg.I\1in ..... S~c ft .. déø ft ft ft .. 7400.00 53.85 5268.83 3257.90 -3262.99 5969314.98 704616.26 70 19 11 . 194 N 148 20 27.831 W 7500.00 53.85 5327.83 3314.95 -3320.13 5969370.42 704557.56 70 19 11.754 N 148 20 29.499 W 7600.00 53.85 5386.82 3372.00 -3377.27 5969425.86 704498.87 70 19 12.315 N 148 20 31.167W 7700.00 53.85 5445.82 3429.05 -3434.41 5969481.31 704440.17 70 19 12.876 N 148 20 32.836 W 7800.00 53.85 314.95 5504.81 3486.10 -3491.55 5969536.75 704381.48 70 19 13.437 N 148 20 34.504 W 7900.00 53.85 314.95 5563.80 3543.15 -3548.69 5969592.19 704322.78 70 19 13.998 N 148 20 36.172 W 8000.00 53.85 314.95 5622.80 3600.20 -3605.83 5969647.63 704264.09 70 19 14.559 N 148 20 37.840 W 8100.00 53.85 314.95 5681.79 3657.25 -3662.97 5969703.08 704205.39 70 19 15.119 N 148 20 39.509 W 8200.00 53.85 314.95 5740.79 3714.30 -3720.11 5969758.52 704146.69 70 19 15.680 N 148 20 41.177W 8300.00 53.85 314.95 5799.78 3771.35 -3777.25 5969813.96 704088.00 70 19 16.241 N 148 20 42.845 W 8400.00 53.85 314.95 5858.77 3828.40 -3834.40 5969869.40 704029.30 70 19 16.802 N 148 20 44.514 W 8500.00 53.85 314.95 5917.77 3885.45 -3891.54 5969924.85 703970.61 70 19 17.363 N 148 20 46.182 W 8600.00 53.85 314.95 5976.76 3942.50 -3948.68 5969980.29 703911.91 70 19 17.923 N 148 20 47.850 W 8700.00 53.85 314.95 6035.76 3999.55 -4005.82 5970035.73 703853.22 70 19 18.484 N 148 20 49.519 W 8800.00 53.85 314.95 6094.75 4056.60 -4062.96 5970091.17 703794.52 70 19 19.045 N 148 20 51.187W 8900.00 53.85 314.95 6153.75 4113.65 -4120.10 5970146.62 703735.83 70 19 19.606 N 148 20 52.856 W 9000.00 53.85 314.95 6212.74 4170.70 -4177.24 5970202.06 703677.13 70 19 20.166 N 148 20 54.524 W 9100.00 53.85 314.95 6271.73 4227.75 -4234.38 5970257.50 703618.44 70 19 20.727 N 148 20 56.193 W 9200.00 53.85 314.95 6330.73 4284.80 -4291.52 5970312.94 703559.74 70 19 21.288 N 148 20 57.862 W 9300.00 53.85 314.95 6389.72 4341.85 -4348.66 5970368.39 703501.05 70 19 21.849 N 148 20 59.530 W 9400.00 53.85 314.95 6448.72 4398.90 -4405.80 5970423.83 703442.35 70 19 22.409 N 148 21 1.199 W 9500.00 53.85 314.95 6507.71 4455.95 -4462.94 5970479.27 703383.66 70 19 22.970 N 148 21 2.868 W 9600.00 53.85 314.95 6566.70 4513.00 -4520.08 5970534.71 703324.96 70 19 23.531 N 148 21 4.536 W 9700.00 53.85 314.95 6625.70 4570.05 -4577.22 5970590.16 703266.26 70 19 24.092 N 148 21 6.205 W 9800.00 53.85 314.95 6684.69 4627.10 -4634.36 5970645.60 703207.57 70 19 24.652 N 148 21 7.874 W 9811.80 53.85 314.95 6691.65 4633.83 -4641.10 5970652.14 703200.64 70 19 24.719 N 148 21 8.071 W 9900.00 52.08 314.95 6744.77 4683.57 -4690.93 5970700.48 703149.46 70 19 25.208 N 148 21 9.526 W 10000.00 50.08 314.95 6807.59 4738.54 -4745.98 5970753.91 703092.91 70 19 25.748 N 148 21 11.134 W 10100.00 48.08 314.95 6873.08 4791.93 -4799.46 5970805.79 703037.98 70 19 26.273 N 148 21 12.695 W 10200.00 46.08 314.95 6941 .17 4843.67 -4851.28 5970856.07 702984.75 70 19 26.781 N 148 21 14.209 W 10300.00 44.08 314.95 7011.78 4893.70 -4901.39 5970904.69 702933.27 70 19 27.273 N 148 21 15.672 W 10400.00 42.08 314.95 7084.81 4941.96 -4949.73 5970951.59 702883.62 70 19 27.747 N 148 21 17.084 W 10500.00 40.08 314.95 7160.18 4988.39 -4996.23 5970996.71 702835.85 70 19 28.203 N 148 21 18.442 W 10600.00 38.08 314.95 7237.80 5032.93 -5040.84 5971040.00 702790.02 70 19 28.641 N 148 21 19.745 W 10700.00 36.08 314.95 7317.57 5075.53 -5083.51 5971081.40 702746.19 70 19 29.060 N 148 21 20.992 W 10800.00 34.08 314.95 7399.40 5116.13 -5124.19 5971120.86 702704.41 70 19 29.459 N 148 21 22.180 W 10900.00 32.08 314.95 7483.19 5154.70 -5162.81 5971158.34 702664.74 70 19 29.838 N 148 21 23.308 W 11000.00 30.08 314.95 7568.82 5191.17 -5199.35 5971193.78 702627.21 70 19 30.196 N 148 21 24.375 W 11100.00 28.08 314.95 7656.21 5225.51 -5233.75 5971227.16 702591.87 70 19 30.534 N 148 21 25.380 W 11200.00 26.08 314.95 7745.24 5257.68 -5265.96 5971258.42 702558.78 70 19 30.850 N 148 21 26.321 W 11300.00 24.08 314.95 7835.81 5287.63 -5295.96 5971287.52 702527.96 70 19 31.144N 148 21 27.197 W 11400.00 22.08 314.95 7927.79 5315.32 -5323.71 5971314.44 702499.46 70 19 31.417 N 148 21 28.008 W 11504.16 20.00 314.95 8025.00 5341.74 -5350.18 5971340.11 702472.27 70 19 31.676 N 148 21 28.781 W 11600.00 20.00 314.95 8115.06 5364.90 -5373.37 5971362.62 702448.44 70 19 31.904 N 148 21 29.458 W 11698.90 20.00 314.95 8208.00 5388.80 -5397.31 5971385.85 702423.85 70 19 32.139 N 148 21 30.158 W 11700.00 20.00 314.95 8209.03 5389.07 -5397.58 5971386.10 702423.58 70 19 32.141 N 148 21 30.165 W 11800.00 20.00 314.95 8303.00 5413.23 -5421.79 5971409.59 702398.72 70 19 32.379 N 148 21 30.872 W 11900.00 20.00 314.95 8396.97 5437.39 -5445.99 5971433.07 702373.85 70 19 32.616 N 148 21 31.579 W 12000.00 20.00 314.95 8490.94 5461.56 -5470.20 5971456.55 702348.99 70 19 32.854 N 148 21 32.287 W 12100.00 20.00 314.95 8584.91 5485.72 -5494.40 5971480.03 702324.12 70 19 33.091 N 148 21 32.994 W 12138.41 20.00 314.95 8621.00 5495.00 -5503.70 5971489.05 702314.57 70 19 33.182 N 148 21 33.265 W Mar-28-2002 07:22 Frorn-MCC WING 6 +907-659-5065 . /' (...: " ::~"...."'.' /' ,~.." ~/ :::.~.... PRUDHOE BAY "",./,-/ /'. ':::~.~.::,...,..... " g /.-/'. ..' ./ ~::: ,.....,. ~ ) .,' .' Z <J: ëL c {? (j ~ ..' ~- I VICINITY MAP N.T.S, l!) :z ¡::: r,I) X L..I.J I V) CL + IJ) (.() r--. co 01 ~ I I I I I I if) û) U1 (ï) (7) if) l1.. a.. 0... Cl.. D- Q.. ++++++ .....J ..-J ~ . EAST DOCK WEST PAD .., ...,...,..,...,. ,,..,..'" ..."..,..".,.. .LEGEND + AS-STAKED CONDUCTOR . EXISTING CONDUCTOR ~ ~ -t .. <> '/ ~-_. ~ -;' =J~?/O'2. ISSUED F"~-,~¡'o(WlI'!1ON ::: N~ ('I"Tf . LOCATED WITHIN PROTRACTED- SEC. 15, T; 11 N.. R. 15 E.. UMtA T MERIDIAN. ALA~t<A wELL A.S.P. -. PLANT' GEODtt'IC GEÖDETIC AfPROX, SECTION NO. COORDINATES COORDINA TES POSITION(DMS) POSITION(D.DD) GND. ELEV. OFFSETS PS 1 Y=5,966,'097,55 'Nr:::10,OOO,00 70"'8'38.69.3" 70.3107481" '-7 6' 3,800' i=-'Sl 1- Xr::: 707,827.10 E:::: :I-,91Q.00 148"18'56.765" 148.3157ß~1" '.4,.579' FEL PS 5 y= 5,966,138.59 N=10,OOO.00 7018'39.066" 70.310851 T 17 5' 3,8.38' FSL - x= 707,939,86 E= 5,030.00 , 148"18'5;3.444" 148.3148456" , 4,465' FEL PS 6 Y= 5,966,148.85 N=:10,OOO.00 70"18'39,159" 70,3108775' 17 5' 3,848' FSL 1- ~=:; 707.968',05 E~ 5,060.00 148"18'52.613". 148.3146147" . ~,4~6' FEL PSI-7 y= 5,966,'59,11 N=10.000.QO 70'18'39.253" 70.3109036" 17.4' 3.857' FSL x= 707,996.~4 E=: 51990.00 148J8'51. 783~ 1 48.3143842" ~.,408' fE~ S 8 Y:.:.5,966,169.37 N=10,OOO.OO 70"18'39.346" 70.3109294" '74' 3.867' fSI-. P 1- x= 708,024,43. E= 5.1~O,90 148~1a'~O.953'. 1:1-8.3141536" u. . 4,;57.9. FEL PSI~9 ~: 5';~~:6;~',~; ~:1 ~.~~g:gg 1 :~..;~r;~'.~~~:: 1 :~',~~ ~~~~~: 17.3' ~,~~~: ~~t y= 5.966,189,89 'N=1 0,000,00 70.18;39.532" 70.31098". 3.886' FSL PSI-10 x= 708.080.81 E=::. 5.180.00 148"18' 49,292" 148.31 ~~922" 17.4' 4.322' FE.L ~'. . R6..9.eIL 6RïÜ,N' JACOBS O. l~ '-0) ~ Clti-:CKtlI: ~SOI':!..- bp DII TE: 3/27/02 . ~ it O~Rã~~ EO 01-00 -- GP8 EAST DOCK WFl PAD ~ rn~~a)(t;o :~~ AS-STAKED CONDUCTORS ::7,' :::¿='~ :SC l"m 100' WELLS PSI-'. 5. 6. 7, 8, 9 & 10 ~...~~~ SH[~¡: '" c ,:;. 1\1 ~ ~ 1\, ~ ~ 9 ~ ~ 0 ~ 0 ù j c..> L.J ,', C C 0 L.J ~ t; ~ ::) ~ ~ .:l IS ~ , OF 1 F<E\II9ION oSJ RFII .. OY CHK H 206292 ) ') DATE 03/14/02 CHECK NO. 00206292 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT AI ASI-\AfïTI A NET 00 03i2ü2 CK03i202B PYMT COMMENTS: HANDLING INST: 100.00 100. 00 Permit to Drill Fee S/H - Terrie Hubble X4628 RECEIVED ?S\ -OlD APR 1 2-002 NI1kaOJlI Ga8 ConI. Cclrmileion .AnciaI8Jê E ATrACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ... ion 00 iOO Of) BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 2 OS 2 9 2 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 '412 00206292 PAY 00/ 100**************************-):',********** US DOLLAR . DATE 03/14/02 AMOONT .$100...00 To The ORDER Of ALÀSKA OIL AND GAS CONSERVATION COMMISSION 333>iWEST 7TH AVENUE. SUITE 100 ANCHORAGE NOTVALlD AFTER 120. DAYS AK 99501 R';;j~~!1: ']'~ III 2 0 b 2 '1 2111 I: 0 L. ~ 2 0 ~ a '1 5 I: 0 0 a ~ L. ~ '1111 , ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL v INJECTION WELL REDRlLL WELL NAME /~ 151- 0 ¡; CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) , ANNUL~ D}8fOSAL , <k::JNO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" Tbe permit is for a new well bore segment of existing weD ~PermitNo, ,API No. .', Production sbould continue to be reported as a function of tbe original API number stated above. . In accordance with 2.0 MC 25.005(1), all r~ords, data and logs acquired for tbe pilot bole 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 wel~ (n8:me on permit). Annular disposal has ~ot been requ~ted... Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed Is tbe approved application for permit to drill the above referenced we)). Tbe permit is approved ,sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume tbe liability of any protest to the spacing exception that may occur. ;D.~C¡ WELL PERMIT CHECKLIST COMPANY /?FA-- WELL NAME ¡tJ~ 1- 0 ~ PROGRAM: Exp - Dev - Redrll - Serv)( Wellbore seg - Ann. disposal para req - FIELD & PDOL C; ~O) b 0 INIT CLASS ý -:; /.J:! /-;'fi~ Al"c. GEDL AREA X'"9 ð UNIT# / / ç; ~ ñ ON/OFF SHORE ,.,JV ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 7v" N A?'G 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . V N ....1/ /:' I / / ../ ~¡'CI."" / 1::1), 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N1$J~ /~ 7*- -t I~.J' hJ~ 11 (/Q/".~~~ ~) 7 '\t' - ~ h...Jj'"ij. T'¿Y- -- Áf( ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N / / ¡I - j 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . V N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . V N 11. Permit can be issued without conservation order. . . . . . . . Y N APPR . D~ T5. T 12. Permit can be issued without administrative approval.. . . . . Y N .(Ie Vro ') - 13. Can permit be approved before 15-day wait.. . . . . . . . . . 0 N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N ~t Q II ,,-' r VD, 15. Surface casing protects all known USDWs. . . . . . . . N, ...¿ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N Åd/ ~ (,¿.¿.;fA e¡( ("!I?S S ('/L"",- l~ . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y /197 1/ 18. CMT will cover all known productive horizons. . . . . . . . . . /9.. ~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ~ N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . CP N A!¡;¡,bt?t S '27[; 21. If a re-drill, has a 10-403 for abandonment been approved. . . --¥-N-.Al/A- 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N \ ~;P:R r~fJFO.7 26. BOPE press rating appropriate; test to ;500 psig. N ß'lsP = ~¿:fl¿ ~ ~ ' .,X-:-A -r r ð Il c...- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . '. N 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y (fV 30. Permit can be issued wlo hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . ~.fR . ~fTE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . /iff., W/o? - 34. Contact namelphone for weekly progress reports [exploratory ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from pool; and (E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPCß!t- TEM SFD- WGA'VJ6k- f GEOLOGY ( APPR DATE ¡fp ~}ÄZ Y N Y /~ /V.lfl i Commentsllnstructions: COT I DTS (1~ I ¿jCJ:;:.v JMH__- G: \geology\templates \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 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 18 17:00:39 2003 Reel Header Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 03/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments........ .........STS LIS Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 031 02/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22084 J. BOBBITT B. DECKER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: E'EL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 # REfvlARKS : Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services PSI-06 5002923082 BP Exploration Sperry Sun 18-FEB-0J. (Alaska) inc. MWD RUN 2 AK-MW-22084 J. BOBBITT B. DECKER MWD RUN 4 AK-MW-22084 T. GALVIN D. FERGUSON 15 llN 15E 1432 843 .00 50.80 17.50 CASING SIZE (IN) 20.000 13.375 9.625 DRILLERS DEPTH (FT) 114.0 6401. 0 11705.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TV D) . 3. MWD RUN .1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) c:1ða-D79 115/~ ) ) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 2 WAS DIRECTIONAL WITH DGR, .~D ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. MWD RUN 4 WAS DIRECTIONAL WI'I'H PRESSURE CASE GAMMA (PCG) UTILIZING SCINTILLATION DE,TE,CTORS. 6. LOG AND DIGITAL DATA ARE DEPTH SHIFTED TO THE PDC GR LOG, (SCHLUMBERGER, 6/21/02) PER PHONE CONVERSA'l'ION OF 2/18/03 WITH D. SCHNORR (BP EXPLORATION). HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 7. MWD RUNS 1-4 REPRESEN'l' WELL PSI-06 WITH API # 50-029-23082-00. THIS WELL REACHED A TOTAL DEPTH ('I'D) OF 12145' MD / 8597.6' TVD. SROP = SMOOTHED RA'I'E OF PENE'I'RATION WHILE DRILLING. SGRD == SMOOTHED GAMMA RAY - SCINTILLATION DETECTORS SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP == SMOOTHED PHASE SHALLOW SPACING) SESP == SMOOTHED PHASE SHALLOW SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) S.FXE = SMOOTHED FORMATION EXPOSURE 'rIME $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/02/18 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 FET RPD RPM RPS RPX $ .l SHIFT DERIVED RESISTIVITY ( EXTRA SHI F'r DERIVED RESISTIVITY ( SHIFT DERIVE',D RESISTIVITY ( MEDIUM SHIFT DERIVED RESISTIVITY ( DEEP clipped curves; all bit runs merged. .5000 START DEPTH 116.5 117.0 6365.0 6365.0 6365.0 6365.0 6365.0 STOP DEPTH 12095.5 12144.5 11664.0 11664.0 11664.0 11664.0 11664.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 11564.0 11608.5 11629.5 11690.0 11709.5 11719.5 11738.5 DEPTH GR 11561.5 11606.0 11627.5 11686.5 11 707 . 0 11717.0 11736.0 ) ') 11751. 0 11863.5 11894.0 11902.0 11936.0 11958.0 11981.5 12004.5 12017.0 12051. 5 12068.5 12077.0 12089.0 12118.0 $ 11747.0 11861.5 11893.0 11901.5 11935.0 11957.0 11979. 5 12001.5 12014.5 12051.0 12068.5 12077.0 12089.5 12118.5 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 114.0 2 6415.5 4 11715.0 MERGE BASE 6415.0 11714.5 12145.0 tI REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 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 Name Service Order Units S:iZ(~ 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 First Las"t Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 116.5 12144.5 6130.5 24057 116.5 12144.5 ROP MWD FT/H 0 1129.19 204.932 24056 117 12144.5 GR MWD API 14.27 472.35 69.3676 23959 116.5 12095.5 RPX MWD OHMM 0.67 55.88 3.06798 10599 6365 11664 RPS MWD OHMM 0.46 527.67 3.27277 10599 6365 11664 RPM MWD OHMM 0.76 74.3 3.39431 10599 6365 11664 RPD MWo OHMM 0.82 1556.81 5.1769 10599 6365 11664 FET MWD HOUR 0.12 9"7.59 2.06551 10599 6365 11664 First Reading For Entire Fi1e..........116.5 Last Reading For Entire Fi1e...........12144.5 File Trailer Service name.............STSLIB.OO1 Service Sub Level Name... Version Number...........l.O.ü Date of Generation.......03/02/18 Maximum Physical Record..65535 File Type................LO Next File Name...-_......STSLIB.OO2 ) Physical EOF File Header Service name.............STSLIB.OO2 Service Sub Level Name... Version Number.. . . . . . . . . .1. O. 0 Date of Generation.......03/02/18 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMEWr: # FILE SUMMARY VENDOR TOOL conE GR ROP 2 ) header data for each bit run in separate files. 1 .5000 START DE PTH 114.0 114.5 STOP DEPTH 6357.0 6415.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOE'TWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D 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 BO'I'TOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (E''I'): 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): REtvr.A.RKS: $ Ii Data Format Specification Record 07-JUN-02 Insite 66.37 Memory 6416.0 114.0 6416.0 .0 59.5 TOOL NUMBER PB00204HG8 16.000 114.0 SPUD MUD 9.30 215.0 8.4 750 9.2 .000 .000 .000 .000 .0 97.6 .0 .0 ) ) Data Record Type..................O Data Specification Blod: Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Polnt..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......... ........... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specif5.cation Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Uni.ts Size Nsam Rep Code Offset Channel F'r 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 :3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 114 6415 3264.5 12603 114 6415 ROP MWD010 FT/H 0 B66.3 2213.626 12602 114.5 6415 GR MWD010 API 14.27 108.42 53.3998 12487 114 6357 First Reading For Entire File..........114 Last Reading For Entire Fi1e...........6415 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/18 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name............ ,STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/1B 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 FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6357.5 6362.5 6362.5 6362.5 6362.5 6362.5 6415.5 STOP DEPTH 11668.0 11661. 0 11661.0 11661.0 11661.0 11661.0 11714.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 16-JUN-02 Insite 66.16 ) DATA TYPE (MEMORY OR REAL-TIME): TO 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL rrYPE DUAL GAMMA RAY ELECTRO~~G. 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 'I'EMPERATURE (MT): MUD AT MAX CIR.CULATING TERMPERATURE: MUD E'IL'l'RATE Nr MT: MUD CAKE AT Mrr: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ ff Data Format Specification Record Data Record Type.................. 0 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Memory 11715.0 6416.0 11715.0 16.5 56.4 TOOL NUMBER PB00205HWRG8 PBOO205HWRG8 12.250 6401. 0 LSND 9.25 52.0 8.4 450 4.6 1. 850 .930 1. 550 2.650 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 FTIH 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 First Last Name Service Unit Min Max I"lean Nsam Reading Reading DEPT FT 6357.5 11714.5 9036 10715 6357.5 11714.5 ROP MWD020 FT/H 0 1068.93 180.098 10599 6415.5 11714.5 GR MWD020 API 17.83 266.65 87.1625 10622 6357.5 11668 RI?X ¡vrwD020 OHMM 0.67 55.88 3.06824 10598 6362.5 11661 RPS MWD020 OHM!V[ 0.46 527.67 3.27305 10598 6362.5 11661 RI?M MWD020 OHMM 0.76 74.3 3.39454 10598 6362.5 11661 ) ) RPD MWD020 OH~[ FET MWD020 HOUR 0.82 0.12 1556.81 97.59 5.17721 10598 2.06557 10598 6362.5 6362.5 11661 11661 First Reading For Entire File..........6351.5 Last Reading For Entire File...........11714.5 File Trailer Service name............. STSLIB. 003 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/02/18 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STS1IB.004 Physical EOr File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/02/18 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: if FILE SUMJVIARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 11668.5 11715.0 STOP DEPTH 12096.0 12145.0 jj LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 20-JUN-02 Insite 66.16 Memory 12145.0 11715.0 12145.0 14.4 17.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER 143791 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 11 705.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT BARADRIL-N 9.00 49.0 t:.1 16000 5.0 TEMPERATURE (DEGF) ) ) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 116. (I . (ì . (I # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: ,$ # Data Format Specification Record Data Record Type.................. 0 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 Name Service Order Uni t.1, Size Nsam R.ep Code Offset Channel DEPT Fir 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT F"1' 11668.5 12145 11906.8 954 11668.5 12145 ROP MWD040 FT/H 34.96 1129.19 163.411 861 11715 12145 GR MWD040 API 23.36 4"72.35 81.5784 856 11668.5 12096 First Reading For Entire File......... .11668.5 Last Reading For Entire File...........12145 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/02/18 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.005 Physical EOt' Tape Trailer Service name..... ........LISTPE Date.................... .03/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number.. ....01 Next Reel Name...........UN~~OWN ) ) Comments.................STS :[,IS Weiting L.ibrary. Scientific Technical Services Physical BOF Physical EOF End Of LIS File ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 13 16:19:42 2003 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/02/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Narne.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name........... ..LISTPE Da"t e. . . . . . . . . . . . . .. . . . .. . 03/ 02/ 13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Numbe.r...... 01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical Eor Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: £'EL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 1 AK-MW-22084 J. BOBBITT 8. DECKER MSL 0) OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 Wdting L.ibrary. Wr"iting Li.brary. PS1-06 5002923082 BP Exploration Sperry Sun 13-FE8-03 MWD RUN 2 AK-MW-22084 J. BOBBITT B. DECKER Ej llN 15E 1432 B43 .00 50.80 17 .50 CASING SIZE (IN) 20.000 13.375 9.625 DRILLERS DEPTH (FT) 114. (I 6401. (I 11705.0 ') Sci.entific Technical Services Scientific Technical Services (Alaska) inc. MWD RUN 4 AK-MW-22084 T. GALVIN D. FERGUSON 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TV D) . 3. HWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMHA RAY (DGR) ~t8-(J71 l/ó¡9 ) ) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 2 WAS DIRECTIONAL WITH DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. MWD RUN 4 WAS DIREC'I'IONAL WITH PRESSURE CASE GAMMA (PCG) UTILIZING SCINTILLATION DETE.CTORS. 6. DEPTH SHIFTING WAS WAIVED, PER THE 1/21/2003 E-MAIL FROM D. SCHNORR (BP EXPl,ORAT'ION). HE',ADER DATA RE'rAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT WELL PSI-06 WITH API # 50-029-23082-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 12145' MD 1 8597.6' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY SCINTILLATION DETECTORS SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHALLOW SPACING) SESP = SMOOTHED PHASE SHALLOW SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) SFXE= SMOOTHED FORMATION EXPOSURE TIME $ SHIFT DERIVED RESISTIVITY ( EXTRA SHIFT DERIVED RESISTIVITY ( S¡..U FT DERIVED RESISTIVITY ( ME DI UM SH H"l' DERIVED RESIS'I'IVITY ( DEEP File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/l3 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 FET RPD RPM RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 114.0 114.5 6362.5 6362.5 6362.5 6362.5 6362.5 STOP DEPTH 12096.0 12145.0 11661.0 11661.0 11661.0 11661.0 11661.0 II BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DErTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MI"iD DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 114.0 2 6415.5 11715.0 MERGE BASE 6415.0 11714.5 1214 5 . (, $ # REfvlARKS: MERGED MAIN rASS. $ ) ) # Data Format Specification Record Data Record Type.................. 0 Data Specificatì.on Block. Type..... 0 Logging Directlon.................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 6B 12 4 RPS MWD OHMM 4 1 6l~ 16 5 RPM MWD OI-IMM <1 1 68 20 6 RPD MWD OHMM <1 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First~ Last. Name Service Unit Min Max Mean Nsam Reading Reading DEPT F'I' 114 12145 6129.5 24063 114 12145 ROP MWD FT/H 0 1129.19 204.917 24062 114.5 12145 GR MWD API 14.27 472.35 69.3709 23965 114 12096 RPX MWD OHHfVI 0.67 55.88 3.06824 10598 6362.5 11661 RPS MWD OHMM 0.46 527 . 67 3.27305 10598 6362.5 11661 RPM MWD OHMM 0.76 74.3 3.39454 10598 6362.5 11661 RPD MWD OHMM 0.82 15.56.81 5.17721 10598 6362.5 11661 FET MWD HOUR 0.12 9'-'.59 2.0655'7 10~)98 6362.5 11661 First Reading For Entire File..........l14 Last Reading For Entire Fi1e...........12145 File Trailer Service name.............STSLIB.OO1 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/02/13 Maximum Physical Record..65535 Fi 1 e 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.......03/02/13 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log ['.IT RUN NU¡..mER: DEPTH INCREMENT: 2 header data for each bit run in separate files. 1 .5000 FILE SUHM.A.RY VENDOR TOOL CODE START DEPTH GR 114.0 ROP 114.5 STOP DEPTH 6357.0 6415.0 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: '1'001 STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL, GAMMA HAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (F'I'): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUFŒ (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MU D CAKE AT M'l': it NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): If TOOL S'rJ.\NDOFF (IN): EWR FREQUENCY (HZ): it REMARKS: $ it Data Format Specification Record Data Record Type............. .....0 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 Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 07-JUN-02 Insite 66.37 Memory 6416.0 114.0 6416.0 .0 59.5 TOOL NUMBER 123225 16.000 114.0 SPUD MUD 9.30 215.0 8.4 750 9.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel OEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 - GR MWD010 API 4 1 68 8 3 ) .0 97.6 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Readi.nr;! DEPT FT 114 6415 3264.5 12603 114 EHS ROP Mì"iTD010 FT/H 0 866.3 :228.626 12602 114.5 6415 GR MWD010 API 14.27 108.42 53.3998 12487 114 6357 ) First Reading For Entire File..........114 Last Reading For Entire File...........6415 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/13 Maximum Physical Record..65535 Fil e 'l'ype................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name............ .S'rSLIB.003 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation.......03/02/13 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record E'ILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DE PTH INCREMEN'f: /I FILE SUMMARY VENDOR TOOL CODE GR FET EPD RPM RPS RPX ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 6357.5 6362.5 6362. :) 6362.5 6362.5 6362.5 6415.5 II LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: II STOP DEPTH 11668.0 11661. 0 11661. 0 11661.0 11661. 0 11661.0 11714.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RES IS. 4 DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS !'1UD TY PE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): l6-JUN-02 Insite 66.16 Memory 11715.0 6416.0 11715.0 16.5 56.4 TOOL NUMBER 123225 123225 12.250 6401.0 LSND 9.25 52.0 2..4 450 ) ') FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERJ.\TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 4.6 1. 850 .930 1.550 2.650 65.0 136.0 65.0 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL S'I'ANDOE'F (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.. ...0 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6357.5 11714.5 9036 10715 6357.5 11714.5 ROP MTÑD020 FT/H 0 1068.93 180.098 10599 6415.5 11714.5 GR MWD020 API 17.83 266.6::> 87.1625 10622 6357.5 11668 RPX MND020 OHMH 0.67 55.88 3.06824 10598 6362.5 11661 RPS MWD020 OHMM 0.46 527.67 3.27305 10598 6362.5 11661 RPM MWD020 OHMM 0.76 74.3 3.39454 10598 6362.5 11661 [\PD MWD020 OHMM 0.82 1556.81 5.17721 10.598 6362.5 11661 FET MWD020 HOUR 0.12 97.59 2.06557 10598 6362.5 11661 First Reading For Entire File..........6357.5 Last Reading For Entire File...........11714.5 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number..... - . . . . .1. 0.0 Date of Generation.... ...03/02/13 Maximum Physical Record..65535 File Type................ LO Next File Name. ......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.OO~ Service Sub Level Name... Version Number. ...... ....1.0.0 ') Date of Generation.......03/02/13 Maximum Physical Record..65535 File Type................ 1.0 Previous File Name.......STSLIB.OO3 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: il FILE SUMMARY VENDOR TOOL CODE GR ROP $ ) header data for each bit run in separate files. 4 .5000 START DEPTH 1.1668.5 11715.0 s'rop DEPTH 12096.0 12145.0 # LOG !-lEADER DATA DATE LOGGED: SOF'I'WAHE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCIJIN.ATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: il TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL 'TYPE NG P NA'rURAL GAMMA PROBE $ # BOREHOLE AND GASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): II 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): REM.Zl.RKS : $ Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction..... ............Down Optical log depth units...........FeeL Data Reference Point. .......,.... .Undefined Frame Spacing.. ".'." ......... ...60 .1IN Max frames per record.............Undefined i\bser.t value...................... -999 20-JUN-02 Insite 3.3 Memory 12145.0 11715.0 12145.0 14.4 17.0 TOOL NUMBER 14 37 91 8.500 11705.0 BARADRIL-N 9.00 49.0 8.1 16000 5.0 .000 .000 .000 .000 .0 116.0 .0 .0 " ) Depth Un.1 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEFT E'T 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11668.5 1214t> 11906.8 954 11668.5 12145 ROP MWD040 FT/H 34.96 1129.19 163.411 861 11 715 12145 GR MWD040 API 23.36 472.3~) 81. 5784 856 11668.5 12096 First Reading For Entire File..........11668.5 Last Reading For Entire File...........12145 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Numbe:r:'.......... .1.0.0 Date of Generation.......03/02/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 02/ 13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name....... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wri ting Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/02/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name..... "'.'." ...UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS file