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Home My WebLink About197-118MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC G-10 MILNE PT UNIT G-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 G-10 50-029-22780-00-00 197-118-0 W SPT 3935 1971180 1500 850 850 850 845 4YRTST P Kam StJohn 12/10/2025 4 year MIT-IA, Monobore no OA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT G-10 Inspection Date: Tubing OA Packer Depth 250 1710 1645 1635IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251211123844 BBL Pumped:1.4 BBL Returned:1.4 Friday, January 16, 2026 Page 1 of 1            MEMORANDUM TO: Jim Regg P.I. Supervisor �efle FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 20, 2021 SUBJECT: Mechanical Integrity Tests Hilcoip Alaska, LLC G-10 MILNE PT UNIT G-10 Src: Inspector Reviewed By: P.I. Supry I -P Comm Well Name MILNE PT UNIT G-10 API Well Number 50-029-22780-00-00 Inspector Name: Guy Cook Permit Number: 197-118-0 Inspection Date: 12/11/2021 - IRsp Num: mitGDC211210165147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well G-10 Type Inj w, T`7]) 3935 'fulling 648 - 649 - 648 648 - PTD 1971180 Type Test SPT Test psi 1500 IA 258 2001 - 1918 - 1901 - BBL Pumped: 1.3BBL Returned: 1.3- OA Interval 4YRTST P/F P Notes: Testing completed with a Little Red Services pump truck and calibrated gauges. This well is a mono -bore. ti%�."GL ZtTZ L Monday, December 20, 2021 Page 1 of 1 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,March 01,2017 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests 1 ) HILCORP ALASKA LLC -VI��` / G-10 FROM: Brian Bixby MILNE PT UNIT G-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry N1,�a2 NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT G-10 API Well Number 50-029-22780-00-00 Inspector Name: Brian Bixby Permit Number: 197-118-0 Inspection Date: 2/28/2017 Insp Num: mitBDB170228172733 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well G-10 Type Inj W TVD 3935'/' Tubing 752 752 753 750 PTD 1971180 Type Test SPT Test psi 1500 IA 304 1815 1756 1749 1.2 BBL Returned: 1.2 OA BBL Pumped: 1 � Interval 4YRTST 'P/F 1 P ✓ Notes: Monobore Well.There is no OA......,...-- SCANNED /SCANNED APR 2 8 Z017 Wednesday,March 01,2017 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 ; a r -r r i e, 4 Ed o December 30, 2011 �'. ) �. t? a Mr. Tom Maunder Y I a Alaska Oil and Gas Conservation Commission 1 ' , \ 333 West 7 Avenue • Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPG -Pad 10/10/2011 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 gal MPG-01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG-02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG -05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG -07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG-09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 ---* MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG-11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG-16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG-17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 ~~~ ~~~ • ~~,~~u~n~i-,4L ~~- PROACTIVE DIAGNOSTIC SERVICES, INC_ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper/ MTT) The technical data listed below is being submitted herewith, P{ease acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~~~`~~I~' ~U~i ~ ~ ~Q~1r Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 03-Ju1-1O MPU G10 BL/EDE 2) Injection Profile 01-Ju1-1O MPU GO7 BL/EDE UzG l9~-- /~~ 1~~~l~ Signed : ~i Print Name: _ 50-029-22780-00 50-029-22140-00 ~ ~; ..,1 :~ , ~, Date . ' j~'- :j ;~(k!~ 3~ mt6r2~ ~a `5~~~: b8i3J9R/B J PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~adsanchorage(n2snes~~rvlrse~.~s3m WEBSITE : °nrN~!v.ra~es~sorydoa.c~rra C:~Document~ and Settings~Diane Williams~DesktoFlTransmit Conoco.docx r~ LJ MEMORANDUM To: Jim Regg ~ ~i~,Z/~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC G-10 MILNE PT UNIT SB G-i 0 Src: hispector ]vniv_rn1vl• rnF.NTiA i . Reviewed By: P.I. Suprv Comm Well Name• MILNE PT UNIT SB G-l0 • API Well Number: 50-029-22780-00-00 Inspector Name: Bob Noble mitRCN090321143417 Insp Num: permit Number: 197-118-0 ~ Inspection Date; 3J17/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G 10 Type III. W TVD 3935 ~ 0 2000 1930 1910 "' P T. 19~llso TypeTest sPT Test psi '00° OA Interval 4YxTST ~ p/F P '' Tubing ~~ goo goo goo Notes: Tuesday, March 24, 2009 Page 1 of 1 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records DepaM¡nent 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing fnspection(Cafiper / MTT) The technical data fisted below is being submitted herewith. Please acknowfedge receipt by returning a signed copy of this transmittal letter to the attention of : 1) EDE Disk 2) EDE Disk 3) 4] 5) 6) 7] Signed: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 1 4 2007 130 West International Airport Road""""'" E.II.\N¡:;[) JUN Suite c ~..~ Anchorage, AK 99518 Fax: (907) 245-8952 &§G-V MPUG-13 ..,..vrð.'"lÄ 16-May-07 # I~ 10,9 j Injection Profile Injection Profile 17-May-07- AP;J:4:t'{~ ~~ /I -r-- ::u... I..:. ~ D/M.e.D1A. e ts ~ ì lÄð U1-r a... --:J ,.. I. - - {- tr ,.... :r:"'- ..J I 0 .leAse UAA~ V\u 'V\Åloe~ RECEIVED c 11-- JUN 1 1 Z007 Date : Print Name: ~ IA Ñ;,h Lt p ~.L. IA IL",,~ i\laska Oil & Gas Cons. Commission Anchorage PRoAcTIVE DIAGNOSTIC SERVICE$, INc., 130 W.INTERNATIONAl AIRPORT RD SUITE C, ANcHoRAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(â)MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:IMas1er_ Copy _ 00 ]DSANC-2Oxx\Z_ WordlDistnòution\Transmit1aCSheetsITnmsmiU)rigina1.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: CaTTy O Taylor L~ DATE: December 10, 2001 Chairman UBJECT: Mechanical Integrity Tests THRU: Tom Maunder /~f~J'~o~ .~f~)\ BPX MPU-G P.I. Supervisor%~c_\'~ ,~ Pad G-10 FROM: Chuck Scheve MPU Petroleum Inspector Milne Point NON..; CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellIMPU G-10! Type InJ. I SI ~.'v.~. I~ I'Tubing I 1650 I 1650 '1 '1650I ~s0I lntervall I" p.T,.D.[ 197-118 ITypetest, I P 'J,Testp~iI 984 I,,Casin'gl 1750I 2450I 2450I 2450 ,I 'P/FI _P' Notes: Intial test post workover We, I .... P.T.D.I i Notes: "Well , P.T.D.I Notes: P.T,D. Notes: J ~y,e,ni. I I T'V'D' I I '~u~k, I I' '1 I ' J,ntervalJ '" Typetestj ITest psi J', ICasing I 'I , i . I ....I'P/F, I , ITYpe'lni.! ' I ,.v.~. I I :rubing I' I I I ' I lntervall" Typetestl' "lTe~tps'il , , I'Casingl ,' I ,I , ,I ' I, 'PIF I IType Inj.'I ' ' I ~::v.o. ! ' I :l'u'bi~ I ' ' i "I ' I" ' l i~te~all ' Type testl I Testpsil', ,, I Cas'ingl' ,',I ' I ,'1 ! "/F I' Notes: Type INJ. FlUid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W-- Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs G Pad in the MPU and witnessed the initial MIT on well G-10 following a rig workover converting this well to an injector. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured tested for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: I hour cc: MIT report form 5/12/00 L.G. MIT MPU G-10 12-10-01 CS.xls 12/13/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Conversion - Prod to Inject Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1665' FSL, 1929' FWL, Sec. 27, T13N, R10E, UM 5. Type of Well: Development _ Explorato~__ Stratigraphic__ Service__X (asp's 557256, 6014101) 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Milne Point Unit 8. Well number MPG-10 At top of productive interval 1034' FSL, 95' FWL, Sec. 22, T13N, R10E, UM At effective depth 1263' FSL, 31' FWL, Sec. 22, T13N, R10E, UM At total depth 1326' FSL, 13' FWL, Sec. 22, T13N, R10E, UM (asp's 555378, 6018736) (asp's 555311, 6018964) (asp's 555293, 6019027) 9. Permit number / approval number 197-118 10. APl number 50-029-22780 11. Field / Pool Miline Point Unit / Schrader 12. Present well condition summary Total depth: measured true vertical 7765 feet Plugs (measured) 4416 feet Effective depth: measured true vertical 7657 feet Junk (measured) 4330 feet Casing Length Conductor 115' Production 7743' Size Cemented Measured Depth True Vertical Depth 20" 250 SX ArcticSet I (Apprc 144' 144' 7" 1275 sx PF 'E', 150 sx 7743' 4398' Class 'G' RECEIVED Perforation depth: measured Open Perfs Behind Gravel Pack 7270'-7290' ~E.~. (} 1 2001 Open Perfs Below Sump Packer 7420'- 7440', 7506'- 7526~as~a0Jl&GasCorl$.COl~lmjssior~ true vertical Open Perfs Behind Gravel Pack 4024' - 4040'. Anchorage Open Perfs Below Sump Packer 4142'- 4158', 4210'- 4226'. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TBG @ 7014' MD. 2-7/8" L-80 TBG @ 7218'. Packers & SSSV (type & measured depth) 7" x 2-7/8" HES PHS Packer @ 7155'. 7" x 3-1/2" HES Versatrielve PKR @ 7218'. 7" x 2-7/8" HES BWD Sump PKR @ 7306'. 2-7/8" HES 'X' Nipple @ 2198'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/18/2001 Subsequent to operation 11/23/2001 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Shut-in, Water Injection Started 11/19/2001. 1662 Casing Pressure Tubing Pressure 1044 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended _ Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~.l~J~.~ Title: Technical Assistant DeWayne R. Schl'iorr ~ ORI¢INAL Date November 261 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 10/16/2001 1 O/23/2OO 1 11/04/2001 11/16/2001 11/19/2001 11/23/2001 10/16/01 MPG-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DOMOBE POST RWO FREEZE PROTECT CHANGE OUT WING VALVE FROM AWV TO MANUEL VALVE. SET BPV WATER INJECTION STARTED WATER INJECTION RATE - 1662 BWPD EVENT SUMMARY SLICK LINE PREVIOUSLY SET BPV. BLED DOWN AND SAFED OUT SYSTEM. SUPPORT REMOVED FLOW LINES AND FOUNDATION. INSTALLED BLIND FLANGES AND TORDQUED. WELL PREPPED AND READY FOR RWO. 10/23/01 TGSM, MIRU HB&R: PRESSURE TESTED SURFACE EQUIPMENT TO 3500 PSI. FREEZE PROTECT TUBING AND ANNULUS WITH DIESEL TO 2000'. 11/04/01 SUPPORT TECHS REMOVE AWV AND INSTALLED MANUAL WING VALVE. ALL FLANGES TORQUED TO SPEC. JOB COMPLETED. PRESSURE TESTED TO 5000 PSI. 11/16/01 PJSM. SUPPORT SET BPV SO WELL TIE INS COULD INSTALL WELL HOUSE. 11/19/01 WATER INJECTION STARTED. 11/23/01 WATER INJECTION RATE IS 1662 BWPD. TUBING PRESSURE IS 1044 PSI. FLUIDS PUMPED BBLS 145 iDIESEL 145 iTOTAL Page 1 STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to Injector 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 58.20' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1665' NSL, 3350' WEL, SEC. 27, T13N, R10E, UM MPG-10i At top of productive interval 9. Permit Number / Approval No. 197-118 1044' NSL, 92' EWL, SEC. 22, T13N, R10E, UM 10. APl Number At effective depth 50-029-22780-00 1263' NSL, 31' EWL, SEC. 22, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1326' NSL, 13' EWL, SEC. 22, T13N, R10E, UM 12. Present well condition summary Total depth: measured 7765 feet Plugs (measured) true vertical 4416 feet Effective depth: measured 7657 feet Junk (measured) true vertical 4330 feet Casing Length Size Cemented M D TVD Structural Conductor 82' 20" 250 sx Arctic Set 1 (Approx.) 112' 112' Surface Intermediate Production 7713' 7" 1275 sx PF 'E', 150 sx Class 'G' 7743' 4398' Liner Perforation depth: measured Open: 7270'- 7290'; 7430'- 7455'; 7506'- 7526' ~i!~;'j~ .'. ,i~ i~': ~ true vertical Open: 4025' - 4040'; 4142' - 4158'; 4210' - 4226' ,:i "~:: i:!'.',!! ~i: i' ::: ?~:~'~.', ~;:~;~-.~ ~i~;:~, Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 7222' Packers and SSSV (type and measured depth) 7" x 2-7/8" PHS Packer at 7156'; 3-1/2" 250 Micron Poroplus screen with 7" HES Versatrieve packer at 7218' and 7" HES BWD Sump packer at 7306' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water Injection [] Daily Report of Well Operations 17. I hereby certify that the foregoing is~true~ and correct to the best of my knowledge Signed s~~ Title Technical Assistant Date [ t~ ~ '~-~l ' (.~ I Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ~'~ [~ I ~'~t ['\I ~\ t Submit In Duplicate Legal Well Name: MPG-10 Common Well Name: MPG-10 Spud Date: 7/29/1997 Event Name: WORKOVER Start: 10/22/2001 End: 10/27/2001 Contractor Name: NABORS Rig Release: 10/27/2001 Rig Name: NABORS 4ES Rig Number: ......... :~ :~::~ ~ ~:~ ~i~i~: ~ ~::': Description of OPerations 10/22/2001 18:00 - 00:00 6.00 MOB P DECOMP MOVE FROM MP B-02 TO MP G-10 & RU. 10/23/2001 00:00 - 01:00 1.00 MOB P DECOMP FINISH RAISING AND SCOPE UP DERRICK. R/U TIGER TANK. 01:00 - 05:00 4.00 REST P DECOMP TAKE ON 9.7 PPG KWF AND R/U TO KILL WELL. 05:00 - 07:30 2.50 REST P DECOMP OPEN WELL. 40 PSI TBG, 0 PSI ANNULUS. KILL WELL AT 6BPM WITH 1800 PSI. MONITOR WELL-STATIC. 07:30 - 08:00 0.50 REST P DECOMP SET AND TEST TWO 3500 PSI-OK 08:00 - 09:30 1.50 REST P DECOMP BLEED VOID BETWEEN HANGER AND ADAPTER FLANGE. N/D TREE 09:30 - 12:00 2.50 REST P DECOMP N/U BOP'S 12:00 - 13:30 1.50 REST P DECOMP BODY TEST BOP'S. JEFF JONES W/AOGCC WAIVED WITNESSING TEST. 13:30 - 14:30 1.00 REST P DECOMP PJU LUBRICATOR AND PULL TWC. L/D LUBRICATOR 14:30 - 17:30 3.00 REST P DECOMP PU LANDING JT AND SCREW INTO HANGER. BOLDS. PULL HGR TO FLOOR. TEST ESP. LD HGR AND LANDING JT. PU WT 51K. HANG DOUBLE SHEAVE AND ELEPHANT TRUNK FOR ESP AND HEAT TRACE. 17:30 - 18:00 0.50 REST ~ DECOMP ATTACH ESP AND HEAT TRACE TO SPOOLING UNIT 18:00 - 00:00 6.00 REST ~ DECOMP POOH WITH 2-7/8" ESP ASSEMBLY AND HEAT TRACE(SLM) 10/24/2001 00:00 - 03:00 3.00 REST ~ DECOMP POOH WITH ESP ASSEMBLY. SLM 03:00 - 04:00 1.00 REST ~ DECOMP INSPECT ESP AND LD 04:00 - 06:00 2.00 REST ~ DECOMP CLEAR RIG FLOOR. RU HANDLING TOOLS FOR CS HYDRIL TUBING 06:00 - 06:30 0.50 REST ~ DECOMP SERVICE RIG 06:30 - 07:30 1.00 REST P DECOMP PU./MU CLEAN OUT ASSEMBLY. MULE SHOE, XO, 15 JTS 1-14" CS HYDRIL TUBING AND XO TO 2-7/8" TUBING. 07:30 - 12:30 5.00 REST P DECOMP TIH Wl2/718" TUBING. TAG TOP OF PACKER @ 7217' WITH JT# 217. TAG FILL 19' ON JT #219 @ 7268' 12:30 - 22:30 10.00 REST P DECOMP REVERSE CIRCULATE AND WASH 7268'-7626' AT 3.5-4BPM WITH 1000 PSI. TUBING PLUGGED WHILE REVERSE CIRCULATING. ATTEMPT TO PUMP DOWN TUBING-NO LUCK. 22:30 - 00:00 1.50 REST ~ DECOMP POOH ABOVE PACKER 7200'. ATTEMPT TO PUMP DOWN TUBING. STILL PLUGGED. POOH 10/25/2001 00:00 - 04:00 4.00 REST ~ DECOMP CONTINUE POOH WET. STANDING BACK 2-7/8" TUBING IN DERRICK 04:00 - 06:30 2.50 REST ~ DECOMP LD CLEAN OUT BHA. UNPLUG LAST TWO JTS OF TUBING. PLUGGED WITH FRAC SAND. ALSO MULESHOE PLUGGED WITH A PIECE OF COPPER BOLT. XO PLUGGED WITH FORMATION SAND. 06:30- 07:00 0.50 REST P DECOMP ,SERVICE RIG 07:00 - 08:30 1.50 REST P DECOMP MAKE UP CLEAN OUT ASSEMBLY 08:30 - 12:30 4.001 REST P DECOMP RIH WITH CIO BHA AND 2-7/8" TUBING. ClR EVERY 18 STANDS TO MAKE SURE PIPE WAS CLEAR. PUMPED AT 3 BPPM WITH 850 PSI. 12:30 - 15:00 2.50 REST P DECOMP TAG TOP OF PACKER @ 7217'. REVERSE CIRCULATE 20 BBL PILL. 4 BPM @ 850 PSI. 15:00 - 15:30 0.50 REST P DECOMP CONTINUE RIH. TAG TOP OF FILL @ 7626'. 15:30 - 16:30 1.00 REST ~ DECOMP POOH LD 16 JTS 2-7/8" TO ABOVE PACKER. 16:30 - 17:30 1.00 REST ~ DECOMP CUT AND SLIP DRILL LINE 17:30 - 20:30 3.00 REST ~ DECOMP POOH WITH 2-7/8" TUBING AND CLEANOUT BHA. 20:30 - 22:30 2.00 REST ~ DECOMP LD CLEANOUT BHA. Printed: 11/1/2001 9:39:41 AM ReP°rt Legal Well Name: MPG-10 Common Well Name: MPG-10 Spud Date: 7/29/1997 Event Name: VVORKOVER Start: 10/22/2001 End: 10/27/2001 Contractor Name: N^BORS Rig Release: 10/27/2001 Rig Name: N^BORS 4ES Rig Number: ~ i~!~'.~ ~ ~ ~i~ity' ~: ~' ~ha~e: ::'i': :: DeScription of Operations : 10/25/2001 22:30- 23:00 0.50 REST P DECOMP CLEAR FLOOR 23:00 - 00:00 1.00 REST P DECOMP PJSM. RUN COMPLETION STRING PER WELL PLAN. 10/26/2001 00:00 - 03:00 3.00 REST P DECOMP CONTINUE RUNNING 2-7/8" COMPLETION STRING WITH HALLIBURTON "J" LOCATER. TAG TOP OF PACKER @ 7218' 03:00 - 04:00 1.001 REST P DECOMP UN "J" FROM PACKER. PU/MU SPACE OUT PUP JTS, MU HANGER AND LANDING JT. 04:00 - 06:00 2.00 REST P DECOMP R/U AND REVERSE CIRCULATE CORROSION INHIBITOR DOWN ANNULUS. 06:00 - 10:00 4.00 REST P DECOMP DROP BALL AND LAND HANGER 40K UP WT, 23K DOWN WT. ATTEMPT TO VERIFY LATCHED INTO PACKER. "J" WAS NOT LATCHED UP. ROTATED AND WORKED PIPE. SHEARED OUT BALL. WASHED AND WORKED PIPE WITH NO SUCCESS. COULD NOT LATCH INTO PACKER. 10:00 - 13:30 3.50 REST N DFAL DECOMP POOH WITH "J" LATCH ASSEMBLY AND 2-7/8" COMPLETION STRING. 13:30- 14:00 0.50 REST N DFAL DECOMP CLEAR RIG FLOOR 14:00- 14:30 0.50 REST N DFAL DECOMP PU AND MU 6.160 WATERMELON ASSEMBLY 14:30 - 17:30 3.00 REST N DFAL DECOMP TIH WITH MILL ASSEMBLY. TAG TOP OF PACKER 7218' 17:30 - 19:00 1.50 REST N DFAL DECOMP POOH WITH WATERMELON MILL AND LD SAME. 19:00 - 00:00 5.00 REST N DFAL DECOMP MU PHL PACKER AND 2-7/8"COMPLETION ASSEMBLY AND RIH. 10/27/2001 00:00 - 02:30 2.50 REST N DFAL DECOMP CONTINUE RIH WITH HALCO PHS PKR AND 2 7/8" TBG. 02:30- 03:00 0.50 REST N DFAL DECOMP LOCATE SEAL ASSY INTO HALCO VERSATRIEVE PKS. PT ANNU TO VERIFY. 03:00- 04:30 1.50 REST N DFAL DECOMP SPACE OUT. MAKE UP TBG HANGER AND PICK-UP LANDING JT. LAND TBG. RILDS. 04:30 - 06:00 1.50 REST P DECOMP DROP BALL. we BALL TO GO ON SEAT. LAY LINE TO ANN AND TEST TO 3500 PSI. 06:00 - 07:00 1.00 REST P DECOMP SET AND TEST PKR. PERFORM MIT. STATE WAIVED RIGHT TO WITNESS TEST. 07:00 - 07:30 0.50 REST P DECOMP SHEAR RHC PLUG AT 3900 PSI. SHEAR RD PLUG AT 3000 PSI. 07:30 - 08:00 0.50 REST P DECOMP SET AND TEST TWC 08:00 - 09:30 1.50 REST P DECOMP ND BOPE. 09:30 - 11:30 2.00 REST ~ DECOMP CO ADAPTOR HEAD. NU X-MASS TREE. TEST TREE AND ADAPTOR TO 5,000 PSI. 11:30 - 12:30 1.00 REST 3 DECOMP PU LUB. PULL TWC...SET BPV. LD LUB. 12:30 - 14:00 1.50 REST ~ DECOMP CLEAR FLOOR. PREPARE TO RD. FREEZE PROTECT WELL TO 2400-FT MD WITH DIESEL. RELEASE RIG. Printed: 11/1/2001 9:39:41 AM 10/17/2001 14:00 FAX 907 $64 4440 BP-ACT DEFT. BP EXPLORATION Fax cover Sheet To.- CC: REMARKS: ]~ Urgent Number of pages including cover sheet: From'- Phone: Fax phone: 5/,q~., qqq t _ -I I _ F'] For your review F] Reply ASAP [7] Please comment RECEIVED nCT 1_ 7- 2¢Z ..... Alaska Oil & Gas Cons. Anohoraoe .LU/J.'l / ZUU.L .L~; U.L ~JL ~U I 'OOtl ~/~U _' _Tlle_e.: 2 9/16" - 5M W, KM Wellhead: 11" × 11" 5~ FMC; Gert ~i w/ 11" x 2 7/8" WKM :Tubing Hange~, w/2715"NSCTT&B,~.5"CIWH JBPVprofile 20" 91.1ppf, H--40 ' [ 115' !a Orig. DF Bier. = 5, ~'N 22E) Orlg, GL Bier, = 29.2' DF To Tbg. Hnr. -- 30.45' (N KOP @ 500' i Max. hole angle -- 76~ to 79 deg. fl 3300' tO 5900' Hole angle thru' perfs! = 37 deg Howco T' 'ES' Cementer 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg_. ( drift ID = 2.347", cap. -- 0,00592 bpf ) 7" 26 ppf, L-80, Btm. 'prod. casing ( drift ID = 6,151", cap. -- 0.0383 bpf ) 7" short joint from ?09t' to 7131' md Stimulation .$umma~: 03/29198- 'OB' 29,500 lbS, ~1' neutral 16-20 PmpLok resin behind pipe, Screened out on 9 ppg, 04/01/9~, 'OA' - 75,500 tbs bf Red re,~ln coated 16-20 Carbolite behind pipe. Screened out on 10 ppg. 04/03/9B - 'N' - 20,561 Ib~. o'f Blue resin coaled 16-20 Ca~bollte behll~d pipe, Screened out wi[h 9 ppg. Perforation Summary .l~ef IocJ: MWD 08102197 COMMENTS Drilled and Cased by Nabors Fac & PCP Completion 4 es Screen off N-sands ! ComplelJon 2-7/8" X Nipple 2.313 J-Slot Locator and Seal Assembly with Mule Shoe latched on to HES Veraatdeve Packer 7" HESVersatrieve pkr. i 7,218' -- 3.5"250 Micron Poroplus screeLT_~~ 7" HIES BWD Sump Packer, L 7,306' 2-7/8" HES X Nipple 2.313" ID[ 7,312' 7' Landing collar (PBTD) 7,658' __ 7" float collar 7,6gg' ?" float ~hoe 7,743' tMILNE POINT UNIT WELL G-I 0 APl NO: 50-029-22780 BP EXPLORATION (AK) RECEIVED OCT 17 2001 10/17/Z001 14:01 ?'A~ 907 ~4 ~ ...... Yree: 2 9/16" - 5M WKM .Wellhead:Il" x 11" 5M FMC Gen w/ 11" x 2 7/8" WKM Tubing Hangel w/2 718" NSCT T&B, 2.5" CIW H BPV profile 20" 91.1 ,p,,.40 [ 1,5' ! 4440 DE-AL;'I' -- '/!Pt G-I',0 o.g. OF e,~. = 5. ~N 22E) Orig. ~L Elev. = 29.2. DF To Tbg. Hnr. = 30_45' (N Max. hole angle '- 76 to 79 deg. f/3300' to 5900' Hole angle thru' parrs = 37 deg Camco 2 718" x 1" ! 153' j KBMM GLM Rachem hem tract Howco 7" 'ES' Cementer I 2,130' J 2 7/8" 6.5 ppf, L~80, 8 rd EUE tbg,. ( drift ID -- 2.347", cap. = 0.00592 bpi' ) 7" 26 ppf, L-80, Bbc. prod. easing (drift ID = 6.'i51", cap. = 0.0383 bpf ) Camco 2 7/8" x 1" ~_· 2,798' KBMM GLM Stimulation Summary: 03/29/98- 'Oi~' 29,500 lbs. ol; neutral 1~-20 PmpLok resin behind pipe. SCreened out on 9 ppg, 04/01~8- 'CA' - ?~,SO0 lbs of Red main coated 16-20 Carbollte behind pipe. ~crcened out on 10 Pl3g, 04/03198 - 'N'. 20,561 lbs. of Blue resin coated 16-20 Carbolite behind pll~e. Screened out with 9 ppg. Perforation ~ummary Ref Ica: MWD 0810219-I' -- Size l' ..~PF Interval (]-VD) I 4.fi~t 4 ,4.5" / 4 N-$ende 7,270'-?.29C OA-Sand~ 7,430'-7455 7,50E~'-7,526 4,026'-4.040' 4,150'-4,170' 4,210'-4,225 7" short joint rTom 7091' to 7131~ md Centriliff PCP 200TP1600 Flexshaff Centrilfft GSTDBIL seal section Gear reduction unit Centrilift GMF 562 series, 63 hp motor, 1560 v. / 26 amps. PHD 7" HES Versatdeve pkr. ~ 3.5"250 Micron Poroplus screen-- 7.264' 7" HIES BWD Sump Packer. ~ 2-7/8" HES X Nipple 2.313" IDI 7,312'_] N - 4.5' AUas Big Hole 6 spf. 90 deg, Phasing CA & OB - $W$ 43C-UP 4 spf I g0 dog, RDX DATE 08/04/97 04/11/98 JBF MDC) COMMENTS Drilled and Cased by Nabors 22E Fac & PCP Completion 4 es 06/21/98 M. Linder Screen off N-sands / Completion 7" Landing collar (PI~TD) 7,658' 7" float collar 7,699' 7" float shoe MILNE POINT UNIT WELL G-'10 ; APl NO: 50-029-22780 BP EXPLORATION (AK) ON OR BEFORE iANUARY 03 2001 W C:LOREM~ILM'DOC Well Compliance Report File.0n.Left side off0!der ............................................... ..... :: ,- .................... _._ 197-118-0 MILNE POINT UNIT SB G-10 50- 029-22780-00 BP EXPLORATION MD 07q65 TV~i6 ~o~ple~tion Date: '4~/6/98 Completed Status: 1-OIL Current: . _ . T Name f. Interval Sent Received D 8112 ~2~ SPERRY MPT/GR/EWR4 OH 9/26/97 9/26/97 L DGR/EWR4-MD L DGR/EWR4-TVD L PERF L PERF ~AL 4962-7765 OH F~AL 3075-4415 OH {~INAL 7040-7306 ~ ~ C~O~ CH t~INAL 6600-7595 3/29/98 / CH L PERF b~XL 7030-7435 3/30/98 CH L SETTiNGSRVC ~INAL 7010-7344 (~t~/fg/~ CH Daily Well Ops 7.~ _~!_ -- ~/~/] q ~ Was the well cored? yes ~ ........ T/C/D ... 9/26/97 9/26/97 9/26/97 9/26/97 4/12/98 4/15/98 8/17/98 8/20/98 8/17/98 8/20/98 C~ IA. L~ 6/21/98 6/25/98 Are Dry Ditch Samples Required? yes ~-.~ And Re~" Analysis Description Received.X~yes no Sample Set # Comments: Monday, May 01, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing r--]Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1665' NSL, 3350' WEL, SEC. 27, T13N, R10E, UM At top of productive interval 1122' NSL, 5218' WEL, SEC. 22, T13N, R10E, UM At effective depth 1263' NSL, 5257' WEL, SEC. 22, T13N, R10E, UM At total depth 1326' NSL, 5275' WEL, SEC. 22, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RTE = 58.2 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-10 9. Permit Number / Approval No. 97-118 10. APl Number 50- 029-22780 ,, 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 7765 feet true vertical 4415 feet Effective depth: measured 7657 feet true vertical 4330 feet Casing Length Structural Conductor Sudace Intermediate Production Liner Size 83' 24" . Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1275 sx PF 'E', 150 sx Class 'G' MD TVD 112' 112' 7743' 4398' Perforation depth: measured true vertical 7270' - 7290', 7420' - 7440', 7506' - 7526' (Subsea) 3966' - 3982', 4084' - 4100', 4152' - 4168' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 7009' Packers and SSSV (type and measured depth) ORIGINAL 13. Stimulation or cement squeeze summary RECEI EO Intervals treated (measured) Treatment description including volumes used and final pressure Naska 0ii & Gas Cons. Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments r--] copies of Logs and Surveys run ~-Daily Report of Well Operations 16, Status of well classifications as: [~ Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed J~ ~-"/' ~ Title Staff Technical Assistant Prepared By Name/Number: Date Jeanne L. I-I/aas, 5[~4-5225 Facility Date/Time 15 Jun 98 16 Jun 98 17 Jun 98 18 Jun 98 19 Jun 98 20 Jun 98 Progress Report M Pt G Pad Well MPG-10 Page 1 Rig Nabors 5S Date 15 July 98 06:00-06:15 06:15-15:30 15:30-16:30 16:30-18:00 18:00-18:15 18:15-21:30 21:30-22:00 22:00-23:00 23:00-01 '30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:15 06:15-07:30 07:30-11:00 11:00-23:00 23:00-03:00 03:00-06:00 06:00-06:15 06:15-09:30 09:30-11:00 11:00-12:00 12:00-15:00 15:00-18:00 18:00-18:15 18:15-19:30 19:30-20:00 20:00-22:00 22:00-01:30 01:30-06:00 06:00-06:15 06:15-08:30 08:30-10:30 10:30-16:00 16:00-21:30 21:30-22:00 22:00-22:30 22:30-02:00 02:00-03:30 03:30-06:00 06:00-20:30 20:30-00:30 00:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 Duration 1/4 hr 9-1/4 hr Ilar 1-1/2 hr 1/4 hr 3-1/4 hr 1/2 hr 1 hr 2-1/2 hr lhr lhr 2-1/2 hr 1/4 hr 1-1/4 hr 3-1/2 hr 12hr 4 hr 3 hr 1/4 hr 3-1/4 hr 1-1/2 hr lhr 3hr 3hr 1/4 hr 1-1/4 hr 1/2 hr 2hr 3-1/2 hr 4-1/2 hr 1/4 hr 2-1/4 hr 2hr 5-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr 14-1/2 hr 4hr 1-1/2 hr 2hr lhr lhr Activity Held safety meeting Rig moved 100.00 % Rigged up Completion string handling equipment Removed Hanger plug Held safety meeting Circulated at 6980.0 ft Monitor wellbore pressures Monitor wellbore pressures Circulated at 6980.0 ft Removed Xmas tree Installed BOP stack Tested All rams Held safety meeting Tested BOP stack Removed Tubing hanger Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 4000.0 ft Held safety meeting Ran Tubing in stands to 6900.0 ft Singled in drill pipe to 7524.0 ft Washed to 7524.0 ft Washed to 7658.0 ft Reverse circulated at 7658.0 ft Held safety meeting Laid down 504.0 ft of Tubing Flow check Circulated at 7152.0 ft Pulled Tubing in stands to 0.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Installed Other sub-surface equipment Ran Tubing in stands to 7297.0 ft Set packer at 7218.0 ft with 1800.0 psi Reverse circulated at 7215.0 ft Laid down 504.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Installed ESP Ran Tubing in stands to 3000.0 ft Installed ESP Installed Tubing hanger Removed BOP stack Installed Xmas tree Serviced Block line Displace treatment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of operator ............................................ 7. 'Permit Number " BP Exploration (Alaska)Inc. 97-118 ..... 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22780 4. AtL°cati°ntop of OfproductiveWell at surfaCeinterval ~'~'::~ ~¥?'~/.~ :~ ';"~ !~~~_ 9. Unit or Lease Name 1665' NSL, 3350' WEL, SEC. 27, T13N, R10E, UM ~ ~ :'-'~ ~ Milne Point Unit i ~~,,~... i "~'0. Well'"~umber ............... 1122' NSL, 5218' WEL, SEC. 22, T13N, R10E, UM ~'~ ,f,.:~,..,~.~ ~ MPG-10 At total depth i ~-~ii 11. Field and Pool 1326' NSL, 5275' WEL, SEC. 22, T13N, R10E, UM .~- ...... ~:~-~,~. Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 58.20'I ADL 025516 12. Date Spudded ..... ]13. Date T.D. Reached ]14. Date Comp., Susp., or Aba~'~'iI15. water depth, i'f offshore i i~".""No, of completions 7/29/97I 8/2/97i 4/6/98 ..............I N/A. MSLI One 17. Total Depth (MD+TVD) 118. Plug Back DePth (MD+TVa)II9. Dir%tional Survey ]20. Depth whe~e'"~'Ssv set ]21. Thickness of permafrost 7765 4416 FTI 7657 4330 FTI []Yes [---] No! N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/RES, GR/CCL ...... 23. . . CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUN'E._Pu~L,ED, 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Appro.x. ~).. ~ '7" 26# L-80 30' 7743' 8-1/2" 127'5 sx PF 'E', 150 sx Class 'G' ' ......... ' 24. Perforations open to Production (MD+TVD of T°P'"~'~d i25. TUBING RECORD Anch0~'age Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 7072' MD TVD MD TVD 7270'-7290' 4024'-4040 ........................................ 7420'-7440' 4142'-4158' 26. AC'iD, FRACTURE, CEMENT SQUEEZE, ETC. 7506'-7526' 4210'-4226' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 79 bbls diesel Proplok frac, 7506'-7526' 29500# 16/20 Carbolite behind pipe Frac, 7420'-7440' 74727# 16/20 Carbolite behind pipe Frac, 7270'-7290' 20561# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First production .............. I Method of'Operation (Flowing, gas lift, etCi'i ............................. April 24, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA ........ Bri~l?'~iescription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests ...... Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBE 7287' 4038' TSBD 7419' 4142' TSBC 7463' 4176' TSBB 7504' 4209' 3~. List of Attachments 8ummary of Daily Drilling ~epoAs, 8urveys ~g~~(*~'~~ Title Drilling Engineerin Supervisor Da~9 r~~r ~ ~ .... g .... . ..... MPG-10 97-118 Prepared By Name/Number: Kathy Campoamor, 564-5122 ....... We,? ,~,~mber ............. Perm, i~, No. / Approv~,,,~.9. , ........................ INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 (DF, 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 Progress Report Facility M Pt G Pad Well MPG-10 Rig Nabors ~1~~ Page 1 Date 01 June 98 Date/Time 28 Jul 97 11:01-12:00 12:00-12:30 12:30-18:00 18:00-18:30 18:30-23:00 23:00-01:00 29 Jul 97 01:00-02:30 02:30-06:00 06:00-06:30 06:30-00:00 30 Jul 97 00:00-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-11:30 11:30-12:30 12:30-14:15 14:15-15:00 15:00-15:30 15:30-16:00 16:00-17:30 17:30-02:00 31 Jul 97 02:00-03:00 03:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-10:00 10:00-11:00 11:00-14:30 14:30-21:30 21:30-22:30 22:30-01:00 01 Aug 97 01:00-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-16:00 16:00-18:00 18:00-19:00 19:00-19:30 19:30-03:30 02 Aug 97 03:30-05:30 05:30-06:00 06:00-10:00 10:00-10:30 10:30-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-18:30 Duration 3/4 hr 1/2 hr 5-1/2 hr 1/2 hr 4-1/2 hr 2hr 1-1/2 hr 3-1/2 hr 1/2 hr 17-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 5-1/2 hr lhr 1-3/4 hr 3/4 hr 1/2 hr 1/2 hr 1-1/2 hr 8-1/2 hr lhr 3hr 1 hr 1/2 hr 1/2 hr lhr lhr lhr 3-1/2 hr 7hr 1 hr 2-1/2 hr 1/2 hr 2hr lhr 1-1/2 hr 10hr 2hr lhr 1/2 hr 8hr 2hr 1/2 hr 4hr 1/2 hr 1/2 hr 1 hr lhr lhr 1 hr 3-1/2 hr Activity Rigged down Drillfloor / Derrick Held safety meeting Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Installed Drillfloor / Derrick Rigged up Bell nipple Made up BHA no. 1 Held safety meeting Drilled to 2284.0 ft Circulated at 2284.0 ft Pulled out of hole to 92.0 ft Serviced Top drive R.I.H. to 2284.0 ft Drilled to 2748.0 ft Drilled to 3575.0 ft (cont...) Circulated at 3575.0 ft Pulled out of hole to 725.0 ft Pulled BHA Serviced Top drive Made up BHA no. 1 R.I.H. to 3575.0 ft Drilled to 4963.0 ft Circulated at 4963.0 ft Pulled out of hole to 3950.0 ft Pulled out of hole to 725.0 ft Downloaded MWD tool Pulled BHA Made up BHA no. 2 Serviced Top drive Serviced Block line R.I.H. to 4963.0 ft Drilled to 6007.0 ft Circulated at 6007.0 ft Pulled out of hole to 1900.0 ft Serviced Top drive R.I.H. to 5435.0 ft Reamed to 6007.0 ft Drilled to 6102.0 ft Drilled to 7151.0 ft Circulated at 7151.0 ft Pulled out of hole to 5913.0 ft R.I.H. to 7151.0 ft Drilled to 7765.0 ft Circulated at 7765.0 ft Pulled out of hole to 7000.0 ft Pulled out of hole to 732.0 ft Pulled BHA Downloaded MWD tool Serviced Top drive Made up BHA no. 2 Repaired Top drive Serviced Block line R.I.H. to 7765.0 ft Progress Report Facility M Pt G Pad Well MPG- 10 Rig Nabors ~1~;~ Page 2 Date 01 June 98 Date/Time 18:30-21:00 21:00-00:00 03 Aug 97 00:00-01:00 01:00-02:15 02:15-02:30 02:30-06:00 06:00-06:00 06:00-10:30 10:30-11:00 11:00-13:30 13:30-14:15 14:15-15:00 15:00-15:15 15:15-17:00 17:00-18:00 18:00-18:30 18:30-19:45 19:45-21:30 21:30-23:00 23:00-00:00 04 Aug 97 00:00-01:00 01:00-03:00 Duration 2-1/2 hr 3hr lhr 1-1/4 hr 1/4 hr 3-1/2 hr 0hr 4-1/2 hr 1/2 hr 2-1/2 hr 3/4 hr 3/4 hr 1/4 hr 1-3/4 hr 1 hr 1/2 hr 1-1/4 hr 1-3/4 hr 1-1/2 hr lhr ilar 2hr Activity Circulated at 7765.0 ft Pulled out of hole to 732.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 3400.0 ft (7in OD) Ran Casing to 7743.0 ft (7in OD) Ran Casing to 7743.0 ft (7in OD) Rigged up Cement head Circulated at 7743.0 ft Mixed and pumped slurry - 199.000 bbl Displaced slurry - 287.000 bbl Functioned DV collar Circulated at 2130.0 ft Mixed and pumped slurry - 358.000 bbl Displaced slurry - 81.000 bbl Cleared Header box Rigged down Casing handling equipment Removed Divertor Installed Casing head Installed Adapter spool Rigged up All tree valves Facility M Pt G Pad Progress Report Well MPG-10 Page 1 Rig Nabors 4ES Date 01 June 98 Date/Time 26 Mar 98 27 Mar 98 28 Mar 98 29 Mar 98 30 Mar 98 31 Mar 98 01 Apr 98 09:00-15:00 15:00-16:30 16:30-20:30 20:30-00:00 00:00-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-11:00 11:00-17:00 17:00-23:30 23:30-03:00 03:00-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-11:30 11:30-14:00 14:00-15:00 15:00-18:30 18:30-02:30 02:30-03:30 03:30-06:00 06:00-10:30 10:30-12:30 12:30-17:00 17:00-18:00 18:00-22:00 22:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-15:00 15:00-16:00 16:00-22:00 22:00-00:30 00:30-04:30 04:30-06:00 06:00-07:00 07:00-09:30 09:30-12:30 12:30-14:00 14:00-16:00 16:00-18:00 18:00-19:30 19:30-03:30 03:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:15 07:15-07:30 Duration 6hr 1-1/2 hr 4hr 3-1/2 hr 6hr 1/2 hr 2hr 2hr 1/2 hr 6hr 6-1/2 hr 3-1/2 hr 3hr 1/2 hr 4hr 1/2 hr 1/2 hr 2-1/2 hr lhr 3-1/2 hr 8hr lhr 2-1/2 hr 4-1/2 hr 2hr 4-1/2 hr lhr 4hr 6hr 1/2 hr 1/2 hr 1 hr 1/2 hr 5-1/2 hr 3 hr lhr 6hr 2-1/2 hr 4hr 1-1/2 hr lhr 2-1/2 hr 3 hr 1-1/2 hr 2hr 2hr 1-1/2 hr 8hr 2hr 1/2 hr 1/4 hr 1/4 hr 3/4 hr 1/4 hr Activity Rig moved 100.00 % Functioned Xmas tree Rigged up BOP stack Tested BOP stack Singled in drill pipe to 1500.0 ft Held safety meeting Singled in drill pipe to 2122.0 ft Drilled installed equipment - DV collar Tested DV collar - Via annulus and string Singled in drill pipe to 7628.0 ft Circulated at 7628.0 ft Circulated at 7628.0 ft Pulled out of hole to 0.0 ft Held safety meeting Pumped out of hole to 7609.0 ft Reverse circulated at 7609.0 ft Tested Casing - Via annulus and string Pulled out of hole to 0.0 ft Worked on BOP - Lubricator Worked on BOP - Lubricator Perforated from 7506.0 ft to 7526.0 ft Worked on BOP - Lubricator Ran Tubing to 3000.0 ft (3-1/2in OD) Ran Tubing to 7030.0 ft (3-1/2in OD) Tested High pressure lines Injectivity test - 180.000 bbl injected at 4500.0 psi Mixed and pumped 322.000 bbl of treatment Monitor wellbore pressures Reverse circulated at 7477.0 ft Injectivity test - 3.000 bbl injected at 1100.0 psi Laid down 471.0 ft of Tubing Circulated at 7005.0 ft Held safety meeting Circulated at 7005.0 ft Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Rig waited · Service personnel Rigged up sub-surface equipment - Gun assembly Perforated from 7420.0 ft to 7440.0 ft Worked on BOP - Lubricator Worked on BOP - Lubricator Ran Tubing to 6965.0 ft (3-1/2in OD) Rigged up High pressure lines Injectivity test - 185.000 bbl injected at 4155.0 psi FRAC job - 116.000 bbl injected at 3203.0 psi FRAC job - 139.000 bbl injected at 3445.0 psi FRAC job - 448.000 bbl injected at 4246.0 psi Monitor wellbore pressures Ran Tubing to 7267.0 ft (3-1/2in OD) Pulled Tubing in stands to 7200.0 ft Held safety meeting Flow check Laid down 473.0 ft of Tubing Flow check Progress Report Facility M Pt G Pad Well MPG- 10 Rig Nabors 4ES Page 2 Date 01 June 98 Date/Time 02 Apr 98 03 Apr 98 07:30-09:00 09:00-09:15 09:15-10:45 10:45-11:00 11:00-14:00 14:00-14:30 14:30-16:30 16:30-19:00 19:00-19:30 19:30-20:15 20:15-20:30 20:30-21:00 21:00-21:30 21:30-23:00 23:00-23:30 23:30-00:00 00:00-02:30 02:30-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-14:15 14:15-15:00 15:00-15:30 15:30-16:00 16:00-16:30 16:30-16:45 16:45-17:15 17:15-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-22:30 22:30-23:00 23:00-23:30 23:30-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-09:30 09:30-15:30 15:30-16:00 16:00-16:30 16:30-18:30 18:30-06:00 Duration 1-1/2 hr 1/4 hr 1-1/2 hr 1/4 hr 3hr 1/2 hr 2hr 2-1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 2hr 1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 3/4 hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 6-1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr 6hr 1/2 hr 1/2 hr 2 hr 11-1/2 hr Activity Circulated at 5810.0 ft Flow check Circulated at 5810.0 ft Flow check Pulled Tubing in stands to 0.0 ft Made up BHA no. 4 R.I.H. to 6267.0 ft Reverse circulated at 7330.0 ft Tested Other sub-surface equipment - Via string Circulated at 7330.0 ft Flow check Laid down 95.0 fl of 3-1/2in OD drill pipe Serviced Block line Pulled out of hole to 198.0 ft Pulled BHA Installed Well control Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Rigged down Logging/braided cable equipment Installed BOP test plug assembly Held safety meeting Serviced Drillfloor / Derrick Tested All functions Installed Wear bushing Rigged up Tubing handling equipment Ran Tubing in stands to 6807.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 49.400 bbl injected at 1850.0 psi Investigated pressure change Rigged down High pressure lines Pulled Tubing in stands to 6530.0 ft Reverse circulated at 6530.0 ft Ran Tubing in stands to 6807.0 ft Reverse circulated at 6807.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines FRAC job - 385.000 bbl injected at 4075.0 psi Monitor pressures FRAC job - 243.000 bbl injected at 4653.0 psi Reverse circulated at 6807.0 ft Monitor pressures Monitor pressures (cont...) Bleed down well Reverse circulated at 6807.0 ft Flow check Laid down 6807.0 ft of Tubing Rigged up Drillstring handling equipment Made up BHA no. 5 R.I.H. to 6984.0 ft Washed to 7515.0 ft Progress Report Facility M Pt G Pad Well MPG-10 Rig Nabors 4ES Page 3 Date 01 June 98 Date/Time 04 Apr 98 05 Apr 98 06 Apr 98 06:00-09:00 09:00-10:30 10:30-10:45 10:45-11:45 11:45-12:00 12:00-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-20:00 20:00-21:30 21:30-22:30 22:30-23:15 23:15-23:30 23:30-00:30 00:30-02:30 02:30-06:00 06:00-06:15 06:15-08:30 08:30-11:15 11:15-11:30 11:30-23:30 23:30-00:30 00:30-02:00 02:00-02:30 02:30-03:15 03:15-03:30 03:30-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-06:45 06:45-07:00 07:00-07:30 07:30-09:00 Duration 3hr 1-1/2 hr 1/4 hr lhr 1/4 hr 6hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 3/4 hr 1/4 hr lhr 2 hr 3-1/2 hr 1/4 hr 2-1/4 hr 2-3/4 hr 1/4 hr 12hr lhr 1-1/2 hr 1/2 hr 3/4 hr 1/4 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr 1/2 hr 1-1/2 hr Activity Washed to 7515.0 ft (cont...) Reverse circulated at 7628.0 ft Flow check Circulated at 7628.0 ft Flow check Laid down 7437.0 ft of 3-1/2in OD drill pipe Held safety meeting Pulled BHA Retrieved Wear bushing Rigged up Tubing handling equipment Ran Tubing to 2300.0 ft (2-7/8in OD) Pulled Tubing in stands to 0.0 ft Rigged up Completion string handling equipment Held safety meeting Installed Electrical submersible pumps Installed Pressure gauge Ran Tubing to 1635.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 4752.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Electric cable Held safety meeting Ran Tubing in stands to 7069.0 ft Rigged up sub-surface equipment - Hanger assembly Installed Electric cable Installed Downhole pressure gauge cable Ran Tubing on landing string to 7071.0 ft Installed Hanger plug Removed BOP stack Installed Adapter spool Tested Adapter spool Installed Xmas tree Held safety meeting Installed Xmas tree Tested Xmas tree Installed Hanger plug Freeze protect well - 79.000 bbl of Diesel Milne Point Unit, Alaska TO: Bill Hill FROM: Herb Thackeray Well Name: IMP G-10 Main Category: IDRLG Sub Category: IELINE PERF Operation Date: 13-28/29-98 Date: 13-29-98 MPU FILE COpy Objective: E-Line conveyed perforate Schrader Bluff "OB" sands. Sequence of Events: 3/28/98 1830 MI RU Schlumberger E-Line. (Unit does not have a marked line). 2000 PJSM. SAFE system available, radio silence not required. 2015 PU lubricator. MU toolstring - rollerstem w/5" wheels, 20' 4 ~,,~" guns, SAFE detonator, another roller, GR/CCL. Total length 41.1' 2145 PT lubricator to 500 psi. 2150 RIH. Max angle 79 degrees. No problem getting downhole on 5" rollers. 2320 Tag "sticky" PBTD @ 7628'. Log GR/CCL up to 6600'. 2345 Drop back down to 7560'. Tie into MWD log 8/2/97 (adjust 1.5') 3/29/98 1210 Perforate "OB" sand from 7506 - 7526' (20') with 4 ~" guns loaded with 4 spf "Big Hole" charges at 180 degree phasing. POOH. 0145 At surface, all shots fired. Fluid level not changing noticeably. RD SWS. Results: Ran GR/CCL from sticky PBTD @ 7628' to 6600'. Tie into Sperry Sun MWD log 8/2/97. Perforate "OB" sand from 7506 -7526' with 4 spf 180 degree phasing. Tie in log/date: Sperry Sun MWD 8/2/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density 7506 7526 4 ~ 4 Orientation Phasing 180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Jim Spearman FROM: Jim Fox DATE: 03/29/98 RE: MPU G-10 'OB' DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY 29,500 # of PropLok resin coated 16/20 Carbolite proppant was placed behind pipe. The designed quantity of 78,000 # was not reached due to a premature screen out when the 9 ppg hit the formation and screened out. Prior to that there was no net pressure build other than a quick 110 psi increase (which then stabilized) when the 8 ppg slurry hit the formation. A 100 bbl. 60ppt. HEC injectivity test was performed initially. The gel was circulated to the end of the tubing, squeezed at matrix rate to the sand face, and then brought up to max. rate (up to 25 bpm) for 80 bbl. and then reduced to 20 bpm for the last 20 bbl. The pressure falloff indicated a NWFP of 40 psi. and ISIP of 890 psi. The data frac which followed consisted of; 195 bbl. of 60 ppt HEC gel circulated to the end of the tubing, squeezed at matrix rates to the sand face, bullheaded at 20 bpm, and overdisplaced into the formation by 5 bbl. The pressure falloff indicated 90 psi of NWFP and an ISIP of 834 psi. Notes: · The resin is clear (i.e. not dyed)'and therefore proppant will be natural colored if recovered the future. · Wellbore fluids were 8.9 ppg NaC1. This may have been diluted slightly as the lighter fluid was pumped past the end of the tubing and migrated / was displaced by the heavier fluid in the annulus. · All proppant was coated at a concentration of 0.375 gal of Halliburton PropLok per 100 # of proppant. Prior to coming up to full rate on injectivity and data frac matrix injection was shut down for 2 to 3 minutes to allow any micro fractures to close. The frac string consisted of 3.5" 9.3 ppf tubing run to 7029' md. Tbg. Cap. = 60.9 bbl., casing cap. from EOT to top perf = 19.4 bbl. Total displacement = 80.3 bbl. Slick 2% KC1 water was used for displacement. 05/27/98 8:19 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL BPM PSlG I PSlGI BBL BBL PUMPING SUMMARY COMMENTS INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft max. 100 25 930 890 40 0.67 DATA FRAC Bbls Bbls XL gel Time gel on Final lAP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs peals psi psi/ff 200 195 9:45 927 834 93 0.66 FRAC Sand Lead prop Tail prop Design total Final lAP pumped, behind pipe, behind behind pipe, Liner Sand, prior to Job was M# M# pipe, M# M# M# screen out, /size /size psi Screened out 54.5 M# 29.5 M# not 78. M# 31.3 M# 1080 16/20 appl. DATE/TIME OPERATIONS SUMMARY I 03/29/98 weather: -2 deg. F ! calm winds 1130 Pre-job safety meeting. 1222 Pressure test surface lines - OK !1230 Start circulating 60# HEC gel to the end of the tubing tail at 8 bpm taking returns to Nabors 4ES pits. 1242 Bullhead gel to perfs at matrix rates. 1300 Come up to max. rate for injectivity test 1304 Slow pump rate down and maintain constant 20 bpm rate for last 20 bbl. 1306 Shut down pumps and monitor falloff pressures. IA ISIP -- 890 psig. 1340 Start circulating 60 ppt HEC gel to the end of the tubing. 1351 Bullhead gel to perfs at matrix rates. 1407 Start coming up to 20 bpm data frac rate. 1417.5 Shut down pumps and monitor falloff pressures. IA ISIP - 834 psig. 1652 Start pumping pad for the frac. 11708 Wellbore screened out. Shut down pumps and prepare for the rig to reverse out the tubing. PUMPING SUMMARY TIME I RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 03/29/98 INJECTIVITY TEST DISPLACEMENT = 80.3 BBLS 1230 7.5 12 861 4 4 Start Circulation of 60# HEC to the end of the tbg. ,1234 7.7 12 1291 30 30 1238 8 / 0 8 1136 61 61.1 HEC at the end of the tubing. S/D to close in annulus. 1242.5 0 / 1.4 866 455 0.5 61.6 Bullhead gel to sand fa~e at matrix rates. 1244 1.5 843 1246 2.7 63.8 1248 1.4 909 1296 8 69.5 1252 1.4 957 1346 13 74.9 1256 1.5 / 0 997 1374 20 81.1 Shut down to allow microfractures to close.. 1259 0 / max. 791 797 81.1 Start coming up to max. rate. 1300.5 20.7 1085 3905 95.5 Back off rate due to air in suction when ~ swapping to slick water. 1301.5 12 / max. 990 3260 25 106 Bringing rate back up to, max. 1302.5 23.9 960 4066 130 1303 24.3 944 4400 151 1304 23 / 20 924 4427 165 Slow rate to 20 bpm for last 20 bbl. 1306 20 / 0 929 4257 187.2 Shut down pumps and monitor pressure falloff. IA ISIP = 890 psif:j 1308 0 744 820 ,,. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1310 0 724 802 1315 0 691 765 1320 0 662 737 1325 0 642 715 133O 0 623 696 DATA FRAC 1340 0 / 8 6 69 187.2 Prepare to circulate 60 ppt gel to the end of the tbg. 1341 6.6 12 614 196.5 1343 8.0 12 916 210 1347 8.2 / 0 10 904 59.6 246.9 $/D pumps to close in annulus. 1351 0 / 1 678 1095 246.9 Bullhead gel to sand face at matrix rates. 1354.5 1.5 885 1227 251.7 1400 1.5 891 1236 260.6 1403.5 1.5 / 0 905 1255 79.3 266.5 Gel 1 bbl. from perfs. Shut pumps down and allow a couple minutes for microfractures to close. 1407 0 / 20 777 829 0 266.5 Start coming up to rate.- 1408+ 20 1057 3179 12.5 279 At rate. 1410 20.1 1028 3040 317 1412 20.2 970 2880 360 1413+ 20.2 955 2875 114 381 Go to flush. 1416 19.7 937 3502 430 1417.5 20 / 0 927 4148 200.6 467.1 S/D pumps and monitor pressure falloff. 1420 0 777 820 1425 0 744 788 1430 0 721 765 1440 0 680 724 1450 0 647 692 1500 0 625 669 1510 0 601 651 1518 0 585 637 FRAC 1652 0 / 20 407 454 0 0 Start pumping 54 bbl. 60 ppt HEC gel pad. 1653 20 957 4244 16.4 16.4 At rate. 1655 20.6 940 3328 54 / 0 54 Start pumping PropLok coated 16 / 20 proppant 1656 20.4 904 2756 27 81 Gel on perfs. 1657 19.9 942 2660 46 100 PUMPING SUMMARY TIME RATE i ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1659 20.1 946 2926 135 I ppg. slurry on perfs. 1702 20.1 940 3067 205 Middle of 4 ppg stage slurry on perfs. 1704 20.1 960 3127 241 Early 7 ppg stage on perfs. 1705 20.2 973 3177 263 8 ppg stage just hitting perfs. Treating pressure stable. 1705.5 19.8 1006 3086 271 Sudden increase in IA treating pressure. 1706 19.5 1072 3333 279 Treating pressure stabilizing. 1707 20.1 1059 3512 303 9 ppg hitting perfs. 1707.7 20.1 1080 3338 315 Middle of 9 ppg stage on perfs. 1708 20 / 0 2623 2170 321.6 Sudden increase in treating pressure. Shut down pumps due to screen out. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 345 Bbls FRAC: 322 Bbls 667 BBLs TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME IINONE PETREDAT WINDOW GEL QUALITY CONTROL CHECK SEA H20 60 #gel temp 60# GEL 60# GEL pH TEMP pH VISCOSITY DF/FRAC 7 80 7 FLUID ADDITIVES DS 60#/Mgal HEC system w/2.5 gpt J-134, 2 gpt F-75N. All 16/20 Carbolite coated with Halliburton PropLok at 0.375 gal/100# proppant, ES-5 surfactant at 2 gal/ 100#. Milne Point Unit, Alaska TO: Bill Hill FROM: Kirby Walker Well Name: MPU G-10 Main Category: PERF Sub Category: E-LINE Operation Date: 03/31/98 Date: I March 31, 1998 Objective: To perforate the OA Sand from 7,420'-7,440' using 4.5" guns, 0°-180° phased, 4 spf. Sequence of Events: 1930 0030 0045 0220 0245 O25O SIb on location. Rig up lubricator and gun assembly. Pressure test lubricator to 500 psi. RIH w/gun assembly Tag sand @ 7,463'. Log into position. Fire gun and perforate OA Sand from 7,420' - 7,440'. (Positive indication of guns firing through decrease in tension.) POOH. RDMO SIb. Results: The OA sand was perforated by Schlumberger from 7,420' - 7,440' using the gun system listed below. Tie in log/date - 03/27/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 7420 II II I[ j[ N/^ II 0-180 Page I BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Jim Spearman FROM: Kirby Walker DATE: April 1, 1998 RE: G-10(O^) DataFRAC AND FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors MPU FILE COPY JOB SUMMARY Of the 120,000# of proppant planned to be pumped, nearly 75,000 pounds were actually placed behind pipe during the frac on the OA Sand. A 100 bbl injectivity test and a 200 bbl DataFRAC were planned and pumped. Due to the brake on one of the pumps not setting after the DataFRAC, additional pumping occurred rendering the falloff data virtually useless. Consequently, a second DataFRAC (60 BBL) was pumped and data analysed for redesign purposes. A leak-off value of 0.01 was determined using a closure of 2775 psi. The frac job was designed with a maximum proppant concentration of 8 PPA. Instructions were to run that program and, depending on the outcome, pump the rest of the proppant at 10 PPA. Throughout the large 8 PPA stage BHP remained constant and it was decided to proceed to 10 PPA. Almost immediately, as 10 PPA hit the perfs, the BHP began to rise. Proppant was cut when 250 psi pressure build was seen above previous treating BHP. Just as flush was called, the BHP flattened out. Pressure remained there until rate was dropped in an unsuccessful attempt to induce a screenout. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft 30 100 27.25 4038 2708 200 .655 DATA FRACI Bbls Bbls XL gel Time XL gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi/ft 200 200 10 min '3875 2832 65 .682 Page 2 DATA FRAC II Bbls Bbls XL gel Time XL gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs peals psi psi/ft 60 60 3 min 4055 2913 90 .701 FRAC Sand Prop behind Prop left in Proppant Tresaver pumped, # pipe, casing Type Liner Sand, rubber left in Job was # # M# hole? Completely 78,927 74,727 4,200 16/20 N/A N/A flushed CarboLite Ft of sand Estimated Final ISIP, psi ISIP Incr % Pad TSO, design, TSO, in Pipe sand top STP, over datafrac (pad/slurry) min Nolte psi Plot 115 7314 1520 1031 -1882 29.6% 19.05 Operational problems A third DataFRAC had to be pumped as a result of a brake not setting on one of the turbine pumps which caused it to start pumping again. This interrupted the data making it unable to analyse. (Importance of 'absolute' shutdown, at this point in the job, was explained to the pump operators.) During the I PPA stage, Halliburton used air to clear one of their PropLok lines. This burst of air went into one of the turbine which caused it to lose prime. Rate was brought back up by the other two pumps until the third pump was re-primed and able to be put back on line. If there is ever a need to clear lines using air, they will now shut the valve on the POD and clear the lines through their bleed- offs. Comments Ramping the proppant schedule from the 8 to the 10 PPA stage would have made the transition a bit easier for the reservoir to take. Once the 10 PPA stage was actually going through the perfs, the pressure levelled, possibly indicating that even a higher proppant concentration could hav, e been used. TIME/DATE OPERATIONS SUMMARY 1242 3/31 Injectivity Test 1355 DataFRAC I 1616 DataFRAC II 1905 Frac 2030 RD Dowell, Peak. Ready for next stage Page 3 PUMPING SUMMARY TIME RATE ANNP WHP ISTAGE CUM COMMENTS BPM PSlG PSlG BBL BBL INJECTIVITY TEST DISPLACEMENT = 85 BBLS 1242 Pressure Test lines - 6,000 psi 1250 8 15 1097 100 - Circulate HEC to tubing tail 1257 - 13 122 61.4 S/D Close rams-shut choke 1300 2 419 932 61.4 Squeeze HEC to top perf 1311 - 679 860 79.4 S/D ISIP - 2799 psi 1316 25 1110 3917 79.4 Start Injectivity Test 1318 26 1104 4095 85 100 Switch to KCI Displacement 1320 20 978 3840 165 Slow Rate (as per procedure) 1321 760 978 185 S/D Monitor pressure ISIP - 2708 psi Grad. = .653 NWBF - 200 psi DataFRAC I DISPLACEMENT = 85 BBLS 1355 8 15 983 200 - Circulate HEC to tubing tail 1403 - 16 90 63 S/D Close rams-shut choke 1407 2 859 1257 63 Squeeze HEC to top perf 1418 747 841 82 S/D 1421 20 967 3202 116 82 Start DataFRAC I 1428 20 925 3029 85 198 Start Flush !14-33 - 918 3852 283 S/D Monitor pressure ISIP - 2832 psi Grad. = .682 NWBF - 65 psi DataFRAC II 1 61 6 8 15 960 60 - Circulate HEC to tubing tail 1626 - 18 100 60 S/D Close rams-shut choke 1629 1.5 848 1207 18.5 60 Squeeze HEC to top perf (w/KCI) 1640 - 796 873 79 S/D 1644 20 989 3445 60 79 Start DataFRAC II 1647 - 893 987 139 S/D ISIP - 2913 psi ~ Grad. = .702 NWBF - 90 psi Page 4 TIMEI RATEBPM PUMPING SUMMARY ANNP WHP t STAGE CUM PSlG I PSIG1 BBL BBL COMMENTS FRAC !1905 923 3065 102.5 Start PAD 1910 20 980 3120 25 102.5 1 PPA 1911 12 946 1917 5 127.5 2 PPA 1912 13 956 2434 8 132 3 PPA 1912 18 969 2882 14 140 4 PPA 1913 20 978 3285 15 154 ' 5 PPA 1914 20 970 3427 23 169 6 PPA ,1915 20 963 3679 24 182 7 PPA 1916 20 963 3839 115 206 8 PPA 1922 20 1002 4091 127 321 10 PPA 1926 20 1015 4055 418 10 PPA on zone 1928 20 1925 4246 68 448 Start Flush 1930 15 1050 2786 495 Reduce Rate 1931 10 1042 2177 505 Reduce Rate 1931 5 988 1520 508 Reduce Rate 1933 942 1015 516 S/D ISIP - 2995 psi 1947 716 777 15 minute SI FLUIDS PUMPED DOWNHOLE INJ TEST 185* BBLs DataFRAC h 283* BBLs DataFRAC I1: 139' BBLs FRAC: 516 BBLs TOTAL: 1123 BBLs were pumped 940 BBLs were actually injected '61 BBLs of this stage was circulated and injected into the formation. GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40//GEL GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC N/A 85° 78 cp 3.9 min N/A N/A Transmittal State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 12-Apr-98 Well Name Services Bluelines R/F Sepia Film 'MPG-10 GR/CCL PERF 1 1 0 Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. MPU FILE COPY BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: FROM: DATE: RE: Bill Hill Kirby Walker April 3, 1998 G-1.0 (N Sand) DataFRAC AND FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors JOB SUMMARY The program called for a 100 BBL Injectivity Test and a 200 'BBL DataFRAC to be circulated to the tubing tail and bullheaded at matrix rate so as to inject One barrel of HEC past perfs before coming up to treatment rates. The first attempt made doing the Injectivity Test was aborted due to the inability to circulate fluid down the tubing. The first 30 BBLs were circulated at 8 BPM with full returns. Pressure then started to rise to the max pressure for circulating (1,500 psi) and rate had to be decreased to 0.5 BPM. Pumps were shut down after 50 BBL had been pumped with no noticeable improvement. The chips of PropLok found while running frac string were thought to have caused a blockage in the tubing, restricting flow (discussed below). Once the tubing was cleared, the job was restarted with the Inj. Test. A leakoff coefficient of 0.01 ft/min2 was determined through analysis of the DataFRAC decline data and used to redesign the proppant schedule for the N Sand frac. The job design called for 61,880# of proppant with a max proppant concentration of 10 PPA. Instructions were to pump as much of the remaining proppant (99,000# on location) as needed at 10 PPA. As the job progressed the Nolte-Smith Plot showed alternating positive and negative slopes, indicating both height and length growth and some proppant packing. The treating pressure remained right around 4350 to 4450 psi for most of the job. This was very concerning because of the 4500 psi maximum pressure set in the program (discussed below). Just as pressure began to rise to near the 4500 psi mark, screenout occurred. At that time 42,649# of the 16/20 CarboLite had been pumped; 20,561# were behind pipe leaving 22,0.8.8# of PropLok coated proppant in the casing. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft max 100 26 3914 2579 161 0.64 05/27/98 8:19 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL DATA FRAC Bbls Bbls XL gel Time XL gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi/ft 200 200 10 4038 2784 45 0.69 FRAC Sand Prop behind Prop left in Proppant Final Prop Tresaver pumped, # pipe, # pipe, # Type/Size on Zone rubber left in Job was hole? Screened out 42,649 20,561 22,088 16/20 9.4 BBL of N/A early CarboLite 9.0 PPA Ft of sand Estimated Final ISIP, psi ISIP Incr % PAD TSO, design, TSO, in Pipe sand top STP, over datafrac (pad/slurry) min Nolte psi Plot 7270 surface 4559 2746 -38 10.4% 5.0 Operational problems · While running the frac string into the hole, chips (-3" diameter) of hardened PropLok fell out of the first 20 stands of the string. The pieces that fell on the floor were collected and just about covered the bottom of a 5 gallon bucket. The rest presumably fell down the hole as connections were being made and was the source of the restriction found during the Injectivity Test. A possible problem here could be having the tubing tail being set too close to the top perf. On this jobit was 17.7 BBL above the top perf. The procedure said to under-displace by 10 BBL which is only about 200 feet in the 7". Halliburton has been running PropLok at full strength until all the proppant is past the downstream densitometer to ensure all proppant is coated. Since we are under-displacing anyway and the final proppant pumped never sees the reservoir anyway, we will now cut PropLok when the cone on the POD is empty of proppant. This will in no way jeopardise uncoated proppant from getting into the reservoir. I also think it smart to leave more space between the tubing tail and the top perf to reduce the amount of coated proppant left in the frac string, maybe double the volume of under-displacement. · The procedure called for a max pressure of 4500 psi based on expected treating pressure of 4500 psi. In this last job treating pressure was around 4400 psi.leaving only a 100 psi cushion. If these max pressures are genuine due to wellhead, tubing; etc. then they must' ' be followed. However, if they are just set from an est/mated treating pressure then we run the risk, as in the G-10 (N) frac, of lowering rate unnecessarily to stay, below that pressure - or possibly getting a pressure spike and tripping out the over-pressure shut downs on the pumps. Page 3 TIME OPERATIONS SUMMARY 1830 Injectivity Test 1908 DataFRAC 2213 Frac TIME1 RATEBPM PUMPING SUMMARY ANNP WHP I STAGE CUM PSlG PSIGI BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 77 + 5 BBLS 1830 8 16 958 100 Circulate HEC to tubing tail 1837 - 9 121 59.5 S/D - Close rams/Hydril 1840 2 500 812 59.5 Squeeze to Top Perf 1851 710 853 78 S/D - Allow microfractures to close 1852 21 903 3598 78 Begin Injectivity Test 1854 24 864 3983 85 100 Start KCI Displacement 1857 20 789 3754 170 Reduce rate as per program ~1858 - 639 843 185 S/D ISIP - 2579 psi NWBF - 161 psi Grad. - 0.64 DataFRAC 908 8 16 994 200 - Circulate HEC to tubing tail 915 - 20 142 59 S/D - Close rams/Hydril 917 2 641 1026 59 Squeeze to Top Perf 928 - 696 805 78 S/D - Allow microfractures to close 930 20 868 3305 122 78 Begin DataFRAC 936 20 835 3264 200 Start KCI Displacement 939 - 848 4025 267 S/D ISIP - 2784'psi ~' NWBF - 45 psi Grad. = 0.69 Page 4 BPM I PS~GIPS~GI BBL BBL PUMPING SUMMARY COMMENTS FRAC 2213 20 768 4016 24 Start PAD 2214 - 14 S/D - Problem with PropLok computer 2217 20 807 3832 10 14 Regain pump rate 2218 20 793 3736 23 24 I PPA 2219 20 787 3621 13 47 2 PPA 2220 20 782 3470 13.5 60 3 PPA 2220 20 771 3379 14 73.5 4 PPA 2221 20 785 3566 14.5 88 5 PPA 2222 20 826 3827 15 102 6 PPA 2223 20- 851 4102 15.6 117 7 PPA 2223 20 846 4326 24 133 8 PPA 2225 20 833 4450 25 157 9 PPA 2226 20 837 4377 61 182 10 PPA 2229 3149 4559 - 243 S/D - Screenout FLUIDS PUMPED DOWNHOLE INJ TEST: '185 BBIs DATA FRAC: *267 Bbls FRAC: 243 Bbls TOTAL FLUIDS PUMPED: TOTAL FLUIDS INJECTED: *59 BBLs of this was circulated out and not injected 695 BBLs 577 BBLs GEL QUALITY CONTROL CHECK SEA H20 SEA H20 HEC HEC PIPE XL XL . pH TEMP @H VISCOSITY TIME TIME pH DF/FRAC 80 90 3.85 N/A Milne Point Unit, Alaska TO: Bill Hill FROM: Well Name: Main Category: Sub Category: Operation Date: Kirby Walker MPU G-10 (N) PERF E-LINE 04/02/98 Date: IApril 2, 1998 I MPU FILE COpy Objective: To perforate the OA Sand from 7,270'-7,290' using 4.5" guns, 0°-180° phased, 4 spf. Sequence of Events: 0000 0230 0300 0400 O4O2 Atlas on location. Rig up lubricator and gun assembly. Pressure test lubricator to 500 psi. RIH w/gun assembly Log into position. Fire gun and perforate N Sand from 7,270' - 7,290'. (Positive indication of guns firing through decrease in tension.) POOH. RDMO SIb. Results: The N sand was perforated by Atlas from 7,420' - 7,440' using the gun system listed below. Tie in log/date - 03/27/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 7270 J l 7290 II 4.5" 1[ 4 ![ N/A, II 0-180 SP~ .~' UN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 .~ JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -58.20 0 0 112.00 112.00 53.80 0 0 202.85 202.85 144.65 0 27 293.68 293.68 235.48 0 28 384.77 384.76 326.56 0 49 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 38.25 E .51 .29N .23E N .63 E .33 .95N .46E N 11.10 E .41 1.97N .59E .00 .00 .21 .78 1.73 476.05 476.03 417.83 1 1 562.34 562.30 504.10 1 14 652.51 652.44 594.24 1 47 744.75 744.59 686.39 3 7 835.21 834.87 776.67 4 1 N .41 W .29 3.43N .71E N 30.47 W .72 5.00N .23E N 38.00 W .66 6.96N 1.14W N 39.55 W 1.43 10.03N 3.63W N 40.88 W 1.00 14.33N 7.27W 3.10 4.74 7.00 10.64 15.78 926.59 925.88 867.68 6 4 1017.76 1016.34 958.14 8 7 1107.75 1105.12 1046.92 10 28 1200.69 1196.10 1137.90 12 58 1292.93 1285.43 1227.23 15 50 N 33.98 W 2.35 20.76N 12.07W N 32.12 W 2.25 30.22N 18.19W N 33.14 W 2.63 42.46N 26.05W N 32.61 W 2.69 58.33N 36.29W N 32.74 W 3.10 77.65N 48.69W 23.28 34.06 47.98 66.05 88.03 1383.78 1372.13 1313.93 18 55 1475.00 1457.70 1399.50 21 35 1563.02 1539.58 1481.38 21 27 1656.95 1626.45 1568.25 23 12 1748.78 1710.23 1652.03 25 5 N 27.51 W 3.80 101.15N 62.20W N 26.49 W 2.95 129.29N 76.52W N 26.94 W .24 158.14N 91.04W N 26.49 W 1.87 190.02N 107.08W N 26.13 W 2.05 223.69N 123.72W 114.34 145.33 177.06 212.12 249.07 1841.14 1792.80 1734.60 28 7 1930.84 1871.18 1812.98 30 2 2026.47 1953.48 1895.28 31 11 2119.74 2031.85 1973.65 34 27 2211.52 2106.26 2048.06 37 11 N 26.55 W 3.30 260.76N 142.08W N 27.24 W 2.16 299.64N 161.81W N 30.64 W 2.17 342.23N 185.39W N 30.50 W 3.50 385.75N 211.09W N 29.27 W 3.09 432.32N 237.84W 289.75 332.56 379.98 428.89 481.02 2304.38 2178.70 2120.50 40 15 2397.00 2247.28 2189.08 44 12 2489.28 2311.55 2253.35 47 29 2581.81 2372.11 2313.91 50 44 2675.93 2429.20 2371.00 54 33 N 27.71 W 3.46 483.38N 265.51W N 28.39 W 4.29 538.29N 294.79W N 28.76 W 3.58 596.42N 326.46W N 29.10 W 3.52 657.64N 360.30W N 30.05 W 4.14 722.69N 397.23W 537.71 598.55 663.14 731.30 803.99 2767.82 2479.84 2421.64 58 32 2860.52 2526.04 2467.84 61 40 2953.42 2568.19 2509.99 64 21 3044.71 2606.I5 2547.95 66 29 3136.84 2641.75 2583.55 68 2 N 29.64 W 4.35 789.18N 435.38W N 29.21 W 3.40 859.17N 474.85W N 28.77 W 2.93 931.58N 514.96W N 29.87 W 2.58 1003.94N 555.61W N 29.88 W 1.68 1077.62N 597.94W 878.40 956.54 1037.18 1117.93 1200.39 ORIGINAL UN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 MWD SURVEY JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3228.28 2672.98 2614.78 3319.44 2698.62 2640.42 3411.04 2719.83 2661.63 3503.35 2738.59 2680.39 3595.50 2758.08 2699.88 72 75 77 78 76 0 19 53 39 55 N 29.85 W 4.34 1152.13N 640.72W N 30.33 W 3.67 1227.81N 684.58W N 30.71 W 2.83 1304.56N 729.83W N 29.83 W 1.25 1382.62N 775.38W N 30.15 W 1.92 1460.62N 820.40W 1283 . 79 1368.60 1454 . 84 1542.40 1629.76 3686.72 2777.51 2719.31 3778.56 2799.31 2741.11 3871.45 2825.44 2767.24 3964.17 2851.78 2793.58 4056.01 2875.74 2817.54 78 74 73 73 76 28 3 16 43 1 N 29.56 W 1.82 1537.91N 864.76W N 30.46 W 4.92 1615.15N 909.36W N 29.28 W 1.48 1692.44N 953.75W N 26.18 W 3.24 1771.12N 995.11W N 25.58 W 2.57 1850.87N 1033.80W 1716.27 1802.78 1889.29 1976.31 2063.62 4149.25 2897.83 2839.63 4242.53 2918.74 2860.54 4334.99 2938.25 2880.05 4428.05 2956.71 2898.51 4521.08 2975.10 2916.90 76 77 78 79 78 34 3O 7 0 12 N 25.24 W .70 1932.69N 1072.67W N 23.77 W 1.83 2015.40N 1110,37W N 22.48 W 1.51 2098.51N 1145.86W N 25.06 W 2.88 2181.97N 1182.62W N 20.89 W 4.48 2265.91N 1218.21W 2152.97 2242.85 2332.51 2422.86 2513.35 4613.55 2993.84 2935.64 4705.59 3013.66 2955.46 4797.88 3035.38 2977.18 4890.13 3057.21 2999.01 4984.37 3079.20 3021.00 78 76 76 76 76 24 43 3 34 26 N 22.34 W 1.55 2350.09N 1251.57W N 20.37 W 2.77 2433.77N 1284.29W N 18.63 W 1.98 2518.32N 1314.23W N 16.09 W 2.73 2603.84N 1340.97W N 17.20 W 1.15 2691.64N 1367.22W 2603.45 2692.90 2782.42 2871.99 2963.62 5077.01 3101.02 3042.82 5168.75 3123.54 3065.34 5260.39 3145.84 3087.64 5355.,76 3167.90 3109.70 5449.45 3189.66 3131.46 76 75 76 76 76 18 16 33 41 26 N 17.45 W .30 2777.58N 1394.03W N 16.64 W 1.41 2862.61N 1420.10W N 14.26 W 2.88 2948.27N 1443.77W N 13.99 W .32 3038.25N 1466.41W N 14.29 W .42 3126.62N 1488.67W 3053.63 3142.54 3231.41 3324.15 3415.23 5544.39 3211.77 3153.57 5638.74 3233.80 3175.60 5735.07 3256.87 3198.67 5830.60 3279.66 3221.46 5925.76 3303.21 3245.01 76 76 75 76 74 37 21 55 27 53 N 14.05 W .32 3216.14N 1511.27W N 14.91 W .93 3304.96N 1534.21W N 13.68 W 1.32 3395.59N 1557.30W N 13.26 W .70 3485.80N 1578.91W N 12.38 W 1.88 3575.69N 1599.37W 3507.52 3599.23 3692.71 3785.39 3877.45 6022.12 3330.13 3271.93 6117.52 3360.85 3302.65 6213.53 3394.30 3336.10 6309.20 3429.72 3371.52 6404,64 3468.99 3410.79 72 69 69 67 64 39 46 26 5 17 N 11.50 W 2.48 3666.19N 1618.51W N 12.19 W 3.09 3754.58N 1637.04W N 12.09 W .37 3842.56N 1655.97W N 12.09 W 2.45 3929.44N 1674.58W N 11.70 W 2.97 4014.55N 1692.51W 3969.72 4059.80 4149.59 4238.25 4325.00 S~ 3 qUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 MWD SURVEY JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6501.06 3513.29 3455.09 61 0 N 11.31 W 3.43 4098.45N 1709.59W 6596.57 3561.88 3503.68 57 50 N 12.01 W 3.37 4178.97N 1726.20W 6692.11 3615.26 3557.06 54 12 N 11.73 W 3.81 4256.49N 1742.50W 6787.69 3673.57 3615.37 50 35 N 11.55 W 3.79 4330.65N 1757.78W 6882.93 3736.05 3677.85 47 24 N 13.33 W 3.63 4400.83N 1773.23W 4410.37 4492.36 4571.37 4646.87 4718.60 6975.45 3800.44 3742.24 44 23 N 15.49 W 3.66 4465.16N 1789.73W 7070.39 3869.95 3811.75 41 27 N 16.23 W 3.13 4527.36N 1807.39W 7165.16 3942.40 3884.20 38 48 N 15.66 W 2.82 4586.09N 1824.17W 7259.37 4016.07 3957.87 38 18 N 16.42 W .73 4642.52N 1840.40W 7355.03 4091.16 4032.96 38 15 N 15.65 W .50 4699.48N 1856.77W 4784.99 4849.64 4910.72 4969.45 5028.71 7450.00 4165.90 4107.70 37 56 N 15.93 W .37 4755.86N 1872.71W 7545.74 4241.50 4183.30 37 45 N 15.32 W .44 4812.43N 1888.53W 7641.01 4317.02 4258.82 37 22 N 16.34 W .76 4868.30N 1904.37W 7687.68 4354.13 4295.93 37 17 N 16.01 W .45 4895.48N 1912.26W 7765.00 4415.64 4357.44 37 17 N 16.01 W .00 4940.52N 1925.18W 5087.30 5146.04 5204.11 5232.41 5279.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5302.36 FEET AT NORTH 21 DEG. 17 MIN. WEST AT MD = 7765 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 344.06 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 7,765.00' MD Si .R ~I/N DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.20 .00 N .00 E .00 1000.00 998.75 940.55 28.10 N 16.86 W 1.25 1.25 2000.00 1930.83 1872.63 330.43 N 178.40 W 69.17 67.92 3000.00 2588.31 2530.11 968.39 N 535.20 W 411.69 342.52 4000.00 2861.82 2803.62 1801.98 N 1010.29 W 1138.18 726.49 5000.00 3082.87 3024.67 2706.15 N 1371.71 W 6000.00 3323.54 3265.34 3645.50 N 1614.30 W 7000.00 3818.10 3759.90 4481.59 N 1794.31 W 7765.00 4415.64 4357.44 4940.52 N 1925.18 W 1917.13 778.96 2676.46 759.33 3181.90 505.44 3349.36 167.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Si R ]UN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.20 58.20 58.20 .00 158.20 158.20 100.00 258.20 258.20 200.00 358.21 358.20 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 N .01 E .00 .00 .66 N .45 E .00 .00 .59 N .51 E .01 .00 458.22 458.20 400.00 558.24 558.20 500.00 658.28 658.20 600.00 758.38 758.20 700.00 858.60 858.20 800.00 3.11 N .71 E .02 .01 4.92 N .27 E .04 .02 7.10 N 1.25 W .08 .04 10.61 N 4.10 W .18 .11 15.57 N 8.34 W .40 .22 959.09 958.20 900.00 1060.05 1058.20 1000.00 1161.79 1158.20 1100.00 1264.69 1258.20 1200.00 1369.09 1358.20 1300.00 23.62 N 14.00 35.28 N 21.37 50.97 N 31.58 71.35 N 44.64 97.02 N 60.00 W .89 .49 W 1.85 .95 W 3.59 1.75 W 6.49 2.90 W 10.89 4.40 1475.54 1458.20 1400.00 1583.03 1558.20 1500.00 1691.49 1658.20 1600.00 1802.14 1758.20 1700.00 1915.85 1858.20 1800.00 129.48 N 76.61 164.66 N 94.35 202.20 N 113.15 244.66 N 134.07 292.97 N 158.38 W 17.34 6.45 W 24.83 7.48 W 33.29 8.47 W 43.94 10.65 W 57.65 13.71 2032.01 1958.20 1900.00 2151.90 2058.20 200,0.00 2277.70 2158.20 2100.00 2412.34 2258.20 2200.00 2560.01 2358.20 2300.00 344.72 N 186.86 401.67 N 220.38 468.29 N 257.52 547.76 N 299.92 642.96 N 352.14 W 73.81 16.17 W 93.70 19.89 W 119.50 25.80 W 154.13 34.64 W 201.81 47.67 2727.42 2458.20 2400.00 2930.66 2558.20 2500.00 3182.88 2658.20 2600.00 3596.03 2758.20 2700.00 3987.07 2858.20 2800.00 759.55 N 418.45 913.66 N 505.10 1114.90 N 619.35 1461.07 N 820.66 1790.85 N 1004.81 W 269.22 67.41 W 372.46 103.25 W 524.68 152.22 W 837.83 313.15 W 1128.87 291.04 4435.81 2958.20 2900.00 4894.39 3058.20 3000.00 5313.62 3158.20 3100.00 5740.54 3258.20 3200.00 6109.73 3358.20 3300.00 2188.89 N 1185.81 2607.83 N 1342.12 2998.46 N 1456.48 3400.74 N 1558.56 3747.42 N 1635.51 W 1477.61 348.74 W 1836.19 358.58 W 2155.42 319.22 W 2482.34 326.93 W 2751.53 269.19 S~ .R 'UN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-10 500292278000 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 080297 JOB NUMBER: AK-MM-70221 KELLY BUSHING ELEV. = 58.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6379.41 3458.20 3400.00 3992.22 N 1687.87 W 2921.21 169.68 6589.59 3558.20 3500.00 4173.17 N 1724.97 W 3031.39 110.18 6763.22 3658.20 3600.00 4311.99 N 1753.96 W 3105.02 73.63 6915.31 3758.20 3700.00 4423.77 N 1778.83 W 3157.11 52.09 7054.63 3858.20 3800.00 4517.27 N 1804.47 W 3196.43 39.32 7185.44 3958.20 3900.00 4598.32 N 1827.60 W 3227.24 30.81 7313.06 4058.20 4000.00 4674.46 N 1849.74 W 3254.86 27.62 7440.24 4158.20 4100.00 4750.09 N 1871.06 W 3282.04 27.18 7566.86 4258.20 4200.00 4824.90 N 1891.95 W 3308.66 26.62 7692.79 4358.20 4300.00 4898.46 N 1913.11 W 3334.59 25.94 7765.00 4415.64 4357.44 4940.52 N 1925.18 W 3349.36 14.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11436 Company: Field: Alaska Oil & Gas Cons Corem Attn: LOri Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape : M PE-24 SIDEWALL CORES RECORD · " 980317 MPG-10 PERFORATING/GR COLLAR LOG 980329 MPG-10 PERFORATING RECORD 980330 MPH-14 PERFORATING RECORD 980725 MPU K-02 PACKER SETTING RECORD 980510 . MPL-37 PERFORA'rlNG RECORD 980623 , MPL-37 TIE IN LOG 980624 · , MPL-37 JEWELRY LOG 980717 . . MPL-39 PERFORATING RECORD ' 980627 , , 8/17/98 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED AUC-, 70 19 8 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 0 !:t I I--I--I IM G S ~:: I::! L~ I r- ~:::~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Lori Taylor 3001 Porcupine Dr. ~ Anchorage, Alaska 99501 q RE: MWD Formation Evaluation Logs - MPG-10, AK-MM-70221 September 26, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPG-10: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22780-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22780-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company n IR I I_L.I IM G S~=: IRL/I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPG-10, AK-MM-70221 September 24, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' :Van Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22780-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser industries, Inc. Company JUL 28 . 0g:45AM SHARED SERVICES DRILLIMG MP G-lO Proposed Summary of Operations 1. Ddll and Set 20" Conductor. Weld a starting head on conductor, 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. MPG-10 has been permitted to drill surface hole without a diverter system. Build Spud Mud. 5. Drill 8-1/;;" surfmce hole as per directional plan to 7,709' MD / 4,366' TVD, Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD, or 6,4S8' to 7,709' MD. NOTE: Fill hole with mud and check riser for leaks before spudding in, NOTE: Short trip no deeper than 3(30' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE; Utilize lubricants as necessary to enhance sliding performance. NOTE: The well will require two insert bits. Drill no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. Current guidelines are to run the first bit at least 30 hours drilling, NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings, At TD, make a wiper trip to ';he last bit trip depth and condition the hole, making sure to record any tight spots. POOH and LD BHA. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. Cement iob will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 2o0' MD below the permafrost. Displace STAGE1 cement with seawater at 7.0-8.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical, After opening the ES cementer, circulate seawater a minimum of ~- hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) BP EXPLO~iON Memorandum To: From: Subiect: Mr. Wonzell - Blair Wonzell, AOGCC Mark Brofka, SSD Operations Drilling Engineer MPG-10 and MPG-12, corrected operations summaries Date: 28 July 97 As a result of your phone call this morning pointing out the error in the MPG-12 "Proposed Summary of Operations," I noted that the same error existed in the MPG-10 summary. ! apologize for the errors and have attached new "Proposed Summary of Operations" sheets with the corrections made on step 4 for each respective well. Please place the corrected sheets in with the respective well permits. Thanks for the phone call If there is anything else I can do for you, please do not hesitate to c&ll. Regards - Mark B rofka 564-4809 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)_279-1433 FAX: (907) 276-7542 July 25, 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPG-10 BP Exploration (Alaska) Inc. Permit No. 97-118 Sur Loc: 1665'NSL, 3350'WEL, Sec. 27, T13N, R10E, UM Btmhole Loc: 1291'NSL, 5257'WEL, Sec. 22, T13N, R10E, UM Dear Mr. Alvord: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated June 19, 1997 are in effect for this revision. BY ORDER OF THE COMMISSION dlffEnclosures CC: Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl ~'~-- STATE OF ALASKA -" ALASKA ,.,iL AND GAS CONSERVATION COry, MISSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 07/22/97 la. Type of work l~ Drill [-IRedrill Ilb. Typeofwell r-]Exploratory I--IStratigraphicTest I~ Development Oil ........... .~. Re-Entry. [] DeepenI .............. [] Service [] Development Gas [] Single Zone ..[] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 58.7 ..... Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025516 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1665' NSL, 3350' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 958' NSL, 5163' WEL, SEC. 22, T13N, R10E, UM MPG-10 At total depth 9. Approximate spUd date Amount $200,000.00 1291' NSL, 5257' WEL, SEC. 22, T13N, R10E, UM 07/25/97 12. Distance to nearest property line113. 'Distance t° n'~'arest weli" 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 315848, 23'I . ........ N...o.. Close Approach 1280. 7709' M D / 4366' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 600' MD Maximum Hole Angle 76.17° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight "~rade Coupl'i'ng Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' ~50 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 '"BTC-Mod 7678' 31' 31' 7709' 4366' 1029 sx PF 'E', 133 sx Class 'G' , ,, , ,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured)ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate R~CI!!~VED Production Liner d UL, ~ ~ !~aska 0il & Gas C011s. C0mmi'.:- Perforation depth: measured Anchorage, true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Carnpoarnor, 564-5122 21. I hereby certify that the foregoing is true and correct to the'best of my knowledge Signed ChipAIvord/~'~/?,,,..?,~,,,,,~_ ~ ~,~,. ......... Title Senior DrillingEngineer Date 7['Zc.//;'? ........... Commission Use Only Perm'i't Number IAPl Number '.".'. I .... Approval Date I See cover letter 97-118 ............... 50-029-22780 ....... 06/19/97 for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes []No Hydrogen Sulfide Measures []Yes []No Directional Survey Required []Yes []No Required Working Pressure for BOPE ~2M; 1--13M; r-15M; r"]10M; r"l15M Other: Original Signed By by order of~ / ,~:~,--~ Approved By David W. Johnston Commissioner the commission Date ~ Form 10-401 Rev. 12-01-85 Submit I~ icate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark J. Brofka I MPG-10 Well Plan Summary ISCHRADER BLUFF PRODUCER 564-4809 Surface Location: 1665 FSL, 3350 FEL, S27 T13N R10E UM Tar~let Location: 958 FSL, 5163 FEL, S22 T13N R10E UM Bottom Hole Location: 1291 FSL, 5257 FEL, S22 T13N R10E UM I AFE Number: I 337081 I Rig: I Nabors22E I Estimated Start Date: 125 July 97 I I Operating days to complete: 16 IUD.' 17,709' I I TVD: 14,366' I IEEE= 158.7' I Well Design: Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS TVD (bkb) KOP 600 541 600 Base of Permafrost 1826 1725 1784 Top of Ugnu 6458 3415 3474 Top M Sand 6871 3667 3726 Top NA (Target) 7170 3894 3953 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7213 3927 3986 NCN D 7247 3953 4012 NE 7281 3979 4038 NF 7340 4024 4083 OA 7385 4059 4118 OA4 7426 4090 4149 OB 7473 4126 4185 Top of Seabee 7509 4154 4213 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 7709 4307 4366 TD at 200' MD past base of Schrader Casin~l/'rul: in~l Program: Hole ~,ize '" Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb9 O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# ES0 BTC-Mod 7678' 31'/31' 7709' / 4366' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at ±4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT rec MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals from 6,458-7,709' MD. A MAD pass will not be performed on this well. NONE ',GR/CCL by the completion rig) uired for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on G-Pad in the Milne Point Unit. To date, there have been 12 wells drilled on Milne Point G-Pad. None of these wells experienced any significant difficulties with shallow gas or hydrates in the interval prior to placement of surface casing to depths not exceeding 5000' TVDSS. In light of accumulated historical evidence indicating virtually no risk due to shallow gas at Milne Point Unit G-Pad within the surface hole interval mentioned previously, it is requested that MPG-12 be permitted to be drilled without installation of the diverter system. A 20" riser will be installed to act as a conduit to facilitate drilling mud flow. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1600' MD Maximum Hole Angle: Close Approach Well: 76.17° NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP G-10 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and function test 20" diverter. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 7,709' MD ! 4,366' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD, or 6,458' to 7,709' MD. NOTE: Fill hole with mud and check riser for leaks before spudding in. NOTE: Short trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: The well will require two insert bits. Drill no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. Current guidelines are to run the first bit at least 30 hours drilling. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. Displace STAGE1 cement with seawater at 7.0-8.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-10. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-10. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-10 7" SURFACE/INJECTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 bbis fresh water spacer (1307' in 7" casing). STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 379 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6371' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 133 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (7709' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6371' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 650 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/-350% EXCESS IS EXPECTED FROM THE ES CEMENTER (2050' MD) TO SURFACE. NOTE THAT 100 SACKS WILL BE IN THE 20" x 7" ANNULAR SPACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-four (24) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (24+2 = 26 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 50% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 50% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: 1. The slurry volume is calculated to cover from the ES cementer to surface with an excess of 350% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry will be pumped until cement returns are seen at surface. Note that approximately 100 sacks will be required just to fill the 20" x 7" annular space. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadril] Schlumberger Alaska District 1LLl East 80th Avenue Anchorage, AK 99518 (907) $49-4511 Fax 344-2£60 DiREcTIONAL ~/~LL PLJ~N for S}IAR~D SKRVrCSS DRILL£NG Well ......... : MDG-10(P~) Pield ........ : ~lLne Point, G-Pad Cc~utation..~ Mln£~u'mCurvaCure Units ........ ~ PHHT Surface Lat..: 70.449159LL N Surface hnnS.: 149.53288895 W LOCATIONS - A/J%SKA Zone: Legal Descri~'t£on X-Coord Surface ....... : 1664 FSi 33S0 ~ S27 T13N RIOE OM S57256.42 Target ....... : 958 FS~ ~163 F~L S22 Ti~N RLOE UM 55540~.00 ~I{L .......... : ~291 'FSi $257 ~ S22 T£~N Rf0E OM $$5~02.23 4 Y-Coord 6014100.83 6018650.00 6018992.62 PROPOSED WKLL PROPIL~ STATIO~ MHASURBD ;HC~N DERECTION VERT[CAL-DEPTHS rD~TIF3CAT~ON DHF%~ AN~H A~ZNUTH ~ ~t~-SHA ~ 0.00 '0.O0 0.00 0.00 -58.70 KOP/BUI~ 1,5/~00 600.00 0.0Q 0.00 600.00 541.30 700.00 L.50 331.00 699.99 641.29 BUILD 2/100 800.00 ~.00 331.O0 799.9L ~. 900.00 5.00 331.00 899.66 8~0.96 BU£r.D 2.~/Loo 3000.O0 7.00 331.00 999.L1 940.4~ 1100.00 9.50 33~.00 L090.06 3039.36 ~200.00 12.00 333.00 ~L96.30 I~37.60 1300.00 14.50 33,~.00 L293.63 L2~4.93 i400.O0 17.00 33L-00 L389.87 L$31.17 mmmmmmmm SRCT~ON DHPA~T 0.00 0.00 5.LO L~.89 22.08 36.05 S4.22 76.55 102.99 Drepared ..... : 21 Jul 1997 Vert sect az.: 344.06 K]3 elevation.: 50.70 [t Magnetic Dcln= ,28.027 (E) Scale Factor.: 0.99996372 ' ' Conve~ence..: ~0.440£8082 ~ ANADtlLL APPROVED FOP, PERMI ING .ONLY PLAN # - Zone 4 TOOL DL/ FACH 100 ma=u mm~m O.O0 1.50 1.50 2.00 mm~==={ummmmmmm~mmm}m CDORDINATES-FROf4 #~LLHF_AD X Y mmmnm~=~ue mmmmmmmmmm m~=~====~ ~mummmmm~ 0.00 H 0.00 ~ S~72~6.42 60£4100.83 0.00 ~ 0.00 ~ ~572g~.42 60L4100.83 1.14 ~ 0.63 W 55725S,7B 60L4101.97 4.58 N 2.54 W 557253.85 60L4105.39 L0.68 N 5.92 W 657250.42 60L4~11.46 L9.82 N 10.99 W 557245.28 60L4120.66 RS 2.00 32.37 N 17.94 W 557238-23 6014133.06 BS 2.50 48.68 N 26.99 W ~57229.06 60£4~%9.30 ~S 2.50 68.73 N 38.L0 W S572~7.80 60L4169.26 HS 2.50 92.47 ~ 51.25 W 5S7204.46 6014192.89 ~S 2.50 L500.00 I9.60 33L-00 1484.83 L426.13 133.49 1L9.85 N /600.00 22.00 33L.00 1578.34 L5~9.64 168.00 150.84 N 66.44 W 557189.07 60L4220.16 HS 2.50 83.6L W 557171-66 60L4251.01 HS 2.50 (AnadrllL (C) 97 MPGLOP9 3.0C 11:25 AM P) Z ~> "O m Pmo- lO (~,9) PROPO$~D ~HLL DROPIhH STATION IOHNTIPICAT~ON 2.5/100 BU[t,D Z < Z 0 ~ 3.5/100 8uIr.D Ct,-'RVg 3.5/100 ~ASURHD INCLN DIRHCT£ON DEL:~/~ A~OLR AZIMUTH ~700.00 24.50 33L.00 L~96.37 26.91 331.00 L826.27 26.91 33~-00 L856.3~ 26.9i 331.00 L~O0.O0 28-%4 33~.00 2000.00 3L.94 333.00 2L00.00 35.44 331.00 2200.00 38.94 333.00 '2300.00 42.44 333.00 2400.00 45.94 331.00 2500.00 49.44 33~.00 2600.'00 52.94' 331.00 2700.'00 56.44 331.00 2800.00 59.94 33Z.00 2900.00 63.44 33~.00 3000.00 66.94 33L.00 3100.00 70.44 33L.00 3200.00 73.94 331.00 3263.81 76.L? 33L,00 3950-00 ?6.L? 33L.00 ~[ 4000.00 76.L3 332.80 4100.00 76.09 336.4L 4200.00 76.10 340.0L 4300.00 96.16 343,62 ~ND 3.5/100 CURVE 43~2.28 96.19 344.06 ~.0~ 4/~00 eo~s.6~ 76.17 34~.06 6L00.00 94.80 344.06 6200.00 90.80 344.06 V'H~TICA~-D~PTHS TVD SUB-SBA 1690.2] L6LL.5~ L?57.O~ 1698.34 L783.90 ~725.00 LSLD.54 L75~.84 L849~18 L790.48 L935.60 L~76.90 20~8.80 L960.10 2098.46 2039.76 2L74.27 2115.57 2245.97 2187.27 2313.28 2254.68 2395.95 2337.25 2433.94 2375.04 2486.45 2427.75 2533.0~ 2475.17 2575,83 2517.13 26L2.18 2553.48 2642.76 2584.06 2659.22 2~00.52 2823,25 2~64'.55 2835.22 2776.52 2859,24 2800.54 2883.29 2824.59 2907.29 2848.57 2910.21 2853.51 3329.35 3290.65 3337.96 3279.26 3367.53 3308.83 (Anadcill (c)97 M~G10P9 3.0C 11:25 AM SSC~IO~ D~PAR~ 206,45 247.17 260.3~ 2?3.62 293.36 342.33 396.36 455.22 586.60 658.62 734.52 813.99 896.96 982.50 L070.91 ~161.65 t254.38 ~334.43 ~963.49 2010.95 2106.68 2203.23 2300.22 2312.14 40L4.70 4047.93 4L43.44 23 Ju.l 1997 Page 2 COORD~NATB~-~RO~ AI, A~KA ~one 4 TO0~ Db/ ~bLHHAD X Y FACH 100 ~85.36 N [02.75 W 557152.26 6014285,38 HS 2,50 221.92 N 233,g~ N L29.~7 ~ SST125,0T 6014333.56 H8 0.00 245.67 N L36.~8 ~ 557~18.37 60L4345.42 H8 0.00 263.39 N L~6.00 H SS7~08.42 60L4~63.06 Hg ~.~0 307,36 N 170.3~ H 557083,73 60L4406.84 HS 3,50 355.86 N 199.26 W 557056.45 60~4455,~3 HS 3.50 408.72 N 226.55 N 557026.75 6014509.95 HS 3.50 465.~2 N 258.16 W 556994.72 60~4564.51 HS 3.60 526~68 N 291.94 W 556960.47 60~4625.20 HS 3.50 59L.34 N 327.79 W 556924.13 6014689.58 HS 3,50 6S9,48 N 365.56 W 556885.84 6014757.42 ~ 3.S0 730.84 N 405.1£ ~ 556845.~5 6014828.46 RS 3.50 805.15 N 446.30 W 556803.99 6014902.45 HS 3.50 882.13 N 488.98 ~ 556760.73 6014979.10 HS 3.50 96L.51 N 1042.98 N 1126.23 N 1180.15 N 1762.9l N S32.9~ ~ 556716.13 6015058.L2 HS 3.50 578.13 W 556670,35 6015139.23 RS 3.50 624.28 ~ 556623.57 6015222.L3 RS 3.50 654.17 M 556593.27 6015275.81 RS 3.50 9~.19 W 556265,8L 6015856.0L 92R 0.00 1805.73 N 1000.06 N 556242.62 60L5898-65 1893.4£ N 1041.68 N 556200.32 6015986.00 1983.52 N 1077,7L W 556163.6L 6016075.82 2075.74 N 1108,00 N 5~6132.6L 60L6L67.80 2087.19 N 1111.32 N ~56129.21 60L6L79.22 3724.28 N 1578,90 3756.24 N 1588.02 3848.07 N 1614.25 S55649.LL 60L7812.53 555639.74 60L7644.40 555612.81 6017936.02 91R 3,50 90R 3.50 89R 3.50 89R 3.50 He 3.50 O.O0 4.00 4.00 Z ;U STATION XDE~TI TOP TOP M SAND HND 4/10o DROP M~ASURHD DEPTH 6300.00 6400.00 64S9.77 6500.00 6600.00 6700.00 6000.00 6870.62 6900.00 6969.91 T~LHGHT 7169.91 TOP SCHRADHR / NA 7169.9L NB 7212.99 NC/ND 7246.93 ~ ?280.87 gROP09ED ~BIJ~ PROFILE £NCLN D£RECT10~ VBRTICAL-DEPTP~S ANGLH AZIMUTH TVD SUB-SHA 66,80 344.06 3403.-69 3344.99 62.80 344.O6 34~6.26 60.49 344-06 3473.~0 341~.00 ~8.80 344.06 3495.04 3436.34 S4.~0 344.06 ~49.79 3~91.09 21 ~uL 1997 Page 3 S0.80 46,80 43.97 42,80 40.00 '40.00 40.00 40.00 40.00 40~00 8BCTION DHPAR~ 4236.65 4327.11 4397.94 4414.38 4498.04 COORDINATIlS-~RO~ ALASKA Zone 4 TOOL D~/ #HL/~ X Y ~ACB 100 ~93~,70 N '~639,85 W 555~86.53 6018025.44 LS 4.00 4024.68 N L664.90 W 595561.02 6010112.22 hS 4.00 4073.56 N L678.66 W SSSS46.68 6018160.98 LS 4.00 4108.60 N ~600.66 ~ 555536.41 6018195.94 LS 4.00 4189.'04 N 1711,64 W 555512.82 6018276.~9 LS 4.00 NF 7339,6% 40.00 OA 7395.30 40.00 OA4 7425.77 40.00 OB 7472.77 40.00 BA.~B SCHRADER 7509.32 40.00 344.06 36L0.25 3551.55 4577.6? 344.06 3676.11 3617.41 4652.89 344.06 3725.70 3667.00 4703.16 344.06 3747.05 3688.35 4723.34 344.06 3q99.49 3740.79 4769.56 4265.61 ~ 1733.5L W 555490.36 6018352.59 LS 4.00 433~.94 N lqS4-L? N 555469.1~ 60~8424.~5 LS 4,00 4386.27 N 1767.97 W 555454.98 6010472,9~ LS 4.00 440S.68 N 1~73~5~ W 555449,29 601849~,33 ~ 4.00 4450.12 N 1786.21 ~ ~$5436,25 6018536.67 HS 4.00 ~,m CAS£NG POINT 7709.32 40.00 TO 7709.32 40.00 344.06 3952.70 3894.00 4998.12 344.06 3952.70 3894.00 4999,12 344.06 3985.70 3927.00 4925.81 344.06 4011.70 3953.00 494q.63 344-06 4037.70 3979,00 4969,45 45~3.74 N L021.$1 R S55400.00 6018660.00 HS 0.00 4573:~4 N L821.51 ~ 555400.00 6018660.00 HS 0.00 4600.36 N L829.12 W 555392.19 60L8686.56 HS 0.00 462~.34 ~ 1935.11 W 555386.04 60L9707.49 HS 0.00 4642.32 N 1841.10 W 55S379.89 6018720.42 HS 0.00 344-06 4082.90 4024.00 5007.2L 4678.63 N 1851.4~ H 555369.24 6018764.65 H.9 0.00 344-0; 4117.~0 4059.00 5036.57 4706.87 N 1859.54 N 555360.96 6018792.82 HS 0.00 344-06 4148.~0 4090.00 5062-59 4731.80 N 1866.68 ~ S55353.62 6018819.77 H9 0.00 344-06 4184.70 4126.00 5092.79 4760.92 N 1874.98'W SS5345.L1 6018846.75 H9 0.00 344.0~ 42L2~70 4154.00 Sl16.29 4783.52 N L88L.43 W S55338.48 6018869.29 ~S 0.OD 344.06 4365.9L 4307.21 $244.85 4907.13 N 1916.74 ~ 555302.23 60L8992.62 0.00 344.06 4365.9L 4307.21 5244.85 4907.13 N L916,74 H 555302.23 60L8992.62 0.00 (Anadr~L1 (c)97 MPG10P9 3.0C 1L:25 A~ p) ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ~---~.-v,m*v~- ': -- ' ~'~ "0 P-I SHARED SERVI'CES--BRILLING i iiiiii i II I IllllI II I _ I I I Anadri ] ] Schlumaerger Immmm · MPG-lO (P§) VEFIIICAL SECTION VIE ' ..... ISectJon at: 344.06 - ,lOeb Sca]e'.: I ~nch = BOO feet ~. .I D~- · . . '. B) KOP/BUILD ~.5/~0D 600 600 0 0.0 ' ' '. '.'. ' C). BUILD ~/~00 BOO 800 5 3.0 ~ ~ ' ... '., ' 0) BUILD2.5?&O0 ~000 ~99 · 22 7.0 ~ E) END ~.5/J~ ~ILD ~795 ~757 ~47 ~6.~ ' - ' . ...... G). E~ 3.5/~ BUILD 3264 · 2~9 13~4 76. , .. N) C~VE 3~5/~ 3950 28~3 t~3 76. '" J} DR~ 4/t00 6066 3329 4015 76. ' ~~ "K) END 4/~00 ~P 6970 3799 4770 40.( L) TARGET · 7170 3953 4898 H) 7" CASING ~N] 7709 · 4366 '5245 40.( ' .. N) TD 7709 4366 5245 40.( . , ] m .... m m m o 4oo ' ' .BOO )eO0 l~O0 mOO 2400 ~00 '~0 ~00 4000 4400 4B00 ~o0 ~600 600o 6400 6~o0 Sect ion Departure Z ~3 -O ~> Pl 14' 4G 907,344-2~-~0 ANADRILL DPC PAGE 0G SHARED SERVICES DRILLi ........ I · mil i i i i · · m i · MPG- I 0 (P91 VERTICAL SECTION VIEW ~650- -~ ..... i Section at: 344.06 TVD Scale · ! inch = ~00 feet 3700-- __ ._ Dep Scale' ~ inch -- ~00 feet' OPawn ' 81 Jul 1997 3750 ~ ' Anadr~ ]1 $ch]umb'erger 3600-- ,'~. Marker. Identification ' 140 BKB SECTN INCLN ~' '~ A) END 4/~00 DROP 6970 3799 4770 40,00 \ 8) TARGET 7170 3953 4898 40.00 C) 7' CASIN6 POINT 7709 4366 . 5845 40.00 - . . 3850-- ~) TD ' . 7709 a366 5~45 40,00 . v 3,oo-- . , ,_.,,.,AOP. rL ,~_l'3p~' ~'~ "--" "~-~'.: ,)NL,' Pl. ANi d+_ c~ ~- 4000 ~ , ...... ~ ~ , , -~. -~-o~ ........... 4100- - .. - ..... ~ ' · · "~i'_- ~'~ F~- ' . I. ~, · 4150 -~z-"~' ,a,~ ...........~ - -" ...... , ......... · - . 'DE - ai~, ....... ' ........ "' ....... 4200 .... ' ~,, _, 'e~'~ sTA~ ~ '.'~:~' ' '" ........ ' ...... ' ' -"'' .............. '4250- - ,. · . 4300"1 . . : . · 4350- - ,-. . . . " C - . ~00 ..... .' . ........... i · '4450- - -,7 -: ~ - 4700 4750 4800 4850 4900 4950 5000 5050 51.00 0~50 5200 5850 5300 5350 5400 Se,,,ct ion Departure LAfla~r%ll (c)g7 ~OGlOPg 3.0C 11:27 ~ p) 07/21/1997 ~ ~ti 46 g07-344~"~'~8 ANADRILL DP¢ ~ PAGE 07 SHAR'ED SERVICES DRILLING Harker IOent 1 f lcation MD N/S E/# o o. MPG-lO (P9) c~ ~o ~/,oo .oo s. ~, PLAN VIEW D) BUILD 2.5/~00 1o00 8o N ~ W ..... El END 2,5/100 BUILD t796 222 N t23 W CLOSURE ' 5268 feet aL Azimuth 338.66 Fl BUILD 3.5/100 t856 246 N $36 W G) ENO 3,5/100 BUILD 3264 I1BO N 654 ~ DECLINATION ' +28.027 (E) CURVE 3.5/100 3950 1763 N 977 ~ SCALE. ' 1 inch = 800 feet ~ END 3.5/100 CURVE 43t~ ~OB7 N 11t1 W J) DROP 4/t00 6066 3724 N t579 ~ DRANN ....... : 21 Jul t997 K} END 4/~00 DROP 6970 4450 N t786 W L) TARGET 7J70 457a N le~ W H) 7" C~SING POINT 7709 4907 N- 1917 W '" N) TD 7709 4907N ~9~7. AnadrJ]] Sch]umberger m mmmmm m PLA q ' . ~ ' . _ . . . · ~ · . ~ ~ ..... mmmm . , 2800 2400 2000 lBO0 120~ 800 400 0 aO0. 800 1200 tBO0 2000 2400 2800 <- WEST: EAST -> m mm NOTES N 2800 G-8 · ~ G-15 G-7 · ~ G-14 G-6 · ~ G-13 G-5 · G-4 · G-3 · e G-11 G-2 · ~ G-10 G-1 · -t~ G-9 LEGEND 1. DATE OF SURVEY: MAY 20, 1997 2. REFERENCE FIELD BOOK : MP97-04 (PCS 48-53) .3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.99990.3725 5. HORIZONTAL/VERTICAL CONTROL IS BASED ON G PAD MONUMENTS G-1 AND G-2. 6. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L EXISTING WELL CONDUCTORS AS-BUILT WELL CONDUCTORS VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 20, 1997. LOCATED WITHIN PROTRACTED SEC. 27, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=6,014,041.66 N 2,170.07 70'26'56..390" 70.4489972' 1,605' FSL G-9 X= 557,264.59 E 1,184.86 149'.31'58.17`3" 149.5328258' 29.2' 3,.342' FEL Y= 6,014,100.83 N 2,229.81 70'26'56.97.3" 70.4491592' 1,665' FSL G-lO X= 557,256.42 E 1,185.10 149'`31'58.400" 149.5`328889' 29.2' 3,350' FEL Y= 6,014,160.28 N 2,289.82 70'26'57.558" 70.4493217' 1,724' FSL G-11 X= 557,248.29 E 1,185.42 149'51'58.626"1 149.5.329517' 29..3' 3,357' FEL Y= 6,014,391.14 N 2,5`30.21 70'26'59.8`35" 70.4499542' 1,956' FSL G-13 X= 557,164.45 E 1,134.92 149'32'01.036" 149.5,336211' 29.6' 3,439' FEL Y=6,014,450.44 N 2,590.02 70'27'00.419" 70.4501164' 2,015' FSL G-14 X= 557,156.65 E 1,135.55' 149'32'01.251" 149.53,36808' 29.5' 3,446' FEL Y= 6,014,509.68 N 2,649.94 70'27'01.002" 70.450278,3' 2,074' FSL G-15 X= 557,147.69 E 1,155.02 149'52'01.501 149.5,3:3750,3' 29.8' " 5,455' FEL .I f 1 17/8/97 CORRECTED PLANT ROTATION ARROW o 15/22/97 ISSUED FOR INFORMATION lO.i OAT[ I REV1SION DRAWN: STOLL CHECKED: KH DA~: 5/22/97 DRA~NG: MPUGASAB JOB NO: SCALE: 1": 200' 9P EXPLORATION MPU C-PAD AS-BUILT WELL CONDUCTORS WELLS 9, 10, 11, 1.3, 14 &: 15 IOF1 TONY t(NOVt/LE$, (]OVEF~NOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19, 1997 Tim Schoficld Senior Drilling Enginccr BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Milnc Point MPG- 10 BP Exploration (Alaska), Inc. Permit No. 97-118 Sur. Loc: 1665'NSL,3350'WEL,SEC 27.T13N.RIOE.UM Btmholc Loc: 5169'NSL, 3214'WEL,SEC 35,TI3N.R10E.UM Dear Mr. Schofield: Encloscd is thc approved application for permit to drill the above rcfcrenccd well. Thc pcrmit to drill docs not exempt you from obtaining additional pcrmits rcquircd by iaxv from othcr governmental agcncics, and docs not authorize conducting drilling operations until all other requircd pcrmitting determinations arc made. Blowout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035· Sufficient notice (approximately 24 hours) of thc BOPE test performed before drilling below the surface casing shoc must bc given so that a representative of thc Commission may witness thc test. Noticc may be given by contacting thc Commission pctrolcum field inspector on thc North Slope pager at 659-3607· · BY ORDER OF THE C MISSION dl ffcnclosures l)cpartment ot' Fish & (lame. l labitat Section w,o cnci. I)t2partlll¢lll oJ' J'~livJllo[lllllCllt Conscn'ation ~v,o cncl. ; -- STATE OF ALASKA ---- ALASKA O;L AND GAS CONSERVATION COMM,~SlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ............ E~].~e:E~ry ~. Deep~nl .~ ~ Serv.i~e El. Deve.!.0. pment Gas I-I single zo..n...e. .... [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool B..p Exploration (Alaska) Inc. Plan RTE = 58.7 Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025906 ,,, 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1665' NSL, 3350' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 10' NSL, 3541' WEL, SEC. 26, T13N, R10E, UM MPG-10 Attotal depth 9~ Approximate Spud date Amount $200,000.00 5169' NSL, 3214' WEL, SEC. 35, T13N, R10E, UM 07/10/97 12. Distance to nearest pr0p~rty li'~el 13. DistanCe io nea~'est well 14. Number Of acr%" in pr0'i~erty '"i' 5. Prc~posed"d'epth (MD and TVD) ADL025516, 111' . .....I No Close Approach ...... 2560 ...... 8167' MD/.4...504' TVD 16. To be completed for'"deviated wells 'i'"~. An':ticipated pressure 'i'~'e 20'AA'~ 25.035 (e)(2)} Kick Off Depth 600' Maximum Hole Angle 76.16° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Setting Depth Size Specifications Top ....... Bottom ....... Quantity of Cement Hole .caSing Weight Grade C~'~Pling Length MD TVD MD TVD (include stage data) 24" 20" 91.1 # H-40 Weld 80' ..... 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 8136' 3i' 31' 8167' 4504' 771 sx PF 'E', 117 sx Class 'G' ............ ................................... ...................................................... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate IP[n°edrU cti° nORIGINALR£CEIV[I) Perforation depth: measured true vertical A|aSk~ 0ii & Gas Cons. C0m~'tssiotl An. ch0rage 20. Attachments [] Filing Fee [] prOperty Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number; Mark Brofka, 564-4809 Prepared By Name/Numbec Kathy Campoamor, 564-5122 21. '1 hereby certify that the foregoing is true andjc~rrect to the best of my knowledge __ __ .... Signed ~ .(~ "J~.~:.I~ Tim Schofield .... Title Seni0..r...Drilling Engineer ..... Date ,...! ..... 7 ........ ' ' ~/ . Commission Use Only ....... ~ 7'"//,/' ~ 50- O ~-- ~ - 2- 2_ ~" ~' O (,~/let..~.~.."~ for other requirements Conditions of Approval: Samples Required []Yes I~ No Mud Log Requi~'ed I []Yes J~ No Hydrogen Sulfide Measures []Yes ~ No Directional Survey Required [~Yes [] No Required Working Pressure for DOPE 1~2M; 1-13M; F-ISM; I-I 10M; E] 15M Other: Original Signed By by order of /I ,,~ Approved By David W. Johnston Commissioner the commission Date .(.¢~i//cjlr] Form 10-401 Rev. 12-01-85 Submit plicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark J. Brofka ] MPG-10 I Well Plan Summary ISCHRADER BLUFF PRODUCER 564-4809 Surface Location: 1665 FSL, 3350 FEL, S27 T13N R10E UM Target Location: 10 FSL, 3541 FEL, S26 T13N R10E UM Bottom Hole Location: 5169 FSL, 3214 FEL, S35 T13N R10E UM I AFE Number: 1337081 I Rig: I Nabors22E Estimated Start Date: I 10 July 97 I I Operating days to complete: 19.o MD: I8167' I ITVD: I4504, I IKBE: I Well Design: 7" Schrader Bluff Producer 58.7 Formation Markers: Formation Tops MD TVDSS TVD (bkb) KOP 600 541 600 Base of Permafrost 1826 1725 1784 Top of Ugnu 6918 3553 3612 Top M Sand 7315 3795 3854 Top NA (Target) 7624 4029 4087 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7664 4060 4119 NCN D 7702 4089 4148 NE 7731 4111 4170 NF 7808 4170' 4229 OA 7847 4200 4259 OA4 7891 4234 4293 OB 7936 4268 4327 Top of Seabee 7967 4292 4351 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 8167 4445 4504 TD at 200' MD past base of Schrader Casing/Tubing Program: ~ Y Y Hole Size Csg/ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 8136' 31'/31' 8167/4504' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at __.4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 fi/hr through the Ugnu and Schrader Bluff intervals from 6918 - 8167' MD. ESS survey tool at TD to correlate with MWD surveys. NONE (GR/CCL) Mudloggers are NOT required' for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec' 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10' Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1 600', S-shaped profile ] Maximum Hole Angle: I 76.16° Close Approach Well: NONE iRECEIVED JUN 1 Alaska 0il & Gas Cons. Commission Anch0ra0e Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. In the event that the bridges are not usable due to breakup, all cuttings will be placed in the Milne Point A-Pad reserve pit. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. If the bridges over the rivers are not usable because of breakup, class 2 waste fluids will be hauled to the Kuparuk injection well and class 1 fluids will be transferred to storage tanks for future disposal after breakup. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP G-10 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill a 8-1/2" surface hole as per directional plan to 8167' MD / 4504' 'rVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD, or 6900' to 8167' MD. 6. Keep the same BHA when tripping for the second bit. If tool problems are experienced, or battery life or operating hours are a concern, then replace the MWD or motor as deemed necessary. 7. Drill at a controlled rate of no more than 200 ft~r through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 8. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 9. Before POOH, drop ESS survey tool at TD. (If two MWD tools were run while drilling, then the ESS will not be required.) 10. POOH and LD BHA. 11. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 12. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) 13. MIRU completion rig. 14. N/U & Test BOPE. 15. Drill out ES cementer and clean out the well. 16. Run GR/CCL and CBL. 17. Perform completion job. MPG-9i will be an injector. 18. Complete well with 3-1/2" L-80, EUE tubing. 19, Set BPV. N/D BOP stack and N/U X-mas tree. 20. RDMO with completion rig. 21. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-10. In the eight wells previously drilled on G-pad, only G-08 encountered gas, but only a minor amount and probably due to a small gas pocket rather than hydrates. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-10. 3. Lost Circulation: Lost circulation has been exl~erienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-10 7" SURFACE/INJECTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 362 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6815' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 117 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (8167' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6815' MD) + 30% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg 409 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/-250% EXCESS IS EXPECTED FROM THE ES CEMENTER (2000' MD) TO SURFACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - two (2) per joint on the bottom twenty-four (24) joints of 7" casing (48 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spac(~r/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 6 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 30% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 30% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: 1. The slurry volume is calculated to cover from the ES cementer to surface with an excess of 250% expected to be required. Ensure that additional sacks of cement are onsite and available for Use The slurry will be pumped until cement returns are seen at surface. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E ~vill be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Auadrill Schlumberger Alaska D£strict [l£f EaSt 00th Avenue Anchora5e, AK 995£8 349-4513 Fax ]44-2160 D£RECTIONAL SHLL PId~ for SHARRD SHRVICBS DRILLING Well ......... : MgG-10(P06) Field ........ : Milne Point, G-Pad Co~putat£on..: Minimum Curvature Units ........ : FHBT Surface Lat..: q0.44915911 N Surface Long.: 149~53288895 ~ hegaL Description Surface ...... : 3664 FSL 3350 FE~ S27 TI3N R1OB UM Target ....... : 10 FSL ~54~ PEL S26 T£3N RiOR U~ BIlL, .......... : 5169 FS~ 1234 FE~ ~35 T£3N R10H UM LOCd%TIONS - ALASKA Zone: 4 X-Coord Y-Ooord 557256.42 6014100.83 562360.00 60/2488.00 562688.34 6012369.[0 PROPOSED WE~b ~ROFII.~ STATION MHASURHD ~NCLN £DHNTIFICATION DBPTH ANGLE KB 0.00 0.00 KOP/BUIhD 1.5/1OO 600.00 0.00 700.00 1.50 BUILD 2/100 800.00 3.00 900.00 5.00 DIRECT. I0~ VERTICAI.,-DHPTHS AZIMUTH TVD SU~-SHA 0.00 0.00 -58.70 0.00 600.00 S4£.30 90.00 699.99 641 29 90.00 799.91 741.21 90.00 899.66 840.96 BU I I.,D 2.5/100 1000.00 ?.00 1100.00 9.50 L200.O0 L2.00 L300.O0 34.$0 1400.00 37.00 90.00 999.11 940.41 90.00 1098.06 1039.36 90.00 1196.30 ]137.60 90.00 1293.63 1234.93 90.00 1389,87 1333.17 21.25 34.70 52-19 73.68 99.13 Prepared ..... : 05 Jun 1997 Vert sect az.: 110.35 KB elevation.: 58.70 Et Magnetic Dc in: +28.045 (g) Scale Factor.: 0.999903~2 Convergence.. :_-t~ .__44018082 ANADRI/t CX)OP.D£NAT~S-~ROM ALASKA Zone 4 WEhLHRAD X Y 0.00 N 0.00 E 557256.42 6014100.83 0.0O N 0.0O ~ 557256.42 60~410~,83 ~.00 N 1.31 B 557257.q3 6014~00.84 0.00 N 5.23 ~ 557261.65 0.O0 N Z2.2~ E 557268.63 60~4100.92 AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ~=== mn~=~ , _ TOOL DL/ FAb-'71 ~00 H9 0.00 90R 0.00 9OR 1.50 90R 1.50 90R 2.00 0.00 N 22.66 E 557279.08 6014L01,00 HS 2.00 0.00 N 37.03 B 557293.43 6014101.i1 RS 2.50 0.00 N 55.66 H 557312.07 60L4301.26 HS 2,50 0.00 ~ 78,58 ~ 557334.99 6014101-43 }IS 2.50 O.O0 N i05.72 H 557362.13 6014101.64 H8 2.50 1500.00 19.50 1600.O0 22.00 90.00 3484_8~ 1426.13 90.00 1578.34 1519-64 128.49 L61.70 0.00 N 137.04 E 557393.44 6014101.88 RS 2.50 0.00 N 172.46 E 557428.86 6014102.15 HS 2.50 (Anaclrill (c) 97 MPOLOP6 3.0C 11:43 AM g] NP~-tO(e06) OS O'an 1997 g~ge 2 STAT £DENTIFICAT£ON END 2.~/100 HND 3 · 5/].00 CURVE m~o~ 4/~oo M~ASURBD 1700.00 24.50 L796.00 26.90 1826,27 26.90 1856.00 26.90 1900.00 28.30 2000.00 31.51 2lO0,00 34.78 2200.00 38.09 2300.00 4£.42 2400.00 44.77 2500.00 48.14 2600.00 51.52 2700.00 54.92 2800.00 58.32 2900.00 61,73 3000.00 65.[4 3100.00 60.56 3200.00 7],99 3300.00 75,41 3321.72 V6.£6 6519.8[ 76.16 6519.82 76,16 6600.00 72,95 6700.00 68.95 ~800.00 64.95 TOP UCA~ 6900.00 60.95 6917.70 60.24 ?000.00 56,95 (Anadr£[f (c) 97 MPGLOP6 3.0C 11:43 AM P) ~ROPOSED W~LL PROP[~E DIRECTION ¥BRTICAL-DHPTHS AZiMUI~ TVD SUB-SBA 90.00 1670.21 161L.51 90.00 17~6.7L 1698.01 90.00 178~.?0 1725.00 90.00 1810.21 £751.51 91.41 L849.21 1790.51 94.17 1935.89 1877,19 96.47 20L9.60 I960.90 98,41 2100.05 204L.35 100.09 2~76.93 21L0.23 101.56 2249.94 ~[91.24 L02.86 23L8.82 2260.L2 104.O4 2383.32 2324.62 105.[[ 2443.19 2384.49 106.09 ]498.20 2439.50 ~07.00 2~48.16 2409.46 BHCTIO~ DEPART £98.7~ 2~?.~4 250.58 263.L9 282.39 329.92 382.73 440.61 503;35 570.72 642.47 7£8.32 798.00 881.20 967,62 COORD~NATES-PROM ALASKA Zone 4 TOOL Db/ ~HLLH~AD X Y FACH L00 0.00 N 211.93 ~ 557466.~3 6014102.46 HS 2.50 0.00 N 253.56 E 557509.95 6014102.78 ~S 2.50 0,00 N 267.26 B 557523,64 6014~02.88 HS 0.00 0,00 N 280,71 H 557537.09 60L4]02,99 26R 0.00 0.26 S 301.09 8 557557.~7 6034102.89 24R 3.50 2,74 7.85 L5.58 25.69 38,74 54.09 7L.89 92.05 114.52 139. ]-9 ~07,86 2592.87 2534.17 L056.93 i65.99 108.67 2632.i7 2573.%7 I]48.81 ~94,82 109.44 2665.92 2607.22 1242,90 225.55 110.19 2693.9~ 2635.28 1338.86 258.09 /~0.35 2699.31 2640.61 1359.92 265.39 310.35 3~64.42 3405.72 4465.14 1345.07 110.35 3464.42 3405,72 4465,15 134~.08 110.35 3485.77 3427,07 4542.42 137L.95 Ll0.35 35L8.40 3~59.70 4636.93 L404.81 /~0,35 3557.54 3498.84 4728.93 1~36.79 110.35 3603.0I 3544.3£ 4817.97 1467.75 S 110.35 361L.?0 3553.00 4833.39 1473.12 S lL0.35 3654.58 3595.88 4903.63 L497.54 S 350-86 H 557607,26 6014100,79 22R 3.50 405.29 H 559661.72 6014096.09 20R 3.50 464.L6 ~ 557720.64 6014088.82 18~ 3.50 527.25 E 557783.80 6014079.00 LTR 3.50 594.34 B 557850.98 6014066.66 ~6R 3.50 665.[6 H 55792~.91 601405L.85 15E 3.50 739.46 E 557996.34 6014054.63 L4R 3.50 8L6.96 B 558073.99 6014015.07 14R 3.50 997.37 B 558154.56 60L3993.22 13R 3,50 980.39 B 558237.76 6013969.19 L3R 3,50 1065.?~ E 558323.27 60l$943,04 12R 3.50 1153.01 B 558410.78 60L3914.89 12R 3,50 £241.97 ~ 558499.97 6013884.84 £2R 3.50 1332.25 E 558590.49 6013853.G0 12R 3.50 1352.00 E 558610,29 6013845.86 HS ~.50 4263.47 B 561529.69 6012788.68 HS 0.00 4263.48 8 561529.70 6012788.67 bS 0.00 4~35.94 E 56£602.35 6012762.36 LS 4.00 4424.54 B 561691.20 60L2730.L9 L~ 4.00 45L0.80 H 5617~7.69 6012698.87 LS ~.00 4594.29 ~ $6L861,41 6012668.55 LS 4.00 4608.~5 E 56~875,9L 6012663.30 h$ 4.00 4674.60 H 56394[.94 60L2639.39 LS 4.00 ,.~ ITl MDG-10(P06) 05 Jun 1997 Pa~e 3 STATION M]{ASURgD INC~ ~DHNTIFICAT£ON DH~"H ANGL~ 7100,00 52.95 7200.00 48.95 7300.00 44.95 N~J~qT) 7514.72 44.36 7400.00 40.95 ~ 4/~00 DROP 7423.78 40.00 TARGET 7623.78 40.00 TOP SCHRADBR / NA 7623.78 40.00 NB 7664,~4 40.00 NC/ND 7702.L0 40.00 ~ 7730.82 40.00 ~ 780?.94 40.00 O~k 7847.00 40.00 OA4 7991.38 ~0.00 OB 7935.77 40.00 {{ASH SC2{RAD~R 7967.10 40.00 CASINO POII',,F~ 8167.10 40.00 8267.10 40.00 (Ar~adrtll (c) 97 NPGt0P6 3.0C 11:43 AM P) PROPOSED WBL~ PROFILE D£R~CTION VERTICJLb-DHPTHS A ~] MU~H T VD SUB -SEA L~0.35 371~.99 3653.29 110.35 3774.98 ~716.28 110.~ 3843.2] 3784.53 110.35 3853.70 3795,00 110.35 3916.40 3857.70 SECTION D~PART 4985.48 5063 5£36.18 5146.~3 5204.31 110.35 3934.49 3875.79 5219.74 110.35 4087.70 4029.00 5349.30 110.35 4087.90 4029.00 5348.30 110.35 4118.70 4060.00 5374.31 t10.35 4147.70 4G89.00 5398.64 110.35 4169.70 4LX~.O0 5417.1G 1L0.35 4228.90 4L?O.O0 5466.61 1L0.35 4258.~0 4200.00 5491.78 LIO.3S 4292,70 4234.00 5520.3£ 110.35 4326.70 4268.00 5548-84 110.35 4350.70 4292.00 5568.98 1L0.35 4503.91 4445.21 5697.54 110.35 4503.91 4445.2L 5697.54 COORDXNATHS-FROM AI~SKA Zone 4 ~HI~D X Y FACB 10O 1~26.00 $ 475].34 B ~S 4.00 15~2.99 S 4824.14 ~ 4.00 1578.40 S 4892.6~ E 4.00 1581.99 S 4902.35 H 4.00 1602.08 S 4956.92 B 4.00 $6201~.99 60£2611.52 562091.89 6012585.09 bS 562160.58 60~2560.22 ~ 562~70.31 60L2556.~9 LS 562224.63 6012537.02 LS 1607.45 S 4970.99 ~ 562239.14 6012531.77 HS 4.00 1652.~5 S 509~.53 ~ 562360.00 6012488.00 ~S 0.00 ~652.~5 8 509~.53 ~ 562360.00 6012488.00 HS 0.00 1661.19 S 5115.92 H 562384.46 6012479.~4 ~49 0.00 1669.65 S 51~8.73 E 562407.33 6012430.86 HS 0.00 1676.07 S 5156.04 B 562424.69 6012464.57 HS 0.Q0 1693.~9 S 5202.46 R 5~2471.23 601244?.72 ~S 0.00 1702.04 S 5226.06 ~ 562494.90 6012439.15 HS 0.00 1711.95 S 5252.8~ E 562521.72 6012429.44 HS 0.00 172].88 S ~279.56 H 562540.$4 6012419.72 ~S O.00 1728.88 9 5299.44 H 662569.48 6012412-Bq HS O.00 1773.58 S 5419.98 ~ 562688.~4 6012369.10 0.00 17T3-58 S 9418.98 ~ 562688.34 6012369-L0 0.00 ~' ANADRILL AKA-DPC { APPROVED FOR PERMITTING ONLY PLAN SHARED SERVICES DRILLING ii 4nadrJ ]] Schlumberger MPG- ~0 (PO6) VERTICAL SECTION VTE~ ! ANADRILL AKA-DPC ~ Section at: ~110.35 A I, .__PJ,OVED JOep Scale,: 1 inch: 800 feet FOi~PEI:MIT'rlN(i Oi~LY k j C L " - ....... Al KB 0 0 0 O, O0 O' B) KOP/BUILD t,5/~O0 600 600 0 O.OC C) BUILD 2/~00 800 800 5 D) BUILD 2,5/]00 1000 999 2~ 7.0C E) E~ 2.5/~00 BUILD t796 t757 238 26.B[ F) CURVE 3.5/~00 }B~ tBlO 263 26.9~ G) END 3.5/100 CURVE 3322 2699 ~360 76. ~) DROP 4/~00 6520 3a64 4465 76.]i .... ~-E- -'--'--- ....... ~~-i~ I) END 4/100 DROP 7424 3934 5220 40,0( · d) ~ARGEI 7624 4088 5348 40..0( K) 7' CASI~ POINI 8~67 4504 5698 40.0t ' L} 1D 8t67 4504 5698 40.01 . . . ~ ..-~- ~ ~ ........ ~-- ............... __~ .m.-- ~ ~ ..... ~ ..... ~ ........... .-- ~~ ..... ::::: ::~ ..... -~-- ::::: l 0 400 BOO 1200 5600 2000 2400 2BO0 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 Section De ~arture (~na<lrill lc)g7 ll~Gl(~P6 3.ac Il: 44 AR P) I1'1 SHARED SERV:I:CES DRTLLTNG i · ~'oo- ,., · MPG-:tO (PO6) VERTICAL SECTION VIEW ~! ~mm 3750-_ SectiOn at: 110.35 TVD Scale.: 1 inch = ~00 feet ~oo- .. ., Oep Scale ' 1 inch -- 100 feet · % ~. .. Drawn .... ' 05 Jun 1997 · ~o ..... '~ ...... r¢~:,~.~'~, "' Anadr~]] SchJumberger ~ I 3gO0= .Marker Identification MO BKB SEC:TN INCLN A) END 4/~00 DROP 7424 3934 5220 40.00 A~ B) TARBET 7624 4088 5348 40.00 C) 7" CASIN6 POINT B~67 4504 5698 40.00 3950 N D) TO B167 4504 5698 40,00 V 4ooo, , , ' ' 4050 ...... ~ , Ta Ig~t .18~ j,u~.190 .feet ) i , i I 4150 ~ z~-I ~200 , ,~ . -u~-~=-- - -~-- · 4~5o I . 4300 '~" . · 'o~ - 4'~_~ . ' ......... ' ~-- % ...... 4350 ~ ~ :--R- ~--- 4400 ~ ' ' 4450 [ · ~hn ~'~,~1~'!~ ! J 1 FORPER ~lT' ri NG, · '"'"' LY ( . n .,,- 'p '~"'~.,.-~ i, ,~oo 4550 ..... 4600- ' , ' 5100 5J50 5200 '5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 , · . Section De¢irt, ure , , (AnaOr~ll (c)g7 MPGJOP$ 3.0C H'.44 AM p) 8l 3E)~ld Od(I 99I~1~/N~/ 09T~-PPg-LB6 gq :£l LGGl/qo/90 i i i i MPG- O (PO6) PLAN V ]EVl CLOSURE ..... : 5702 feel aL Azieuth ~08,12 DECLINATION,: ,28.045 [E) SCALE .......: t inch = 800 feet DRAW~i ....... : 05 Jun 1997 Marker Iden[i fkcat~on MD N/S E/W A) KB 0 0 )l 0 E B) K§P/BUILD 1.5/lO0 600 0 N 0 E C) BUILD 2/100 BOO 0 N 5 E O) BUILD ;~. 5/100 )000 0 N 23 E E) END 2.5/~00 BUILD ~796 0 N 254 E F) CURVE 3.5/100 t856 0 N 2B~ E G) END 3.5/100 CURVE 3322 265 S 1352 E H) DROP 4/tO0 65,?.0 1345 S 4~63 E I) END 4/~00 DROP 7424 1607 5. 4971 E d) TARGEI 7624 ~652 S 5092 E K) 7' CASING POINl 8)67 )774 S 54)9 E L) TD B~67 i774 S 54)9 E ANADRILL AKA-DPC APPROVED ' FOR PERMITTING ONL~ i~LAN ~)'" .. ,, ~ .,~iTa.~rg, t (Rad)~ s tOO (ei;~) 400 0 400 800 t200 2600 2000 2400 2800 3200 3600 4000 4400 4BO0 <- NEST · EAST -> Oma~'-i]! (c)97 I~GIOP6 3.0C I:=:00 I:N PI '1] ~> m WELL PERMIT CHECKLIST COMPANY · FIELD & POOL ~,¢'.,2_.,5'/~-7"~ INIT CLASS .,,~~ WELL NAME_.,"~~'_ ~-' ,,/~::) PROGRAM: exp [] devyredrll [] serv [] wellbore seg r21 ann. disposal para req ~ GEOL AREA ~'~O UNIT# //3 2_~-~ ON/OFF SHORE ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 13. · Permit fee attached ....................... Y Lease number appropriate ................... Unique well name and number .................. Y Well located in a defined pool .................. Y Well located proper distance from drilling unit boundary .... Y Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... IY Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... N N N N N N N N N N N ENGINEERING D/~TE 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... ~(~NNN~ 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~j.~ 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation N 26. BOPE press rating appropriate; te'st't(~' ' "~'-~' ' ' ~sigl U 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~N / YY N.~~~, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. N 33. Seabed condition survey (if off-shore) ............. //Y N / Y N /~)~.. ~.~~ 34. Contact name/phone for we.eklyprogress repqrtSlexplora,ory only] ...... GEOLOGY: ENGINEERING: COM S~N: BEW~ "(('~ DWO'l"' ~ JDH~::P~ RNC Comments/Instructions: z o H z HOW/Ijt - A:\FORMS\cheklist rev 07~97 WELL PERMIT CHECKLISTco Y INIT CLASS / -'6~,;7/ GEOL AREA PROGRAM: expB dev~redrlB serv~ wellbore seg~ ann dtsp para req~ ADMINISTRATION ENGINEERING 1 2 3 4 5 6 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... N Lease number appropriate ................ N Unique well name and number ............... N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary. . N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party .............. N Operator has appropriate bond in force ......... N Permit can be issued without conservation order .... N Permit can be issued without administrative approval. . N Can permit be approved before 15-day wait ....... N REMARKS APPR 14 15 16 17 18 19 20 21 22 23 24 25 26. 27. 28. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf cst. .~ N? ~ ~ CMT vol adequate to tie-in long string to surf cst.. ~ N~ ~/--~~p CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved. ~/~ Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate ........... ~ N k~ ~ Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~~ psig~ N Choke manifold complies w/API RP-53 (May 84) ...... ~ N Work will occur without operation shutdown ....... ~ ~ Is presence of H2S gas probable ............. Y GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y//~ 32. Seismic analysis of shallow gas zones .......... ~/ N 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports . . . y. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 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 Wed Sep 17 11:36:02 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/17 Origin ................... STS Reel Name ................ UArKNOWN Continuation Number ...... 01 Previous Reel Na/ne ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT 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: FEL: FWL: MWD RUN 2 AK-MM-70221 GABEL ANGLEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Ams a & Gas ns. MPG- 10 500292278000 BP EXPLO~TION (ALAS~) , INC. SPERRY-S~ DRILLING SERVICES 17-SEP-97 Date 27 13N 10E 1665 3350 .00 58.20 29.20 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 7765.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MARK VANDERGON OF BP EXPLORATION (ALASEA), INC. ON 08 SEPTEMBER, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7765'MD, 4415'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Ntmzber ........... 1.0.0 Date of Generation ....... 97/09/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP .5000 START DEPTH 4903 0 4903 0 4903 0 4903 0 4903 0 4910 5 4962 0 STOP DEPTH 7707 0 7707 0 7707 0 7707 0 7707 0 7714 5 7765 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 4962 . 0 7765 . 0 $ REMARKS: MERGED MAIN PASS. $ 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 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHI~M 4 1 68 RPD MWD OHPIM 4 1 68 FET MWD HOUR 4 1 68 ROP MWD FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 4903 7765 6334 GR 17.0065 119.733 57.5096 RPX 1.7877 153.052 9.92497 RPS 1.6574 128.68 10.2077 RPM 1.4932 129.288 10.0786 RPD 1.5288 109.945 10.395 FET 0.1484 13.3601 1.02437 ROP 9.8998 632.519 203.078 Nsam 5725 5609 5609 5609 5609 5609 5609 5607 First Reading 4903 4910.5 4903 4903 4903 4903 4903 4962 Last Reading 7765 7714.5 7707 7707 7707 7707 7707 7765 First Reading For Entire File .......... 4903 Last Reading For Entire File ........... 7765 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service ~Ub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER r FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4903.0 RPD 4903.0 RPM 4903.0 RPS 4903.0 RPX 4903.0 GR 4910.5 ROP 4962.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 7707.0 77 07.0 7707.0 7707.0 7707.0 7714.5 7765.0 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 02-AUG-97 5.06 5.46 MEMORY 7765.0 4962.0 7765.0 37.3 76.7 TOOL NUMBER P0776CRG6 P0776CRG6 8.5OO 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical.log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD 9.00 68.0 9.2 5O0 5.3 2.600 2.095 2.500 3.500 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHM~ 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 ROP MWD 2 FT/H 4 1 68 Code Offset Channel ' 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 31.1 Maine DEPT GR RPX RPS RPM RPD FET ROP Min 4903 17 0065 1 7877 1 6574 1 4932 1 5288 0 1484 9 8998 Max Mean 7765 6334 119.733 57.5096 153.052 9.92497 128.68 10.2077 129.288 10.0786 109.945 10.395 13.3601 1.02437 632.519 203.078 Nsam 5725 5609 5609 5609 5609 5609 5609 5607 First Reading 4903 4910.5 4903 4903 4903 4903 4903 4962 Las t Reading 7765 7714.5 7707 7707 7707 7707 7707 7765 First Reading For Entire File .......... 4903 Last Reading For Entire File ........... 7765 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Physical EOF Scientific Scientific Physical EOF End Of LIS File