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197-105
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC L-33 MILNE PT UNIT L-33 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2022 L-33 50-029-22774-00-00 197-105-0 W SPT 6976 1971050 1744 1458 1467 1462 1462 40 69 71 72 4YRTST P Guy Cook 5/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 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 L-33 Inspection Date: Tubing OA Packer Depth 390 2214 2180 2176IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220509164407 BBL Pumped:1.8 BBL Returned:1.8 Friday, June 10, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 7HVWGXH ZHOOVKXWLQVLQFH UHVWDUWLQMHFWLRQ James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 14:52:44 -08'00' DATE 10/04/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 9 6 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska vii &Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-33 (197-105) Halliburton INJECTION PROFILE 22 JUL 2019 CD 1: x MPI_-33_IPR0F 22JUL19 7/30/20191:16 PM PDF Doa MPL-33_IPR0F_22JUL19_40dwn 7/30./20191:16 PM LAS File :4 MPL-33IPROF Mul-19-40up 7/30/20191:16 PM LAS File MPL-333PROF 22JUL79 80dwn 7/30.120191:16 PM LAS File J MPL-33_€PROF 22JUL19_30up 7/30/20191:16 PM LAS File MPL-33_IPROF_22JUL19_120dwn 7/30.120191;16 PM LAS File MPL-33_IPROF 22JUL19_120up 7/30./20191:16 PM LAS File MPI_-33_IPR0F 22JUL19_img 7/31/20191:16 PM TIFF File MPL-33_IPR0F 22JUL19_stop-10500 7,/30/20191:16 PM LAS File MPL-33_I1PROF 22JUL19 stop -1070D 7/30/20191:16 PM LAS File J MRL-33_IPR0F 22JUL19 stop -10800 7+30./20191:16 PM LAS File Please include current contact information if different from above. Ro c�jVieo � Q p 4 2p�9 GCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 16,2018 TO: Jim Regg 2 P.I.Supervisor , �eiq 1 !7(iS SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC L-33 FROM: Adam Earl MILNE PT UNIT L-33 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT L-33 API Well Number 50-029-22774-00-00 Inspector Name: Adam Earl Permit Number: 197-105-0 Inspection Date: 1/14/2018 Insp Num: mitAGE180114210501 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-33 " Type Inj W ` TVD 6976 • j Tubing3198 3199 - 3198 ' 3198 PTD 1971050 ' Type Test, PT Test psi 1744 IA 232 2413 - 2385 - 2379 - BBL Pumped: I 2.1 _iBBL Returned: i 2.1 - OA 24 43 43- 43 nterval 4YRTST P/F I P Notes: MIT/IA SCANNED Tuesday,January 16,2018 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: ,~ Grayscale, halftones, pictures, graphs, charts - Pages: '~ [] Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type 'OVERSIZED Logs of various kinds Other Complete COMMENTS: Scanned b MitdredDaretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si , G+s?Ya�.tt+°YaR+.m+B` +'D'".+`V', >+r.Rro?9M'44F;+w5 <m*ert.T°^vp.nA' .sa vn + .qm wr, .a ean'+!ma? "u^^Rm^M*r 'r..rm.aw*+eF.Tisrc*�t +?^'cw,m+'rywe'K?'F'" xn ^""»u'. rn.w. < :• ^.++m'+t .m+vr. .. .r„s*a. ,r ..; • +':hr?rv;" • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 # ' ED FFB 2, 4 ZOri Mr. Tom Maunder I q 1 3 Alaska Oil and Gas Conservation Commission j 333 West 7 Avenue PI Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPL -Pad Date: 10108/11 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 MPL -01A 2030640 50029210680100 Sealed conductor _ N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL-06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 -> MPL-33 1971050 50029227740000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL-39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL-40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL-42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job MPL -45 1981690 50029229130000 10 N/A 10 N/A 8.5 8/10/2011 ~~~ ~O 1~A/1/~/T°?"a4 PROAcnve DIACINOSTIC SEUVicES~ INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ,t .r ~ r fi ~It i, RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. ~_ Attn: Robert A. Richey ~~~~ 130 West International Airport Road Suite C ~ ~ v Anchorage, AK 99518 Fax: (907j 245-8952 1 ] Injection Profile 24-Aug-10 MPU L-33 BL / EDE 50-029-22774-00 ,, z "1 2] ,_, _ ~ -- Signed . ~ Date J Print Name: ~- N '~' =~ ~• ~ ~•~ .~~~~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 Fax: (9071245-88952 E-MAIL : ~s~5ar~~.,~o~~ac~(r~laae~~~,al®~ WEBSITE : ~v~nrt+r.l~t,iaa®r*.~I®~.~~rsl C:\Documents and SettingslDiane Williams\Desk[op\Tcansmit_BP.docx ~ • IF NGLL ~~~ ~/'ffi[ K~7fY/~~/r-~L ;,, ~ PaoAcrive Diagroosric SeRViar, Inrc. To: DNR - Division of Oil & Gas Corazon Manaois 550 West 7th Ave., Suite 800 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanica( Logs and /or Tubing Inspection(Caliper / MTT~ The technica! data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Ja~ Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ,f.~~:,~~-~d~~~ '~~~;,,i :~ ~ ~~JO~ ProActive Diagnostic Services, inc. A~Ctn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 89518 Fa~c (9~7~ 245-g952 1J 2) Injection Profile 2S-Jun-09 MPU L-33 BL / EDE 50-029-2277400 Signed : Print Name: Date : PROACT-VE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907y245-8951 Fax: (907)245-88952 E-MAIL: "~._.__~_.~.._ . _~.__~ _,..___~_._ ~: WEBStTE __.____.____. .__ _..___._ / ~~~ ~~~ ~~ n~~ ~i ~'y/_ T C:\Documents and Settings~Ownzr\Desk[op\Transmit_BP.docx ~,/ ~v / ~ 7cp(J 04/25/08 NO.4673 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wnll _Inh ft ~ n...... ..... 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) 08/18/07 1 1 F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE - ~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 LS-29 11963087 MEM TEMP SURVEY "Q 04/04/08 1 1 S-26 12071843 SBHP SURVEY ~ 04/03/08 1 1 06-15 11962594 LDL ~ _ (0 04/09/08 1 1 W-30 12034892 PROD PROFILE (1g~~(~ /(~/.(~ 04!11/08 1 1 L-221 11962592 USIT/CBL ~~ o~ ~6~ .~ 1 /(o~ 04/07(08 1 1 4-14A/S-37 11970818 CH EDIT PDC GR JEWELRY ~_ ~ 03/24/08 1 18-326 11978442 MCNL - ~ C 02/26/08 1 1 G-24A 11660525 MCNL 3k 02/02/07 1 1 .~ ~~~~ •-•~•~••v ••~w.wv ,.wa-•r ~ ~+~ .~~•a rn•~aa ri~w nGi Vf11Y11YU VIVC liVl-i cr~~.n ~v: BP Exploration (Alaska) {nc. Alaska Data & Consulting Service Petrotechnical Data Center LR2-1 ~~~~ APR 2 g 2008 2525 Gambell Street, Suite 40 900 E. BenSOn Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth Date Delivered: ', `t'~~~~(5 Received by: `~~ v~ 11/27/07 ~~h1~~U~~~~~ NO. 4517 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~,~r f,~~yyg~~(~ onff nn I~ ~'VL1V ~ °` 20~~' ~ ` ~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 t08VEm lt l`~r Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 ~ ~~ Anchorage, AK 99501 ~~ ~ '~ Field: P.Bay, Milne Pt., Lisburne well Job # Lo Descri tion Date BL Color CD MPL-33 11661179 MEM INJ PROFILE iREV15ED) 11/13/07 1 L1-15A 11661181 MEM PROD PROFILE ~ 11/21/07 1 MPH-08 11686799 USIT ~ _ 11/18/07 1 02-09B 11890327 USIT 11/21/07 1 LGI-04 11686752 RST ~~ .- ft / ~ ) 5' ~~ ~ 05/27/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska] Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. _ Anchorage, Alaska 99508 1i ~ ~~ Date Delivered: ~~~`"j~~` ~ ~ ?('~( Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • 11 /21 /07 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~a~~:~ '~~y~~,~ ~ ~ 2007 Wr±ll .Inh it 1 nn rlncrri nfinn NO.4509 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ~] 333 West 7th Ave, Suite 100 „- ~,~" Anchorage, AK 99501 Field: P.Bay, Milne Pt., Endicott ~~~ nMn QI r'•..1... nn Z-10 11676974 GLS ";'-?,. -- / 11/11/07 1 06-16 11686797 PPROF & RS _!' °:%°~? 11/15/07 1 MPL-33 11661179 MEM INJECTION PROFILE ;.") ~:~'~_ .~: •-;;7 ¢- -• "" ~ 11/13/07 1 MPF-25 11846827 USIT / '~ `~~"-. •"g s' i`„ 11/10107 1 GNI-04 11846828 USIT ,~~~~r~`;P-~ ; `"1_ 11/11/07 1 OWDW-SW 11626128 RST s} -"~?y "~ /• ..;., "~ ,~,,.'+• 10/10/07 1 1 3-35/L-36 11630502 RST ` t~ `"°- d r,, ~,`, ~ --~ ~_ y /~ 09{09107 1 1 15-26B 11661165 MCNL '? ~°1 = ~"°~' ! •~"'°~~_ ~; 08/24/07 1 1 05-36A 10928638 MCNL ~ ~ - {}'~).t~`~ `~ ' '"d. # 06/11/05 1 1 07-16A 71216211 MCNL ° -~ I " '~-, ~""~ y '" ; •( 08/27/06 1 1 2-28B/0-19 11638650 RST ); ~~' ~ ~r_~ ~~, ~ ~'~ t"- ~~ ~~ 07/05/07 1 1 07-02A 11649983 MCNL CfJ/ ~' ~- O'iS"~,~' ~I'` , ~; ..,.z t< 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT f,'jfo-"`? ...E~/~~r' - \ -""~,__ ae 09/11/07 2 1 r4LMJG AVn1YVYYLGVVC RCliClr' 1 at JIVIYIIYV AMU KCI VKIVIIVb VIV C.. ~.VYcT ~CAl:ri I V: BP Exploration (Alaska) Inc. _ _ Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ;~ s_.n Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283~,~ ATTM Beth f, i ~" Received by ~ ~~ .,~ ~(~ ~, • • MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ."7'/\ .... - I \ C P.I. Supervisor '-...,e11 '2 I ·10 DATE: Wednesday, February 01, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-33 MILNE PT UNIT KR L-33 rV /(D5 \If\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,:.E;.e-- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR L-33 API Well Number 50-029-22774-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060127133527 Permit Number: 197 -105-0 Inspection Date: 1/26/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I L-33 !Type Inj. ¡ w i TVD ! I I ! ! Well I I 6976 IA i 0 I 2050 ! 2050 2050 I 1971050 ! I, ¡ ! OA I ! j i , P.T. ¡TypeTest . SPT I Test psi 1744 50 50 50 50 ! , I I i I 3000 ! Interval 4YRTST P/F P Tubing I 3000 I 3000 3000 I , Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ~'CANNErJ FED ¡i Wednesday, February 01, 2006 Page 1 of 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well MPC-41 MPG-05 MPL-33 P-06A DS 02-25 D.:). 09-10 B-20 Y-25 PSI-10 P-26 02-14A F-12 04-35 ~ 5-09A 15-09A 5-09A J-13 D.S. 09-29 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889195 10715440 11058514 11132061 10987525 11058237 10980591 10928605 10715447 10928634 11075901 NA 10889172 10889183 NA 10919942 10877750 10980596 $CANNED OCT 3 1 2005 Log Description SBH SURVEY MPSP INJECTION PROFILE INJECTION PROFILE LDL INJECTION PROFILE INJECTION PROFILE 't>"'-- V\~~ ~ LDL MEM PPROF W/DEFT MPSP IPROF & WARMABACK MEM PPROF W/DEFT MEM PPROF & IPROF LDL SBHP SURVEY OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE LDL PPROF W/DEFT c o&- ~~- Date 12/24/04 11/09/04 06/03/05 10/12/05 06/24/05 08/16/05 08/05/05 11/20/04 01/01/05 06/02/05 07/09/05 06/03/05 10/10/04 11/04/04 02/02/05 02/13/05 06/29/04 08/10/05 10/18/05 NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD -/ -' Alaska Data & Consulting Services 2525 Gambe" Street, Suite 40 Anchorage, AK 99503- 8 ATTN: Beth Received by: 'I)j () ~\ ". L (l~. .. ..."':'l:..."..... ~.'.". _;c~:~'F""".' ..:.·c.:"' ~~... t~~'~f·· . ·£1j~L ~ MEMORANDU' ' State of A-i aska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor Chair THRU: Tom Maunder Petroleum Engineer FROM: Lou Grimaldi Petroleum Inspector DATE: January 5, 2002 SUBJECT: Mechanical Integrity Tests BPX ~ Well L-33i Milne Point Unit Kuparuk River Field NON- CONFIDENTIAL WellI P.T.D.I Notes: L-33i 197-1050 Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj. I p I T.V.D. I 6974 I Tubing I 2790 I 2790 I 2780 I 2780 I lntervall 4 TypetestI M {TestpsiI 1744 ]CasingI 5 I 20201 20101 2010l P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. P = PRODUCED 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 witnessed the four year Mechanical Integrity Test on the above injection well in the Milne Point Field. The well tested was properly prepped and was concluded successfully. Lee Hulme (BPX rep.) provided all pertinent data and performed a good test on ths well. The wellhouses were all very clean and I was impressed with the neatness of the piping on these wells. M.I.T.'s performed: 1_ Attachments: Number of Failures: None Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. MIT L pad MPU 1-5-02 LG.xIs 1/14/02 ITree: ~--~head: 11" 5M FMC Gen. 5 w/ 11" x 4.5" FMC Tbg. Hng., 4.5" NSCT threeds top end bottom, 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 HOWCO 9 5/8" 'ES' 1 2016' mdl cementel MPU L-33i Orig. k:_~lev. = 49.40 (N 27E) Orig. GL Elev. = 16.40 DF to 7" csg. hnr. 33.06' (N 27E) 9 5/8", 40ppf, L-80 Btrc. ~ KOP (~500' Max. hole angle -- 109 deg. Hole angle thru' perfs - 65 to 109 deg. Horizontal Wellbore Well equiped with tbg patCh and redUcing nipple. 7" 26 ppf, L-80, Mod. BTRC casing ( drift ID = 6.151", cap. = 0.0383 bpf Stimulation Summary none performed HOWCO 7" ES cementer 11,481' md Two 7" x20' marker joints f/ 10,953'- 10,633' mc Baker payzone packer 11,483' md Perforation Summary Ref Icg: Anadrill CDP, 7/11/97 Interval (-I'VD) "Heel" Ku: 10,792'-10,806 ' (7065'-7071' 10,912'-10,932' (7111'-7118' 10,972'-10,992' (7133'-7140' 11,044'-11,127' (7156'-7178': "Toe" Kuo."A" 13,022'-13,084' (7147'-7130' 13,128'-13,158' (7115'-7105'I 13,180'-13,200' (7099'-7093'; 4.5" HES X-Nipple (3.813" id) [ 10,574' 7" Baker" S-3" Packer [ 10,596' 4.5"x 1" Camco"KBG-2 LS" I 10,662' w/Btm, latch 4.5" x 1" Camco "KBG-2 LS" [ 10,730' w/Btm, latch 4.5" Halliburton DWP tubing patch| 1 0,899' minimum ID 2.375". Patched hole L at 10911'-10915'. Bottom of patch[ 10,919' 7" x 4.5" Baker" $^BL-3" I ,208' Prod. pkr. anchor release £ 4.5" lIES XN-Nipple (3.725" id) [ 11,5}13' XN-Nipple reducer set (2.205" icl) 12,164' mO ]' 7" lending collar (PBTD) 13,296' 7" float shoo 13,382' md DATE REV. BY COMMENTS 07/14/97 M. Linder Drilled and Cased by Nabors 27-E 10/13/97 JBF Initial WIW Completion by Nabors 4ES 10/18/97 MDC Completion 4ES M.Linder 9/22/01 Set tbg patch/reducing nipple MILNE POINT UNIT WELL L-33i APl No: 50-029-22774-00 BP EXPLORATION (AK) 17 MEMORANDUM TO' THRU: FROM: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor John Crisp, Petroleum Inspector State of Alaska Alaska Oil and Gas COnservation Commission DATE: SUBJECT: December 22, 2000 Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arriVed on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments' SVS MPU L pad 12-22-00jc ,cc; NON-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and Gas conservation CommiSsion Safety Valve System Test Report Operator: BPX Submitted By: John CriSp Date: 12/22/00 Operator Rep: Larry Niles Field/Unit/Pad: PBU MPU L Pad AOGCC Rep: John Crisp Separator psi: LPS 140 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI ! Trip Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060 140 1001 90 P P OIL L-03 1900070 L-04 1900380 140 100 105 P P OIL L-05 1900390 1401 100 100 P P OIL L-06 1900100 140 100 100 P ' P OIL iL-07 1900370 140 100 100~ P P OIL L-08 1901000 4000 2000 1950 P P WAG ~L-09 1901010 I L-11 1930130 140! 100 115 P P .OIL L-12 1930110 140 100 100 P P OIL L-13 1930120 140 100 100 P P OILi L-14 1940680 140 100 95 P P OIL L-15 1940620 · L-16A 1990900 L-17 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800 140 100! 105 P P OIL L-28A 1982470 140 100! 110 P P OIL L-29 1950090 140 100! 95 P P OIL L-32 1970650 140 100 100 P 'P OIL L-33 1971050 L-35 1970920 140 100- 105' P P OIL L-36 1971480 140 100 105i P P OIL L-37A 1980560 L-40 1980100 140 100 100 P P ~,:2,~ ~ ~ ¥,~ ~ OIL L-45 1981690 140 100 105 P P ~' OIL L-34 1970800~ 4000 2006 1900 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% ["']9o Day Remarks: 12/26/00 page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CVCLr. Page 2 of 2 SVS MPU L Pad 12-22200jc'xls THE MATERIAL UNDER THIS cOVER HAS BEEN MICROFILMED ON OR BEFO. RE JANUARY 03., 2001 M P L ATE E IA L U..N W DER TH iS M ARK E R C:LO~M.DOC AOGCC Geological Materials Inventory PERMIT 97-105 ARCO Log Data Sent Recieved MMS SRVY R SPERRY 0.-5798.37 1/7/1998 1/12/1998 SRVY RPT R SCHLUM 112.13405. 1/7/1998 1/12/1998 7877 T SCHLUM CDR/ADN 12/9/1997 12/18/1997 ADN-MD L 5930-13300 12/9/1997 12/18/1997 T ADN-TVD L 4300-7530 12/9/1997 12/18/1997 CDR-MD L 111-13340 12/9/1997 12/18/1997 T CDR-TVD L 300-7550 12/9/1997 12/18/1997 GR/CCL L 10100-10700 11/5/1997 11/5/1997 PERF L 10100-10700 11/5/1997 11/5/1997 USIT L BL(C) 8250-13269 3/23/1998 3/25/1998 10-407 Completion Date Daily well ops Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis _description recieved? yes Are tests required? yes no Received? yes no Well is in compliance Initial Comments Box no UIC Friday, October 08, 1999 Page 1 of 1 AOGCC Geological Materials Inventory PERMIT 9 7-105 AP. CO Log Data 97-105 ~'~'~'~ SPERRY 0.-5798.37 ~' SCHLUM 112. i3405. ~ BL(C) 8250-13269 ~"~SCHLUM CDR/ADN Sent Recieved 1/7/1998 /12/1998 97-105 1/7/1998 /12/1998 97-105 3/23/1998 /25/1998 97-105 ) ~)7~'? 12/9/1997 /18/1997 97-105 300-7550 7(/f~ F__~I~ ~x. 12/9/1997 /18/1997 97-105 4300-7530 ."J' ¥ 0 ~] h llj 12/9/1997 /18/1997 97-105 10100-10700 ..~'e~t~j,;.:)(.,.:~.-, ,¢',-)'~ '!-~ []~:[~ 11/5/1997 1/5/1997 Are dry ditch samples required? yes ~o And received?.~...-yss---"----~no Was the well cored? yes ~no Analysis description recieved? yes ..... no Received? Initial 97-105 ~ 5930-13300 /~ ~ p~/ (/t~q~?~) 12/9/1997 /18/1997 T 97-105 t~' 111-13340 .( l.~, ), (/'.OB) 12/9/1997 /18/1997 T 97-105 ~ 10100-10700 T~;¢~ j~ (,,){. c ~. ~-~ 11/5/1997 1/5/1997 ~4.0~-~07 Completion Date Are tests required? Well is in compliance Comments Box UIC Thursday, October 07, 1999 Page 1 of 1 3/23/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11950 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Colored Well Job # Log Description Date Print RF Sepia LIS Tape MPB-25 981 47 USIT 9801 01 I 1 MPC-36 981 47 USIT 980205 I 1 MPC-39 98147 USlT 980118 I 1 MPG-09 981 47 USIT 980220 I 1 MPJ-17 98147 USlT 971119 1 1 MPL-33 981 47 USIT 971008 1 1 MPL-42 981 47 USlT 980224 I 1 -- 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: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~ · · - STATE OF ALASKA -~ .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well i--~ Oil ~1 Gas F-q Suspended I~Abandoned l~ Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-105 !3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-66;12;.~.. ..... ~ ~ 50-029-22774 4. Location of well at surface ~ .... " ' ¢ t,O¢,~:t'~ 9. Unit or Lease Name 3764' NSL, 5118' WEL, SEC. 8, T laN, R10E, UM! ~.,~'~/~~/_./~_/. ~. '~lr~ii~ '. Milne Point Unit At top of productive interval i ~~ 10. Well Number 2716' NSL, 702' WEL, SEC. 1, T13N, R9E, UM * ~/~,~i-.;: ' MPL-33i At total depth ..... :--". 11. Field and Pool 4340' NSL, 2695' WEL, SEC. 1, T13N, R9E, UM Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 50.7'I ADL 388235 12. Date Spudded 113. Date T.D. Reached i 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 6/23/97 7/10/97 t9/--t-5¢~/~:~,,/?,/'?? ,~ N/A MSLI One 17. Total Depth (MD+-I-VD)13405 7026 FT1]18' Plug Back Depth (MD+TVD) ]19' Directi°nal SurveY 120' Depth where SSSV set121' Thickness °f Permafr°st13296 7061 FTI [~Yes I-]No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/CCL, CDR, Acoustic, GR/JB 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 5908' 12-1/4" 1675 sx PF 'E', 500 sx Class 'G' 7" 26# L-80 33' 13382' 8-1/2" 570 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 11226' 10596', 11208' MD TVD MD TVD Payzone Pkrs: 11483', 12164' 10792'-10806' 7065'-7071' 10912'-10932' 7112'-7119' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10972'-10992' 7133'-7139' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 11044'-11127' 7155'-7178' 13022'-13084' 7148'-7129' Freeze protect with 40 bbls diesel 13128'-13158' 7115'-7106' 13180'-13200' 7099'-7092' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) November 7, 1997 ! On Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL 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. Top Kuparuk 10496' 6925' Top Kuparuk 'C' 10763' 7052' Top Kuparuk 'A' 10888' 7103' Top Kuparuk A1 11039' 7153' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAlvord .~.,,../~:~,,~.- ~ ~ Title Senior Drilling Engineer Date ~,/5' (.9~ MPL-33i 97-105 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (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 Performance Enquiry Report Operator BP Exploration Date 21:58, 12 Dec 97 Page 1 The analysis is from - 18:00, 30 Jun 97 - to - 18:00, 30 Jun 97 Programs in Result Table: MPL-33 Drill Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPL-33 Event 18:00, 30 Jun 97 18:00, 30 Jun 97 0 hr 0 min Obtained leak off 13.8 Hole Size MDR 8-1/2 Facility Date/Time 22 Jun 97 23 Jun 97 24 Jun 97 25 Jun 97 26 Jun 97 27 Jun 97 28 Jun 97 Progress Report M Pt L Pad Well MPL-33 Rig Nabors ~ Page 1 Date 12 December 97 06:00-09:00 09:00-09:30 09:30-18:00 18:00-23:00 23:00-01:30 01:30-05:00 05:00-06:00 06:00-11:00 11:00-12:00 12:00-20:00 20:00-20:30 20:30-21:00 21:00-22:30 22:30-01:30 01:30-02:30 02:30-06:00 06:00-14:00 14:00-16:00 16:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-16:00 16:00-17:00 17:00-18:30 18:30-19:30 19:30-20:00 20:00-06:00 06:00-06:30 06:30-10:00 10:00-12:00 12:00-14:00 14:00-16:00 16:00-18:00 18:00-18:30 18:30-21:30 21:30-23:30 23:30-00:30 00:30-01:00 01:00-06:00 06:00-06:30 06:30-08:00 Duration 3hr 1/2 hr 8-1/2 hr 5hr 2-1/2 hr 3-1/2 hr lhr 5hr lhr 8hr 1/2 hr 1/2 hr 1-1/2 hr 3hr lhr 3-1/2 hr 8hr 2hr 14 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 7-1/2 hr 1/2 hr lhr lhr lhr 8hr 1/2 hr 1/2 hr lhr lhr 7-1/2 hr lhr 1-1/2 hr lhr 1/2 hr 10hr 1/2 hr 3-1/2 hr 2hr 2hr 2hr 2hr 1/2 hr 3hr 2hr lhr 1/2 hr 5hr 1/2 hr 1-1/2 hr Activity Rigged down High pressure lines Held safety meeting Rig moved 50.00 % Rig moved 80.00 % Installed Divertor Installed Flowline Racked back drill pipe Serviced Top drive Serviced Flowline Racked back drill pipe Serviced Top drive Tested Divertor Washed to 112.0 ft Drilled to 335.0 ft Made up BHA no. 1 Repaired Top drive Repaired Top drive Made up BHA no. 1 Drilled to 1685.0 ft Held safety meeting Drilled to 2154.0 ft Circulated at 2154.0 ft Pulled out of hole to 1000.0 ft R.I.H. to 2154.0 ft Drilled to 3472.0 ft Held safety meeting Circulated at 3472.0 ft Pulled out of hole to 1656.0 ft R.I.H. to 2150.0 ft Drilled to 3283.0 ft Backreamed to 3283.0 ft Held safety meeting Backreamed to 1874.0 ft R.I.H. to 3283.0 ft Drilled to 4505.0 ft Circulated at 4505.0 ft Pulled out of hole to 1787.0 ft R.I.H. to 4505.0 ft Held safety meeting Drilled to 5633.0 ft Held safety meeting Drilled to 5930.0 ft Circulated at 5930.0 ft Pulled out of hole to 980.0 ft R.I.H. to 5930.0 ft Circulated at 5930.0 ft Held safety meeting Pulled out of hole to 240.0 ft Pulled BHA Serviced Casing handling equipment Held safety meeting Ran Casing to 5908.0 ft (9-5/8in OD) Ran Casing to 5908.0 ft (9-5/8in OD) Circulated at 5908.0 ft Facility Date/Time 29 Jun 97 30 Jun 97 01 Jul 97 02 Jul 97 03 Jul 97 M Pt L Pad Progress Report Well MPL-33 Rig Nabors at~ 08:00-10:30 10:30-11:30 11:30-13:30 13:30-14:00 14:00-16:00 16:00-20:00 20:00-21:00 21:00-23:30 23:30-00:00 00:00-06:00 06:00-06:30 06:30-21:30 21:30-22:00 22:00-00:00 00:00-02:00 02:00-06:00 06:00-08:00 08:00-08:30 08:30-14:30 14:30-15:00 15:00-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-12:30 12:30-13:00 13:00-14:30 14:30-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-15:30 15:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-20:30 20:30-22:00 22:00-23:00 23:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:30 10:30-11:30 11:30-14:00 Duration 2-1/2 hr lhr 2hr 1/2 hr 2hr 4hr lhr 2-1/2 hr 1/2 hr 6hr 1/2 hr 15hr 1/2 hr 2hr 2hr 4hr 2hr 1/2 hr 6hr 1/2 hr 2hr 1/2hr 1/2 hr 1/2 hr 8hr 1/2 hr 3hr 1/2 hr 6hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 9hr 2-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr lhr 6hr lhr 1/2 hr 1-1/2 hr lhr 1-1/2 hr lhr 2-1/2 hr Activity Mixed and pumped slurry - 295.000 bbl Circulated at 2018.0 ft Mixed and pumped slurry - 475.000 bbl Rigged down Casing handling equipment Rigged down Divertor Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Repaired Top drive Held safety meeting Repaired Top drive Held safety meeting Made up BHA no. 2 R.I.H. to 2018.0 ft Repaired Top drive Repaired Top drive Drilled installed equipment - Cementing packer R.I.H. to 5823.0 ft Tested Casing Drilled installed equipment - Float collar Circulated at 5950.0 ft Performed formation integrity test Held safety meeting Drilled to 7206.0 ft Repaired Fluid system Drilled to 7487.0 ft Held safety meeting Drilled to 8231.0 ft Circulated at 8231.0 ft Pulled out of hole to 5608.0 ft Serviced Block line Serviced Top drive R.I.H. to 8231.0 ft Drilled to 8421.0 ft Held safety meeting Drilled to 9741.0 ft Held safety meeting Drilled to 10570.0 ft Circulated at 10570.0 ft Pulled out of hole to 8200.0 ft Serviced Top drive Held safety meeting R.I.H. to 10570.0 ft Circulated at 10570.0 ft Rest hole at 10570.0 ft Pulled out of hole to 250.0 ft Pulled BHA Held safety meeting Pulled BHA Repaired Casing stabbing board Ran Drillpipe to 5350.0 ft (5in OD) Tested Surface lines Mixed and pumped 25.000 bbl of treatment Page Date 2 12 December 97 Facility Date/Time 04 Jul 97 05 Jul 97 06 Jul 97 07 Jul 97 08 Jul 97 09 Jul 97 10 Jul 97 M Pt L Pad Progress Report Well MPL-33 Rig Nabors ~ 14:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:00 23:00-00:00 00:00-04:00 04:00-06:00 06:00-12:00 12:00-06:00 06:00-21:00 21:00-22:00 22:00-01:00 01:00-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:00 10:00-11:30 11:30-12:00 12:00-13:30 13:30-15:00 15:00-19:00 19:00-19:30 19:30-21:30 21:30-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-12:00 12:00-13:00 13:00-18:00 18:00-18:30 18:30-06:00 06:00-11:00 11:00-11:30 11:30-13:30 13:30-14:30 14:30-15:00 15:00-16:00 16:00-21:00 21:00-21:30 21:30-03:00 03:00-03:30 03:30-04:30 Duration 4hr 1/2 hr 1-1/2 hr lhr 2hr lhr 4hr 2hr 6hr 18hr 15hr 3hr 2hr lhr 1/2 hr lhr 2hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 4hr 1/2 hr 2hr 4-1/2 hr 2hr 2hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 4hr 1/2 hr lhr 5hr 1/2 hr 11-1/2 hr 5hr 1/2 hr 2hr lhr 1/2 hr 5hr 1/2 hr 5-1/2 hr 1/2 hr lhr Activity Monitor pressures Circulated at 5350.0 ft Ran Drillpipe in stands to 6279.0 ft Circulated at 6279.0 ft Ran Drillpipe in stands to 10570.0 ft Circulated at 10570.0 ft Pulled Drillpipe in stands to 5908.0 ft Circulated at 5908.0 ft Pulled out of hole to 0.0 ft Repaired Top drive Repaired Top drive Installed BOP test plug assembly Tested BOP stack Installed Wear bushing R.I.H. to 560.0 ft R.I.H. to 5908.0 ft Circulated at 5908.0 ft Held safety meeting Ran Drillpipe in stands to 7030.0 ft Circulated at 7030.0 ft Ran Drillpipe in stands to 9193.0 ft Circulated at 9193.0 ft Ran Drillpipe in stands to 10215.0 ft Washed to 10570.0 ft Circulated at 10570.0 ft Pulled Drillpipe in stands to 0.0 ft Held safety meeting Made up BHA no. 3 R.I.H. to 10570.0 ft Circulated at 10570.0 ft Drilled to 10682.0 ft Held safety meeting Drilled to 11059.0 ft Held safety meeting Drilled to 11360.0 ft Held safety meeting Drilled to 11625.0 ft Circulated at 11625.0 ft Pulled out of hole to 10400.0 ft R.I.H. to 11625.0 ft Drilled to 12001.0 ft Held safety meeting Drilled to 12377.0 ft Drilled to 12490.0 ft Held safety meeting Drilled to 12565.0 ft Circulated at 12565.0 ft Pulled out of hole to 11635.0 ft R.I.H. to 12565.0 ft Drilled to 12659.0 ft Held safety meeting Drilled to 13128.0 ft Circulated at 13128.0 ft Pulled out of hole to 11718.0 ft Page Date 3 12 December 97 Facility Date/Time 11 Jul 97 12 Jul 97 13 Jul 97 Progress Report M Pt L Pad 04:30-06:00 06:00-11:30 11:30-13:30 13:30-16:30 16:30-18:00 18:00-19:30 19:30-21:30 21:30-04:00 04:00-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-10:00 10:00-03:30 03:30-04:00 04:00-06:00 06:00-13:00 13:00-15:30 15:30-17:30 17:30-19:00 19:00-01:00 01:00-03:00 03:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-11:00 11:00-18:00 Duration 1-1/2 hr 5-1/2 hr 2hr 3hr 1-1/2 hr 1-1/2 hr 2hr 6-1/2 hr 2hr lhr 1/2 hr lhr 1-1/2 hr 17-1/2 hr 1/2 hr 2hr 7hr 2-1/2 hr 2hr 1-1/2 hr 6hr 2hr 3hr lhr lhr lhr 2hr 7hr Well MPL-33 Rig Nabors ~ Page Date 4 12 December 97 Activity R.I.H. to 13128.0 ft Drilled to 13405.0 ft Circulated at 13405.0 ft Pulled out of hole to 9605.0 ft Repaired Top drive R.I.H. to 13405.0 ft Circulated at 13405.0 ft Pulled out of hole to 248.0 ft Pulled BHA Serviced Drillfloor / Derrick Retrieved Wear bushing Serviced BOP stack Rigged up Casing handling equipment Ran Casing to 13382.0 ft (7in OD) Rigged up Cement head Circulated at 13382.0 ft Circulated at 13382.0 ft Mixed and pumped slurry - 57.000 bbl Circulated at 11480.0 ft Mixed and pumped slurry - 59.000 bbl Wait on cement Rigged down Casing handling equipment Rigged down BOP stack Rigged down BOP stack Installed Tubing head spool Serviced Block line Tested Xmas tree Laid out 5in drill pipe from derrick Facility Date/Time 06 Oct 97 07 Oct 97 08 Oct 97 09 Oct 97 10 Oct 97 11 Oct 97 12 Oct 97 Progress Report M Pt L Pad Well MPL-33 Page 1 Rig Nabors 4ES Date 12 December 97 06:00-10:00 10:00-15:00 15:00-17:30 17:30-23:00 23:00-00:00 00:00-06:00 06:00-06:30 06:30-07:30 07:30-11:00 11:00-12:00 12:00-17:00 17:00-19:00 19:00-20:00 20:00-21:00 21:00-00:30 00:30-06:00 06:00-06:45 06:45-07:45 07:45-08:30 08:30-13:00 13:00-01:30 01:30-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-19:00 19:00-19:30 19:30-00:30 00:30-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-12:30 12:30-22:00 22:00-22:30 22:30-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:00 11:00-13:00 13:00-14:00 14:00-16:30 16:30-17:30 Duration 4hr 5hr 2-1/2 hr 5-1/2 hr lhr 6hr 1/2hr lhr 3-1/2 hr lhr 5hr 2hr lhr lhr 3-1/2 hr 5-1/2 hr 3/4 hr lhr 3/4 hr 4-1/2 hr 12-1/2 hr 3hr 1-1/2 hr 1/2 hr 3-1/2 hr 9hr 1/2 hr 5hr 3-1/2 hr 2hr 1/2hr 4-1/2 hr 1/2 hr lhr 9-1/2 hr 1/2 hr 6hr 1-1/2 hr 1/2 hr 3hr lhr 6hr 1-1/2 hr 1/2 hr 1-1/2 hr 10hr 1/2 hr 1-1/2 hr 2hr lhr 2hr lhr 2-1/2 hr lhr Activity Rigged up Drillfloor / Derrick Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Circulated at 2384.0 ft R.I.H. to 10317.0 ft Held safety meeting R.I.H. to 11433.0 ft Drilled installed equipment - DV collar Circulated at 11474.0 ft R.I.H. to 11951.0 ft R.I.H. to 13292.0 ft Circulated at 13292.0 ft Tested Casing Circulated at 13292.0 ft Pulled out of hole to 4847.0 ft Held safety meeting Pulled out of hole to 0.0 ft Set downhole equipment (wireline) Conducted electric cable operations Ran logs on tubulars Conducted electric cable operations Conducted electric cable operations Held safety meeting Conducted electric cable operations Pulled out of hole to 0.0 ft Held safety meeting Perforated R.I.H. to 13224.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Perforated from 10790.0 ft to 13200.0 ft Circulated at 10750.0 ft Pulled out of hole to 0.0 ft Held safety meeting R.I.H. to 13292.0 ft Reverse circulated at 13282.0 ft Held safety meeting Laid down 1550.0 ft of 3-1/2in OD drill pipe Serviced Block line Laid down 11675.0 ft of 3-1/2in OD drill pipe Pulled BHA Held safety meeting Installed BOP stack Conducted electric cable operations Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Tested Well control Made up BHA no. 3 R.I.H. to 2700.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 4 Made up BHA no. 3 Facility Date/Time 13 Oct 97 14 Oct 97 15 Oct 97 Progress Report M Pt L Pad Well MPL-33 Page 2 Rig Nabors 4ES Date 12 December 97 17:30-02:00 02:00-06:00 06:00-06:30 06:30-14:00 14:00-15:00 15:00-16:00 16:00-18:00 18:00-23:00 23:00-06:00 06:00-06:30 06:30-15:00 15:00-17:30 17:30-01:30 01:30-04:30 04:30-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-13:00 Duration 8-1/2 hr 4hr 1/2 hr 7-1/2 hr lhr lhr 2hr 5hr 7hr 1/2 hr 8-1/2 hr 2-1/2 hr 8hr 3hr 1-1/2 hr 2hr lhr 1-1/2 hr 2-1/2 hr Activity R.I.H. to 11500.0 ft Reverse circulated at 11500.0 ft Held safety meeting Laid down 11255.0 ft of 3-1/2in OD drill pipe Pulled BHA Tested Pipe ram Space out tubulars Conducted slickline operations on Slickline equipment - Retrival run Ran Tubing to 5658.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 11225.0 ft (4-1/2in OD) Conducted electric cable operations Removed BOP stack Installed Xmas tree Mixed and pumped 196.000 bbl of treatment Reverse circulated at 11225.0 ft Tested Tubing Tested Production packer - Via annulus Rigged down High pressure lines S~ BP EXPLORATION MILNE POINT / MPL-33 500292277400 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -49.40 217.99 217.99 168.59 308.75 308.75 259.35 399.84 399.84 350.44 488.77 488.77 439.37 578.18 578.16 528.76 666.92 666.83 617.43 756.81 756.55 707.15 847.19 846.52 797.12 942.12 940.66 891.26 1035.82 1033.24 983.84 1130.61 1126.31 1076.91 1225.86 1219.13 1169.73 1320.19 1310.46 1261.06 1414.00 1400.51 1351.11 1509.01 1491.41 1442.01 1603.97 1582.20 1532.80 1698.33 1671.26 1621.86 1792.58 1758.88 1709.48 1884.58 1843.61 1794.21 1978.78 1929.66 1880.26 2072.70 2015.14 1965.74 2167.53 2101.47 2052.07 2261.74 2186.04 2136.64 2355.42 2267.65 2218.25 2450.25 2347.88 2298.48 2544.07 2423.50 2374.10 2638.95 2497.38 2447.98 2733.96 2569.28 2519.88 2828.36 2637.05 2587.65 2921.81 2701.65 2652.25 3017.39 2765.26 2715.86 3108.49 2823.03 2773.63 3202.05 2879.56 2830.16 3296.86 2934.19 2884.79 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 062797 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70192 KELLY BUSHING ELEV. = 49.40 OPERATOR: BP EXPLORATION FT. COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 0 0 N .00 E .00 .00N .00E 0 10 S 16.72 E .08 .31S .09E 0 19 S 25.59 E .18 .67S .24E 0 17 S 30.95 E .05 1.11S .48E 0 28 N 56.50 W .85 1.10S .28E VERT. SECT. .00 -.25 -.59 -1.03 -.86 1 13 N 45.15 W .86 .21S .71W 2 59 N 60.31 W 2.06 1.61N 3.40W 4 6 N 64.42 W 1.28 4.16N 8.34W 6 37 N 57.94 W 2.86 8.33N 15.68W 8 6 N 53.02 W 1.69 15.26N 25.68W .46 3.70 9.21 17.62 29.78 9 32 N 49.58 W 1.63 24.27N 36.87W 12 18 N 46.65 W 2.97 36.30N 50.19W 13 36 N 45.52 W 1.40 51.12N 65.57W 15 19 N 53.11 W 2.70 66.37N 83.45W 17 16 N 61.38 W 3.23 80.49N 105.60W 44.12 61.94 83.04 106.44 132.68 16 31 N 61.20 W .79 93.76N 129.83W 17 32 N 61.60 W 1.07 107.07N 154.26W 21 0 N 58.47 W 3.82 122.68N 181.18W 22 12 N 58.40 W 1.28 140.85N 210.75W 23 37 N 56.07 W 1.83 160.25N 240.86W 160.13 187.77 218.78 253.41 289.20 24 23 N 52.80 W 1.63 182.55N 272.02W 24 32 N 52.80 W .16 206.08N 303.02W 24 19 N 52.35 W .30 229.92N 334.17W 27 55 N 52.38 W 3.82 255.25N 367.03W 30 51 N 53.08 W 3.14 283.08N 403.62W 327.52 366.40 405.61 447.05 492.99 33 34 N 53.73 W 2.90 313.20N 444.21W 38 57 N 54.94 W 5.77 345.51N 489.30W 38 46 N 53.79 W .79 380.19N 537.68W 42 50 N 55.44 W 4.44 416.10N 588.32W 45 21 N 55.46 W 2.66 453.35N 642.42W 543.52 598.99 658.52 720.59 786.27 47 9 N 55.85 W 1.95 491.44N 698.15W 49 22 N 56.70 W 2.42 531.02N 757.47W 51 54 N 57.48 W 2.84 569.28N 816.61W 53 44 N 57.43 W 1.97 609.38N 879.44W 55 52 N 56.97 W 2.29 651.35N 944.55W 853.77 925.07 995.44 1069.90 1147.31 ORIGINAL Sr PAGE 2 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPL-33 500292277400 NORTH SLOPE BOROUGH COMPUTATION DATE' 7/17/97 DATE OF SURVEY: 062797 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70192 KELLY BUSHING ELEV. = 49.40 FT. OPERATOR: BP EXPLORATION 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. 3389.91 2986.04 2936.64 56 22 N 57.09 W .55 693.39N 1009.37W 3483.95 3038.40 2989.00 55 57 N 56.66 W .59 736.08N 1074.79W 3578.79 3091.32 3041.92 56 12 N 54.39 W 2.01 780.62N t139.66W 3673.41 3144.03 3094.63 56 4 N 54.36 W .14 826.40N 1203.53W 3767.74 3196.55 3147.15 56 15 N 54.87 W .48 871.77N 1267.40W 1224.51 1302.58 1381.26 1459.84 1538.19 3861.52 3248.53 3199.13 56 25 N 54.91 W .19 916.67N 1331.26W 3955.66 3299.54 3250.14 57 57 N 54.70 W 1.63 962.27N 1395.91W 4047.63 3347.90 3298.50 58 35 N 54.62 W .70 1007.52N 1459.71W 4141.57 3396.67 3347.27 58 52 N 54.08 W .57 1054.32N 1524.95W 4234.48 3444.02 3394.62 59 50 N 54.35 W 1.07 1101.06N 1589.80W 1616.25 1695.36 1773.59 1853.87 1933.80 4329.46 3491.60 3442.20 60 2 N 53.88 W .48 1149.25N 1656.39W 4423.70 3539.90 3490.50 58 17 N 53.71 W 1.86 1197.05N 1721.68W 4517.43 3588.86 3539.46 58 43 N 53.59 W .48 1244.42N 1786.05W 4611.95 3637.72 3588.32 59 0 N 53.65 W .30 1292.41N 1851.19W 4705.27 3685.97 3636.57 58 43 N 53.18 W .53 1340.02N 1915.33W 2016.00 2096.89 2176.80 2257.69 2337.54 4799.71 3734.96 3685.56 58 47 N 54.02 W .77 1387.93N 1980.32W 4894.01 3784.71 3735.31 57 31 N 53.17 W 1.55 1435.46N 2044.79W 4986.68 3834.34 3784.94 57 42 N 53.21 W .21 1482.35N 2107.44W 5080.60 3884.69 3835.29 57 27 N 52.79 W .46 1530.06N 2170.76W 5174.63 3935.12 3885.72 57 40 N 52.97 W .29 1577.96N 2234.05W 2418.26 2498.34 2576.56 2655.81 2735.12 5269.71 3985.94 3936.54 57 42 N 52.99 W .02 1626.34N 2298.21W 5364.60 4037.37 3987.97 56 39 N 53.15 W 1.12 1674.25N 2361.95W 5456.90 4088.05 4038.65 56 45 N 53.46 W .30 1720.35N 2423.80W 5551.80 4140.44 4091.04 56 13 N 55.93 W 2.24 1766.07N 2488.36W 5645.21 4192.42 4143.02 56 8 N 56.48 W .50 1809.24N 2552.85W 2815.44 2895.13 2972.25 3051.36~ 3128.94 5728.00 4238.54 4189.14 56 9 N 56.59 W .11 1847.15N 2610.21W 5740.22 4245.34 4195.94 56 13 N 56.60 W .65 1852.75N 2618.68W 5798.37 4277.78 4228.38 55 57 N 54.33 W 3.26 1880.10N 2658.43W 3197.67 3207.82 3256.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3256.08 FEET AT NORTH 54 DEG. 43 MIN. WEST AT MD = 5798 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 305.13 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 5,798.37' MD PAGE 3 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPL-33 500292277400 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 062797 JOB NUMBER: AK-EI-70192 KELLY BUSHING ELEV. = 49.40 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 -49.40 1000.00 997.92 948.52 2000.00 1948.98 1899.58 3000.00 2753.93 2704.53 4000.00 3323.07 3273.67 .00 N .00 E 20.43 N 32.35 W 187.85 N 279.00 W 523.78 N 746.44 W 983.99 N 1426.58 W .00 2.08 2.08 51.02 48.94 246.07 195.05 676.93 430.87 5000.00 3841.46 3792.06 1489.09 N 5798.37 4277.78 4228.38 1880.10 N 2116.46 W 1158.54 481.61 2658.43 W 1520.59 362.05 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~ RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPL-33 500292277400 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 062797 JOB NUMBER: AK-EI-70192 KELLY BUSHING ELEV. = 49.40 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-TV-D VERTICAL DIFFERENCE CORRECTION .00 .00 -49 49.40 49.40 149.40 149.40 100 249.40 249.40 200 349.40 349.40 300 .40 .00 N .00 .00 .00 N .00 .00 .11 S .03 .00 .40 S .12 .00 .88 S .35 E .00 E .00 .00 E .00 .00 E .00 .00 E .00 .00 449.40 449.40 400 549.41 549.40 500 649.46 649.40 600 749.65 749.40 700 850.09 849.40 800 .00 .00 .00 .00 .00 1.26 S .53 .65 S .27 1.15 N 2.61 3.94 N 7.88 8.51 N 15.97 E .00 .00 W .01 .01 W .06 .05 W .25 .18 W .69 .44 950.95 949.40 1052.22 1049.40 1154.24 1149.40 1257.01 1249.40 1360.65 1349.40 9OO 1000 1100 1200 1300 .00 .00 .00 .00 .00 16.01 N 26.67 26.11 N 38.99 39.76 N 53.85 56.25 N 70.80 72.65 N 92.44 W 1.55 .86 W 2.82 1.27 W 4.84 2.02 W 7.61 2.76 W 11.24 3.64 1465.19 1449.40 1569.57 1549.40 1674.99 1649.40 1782.34 1749.40 1890.90 1849.40 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 87.75 N 118.89 102.14 N 145.14 118.45 N 174.18 138.82 N 207.45 161.66 N 242.96 W 15.79 4.54 W 20.17 4.39 W 25.59 5.42 W 32.94 7.35 W 41.50 8.56 2000.46 1949.40 2110.37 ' 2049.40 2220.57 2149.40 2334.24 2249.40 2452.10 2349.40 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 187.97 N 279.15 215.54 N 315.48 243.78 N 352.15 276.61 N 395.05 313.82 N 445.06 W 51.06 9.56 W 60.97 9.91 W 71.17 10.20 W 84.84 13.68 W 102.70 17.86 2577.38 2449.40 2707.13 2549 · 40 2845 · 94 2649 . 40 2993.04 2749.40 3151.34 2849.40 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 357.54 N 506.44 405.82 N 573.52 460.45 N 652.72 520.88 N 742.02 587.44 N 845.08 W 127.98 25.27 W 157.73 29.75 W 196.54 38.81 W 243.64 47.09 W 301.94 58.31 3323.98 2949.40 3503.60 3049.40 3683.04 3149.40 3863.09 3249.40 4050.50 3349.40 2900.00 3000.00 3100.00 3200.00 3300.00 663.59 N 963.37 745.03 N 1088.40 831.05 N 1210.02 917.42 N 1332.33 1008.94 N 1461.71 W 374.58 72.64 W 454.20 79.62 W 533.64 79.43 W 613.69 80.06 W 701.10 87.41 SP IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPL-33 500292277400 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 062797 JOB ATUMBER: AK-EI-70192 KELLY BUSHING ELEV. = 49.40 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4245.19 3449.40 3400.00 1106.46 N 1597.32 W 795.78 4441.78 3549.40 3500.00 1206.15 N 1734.07 W 892.38 4634.63 3649.40 3600.00 1303.93 N 1866.85 W 985.23 4827.58 3749.40 3700.00 1401.93 N 1999.61 W 1078.18 5014.86 3849.40 3800.00 1496.62 N 2126.52 W 1165.46 94.68 96.60 92.85 92.95 87.28 5201.35 3949.40 3900.00 1591.55 N 2252.08 W 1251.95 5386.48 4049.40 4000.00 1685.21 N 2376.57 W 1337.08 5567.92 4149.40 4100.00 1773.58 N 2499.46 W 1418.52 5747.52 4249.40 4200.00 1856.09 N 2623.75 W 1498.12 5780.00 4267.50 4218.10 1871.22 N 2646.07 W 1512.50 86.49 85.13 81.44 79.60 14.38 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST .20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Schlumberger ANADRILL Survey Report Client: BP Exploration (Alaska), Inc. Field: Milne Point Well Name: MPL-33i Permanent datum GROUND LEVEL Depth measured from Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination 28.02 DEG Grid Convergence 0.00 DEG Total Correction 28.02 DEG 10-JUL-97 11:41:42 50.72 FT 50.72 FT 16.40 FT Page 001 TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ye for W) 112.00 FT 112.00 FT 0.00 FT 0.00 FT MEASURED INTERVAL VERTICAL DEPTH DEPTH FT FT FT 112.0 0.00 112.00 204.4 92.40 204.40 296.3 91.90 296.30 386.1 89.80 386.10 476.3 90.20 476.29 Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 305.13 DEG Minimum Curvature Method TARGET SECTION FT 0.00 -0.09 -0.30 -0.49 0.21 STATION INCLN. DEG DEG FT FT 0.00 0.0 0.00 0.00 0.22 66.9 0.07 0.16 0.15 111.1 0.10 0.44 0.10 97.4 0.04 0.63 1.01 320.5 0.65 0.20 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH N/-S E/-W CEMENT FT DEG 0.00 0.00 0.18 66.90 0.45 77.69 0.63 86.06 0.68 16.99 565.9 89.60 565.86 654.8 88.90 654.63 745.0 90.20 744.57 834.5 89.50 833.75 929.7 95.20 928.35 2 7 14 21 32 .57 2.05 310.6 2.30 -1.52 2.76 326.50 .23 3.99 299.8 4.87 -5.41 7.28 311.98 .03 4.70 298.5 8.19 -11.38 14.03 305.74 .59 5.06 299.0 11.86 -18.06 21.60 303.29 .18 7.74 305.8 17.64 -26.93 32.20 303.23 1024.0 94.30 1021.57 1119.1 95.10 1114.94 1213.0 93.90 1206.49 1307.0 94.00 1297.61 1401.6 94.60 1388.51 46 64 84 107 133 .36 9.61 311.0 26.52 -38.02 46.36 304.90 .22 12.24 314.0 38.74 -51.27 64.26 307.07 .75 13.42 316.1 53.50 -65.99 84.95 309.04 .66 15.06 308.3 68.93 -83.14 108.00 309.66 .77 17.13 298.3 83.16 -105.05 133.98 308.36 1498.2 96.60 1480.88 1591.1 92.90 1569.57 1686.2 95.10 1659.72 1780.2 94.00 1747.64 1872.3 92.10 1832.63 161 189 219 252 287 .86 .29 .35 .42 .82 16.92 298.5 96.61 -129.93 17.69 297.8 109.65 -154.30 19.43 299.0 124.05 -180.92 21.99 299.7 140.36 -209.88 23.35 302.3 158.65 -240.29 161.91 306.63 189.29 305.40 219.36 304.44 252.49 303.77 287.94 303.44 1968.5 96.20 1920.69 2059.0 90.50 2003.17 2155.8 96.80 2091.34 2249.8 94.00 2175.86 2345.2 95.40 2259.15 326 363 403 444 491 .52 .77 .69 .75 .21 24.12 305.3 180.20 -272.45 24.51 306.7 202.10 -302.59 24.23 307.2 226.11 -334.51 27.64 308.3 251.30 -367.00 30.71 306.6 279.54 -403.93 326.65 303.48 363.88 303.74 403.76 304.06 444.79 304.40 491.23 304.69 2438.5 93.30 2338.15 2532.4 93.90 2415.16 2627.2 94.80 2490.31 2722.9 95.70 2563.21 2816.8 93.90 2631.73 2910.6 93.80 2697.24 540.83 594.54 652.30 714.29 778.48 845.58 33.57 305.9 308.88 -443.96 36.22 304.5 339.82 -487.86 38.87 304.5 372.54 -535.47 41.89 304.1 407.47 -586.68 44.38 304.3 443.55 -639.78 540.84 304.83 594.55 304.86 652.31 304.83 714.30 304.78 778.49 304.73 47.01 303.4 480.93 -695.52 845.61 304.66 DLS D/HF 0.00 0.24 0.17 0.06 1.20 1.19 2.26 0.79 0.41 2.92 2.15 2.83 1.35 2.68 3.65 0.23 0.86 1.87 2.74 1.83 1.49 0.77 0.36 3.66 3.33 3.09 2.95 2.80 3.17 2.66 2.89 ORIGINAL Schlumberger ANADRILL Survey Report 10-JUL-97 11:41:42 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 3005.6 95.00 2760.60 916.31 49.31 303.3 519.84 -754.64 916.36 304.56 2.42 3097.2 91.60 2818.85 986.96 51.72 302.8 558.38 -813.90 987.03 304.45 2.66 3190.9 93.70 2875.50 1061.52 53.87 302.9 598.87 -876.59 1061.63 304.34 2.30 3285.9 95.00 2930.21 1139.10 55.80 302.2 640.64 -942.05 1139.25 304.22 2.12 3378.3 92.40 2981.99 1215.56 56.03 303.1 681.93 -1006.48 1215.75 304.12 0.84 3472.9 94.60 3034.87 1293.97 56.01 303.7 725.11 -1071.97 1294.18 304.08 0.53 3568.1 95.20 3088.11 1372.86 55.98 303.9 769.01 -1137.55 1373.10 304.06 0.18 3662.4 94.30 3140.73 1451.11 56.19 305.5 813.56 -1201.89 1451.35 304.09 1.43 3756.9 94.50 3193.41 1529.57 56.05 305.3 859.01 -1265.84 1529.79 304.16 0.23 3850.6 93.70 3245.57 1607.41 56.30 305.7 904.21 -1329.21 1607.61 304.23 0.44 3945.1 94.50 3297.30 1686.48 57.31 305.3 950.13 -1393.59 1686.67 304.29 1.13 4036.9 91.80 3346.36 1764.07 58.08 305,4 995.02 -1456.87 1764.24 304.33 0.84 4130.7 93.80 3395.71 1843.84 58.44 304.9 1040.95 -1522.10 1844.01 304.37 0.59 4222.3 91.60 3443.30 1922.11 58.95 305.1 1085.84 -1586.21 1922.27 304.39 0.59 4318.1 95.80 3492.19 2004.49 59.68 306.0 1133.74 -1653.24 2004.63 304.44 1.11 4413.3 95.20 3540.69 2086.40 59.07 305.7 1181.72 -1719.64 2086.53 304.50 0.70 4506.6 93.30 3588.97 2166.22 58.60 306.6 1228.81 -1784.10 2166.33 304.56 0.97 4600.8 94.20 3638.02 2246.63 58.65 306.3 1276.59 -1848.79 2246.72 304.63 0.28 4693.4 92.60 3686.09 2325.75 58.80 306.6 1323,62 -1912.46 2325.82 304.69 0.32 4787.9 94.50 3735.18 2406.47 58.61 306.7 1371.82 -1977.24 2406.53 304.75 0.22 4882.3 94.40 3784.87 2486.69 57.86 307.2 1420.06 -2041.38 2486.73 304.82 0.91 4975.5 93.20 3834.63 2565.46 57.61 306.8 1467.49 -2104.32 2565.48 304.89 0.45 5069.2 93.70 3884.95 2644.46 57.42 307.0 1514.95 -2167.53 2644.47 304.95 0.27 5163.1 93.90 3935.38 2723.58 57.62 308.6 1563.49 -2230.11 2723.59 305.03 1,45 5257.8 94.70 3986.14 2803.39 57.55 308.3 1613.21 -2292.72 2803.39 305.13 0.28 5354.3 96.50 4038.47 2884.35 56.77 308.3 1663.46 -2356.35 2884.35 305.22 0.81 5444.0 89.70 4087.66 2959.30 56.73 306.4 1708.96 -2415.98 2959.31 305.27 1.77 5541.0 97.00 4141.36 3040.07 56.04 304.0 1755.53 -2481.97 3040.08 305.27 2.18 5634.8 93.80 4193.60 3117.97 56.28 304.9 1799.60 -2546.22 3117.98 305.25 0.84 5728.3 93.50 4245.59 3195.68 56.15 304.3 1843.73 -2610.18 3195.68 305.24 0.55 5837.3 109.00 4306.48 3286.08 55.93 304.3 1894.67 -2684.87 3286.08 305.21 0.20 5994.4 157.10 4394.65 3416.10 55.79 305.3 1968.88 -2791.64 3416.10 305.19 0.53 6086.4 92.00 4446.42 3492.13 55.72 303.1 2011.62 -2854.53 3492.13 305.17 1.98 6181.3 94.90 4499.90 3570.45 55.68 302.1 2053.86 -2920.58 3570.45 305.12 0.87 6275.4 94.10 4552.79 3648.25 55.95 305.8 2097.32 -2985.13 3648.25 305.09 3.27 6368.1 92.70 4604.87 3724.93 55.68 305.6 2142.07 -3047.40 3724.93 305.10 0.34 6461.7 93.60 4657.72 3802.15 55.58 302.1 2185.10 -3111.55 3802.15 305.08 3.09 6557.2 95.50 4712.18 3880.47 54.89 301.5 2226.44 -3178.22 3880.48 305.01 0.89 6652.5 95.30 4767.78 3957.75 53.73 302.5 2267.45 -3243.86 3957.77 304.95 1.49 6746.5 94.00 4823.33 4033.55 53.82 304.6 2309.35 -3307.05 4033.57 304.93 1.80 6839.7 93,20 4877.70 4109.24 54.80 305.3 2352.72 -3369.09 4109.27 304.93 1.22 6933.7 94.00 4931.95 4186.01 54.71 304.5 2396.64 -3432.06 4186.04 304.93 0.70 7025.5 91.80 4985.10 4260.85 54.53 304.7 2439.14 -3493.66 4260.88 304.92 0.26 7117.1 91.60 5038.23 4335.44 54.58 302.4 2480.38 -3555.85 4335.48 304.90 2.05 7213.2 96.10 5093.32 4414.10 55.46 302.8 2522.80 -3622.18 4414.15 304.86 0.98 Schlumberger ANADRILL Survey Report 10-JUL-97 11:41:42 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIPrUTH LATITUDE DEPARTURE DISPLA- at AZI~fUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7304.8 91.60 5144.82 4489.83 56.13 306.4 2565.82 -3684.52 4489.89 304.85 3,33 7399.1 94.30 5197.72 4567.90 55.64 303.8 2610.71 -3748.38 4567.95 304.86 2.34 7492.1 93.00 5250.50 4644.44 55.20 303.7 2653.25 -3812.05 4644.50 304.84 0.48 7583.7 91.60 5302.81 4719.63 55.16 304.9 2695.62 -3874.17 4719.70 304.83 1.08 7677.1 93.40 5355.17 4796.96 56.65 307.1 2741.09 -3936.72 4797.02 304.85 2.52 7771.1 94.00 5407.07 4875.31 56.32 304.9 2787.15 -4000.12 4875.37 304.87 1.98 7864.2 93.10 5458.63 4952.83 56.42 304.7 2831.39 -4063.77 4952.88 304.87 0.21 7956.3 92.10 5509.87 5029.36 55.98 306.1 2875.72 -4126.16 5029.41 304.87 1.35 8050.8 94.50 5562.75 5107.67 55,97 305.7 2921.65 -4189.60 5107.72 304.89 0.35 8146.4 95.60 5616.38 5186.81 55.79 304.0 2966.87 -4254.55 5186.86 304.89 1.48 8238.0 91.60 5667.88 5262.55 55.79 304.6 3009.56 -4317.12 5262.60 304.88 0.54 8332.2 94.20 5720.91 5340.40 55.69 303.9 3053.38 -4381.48 5340.46 304.87 0.62 8425.9 93.70 5773.76 5417.76 55.64 304.7 3096.98 -4445.39 5417.82 304.86 0.71 8521.5 95.60 5827.55 5496.79 55.88 306.0 3142.70 -4509.85 5496.85 304.87 1.15 8615.4 93.90 5880.24 5574.51 55.85 306.0 3188.39 -4572.73 5574.56 304.89 0.03 8709.8 94.40 5933.33 5652.56 55.71 304.9 3233.66 -4636.32 5652.61 304.89 0.97 8805.5 95.70 5987.31 5731.58 55.61 305.4 3279.15 -4700.93 5731.63 304.90 0.44 8901.5 96.00 6041.60 5810.76 55.52 305.7 3325.19 -4765.35 5810.80 304.91 0.27 8994.5 93.00 6094.08 5887.53 55.78 305.7 3369.99 -4827.70 5887.57 304.92 0.28 9088.6 94.10 6146.97 5965.36 55.82 305.5 3415.30 -4890.98 5965.40 304.93 0.18 9180.1 91.50 6198.37 6041.05 55.82 304.8 3458.88 -4952.87 6041.09 304.93 0.63 9275.5 95.40 6252.05 6119.89 55.70 302.8 3502.75 -5018.40 6119.94 304.91 1.74 9370.1 94.60 6305.04 6198.20 56.17 303.1 3545.37 -5084.16 6198.26 304.89 0.56 9464.1 94.00 6357.27 6276.34 56.33 305.3 3589.30 -5148.80 6276.40 304.88 1.95 9558.2 94.10 6409.65 6354.51 56.02 303.9 3633.69 -5213.14 6354.57 304.88 1.28 9653.6 95.40 6462.79 6433.74 56.29 305.8 3678.96 -5278.16 6433.80 304.88 1.68 9749.4 95.80 6516.06 6513.34 56.14 306.6 3725.99 -5342.41 6513.40 304.89 0.71 9844.0 94.60 6569.06 6591.69 55.72 303.9 3771.21 -5406.39 6591.75 304.90 2.41 9937.5 93.50 6621.73 6668.94 55.72 304.5 3814.64 -5470.29 6669.00 304.89 0.53 10031.6 94.10 6674.28 6747.00 56.38 305.4 3859.36 -5534.27 6747.06 304.89 1.06 10123.9 92.30 6724.88 6824.18 57.14 307.0 3904.95 -5596.56 6824.23 304.91 1.67 10217.5 93.60 6775.63 6902.77 57.19 307.4 3952.50 -5659.20 6902,81 304.93 0.36 10311.2 93.70 6826.12 6981.64 57.59 307.3 4000.38 -5721.95 6981.67 304.96 0.44 10404.7 93.50 6876.04 7060.66 57.88 306.9 4048.07 -5785.01 7060.68 304.98 0.48 10499.4 94.70 6926.45 7140.79 57.80 306.9 4096.21 -5849.12 7140.81 305.00 0.08 10594.4 95.00 6974.86 7222.50 60.92 305.8 4144.64 -5914.95 7222.51 305.02 3.43 10688.8 94.40 7019.51 7305.66 62.61 305.6 4193.17 -5982.48 7305.67 305.03 1.80 10783.3 94.50 7061.43 7390.35 64.73 304.9 4242.04 -6051.65 7390.36 305.03 2.34 10877.9 94.60 7099.56 7476.91 67.72 305.0 4291.63 -6122.60 7476.92 305.03 3.16 10970.7 92.80 7132.44 7563.68 70.78 305.7 4341.84 -6193.37 7563.69 305.03 3.37 11064.7 94.00 7161.38 7653.10 73.35 305.9 4394.15 -6265.90 7653.10 305.04 2.74 11159.0 94.30 7186.10 7744.07 76.25 306.3 4447.76 -6339.42 7744.08 305.05 3.10 11253.3 94.30 7206.15 7836.13 79.20 308.5 4503.73 -6412.60 7836.13 305.08 3.87 11349.0 95.70 7223.87 7930.02 79.46 308.4 4562.21 -6486.25 7930.02 305.12 0.29 11441.5 92.50 7239.87 8020.96 80.62 308.6 4618.92 -6557.55 8020.96 305.16 1.27 Schlumberger ANADRILL Survey Report 10-JUL-97 11:41:42 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 11535.8 94.30 7254.34 8113.92 81.72 11630.2 94.40 7266.62 8207.26 83.33 11723.3 93.10 7274.82 8299.70 86.57 11818.4 95.10 7280.27 8394.32 86.86 11913.4 95.00 7285.21 8488.85 87.17 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 309.5 4677.63 -6629.91 8113.93 305.20 1.50 309.3 4737.03 -6702.23 8207.28 305.25 1.72 310.0 4796.20 -6773.63 8299.73 305.30 3.56 309.7 4857.04 -6846.52 8394.38 305.35 0.44 310.3 4918.02 -6919.19 8488.94 305.40 0.71 12005.8 92.40 7289.43 8580.78 87.60 12100.3 94.50 7293.17 8674.82 87.86 12193.5 93.20 7295.78 8767.60 88.94 12288.3 94.80 7296.06 8861.99 90.71 12382.5 94.20 7292.38 8955.73 93.77 310.2 4977.66 -6989.64 8580.92 305.46 0.48 310.4 5038.73 -7061.66 8675.01 305.51 0.35 310.3 5099.05 -7132.66 8767.85 305.56 1.16 310.6 5160.55 -7204.79 8862.30 305.61 1.89 309.8 5221.30 -7276.68 8956.12 305.66 3.36 12476.7 94.20 7282.90 9049.09 97.79 12570.5 93.80 7267.47 9141.26 101.15 12665.2 94.70 7246.43 9233.24 104.52 12759.7 94.50 7222.21 9324.20 105.19 12852.7 93.00 7197.07 9413.39 106.17 310.3 5281.59 -7348.41 9049.55 305.71 4.30 309.7 5341.06 -7419.27 9141.80 305.75 3.64 310.5 5400.52 -7489.89 9233.86 305.79 3.65 310.2 5459.66 -7559.50 9324.91 305.84 0.77 310.1 5517.39 -7627.94 9414.20 305.88 1.06 12947.0 94.30 7170.20 9503.44 106.94 13040.3 93.30 7142.43 9592.12 107.69 13137.2 96.90 7112.34 9683.90 108.49 13230.4 93.20 7082.59 9771.99 108.74 13315.8 85.40 7054.98 9852.49 108.98 310.1 5575.62 -7697.08 9504.34 305.92 0.82 311.0 5633.52 -7764.76 9593.13 305.96 1.22 308.8 5692.60 -7835.42 9685.01 306.00 2.31 309.8 5748.54 -7903.77 9773.19 306.03 1.05 310.6 5800.71 -7965.49 9853.79 306.06 0.93 Survey Projected to TD: 13405.0 89.20 7025.97 9936.45 108.98 310.6 5855.60 -8029.54 9937.88 306.10 0.00 Schlumberger - GeoQuest A Division of SchlumBerger Technologies Corpora[ion 500 W. International Airoort Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 9, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. 99519-6612 Anchorage, Alaska ~j ~-"~"~ The following data of the Depth Corrected CDR/ADN, CDR/ADN TVD'S for well MPL-33, Job # 97410 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 I OH LIS Tape 3 Bluelines each I Film each I Depth Shift Display State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 I OH. LIS Tape I Blueline each I RF Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail: P 067 695 407 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 Date Delivered' Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11525 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 11/5/97 Well Job # Log Description Date BL RF Sepia LIS Tape ,,, MPC-6 {.r~l ~ WATER FLOW LOG/TDTP-GR/CCL 97061 5 I 1 MPU C-8 .LX.~ ~ TDT WATER FLOW LOG 970927 1 1 MPU C-10 . [iLC-~ WATER FLOW LOG W/RST INVERTED 970911 1 1 MPE-10 , TUBING PUNCHER 970928 I 1 MPU E-22, TUBING LEAK DETECTION LOG 970702 I 1 MPU E-22 ~ TUBING PATCH RECORD 97071 9 1 1 MPU F-09 ~ PERFORATING RECORD 970712 I 1 MPU F-09 ~. STATIC TEMP/PRESS SURVEY 970712 I 1 MPU F-09 ' PERFORATING RECORD 970719 I I ,, F-41, CHEMICAL CUTTER 970820 I 1 F-41 · CHEMICAL CUTTER 970829 1 1 MPU F-73 ' PERFORATION RECORD 970815 I 1 MPG-09 ~ RFT 970702 I 1 MPH-11 ~ !RFT 970903 I 1 UPU J-2 ~[(..~ WATER FLOW LOG/TDT-GR .. 970726 I 1 MPu J-09 ~L(..-.- JETCUTrER RECORD 970807 I 1 MPK-43A · GAMMA RAY CORRELATION LOG 971 024 1 1 .,, MPU L-9 L~[ ~ ;WATER FLOW LOG/'rDTP-GR/CCL 970614 I 1 MPU L-32 ~ GAMMA RAY CCL TCP CORRELATION LOG" 970515 1 1 MPL-33 ~ TUBING CONVEYED PERF TIE-IN GR-CCL 971010 I 1 MPL-33 , TIE-IN GR-CCL 971 014 I 1 ,, lot ctq. c~5' 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: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~ ,~~ TONY KNOWLE$, GOVEF~NOFt ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 6, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPL-33i BP Exploration (Alaska) Inc Permit No 97-105 Sur. Loc.: 3764'NSL. 5118'WEL, Sec. 8, T13N, R10E. UM Btmhole Loc: 4028'NSL, 2278'WEL, Sec. 1, T13N, R9E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The pemfit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission max' witness the tests. Notice may be given bv contac~ nspector on the North Slope pager at 659-3607. David W~,Johnston ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/enclosures cC: Department of Fish & Game. t labitat Section wio encl. Department of Envinonuncnt Conservation w;o encl. STATE OF ALASKA ALASKA C~ AND GAS CONSERVATION COM'r~-,~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] 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 KBE = 50' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 388235 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3764' NSL, 5118' WEL, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3892' NSL, 2114' WEL, SEC. 1, T13N, R9E, UM MPL-33i At total depth 9. Approximate spud date Amount $200,000.00 4028' NSL, 2278' WEL, SEC. 1, T131'4, R9E, UM 06/08/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355018, 1252'I No Close Approach 1920 12854' MD / 7132' 'I-VD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 500' Maximum Hole Angle 56.04° Maximum surface 2880 psig, Attotal depth (TVD) 7215'/3602 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling 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.) 12-1/4" ~-5/8" 40# L-80 Btrc 5982' 31' 31' 6013' 4413' 1475 sx PF 'E', 495 sx Class 'G' 8-1/2" 7" 26# L-80 Btrc 12824' 30' 30' 12854' 7132' 492 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) Aicsk8 0il & (~3 C0r~s. C0mmissis~ true vertical feet AnCi','0Fa~8 Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 0RIG NAL Perforation depth: measured 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: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoarnor, 564-5122 21. I hereby certify that the foregoing is tru~ and cqrrpct to the best of my knowledge Signed ~ ~-~ ~¢_ /q~/~~' Tim Schofield ~ Title Senior Drilling Engineer Date Commission Use Only / Permit Number I APl Number Approval Date I See cover letter ~ ~-//~.~, 50- 4:~ _~.~ ----. ~ ~-* ~ '~ 4'7Z (O-- ('~ ~c~ qI for other requirements Conditions of Approval: Samples Required []Yes ~No Mud Log Required []Yes []No Hydrogen Sulfide Measures []Yes~No Directional Survey Required j~Yes I-'lNo Required Working Pressure for BOPE []2M; 1--13M; ~ii~5M; []10M; I--I15M Other: Original Signed By by order of Approved By ~VJd W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: Lance Spencer 564-5042 Name: I MPL-33i I Well Plan Summary I Type of Well (producer or injector): I Kuparuk Injector Surface Location: 3764' NSL, 5118' WEL, Sec. 08, T13N ,R10E, UM., AK Enter A3 #1 2813' NSL, 800' WEL, Sec. 01, T13N, R09E, UM., AK Exit A1 #2 2950' NSL, 964' WEL, Sec. 01, T13N, R09E, UM., AK Enter A1 #3 3892' NSL, 2114' WEL, Sec. 01, T13N, R09E, UM., AK Exit A3 #4 4028' NSL, 2278' WEL, Sec. 01, T13N, R09E, UM., AK Bottom Hole Location: I AFE Number: 1337087 I I Ri~l: I Nabors 27-E I I Estimated Start Date: I 8 June 97 I I Operating days to complete: IuD= 112,e54' II TVD= 17,132'BEb I I KBE= 119 15o.oo I Well Design: Ultra Slim Hole Long String I 9-5/8", 40# Surface X 7", 26# Longstring Horizontal I --, r-', i ,'"~ I NA Formation ~arker~: Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1,833 1,800 8.4 ppg 786 psi NA 5,201 3,960 8.4 ppg 1730 psi OA 5,613 4,190 8.4 ppg 1830 psi Base Schrader 5,736 4,270 8.4 ppg 1865psi Top HRZ 9,954 6,615 8.8 ppg 3027 psi Base HRZ 10,098 6,695 8.8 ppg 3064 psi TKLB(MK-19) 10,277 6,795 9.2 ppg 3251 psi TKUD 10,527 6,935 9.2 ppg 3318 psi TKUC 10,799 7,070 9.6 ppg 3529 psi.. , TKUB 10,822 7,080 9.6 ppg 3534 psi~'~'~''~': TKA3FFARG ET1 10,907 7,115 9.6 ppg 3552 psi TKA2 10,946 7,130 9.6 ppg 3559 psi TKA1 11,018 7,155 9.6 ppg 3572 psi TARGET2 11,134 7,190 9.6 ppg 3589psi TMLV 11,235 7,215 9.6 ppg 3602 psi TARGET 3 12,630 7,200 9.6 ppg 3594psi TARGET4/Total 12,854_+ 7,132_+ 9.6 ppg 3560 psi Depth · *These are estimated maximum pressures and the actual pressures may be lower. Casinq/Tubing ProS ram: y ",r Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 5982 31/31 6013/4413 8-1/2" 7" 26# L-80 btrc 12824 30/30 12854/7132 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _ 7,215 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,215 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,602 psi is 2,880 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP L-33i (Bi) Drilling Permit 1 5/30/97 Cementing Program: Halliburton Cementing Services Hole Casing Interval Volume~ Spacer Type of Cement Properties2 Category Size/Depth Surface Lead~ Lead Lead Lead. First 9-5/8" @ 2033-4701' 501 sx 70 bbls Fresh Permafrost "E" Den 12.0 ppg Stage 6,013' 194 bbls water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 4701-6103' Tails Tail Tai__l 495 sx Premium Class "G" w/ Den 15.8 ppg 103 bbls 0.2 % CaCl, 0.15 #/sk Celoflakes Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs ............................................................................................ Second Sta~e ~'~'~J~' .............. ['~i' .................... ~'~i ...................................... i'~i'~ ....................................................... Stage colla¢ @ 0-1833 974 sx 75 bbls Fresh Permafrost "E" Same as above 2,033' 1833-2033 376 bbls water Wellhead If Lead~ Lead Lead Stability Cmt necessary. 150 sx Permafrost "E" Same as above Production LeadTM Lead Lead Den 15.8 ppg First 7" @ 11350- 231 sx 20 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx Stage 10,498' 12854' 47 bbls Fresh water 0.2 % CFR-3 Water 5.0 gps 70 bbls NSCI 0.1% HR-5 'IT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/3..~in ~-, i{~' ii ~ @140~ ? ~., ~'~ ~_., Second Stale 9527- Lead~2 Lead Lead Lead Stage collar'" @ 11350' 261 sx Same as Same as above Same as above 11,350' 54 bbls above ~ :-'~ ~; 'ii"; 1 Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times shouldab~-~b~a~d~z~-n~j~l~ requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility~pd~o pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2033'MD_+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,033-4,701' md. The estimated first stage lead cement volume from 2,033-4,701' md and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,033' md which is 200 ft md below Base of the Permafrost at 1,833' md (1,799 TVD bkb) to 4,701' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 4,701-6013' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 4,701-6013' (500' md above the NA top) to surface TD at 6,013' md (4413; TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,033' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,033' MD (1,975' TVDbkb) to surface. From 1833; to surface include 250% open hole excess and from 1,833-2,033' use 30% open hole excess. 7. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. Install one(l) Bow Spring Centralizers per joint from 9,100-10,100 of 9-5/8" casing to cover the top of the NA to Base OB. 10. A Type H ES Cementer will be installed in the 7" csg. at 11,350'MD_+ 11. The production hole First Stage LEAD Cement Volume covers the interval from 11350-12854' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the ES Cementer located at 11350 to TD at 12854' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 26# casing. 12. The production hole Second Stage LEAD Cement Volume covers the interval from 0-2,033' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 11,350' MD to 9527' which is 1000' above the Kuparuk D Shale plus 30% open hole excess. 13. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint from 120' below to 120' above any potential hydrocarbon bearing sands. 14. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 15. Install two 7" marker joints and position three joints above the Kuparuk C sand. 16. Place all centralizers in middle of joints using stop collars. 17. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no._it necessary. MP L-33i (Bi) Drilling Permit 2 5/30/97 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ Cased Hole Logs: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-25 20-35 9-10 8-15 <9 Production Mud Properties LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-10.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 <4 Miluveac h Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. Directional: KOP1 . Tangent Hole Angle Curve 2 Curve 3 Curve 4 KOP 3 Maximum Hole Angle Close Approach Wells Survey Program 500' Start Variable @ 1.0°- 2.5 °/100 and Az 305.13°. EOB 3187' 56.04° from 3187-10,516' 10516' Start Curve @ 3.0°/100 to 67° incl. and 310 Az o EOB 11408' 10906' Start Curve @ 3.5 °/100 to 72° incl. and 310 Az o EOB 11408' 11075' Start Curve @ 3.5 °/100 to 90.43° incl. and 310 Az o EOB 11408' 12242' Start Curve @ 3.5 °/100 to 110° incl. and 310 Az o EOB 11408' 110° from 12801-12854' All wells may remain flowing while drilling ~3~ and no shut-ins are required. 1. Surface to 6,013' MWD surveys. 2. 6,013-TD' MWD with in hole reference. MP L-33i (Bi) Drilling Permit 3 5/30/97 Disposal: No "Drilling Wastes" will be injected or disposed into L-35 while drilling this well. Cuttinqs Handlinq: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handlinq: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPL-33i is planned as a 12,854' md, 9,419' departure, U-Shaped horizontal Kuparuk River A Sand injector. At total depth the U-shaped well profile has a final angle of 110°. With this U-shaped design the well bore will intersect and exit the Kuparuk A3-A1 sands twice --, i.e. one time in each fault block. The well bore will enter the A3 sand at target point 1 and then go through the A1 sand into the Miluveach at target 2. The well will then exit up from the Miluveach into the A1 at target point 3 and exit out of the A3 at target point 4. This profile will facilitate optimum injection into two separate fault blocks from a single well bore. The surface casing will be deep set below the Schrader Bluff at 6,013 feet measured depth to isolate the Ugnu and Schrader Bluff from the Kuparuk interval. The Kuparuk will be partially pressure depleted with an estimated pore pressure of 9.6 ppg EMW due to nearby production from F-13, F-25 and L-13. Low pressures from depletion and high pressure from injection should not cause drilling problems. Geoloc~v L-33i (ExpBi) will penetrate three major fault blocks. The primary targets are the Kupauuk A3, A2 and A1 sands but has some potential in the Kuparuk B and C sands. The Kuparuk targets were selected to provide injection support into the Tract 22 accumulation. L-33i is located in a fault blocks filled to the Base of the A sands. The deepest known oil in the area is at L-24 to a depth of 7360 tvd ss. No water contact is expected at he L-33i location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 50-!-_ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this injector are estimated at 5.0 MMBO. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted and not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP L-33i, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Iniection Formation pressures are expected to be partially depleted at a maximum of 9.6 ppg EMW pore pressure in the Kuparuk while drilling L-33i. L-15i is the only other injector expected to be in communication with the proposed L- 33i but it has not abnormally pressured the reservoir. Annular Iniection Currently annular injection is not permitted on L-Pad. ORIGINAL Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Since the L-33i well bore will pass through three faults the potential for lost circulation is higher. Contingencies have been incorporated to well program remedy loses if encountered. MP L-33i (Bi) Drilling Permit 4 5/30/97 Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on L-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. With the possibility that the HRZ will be truncated or absent the potential for stuck pipe the transition interval from Colville(SeeBee) to Kulubik is recognized. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been exPerienced after drilling into Kuparuk. This is a common occurrence has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK C SAND 7070' TVDss 3529 PSI 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _+ 7,215 TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,215' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,602 psi is 2,880 psi. The maximum expected pore pressure for this well is 10.5 ppg EMW (3,602 psi @ 2,880' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on L pad and review recent wells drilled on L Pad. MP L-33i (Bi) Drilling Permit 5 5/30/97 MP L-33i Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5 Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2033' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk A sand and PBTD before running the 7" casing. 11. Run 7" casing. Space out ES Type H Cementer and ECP (external casing packer) to 11,350' md. 12. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 13. Displace cement with 8.4 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). 14. Test casing to 4000 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP L-33i (Bi) Drilling Permit 6 5/30/97 MP L-33i (Bi) Drilling Permit 7 5/30/97 Anadrill Schlumberger Alaska District A~tchoTs~e, AK 995£8 (907) 349-45[% ~a~ ]44-2[60 DIRECTIONAL WHL~ PLAN £or S~RED SHR¥ICSS DRZLb£NG Well ......... : ~L-33 (P03) Pteld ........ : MLLne Point, L-Pad Co~utation,.: Minimum Curvature Units ........ : PBBT Surface Lat..: ~0.49816668 N Surface bong.: 149.63397/6~ W Legal Description Surface', ..... : 3764 FSL 5118 FEi SOB T£3N R108 ~ Tgt Pt #L .... : 2813 PSL 800 FEn S01 TL3N RO~H UM Tgt Pt ~2 .... : 2950 PSb 964 ~EL S0~ T13N R098 UM Tc3t ~t ~3 .... : 3892 PSi 21L4 FBi S01 T~3N RD~~ UM Tgt Pt ~4 .... : 4028 PSL 22?8 PHL 601 T13N RD9EUM B/{~ .......... : 4020 FSi 22]8 PHi $01 T13N R09E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 544758,38 603[953.03 538600.~0 6'036248.00 538435.a0 6036384,00 537280.00 6037320.00 537L15.00 6037455.00 ~]7115.00 6037455.00 PROPOSHD WELL PROFIL~ Prepared ..... : 29 May ~997 ~ert sect az.: 306.09 K~ elevation.: 49.40 ft Magnetic E~ln: +28.02~ (~) Scale Factor.: 0,99990228 Convergence..: +0.34503016 ANADRILL ....... AKA-DPC APPROVED FOR PERMITTING ONLY STATION MF~ASURED ~NCLN D~RBCTION ~DHNT~FICATIO~ DHPTH ANGLE AZ~MU77~ KB O.O0 O.O0 0.00 KOP / BUILD 1/100 500.00 0.00 305.00 600,00 1.00 305.00 BUILD 1,5/100 7~0,00 2.00 305.00 800.00 3.50 305.08 ~ SUb-SBA 0.00 -49.40 500.O0 450.60 599.99 550.59 699.96 650.56 799.84 750.44 SECTX0N DHPART 0.00 -~.00 0.87 3,49 8-29 CDORDINATE$-FROM ~SL~ x Y PACH O.OO N 0.0O 8 544758.30 603£953.03 55L 0.00 ~ 0.00 H 544758.30 603L953,03 55~ 0.50 ~ 0.71 W 544757.58 6031963.53 55L 2.00 ~ 2.86 N 544755.43 6031955.01 55L 4.75 ~ 6.7~ ~ 54475~.48 603~957.74 ~mm ALA~K~Zone 4 ~O0~ Dh/ 100 0.00 0.00 I .00 I .00 1 .~0 Curve 2/lOO 900.00 5.00 305.00 1000.00 7.00 305.04 1100.00 9.00 305.06 1200.00 11,00 305.08 L300.O0 13,00 305.09 899.56 B50.16 999.01 949.61 1098,03 1048.63 1196.5l 1294.3~ 1244.92 tS.90 26,15 40.06 57.42 78.2L 9.00 15. O0 23.00 32.97 44.92 12.86 H 544745,39 603196L.96 55L 1.50 2k,42 U 544736.79 6031967.90 ElS 2,00 32.81 N 544725,35 603[975.83 H~ 2.00 47.02 W 5447[1.08 6031985.72 HS 2.00 64.04 W 544694.00 603~997.56 ~8 2.00 "0 [Anadri]l (c)97 MPL33P03 3.0C 2:59 ~ P) NJ MPL-33 (P03) 29 May 1997 Page 2 STAT[ON NHASURED INCLN IDH~T~[CATION OHgTH ANG~,R 1400.00 15.00 1500,00 17.00 1600.00 kg.00 L700.O0 21.00 1800.00 23.00 a~o 2/loo RASE PHRMA/~ROST CURVH 2.5/L00 1800.17 23.00 1832.76 23.00 1865.35 23.00 1900,00 23.87 2000.00 26.37 2100.00 28.87 2300.00 31.37 2300,00 33.87 2400,00 36.37 2500.00 38.87 2600-00 41.37 2700.00 43.87 2800.00 46.37 2900.00 48.07 3000.00 51.37 3100.00 53.87 HN'D 2.5/300 CrJRVE 3186.96 56.04 NA 5200.40 56.04 O~ 5612.17 56.04 ~ASH ~CHRADHR 5?55.40 56.04 9-5/8" CASING PO[~ 6012.£7 56.04 TOP HRZ 9953.68 56.04 BASE HRZ 10096.91 56-04 (Anadrill (c}97 MPL33P03 3,0C 2:59 PM P} PROPOSED W~hh PROF£LH DIRHCTXQN VHRTICAL-DBPT}L9 AZ~MCYrH TVD SUB-$HA 305.09 139L.34 ~341.94 305.10 1487.46 1438.06 305,10 1582.56 1533.16 305.£1 ~676.53 ~627.13 305.il ~769.24 ~719,84 305-11 1769.40 1920.00 305.1L L799.40 t?50.00 305,L1 Lfl29.40 1780.00 305.13 L861.L9 1811,79 305.11 195~.~2 1902.32 305,12 2040.32 1990.92 305,12 2126.81 2077.tL 305.12 2211.03 2161.63 305.I2 2292.82 2243.42 305.12 2372.02 2322.62 305,12 2448-49 2399.09 305.L2 2522.07 2472,67 305.12 2592.62 2543.22 305.32 2660.02 2610.62 305.13 2724_14 2674.74 SHCT[ON OOORDINA~HS-PROM A]_.~KA Zone 4 T00~ DHPART ~HLLHFdM3 X Y PACE L00 102.40 58.83 N 83.83 W 544674.13 6012011,35 RS 2.00 129.95 74,68 H 306,38 ~ 544651.48 603102~.06 H~ 2.00 L60,85 92,44 ~ 131.66 ~ 544626.10 603~044.67 ~S 2.00 195,04 112.11 N L59.64 W 544598.00 6032064,17 HS 2.00 232.50 ~33.66 N 190.28 W 544567.23 6032085.53 H$ 2-00 232.56 133.70 N 190.34 M 544567,18 6032085.56 HS 2,00 245.30 141.02 N 200.76 N 544556.72 6032092.83 HS 0.00 258.03 148.35 N 211.18 ~ 544546.26 6032100.09 HS 0.00 37L.83 L56.27 N 222.45 ~ 5%4534.94 6032L07.94 RS 2.50 3L4.25 180,69 N 257,17 ~ 5~4500.0~ 6032L32,15 HS 2,50 360.60 207,35 N 295.09 W 544462.00 6032158.58 HS 2.50 410.77 236.23 N 336.13 ~ 544420.78 6032167.20 R~ 2.50 464.66 267.22 N 380.12 ~ 544376.5l 6032217.93 HS 2.50 522.18 300,32 N 427.27 N 544329.2? 6032250.74 IlS 2.50 583.21 336-43 N 477.20 W 544279.14 6032285.55 HS 2.50 647.63 372.50 N 529.90 ~ 544226.22 6032322.30 HS 2,50 715.33 413.46 N 585.28 ~ 544170.61 6032360.91 HS 2.50 786.17 452,22 N 643.23 N 544112.42 6032401.3~ HS 2.50 860.02 494.~2 N 703.64 W 5440~1.76 60324t3-45 H$ 2.50 936,75 ~38.87 N 766.40 ~ 543988.74 6032487.22 ~S 2,~0 305.13 2784,84 2735.44 1016.L9 305_L3 2834,78 2785.38 1087.38 305.~3 3959.40 3910.00 2757.21 305.13 4189.40 4140.00 3098,7l 305.13 4269.40 4220.00 3217,49 305.13 4412.82 4363.42 3430.45 305.L3 6614.40 6565.00 6699.33 305-L3 6694.40 6645.00 6818.1l 584,58 N 831.39 W 543923.49 6032532,54 HS 2.50 625.55 N 889.62 W 543865.02 6032573.15 RS 2.50 3586.49 N 2255.53 N 542493.48 6033525.~5 HS 0.00 1783.01 N 2534,88 ~ 5422L2.98 6033V20.57 HS G,00 185L.37 N 2632.04 W 542L15.4t 6033788-34 HS 0.00 1973,92 g 2806.24 W 54~940,50 6033909.82 RS 0.00 3855.06 N 5480.L7 W 539255.55 6035774.65 KS 0.00 3923.42 N 5577.34 H 539L57.99 6035842.41 HS 0.00 u rq MP~-33 (P03) 29 Nay £997 Page 3 STAT I ON MHABURED IRCLN ID~[TI~IFICATION DHPTH ANGLE ~-19 ~027S.94 ~6.04 C-'U~VH 3/aO0 305~6.00 56.04 TOP KUD 10526.63 56.34 lO60~.00 58.~9 k0?0~,O0 61.k9 TOP KUC ~0797.92 63.94 10805.00 64.00 TOP ~ 1082~.95 64.~9 10900.00 66.82 CUP~VE 3.5/£00 £0906.32 6~.O0 TARI3HT POINT #k ~*~ ~0906.32 67.00 TKA3 10906.3~ 67.00 TKA2 10945.84 68.38 11000.00 70.28 TKA1 110~7.70 70.90 HND 3.S/100 CURVE CURVE 3.5/t00 TARGHT DOI. NT #2 ~*** TNr.V £1048.25 71.97 11075.00 ~1.97 11100-00 72.84 11133.07 74.00 11200.00 76.34 L/2~4,86 77.56 11300,00 79-84 LI400.O0 83.34 11500.00 86.84 11600.00 90.33 HL'TD 3.5/L00 11602,84 90.43 CURVH 3.5/100 12242,14 90.43 12300.00 92,46 (Anadrill (c) 97 MPL33P03 3.0C 2:59 PM P) PROPOSHD WHGb PROFILE D£1~CTION VHRTICAL-DHPTHS AZIMUTH TVD SUB-SEA 305.13 6794.40 6745.00 305.13 6928.49 6879.09 305.~7 69~4-40 6885.~0 306.23 6975~97 6924.57 307.47 7024.29 6974.89 308,63 7069,40 7020.00 308.65 7070.33 7020.91 308.89 7079.40 7030.00 309.77 7Lll.92 7062 52 309.84 7114,40 3065.00 309.84 7114.40 7065.00 309.64 7114.40 7065.00 309.84 7[29.40 7080 .O0 309.84 7[48.52 7099. ~2 309.84 7154 .40 7105.00 309.84 7164.~3 7L14.73 309.84 7172.41 7L23.01 309.84 7179.96 7230,$6 309.84 7189.40 7340.00 309.76 7206.53 ~157.£3 309,72 7214.40 7L65.00 309.64 7227.16 7£77.76 309.52 724k-79 7292.39 309.40 7250.35 7200.95 309-28 7252.82 7203.42 309.28 7252.8[ 7203.41 309.28 7247.98 7198.58 309.28 ~246.52 7197,12 SHCT1ON COORD£NA?SS-PROM ALASKA Zone 4 TOOL Dh/ DEPART WELLHEAD X ¥ FACE ~00 6966.59 4008.87 N 5698.79 W 539036.03 6035927.11 HS 0.O0 7~65.68 4123.44 N 5861.65 W 538872.51 6056040,69 22R 0.00 7174.51 4128,53 N ~868.86 W 538865.26 6036045.74 22R 3.00 7236.29 4164.63 N 5919.00 7322.69 4216.46 N 5988.13 W 538745.4~ 6036132.94 2~R 3,00 7409.53 4270.05 N 6056.56 W 538676.73 6036186.09 20R 3.00 7411.40 427l.[9 N 6050.02 W 538675.27 6036187.~5 20R 3.00 7430.26 4283.01 N 6072.74 N 538660,48 6036198.98 20R 3.00 7502-19 4328.68 N 6128.46 W 538604.49 6036244.30 20R 3.00 7507.99 4332.40 N 6132.92 M 538600.00 60~6248,00 HS 3.00 7507.99 4332.40 N 6132.92 W 536600.00 6036248.00 H9 3.00 7507.99 4332.40 N 6132.92 ~ 538600.00 6036248.00 HS 3.00 7544.47 4355.82 N 6160.99 W 538571.79 6036271.25 HS 3.50 7595,03 4388.29 N 6199.90 W 538532.69 6036303.48 tLS 3.50 76LL.70 4398.99 ~ 6212.72 W 538519.81 6036314,10 H$ 3,50 7640,59 4417.54 N 6234-96 W 538497.47 6036332.51 HS 3.50 7665.97 4433.83 N 6254.49 ~ 538477.84 6036348.69 ~S 0.00 7689.75 4449.10 N 6272.78 W 538459.46 6036363.84 HS 3.50 7721.38 4469,4l N 6297.12 W 538435.00 6036384,00 2L 3.50 7785.94 4510,82 N 6346.82 W 538385.05 6036425.LL 2h 3.50 7829.83 4532.53 N 6372.94 H 538258,8[ 6036446.66 2h 3.50 7883,58 4573-31 N 6422.10 W 538309,41 6036487.14 2~ 3,50 7982.30 4636.32 N 6498.33 W 538232.80 6036549.68 2L 3.50 808L.75 4699,63 N 6575.25 W 53815~.52 6036612.52 2L 818L.54 4763.00 N 6652.55 W 538077.84 6036675.42 2L 3.50 8L84.38 ~764.79 N 6654.75 W 538075.64 6036677.20 HS 3.50 8822,67 5169.53 N ~L49.59 ~ 537578.42 6037078.91 HS 0.00 8880.42 5106.15 N 7294.36 W 537533.43 6037~15.25 HS 3.50 P'I 96.96, 99.46 i. 0~t .00 12700.00 L06 ~2~oo.oo ~o~.~a 3.5/100 CURVE ~2B01.39 109.98 TAROBT POINT #4 ***~ 12853.7~ 109-9B 1~8~3.71 L09,98 D~RBCTION VERT£ChL-DBPTHS AZIMUTH TV/) SUB-SEA 309,28 7225.77 ~176.39 309.28 7206.34 7L56.9~ 309.28 7199.40 7~50.Q0 309.51 7180.96 7131.56 29 Hay A997 SECTIO~ OOORDINAT~$-FHOM DBPART ~LL~--~AD B979.98 5269.28 N 727L.5~ 9078.9[ 5332.01 N 734B.~4 9176.83 5~9~.~0 N 7424.16 9205.7S 5412.44 N 7446.57 92$3.39 5455.~4 N 7~9B.93 309.86 7149.75 7100.35 9368.19 ~516.O9 N 7592.03 309.8G ?149.28 7099.88 9369.~9 S536.93 N 7573.03 309.86 713~.40 70B2.00 9418.55 5548.44 N 7610.77 309.06 7L31,40 7082.00 94~8.55 5548.44 ~ 7610.77 Page 4 AJ_4%SKA Zone 4 TOOL X Y PACE LOG 537455.87 6037177,91 HS 3.50 537378.81 6037240.L? ~S ]-50 537302.62 603730£.80 H~ 3.50 533280.90 6037320.00 5R 3.$0 $33227.39 6037362,68 SR 3.50 537L53.93 6837422.89 5R 3.50 537152.93 6037423.72 HS 3,50 537115.00 6037455.00 0.00 537115.00 6039455.00 0.00 Z ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY _ PLAN (AnadriLi [c)97 MPL33~03 3.0C 2:59 PM P) i SHARED SERVICES DRILLI'NG"' ' .... llnadrJ]] $ch]U¢ber'ger' i iii i i i i ii i i i i i ii iii i i i ii i i i iii i i i i i iii ii i i i ANADRILL AKA-DPC MHL-JJ APPROVED VERTICAL SECTION V'IE ii i i i i FOR PERMiTTiNG 3o .o , ONLY TYD Scale.' I ~nch = ~500 feet ,, ~ Oep Scale.' ] inch = ]500 feet __ ~ PLaN ~ ~ Drawn ' 29 May 1997 i iiii i i iii i I O ~ F A) KB 0 0 0 0.0' 9] KOP / BYILO l/lOg 500 ~0 -0 0.0' ~} BOILD 1,5JtO0 700 100 3 ~ , ...... '~7 ~) CO,yE ~/too ~o 9oo l~ 5.0 ..... ' - --- .............. E) END ~/~00 ~800 ~769 233 23.0 4.............. ~~r ',3¢ F) CURVE 2.5/lO0 ~865 le~9 ~5B 23.0 -- ,. ..... 6) END ~.5/300 c~VE 3~B7 ~35 ]OB7 ~0 ~ NJ 9-5/8' CASING ~INI 60~2 44~3 3430 56.0 ]] C~VE 3/100 ]05]B 69~ 7~66 56.0 ~ CURVE 3.5/t00 ~0~6 ' 7114 750B 67,0 - ~ K) TAROT PO]N1 ¢I ~ f0906 .73t4 750B 67,~ % L) END 3.5/10~ CURVE ~1048 7164 764t. 7~.9 N) CURVE 3.5/1~0 t~075 7172 7666 -- ~ NJ IARGEI ~OINT ~2 ~ 1t]33 7189 77~] 74.0 ~ O) E~ 3.5/&~0 ]1603 7253 8184 90.4 -~-~ ~ PI CUEVE3.5/]O0 1~242 724a B823 90.4 ....~H ~ " - R) ENO 3.5/$00 CURVE l~BO] 7149 9369 ]09.~ S) TARGET POINI ~4 ~ t~854 7~3~ 94~9 j ~ T) 10 t~854 7t3~ 94~9 t09.~ " .... :~; ~ ~~ ............... .... ¢ P ~ ,, , ,,, 0 750 ~JSO0 2250 3000 3750 4500 5250 6000 6750 7500 6250 9000 9750 ID500 it250 '12000 '12750 Section I]eparture ! IAnadr~li lc)e7 ~L3~n3 3.0C ~(]0 PN Pi z ' HAR D S'FRVZCES 'DRILLING ANADRILL AKA-DPC APPROVED 'FOR PERMiTTiNG ONLY PLAN ..¢¢:_ 0~ ! i ~nadrJ]] Schlumberger i ! MPL-33 (PO3) VE~IICAL SECIION Section at: 306.09 TVD Scale ' ! loch : 300 feet Oep Scale · 1 inch : 300 feet Drawn ' 29 gay 1997 VIE~ - " I~Idl'K~[' 1 U f~ I! I. l [ ll;idl; 1 UJ1 Fig A] CURVE 3/100 10516 6929 7165 56.0 '~ 8] CURVE 3.5/~00 i0906 7ii4 7506 67.0 ~ C) TAR6ET POINT #~l ~x~ i0906 7~i4 7508 67.0, - -- D] END 3.5/i00 CURVE ii048 7~64 764i 7i ................. ~ ........ rmr~l~'-~t~ E] CURVE 3.5/100 ii075 7172 7665 F} TARBE[ POIHT #2 x,xx ]ii33 7t89 772t 74.0 ............ ',~ mL b~_~ 'G) END 3.5/]00 ~i603 7253 B184 ~0.4 H) CURVE 3.5/i00 {2242 7248 9823 B0.4 ' .I) TARGEI POINI f3 ~{~ 12630 7i99 9~06 i04.0 kq~-~ J) END 3.5/~00 ~URVE i280i 7i49 9359 i09.9 ~~ ' K) ]ARGET ~INI ,4.,,. 12854 7i31 9419 i09.9 L) 1U i2854 7,3, 94i9 ,09.9 . ~:~ ~=::j:::::: ::=: ::=:. Tn~ ~. ]e~u~2 ~.[ee[ ~ ~:~ ...... ,_~ .... . ................. -',~f~ --' ..... U .... ~ ....... [g~'P~ '~' (~]dits 200 le,tJ ~~ I ' . ,. ~ H ... _, I 7000 7~150 7300 7450 7600 7750 7900 B050 I]200 8350 8500 8650 8600 9950 9i00 9250 9400 9550 9700 Section Departure I~adr ~ l [ lc) 97 I~'L33P03 3. O: 3: {)~ P# P) Z ~d~us 20C- ~ '13 m 08 PAGE ANADRILL ·DPC 907-344~2160 15:04 OS/29/1997 DAILLING MPL - 33 (P03) PLAN VIEW SERVICES . Azimuth 306.09 feet IrnBdr j 11 ~(,h }umberoer AW,DRiLL - /,I(,I...D:-(:' APPROVED FOR PERM.lTT~NG ONLY PL.AN #_.v,.r¿~.~~.. l' . C.l'o-' -""",ç;.,;....~ ~. ---..,...,..... at 9419 feet +28.021 (E) 1 == 1200 1997 inch 29 May CLOSURE DECLINATION SCALE DRAWN E/W o E o E 3 W 13W 190W 211 W 890 W 2B06 W 5862 W 6133 W 6133 W 6235 W 6254 W 6297 W 6655 W 7150 W 74~7 W 7573\11 7611 W 7611 W N/S o N o N 2 N 9 N 134 N 148 N 626 N 1974 N 4~23 N 4332 N 4332 N 4418 N 1.2434 N 4469 N 4765 N 52 70 N 5412 N 5517N 554B·N 5548 N SHARED HD o 500 700 900 1800 1865 3187 6012 10516 10906 10906 11048 11075 ~ 1133 11603 12242 12630 12801 12851.2 12854 Marker AI KB B) KOP /BUILD 1/100 C) BUILD 1.5/100 0) CU~VE 2/100 EJ END 2/100 F) CURVE 2.5/100 G) END 2.5/100 CURVE H) 9-5/SG CASING POINT 1) CURVE 3/100 J) CURVE 3.5/100 KJ TARGET POINT #1*~~* LI END 3.5/100 CURVE M) CURVE 3.5/100 N) TARGET POINT 12 **~* D) END 3.5/10D P) CURVE 3.5/100 Q) TARGET POINT '3 ~*~~ R) END 3.5/100 CURVE S) TARGET POINT #4 **** T) TO Identification 6600 6000 5400 4800 1.2200 Pt #¿ (Radius 200 fee: ) pt '3 (Radius 200 f~et 3600 ~ 3000 2ciOO ^ I :z: I- a: c Z ::z: I- ;:) o tf) , v 1800 1200 600 o o 600 7800 7200 6600 6000 S40(Þ=" 4800 ~200 3600 3000 2400 AJiOO 1200 600 0 600 (- WEST : EAST -> IAn;,dril) (c) 97 MPL.33P03 3.0C 3: 03 PH PI 0£ ~97 ~P EXPLORATION (ALASKA) ANCHORAGE, ALASKA FAX # (907) 564-5193 P.1 TELEC_OPY C_OVER SHEET TO: COMPANY: LOCATION: Bob Crandall . AOGCC Anohora.ge FAX #: 276-7542 FROM: LOCATION: PAGES TO FOLLOW: 3 COMMENTS: Kathy Campoam, o,r, ..... SHARED SERVICES DRILLING ANCHORAGE, ALASKA PHONE #: $64-$122 -- DATE: 6-2-97 Per your request, this Is the letter which explains the ion of ADL355023. This should help for the MPF-09 & Permit To Drill applications. If you have any other quesbons, please give me a call. IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) $64-$122 DEPARTMENT OF NATURAL RF~OURCES DIVISION OF OIL AND GAS ?'OIVF KIVOIML£$. $OOl "C" &.7'P, EET, YUITE ANCHORAGE, AI..4EKA PHONE' (907J CERTIPI~) MAIL 53474 & 53475 RETURN RBCBIFT REQUESTED MAY 9 1997 ARCO Alaska, Attn: La~d M~ager P,O. Box 100550 Anchorage, Al( 99510-0360 DECISION Oil &Ous [.ease ADL 355023 Kuparuk River Un]t Tract ] 22 BP Exploration (Alaska) lnc, Attn: Land M~agcr - Alaska P.O. ]Box 196617. 900 E. Benson Blvd. Anchorage, AK 99519-6612 Oil & Gas Lease ADL 388235 Kuparuk River Unit Tract 122 Milne Point Unit Tract.22 ._ __ LEASE SEOREGA'rBD MILNB POINT UNIT EXPANDF, D CONTRACTION OF ME.NB POINT UNrr DEFERRED Oil and gas lease ADL 355023 was issued ¢ff¢ctivc June 1, 1983 with a primary term of ten years. Tho lease was committed in its entirety to the Kuparuk River Unit (KRU) and incorporated in part into [he Kuparuk Participating Area (KPA) upon lheir Second thpansions, effective J'unm 1, 1985, The lea.~e was ,xtunded indefinitely in a¢oord~co with the KRU Agreement and paragraph 4b of the lease. Additional acreage was incorporated isa the KPA upon its Fourth Expansion, effective December 1, 1990, On Iuly 8, 1996, application w;s mad~ to ibc Director, Division of O{! and Gas for "Approval of Assignment, Con~racdon of Kuparuk Riwr Unit and Expansion of Milne Point Unit" by ARCO Alask~ Inc. (ARCO) ~ lessee and ~U Operator ~d BP ExploraQon (Alaska) Inc. af Milne Point Unit (MP~ Operator, In dmat application, tho subject lands w~m requust~ to bc l) se~gat~ from oil and ~ l~ase ~L 355023 2) ~misned from ~CO A]~k~ Inc. ~o BP Exploration (Alaska) Inc. (BP), et al 3) contracted out of ~e ~U and 4) committed to the MPU with its pending contraction deferred, Tho subject lands we~ identified ~: Conserve and E~hanc~ Naft~rtrl Resources for ~re~ent and Future Ala.fkang" E0'cI ~i{:~058SY..08~0 'OH 14¥'{ S¥O '~ 'II0'/~I(I/~{HQ¥ 00-~8- I~{.'{ L6-0E-A¥{,I 0£:58PM BP E--~PLORATIOM ~ P.3 5h')/97 35502lng.dec Pag~ 2 of 3 T. 13 N., R. 9 E., U.M. Sectfon 1: All; 640 acres Section 2: Nl/2, S[51/4; 480 acres Section I l: NEt/4; 160 ac~e.s S~ction 12: Ail; 640 am'cs Containin. g !,920,00 acm.% more or]ess. By Decision dated November 18, 1995, thc Director approved the expansion of the MPU and the commitment of the $~;bje~t lands to th~ unit with defen'al of contraction of those lands from MPU until December 31, 1997. By Decision dated November 25, 1996, the Director approved the assignment of ARCO's working interest in the subj~t land~ to BP, ct al, The subject lands were segmen~cd within oil and g~ lea~e ADL 355023 as Segments I and A, .~. In accordance with paragraph 18 of the l~ase and I 1 AAC 82.610, tho subject lands (segments 1 and A) are hereby severed from oil a~d gas ]eas~ ADL 355023 and gssigned ~L 3gg235. ~e lands rerunning in oil and gas lease ADL 355023 following th~ segregation am: T. 1 :~ N,, R, 9 1~,, U.M. Section 2: SW1/4; 160 acres Section 3: All; 640 acres Section 4: All; 640acres Section 8: Ail, excluding, all tide and submerged lands and USS 4275; 5~ acres Section 9: All; 640 acres Section 10: All; 640 acres S~tion ! 1: ~ l/a, $ l/2; 480 acrcs Containing 3,255.00 acres, more or less. State of Alaska oil amd gas I~ase ADL 355023 r~mains extended in accordance with the ~I~.U Agreement ~d p~agraph 4b of th~ l~e. Th~ teas~ ~m~ns commi~ed in its ~ntir~ty ~o the ~U ~d ~n p~ ~ th~ ~A. Tb~ poni6n of tb~ ieee within ~e ~A is described as follows: T. 13 N,, R. 9 E., U.M. , Section 3: All; 640 acrcs · ~0 'd 5II~0Sg@L0@[0 'ON 02:58PM BP EXPLOR~TI©M P.4 P.~e .3 or 3 Section 4: All; 640ac~s Section 8: All, excluding all tide and submerged lands and USS 427~; $$ acres S~tion 9: All; 640~cr~s Se~(ion 10: Alk 640 acl~s Section 1 I; NWI/~, SW1/4~ 320 acr~ Con£afning 2,93f00 acre& moro or less. The lands included in oil and &as base ADL 38823:5 as a resul[ of the segregation arc: T. 13 N., R. 9 1~., U.M. MPU Tract 22 Section 1: All: 6d,0acres $~¢tion 2: NI/2. SEI/4; 480 acres Section 11: NI~lI4; 160 acres Section 12: All; 640 acres Containing 1,920.00 acres, mor~ or l~s. State of Alaska oil and gas Ica.se ADL 38823:5 r~tain$ the same effective dale and primar~ t~n'n as thc original lease. The lease is core.trod in iL~ entir~iy lo the MPU ~ KRU and is exmnded in accordance with the MPU & KRU Ag~oments and paragraph 4b of the le~e. A de~ision r~garding ~e contraction of th~ KRU ~ to ~he subjzct lands is still p~nding. If you have m~y qu~tions regarding this decision, please call Pirtle Bates al (907) 269.8t~ lO. Kenneth A. Boyd Director cc: Mike Kotowski, Units Manager ICA B/Pl!t/pbj/355023sg.dee 1~0 'd 'ON X¥ 4 WELL PERMIT CHECKLISToo Y PROGRAM: exp[] dev [] redrl[] serv~wellbore segD ann disp para reqD uNi , //.92_F oN/oFF ADMINISTRATION 1. Permit fee attached .................. Y ~, N 2. Lease number appropriate ............... Y' .N 3. Unique well name and number .............. Y N 4. Well located in a defined pool ............. Y N 5. Well located proper distance from drlg unit boundary. .Y N 6. Well located proper distance from other wells ..... Y N 7. Sufficient acreage available in drilling unit ..... Y N 8. If deviated, is wellbore plat included ........ Y N 9. Operator only affected party .............. Y N 10. Operator has appropriate bond in force ......... Y N 11. Permit can be issued without conservation order .... Y N 12. Permit can be issued without administrative approval. .Y N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . Y.~ N 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... ~J N 23. If diverter required, is ±t adoquate .......... 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... N BOPE press rating adequate; test to ~--6~-~2> psig 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 .... Y~' 31. Data presented on potential overpressure zones ..... ~/~ 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... / Y N 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISS ION: 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. * ALASKA COMPUTING CENTER * . . . ............................ . * ....... SCHLUMBERGER ....... * . ............................ . COMP~ N~ : B.P. ~PLO~TION ~LL N~ : MPL- 33 FIE~ N~ : MI~ POI~ BOROUGH : NOR~ SLOPE STATE · ~S~ API ~ER : 50-029-22774-00 ~F~CE NO : 97410 * ALASKA COMPUTING CENTER * ....... SCHLUIViBERGER ....... COMPANY NAFIE : B.P. EXPLORATION WELL NAME : MPL- 33 FIELD NAM~ : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22774-00 REFERENCE NO : 97410 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/12/ 4 ORIGIN : FLIC REEL NAME : 97410 CONTINUATION # : PREVIOUS REEL COMMENT : B.P. EXPLORATION, MILNE POINT MPL-33, API #50-029-22774-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/12/ 4 ORIGIN · FLIC TAPE NAME : 97410 CONTINUATION # : 1 PREVIOUS TAPE : COI4MENT · B.P. EXPLORATION, MILNE POINT MPL-33, API #50-029-22774-00 TAPE HEADER MILNE POINT MWD 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: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPL-33 500292277400 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 4-DEC-97 BIT RUN 1 BIT RUN 2 BIT RUN 3 97410 97410 97410 ST. AMOUR DAI~VlEYER DAFk4EYER WILLSON PYRON PYRON 8 13N 10E 3764 5118 49.40 49.40 16.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 5906.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 3RD STRING PRODUCTION STRING Rb~4ARKS: Well drilled 29-JUN through il-JUL-97 with CDR and CDR/ADN. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVTJMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUFkZzARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 225.0 13410.0 BASELINE DEPTH 88888.0 88893.5 13212.5 13218.0 13209.0 13215.0 13204.0 13209.0 13168.0 13173 5 13162.5 13169 0 13160.0 13165 5 13154.0 13160 0 13147.0 13154 0 13144.0 13150 0 13134.5 13139 5 13107.0 13112.5 13098.0 13103.0 13082.5 13088.0 13047.5 13053.0 13039.5 13046.0 13013.5 13019.5 12999.0 13005.0 12979.5 12985.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD LIS Tape Verification Listing Schlumberger Alaska Computing Center 12962.0 12968.0 12942.0 12948.0 12926.0 12934.0 12924.0 12932.0 12919.0 12925.0 12908.0 12913.0 12891.5 12896.5 12888.5 12893.0 12879.5 12884.5 12859.5 12864.0 12841.5 12848.5 12836.5 12842.5 12810.0 12815.5 12799.5 12804.0 12785.5 12791.5 12777.0 12784.0 12765.0 12769.5 12757.5 12762.5 12750.0 12754.0 12725.5 12731.0 12693.0 12700.5 12681.5 12688.5 12663.5 12669.5 12647.5 12654.5 12631 . 0 12638.5 12624.5 12632.5 12617.5 12625.5 12595.5 12601.5 12580.0 12585.5 12566.5 12571.0 12561.5 12566.5 12524.0 12528.5 12499.0 12503.5 12489.5 12493.5 12476.5 12481.0 12449.5 12454.0 12429.0 12435.0 12394.0 12398.0 12380.0 12384.0 12370.5 12374.5 12358.5 12361.5 12347.5 12351.5 12346.0 12350.0 12329.0 12332.0 12309.0 12312.0 12258.0 12261.5 12213.5 12219.0 12199.0 12205.0 12190.0 12196.5 12184.0 12189.5 12164.0 12171.0 12156.5 12162.5 12128.5 12134.0 12108.5 12115.0 12094.0 12102.0 5-DEC-1997 07:56 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:~6 PAGE: 12051.0 12058.5 12034.5 12041.5 12023.0 12031.0 11985.0 11992.5 11973.5 11980.5 11958.0 11964.0 11928.5 11935.0 11870.5 11875.5 11869.0 11873.5 11850.0 11853.0 11781.0 11788.5 11747.5 11754.5 11707.0 11713.0 11693.5 11699.5 11641.0 11646.0 11628.5 11634.5 11612.5 11619.5 11601.0 11608.0 5906.0 5906.0 100.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: BIT RUN NO. MERGE TOP MERGE BASE 1 225.0 5930.0 2 5819.0 10571.0 3 10434.0 13410.0 The depth adjustments shown above reflect the MWD GR to the PDC GRCH logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF, Max. Density) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/ PEL/PER, and ROMB/ROMU/ROML/ROMR. The LDWG outputs of CALA and CALS are PHgIA and VDIA respectively. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMS4000811 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~M4000811 O0 000 O0 0 1 1 i 4 68 0000000000 VRA MWD OH~M4000811 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OPiMM4000811 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0H~4000811 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 R3IO1 MWD G/C3 4000811 O0 000 O0 0 1 1 I 4 68 0000000000 RH02 MWD G/C3 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 4000811 O0 000 O0 0 1 1 t 4 68 0000000000 RH04 MWD G/C3 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 4000811 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: DEPT. 1341 O. 000 FET. MWD VR~ . MWD -999.250 VRP. MWD GR. MWD - 999. 250 RHOB. MWD RH03 .MWD -999. 250 RH04. MWD DCAL . MWD -999. 250 CALS . MWD DEPT. 13000.000 FET.MWD VRA.MWD 13.676 VRP.MWD GR.MWD 86.322 RHOB.MWD RHO3.MWD 2.362 RHO4.MWD DCAL.MWD 0.000 CALS.MWD DEPT. 12000. 000 FET. MWD VRA . MWD 3. 059 VRP . MWD GR.MWD 111. 470 RHOB.MWD RH03 .MWD 2. 471 RH04 .MWD DCAL.MWD O. 301 CALS.MWD DEPT. 11000.000 FET.MWD VRA.MWD 16.920 VRP.MWD GR.MWD 77.807 RHOB.MWD RHO3.MWD 2.398 RHO4.MWD DCAL.MWD 0.000 CALS.MWD DEPT. 10000.000 FET. MWD VRA.MWD 3.302 VRP.MWD GR.MWD 106.599 RHOB.MWD RHO3.MWD 2.512 RHO4.MWD DCAL.MWD 0.177 CALS.MWD DEPT. 9000.000 FET.MWD VRA.MWD 2.765 VRP.MWD GR.MWD 111.533 RHOB.MWD RHO3.MWD 2.388 RHO4.MWD DCAL.MWD 0.111 CALS.MWD DEPT. 8000.000 FET.MWD VRA.MWD 2.944 VRP.MWD GR.MWD 94.776 RHOB.MWD RHO3.MW 2.356 RHO4.MWD DCAL.MWD 0.086 CALS.MWD DEPT. 7000.000 FET.MWD VRA.MWD 2.478 VRP.MWD GR.MWD 96.295 RHOB.MWD RHO3.MWD 2.354 RHO4.MWD DCAL.MWD 0.105 CALS.MWD DEPT. 6000.000 FET.MWD VRA.MWD 3.292 VRP.MWD GR.MWD 89.040 RHOB.MWD RHO3.MWD 2.288 RHO4.MWD DCAL.MWD 0.547 CALS.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD O . 622 RA . MWD 20. 680 DER.MWD 2.362 RHO1. MWD 2.381 DRHO.MWD 8. 602 CALA . MWD 0.907 RA.MWD 4. 016 DER . MWD 2. 481 RHO1 .MWD 2. 493 DRHO.MWD 8. 935 CALA . MWD O . 924 RA . MWD 26.547 DER.MWD 2.3 62 RHO1. MWD 2.398 DRHO . MWD 7. 868 CA_LA . MWD -999.25O RA.MWD 3. 454 DER.MWD 2. 557 RHO1 .MWD 2. 515 DR_HO. MWD 8. 868 CALA . MWD -999.250 RA.MWD 2. 765 DER.MWD 2. 432 RHO1 .MWD 2. 338 DRHO.MWD 9. 269 CALA . MWD -999.250 RA.MWD 2. 932 DER.MWD 2. 314 RHO1 .MWD 2.334 DRHO . MWD 9. 535 CALA . MWD -999.250 RA.MWD 2. 559 DER. MWD 2. 358 RHO1 .MWD 2. 380 DRHO.MWD 9. 602 CALA . MWD -999.250 RA.MWD 3.230 DER.MWD 2. 309 RHO1 .MWD 2.282 DRHO. MWD 10. 069 CALA . MWD -999.250 -999.250 -999.250 -999.250 -999.250 11. 037 16. 327 2. 352 O. 009 8. 602 3.285 3.679 2.508 0.028 9.135 20. 182 27. 624 2.398 O. 036 8.201 3.203 3.300 2. 536 O. 014 9. 202 2.722 2.745 2.412 0.001 8.802 2. 972 2.918 2.315 O. 002 9. 469 2.358 2.486 2.362 0.004 9.669 3.165 3.142 2.270 O. 041 9. 669 RP.MWD R OP. MWD RH02 .MWD PEF. MWD NPHI.MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPHI .MWD RP.MWD ROP.MWD RH02. MWD PEF.MWD NPH I . MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPH I . MWD RP.MWD ROP.MWD RH02. MWD PEF.MWD NPH I . MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02 .MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02 .MWD PEF.MWD NPHI.MWD -999.250 44.888 -999.250 -999.250 -999.250 17.698 127.668 2.408 2.531 30.400 3.976 55. 046 2. 474 3. 412 38.500 28.240 25.246 2.398 2.498 29.400 3.357 197.821 2.494 3.818 29.400 2.758 180.000 2.359 3.632 34.900 2.890 206.869 2.315 3.038 34.700 2.577 189.483 2.327 3.025 39.500 3.129 282. 456 2.268 3. 291 37.900 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: DEPT. 5000.000 FET.MWD VRA.MWD 2.167 VRP.MWD GR.MWD 74.408 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 4000.000 FET.MWD VRA.MWD 7.238 VRP.MWD GR.MWD 64.204 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 3000.000 FET.MWD VRA.MWD 11.986 VRP.MWD GR.MWD 64.211 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 2000.000 FET.MWD VRA.MWD 17.075 VRP.MWD GR.MWD 55.806 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 1000.000 FET.MWD VRA.M-WD 15.370 VRP.MWD GR.MWD 54.219 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 265.500 FET. MWD VRA . MWD -999. 250 VRP . MWD GR.MWD 69. 764 RHOB.MWD RHO3.MW-D -999.250 RHO4.MWD D CAL . MWD -999. 250 CAL S .MWD O. 267 RA. MWD 2. 277 DER. MWD -999. 250 RHO1 .MWD - 999. 250 DRHO. MWD -999.250 CALA.MWD 0.406 RA.MWD 7.278 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD 0.247 RA.MWD 12.564 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD 0.237 RA.MWD 16.762 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD 0.528 RA.MWD 16.148 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD 1.786 2.035 -999.250 -999.250 -999.250 7.042 7.210 -999.250 -999.250 -999.250 12.115 12.542 -999.250 -999.250 -999.250 16.252 16.068 -999.250 -999.250 -999.250 14.358 15.908 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 RP.MWD ROP. MWD RH02 .MWD PEF.MWD NPHI .MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02 .MWD PEF.MWD NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD 2.293 972.220 -999.250 -999.250 -999.250 7.281 416.958 -999.250 -999.250 -999.250 12.671 417.201 -999.250 -999.250 -999.250 16.023 975.615 -999.250 -999.250 -999.250 16.347 104.044 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 225.0 5930.0 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 CDR RESIST./GR ADN AZ. DEN./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: Il-JUL-97 2.6 4.0 MEMORY 13405.0 225.0 13410.0 60 55.9 TOOL NUMBER CDR752 ADN059 8.500 5906.0 LSND 10.30 43.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~k4) AT TEMPERATURE (DEGF): MUD AT MEASURED TE~IPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 2.120 1. 850 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) TOOL STANDOFF (IN) '. EWR FREQUENCY (HZ): 20000 REMARKS: ** RUN 1 DRILLED 111'-5930'** RES TO BIT: 58.46'; GR TO BIT: 69.04' ** RUN2 DRILLED 5930' - 10571'** RES TO BIT: 53.91'; GR TO BIT: 64.91' NEUT TO BIT: 112.29'; DENS TO BIT: 108.16' ** RUN3 DRILLED 10571' - 13406'** DEVIATION PROJECTED TO 108.98 DEG AT TD DATA FROM DOWNHOLE ~ORY, V4.26 SOFTWARE $ LIS FORMAT DATA 80.0 72.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 10 ** SET TYPE - CHAN ** Ngl~ SERVUNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000811 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LWl OH~ff~4000811 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OPH~14000811 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 OH~4M4000811 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 OHFff4 4000811 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 0H~4000811 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 4000811 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 4000811 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 4000811 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5929.500 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR. LW1 - 999.250 DER. LW1 - 999. 250 ROPE. LW1 82. 594 GR. LW1 TABR. LW1 -999. 250 DEPT. 5000. 000 ATR. LW1 1. 775 PSR. LW1 1. 678 ATVR. LW1 PSVR.LW1 1.648 DER.LW1 1.714 ROPE.LW1 477.251 GR.LW1 TABR . LW1 O . 278 DEPT. 4000. 000 ATR. LWl 7. 026 PSR. LW1 7. 192 ATVR.LW1 PSVR.LW1 7.152 DER.LW1 7.142 ROPE.LW1 417.336 GR.LW1 TABR . LW1 O . 414 DEPT. 3000. 000 ATR.LW1 12.259 PSR.LW1 12. 857 ATVR.LW1 PSVR. LW1 12. 807 DER.LW1 12. 718 ROPE.LW1 408. 950 GR.LW1 TABR. LW1 O. 245 DEPT. 2000. 000 ATR. LWl 16. 322 PSR. LW1 14. 106 ATVR. LW1 PSVR. LW1 14. 123 DER. LW1 14 . 526 ROPE. LW1 1003 . 884 GR. LW1 TABR. LW1 O. 239 DEPT. 1000. 000 ATR.LW1 14.578 PSR.LW1 16. 744 ATVR.LW1 PSVR.LW1 18.511 DER.LW1 16.269 ROPE.LWl 104. 044 GR.LW1 TABR. LW1 O. 52 6 DEPT. 225. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR.LW1 -999.250 DER.LWl -999.250 ROPE.LWl -999.250 GR.LW1 TABR. LW1 -999. 250 -999.250 -999.250 1.560 81.000 7.073 63.942 12.343 69.919 14.672 73.352 17.446 53. 983 -999.250 57.188 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCR~4ENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 5867.0 10571 . 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 CDR RESIST./GR ADN AZ. DEN./NEUT. $ il-JUL-97 2.6 4.0 MEMORY 13405.0 225.0 13410.0 100 55.9 57.9 TOOL NUMBER CDR752 ADN059 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 5906.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. 30 MUD VISCOSITY (S) : 43.0 MUD PH: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (OHFk4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 2. 120 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 850 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 EWR FREQUENCY (HZ): 20000 REMARKS: ** RUN1 DRILLED 111'-5930'** RES TO BIT: 58.46'; GR TO BIT: 69.04' ** RUN2 DRILLED 5930' - 10571'** RES TO BIT: 53.91'; GR TO BIT: 64.91' NEUT TO BIT: 112.29'; DENS TO BIT: 108.16' ** RUN3 DRILLED 10571' - 13406'** DEVIATION PROJECTED TO 108.98 DEG AT TD DATA FROM DOWNHOLE ~ORY, V4.26 SOFTWARE $ LIS FORMAT DATA 80.0 72.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 108 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 13 TYPE REPR CODE VALUE 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 0H~4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 0I~44000811 O0 000 O0 0 3 1 1 4 68 0000000000 ATVR LW2 OHNf44000811 O0 000 O0 0 3 1 1 4 68 0000000000 PSVR LW2 OHNf~ 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 0P~4~4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROMB LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 CALNLW2 IN 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 DCALLW2 IN 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 PiDIA LW2 IN 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 VDIA LW2 IN 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM 4000811 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13300. 000 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 -999.250 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE. LW2 -999.250 GR.LW2 -999.250 ROMB.LW2 -999.250 ROBB.LW2 -999.250 ROBU. LW2 -999.250 ROBL.LW2 -999.250 ROBR.LW2 -999.250 DRHB.LW2 -999.250 DRHU. LW2 -999.250 DRHL.LW2 -999.250 DRHR.LW2 -999.250 PEB.LW2 -999.250 PEU. LW2 -999.250 PEL.LW2 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 14 PER.LW2 -999.250 CALN. LW2 HDIA.LW2 -999.250 VDIA.LW2 DEPT. 13000. 000 ATR. LW2 PSVR. LW2 -999. 250 DER. LW2 ROMB. LW2 -999. 250 ROBB. LW2 ROBR . LW2 - 999. 250 DRHB . LW2 DRHR . LW2 - 999.250 PEB . LW2 PER. LW2 - 999.250 CALN. LW2 HDIA. LW2 -999. 250 VDIA. LW2 -999. 250 TNPH. LW2 - 999 . 250 RPM. LW2 - 999 . 250 PSR. LW2 -999. 250 ROPE. LW2 -999. 250 ROBU. LW2 -999. 250 DRHU. LW2 -999. 250 PEU. LW2 -999. 250 TNPH. LW2 -999. 250 RPM. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPT. 12000.000 ATR.LW2 -999.250 PSR.LW2 -999.250 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE.LW2 -999.250 ROMB.LW2 -999.250 ROBB.LW2 -999.250 ROBU. LW2 -999.250 ROBR.LW2 -999.250 DRHB.LW2 -999.250 DRHU. LW2 -999.250 DRHR. LW2 - 999. 250 PEB. LW2 -999. 250 PEU. LW2 -999. 250 PER. LW2 -999. 250 CALN. LW2 -999 . 250 TNPH. LW2 -999. 250 HDIA.LW2 -999.250 VDIA.LW2 -999.250 RPM. LW2 -999.250 DEPT. 11000. 000 ATR.LW2 PSVR . LW2 - 999.250 DER. LW2 ROMB.LW2 -999.250 ROBB.LW2 ROBR. LW2 -999. 250 DRHB . LW2 DRHR . LW2 - 999.250 PEB . LW2 PER. LW2 -999. 250 CALN. LW2 t~DIA. LW2 -999. 250 VDIA. LW2 10000 000 3 261 2 519 2 528 0 046 4 563 11 803 9000. 000 2. 752 2.380 2.411 O. 019 3. 039 10. 536 8000. 000 3. 028 2.388 2.323 O. 011 2. 894 10. 736 7000.000 2.615 2.385 2.384 A TR . LW2 DER. LW2 ROBB . LW2 DRHB . LW2 PEB.LW2 CALN. LW2 VDIA. LW2 A TR . LW2 DER. LW2 ROBB . LW2 DRHB . LW2 PEB . LW2 CALN. LW2 VDIA . LW2 A TR . LW2 DER. LW2 ROBB . LW2 DRHB . LW2 PEB. LW2 CALN. LW2 VDIA. LW2 A TR . LW2 DER. LW2 ROBB . LW2 DRHB. LW2 DEPT. PSVR. LW2 ROMB. LW2 ROBR. LW2 DRHR . LW2 PER. LW2 HDIA. LW2 DEPT. PSVR . LW2 ROMB. LW2 ROBR. LW2 DRHR . LW2 PER. LW2 HDIA. LW2 -999. 250 PSR. LW2 -999. 250 ROPE. LW2 - 999 . 250 ROBU. LW2 -999. 250 DRHU. LW2 -999. 250 PEU. LW2 -999. 250 TNPH. LW2 - 999. 250 RPM. LW2 3. 004 PSR. LW2 3.160 ROPE. LW2 2.514 ROBU. LW2 0.016 DRHU. LW2 3. 850 PEU. LW2 8.513 TNPH. LW2 11. 203 RPM. LW2 2. 683 PSR. LW2 2. 709 ROPE. LW2 2. 358 ROBU. LW2 -0. 005 DRHU. LW2 3.686 PEU. LW2 8. 606 TNPH. LW2 10. 269 RPM. LW2 2. 976 PSR. LW2 3.020 ROPE. LW2 2. 358 ROBU. LW2 O . O11 DRHU. LW2 2. 964 PEU. LW2 8. 686 TNPH. LW2 10. 536 RPM. LW2 2.507 PSR.LW2 2. 553 ROPE. LW2 2. 405 ROBU. LW2 O. 020 DRHU. LW2 DEPT. PSVR. LW2 ROMB. LW2 ROBR. LW2 DRHR. LW2 PER. LW2 HDIA. LW2 DEPT. PSVR. LW2 ROMB. LW2 ROBR. LW2 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 3.259 159.309 2.439 0.038 5.443 29.900 102.000 2. 724 214. 263 2. 400 O. 038 3. 634 35.500 98. 000 3.046 225.055 2.313 0.033 3.002 36.000 84.000 2. 581 250. 010 2. 365 O. 038 DCAL . LW2 A TVR . L W2 GR. LW2 ROBL. LW2 DRHL . LW2 PEL . LW2 DCAL . LW2 A TVR . L W2 GR. LW2 ROBL . LW2 DRHL . LW2 PEL . LW2 DCAL . LW2 A TVR . L W2 GR. LW2 ROBL. LW2 DRHL . LW2 PEL . LW2 D CAL . L W2 ATVR. LW2 GR. LW2 ROBL. LW2 DRHL. LW2 PEL. LW2 DCAL. LW2 A TVR . LW2 GR. LW2 ROBL. LW2 DRHL. LW2 PEL. LW2 DCAL. LW2 A TVR . LW2 GR. LW2 ROBL . LW2 DRHL . LW2 PEL. LW2 D CAL . L W2 A TVR . L W2 GR. LW2 ROBL. LW2 DRHL . LW2 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3. 089 108.254 2. 518 O. 035 4. 592 O. 013 2.759 111.584 2.424 0.021 3.436 0.106 3. 059 100. 668 2.329 O. 025 3. 513 0.186 2. 532 100. 371 2. 363 O. 016 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 15 DRHR. LW2 O. 046 PEB.LW2 PER. LW2 3. 421 CALN. LW2 HDIA. LW2 9. 002 VDIA. LW2 DEPT. PSVR. LW2 ROMB. LW2 ROBR. LW2 DRHR. LW2 PER. LW2 HD IA . LW2 6000 000 3 117 2 332 2 327 -0 005 3 426 9 469 A TR . LW2 DER. LW2 ROBB . LW2 DRHB . LW2 PEB . LW2 CALN. LW2 VDIA. LW2 DEPT. 5818.000 ATR. LW2 PSVR . LW2 - 999. 250 DER. LW2 ROMB. LW2 - 999. 250 ROBB. LW2 ROBR . LW2 - 999. 250 DRHB . LW2 DRHR. LW2 - 999. 250 PEB. LW2 PER.LW2 -999.250 CALN. LW2 HDIA. LW2 -999. 250 VDIA. LW2 3.010 PEU. LW2 8. 662 TNPH. LW2 8. 935 RPM. LW2 3. 081 PSR. LW2 3.140 ROPE. LW2 2. 319 ROBU. LW2 -0. 013 DRHU. LW2 3.161 PEU. LW2 8.500 TNPH. LW2 9.269 RPM. LW2 -999. 250 PSR. LW2 -999. 250 ROPE. LW2 -999. 250 ROBU. LW2 -999. 250 DRHU. LW2 -999. 250 PEU. LW2 -999. 250 TNPH. LW2 -999. 250 RPM. LW2 3.367 PEL.LW2 40. 500 DCAL.LW2 95. 000 3.175 ATVR. LW2 363. 367 GR. LW2 2. 309 ROBL. LW2 O. 005 DRIIL. LW2 3. 295 PEL. LW2 37. 300 DCAL.LW2 76. 000 -999. 250 ATVR.LW2 -999. 250 GR. LW2 - 999. 250 ROBL. LW2 -999. 250 DRHL. LW2 -999. 250 PEL. LW2 -999. 250 DCAL. LW2 -999. 250 3. 025 O. 162 3.151 96. 671 2.330 -0. 001 3.398 O. 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 16 VENDOR TOOL CODE START DEPTH LOG HEADER DATA 10434.0 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: M3L¥IMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZ. DEN./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : STOP DEPTH 13406.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 11 -JUL-97 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 2.6 4.0 ~ORY 13405.0 225.0 13410.0 80 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 57.9 109.0 REMARKS: TOOL NUMBER CDR752 ADN059 8.500 5906.0 LSND 10.30 43.0 500 2.120 80.0 1. 850 72.0 ** RUN1 DRILLED 111'-5930'** RES TO BIT: 58.46'; GR TO BIT: 69.04' ** RUN2 DRILLED 5930' - 10571'** RES TO BIT: 53.91'; GR TO BIT: 64.91' 0.5 20000 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 17 NEUT TO BIT: 112.29'; DENS TO BIT: 108.16' ** RUN 3 DRILLED 10571' - 13406'** DEVIATION PROJECTED TO 108.98 DEG AT TD DATA FROM DOWNHOLE MEMORY, V4.26 SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N.,3~ SERV UNIT SERVICE API API API API FILE ~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) DEPT FT 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 0H~944000811 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OPi~ff44000811 O0 000 O0 0 4 1 1 4 68 0000000000 ATVR LW3 OH~M4000811 O0 000 O0 0 4 1 1 4 68 0000000000 PSVR LW3 OH~4~ 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW3 OH~4M4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 4000811 O0 000 O0 0 4 I 1 4 68 0000000000 TABR LW3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROiZfl3LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DRHU LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 DRHL LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 DRHR LW3 G/C3 4000811 O0 000 O0 0 4 1 1 4 68 PEB LW3 4000811 O0 000 O0 0 4 1 1 4 68 PEU LW3 4000811 O0 000 O0 0 4 1 1 4 68 PEL LW3 4000811 O0 000 O0 0 4 1 1 4 68 PER LW3 4000811 O0 000 O0 0 4 1 1 4 68 CALN LW3 IN 4000811 O0 000 O0 0 4 1 1 4 68 TNPH LW3 PU 4000811 O0 000 O0 0 4 1 1 4 68 DCAL LW3 IN 4000811 O0 000 O0 0 4 1 1 4 68 HDIA LW3 IN 4000811 O0 000 O0 0 4 1 1 4 68 VDIA LW3 IN 4000811 O0 000 O0 0 4 1 1 4 68 RPM LW3 RPM 4000811 O0 000 O0 0 4 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 13404. 500 ATR. LW3 -999. 250 PSR. LW3 -999 PSVR.LW3 -999.250 DER.LW3 -999.250 ROPE.LW3 44 TABR. LW3 -999. 250 ROMB. LW3 -999 . 250 ROBB. LW3 -999 ROBL. LW3 -999. 250 ROBR. LW3 -999. 250 DRHB. LW3 -999 DRHL. LW3 -999. 250 DRHR. LW3 -999. 250 PEB. LW3 -999 PEL. LW3 -999. 250 PER. LW3 -999. 250 CALN. LW3 -999 DCAL. LW3 - 999. 250 HDIA. LW3 - 999 . 250 VDIA. LW3 - 999 DEPT. 13000. 000 ATR.LW3 12. 764 PSR.LW3 16. PSVR.LW3 14.813 DER.LW3 16.118 ROPE.LW3 134 TABR.LW3 O. 614 ROMB.LW3 2. 407 ROBB.LW3 2 ROBL . LW3 2.372 ROBR . LW3 2.390 DRHB . LW3 0 DRHL . LW3 O . 030 DRHR . LW3 O . 018 PEB . LW3 2 PEL.LW3 2. 785 PER.LW3 2.519 CALN. LW3 8 DCAL. LW3 O. 196 HDIA. LW3 8. 701 VDIA. LW3 8 DEPT. 12000. 000 ATR. LW3 3. 237 PSR. LW3 4 PSVR. LW3 3. 998 DER. LW3 3 . 686 ROPE. LW3 52 TABR.LW3 0.857 ROMB.LW3 2.506 ROBB.LW3 2 ROBL.LW3 2. 478 ROBR.LW3 2. 472 DRHB.LW3 0 DRHL.LW3 O. 061 DRHR.LW3 O. 025 PEB.LW3 3 PEL . LW3 3.944 PER. LW3 3.347 CALN. LW3 8 DCAL. LW3 O. 360 HDIA. LW3 8. 935 VI)IA. LW3 9 DEPT. 11000. 000 ATR.LW3 15. 786 PSR.LW3 31 PSVR. LW3 35. 053 DER. LW3 28. 696 ROPE. LW3 47 TABR.LW3 O. 943 RO~.LW3 2.251 ROBB.LW3 2 ROBL.LW3 2.278 ROBR.LW3 2.317 DRHB.LW3 0 DRHL.LW3 0.008 DRHR.LW3 0.027 PEB.LW3 2 PEL.LW3 2. 466 PER.LW3 2. 438 CAL1V. LW3 8 DCAL. LW3 O . 072 PiDIA. LW3 8. 815 VDIA. LW3 8 250 ATVR. LW3 888 GR. LW3 250 ROBU. LW3 250 DRHU. LW3 250 PEU. LW3 250 TNPH. LW3 250 RPM. LW3 595 ATVR.LW3 344 GR.LW3 375 ROBU. LW3 000 DRHU. LW3 857 PEU. LW3 696 TNPH. LW3 735 RPM. LW3 048 ATVR.LW3 787 GR. LW3 480 ROBU. LW3 000 DRHU. LW3 2 68 PEU. LW3 860 TNPH. LW3 168 RPM. LW3 609 ATVR. LW3 872 GR. LW3 285 ROBU. LW3 035 DRHU. LW3 574 PEU. LW3 572 TNPH.LW3 668 RPM. LW3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 11.006 87. 720 2. 382 O. 050 3.299 29.400 71.000 3.036 113.381 2.467 0.095 4.586 35.600 69.500 20. 633 64. 483 2.309 O. 020 3.123 28. 400 123. 750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-DEC-1997 07:56 PAGE: 19 DEPT. 10387.500 ATR . LW3 PSVR . LW3 - 999. 250 DER. LW3 TABR. LW3 -999. 250 RO~i~. LW3 ROBL. LW3 -999. 250 ROBR. LW3 DRHL. LW3 - 999. 250 DRHR. LW3 PEL . LW3 - 999.250 PER. LW$ DCAL. LW3 - 999. 250 HDIA. LW3 - 999.250 PSR . LW3 -999. 250 ROPE. LW3 -999. 250 ROBB. LW3 -999. 250 DRHB. LW3 - 999. 250 PEB. LW3 -999.250 CALN. LW3 -999.250 VDIA.LW3 - 999.250 ATVR. LW3 -999. 250 GR. LW3 - 999. 250 ROBU. LW3 -999.250 DRHU. LW3 -999.250 PEU. LW3 - 999 . 250 TNPH. LW$ - 999. 250 RPM. LW3 -999.250 -999. 250 -999.250 -999.250 -999.250 - 999. 250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA2GE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/12/ 4 ORIGIN : FLIC TAPE NAME : 97410 CONTINUATION # : 1 PREVIOUS TAPE : COI4~qENT : B.P. EXPLORATION, MILArE POINT MPL-33, API #50-029-22774-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/12/ 4 ORIGIN : FLIC REEL NAME : 97410 CONTINUATION # : PREVIOUS REEL : COP~PENT : B.P. EXPLORATION, MILNE POINT MPL-33, API #50-029-22774-00
