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Home My WebLink About187-015 • • \-61_ 0t_5 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501iz.►r201Ca .v1.K.BENDER RE: Static Bottom Hole Pressure Record: 3M-04 Run Date: 11/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21697-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-029-21697-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari MESI 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' ✓QAgza.. /_ -' ,/ STATE OF ALASKA ALP.OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other:Cond Ext I 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J' Exploratory r 187-015 3.Address: 6.API Number: Stratigraphic r Service r 50 029-21697-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025521 • KRU 3M-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 9976 ' feet Plugs(measured) None true vertical 6502 IL feet Junk(measured) None Effective Depth measured 9632 feet Packer(measured) 9457 true vertical 6293 feet (true vertical) 6186 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 1640 630 SURFACE 4638 12 4675 3389 3520 2020 PRODUCTION 9907 7 9944 6482 4980 4330 Perforation depth: Measured depth: 9556'-9686' � � ,(t If RECE1 +�E � ,J True Vertical Depth: 6246'-6326 NOV 1 0 201 5 Tubing(size,grade,MD,and TVD) 2.875,J-55, 9488 MD,6204 TVD AOGCC Packers&SSSV(type,MD,and TVD) PACKER-CAMCO HRP-1-SP RETRIEVABLE PACKER @ 9457 MD and 6186 TVD SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1801 MD and 1661 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development F..7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: OilGas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r , SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-627 Contact Email n 1878(a,cop.com Printed Name MJ Lovel nd Title Well Integrity Supervisor Signature ,/( / Phone:659-7043 Date 11/7/2015 / VTL I/4/14 (4-77i RBDMS*NOV 13 2015 Form 10-404 Revised 5/2015 Submit Original Only • it 11.7 ConocoPhillips RECEIVED Alaska NOV 10 2015 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AO CC November 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3M-04, PTD 187-015, Sundry 315-627, conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • 3M-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date 11/7/15 Event Summary 10/30/15 Welded a 8" conductor extension onto the existing conductor due to rising wellhead. • _ • J ConocoPhillips RECEIVE® Alaska P.O. BOX 100360 N O V 10 2015 ANCHORAGE,ALASKA 99510-0360 AOGCC November 7, 2015OS) G 9 2016 Commissioner Cathy Foerster g o i Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 3" Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • 4 . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/7/2015 3G,3M&3S PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 3G-26 50029216960100 1990750 22" 0.4 26" 11/3/2015 2 11/6/2015 3M-03 50029216960100 2081790 SF NA 9" NA 2.6 11/6/2015 3M-04 50029216970000 1870150 12" NA 8" NA 3.7 11/6/2015 3M-25 50029224330100 1940060 12" NA 9" NA 3.2 11/6/2015 3S-14 50103204390000 2022210 64" 0.10 12" 11/3/2015 6 11/6/2015 • oF 4,sA THE STATE Alaska Oil and Gas � of LAsKA Conservati®n Commissi®n S " x =' "= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ...• .�A Main: 907.279.1433 ALAS Fax: 907.276.7542 DEC 0\5 www.aogcc.alaska.gov SCO Martin Walters Well Integrity Supervisor ` D ConocoPhillips Alaska, Inc. I g 7 / P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-04 Sundry Number: 315-627 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this /3 day of October, 2015 Encl. RBDMS of T 14 205 1rtC STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMIPSION OCT 0 6 2015 • APPLICATION FOR SUNDRY APPROVALS ire's 1Q11311,5 20 AAC 25.280 "R.„ 1.Type of Request: Abandon r RugFbrforations Fracture Stimulate � r--- Pull Tubing r Operations shutdown Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well F., Re-enter Susp Well r Other:Cond Ext fq 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. - Exploratory r Development p, 187-015 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 r 50-029-21697-00 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r J v.'R.tj 3M-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025521 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9976 - 6502 ' 9632' 6293' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' 1640 630 SURFACE 4638 9-5/8 4675' 3389' 3520 2020 PRODUCTION 9907 7 9944' 6482' 4980 4330 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9556'-9686' ' 6246-6326 2.875 J-55 9488 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER=CAMCO HRP-1-SP RETRIEVABLE PACKER MD=9457 TVD=6186' SAFETY VLV=CAMCO TRDP-1A-SSA(LOCKED OUT) MD=1801 TVD=1661 i 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F:. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2015WINJ r WDSPL I® Suspended r 16.Verbal Approval: Date: GOAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters/MJ Loveland Email: n1878cop.com Printed Name Martin Waiter: Title: Well Integrity Supervisor Signature '( , 0 �7��tsl+ x�� Phone:659-7043 Date: 10-03-15 / Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 7 IS —CO 27 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No R Subsequent Form Required: /0—440 7— 7) (� c rvtnn AHPEPR�OpVnEnD�gBY N / / Approved by: ' ,,rc a�aWAL Ata ror months fro tf1CZ13ic ora§4$roval. Date: ( �"`.3'�S j/) • �j, i Sub 't rm and Form 10-403 Re ised 5/2015 ' RI i I0 l0/.� — i a/,y tf 41015 • • _ fix' ConocoPhillips Alaska c+ 0 6 2015 P.O. BOX 100360 it ANCHORAGE,ALASKA 99510-0360 \✓ "+' October 3, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3M-04, PTD 187-015 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, Aivleitzt&-/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska,Inc. Kuparuk Well 3M-04 (PTD 187-015) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 3, 2015 This application for Sundry approval for Kuparuk well 3M-04 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 8". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD • 3M-04 ConocoPhillips u Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) f tes-otTelhp. 500292169700 KUPARUK RIVER UNIT PROD 59.05 3,100.00 9,976.0 "' Comment H2S(ppm) Dale Annotation End Date KB-Grd(ft) -Rig Rebase Date 3M-04,8/4/201410:48.34 AM SSSV:LOCKED OUT 240 12/19/2013 Last WO: 39.61 3/17/1987 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Data Last Tag:SLM 9,599.0 7/29/2014 Rev Reason:TAG,GLV C/O,H2S hipshkf 8/4/2014 ................................................. / HANGER;33.0 1r-I' (�) Casing Stnngs - 1 Casing Description OD(in) ID(in) Top(ftKB) Sot Depth(f KB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 36.9 4,674.9 3,388.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread auicmsmsauumuunsuuutu •' • im amt.PRODUCTION 7 6.276 36.9 9,943.8 6,482.0 26.00 J-55 BTC -^Tubing Strings CONDUCTOR;380-115.0 -A Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 2 7/8 2.441 33.0 9,487.8 6,204.6 6.50 J-55 EUE8rdABMOD Completion Details SAFETY VLV;1,800.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID r- (in) 33.0 33.0 0.22 HANGER VETCO GRAY TUBING HANGER 2.441 1,800.7 1,661.0 45.76 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.312 GAS LIFT;2,783.3 �.. 3/5/2009) a 9,440.0 6,175.4 52.41 SBR CAMCO OEJ SBR 4,312 9,456.5 6,185.5 52.35 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.347 9,475.4 6,197.0 52.28 NIPPLE CAMCO D NIPPLE NO GO 2250 9,487.1 6,204.2 5224 SOS CAMCO SHEAR OUT SUB,TTL ELMD 9475'SWS 2.441 SURFACE;38.9-4,674.9-c41 L, 3/15/1987 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top D) Top Incl GAS LIFT;4,832.6 Top(ftKB) (MB) r) Des Com Run Date ID(in) 9,748.0 6,363.0 52.71 FISH 1"DMY VLV BODY/WOBBLE RING 4/17/2009 0.000 9,751.0 6,364.9 52.70 FISH 1"DV Fell downhole 6/2/1999 6/2/1989 0.000 GAS LIFT;5,750.8 9,783.0 6,384.3 52.63 FISH 10'Strip Gun Lost in Hole 4/27/1990 4/27/1990 0.000 1 Perforations&Slots GAS LIFT;8,277.0 Shot Dens Top(TVD) Btm(ND) (ehots/f GAS LIFT;8,803.2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,556.0 9,576.0 6,246.4 6,258.6'A-3,3M-04 4/30/1990 6.0 IPERF EnerJet II,Zero deg. phasing GAS LIFT;7,327.0 9,584.0 9,604.0 6,263.5 6,275.7 A-2,3M-04 4/30/1990 6.0 IPERF EnerJet II,Zero deg. phasing 9,630.0 9,670.0 6,291.6 6,315.9 A-1,3M-04 4/28/1990 7.0 RPERF 4"Csg Gun,Zero deg. GAS LIFT;7,852.8 phasing 9,630.0 9,686.0 6,291.6 6,325.5 A-1,3M-04 4/280990 1.0 RPERF 4"Csg Gun,Zero deg. phasing GAS LIFT;8,348.3 Mandrel Inserts St alt C GAS LIFT;8,900.5 on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date 1 2,783.3 2,351.8 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,306.0 8/3/2014 or 2 4,932.6 3,529.1 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/5/1987 GAS LIFT;9,394.7 3 5,750.6 4,000.9 Camco KBMG ' 1 GAS LIFT GLV BK 0.188 1,286.0 8/3/2014 4 6,277.0 4,310.0 Camco KBMG 1 GAS LIFT OV BK 0.188 0.0 8/2/2014 5 6,803.2 4,616.9 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/21/1997 6 7,327.0 4,929.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,332.0 4/18/2009 SBR;0,440.0 7 7,852.6 5,243.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/2/2014 PACKER;9,456.5 8 8,346.3 5,534.4 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/18/2009 9 8,900.5 5,856.0 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/5/1987 1 9,394.7 6,147.8 OTIS LB 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/25/2009 NIPPLE;0,475.3 0 Notes:General&Safety End Date _ Annotation sos;9,487.1 4/14/2005 NOTE:WAIVERED WELL: IAx OA ANNULAR COMMUNICATION 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0-RKB PROD/TBG DIFFERENT RIGS 8/11/2011 NOTE:DV IN GLM#2 IS SCALED OVER AND IMPOSSIBLE TO REMOVE (PERF;9,558.0-9,576.0--t (PERF,9.584.04804.0 RPERF;9,630.0-9,670.0 -. .- RPERF;9,830.0-9,686.0-- .- 1 • = yyy f FISH;9,748.0 -> 9,;.FISH;0,751.0 FISH;9,783.0 PRODUCTION;38.9-9,943.8 • • Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Friday, October 09, 2015 8:15 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3M-04 (PTD 187-015): Sundry Application Attachments: 3M-04.pdf Patricia Attached is the 3M-04 Schematic Apologies for the oversite error. MJ From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, October 07, 2015 1:52 PM To: NSK Well Integrity Proj<N1878@conocophillips.com> Subject: [EXTERNAL]KRU 3M-04 (PTD 187-015): Sundry Application Good afternoon Martin, Please submit a current wellbore schematic for the KRU 3M-04 well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 - . r Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, October 07, 2015 1:52 PM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 3M-04 (PTD 187-015): Sundry Application Good afternoon Martin, Please submit a current wellbore schematic for the KRU 3M-04 well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning, They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) ~ Two-Sided RESCAN [] Color items: D Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type ORGANIZED BY: BEVERLY NOTES: BREN VINCENT SHERYL MARIA LOWELL Project Proofing DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ SCANNED BY: ~-~REN VINCENT SHERYL MARIA LOWELL DATE; F~ESCANNEDBY: BEVERLY BREN VINCEN~ARIA LOWELL DATE; General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned,wpd MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALAb,,,,/-~ OIL AND GAS CONSERVATION COMMISS,L)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- Location of well at surface 1227' FNL, 1713' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1492' FSL, 818' FEL, Sec. 30, T13N, R8E, UM At effective depth 1402' FSL, 558' FEL, Sec. 30, T13N, R8E, UM At total depth 1 12. 6. Datum elevation (DF or KB) RKB 64 7. unit or Property name Kuparuk River Unit 8. Well number 3M-04 9. Permit number/approval number 87-15 10. APl number 50-029-21697-00 11. Field/Pool Kuparuk River Field/Oil Pool 367' FSL, 456' FEL, Sec. 30, T13N, R8E, UM Present well condition summary Total Depth: measured true vertical 9976 6501 feet Plugs (measured) None feet feet Effective depth: measured 9840 true vertical 641 8 feet feet Junk (measured) DV and 10' perf strip in rathole Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 198 Sx CS II 1 15' 1 15' 1200 Sx AS III & 4675' 3388' 350 Sx Class G 300 Sx Class G & 9931' 6473' 175 Sx AS I 80' 16" 4638' 9-5/8" 9895' 7" measured 9556'-9576',9584'-9604',9630'-9686' true vertical 6245'-6257',6262'-6274',6290'-6324' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 9488' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 9456'; SSSV: Camco TRDP-1A-SSA @ 1801' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 7/25/97. Intervals treated (measured) ORIGINAL 9556'-9576',9584'-9604',9630'-9686' Treatment description including volumes used and final pressure Pumped 260 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 6257 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 543 304 101 1246 172 Subsequent to operation 929 462 244 1259 191 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~)~ ~~ Title Wells Superintendent Form /1Z¢~'04 ! Re~'~ ~,' - / Date. _/~.-/"~'...~ ~ % ~~~ ~,PLIOATE JAN 0 iL,, 1998 Oil & Gas Cons. Comrnis,!,,, ~;RCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(3M-04(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-04 FRAC, FRAC SUPPORT 0720971654.2 DATE DAILY WORK UNIT NUMBER 07/25/97; PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes O NoI (~) Yes O No DS-GALLEGOS JOHNS FIELD AFC.,~ CC# DALLY COST ACCUM COST Sign_e~..~; /.~ ')/~.,/ ESTIMATE KD1104 230DS36ML $1 1 5,201 $130,670 Initial Tb~l Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Oute~"Ann I Finacl~uter Ann I 180 PSI 2400 PSI 540 PSI 1000 PSII 50 PSII 400 PSI DALLY SUMMARY PUMPED "A' SANDS FRAC, W/260,366# PROPPANT TO 13 PPA 12/18 TO PERFS , FLUSHED 45 BBLS OR 9 BBLS SHORT OF PERFS ,~ SCREENED OUT PERFS. LEFT 2600# 12/18 IN PIPE. TIME 07:00 09:30 10:00 !o:!5 10:21 10:23 10:26 10:29 11:17 12:14 13:21 13:27 14:08 14:35 14:40 14:44 LOG ENTRY MIRU DOWELL FRAC EQUIP. , HOT OIL PUMP AND APC VAC TRUCK. HELD SAFETY MEETING PRESSURE TEST SURFACE LINE TO 10,700 PSI. INITIAL WHP 1180 PSI, START PUMPING BREAKDOWN, 15 BPM TO 8400 PSI AND 21 BPM & 7300 PSI. 100 BBL XL-LINK 50# GEL. ' PUMP 1 PPA PROPPANT FOR SCOUR STAGE 20 BPM AND 7493 PSI. PUMP FLUSH W/50 BBLS XL-LINK 50 # GEL, 15 BPM AND 7000 PSI. PUMP 2 PPA PROPPANT FOR SCOUR STAGE, 15 BPM AND 6450 PSI. PUMP 10 BBLS XL GEL AND 89 BBLS STRIAGHT WATER FOR FLUSH , 15 BPM AND 6500 PSI , SHUT DOWN FOR ISIP 1903 PSI, PUMP PULSE TESTS. PUMP DATA FRAC & DISPLACMENTS WITH 105 BBLS FLUIDS AT 5 TO 15 BPM AND 5025 PSI. SHUT DOWN ISIP 2260 PSI. PUMP 900 BBLS PAD , 15 BPM AND 5150 PSI. PUMP 2PPA FLAT STAGE OF 20/40 PROPPANT , 15 BPM AND 5340 PSI. PUMP RAMP 2PPA TO 6 PPA 12/18 PROPPANT , 15 BPM AND 6115 PSI. PUMP 10 PPA FLAT STAGE, 15 BPM AND 6110 PSI. PUMP 11.5 PPA, 13.5 BPM AND 6350 PSI. PUMP TO 13 PPA, 13 BPM AND 6257 PSI , GO TO FLUSH , PUMPED 45 BBLS FLUSH , CUT RATE TO 5 BPM , AND SCREENED OUT AT PERFS , LEAVING FLUSH 9 BBLS SHORT OR 2600# 12/18 IN PIPE. GOT 260,366 # PROPPANT TO 13 PPA, 12/18 AT PERFS. SHUT DOWN , LEAVE EQUIP. RIGGED UP FOR 3M-09 FRAC. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $953.00 _APC $7,300.00 $7,450.00 DOWELL $105,801.00 $105,801.00 HALLIBURTON $0.00 $9,911.00 LITTLE RED $2,100.00 $6,555.00 TOTAL FIELD ESTIMATE $115,201.00 $130,670.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate X Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1227' FNL, 1713' FEL, Sec. 25, T13N, R9E, UM At top of productive interval 1492' FSL, 4462' FWL, Sec. 30, T13N, R9E, UM At effective depth 1437' FSL, 4730' FWL, Sec. 30, T13N, R9E, UM At total depth 1367' FSL, 4824' FWL, Sec. 30, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 9976' feet Plugs (measured) true vertical 6502' feet Effective depth: measured 9970' feet Junk (measured) true vertical 6498' feet Casing Length Size Cemented Structural Conductor 115' 1 6" 198 Sx CS II Surface 431 3' 9 5/8" 1200 Sx AS III & Intermediate 350 Sx Class G Production 9931 ' 7" 300 Sx Class G Liner 175 Sx AS I 6. Datum elevation (DF or KB) C;~4' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3M-04 . 9. Permit number/approval number 86-15 / 90-219 10. APl number 5o-029-21697 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Cement · 9840'-9976' None Measured depth True vertical depth 115' 115' 4379' 3163' 9949' 6485' Perforation depth' measured 9556'-9576'; 9584'-9604'; 9630'-9670' true vertical 6246'-6259'; 6263'-6276'; 6291 '-631 6' Tubing (size, grade, and measured depth) 2 7/8" J-55 tbg w/ tail @ 9488' Packers and SSSV (type and measured depth) Camco HR ~ 9456'; Camco TRDP-1A-SSA ~ 1801' 13. Stimulation or cement squeeze summary Refer to attached Well Service Report Intervals treated (measured) Refer to attached Well Service Report Treatment description including volumes used and final pressure 14. Refer to attached Well Service Report Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 420 300 -0- 1300 133 Subsequent to operation 920 600 -0- 1260 135 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Water Injector Daily Report of Well Operations Z Oil ,X Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge.' Title Sr. Operations Engineer 17. Signed Form 10-404 Rev 05/17/89 Service Date SUBMIT IN DUPLICATE ARCO Alaska, 'Subsidiary of Atlantic Richfield Compar.. WELL SERVICE REPOh, CONTRACTOR IPBDT I FIELD. DISTRICT - STATE IDAYS IDATE OPERATION AT REPORT TIME .MARKS Poo A/ i"-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather "[Temp. Report *F Chill Factor I Visibility "F miles Iwind Vel. I Signed knots p~.-~. ~. ARCO Alaska, In~O 'Subsidiary of Atlantic Richfield Compan~ WEL.L PBDT CONTRACTOR ~MARKS WELL SERVICE REPORT FIELD- DISTRICT- STATE I IDAYS I DATE r-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather'[TemP.Report 'F I Chill Fact°r I VlsibllltY'F miles 1wind vel' Signed knots ~" '~"- ~ c.~.~ ARCOAlaska, In¢ .... ¢) Subsidiary of Atlantic Richfield Company ; WELl.. CONTRACTOR ;MARKS IPBDT WELL SERVICE REPORT I FIELD- DISTRICT-STATE "^-,o. /L/?~ IOPEn / AT REPORT TIME DAYS t DATE [Z3'O 'TO 5 I-tUT CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, In¢~-~ ¢~ Subsidiary ot. Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR .MARKS IPBDT FIELD- DISTRICT- STATE I DAYS OPERATION AT REPORT TIME IDATE [~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReportTemp, *F I Chill FactOr, F Vlaibilit¥ miles I Wind Vel, knots ISigned ARCO Alaska, Inr-O · "Subsidiary of. Atlantic Richfield Compar,, W~ELL CONTRACTOR ] PBDT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT I DAY,,,~ lDATE r--i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 'Weather ' 1 Temp. I Chill Factor Visibility IWlnd Vel. · Report °F °F miles knots ISigned ARCOAlaska, In; ~ WELLSERVICE REPOR'~ Subsidia~ of Atlantic Richfield Companx ,_~,~~. } . IEIELD- DISTRICT- STATE ~ IDAYS DATE ~ ...,,~ /o.2o ~ I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather l'Temp' I Chill Fact°r t Vl'lbillty lWlnd Vel'Report -' "F "F mil. knot, J ~ ARCO Alaska, In Post Offic,. .~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. W~ll Action Anticipated Start Date 3B-10 Variance April, 1990 3C~03 Stimulate April, 1 990 3M-04 Perforate & Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber AT. 1478 J. R. Brandstetter AT. 1120 L. Perini AT. 1130 KOE1.4-9 w/o attachments RECEIVED 'APR 1 21990 /)il & Gas Cons. Commission ~1 ~ohora~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /\Ii2,1{ /;002. C STATE OF ALASKA A~, ~ OIL AND GAS ~SERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate X Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 1227' FNL, 1713' FEL, SEC. 25, T13N, R8E, UM At top of productive interval 1492' FSL, 4462' FWL, Sec. 30, T13N, R9E, UM At effective depth 1437' FSL, 4730' FWL, Sec.30, T13N, R9E, UM At total depth 1367' FSL~ 4824' FWL~ Sec. 30~ T13N~ 12. Present well condition summary Total Depth: measured R9E~ UM 9976' feet 6. Datum elevation (DF or KB) Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical 65 0 1' measured 9 9 7 0' true vertical 6 21 7' Length Size 115' 16" 4313' 9 5/8" feet feet feet 9931' 7" measured 9630'-9686' 1 SPF RKB 64 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-04 9. Permit number feet 10. APl number S0-029-21 697 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Cement' 9840-9976 Junk (measured) None Cemented Measured depth True vertical depth 198 Sx CS II I 15' 1200 Sx AS III & 4379' 350 Sx Class G 300 Sx Class G 9 9 4 9' 175 Sx AS I 120 degree phasing, true vertical 6230'-6260 TVD Tubing (size, grade, and measured depth 2 7/8" J-55 set at 9488' Packers and SSSV (type and measured depth) Camco HR ~ 9456', Camco TRDP-1A-SSA ~ 1801' 13. Attachments Description summary of proposal X Add Perfs and Fracture Stimulate Well. 14. Estimated date for commencing operation May. 1990 16. If proposal was verbally approved Name of approver 115' 3437' 6484' Detailed operation program _ (Wellbore schematic attached). 15. Status of well classification as: Oil X Gas __ Date approved Service BOP sketch Suspended _ 17. I her_e.,~certify th~the Signed -~"~~ . forego~g, is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ~,pproved by the order Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. , Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Description Summary of Proposal for 3M-04: · Add Perfs to existing completion in A1 Sand 9630' - 9670' MD, 6 SPF, 0° Phasing, 2, Perforate A2 Sand 9556' - 9576' MD (new perforations), 6 SPF, 0° Phasing, e Perforate A3 Sand 9584' - 9604' MD (new perforations), 6 SPF, 0° Phasing, , Return Well 3M-04 to production for post perforation well production test. , Fracture stimulate the Al, A2, and A3 Sands with 102,400 lbs of 16/20 Carbolite or Light Weight Proppant (LWP), using 1409 barrels of carrying fluid (1353 barrels gelled water, 56 barrels gelled diesel). Note· There will be some lag time between the perforation work and the stimulation work in order to obtain multiple post perforating well test. KUPARUK WELL 3M-04 APl #: 500292189700 SPUD DATE: 0,3/09/87 ADL LEASE: 25521 PERMIT #: COMPLETION DATE: 07/05/87 WORKOVER DATE: 87-15 SURFACE LOCATION: 1227'FNL 1713'FEI.,SEC25,T13N,RSE TOP OF KUPARUK: 1492'FSL4482'FWL,SEC30,T13N,R9E TD LOCATION: 1367'FSL,4824'FWL,SEC30,T13N,RgE NI del:~hs are MD-RKB 1~ t3p of equipment unless otherwise noted ORIGINAL RKB: 63 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5# H-40 115 9.625' 36# J-55 4675 7' 26# J-55 9931 2.875" 6.5# J-56 ABM 9488 TUBING SPOOL: 33 WELLTYPE: PRODUCER SIZE LINER DETAILS WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH sssv CAMCO TRDP-1A-SSA 2.312' 1801 SBR CAMCO OEJ 2.313' 9440 PKR CAMCO HR 9456 NOGO CAMCO 'D 2.25' 9475 SHROUT CAMCO PE 9487 PAD ELEVATION: 26 STN 1 2 3 4 5 6 7 8 9 10 INTERVAL 9630-9686 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2783 CAMCO KBMG 1' 493,3 CAMCO KBMG 1' 5751 CAMCO KBMG 1' 6277 CAMCO KBMG 1' 6803 CAMCO KBMG 1' 7327 CAMCO KBMG 1' 7853 CAMCO KBMG 1' 8346 CAMCO KBMG 1' 8900 CAMCO KBMG 1' PORT SIZE 0.188 .DV .DV .DV 0.188 .DY .DV .DV .DY 0.25 PERFORATION DATA ZONE FT SPF PHASE COMMENTS A1 56 1 120 7/4/87 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 400 MAX HOLEANGLE: 59 deg 3100 HOLE ANGLETHRU KUP: 53 deg LAST TAG DATE: 10/04/87 9751 RATHOLE: 65 ft FIS H/OBSTRUCTION: LOST 1' DV W/O LATCH 6/2/89 PBTD: ~ 9840 PBTDSS.~ -5356 REVISION DATE: 05/23/89 REASON: STATE OF ALASKA ALASK~ ~>IL AND GAS CONSERVATION 'COMMISSION WELl COMPLETION OR RECOMPLETION REPORT AND LOG ~ kkk VVlflrkk · IVfl vn nGvvmrk& I IVll n&rvn i KAY kVU 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-15 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21697 4. Location of well at surface 9. Unit or Lease Name 1227' FNL, 1713' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval '"10. Well Number 1492' FSL, 4462' FWL, Sec.30, T13N, R9E, UM 3M-4 At Total Depth 11. Field and Pool 1367' FSL, 4824' FWL, Sec.30, TI~N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 64' ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/09/87 03/15/87 08/31/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of PermafrOst 9976'MD, 6501'TVD 9840'MD, 6418'TVD YES~] NO []I 1801' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CBT, GCT, Temp./GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 198 sx CS il 9-5/8" 36.0# J-55 Surf 4675' 12-1/4" 1200 sx AS Ill & 350 s:~ Class G 7" 26.0# J-55 Surf 9931' 8-1/2" 300 sx Class G & 175 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9630 ' -9686 'MD 6290 ' -6324 'TVD 2-7/8" 9488 ' 9456 ' 26[ ACID, FRACTURE, CEMENT SQUEEZE, ETC. " , ,, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perforated w/1 spf, 120° phasing See attached AddenJum, dated 9/7/87 for fracture d~ta. , , 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) . Date of Test Hours Tested pRODUCTiON FOR OIL-BBL GAS-MCF W'ATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD , I Flow Tubing Casing Pressure CALCULATED=k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-A'PI (corr) Press. 24-HOUR RATE 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of None °il' gas °r water' Submit c°~°~'E I V E D SEP o IS8/ Alaska Oil & Gas Cons. Commission Anchorage *Note: Drilled RR 3/17/87. Perforated well & ran tubin9 7/5/87. Fractured well 8/31/87, -, , Form 10-407 WC3/73 :DAN I Submit in dupl~ate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ('~ _~ 29. ( " '~' ' '.. _...~ 30. GEOLOGIC MARKERS '~,-oRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9493' 6207' N/A Base Kuparuk C 9493' 6207' Top Kuparuk A 9540' 6236' Base Kuparuk A 9720' 6345' 31. LIST OF ATTACHMENTS Addendum (dated 9/7/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed :,(~./Y?.,'~.; . J/_~L/_J~ j~ Title Associate Engineer Date ;/-~3-~/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClassifiCation of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/26/87 4/30/87 8/31/87 3M-4 Arctic Pak w/175 sx AS I & 65 bbls Arctic Pak. RU Schl, rn GR/JB to 9851' WLM. Rn CBT f/9845' - 7950'. Rn GCT gyro f/9822' - surf. Frac Kuparuk "A" sand perfs 9630' - 9686' as follows per procedure dated 8/19/87. Stage 1: 100 bbls gel/diesel @ 4 - 20 BPM, 3400 - 4800 psi Stage 2: 465 bbls gel diesel @ 20 BPM, 4930 - 4380 psi Stage 3: 18 bbls gel diesel 2 ppg 20/40 sand @ 20 B?M, 4380 - 4450 psi Stage 4: 34 bbls gel diesel 4 ppg 20/40 sand @ 20 BPM, 4450 - 4630 psi Stage 5: 32 bbls gel diesel 6 ppg 20/40 sand @ 20.5 BPM, 4630 - 4790 psi Stage 6: 30 bbls gel diesel 7 ppg 20/40 sand @ 20.5 BPM, 4790 - 4860 psi Stage 7: 15 bbls gel diesel 8 ppg 20/40 sand @ 20 BPM, 4860 psi Stage 8: 11 bbls gel diesel 9 ppg 20/40 sand @ 20 BPM, 4860 - 4960 psi Stage 9: 10 bbls gel diesel 10 ppg 20/40 sand @ 20 BPM, 4960 - 5130 psi Stage 10:61 bbls flush @ 20 BPM, 5130 - 4690 psi RU E-Line, rn Temp/GR; tag fill @ 9727'. Rn temp surv to 9350', POOH, RD Otis. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 776 bbls 44,650# 20/40 sand 340# 20/40 4700 psi Job complete 8/31/87. Turn well over to Production. Supervi~ SEP 3 o Al~sk~ Oil & Gas Cons. commission AnchOrage / ~te . j,) $ UB-$ URFA CE DIRECTIONAL SURVEY F~UIDANCE ~'~ ONTINUOUS ~"~ OD L Company , , ARCO ALASKA,, , I NC. Well Name 3M-4(1227' FNL, 1713' i i iii i i Field/LOcation KUPARUK,, NORTH SLOP,E~ FEL,SEC ii ALASKA, Job Reference N°. 72303 L., ocj~3ed SARBER RECEIVEI) J u L ~' 8 ~ 0ti & Gas Cons. Commission Anchorage ,25,T13N~R8E~ UM) Date 28-APR-87 Computed By: KRUWELL ~ SCHLUMBERGER ~ GCT DIRECTIONAL SURVEY CUSTOMER LISTING ARCO ALASKA~ INC, 3M-4 KUPARUK NORTH SbOPE~ALASKA SURVEY DATEI 28-APR-B7 ENGINEERI G, ~ARBER METHODS OF COMPUTATION TOOL DOCATIONI TANGENTIAL- Averaged deviation and azimuth INTERPOLATIONI LINEAR VERTICAL SfCTIONI HORZZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 66 DEG [3 MIN EAST COHPUTATION DATEr 17-MA¥-87 PAGE ARCO AbASKA, TNC. 3M-4 KUPARUK NORTH SbOPE,ALASKA DATE OF SURVE¥I 28-APR-87 KEbb¥ BUSHING EbEVATIONI 64.00 F? ENGINEERI Ge. SARBER INTERPObATED VAbUE$ FOR EVEN 100 FEET or MEASURED DEPTH TRUE SUB-SEA ¥~URSE MEASURED VERTICAb VERTICAb DEVIAT N AZIMUTH DZPTH DEPTH DEPTH DEG MIN DEG MIN VERTICA6 DOGb£G RECTANGUbAR COORUINA~E$ HORI~. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DI~?e AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 0 O0 00 O0 O0 O0 O0 O0 7O0 8O0 900, ooo ;!i.oo !.o .o °i o o : . 39 21 41 ' 35. 83 19 E 8 8b O0 797.25 7 ,25 ii 9 S 68 29 E 39.23 O0 894.19 830.$9 I 8 $ 72 41E 63.58 0 O0 04 10 77 0 24 53 13 0 O0 N 0,00 g 15 0.36 07 ~ 0.96 65 1,93 08 .,97 55 S 40,43 E 40 55 $ 63,51 E 64 0 O0 N 0 0 E 81 6 89 36 E 81 $ 82 11 E 94 & 7757 E 1000 i°° O0 O0 0 &O0 ?00 ~00 9OO O0 O0 1083 1435 O0 1514 O0 1589 O0 1660 O0 1729 989 43 925,43 19 14 04 1019,04 2t i; 120].17 28 31 I 1287.91 13 1371.13 35 38 28 14b0.28 39 43 O0 1525.00 43 14 24 1596.24 45 45 66 1665.66 45 16 $ 70 40 E 93.64 S 66 4 E 126.97 S 66 15 E 167033 $ 66 47 E 211,25 S 69 59 E 260.90 S 71 39 E 316.11 S 71 29 E 376,90 S 69 57 E 443,14 S 69 20 E 513.17 S 69 23 E 585.03 46 80 4 22 3 9B I 82 35 51 66 65 104 23 194 22 86 S 89 $ 125 75 S 160 46 S 200 96 S 247 03 $ 299 23 357 $ 486 92 S 553 92 46 E 95 12 E 130 06 E 168 b6 E 212 23 E 261 60 g 317 7 E 378 ~0 E 444 O2 E 514 42 E 586 25 S 76 6 E 17 S 73 59 E 2t $ 7i 5 E 04 S 7 499 E 75 8 7 E 66 8 70 E 78 O0 O0 ~600 1801.56 1737.56 43 9 O0 2 2 .43 1961,43 42 4 32 2035.32 42 15 oo O0 .61 2108.61 44 17 O0 2241,J7 2177.37 48 49 0 2304,13 2240.13 53 ~l 0 2360,62 2296.62 57 5 0 2413,53 2349,53 58 23 S 68 36 E 654,45 S 67 37 E 7 12 ,52 S 67 29 E 716,60 S 67 35 K 854.02 S 67 14 E 921.39 S 67 13 E 969,40 S 67 0 E 1061,95 S 66 33 E 1139,76 S 66 7 E 1222,24 S 65 38 E 1307,09 I 47 86 0 38 4 $~ 2 26 0 64 244 76 $ 269 295 2 375 ~06 81 $ 740 46 S 803 32 $ 865 64 $ 928 81 $ 994 54 S 1066 56 S 114 24 S 121~ 33 E 656 22 & ~00 ~5 E 61 g 72 28 S 3 g 781 51 S 69 59 E 91 E O6 E 855 29 E 923 O0 E 990 86 E 1063 36 E 1141 94 E 1223 39 g 1308 S 69 46 E 98 $ 69 50 $ 69 ~8 E 23 $ 69 ? E 62 $ 68 56 E 36 $ 68 44 E 3700 800 9OO O0 2465 60 2401,60 58 47 O0 2517 11 2453.11 59 2 2568 00 2673 O0 272b O0 2?79 O0 2833 51 68 2504,68 58 46 42 2556,42 58 35 57 2609.57 57 53 35 2662,35 58 15 16 2715,18 57 57 47 2769.47 55 60 2828.60 53 34 81 28~7,81 53 51 S 65 10 g 1392,45 S 64 53 £ 1478,14 $ 64 46 E 1563,80 S 64 49 g 1649,34 $ 64 46 £ 1734.03 S 64 38 E 1818,93 S 64 35 E 1903.80 S 64 38 £ 1987.73 S 64 24 E 2068,33 S 64 13 E 2148088 0 0 0 1 0 46 9S 04 46 18 97 70 66 509 76 $ 1297 Ol E 1393,60 & 68 545 96 S 1374 582 616 763 47 $ 1452 87 $ 1529 94 $ 1606 9 S 1683 9 S 1759 63 S 1835 30 S 1908 22 S 1981 71 E 1479 16' & 66 1~64 68 $ 68 ~2 E 1904 30 S 67 32 E 66 E 1988,16 S 67 24 E 09 E 2149,18 S 6 E ARCO AbATKA, INC, U;ARUK NORTH SLOPE,ALASKA COMPUTATION DATE{ 17-MA¥-87 PAGE 2 DATE OF SURVE¥I 28"APR'87 KEIabY BUSHING EbEVATIONI 64.00 let ENGINEERI G. ~ARBER INTERPObATEO VAEUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE &UR-SEA COURSE MEASURED VERTICAL VERT]CAb DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG VERTICAL DOGbEG RECTANGUbAR COORDINATES HORIZ,~ DEPARTURE SECTION SEVERITY NORTH/SOGTH EAST/NEST DIST,, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG #IN 40 ~, .40 2946, 54 26 ~ 64 4~ ~ 2229 3068 06 3004.~ ~½~. ~ ~o~o ~ 2311 . . 63 3124.91 3060. 55i [~ 410 2393 55 63 20 ~ . , 2476 . .74 3172, 56 3B 48 3456,10 3392, 57 , 2976 904~ O. 977 ~:~ 'I°'~o~, 63 109 32 173 0,13 1214 O8 £ ~6¢2 E 28.09 271~,50 E 2976 67 4 66 37 66 29 i 64 20 12 ~ 66 34 i 66 65 55 ~ 5000 O0 3565 25 3501.25 56 40 6 4~. E 3059 75 0 40 1253 76 $ 2791,17 3143 ~ 65 48 . 56 3307 O0 0 68 1369 3010 3307 23 3729 22 53 43 6 338788 · 35 53 48 S 3082 ~ ~ 65 64 11 440 86 65 7 42 57005600~00 39il 40 3847:40 53 53 ~[ ~~ 64 64 26 i 3468. ~ 37 88 3155 73~ 3468 49 57 39 1510 50 3906.36 ~ ~ 5800 4029 08 S 590000 3965,08 54 65 371050 1544 337402 371088 4087 66 o 65 10 v 4023.66 54 7 E 3791.53 41 1579 01 a 3447 ~ 3791:92 4440,42 65 coo O0 4614,28 4550,28 54 900 O04672.574608.57 53 ~ i~ i 4521.4602. ~ 19051874 $ 41{44190 i 4521.66 4602.84 i6565 io oo '"'1 65 4340 4762 4762,~7 7 5oo oo 5o3~ ~3 4968.4) ~ 20 s ~o E s E 60 5092 ~0 5028,20 53 700 O0 4719 51&0,97 66 800 O0 5211 ~9 5~47,1953 71 55 5320 53~0.95 66 ,oo oo ,~o ~o ~o~.~o ~, ~ [ :{~ 27 ~ 4871 5400 96 0 4948 39 ~ . 66 7217 5400,98 COaPUTATION DATES 17-HA¥-e7 PAGE 3 ARCO ALASKA, INC, 3N-4 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY1 280APR-87 KELLY BUSHING ELEVATXONI 64.00 FT ENGINEERI G.: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL V£RTXCAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORD%NATES HORIg.~ DEPARTURE SECTION SEVERXT¥ NORTH/SOUTH EAST/WEST P/ST,~ AZX#UTH FEET DEG/1 O0 FEET FEE~ F'j~EI, D~G MXN 8000 00 5329 87 5255,87 53 ~ 72 26 5481.04 34 2188 68 5025 14 66 $ 5179 34 5641081 66 38 5256 28 ~ 5722.)3 i 66 5722,12 8400 O0 5565 15 550i.15 ~{ 13 71 ~i i 5802.7, ~ ~6 2287 20 5333 26 5803.01 !i 8 E 5410 42 6127.4~5883'90 8500 O0 5623,51 5559.51 ~ I 71 5883.53 25 2312 49 I ~ 72 ~ 39 2362 74 i ~ 5964.74 66 8600 O0 5681,94 5617,94 S E 5964,28 . 58 2337 63 5487 58 66 6045.33 238801 ,,oooo ii 8800 O0 5797,38 5733.38 54 8900 O0 5854.88 5790.88 54 52 ~ 15 i 6208.~3 ~59 2413 07 ~5720 a2 t6208,92 9100 5907,09 54 $ 6371,05 S875,94 O0 5971 09 5{ 3) ~ 2462.39 6029,35 655i,41 6329,40 6848.16 71 9900 O0 6454 32 6390,32 70 58 67 6479,91 7004.91 9976.00 6500.55 6436.55 52 32 $ 70 58 E 7065.02 0,00 2685,99~ 6536094 E 7067,26 $ 67 39 E ARCO A~ASKA; ZNC.. KUPARUK NORTH SLOP£;A[,ASKA CDM~UTA?ION DATEI DATE; DF ~UR.V£Y 1 KELLY BUSHXNG EL~EVA TXONI EHGXNE:ERI PAG~ 4 2B?APRo87 64,00 FT G,~ BARBER ZNTERPObA?ED VAbUE$ FOR EVEH 1000 FEET DF MEASURED DEPTH TRUE SUB'SEA COUR6E MEASURED VERT/CAL VERTICAL DEVXATXON AZXMUTH DEPTH DEPTH DEPTH DEG MXN DEG. HXN VERTICAL,, DOGLEG RECTANGULAR COORDXNATE$ HORZZ.. SECTXON ~KVERXT¥ NORTH/~OUTH EAST/~EST FE~T DEG/1 O0 FEET F~ET r]~ ET DEPARTURE AT, XHUTH DEG PlXN o o, ,, o, ~ 'i ~ ?o ~ E ~ o, o.oo o.oo o.oo 5ooo oo ~5~5 =5 ~5 =5 ~oo ~ ,ooo o, ~=. ,? ~= 07 ~ ~.o, ,ooo o, ~,~= ~ ~0 ~, ~? o E . O. 2X88.68 5025,14 48 66 · 6289, 2437,89 5?98,62 ,26 99?6.00 6500.55 6436.55 52 32 S ?0 58 £ 7065.02 0.00 2685,99 5 6536,94 E 7067.26 $ 67 39 E ARCO AbASKA, 3M'4 KUPARUK NORTH SbOP£;AbASKA COHPUTAT/ON DATEI PAGE 5 DATE OF SURVEY Z 28.,APR-8? BUSHING Eb~¥ATIONI 64.00 leT ENGI#EZRI G. SARBER INTERPObATED VALUES FOR £VEN 100 FEET OF SUB-SEA DEPTH TRU~ SUB-SEA COURSE V~RTICAb DOG~ R~CTANGUI,,AR COOROINAT~S HORI~,. 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[ ..... i:"/ 'llB'lq~qF1 ............ f"'; ..... :":"'? =' ....... PROJECTION ON VERTICAL PLAN~ 119. - 299. $6ALE0 IN VE~TlCPL 0EPTHS HORIZ. S£qLE = 1,'2000 IN/FT ARCO Alaska, i Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 26, 1987 Transmittal ~ 6041 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 · Transmitted herewith are the following items. Please acknowledge receipt and. return'one signed copy of this transmittal. 2U-13 Static Well Pressure Survey 'C' Sand 8-27-87 3M-8 Kuparuk Well Pressure Report 'A' Sand 7-10-87 ~3M-7 Kuparuk Well Pressure Report 8-13-87 ~3M-6 Kuparuk Well Pressure Report 'A' Sand 8-12-87 ~3M-5 Kuparuk Well Pressure Report 'A' Sand 8-12-87 "~"-3M-4 Kuparuk Well Pressure Report 8-11-87 100554H Receipt Acknowledged: · DISTRIBUTION: BPAg Chevron Mobil SAPC Unocal State of Alaska ~ D & H' ARCO Alaska, Inc. Is a Subsidiary ol AllantlcRIchlleldCompany STATE OF ALASKA · AL. , OIL AND GAS CONSERVATION CC .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate,~ Pull tubing [] Alter Casing [] Other X] COHPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1227' FNL, 1713' FEL, 5ec.25, T13N, R8E, UN At top of productive interval 1492' FSL, 4462' FWL, Sec.30, T13N, R9E, UH At effective depth 1402' FSL, 4722' FWL, Sec.30, T13N, R9E, UN At total depth 1367' FSL, 4824' FWL~ Sec.30~ T13N~ R9E~ UN 11. Present Well condition summary Total depth: measured 9976'MD true vertical 6501 'TVD 5. Datum elevation (DF or KB) RKB 64 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-4 8. Approval number 7-218 9. APl number 50-- 029-21697 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 9840'MD true vertical 6418'TVD feet Junk (measured) None feet Casing Length Size Conductor 80' 16" Surface 4638' 9-5/8" Production 9907' 7" Cemented Measured depth 198 sx CS Ii 115'MD 1200 sx AS III & 4675 'MD 350 sx Class G 300 sx Class G & 9931 'MD 175 sx AS I True Vertical depth 115'TVD 3388 'TVD 6473 ' TVD Perforation depth: measured 9630'-9686'MD 12. true vertical 6290 ' -6324 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tubing w/tail ~ 9488' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 9456' & TRDP-1A-SSA SSSV @ 1801' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JUL 2 8 Lg ? /daska 0il & Gas Cats. Commission 13. N/A Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History w/Addendum, dated 5/16/87) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my Signed (~~ c~JJ/,~L,),,.__ TitleAssociate Engineer Form 10-404 Rev. 12-1-85 ~/ (Dani) $W02/52 Date Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field ICounty or Parish North Slope Borough Lease or Unit ADL 25521 Title Completion State Alaska IWell no. 3M-4 Kuparuk River Auth. or W.O. no. AFE AK2041 Nordic #1 API 50-029-21697 I otal number of wells (active or inactive) on this est center prior to plugging and ~ bandonment of this well I our I Prlor status if a W.O. I 0615 hrs. Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 7/4/87 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 7/04/87 0615 hrs. Classifications (oil, gas, etc.) O±1 Producing method 7" @ 9931' 9840' PBTD, RR 6.9 ppg Diesel Accept.rig @ 0615. hfs, 7/4/87. ND tree, NU & tst BOPE. RU WL, perf 9686'-9630' in 3 rns w/spf, 120° phasing. Make GR/JB rn, RD WL. RU & rn 287 its, 2-7/8", 6.5# J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1801', HRP-I-SP Pkr @ 9456', TT @ 9488'. Set pkr, tst csg; OK. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. RR @ 0615 hfs, 7/5/87. Flowing INew TD Date 7/5/87 PB Depth 9840 ' PBTD Kind of rig Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands RECElYEll JuL. 2 8 1987 0il & (]as Cons. Comlll[~Jgi~ Anch_-rage Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S gnature/~ , ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor ~IELL : 3/26/87 4130/87 3M-4 Arctic Pak w/175 sx AS I & 65 bbls Arctic Pak. RU Schl, rn GR/JB to 9851' WLM. Rn CBT f/9845' Rn GCT gyro f/9822' _ surf. - 7950 ' RECEIVED JUL 2 8 /~laska Oil & Ga~ Certs. Commissio[~ Anclmrage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, 6tuber Associate Engineer JG/pk GRU1/31 Enclosure Oil & Gas Ccns.'~ Com]t]issiotl Anchorau~ ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany 24 t9 Eh4,,¥ StkiPSOfl LAGOON VICINITY MAP sCALE I' · 2. ,~S NOTES '. I. ALL COORDINATES ARE A.S.P., ZONE 4. P..ALL DISTANCES gtOWN ARE TRUE. ALL WELLS LOCATED IN SEC. 25, TISN, R8E, UMIAT MERIDIAN. ASPs 'X' LATITUDE $.ELEVATIONS ARE B.RM.S.L. 4.RER FIELD BOOK L87-$, POt 7.14 L87-1, R T; L87-3,P 51 - 55; $.O.G.ELEVATIONS FROM F.R. BELL & ASSOCIATES. IdONUId~NTS PER LHD 81 ASSOCIATES. , T 506,t26.'~9 ,225. 506,13,6.45 6,246. 506,145.9i 506,155.5' 506,165.0' 506,174.6 6,016,$40.48 506,184.1: 6,016,365.49 506,195.5 6,016,$86.92 506,20:5.1' 6,016,456. I$ 506,252.0; 6,016,479.22 506,241.5: LONGIT UD E 49o.. ,6'58.$16 .016,502.26 50,6,251.O7 70°21 016,525.51 506,260.73 70°21 .016,548.62 506,270.:50 70027',2:5'1 86 016,571.43 506,2*79.77 70027.25-410 016,594.7:5 505,289.40 70°27'2:5-6:59 016,617.99 506,199.05 70°27.2:5.868 016,641.02 506,$08.76 70°?.*7'24.094 49°56'54.647 70'27' 24:. /~'~' ~.~q7" 7~'~7' /9. 323 /~q~sT'~. ~ Z Dist. F..N.L. 1298' 1273 1150 1227 1204 Iltl Il Il 56 1112 IO42 IOI9 996', 97:5 950', 927, 904 86i' 858' ~lZ' Dis t. £E.L. 1741' 1752' 1722 1713 1705' 1694 1884 16 TS 1665 1656 16 26 1617' 1607' 1598', 1586, 1578, 1569 1559' /7~/' 25.1' t6.6' 2:5.2' 26.6** 13.3', 16.9, 23.4 26.8 I$.5 16.7 2:5.2: 26.6' 2:5. I, 16.6' 15.0, 16.4', I 1.7, 26.5, 2 I.S 16.5 21.2 26.$ * 16 4' 20.g 10.9', 16.5, 20.9 26.5 20.8' 26.6' Za. ,~ ' 25.9' Z. c~. ,~ ' ~ 5. 7 ' · z~.~' / ~_~' 17Z.~' Z3.0' Z~,,~ ' ARCO Alosko Inc. 6 1,,,/7~.~~ ~Pi,,/17. ~,~ I HEREBY CERTIFY THAT I AM PROPERLY REGISIERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNOER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/87 D.S. 3M WELL CONDUCTOR AS-BUILT ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET~ 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC ., ~S tate~ of.~Alaska ~.i (+sepia) ~;~'~ BPAE Chevron Union Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Post Office Bu,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal f~: 5956 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted'herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Final Lo~s:. 3M-5 5" FDC Porosity 3-23-87 6750-8959 2" FDC Porosity 3-23-87 6750-8959 2" FDC Raw Data 3-23-87 6750-8959 5" FDC Raw Data 3-23-87 6750-8959 2" DIL 3-23-87 2700-8986 5" DIL 3-23-87 2700-8986 Cyberlook 3-23-87 8270-8959 3M-4 Cyberlook 3-15-87 2" FDC Porosity 3-15-87 9250-9815 5" FDC Porosity 3-15-87 9250-9815 2" FDC Raw Data 3-15-87 9250-9815 5" FDC Raw Data 3-15-87 9250-9815 2" DIL 3-15-87 4668-9841 5" DIL 3-15-87 4668-9841 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Vault (film) Rathmell D & M L. Johnston (vendor pkg) State of Alaska (+ sepia) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfiel(~Company ARCO Alaska, Inc. Post Office b.~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5958 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-4 3M-5 OH LIS Tape + Listing 3-15-87 #72228 OH LIS Tape + Listing 3-23'87 #72232 Receipt Acknowledged: DISTRIBUTION: D. Wetherell ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALAS,,.. OIL AND GAS CONSERVATION COMk~...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate [] Other L-~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1227' FNL, 1713' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1362' FSL, 888' FEL, Sec.30, T13N, R9E, UM At effective depth 1312' FSL, 4675' FWL, Sec.30, T13N, R9E, UM At total depth 1279' FSL, 4778' FWL~ Sec.30~ T13N, RgE, UH 11. Present well condition summary Total depth: measured 9976 'MD feet true vertical 6500 ' TVD feet 5. Datum elevation (DF or KB) Ri{R 6.~ ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-4 8. Permit number 87-15 9, APl number 50_029-21 697 10. Pool KuDaruk River Oil Plugs (measured) None Pool Effective depth: measured 9840 ' HI:) feet true vertical feet 6418 ' TVD Casing Length Size Conductor 80 ' 16" Surface 4638 ' 9-5/8" Producti on 9907 ' 7" Junk (measured) None Cemented Measured depth True Vertical depth 198 sx CS 11 115'MD 115'TVD 1200 sx AS II I & 4675'MD 3392'TVD 350 sx Class G 300 sx Class G 9931'MD 6473'TVD Perforation depth: measured None true vertical None ~bing(size,'grade and measured depth) None Packers and SSSV (type and measured depth) N o n e RECEIVED Ai~;ska (;!il & Oas O0r~s. 60mmissi0~ Anchorage 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./ JL Title A.,., o¢.i ~ ~,~ r-- ~,,eer Date Commission Use Only (JL0~ ~z~ Conditions of approval Notify commission so representative may witness [ 'A~p~ ~o. ~ Plug integrity ~ BOP Test ~ Location clearancel '? ~ Approved by ~ ~-~¢>,:i':~' Form 10-403 Rev 12-1-85 Commissioner ' 'by oCder'iSf' the commission Date Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. Field Kuparuk River Auth. or W.O. no. AFE AK2041 District ICounty, parish Or borough IState Alaska North Slope Borough I tease or unit 25521 ADL Drill Alaska IWell no. 3M-4 Doyon 9 API 50-029-21697 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate IHour Pr or status il a W.O. Spudded { 3/9/87 I 0100 hrs. Date and depth as of 8:00 a.m. 3/09/87 3/10/87 3/11/87 3/12/87 3/13/87 Complete record for each day reported 16" @ 115' 568', (453'), Drlg Wt. 9.1, PV 20, YP 27, PH 9.0, WL 8.8, Sol 6 Accept ri~ @ 2130 hrs, 3/8/87. NU diverter sys. 0100 hrs, 3/9/87. Drl surf hole to 568'. Spud well @ 16" @ 115' 2493', (1925'), Drlg Wt. 9.2, PV 15, YP 27, PH 8.5, WL 11.8, Sol 6 Drl & surv 12¼" hole to 2493'. 613', 5.5°, S82.7E, 612.79 TVD, 8.28 VS, 1192', 23.4°, S64.7E, 1169.23 TVD, 158.49 VS, 1380', 30.7°, S68.9E, 1336.55 TVD, 243.90 VS, 1756' , 45.1° 1.10S, 8.57E 55.01S, 148.95E 88.66S, 227.46E , S68.0E, 1632.06 TVD, 474.43 VS, 170.24S, 443.44E 16" @ 115' 4700', (2207'), CBU Wt. 9.4, PV 13, YP 12,~PH 8.0, WL 10.0, Sol 8 Drl & surv to 4700', CBU. 2062', 42.1°, S66.3E, 1853.63TVD, 685.40VS, 2638', 49.8°, S65.1E, 2268.54TVD, 1084.24VS, 3533', 58.3°, S63.0E, 2757.40TVD, 1832.11VS, 4380' 252.17S, 637.87E 415.38S, 1001.80E 742.95S, 1674.72E , 56.4°, S21.5E, 3230.64TVD, 2533.33VS, 1061.03S, 2300.82E 9-5/8" @ 4675' 4700', (0'), PU 8½" BHA Wt. 9.4, PV 11, YP 12, PH 8.0, WL 10.4, Sol 8 Short trip, circ, POOH. RU & rn 117 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 4592', FS @ 4675'. Cmt w/1200 sx AS III & 350 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND diverter sys. NU & tst BOPE. PU 8½" BHA. 4610', 57.1°, S59.5E, 3356.75 TVD, 2724.69 VS, 1155.74S, 2468.22E 9-5/8" @ 4675' 7572', (2872'), Drlg Wt. 9.1, PV 9, YP 4, PH 8.0, WL 8.8, Sol 6 RIH w/8½" BHA, tag FC @ 4592', tst csg to 2000 psi. DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv to 7572'. 4860', 57.1°, S59.9E, 3492.54 TVD, 2933.24 VS, 1261.64S, 2649.45E 5647', 54°, S64.0E, 3945.20 TVD, 3575.03 VS, 1563.16S, 3217.93E 6621', 54.4°, S65.3E, 4515.60 TVD, 4364.35 VS, 1896.37S, 3933.65E The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test [s not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska County or Parish Field Lease or Unit Kuparuk River Auth. or w,O.AFgnO. AKa041 Tit e North Slope Borough ADL 25521 Accounting cost center code State Alaska Drill Well no. 3M-4 Doyon 9 API 50-029-21697 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun Date Spudded 3/9/87 Date and depth Complete record for each day reported as of 8:00 a.m. Iotal number of wells (active or inactive) on this i ost center prior to plugging and bandonment of this well I our I Prior status if 'a W.O. I 0100 hrs. 3/14/87 thru 3/16/87 3/17/87 9-5/8" @ 4675' 9976', (2404'), Make wiper trip Wt. 10.1, PV 20, YP 14, PH 8.0, WL 3.8, Sol 11 Drl & surv 8½" hole to 9976', short trip, POOH. RU Schl, rn DIL/GR/SP/SFL f/9840'-4678', cont w/GR to 1000'. Log FDC/CNL f/9840'-9250' & CAL f/9840'-8450'. Make wiper trip. 7597', 53.5°, S73.2E, 5095.69 TVD, 5147.22 VS, 2169.62S, 4668.75E 8067', 53.8°, S72.0E, 5374.27 TVD, 5523.41VS, 2282.82S, 5029.86E 8542', 54.3°, S71.2E, 5653.13 TVD, 5906.24 VS, 2404.19S, 5394.83E 9012', 54.9°, S71.1E, 5925.39 TVD, 6287.93 VS, 2527.97S, 5757.93E 9737', 53.2°, S70.8E, 6355.67 TVD, 6869.12 VS, 2715.24S, 6309.98E 9976', 52.6°, S72.5E, 6500.25 TVD, 7058.45 VS, 2774.03S, 6490.97E 9-5/8" @ 4675' 3/18/87 Wt. 10.0, PV 12, YP 8, PH 8.0, WL 3.7, Sol 10.5 TIH, rm 9656'-9976', CBU, spot diesel pill. RU & rn 7" csg.:~ 7" @ 9931' 9976' TD, 9840' PBTD, RR A/~$ka 0ii & 10.0 ppg NaBr ~,- ~ 230 its, 7", 26#, J-55 BTC csg w/FC ~ 9841', FS ~ 9931'. Cmt w/100 sx 50/50 Pozz & 200 w/4% D-20, .5% D-65 & .2% D-46 & 200 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/377 bbls 10.0 ppg brine. Bump plug. ~ BOPE. Instl packoff. NU tbg spool & master vlv. Tst packoff to 3000 psi. ~ ~ 1730 hrs, 3/17/87. Old TD I New TD PB Depth 9976' TD 9840' PBTD Released rig Date IK nd of rig 1730 hrs. 3/17/87 I Rotary Classifications (oil, gas, etc.) 0il Producing method Flowing Type completion (single, dual, etc,) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production" Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor ARCO Alaska, Inc. Po~t Office Box 100360 /~,nchOrage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton' Enclosed is an as-built location'plat for the subject wells. If you have any questions, pleaSe call me at 263-4944. Sincerely, ~]. Gruber Associate Engineer JG/db GRU1/31 Enclosure RECEIVED MAF, z I ! Oil & G;~$ Con.s. Oommlssiof~ AI1CO Ala~!',a, Inc. is a Subsidiary of AtlnnticRichfieldO, on~.p[my ALL WELLS LOCATED IN SEC. 25, TISN, R~E~, ~UMI,AT~ME, RIDIAN' o _ 19 OLIKTOK PT. SIMPSON VICINITY MAP SCALE I"= 2MILES NOTES: I. ALL COORDINATES ARE A.S.P., ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. 3.ELEVATIONS ARE B.P.M.S.L. 4.REF. FIELOBOOK L87-$,Pg$.7-12; LST-I,RT;L87-3,PSI-55; 5.0.G. ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON SM CONTROL MONUMENTS PER LHD & ASSOCIATES. 4,016, E02.17 6,016,225.10 6,016,248 6,016,271.24 6,016,294.28 6,016,$17.42 6,016 ,:540.48 6,016 ,$ 65.49 ,016 ,:586.92 ,016,456.1:5 6,016,479.22 6,016,502.26 6,016,525.51 ,016,548.62 ,016,571.45 6,016,594.7:5 6,016,61 7.99 6,016,641.02 5 06, :508.76 LATITUDE LONGI T UD.__._._~E Dist. FN.L. 506,12 6.~9 70~ 2 T' I g-?lK)'~J149°57'00'000'' 1296' 506,156.45 170° 27'20-0051149°56' 59'720 506,145.98 17 0°27'20-Z 32.'II49056:59'459 1250, 506,155.57 170°27'20-459''1149056 59.157 1227 506,165.07 170°27120.685'1149°56',58.877 1204' 506,174.6:5 170°27 20.915'~149056 58.596 1181' 506 184.1:5 70°27'21.140"I 49°56'58':516 , 49° 56' 58.04C ;~, 506,205.14 ?0o27~21.59_6",Jl49O56157.756 II I 5o~,~4,.~ 7oo~7,z..~o4~,,'~°.~6 ~.~? ,o,~ 506,260.75 70°27 22-959]149056 56.06 975 50~,z~o.~o 707~',z~.,~:: ~eo5~:~.~7. ~0', 506,279.77 70 27 23.410, 49°56'55-501 927, 506,289.40 70°27',25.659,', 49°56'55'217 904 506,299.05 70°27 25.868 49o56'54.9:5:5 881' 70027'24.094.' 49056'54.647 8 58' Dist. FE.L. 1741' 17:52' IT 22' 1713 1705' 1694 1684 1675 1665 1656 1626 16171 1607 1598', 1586, 1578, 1569 1559' O.G.Elev. 23. I' 23.2' 23.$', 2:5.4 25.4', 25.21 25.~), 21.5 .2: 21.1' 20.9' 20.9 20.8' Pud Ele~. 26.6' 26.6' 26.9', 26.8 26.8', 26.7 26.6' 26. , 26.5, 26.5 6.3 26.4~ ~6.4~ 26.5, 26.5 26.6' I HEREBY CERTIFY THAT I AM PROPERLY TICE LAND SURVEYING IN THE °" '"'"SK' I DS3M PLAT REPRESENTS A LOCATION ~=~.~.~/,,,.'~.o.. __.~Z~.~%%_1.~2, SURV~ MAD[ BY ~ OR UNDER g~ . ~~ . re M. SUPERV,SION, AND THAT .LL ~'/~9~.~ :~: '~ ....... ARE CORRECT AS OF 3/8/87 ~ ~~~~~ ~ CRAIG L SAVAGE MEMORAndUM Stat of Alaska · ALASKA o~ AND GAS CONSERVATION COM,~SSION TO: C.y. Cha~~on DATE: March 18, 1987 Chairman roLE NO.: D .EWS. 25 THRU' Lonnie C Smith -~-~'?f'~'·:' ' ' /~"'i~ TELEPHONE NO.: CommiS:s ioner · FROM- Edgar W. Sipple, Jr. Petroleum InSpector SUBJECT: BOP Test ARCO KRU 3M- 4 Permit No. 87-15 Kuparuk River Field Wednesday, March 11, 1987: I traveled this date from ARCO's CPF 1, ~S~b~-ct~ ~and~h~ repO~, to ARCO's KRU 3M-4, Doyon Rig 9, to witness a BOP test. The drilling contractor was in the process of coming out of hole to run casing. Thurs day, March. ! 2, . !987: The test commenced at 3:40 a.m and was conCiude~ at 4:40~a,~ There were no failures. I filled Out the AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test on ARCO's KRU 3M-4, Doyon Rig 9, Attachment 02-001 A ( Rev 10-84) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~-~ Location: S~c~ Drillin~ Co~tractor Location, General General Housekeeping.~/,_Rig, D Well SiGn Well Representative~/~/,q~//-C P~it ~ Casing Set Representative ~4Y ACC~ATOR SYST~ Full Charge Pressure ~ Pressure After Closure Pump incr. clos. pres. 200 psig ~ miq~sec. Fu~l Charge Pr~sure Attaised:: ~min~sec. . _ psiE Controls: Master ~e~. Remote ~ Blinds switch cover Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge ~_ Flow Monitor Gas Detectors ROPE Stack ~~reventerO~ Pipe Rams (~)t~ Blind R~m_s CSoMe, Line Valves H.C.R. Valve Kill Line Valves Che'ck Valve ~/~- Test Results: Failures Test Pressure 3000 Kelly and Floor Safety Valves Upper Kelly ~K~"Test Pressure Lower Kelly ~M'~Test Pressure Ball Type Test Pressure Inside BOP Choke Manifold No. Valves No. flanges~-, Adjustable Chokes Hydrauically operated choke I./~L~ '---- 0 ' Test Time / hrs. ~D~,~/--~ Repair or Replacement of failed equipment to be made within ~/~ days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspectcr~ February 10, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3M-4 ARCO Alaska, Inc. Permit No. 87-15 Sur. Loc. 1227'FNL, 1713'FEL, Sec. 25, T13N, R8E, UM. Btmhole Loc. 1212'FSL, 549'FEL, Sec. 30, T13N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~y~ trulyfyo~?p, ? ~ Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery~ STATE OF ALASKA ALASKA C,_ AND GAS CONSERVATION CO, .... llSSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~3' Redrill E~[ lb. Type of welI. ExploratoryF1 StratigraphicTest[]~,DevelopmentOil,~ Re-Entry Deepen Service [] Developement Gas [] Single Zone/~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63', PAD 26' feet Kuparuk River Field Kuparuk River Oil Pod p3: Address 6A ~'[.° P~.~tbY 2Dle s i ~r~:t i °2n557 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1227'FNL, 1713'FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1362'FSL, 888'FEL, Sec.30, T13N, R9E, UM 3M-4 #8088-26-27 At total depth 9. Approximate spud date Amount 1212'FSL, 549'FEL, Sec.30, T13N, R9E, UM 03/06/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3M -399 80 ' MD 1227'@ Surface feet 25' (~ Surface feet 2560 (6499'TVD) feet 16. To be completed for deviated wells. 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth500 feet Maximum hole angle~~''° Maximum surface 2015 psig At total depth (TVD) 3154 psig ,. 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 4606' 35' 35' 4641 ' 3403' 1200 sx AS Ill & HF-EI:W 350 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 9946' 34' 34' 9980' 6499' 200 sx Class G(minimurr HF-EI:W TOC 5DO' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner 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 rCquirementsJ;i~ 21.1 hereby certi, J,C'~at/////~/~/)''''//'~~~-'¢~'4'4~///the foreg.qi~ ng is true and correct to the best of my knowledge Signed Title Regional Drill¢l~.~l En~ll~t~r Date Commission Use Only Permit Numb'er / I APl number I Approval date I See cover letter ? 7 '- 15- I 50-- cc ~. c! _ ~ I e, ~7 ;7I 0 2 / 1 0 / 8 7 I for other requirements . Conditions of approval Samples required [] Yes '~L No Mud log required [] Yes'~No Hydrogen sulfide measures [] Yes ~ No D. ir/ectional survey required ~ Yes [] No-- Required working pr. eCC~re fo~..,BOPJ-~.~21VJ,A ]~ 3M; [] 5M; [] 10M; [] 15M Other: //,;"'/,~.~// -/~~/~ by order of Approved by ~ ;, ,/,, ~ _.~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 / / / Sub~ / ;ate : , : , i , " .......... , .... i -i .... : i ....................... -,':: :": %: :-.'I-: :.: ,":::: ( :': :',::: :i ' ': :':: f:::: ':":':-:'"t-:': :-: [":: :'7 f: ::- /~--~ I ~ ~--~ ~v~ ~,l --~ ~ i ..... , ' ' ' ! ~ ' ;..i'-:;:-;-:;::~::.:I-::- :--i ~ ;.t ..... I . ' ...... t ..................... ~$- TI ~3 ,T~ -9780 -DEP, 688t. I . ' ! - PTI :f~ ~000 ..: , ' ~00 ..... ........ ! ~ o~"~v~ .... ' ~ ..... i - - - :i ....... , 't - ....... ~ ...... ~ I ' .... ~ I . , ~ I I ~ ~ ' ~ ~ ~ ~ ~ ~ ~ -; ~ i ~.i ~ · · , , i ..... ' ~ ,' i ' , , ' , : ~ , ~ , : : , ~ , T, . . -~ ......... ' : ~ : : ' , :~:. , t ' ' '~' r ] , bnn T ....... l ......... ' ' , ' . . : l~ , t, ' .... ~ ~ , '' ~' ~ ' ' ', ~ ~ L -- ' I , ; ~ + ~ . , , ' .......... , [ '" ........................................................... , ............ , ' : , , : '' 'I ' ~ 1 ' ' ' · ~ ' ' I ' ' ' I ' ' , ; , :~ , , : ~ ~ ~ : . , , : - -- ............. ' = ' ' '"' ' ; ~ '~- ~ , ' ' ~ ; I ' ' ' ' ' ~ ....... ~ ' ; 1 ' ' ; ~ ~ ~ ~ . ~ ' . · ~ , ~ ~-'-,' . , . [ ' "I, : DEC ' ' t .................. '' : ~ , i , ' '' 'i~ i 800 .FSO[ 700: 650 600~~ KUPARUK RI VER UNIT 20' D IVERTER SCHEMATIC J L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION, DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-~-86 < < 7 Fl g 5 4 > > DIAGRAM #1 .13-5/8" 5~30 PS~ RSRRA BOP STACK I. 16" - 2000 PSI TAI~CO STARTING NEAD 2. II" - 3000 PSI CASING HBAD 3. II" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE ~ KILL LIKES 6. 13-5/8" - 5000 PSI D~LE RAM W/PIPE R/~ ON TOP, BLIND RAMS ON BOTTCM. 7. 13-5/8" - 5000 PSI A~ ACO. IvtJLATOR CAPACITY TEST i. CHECK ~ FILL ACCI~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASS~ THAT ACCL~T~R PRESSl~ IS 3000 PSI WITH 1500 PSI D(~TREAM OF THE REGULATOR. 3. 08,SF_.RVE TI~E~, THEN CLOSE ALL UNITS SIMULTAt~OI~Y ~ RECORD THE TIhE A~D PRES,S~ RE~AINING AFTER ALL UNITS ARE CLOSF_D WITH CHARGING PLIVP OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LO/~ LIMIT IS 45 SECONDS CLOSING TIt~ ~ 1200 PSI RE]VIAINING PRESSURE. 13-5/8" BOP STACK TEST i. FILL BOP STACK ~ CHOKE MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCI< D~ SCRE~ IN WELLFF_AD ARE FULLY RETRACTED. SEAT TEST PLUG IN WELLHEAD WITH RUttING JT At~D RUN IN LOCK~ SCREWS. 3. CLOSE AltAR PRE'V~ER AI~ lVlAI~AL KILL A~D CHOKE LIkE VALVES ADdACENT TO BOP STACK. ALL OTHER VALVES ~ CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI ~ HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI ~ HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN A~ PREVENTER ~ MANUAL KILL ~ CHOKE LIkE VALVES. CLOSE TOP PIPE RAMS At~D HCR VALVES ON K~ILL ~ CHOKE LIKES. 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LIKES, AND CHOKES WITH A 250 PSI LOW A~ 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHCI<E THAT NQT /~ FULL CLOSING POSITIVE SEAL CHCKE. O~Y FUNCTION -[EST C~FS THAT DO NUI FULLY CLOSE. 8. OPEN TOP PIPE RAMS ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI /~ 3000 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK OUT RUt~I~ING JT A~D PULL OUT OF HOLE. I0. CLOSE BLIND RAMS At~D TEST TO 250 PSI /~ 3000 PSI. II. OPEN BLIND RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AND LIKES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAt~DPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI A~D 3000 PSI. 13. RECORD TEST IN=ORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN, AND SE~ TO DRILLING SUPERVISOR. 14. PERFORM CC~LETE BOPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15,1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psis. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13, Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plus back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE -.w. STIR ,,.-w. STIR _~ STIR SHAKERS . I [CLEANER, ' TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih CHECK LIST FOR NEW WEt.T. PERMITS rr~ AP£ROVE DATE (1) Fee ~ ~- -G-F? 1. (2) Loc (2 '~-'u 8) e 6. 7. 8. (3) '("~kru:9~]4f ~,-~-1"2 9. '13) 10. ,F~.~.,~f ;,- '~-,9 ""; 11. (10 and 13) 12. 13. (14 thru 72-)sT' (23 thru 28) (6) UI"HER ~,~, (29 thru 31) (6) Add: 14. 15. 16. 17. 18. 19. 20. 21. 22. YES Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Lease & Well No. NO - Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease number appropriate ............................ ~ Does the well have a unique name ~ ~~ .............. Is conductor string prOVided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandormmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o psig .. Does the choke nmnifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ 32. Additional requirements ............................................. g Geology: Enginee~ring: LCS -~.~ BEWj'. rev: 01/28/87 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 3~q-~ ~ g~ ~,~,~z ~g~'~ 3~4-~ 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. LIS T~PE V E!R IFIC.~T ION Li STIN,$ Vo 010.~02 VERIFICATION Li3TiNG PAGE 1 :::~ R=EL. Hr- AD ER. .,..,. ',E2VICE NAME :EDIT )ATE :87/03/24 )RIGiN : ',EEL NAME :1~9507 iONTINUATIQN ~ >REViOUS REEL : 'OMMENTS :EDIT LIS~ARCC 3M-~ KUP&RUK, APi m 50-0Z9-21697 .-'-,. TAPE HEA~ER ~-~- iERVlCE NAME :EDIT )~TE :87/03/24 ]RIG!N :7222 rAPE NAME : ~DNTINUATION ~ :01 ~REViOUS TAPE : ]DMMENTS :EDIT LIS~ARCO 3M-4 KUPARUK~ API ~ 50-OZg'-2169T ,-~- FILE HEADER :iLE NAME :EDIT o001 SERVICE NAME : ~ERSION ~ : ]ATE : qAXIMUM LENGTH : lOZ4 :I LE TYPE : ~REVIOUS FILE : ,-~, INFORM~TION RECORDS ~tNEM CONTENTS UNIT TYPE C,~T~ SIZE 'N : ARCO ALASKA, INC. 000 000 017 06~ 8N : 3M-4 000 000 004 055 :N : KUPARUK 000 000 007 065 RANG: BE 000 000 002 065 TOWN: 13N 000 000 003 065 SEC'T: 25 000 000 002 055 ?,DUN: NORTH SLOPE 000 000 011 065 STAT: ~LASKA 000 000 006 065 CTRY: USA 000 000 00'3 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE PRES: E 000 000 00! 065 -, .... COMMENTS .VP 010.~02 VE~I~!C~TICM LISTi~ PAG~ 2 S CHLUMA ALASKA CSMPU:TZNG CSNTER :OMPANY = ARCC ALASKA INC ~ELL = 3M-4 :IELD = KUPARUK :OUNTY = NCRTH $LJPE BOROUGH ~TAT~ = ALASKA JOB NUMEER AT AKCC: 72228 ~UN ~i, DATE LOGGED: 15-MAR-ST _DP: RICK KRUWELL :AS!NG : 9.625" @ 4675' - 6I'T SiZE : 8.5" TD 9976' tYPE FLUID : LSND ]ENSlTY = 10.2 LE/G RM = 3.48 ~ 70 DF ¢iSCDSiTY : 42 S RMF : 3.72 ~ 70 DF ~M = 9.0 RMC : 3.33 2 72 DF =LUiD LOSS : ~.6 C3 RM AT BHT = 1.729 ~ 148 D~ ~ATRiX SANDSTONE ~:~,:~ THIS DATA HAS N~T BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS VP OiO.HO2 VERIFiCATiON LISTING P~E ~ S CHLU ~18 = R GE q~ LOGS~ I N CL UO ¢ O_ '~ ! T r~ This M AGN ET r C. TgPE:. .,."- ::~ DUAL iNDUCTION SPHERICALLY FOCUSE2 LOG (DIL) '~ D~TA ~.VAILABLE: ~8~i' TG 4669' .,. ~:= FORMATION DENSITY COMPENSATEO LOG (FDN) ~;~ DATA AVAILABLE: 98i5' T~ q250'. -,-'" ~- COMPENSATED NEUTRON LCG (~DN) -,."' DATA AVAILABLE: 9791' TO 9250' '~-,. GAMMA RAY IN CASING (GR.CSG) .."' -. DATA AVAILABLE: 4858' TC 910 .... '~' ',~ '1' ',~ DATA FORMAT RECORD.-".. ~NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66. 0 4 1 66 1 8 4 73 80 9 4 65 .lin 16 1 66 0 1 66 0 )ATUM SPECIFICATION BLOCKS ~NEM SERVI~CE SERVICE UNIT API API AP1 API :FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. CDDE (OCTAL) ]EPT FT O0 000 O0 0 0 ~ 1 68 00000000000000 ~FLU DIL OHMM O0 220 O1 0 0 4 t 68 O00OO000000000 ELD DI~L OHMM O0 1ZO ~6 0 0 4 1 68 00000000000000 ,V? OlO.H02 VERIFiCATiOh LISTING iLM DIL ;? D!L ;R D!L 'ENS DIL ;R ,:ON 'ALi FON ~H05 FDN )RHO ~DN ~RAT FDN ~NRA FDN ~PHI ,:ON )PHi PON ~CNL FDN :CNL -~ON 'ENS PON ;R CSG 'ENS CSG ;'ALI ~NRA =CNL )EPT ~P ;ALi ~NRA :~C NL )EPT ~P ]ALI ~NRA :CNL ]EPT SP 2A L I RNRA ='C NL DEPT SP CALI RNRA ~CNL DEDT SP SALI CHMM O0 120 44 0 MV O0 010 Ol 0 GADI O0 310 O1 LB O0 835 21 0 G~Pi O0 310 Oi 0 iN O0 280 O1 0 G/C3 O0 350 02 G/C3 O0 356 O1 0 O0 ~20 O1 0 O0 000 CO 0 PU O0 890 O0 0 PU O0 890 00 0 CPS O0 330 31 0 CoS OO 330 30 0 L5 O0 835 21 O GAPI O0 310 O1 0 LB O0 835 Z1 0 9989.0000 SFLU -20,4588 GR 7,1641 RHOB 3,5703 NPHi 545.5000 TENS 9900,0000 SFLU -16.3750 GR 7,2813 RH05 3,6621 NPHI 537.0000 TENS 9800.0000 SFLU -24,4844 GR 7.8085 RHOB 3.8418 NPHI 528.0000 'TENS 9700,0000 SFLU -39.6563 GR 8,4219 RHO5 3.2207 NPHI 540,5000 'TENS 9600.0000 SFLU -69,3750 GR 8,1016 RHO5 2,7402 NPHi 1063.0000 'TENS 9500, 0000 SFLU -60.2500 GR 8,8281 RHO5 2.9692 ILO 107,5000 TENS 1.9600 DRHO 42,3340 DPHI 380,0000 GR 2.5825 ILD 89.3125 TENS 2,156.2 DRHO 45,5078 DPHI 290~.0000 GR 3,2876 ILO 91,3750 TENS 2.3891 DRHO 44,5801 DPHI 9750.0000 GR 6,8729 ILO 80.1250 TENS 2,3672 DRHO 37.7441 DPHi 918~,0000 GR 56,9000 ILO 44, 9687 TENS 2,2949 DRHG 28,9062 DPHI 9208,0000 GR 6,6790 ILD '79,8125 TENS 2,5781 DRHO . 380. 41. -999. 2904. O. 29. -999. . 9760. O, 17, -999, . 9184. O. 17. -999. 3 0 · 9208, --0 . 21, - 9'9' 9. . 9616. O. 7440 0000 0i56 826~ 2500 7575 0000 096:2 9312 2500 1237 0000 0977 0301 2500 2890 0000 0063 1484 2500 76~7 0000 0005 5277 2500 68 O0000gOOOOOOO0 ! 68 00000000000000 55 00000000000000 i 68 O000000OO00000 68 00000000000000 6:8 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 i 58 O00000000000CO i 68 O000000000000C I 68 00000000000000 i 68 OOO00000000000 1 5~ 00000000000000 I 65 00000000000000 ! ~8 O0000000OO0000 I 5~ O00000000000OO 73:62 I~LM 6.9541 0000 GR 79.8125 0054 NRAT 3,0449 ILM 2.5926 GR 89.3125 NRA'T 3.537t NCNL 1967.0000 T~NS -9'99.2500 ILM 3,19'76 GR 91,3750 NRAT 3.5136 NCNL 2029,0000 TENS -999.2500 ILM 6..23 67 GR 80.1250 NRAT 3.1953 NCNL 2064.0000 TENS -999. 2500 ILM 30.3833 GR 44.9687 NRAT 2.5348 NCNL 2914.0000 TENS -999.2500 'ILM 2.6569 GR 107.5000 NRAT 3.3555 NCN~L 1948.0000 TENS -999.2500 VP OlO.HO2 VERIFiCATiON LISTING P~GE 5 :NRA 3.8387 NPHI :CNL 666.5000 TENS ~EPT 9400.0000 SFLU ;m -23.~531 GR :ALi 8.9766 RH05 :NRA 4.1562 NPHZ :CNL 415.2500 TENS )EPT 9300,0000 SFLU ;P -25.3594 GR :ALI 8.9062 RHO5 INRA 4,0585 NPHi :CNL 430.5000 TENS )EPT 9200,0000 SPLU ;P -37,1562 GR ;ALI -999,2500 RHO~ ~NRA -999.2500 NPHI :CNL -999,2500 TENS )EPT 9100,0000 SFLU iP -40.2187 GR ;ALI -999,2500 RHD5 ~NRA -999,2500 NPHZ :CNL -999,2500 TENS )EPT 9000,0000 SFLU ~P -36.7500 GR ]ALI -999,2500 RHO~ ~NRA '-999,2500 NPHI :CNL -999,2500 TENS )EPT 8900,0000 SFLU iP -39.3438 GR :ALI -999,2500 RHO5 RNRA -999.2300 NPHI :CNL -999,2500 TENS 3EPT 8800,0000 SFLU SP -45,7500 GR :ALI -999,2500 RHOB ~NRA -999.2500 NPHI ~CNL -999.2500 TENS DEPT 8700,0000 SFLU SP -52,5938 GR CALI -999,2500 RHOB RNRA -999,2500 NPHI ~CNL -999,2500 TENS DEPT 8600,0000 SFLU SP -56.8750 GR CALl -999,2500 RHOB 34.3750 DP~I 9616.0000 GR 2.3529 ILD 116.8750 TENS 2.3086 DRHO ~8.6328 DPhi 9216.0000 ~R 1,7108 ILD 114,5625 TENS 2,3281 ORHO 52. 1484 DPHi 9080,0000 GR 2.2708 ILD 107,3750 TENS -999,2500 DRHO -999,2500 DPHZ --999.2500 GR 4,0867 ILD 120.2500 TENS -999,2500 DRHO -999.2500 DPHI '-999,2500 GR 4,2208 ILD 168,6250 TENS -999,2500 DRHO -999,2500 DP'HI -999.2500 GR 5.4290 ILO 236.0000 TENS -999.2500 ORHO -999,2500 DPHI -999.2500 GR 4.3226 !LD 113.5000 TENS -999,2500 DRH~ -999,2500 DPHI -999,2500 GR 4.,3006 ILO 120,0000 TENS -999.2500 DRHO -999,2500 DPHi -999.2500 GR 4,2819 I'LD 100.1250 TENS -999,2500 DRHD 4.365~ NCNL -999.2500 TENS 2.2426 ILM 9216,0000 GR 0,0083 NRAT 20.6992 NCNL -999.2300 TENS 1,6739 ILM 9080.0000 GR 0,0098 NRAT 19,5156 NCNL -999.2500 TENS 2,5119 ILM 9488,0000 GR -999.2500 NRA'T -999,2500 NCNL -999.2500 TENS 3,06t3 ILM 9304.0000 GR -'999,2500 NRAT -999,2500 NCNL -999.2500 TENS 3.5727 ILM 9376,0000 GR -9'99,2500 NRAT -999.2500 NCNL -999.2500 TENS 4,2231 ILM 8800,0000 GN -999,2500 NRAT -999.2500 NCN:L -999.2500 TENS 3,9517 ILM 8648,0000 GR -999,2500 NRAT '-99'9.2500 NCNL -999,2500 TENS 4,1781 ILM 8424,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 4.2560 iLM 8312.0000 GR -999.2500 NRA'T 2424.0000 -999.2500 2.2325 116.8750 3.8359 1727.0000 -999.2500 1.7363 114.5625 4.0195 1748.0000 -9'99.2500 2.5151 -999.2500 -999.2500 -999.2500 -999.2500 3.1564 -999.2500 -999,2500 -999,2500 -9'99.2500 3.6386 -999.2500 -999.2500 -999.2500 -999.2500 4.1765 -999,2500 -999,2500 -999.2500 -999.2500 3.8865 -999.2500 -999.2500 -999.2300 -999.2500 4.0377 -999.2500 -999.2300 -999.2500 -999.2500 4.1350 -999.2500 -999.2500 .VF OiO.HO2 VERIFICATION LiSTiNG PAGE 6 ~NR~ :CNL )EPT ;P 'ALI ]NRA :CNL )EPT ;ALI ~NRA :CNL DEPT ;P ;ALi ~NRA :CNL SEPT SP ;ALI RNRA =CNL DEPT SP SALI RNR4 =C NL DEPT SP ~ALI RNRA FCNL DEPT SP CALI RNRA FCNL DE PT SP CALl RNRA FCNL DEPT SP CALl -999.2500 NPHi -999.2500 TENS 8500.0000 SFLU -50.3750 GR -999,2500 RH05 -999,2500 NPHI -999,2500 TENS 8400,0000 SFLU -49.6250 GR -999,2500 RHOB -999,2500 NPHI -999,2500 TENS 8300.0000 SFLU -51.3750 GR -999.2500 RHO~ -999.2500 NPHI -999.2500 TENS 8200.0000 SFLU -36.0938 GR -999.2500 RHO5 -999.2500 NPHi -999,2500 TENS 8100:,0000 SFLU -39,0313 GR -999,2500 RH05 -999.2500 NPHI -999,2500 TENS 8000.0000 SFLU · -54.3750 GR -999.2500 RHOB -999.2500 NPHI -999.2500 'TENS 7900,0000 SFLU -79,6250 GR -999,2500 -999.2500 NPHI -999.2500 TENS 7800.0000 SFLU -51,0938 GR -999.2500 RHOB -999,2500 NPHI -999,2500 TENS 7700,0000 SFLU -68.3750 GR -999,2500 RHG~ -999.2500 DPHI -9'99.2500 GR 5.1592 ILO 97.9375 TENS -999.2300 DRHO -999,2500 DPHI -999.2500 GR 3.~606 iLO 104,5000 TENS -999,2500 ORHO -999.2300 DPHI -999.2500 GR 4.3899 ILD 104,6250 TENS -999.2500 ORHO -999,2500 DPHi -999.2500 GR !,8?2i iLD 90.4375 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR 1,9992 ILO 98,0625 TENS -'999.2300 ORHO -999,2500 DPHI -999,2500 GR 2,1581 ILO 83.5000 TENS -999.2500 DRHO -999.2500 DPHI -9'99.2500 GR 2,7887 I'LD 120,1250 TENS -9'99.2500 ORH3 -999.2500 DPHI -999.2500 GR 2,0094 ILO 85,1250 TENS -999,2500 DRHO -9'99. 2500 OPHi -999.2500 GR 3.0645 IL~ 153,6.250 TENS -999.2500 DRHO -999.2300 NCNL -999.2500 TENS 5.2~0 ILM 330~.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2300 TENS 3,3862 ILM 8352,0000 GR -999,2300 NRAT -999,2500 NCNL -999,2500 TENS 3,6322 iLM 8640.0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 1,8998 ILM 8424,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 2,1332 ILM 8920,0000 GR -999,2500 NRAT -999,2300 NCNL -999,2300 TENS 2,1612 ILM 8304.0000 GR -999,2500 NR~T -999.2500 NCNL -999.2500 TENS 3,0267 ILM 8296,0000 GR -999.2300 NRAT -999,2500 NCNL -999.2500 TENS 2,1340 iLM 8164.0000 GR -999,2500 NRAT -999.2500 NCNL -999.2500 TENS 2,9784 iLM 7768,0000 GR -999.2500 NRAT -999.2500 -999.2500 5.0253 -999.2500 -999.2500 -999.2500 -999,2500 3.3081 -999.2500 -999.2300 -999.2500 -999.2500 3.5149 -999.2500 -999.2500 -999.2500 -9'99.2500 1.8940 -999.2500 -999.2500 -999.2500 -999.2500 2.1108 -999.2500 -9'99.2500 -999.2500 -999.2500 2.1116 -99'9,2500 -999.2500 -999.2500 -999.2500 2.9877 -999.2500 -999.2500 -999.2500 -999.2500 2,I150 -999.2500 -999.2500 ,-999.2500 -999.2500 2.8719 -999.2500 -999.2500 VERIFICATION LISTING FAG5 '? NRA -999.2500 NP~i CNL -999.2500 'TENS )EFT 7600.0000 SFLU ;P -48.3438 SR 'ALi -999.2500 RH06 iNRA -999.2500 NPHi :CNL -999.2500 TENS )EFT 7500.0000 SFLU ;P -22.3281 GR ;ALI -999.2500 RH05 ~NRA -999.2500 NPHi :CNL -999,2500 TENS )EPT 7400.0000 SFLU ~P -45.5000 GR 'ALI -999.2500 RH35 ~NRA -999.2500 NPHI =CNL -999.2500 TENS 3EPT 7300.0000 SFLU ~P -4.3.4375 GR ",~,L I -999.2500 RH05 ~NRA -999.2500 NPH'i :CNL -999.2500 TENS DEFT 7200.0000 SFLU SP -42.2i87 GR CALl -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEFT 7100.0000 SFLU SP -52.7188 GR CALI -999.2500 RHO8 RNRA -999°2500 NP~I FCNL -999.2500 TENS DEFT 7000.0000 SFLU SP -35.3~750 GR CALl -999.2500 RH06 RNR~ -999.2500 NPHi FCNL -999.2500 TENS DEFT 6900.0000 SFLU SP -38.0000 GR CALI -999.2500 RHOB RNR~ -999.2500 NPHi FCNL -999.2500 TENS DEFT 6800.0000 SFLU SP -24.9844 GR CALi -999.2500 RH08 -9'29.2500 OPHi -999.2500 GR 2.35~8 ILD 130.2500 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR 2.0231 iLD 90.1230 TENS -999.2500 DRH8 -999. 2500 OPHi -999.2500 GR 3.2151 ILD 77.5525 TENS -999.2500 DRHJ -999.2300 DPHI -9'99.2500 GR 2.8233 iLO 109.4375 TENS -999.2500 DRHD -999.2500 DPHi -999.2500 GR 2.5740 ILD '98.9375 TENS -999.2500 ORHD -999.2500 DPHI -999.2500 GR 1.9364 ILO 106.6875 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 2.9485 110.2500 TENS' -999.2500 DRHO -999.2500 DPHZ -'999.2500 GR 2.6513 iLD 101.3125 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR 3.6732 ILD 111.6250 TENS -999. 2500 CRHO -959.2500 NCNL -999.2500 TENS 2.3718 iLM 7760.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2.2050 ILM 8240.0000 GR -999.2500 NR~T -'999.2500 NCNL -999.2500 TENS 3.2897 ILM 8028.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 2.8448 ILM 7504.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2.7127 tLM 7484.0000 GR -999.2500 NRA~T -999.2500 NCNL -999.2500 TENS 2.1388 iLM 7312.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3.0956 ILM 7205.0000 GR -999.2500 NR~T -999.2500 NCNL -999.2500 'TENS 2.9093 ILM 7032.0000 GR -999.2500 NRAT -999.2500 NCN<L -999.2500 TENS 3.9321 iLM 7008.0000 GR -999.2500 NRAT -99~.2300 -999.2500 2.2910 -999.2500 -999.2500 -999.2500 -999.2500 2.1379 -999.2500 -999.2500 -999.2500 -999.2300 3.17~9 -999.2500 -999.2300 -999.2500 -999.2500 2.7761 -999.2500 -999.2500 -999.2500 -999.2500 2.6189 -999.2500 -999.2500 -999.2500 -999.2500 1.9916 -999.2500 -999.2500 -999.2500 -999.2500 3.0062 -999.2500 -999.2500 '-999.2500 -999.2500 2.7596 -999.2500 -999.2500 -999.2500 -999.2500 3.7723 -999.2500 -999.2500 .VP OIO.HO2 VERIFICATION LISTING :CNL )EPT ~P 'ALi ~NRA :CNL )EPT 'ALI ~NRA :CNL )EPT ~P 'ALI ~NRA :CNL )E PT :ALI ~NRA :CNL ]EPT SP SALI RNRA =CNL OEPT SP CALI RNRA FCNL DEPT SP CALI RNRA ~CNL DEPT SP C~Li RNRA FCNL DEPT S? C~LI -999.2500 NPHI -999.2500 TENS 6700.0000 SFLU -26,8125 GR -999,2300 RHJB -999,2300 NPHi -999.2500 TENS 6600,0000 SFLU -43,2187 GR -999.2300 RHGB -999,2500 NPHI -999.2500 TENS 6500.0000 SFLU -70,1250 GR -999,2500 RHO5 -999,2500 NPHI -999,2500 'TENS 6~00,0000 SFLU -39,8750 GR -999.2500 RHO~ -999,2500 NPHI -999.2300 TENS 6300,0000 SFLU -35,2500 GR -999,2500 RHO6 -:999,2500 NPHI -999.2500 'TENS 6200.0000 SFLU -38.8750 GR -999.2500 RH08 -999.2500 NPHI -999.2500 TENS 6100..0000 SFLU -56,5938 GR -999.2500 RHO8 -999,2500 NPHI -999,2500 TENS 6000,0000 SFLU -50,8750 GR -999.2500 -999.2500 NPHi -9:99.2500 TENS 5900,0000 SFLU -60,6250 GR -999,2500 RH35 -999.2500 DPHI -999.2500 GR 2.8327 ILD 95.8125 TENS -999,2300 DRHO -999,2500 DPHi -999.2500 GR 3,5843 ILD 90,2500 TENS -999.2500 DRHO -999,2500 DPHI -999,2500 GR 2.899~ ILO 87.3125 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3,7716 ILO 100,5625 TENS -999,2500 ORHO -999,2500 DPHI -999,2500 GR 2.8045 ILD 114,000.0 TENS -999.2500 DRHO -999,2500 DPHI -999,2500 GR 3,2196 ILO 108,31.25 TENS -999,2500 DRHO -999,2300 DPHI -9:99.2500 GR 2,5354 ILD 105,5000 TENS -999,2500 DRHO -999,2500 OPHI -999. 2500 GR 2,5606 ILD 9'7.93T5 TENS -999,2500 DRHO -999.2500 DPHi -999,2500 GR 2,4885 ILD 85. 3125 TENS -9}9. 2500 DRHO -999.2300 NCNL -999.2300 TENS 3.1112 ILM 6888.0000 GR -999.2300 NRAT -999,2500 NCNL -999.2500 TENS 3,7001 ILM 67~,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 3.2552 ILM 6580,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2300 TENS 4,1955 ILM 6404,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 2,9478 !LM 6228,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 3,5693 ILM 5860,0000 GR -999.2500 NRAT -999,2500 N:CNL -999,2500 TENS 2,9011 ILM 6040.0000 GR -999:,2300 NRAT -999.2500 NCNL -999,2500 TENS 2.9519 ILM 6068.0000 GR -999.2300 NRAT -999,2500 NCNL -999,2~00 TENS 2,9325 ILM 5808.0000 GR -999.2500 NRAT -999.2500 -999.2500 2.9935 -999.2500 -999.2500 -999.2500 -999.2500 3.4978 -999.2500 -999.2500 -999.2500 -999.2500 3,0977 -999,2300 -999,2500 -999.2500 -999.2500 3,8670 -999.2500 -999,2500 -999,2500 -999,2500 2,8165 -999,2500 -999.2500 -999,2500 -999.2500 3.3907 -999,2500 -999,2500 -999,2500 -999,2500 2,7575 -999,2500 -999.2500 -999.2500 -999.2300 2,7871 -999.2500 -999.2500 -999.2500 -999.2500 Z.7827 -99:9.2500 -999.2500 .VO 010.H02 VERiFICATICN LISTING P'AG~ 9 INRA -999.2300 NPHi :CNL -999.2500 TENS )EPT 5800.0000 SFLU ;F -74.3750 GR :ALI -999,2500 RHO5 INRA -999.2500 NPHI :CNL -999,2500 TENS )EPT 5700,0000 SFLU ;P -81,2500 GR ~ALI -999.2500 RH05 ~NRI -999,2500 NPHI :CNL -999,2500 TENS )EPT 5600,0000 SFLU ~P -7,6250 GR :AL! -999,2500 RH05 ~NRA -999,2500 NPHI :CNL -999,2500 TENS )EPT 5500,0000 SPLU 3P -16,98.87 GR ~4LI -999,2300 RH06 {NR4 -999,2500 NPHi =CNL -999. 2500 TENS 3EPT 5400,0000 SFLU SP -35.8750 GR 2AL! -999,2500 RHO5 ~NRA -999,2500 NPHi :CNL -999.2500 TENS 3EPT 5300,0000 SFLU SP -46,4688 GR ;ALi -999,2500 RHOB RNRA -999, 2500 NPHi FCNL -999,2500 YENS DEPT 3200.0000 SFLU SP -75.8750 GR CALl -999,2500 RHO5 RNRA -999,2500 NPHI FCNL -99:9,2500 TENS DEPT 5100,0000 SFLU SP -60..0000 GR CALi -999.2500 RH05 RNRA -999.2500 NPHZ FCNL -999,2500 'TENS DEPT 5000.0000 SFLU SP -51.2187 GR CALl -999,2500 RH~ -999,2500 -999.2500 2.7346 I02.0625 -999.2500 -999.2500 -999.2500 2.7808 100.5525 -999.2500 -999.2500 -999.2500 3.2784 98.3125 -999.2500 -9'99.2500 -999.2500 4,2634 90.8125 -999,2500 -999,2500 -999.2300 3.9293 97.4375 -999.2300 -999.2500 -999.2500 4,4095 97,1875 -999,2500 -999,2500 '-999.2500 3.6'778 86.6250 -999.2500 -999.2500 -999.2500 3.7324 104.2500 -999.2500 -999.2500 -999.2500 4.1556 110,6875 -999,2500 DPHI GR TENS DRHO GR iLO TENS DRHO DPHi GR ILD TENS DRHO GR iLO TENS DRH~ DPHi GR ILD TENS DRHO DPHI GR ILD lENS DRHO DPHI. GR ILO TENS DRHO GR ILD TENS DRHO DPHi GR ILD TENS DRHO -999.2300 NCNL -999.2500 TENS 3.0925 ILM 3628.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3,0089 ILM 5672,0000 GR -999,2300 NRAT -999,2500 NCNL -999,2500 TENS 3,6222 ILM 5508,0000 GR -999,2300 NRAT -999,2500 NCNL -999,2300 TENS 5,0348 ILM 5~60,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 4,5831 ILM 5268,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 5,1730 iLM 520~,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 4.2178 iLM 5128.0000 GR -999,2300 NRAT -999,2500 NCNL -'999,2500 YENS 3,99~2 iLM 4992,0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4,2290 ILM 4752.0000 GR -999.2500 NRA'T -999.2500 -999.2500 Z.90~8 -999.2500 -999.2500 -999.2500 -999.2500 2.8851 -999.2500 -999.2300 -999.2500 -999.2500 3,.~10t -'99'9.2300 -999.2500 -999.2500 -99'9.2300 4.5656 -999.2500 -999.2500 -999.2500 '-999.2500 4.2874 -99'9.2500 -99'9.2500 -999.2500 -999.2500 4.7808 -999.2500 -999.2500 -999.2500 -999.2500 3.8921 -999.2500 -999.2300 -999.2500 -999.2500 3.8218 -999.2500 -999.2500 -999.2500 -999.2500 4,1701 -999,2500 -999,2500 VP OIO.HO2 VERIFiCATiON LiSTiNG PAGE i0 N~ -999.2500 NPNI GNL -999.2500 TENS EPT 4900.0000 SFLU P -19.1094 GR ALI -999.2500 RH05 NR6 -999.2500 NPHI CNL -999.2500 TENS ,EPT 4800.0000 SFLU ,P -11.4375 GR ,ALI -999.2300 RHO5 :NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 4700.0000 SFLU ;P -25.2187 GR 'ALi -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 4800.0000 SFLU ;P -999.2500 8R ;ALi -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 4500.0000 SFLU ~P -999.2500 GR 2ALI -999.2500 RHOB ~NR~ -'999.2500 NPHI :CNL -999.2500 TENS DEPT 4400.0000 SFLU SP -999.2500 GR :ALi -999.2500 RHOB ~NRA -999.2'500 NPHI =CNL -999. 2500 TENS 3EPT ~300.0000 SFLU SP -999. 2500 GR ,,ALI 999. 2500 RHO5 RNRA -999.2500 NPHi :CNL -999.2500 TENS DEPT 4200.0000 SFLU SP ,-999.2500 GR CALI -999.2500 RHO~, RNRA -999.2500 NPH! FCNL -999.2500 TENS OEPT 4100.0000 SFLU SP -999.2500 GR CALl -9'99.2500 RH06 -999.2500 DPHi -999.2500 GR 3.8728 ILD 92.5523 TENS -999.2500 -999.2500 DPHZ -999.2500 GR 4.1266 ILD 95.4375 TENS -999.2500 DRMO -999.2500 OPHi -99~.2500 GR 4.8111 ILO 88.1250 T:NS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -'999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 GR -99'9.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 GR -999.2500 ILO -999.2500 TENS -9'99.2500 DRHO -999.2500 DPHi -999.2500 GR -999.2500 ltd -999.2500 TENS '-999.2500 DRHO -999.2500 D~HI -999.2500 GA -999.2500 iLD -999.2500 TENS -999.2300 O~NO -999.2500 NCKL -999.2500 TENS 4.6497 ILM 4968.0000 GR -'999.2500 NRAT -999.2500 NCNL -999.2500 T~NS 4.6723 ILM 4412.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.3~08 ILM *932.0000 GR -999.2300 NRAT -999.2500 NCNL 93.8750 TENS -999.2500 ILM -999.2300 GR -'999.2300 NRAT -999.2500 NCNL 41.9375 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 55.9062 TENS -999.2500 iLM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 56,9687 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 50.0000 TENS -9'99.2500 iLM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 46.1250 TENS -999.2500 !LM -999.2500 GR -999.2500 NRAT -999.2500 -999.2500 4.3062 -999.2500 -999.2500 -999.2500 -999.2500 4.3182 -999.2500 -999.2300 -999.2500 -999.2500 ~.6981 -999.2500 -999.2500 -999.2500 4348.0000 -999.2500 -999.2500 -999.2500 -999.2500 4324.0000 -999.2500 -999.2500 -999.2500 -999.2500 4408.0000 -999.2500 -999.2500 -999.2500 -999.2500 4332.0000 -999.2500 -999.2500 -999.2500 -999.2500 4252.0000 -999.2500 -999.2500 -999.2500 -999.2500 ~244.0000 -999.2500 -999.2500 -999.2500 YP 010 HO2 VERTFIC~T~ON LiSTiNG PAG~ 11 ~NRA :CNL )EPT ;P ~ALI (NRA :CNL )EPT ;P 'ALZ ~NRA :CNL DEPT SP 'ALI ~NRA =CNL DE PT 3P CALl ~NRA :C NL DEPT SP CALI RNRA FCNL DEPT SP CALl R'NRA FCNL DEPT SP CALi RNRA FCNL DEDT SP CALZ RNRA FCNL DEPT SP CALI -999.2500 NPHI -999.2500 TENS 4000,0000 SFLU -999.2500 GR -999.2500 RHOB -999,2500 NPHi -999.2500 TENS 3900.0000 SFLU -999.2500 GR -999,2500 RHOB -999.2500 NPHI -999,2500 TENS 3800,0000 SFLU -999,2300 GR -999,2500 RHO5 -999,2500 NPHZ -999.2500 TENS 3700,0000 SFLU -999,2500 GR -999,2500 RHOB -999.2500 NPHI -999.2500 TENS 3600,0000 SFLU -999,2300 GR -999,2300 RHOB -999,2500 NPHi -999,2500 TENS 3500,0000 SFLU -999,2500 GR -999,2500 RHO6 -999.2500 NPHi -999,2500 TENS 3400.0000 SFLU -999.,2300 GR -999,2500 RHO8 -999.2500 NPHI -999.2500 TENS 3300.0000 SFLU -999.2500 GR -999,2500 '-999,2500 NPHii -999.2300 TENS 3200.0000 SFLU -999.2500 GR -999.2500 RHO5 -999.2500 OPHI -999.2500 GR -999,2500 ILO -999.250C TENS -999,2500 CRHJ -999.2500 DPHi -999,2500 GR -999.2500 ILC -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR -999.2500 ILD -999.230C TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 iLD -999.2500 TENS -999.2500 DRHO -999.2300 DPMI -999.2500 GR -999.2500 ILO -999. 2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 GR '-999.2500 ILO -999,2500 TENS .-999.2500 DRHO -999.2500 DPHI -999.2500 GR -999,2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999,2500 GR -999..2500 ILO -999,2500 TENS -999,2300 DRHO -999. 2500 DPHi -99'9. 2500 GR -999,2500 ILD -999,2500 TENS -999.2500 CRHO -999.2300 NCNL 5~,5938 TENS -999,2500 iLM -999.2500 GR -999,2500 NRAT -99'9.2500 NCNL 53.2187 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 36.5938 TENS -999,2300 iLM -999,2300 GR -999,2300 NRAT -999,2500 NCNL 52,8125 TENS -999,2300 iLM -999,2500 GR -999.2500 NRAT -999.2500 NCNL 48,6875 TENS '-999.2500 ILM -99'9.2500 GR -999.2500 NRAT -999,2500 NCNL 51.7t88 TENS -99~.,2500 ILM -999.2500 GR -999.2500 NRAT -999,2500 NCNL 51,8~37 TENS -999,2500 ILM -9'99.2500 GR -999.2300 NRAT -999,2500 NCNL 40.6875 TENS -999,2500 ILM -999,2500 GR -999.2500 NR~'T -999,2500 NCNL 32.8750 TENS -999,2500 iLM -999.2500 GR -999,.2500 NRAT - 999.2500 ~108.0000 -999.2500 -999.2300 -999.2500 -999.Z500 4144.0000 -999.2500 -999.2500 -999.2500 -999.2500 4040.0000 -'999.2500 -999.2500 -999.2500 -999.2500 ~070.0000 -999.2500 -999.2500 -999.2500 -999.2500 3890.0000 -999.2500 -999.2500 -999.2500 -999.25'00 3724.0000 -999.2500 '-999.2500 -999.,2500 -999.2500 3640.0000 -999.2500 -999.2500 -999.2500 -999.2500 3580.0000 -999.2500 -999.2500 -999.2500 -999.2500 3500.0000 -999.2500 -999.2500 -999.2500 VP OlO.H02 VERIFiCATZON LISTING P~GE 12 NR~ -999.2500 NPHI CNL -999.2500 TENS ,EPT 3100.0000 $FLU P -999.2500 GR :ALi -999.2500 RH03 ,NRA -999.2500 NPHI :CNL -999.2500 TENS ~EPT 3000.0000 SFLU ;P -999.2300 GR 'ALI -999.2500 RHO5 INRA -999.2500 NPHI :CNL -999,2500 TENS )EPT 2900.0000 SFLU ;P -999.2500 GR :ALi -999.2500 RHOB ~NRA -999,2500 NPHI :CNL -999.2500 TENS )EPT 2800.0000 SFLU iP -999.2500 SR ;ALi -999.2300 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS ]EPT Z?O0.O000 SFLU ~P -999.2500 GR ;ALI -999.2500 RHO8 ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 2600.0000 SFLU SP -999.2500 GR ;ALI -999.2500 RHO5 ~NRA -999.2300 NPHI :CNL -999.2500 TENS 3EPT 2500.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO8 RNRA -999.2500 NPHI ;CNL -999.2500 TENS DEPT 2400.0000 SFLU SP -999.250'0 GR CALl -999.2500 RHOB RNR4 -999.2500 NPHI FCNL -999.2500 TENS DEPT 2300.0000 SFLU SP -999.2500 GR CALI -999.2300 RHOB -999.2500 DPHi -999.2500 GR -999.2500 iLO -999.2300 TENS -999.2500 DRHO -999.2500 DPHI -999.2300 GR -99'9.2500 ILD -999.2500 TENS -999.2500 DR~G -999.2500 DPHI -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRH:O -999.2500 DPHI -999.2500 -999.2500 iLO -999.2500 TfNS -999.2500 DRHO -999.2500 DPHi -999.2500 GR -999.2500 ILO -999.2500 TENS --9'99.2300 DRHO -999.2500 DPHI -999.2500 GR -999'.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRH'O -999.2500 DPHI -999.2500 GR -999.2500 !LD -999.2500 TENS -999. 2500 DRHO -999.2300 NCNL 36.8123 TENS -999.2500 ILM -999.2300 GR -999.2500 NRAT -999.2300 NCNL 24.0313 TENS -999.2500 iLM -999.2500 GR -999.2300 NRAT -999.2500 NCNL 41.8125 TENS -999.2300 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 41.8437 TENS -999.2500 iLM -999.2500 GR -999.2300 NRAT -999.2300 NCNL 47.9687 TENS -999.2500 iLM -999.2500 GR '-999..2500 NRAT -999.2500 NCNL 43.8125 TENS -999.2500 ILM -99!9.2500 GR -999.2500 NRA'T -999.2500 NCNL 36.9375 TENS -999.25,00 ILM -9'99.2500 GR -999.2500 NRAT -999.2500 NCNL 42.~688 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2300 NCNL 34.0938 TENS -999.2300 iLM -999.2300 GR -999.2300 NRAT -999.2500 3400.0000 -999.2500 -999.2500 -9~9.2500 -999.2500 3320.0000 -999.2500 -999.2500 -999.2500 -999.2500 3324.0000 -999.2500 -999.2500 -999.2300 -999.2500 3214.0000 -999.2500 -999.2500 -999.2300 -999..2500 3150.0000 .-999.2500 -999.2500 -999.2500 -999.2500 3150.0000 -999.2500 -999.2500 -999.2500 -999.2500 316~.0000 -999.2500 -999.2500 -999.2500 -999.2500 3140.0000 -999.2500 -999.2500 -999.2500 -999.2500 3064.0000 -99'9.2500 -999.2500 -999.2500 .VP OlO.H02 VE~IFIC&TiON LISTiN~ PaG~ 13 [NRC -999.2500 NPHI :CNL -99'9.2500 TENS )EPT 2200.0000 SFLU ;P -999.2500 SR :ALI -999.2500 RHO6 iNRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 2100.0000 SFLU ;P -999.2500 GR ]~Li -999.2500 RHG5 ~NRA -999.2500 NPHi :CNL -999.2500 TENS )EPT 2000.0000 SFLU ~P -999.2500 GR :ALI -999.2500 RHO5 ~NRA -999.2500 NPHI =CNL -999.2500 TENS )EPT 1900.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO5 RNRA -999.2500 NPHI FCNL -999°2500 TENS DEPT 180:0.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO5 RNRA -999,2500 NPHI FCNL -999,2500 'TENS DEPT i?O0.O000 SFLU SP -999.2500 GR CALl -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT 1600.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO~ RNR~ -999,2500 NPHI FCNL -999.2500 TENS DEPT 1500.0000 SFLU SP -999.2500 GR CALl -999.2500 RH08 RNRA -999.2500 NPHi FCNL -999.2500 TENS DEPT 1400.0000 SFLU SP -999.2500 GR CALl -999.2500 RHOB -999.2500 DPml -999,2500 GR -999.2500 iLO -999.2500 TENS -999.2500 DRHO -999.2300 DPHi -999.2500 GR -999.2500 iLD -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR -999.250'0 iLD -999.2500 TENS -999.2500 DRHO · -999.2500 DPHI -999.2500 GR -999.2500 ILO -999.2500 TSNS -999.2500 ORHO -999,2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHD -999.2500 DPHi -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR -999.2500 ILO -'999,2500 TENS -999.2500 ORHO -999.2500 DPHI -999,2500 GR '-9'99.2500 iLO -999.2500 TENS -999.2500 DRHS -999.2300 NCNL 34.2500 TENS - 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