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Home My WebLink About198-203CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF2 Subject:10-426 form for 2T-pad SI non-witnessed MIT-IA"s 6-15-25 Date:Monday, June 16, 2025 9:52:34 AM Attachments:image001.png MIT KRU 2T PAD SI TESTS 06-15-25 .xlsx Morning, Please see the attached 10-426 form from the 2T-pad SI non-witnessed MIT-IA’s that was performed on 6-15-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .587 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982430 Type Inj N Tubing 293 2530 2430 2410 Type Test P Packer TVD 2789 BBL Pump 2.6 IA 310 2530 2440 2410 Interval 4 Test psi 1500 BBL Return 2.3 OA n/a n/a n/a n/a Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982030 Type Inj N Tubing 3 69 79 77 Type Test P Packer TVD 3009 BBL Pump 0.5 IA 280 1810 1750 1735 Interval 4 Test psi 1500 BBL Return 0.4 OA 550 750 725 725 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2T Pad Non-witnessed Cook/Sheets 06/15/25 Notes: Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:CMIT T x IA plug in hole and open pocket in tubing. Notes: 2T-209 2T-210 Form 10-426 (Revised 01/2017)2025-0615_MIT_KRU_2T-210 9 9 9 9 999 99 99 9 9 -5HJJ 2T-210 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5340' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/7/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 5302' 121'121' 5337' 84'16" 7 5/8" 5 1/2" 4359' Length TVD Burst 4802' MD 2789' 3239' 4397' 3275' PRESENT WELL CONDITION SUMMARY 5020' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025569 198-203 P.O. Box 100630, Anchorage, Alaska 99508 5010320273-0000 ConocoPhillips Alaska, Inc. KRU TABS 2T-210 Kuparuk River/Tabasco Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3052- 3062' Perforation Depth TVD (ft):Tubing Size: 4887'-4907' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 N/A N/A N/A N/A Size Authorized Signature: 7/21/2021 3 1/2" Perforation Depth MD (ft): L-80 m n P s 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:51 am, Jul 07, 2021 321-339 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.07 06:57:21-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter 50-103-20273-00-00 VTL 7/14/21 ext conductor X X DSR-7/9/21 10-404 Photo document pre and post extension SFD 7/7/2021 JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 12:47:30 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 07 July 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2T-210 (PTD 198-203) to extend conductor. Summary: Conductor has subsided or well has grown 8” or more so we would like to add conductor to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.07 06:56:53-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 8” or more Casing Strings Casing Description CONDUCTOR String O... 16 String ID ... 15.062 Top (ftKB) 37.0 Set Depth (f... 121.0 Set Depth (TVD) ... 121.0 String Wt... 62.58 String ... H-40 String Top Thrd Welded Casing Description SURFACE String O... 7 5/8 String ID ... 6.750 Top (ftKB) 37.4 Set Depth (f... 4,396.6 Set Depth (TVD) ... 2,826.2 String Wt... 29.70 String ... L-80 String Top Thrd BTCM Casing Description PRODUCTION 5.5"x3.5" @ 4811' String O... 5 1/2 String ID ... 4.950 Top (ftKB) 34.7 Set Depth (f... 5,337.0 Set Depth (TVD) ... 3,274.0 String Wt... 15.50 String ... L-80 String Top Thrd BTCM Tubing Strings Tubing Description TUBING String O... 3 1/2 String ID ... 2.992 Top (ftKB) 32.5 Set Depth (f... 4,802.4 Set Depth (TVD) ... 3,010.2 String Wt... 9.30 String ... L-80 String Top Thrd EUE-8rd Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 32.5 32.5 0.52 HANGER FMC TUBING HANGER 3.500 4,761.9 2,989.9 60.36 NIPPLE CAMCO DS NIPPLE w/NO GO PROFILE 2.812 4,800.6 3,009.3 60.14 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.968 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Description Comment Run Date ID (in) 4,975.0 3,095.2 60.73 RETAINER CEMENT RETAINER 8/6/1999 5,020.0 3,117.5 59.90 PLUG BRIDGE PLUG 6/25/1999 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 4,887.0 4,907.0 3,052.2 3,061.9 TABASCO, 2T-210 10/9/1999 6.0 IPERF 2.5" HSD, 60 deg. phase Cement Squeezes Top (ftKB) Btm (ftKB) Top Depth (TVD) (ftKB) Btm Depth (TVD) (ftKB)Description Start Date Comment 4,820.0 4,830.0 3,019.0 3,024.0 Cement Squeeze 7/21/1999 4,984.0 4,990.0 3,099.6 3,102.6 Cement Squeeze 6/25/1999 Notes: General & Safety End Date Annotation 11/26/1999 NOTE: Several pieces of cement sheath recovered when gauges pulled. 6/21/2001 NOTE: FCO RECOVERED CLAY, ROCKS & MUD @ 4827' RKB - LINER DAMAGE? 12/14/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NONEWell Config: - 2T-210, 2/6/2012 8:30:43 AM Schematic - Actual TD, 5,340 PRODUCTION 5.5"x3.5" @ 4811', 35-5,337 PLUG, 5,020 SQZ PERFS, 4,984 RETAINER, 4,975 IPERF, 4,887-4,907 SQZ PERFS, 4,820 SEAL ASSY, 4,801 NIPPLE, 4,762 GAS LIFT, 4,710 SURFACE, 37-4,397 CONDUCTOR, 37-121 HANGER, 33 Annotation Last Tag: Depth (ftKB) 4,829.0 End Date 5/26/2005 Annotation Rev Reason: WELL REVIEW Last Mod ... osborl End Date 2/6/2012 KUP KB-Grd (ft) 42.60 Rig Release Date 12/5/1998 Annotation Last WO: End Date 2T-210 H2S (ppm) Date Mandrel Details Stn Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com... 1 4,709.7 2,965.0 62.99 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 4/25/1999 ... TD Act Btm (ftKB) 5,340.0 Well Attributes Wellbore API/UWI 501032027300 Field Name TABASCO Well Status INJ Max Angle & MD Incl (°) 65.14 MD (ftKB) 4,651.48 O 116430 Regg, James B (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, June 7, 2017 9:44 AM 617it 7 To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg,James B (DOA); DOA AOGCC Prudhoe Bay Subject: Recent MIT's performed at KRU Attachments: MIT KRU 2T PAD pg 1 06-05-17.xlsx; MIT KRU 2T PAD pg 2 06-05-17.xlsx; MIT KRU 21-210 and 217 Non witnessed 06-05-17.xlsx Attached are the test forms of the recent MIT's performed at KRU. Please let me know if you have any questions. Brent Rogers 1 Kelly Lyons I /� NSK Well Integrity Supervisor CPF 1 & 2 -- I l tA2v1W-S5c'r/ '4c1S 6L 5. ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 C Cell Phone (907) 394-0402 ilNWELLS TEAM Conoci taps SCANNED JUL 1 4 2017 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recloaalaska.00vs AOGCC.Inspectors2(alaska.aov phoebe.brooksaalaska.aov chris.wallaceaalasska.gov OPERATOR: ConocoPhillips Alaska Inc, ' 61 e11 6!- FIELD/UNIT/PAD: Kuparuk/KRU/2T Pad l DATE: 06/05/17 OPERATOR REP: Phillips/Duffy AOGCC REP: Well 2T-210 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982030 ' Type Inj N - Tubing 550 650 - 640 640 Type Test P Packer TVD 3009 BBL Pump 0.4 - IA 260 2000 - 1940 - 1930- Interval 4 ,/ Test psi 1500 - BBL Return 0.6 ' OA 350 575 - 550 - 550 . Result P ✓ Notes: AOGCC inspector Lou Laubenstein waived right to witness i Well 2T-217A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000740 Type Inj N Tubing 100 100 100 100 Type Test P Packer TVD 3007 BBL Pump 7.6 IA 0 1890 1820 1790 Interval 4 Test psi 1500 BBL Return 7.7 OA N/A N/A N/A N/A Result P Notes: AOGCC inspector Lou Laubenstein waived right to witness ***single casing well*** Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 2T-210 and 217 Non witnessed 06-05-17 2-CDS91— WELLLOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 iat/207Gi BENDER RE: Static Bottom Hole Pressure Record: 2T-210 Run Date: 11/18/2015 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 2T-210 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20273-00 Static Bottom Hole Pressure Record(Field Print) 1 Color Log 50-103-20273-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:, e , /` .t XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by: Beverly Mildred D'areth NaNa~ Lowell Date: Is~ ,~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ ConocoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~_! t_. `~ ~~ 2 01 ii ~iM~~kB C!A ~ Gas C~ Ct~t~ttission ~! tiG~rht3Q~ J ~~ V` /~•~~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with 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 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped July 11th, 12th, 13th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16110 2T_ 3H PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2T-22 50103202240000 1950860 8" n/a 8" n/a 3.8 7/12/2010 2T-23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010 2T-27A 50103202170100 2090900 7" n/a 7" Na 1.7 7/12/2010 2T-32 50103202180000 1950490 36" n/a 36" n/a 11.9 7/12/2010 2T-37 50103202270000 1951010 22" n/a 22" n/a 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" Na 8" n/a 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T-208 50103205180000 2051870 13" n/a 15" n/a 2.5 7/13/2010 2T 210 50103202730000 1982030 18" Na 18" Na 5.1 7!122010 2T-217A 50103203340100 2000740 8" n/a 8" n/a 1.7 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/112010 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ è.d},&,tJ7/Cn P.I. Supervisor ( l 7 DA TE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 2T-210 KUPARUK RIV U TABS 2T-210 03 \C\~~ ';)J FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~/2_· Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TABS 2T-2IO API Well Number: 50-103-20273-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603I50242 Permit Number: 198-203-0 Inspection Date: 6/2/2007 ,/ ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-210 Type Inj. N TVD 3009 IA 1000 I 2520 I 2500 2500 P.T.D 1982030 TypeTest SPT Test psi 1500 OA 0 I 0 I 0 0 Interval 4YRTST P/F P j Tubing 700 700 I 700 700 Notes: This Well is a long term shut in and should be retested if it is placed on injection. ./ ~~ED JUN ~ 1 Z007 Wednesday, June 06, 2007 Page I of I ( MEMORANDUM ¡,'. , State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner I . (\3 SUBJECT: Mechanical Integrity Test THRU: Jim Regg~¿'-4{). II \ 1ß u.; Conoco Phillips P.I. Supervisor II 2T Pad KRU DATE: November 1 2003 FROM: Chuck Scheve Petroleum Inspector NON. CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 2T -32 Type Inj. N TV.D. 5736 Tubing 3600 3600 3600 3600 Interval 4 P.TD. 195-049 Type test P Test psi 1434 Casing 150 2460 2400 2400 P/F P Notes: Well 2T-21 0 Type Inj. N TVD. 3009 Tubing 600 600 600 600 Interval 4 P.TD. 198-203 Type test P Test psi 752 Casing 0 1940 1920 1920 P/F P Notes: Well Type Inj, T.VD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. T.VD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj, TVD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: ' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to Conoco Phillips 2T Pad in the KRU and witnessed the routine 4 year MIT on wells 2T -32 and 2T -210. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then perfonned with both wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 2 hours cc: ~t~¡~NE[)! DEC 3 12003 MIT report form 5/12/00 L.G. MIT KRU 2T 11-1-03 CS.xls 11/20/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 11/01/03 Sauvageau / Brake C Scheve Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. I1950490 TypeTest Test psiI 1500 I Casing I 1501 24601 24001 24001 P/F Notes: Well SI for reservoir P reduction OA 350 500 475 475 P.T.D. I1982030 TypeTest TestpsiI 1500 I Casing] 01 19401 19201 1920] P/F Notes: Well SI for reservoir balance OA 300 600 600 600 P.T.D.I Notes: Type Test Test psi 1500 Casing Interval P/F Interval P.T.D.I Notes: Type Test Test psi 1500 Casing P/F Interval P/F P.T.D. I Type Test Test psi Notes: . Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 KRU MIT 2T 11-01-03.xIs 11/3/2003 198-203-0 KUPARUK R1V U TABS 2T-210 50- 103-20273-00 PH~LL~S ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD 05340 TVD 03275 Completion Date: 12/3/98 Completed Status: 1WTNJ Current: T Name Interval Sent Received T/C/D c 9492 ! SCHLUM RST 12/9/99 CH 3/29/00 4/10/00 D ~..L L R T 8842 1-3 SPERRY MPT/GR/EWR4 OH 1/6/99 1/6/99 CBL/SCMT FINAL BL(C) 4750-4946 9/18/99 CH 5 9/30/99 9/30/99 DGR/EWR4-MD FINAL 117-5340 OH 1/13/99 1/13/99 DGR/EWR4-TVD FINAL 110-3275 OH 1/13/99 1/13/99 RST-WFL FINAL 4696-4870 12/11/99 CH 5 12/21/99 12/29/99 RST-WFL FINAL 4680-4867 12/9/99 CH 5 3/29/00 4/10/00 SCMT-PSP FINAL BL(C) 4650-5246 5/23/99 CH 5 6/8/99 6/16/99 STATBH PRES FINAL 4750-5019 7/21/99 CH 5 8/11/99 8/19/99 SRVY RPT SPERRY 0-5340. OH 12/9/98 12/17/98 8904 1 SCHLUM SLIM-CN/SDN/DLL OH 11/11/98 11/13/98 Thursday, January 18, 2001 Page 1 of 1 12/21/99 Schlumberger NO. 121033 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2A-24 PRODUCTION PROFILE 991210 I 1 2T-210 u.~ (-. RST/WFL 991211 I 1 2Z-29 PRODUCTION PROFILE 991213 I I SIGNED: DATE: P~-C Z 9 1999 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. T~ Re: 2T-210 Injector Subject: Re: 2T-210 Injector Date: Mon, 13 Dec 1999 11:55:13 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Jack A Walker <JAWALKER~mail.aai.arco.com> Jack, Thanks for the update on your plans. I don't consider this a monobore. Would you please see that I get a copy of the post squeeze CQL. Please keep me posted on the results of the spinner survey. The flow log results, if you run it, will be of interest. Thanks, Blair Wondzell 12/'3/99. Jack A Walker wrote: The following describes the background and plans for Tabasco injector 2T-210 in the Kuparuk River Field, consistent with our phone conversation today. Injector 2T-210 is a "monobore" injector with 7-5/8" surface casing and 5-1/2 x 3-1/2" production casing. It also has 3-1/2" tubing to surface. The original cement log indicated cement top at approximately 5000'MD, below the top of Tabasco at 4887'MD. A coiled tubing cement squeeze was performed to confine injection to the Tabasco interval. The post-squeeze cement log indicated 50' of good cement above the top of Tabasco and good cement across the Tabasco interval. The recent sequence of events is as follows: 9/18/99 Post squeeze cement log indicated 50' good cement above Tabasco and good cement across Tabasco. 10/9/99 Passed preliminary mechanical test. Perforated 4887 to 4907'MD. 10/10/99 Put on water injection. 10/31/99 Passed official MIT. 12/9/99 Borax pulsed neutron log indicated water exiting well bore near upper squeezed perfs at 4820 to 4830'MD above the Tabasco interval, but no evidence of behind pipe upward flow. Our plans are as follows: Continue injection at least until diagnostic work is complete. Verify tubing not leaking to inner annulus. Pin point water exit with spinner log. If we obtain verification that the water is existing the well bore above the Tabasco interval, then we will attempt to demonstrate downward water flow (outside of casing) with activated oxygen water flow log. We plan to run the spinner on Saturday, December 11, 1999. Enclosed MS Word file shows the 2T-210 schematic. I'll follow up with you after we've made progress in our plan. Please call me at 265-6268, or 338-1418 if you have any questions. Jack (See attached file: 2T-21OSchematic.doc) Name: 2T-21OSchematic.doc 2T-21OSchematic.doc Type: Microsoft Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 1 of 1 12/13/99 11:55 AM 2T-210 Injector Subject: 2T-210 Injector Date: Fri, 10 Dec 1999 15:33:27 -1000 From: "Jack A Walker" <JAWALKER~mail.aai.arco.com> To: blair_wondzell~admin.state, ak.us CC: "Erickson&Versteeg" <N 1177~mail.aai.arco.com>, "Ted W Cahalane" <TCAHALA@mail.aai.arco.com> The following describes the background and plans for Tabasco injector 2T-210 in the Kuparuk River Field, consistent with our phone conversation today. Injector 2T-210 is a "monobore" injector with 7-5/8" surface casing and 5-1/2 x 3-1/2" production casing. It also has 3-1/2" tubing to surface. The original cement log indicated cement top at approximately 5000'MD, below the top of Tabasco at 4887'MD. A coiled tubing cement squeeze was performed to confine injection to the Tabasco interval. 'The post-squeeze cement log indicated 50' of good cement above the top of Tabasco and good cement across the Tabasco interval. The recent sequence of events is as follows: 9/18/99 Post squeeze cement log indicated 50' good cement above Tabasco and good cement across Tabasco. 10/9/99 Passed preliminary mechanical test. Perforated 4887 to 4907'MD. 10/10/99 Put on water injection. 10/31/99 Passed official MIT. 12/9/99 Borax pulsed neutron log indicated water exiting well bore near upper squeezed perfs at 4820 to 4830'MD above the Tabasco interval, but no evidence of behind pipe upward flow. Our plans are as follows: Continue injection at least until diagnostic work is complete. Verify tubing not leaking to inner annulus. Pin point water exit with spinner log. If we obtain verification that the water is existing the well bore above the Tabasco interval, then we will attempt to demonstrate downward water flow (outside of casing) with activated oxygen water flow log. We plan to run the spinner on Saturday, December 11, 1999. Enclosed MS Word file shows the 2T-210 schematic. I'll follow up with you after we've made progress in our plan. Please call me at 265-6268, or 338-1418 if you have any questions. Jack (See attached file: 2T-210Schematic.doc) ~ 2T-210Schematic.doc Name: 2T-210Schematic.doc Type: Microsoft Word Document (application/msword)i Encoding: base64 Description: Mac Word 3.0 1 of 1 12/13/99 8:42 AM 16" Conductor @ 80' 2T-210 Injector Schematic 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface 7-5/8" Surface Casing 4397' MD 3-1/2" x 1" Camco KBG-2-9 mandrel w/DV & latch 4710' MD 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile 4762' MD Production Csg. 5-1/2" 15.5~ L-80 BTCM Baker 3-1/2" 'GBH-22' Locator Seal Assy w/10' of seals & Iocator 4801' Squeeze perfs 4820-4830' Top of Tabasco at 4887' Perfs 4887-4907' Original top of cement before cement squeeze 5000' Squeeze perfs 4984-4990' Bridge plug 5020' Production Csc~. 3-1/2" 9.3# L-80 EUE 8RD-Mod 5337' Schlmberger NO. 12742 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Kuparuk,Tabasco Pool Color Well Job # Log Description Date BL Sepia Print 1A-10 ~I~.! ~__ INJECTION PROFILE 990719 I 1 1A-11 ~ ~(._. INJECTION PROFILE 990707 I 1 1Y-10 [,[~ (L_ MI INJECTION PROFILE 990716 I 1 2A-03 I.,~.% (---- INJECTION PROFILE W/PSP 990708 I 1 2M-20 PRODUCTION PROFILE 990702 I 1 2M-30 ~t~l ~ INJECTION PROFILE W/PSP 990722 I 1 2N-321A Ltl C~, INJECTION & STATIC PROF W/PSP 990710 I 1 2N-325 tX % (--- INJECTION & STATIC PROF W/PSP 990709 I 1 2N-335 PRODUCTION PROFILE 990705 I 1 2T-28 [J~.l ~ MEMORY INJECTION PROFILE 990715 I 1 2T-202 PRODUCTION PROFILE 990706 I 1 2T-210 STATIC BOTTOM HOLE PRESS SURVEY 990721 I 1 2X-10 PROD PROFILE & GAS LIFT SURVEY 990708 I 1 13H-12 ~,J~l ~ INJECTION PROFILE 990706 I 1 i3J'04 L~I L.- INJECTION PROFILE W/PSP 990724 I 1 3J-05 /.,~l ~ INJECTION PROFILE WIPSP 990725 I 1 '3M-04 STATIC BOTTOM HOLE PRESS LOG 990701 I 1 3M-29 STATIC BOTTOM HOLE PRESS LOG 990701 I 1 S' L ;.~]'"':" ~" ~"~ Fl'i; ~','~'"~ ........ ~,, SIGNED: ~~~-'~ DATE: l[llC, i :)1999 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~'~qg 8/11/99 9/30/99 Scblumberger NO. 12823 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk,West Sak,Tarn Color Well Job # Log Description Date BL Sepia Print 2N-321A Lk.~(.-. INJECTION & STATIC PROFILE 990917 I 1 3G-26 STATIC PRESSURE SURVEY 990912 I 1 31-12 DEPTH DETERMINATION LOG 990914 I 1 30-07 (.,~-I ~_~ INJECTION PROFILE 990922 I 1 2T-210 99367 CBI.JSCMT 990918 1 ~ ~:~,'?i~ ..... i~".', ~. ~':~'~. ~'"':':! SIGNED: __~ (~- _ ....................... DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank 6~8~99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 L~ 99239 CBTW/PSP/SCMT 990221 1 ,, 1C-18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 ~ ~ ~._.. 99248 SCMT 990216 1 1D- 125 99249 CBT W/PSP/SCMT 990220 1 1D-114 L.~ ~ c 99246 CBT W/PSP/SCMT 990421 1 1D-128 99247 SCMT 990215 1 1 D- 122 us I ¢-. 99244 CBT W/PSP/SCMT 9~0226 1 1D-111 b~ c 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 6c / ¢. 99242 SCMT 990122 1 SIGNEI~. ,,,I ._.. ~__)L,j . DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Re: Tabasco 2T-210 Injector Squeeze Subject: Re: Tabasco 2T-210 Injector Squeeze Date: Thu, 10 Jun 1999 08:26:20 -0900 From: "Ted W Cahalane" <TCAHALA@mail.aai.arco.com> To: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> CC: "Erin Oba" <EOBA~mail.aai.arco.com>, "Michael L Bill" <MBILL~rnail.aai.arco.com> Thanks Blair. We'll let you know when we are ready to MIT. Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 06/10/99 06:52:40 AM To: Ted W Cahalane/AAI/ARCO cc: Erin Oba/AAI/ARCO, Michael L Bill/AAI/ARCO Subject: Re: Tabasco 2T-210 Injector Squeeze Ted, Your program sounds goood and is as we discussed. However, if all goes well with the cement job, you will need to run a valid MIT before injecting. If our inspector is unable to witness, run a avalid test; if it passes, send me the data and start injection; we will witness an MIT at a mutually agreeable time. Thanks for the information. Blair Ted W Cahalane wrote: > > Blair, > > As we discussed on the phone, here's our general plan for cementing the Tabasco > injector 2T-210. This well was drilled in November 1998 and has not been on > injection to date. The cement top in the primary cement job was lower than > expected due to hole wash out. The goal is to circulate cement at least 500' > above the injection zone which will put the cement top well into the surface > casing. Here's the key steps. > > 1) Drift and tag. > 2) Shoot circulating holes above the known cement top and establish > circulation. > 3) Set a pump through EZSV packer above the circulation holes and sting into > with coil. > 4) Circulate diesel to surface. > 5) Circulate cement to bring cement top at least 500' above the injection zone > and into the surface casing. > 6) Drift, tag, and run CBL. > 7) If cement OK, shoot injection perfs and put on injection. > > If you have any quest)ons please call me at 263-4684. i of 1 6/10/99 3:16 PM Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121326 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk 3~29~00 Well Job # Log Description Date BL Sepia CD · ~W-12 PRoDU(~TION'PROFILE w/PsP 000321 1 ..... 1 2T-210 l~..C-~q.~, c~/~ RST BORAX & ~L I~ ' 991209 I I 1 ........... ,,. ..... ............... . , ........ . . . , , ....... ............. ....... ........ ................. ....... . ........ .... ~E~EI~ ..... 1~ '~, ' ........... ~ I LI I ' APR 10 ?.000 SIGNE DATE: ~ Naska Oil & G~s C0~s. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Re: 2%210 Annular Disposal PERMIT TO DRILL 98-203 Subject: Re: 2T-210 Annular Disposal PERMIT TO DRILL 98-203 Date: Tue, 15 Feb 2000 13:36:45 -0900 From' Blair Wondzell <blair_wondzell@admin.state.ak. us> intern~i Organization' State of Alaska, Dept of Admin, Oil 8, Gas To: Thomas A Brockway <TBROCKW@mail.aai.arco.com> CC: tom_maunder@admin.state.ak, us, wendy_mahanC_.admin.state.ak, us Tom, Thanks for the closure. Blair Thomas A Brockway wrote: Blair, After our conversation this morning, I went back and took a closer look at the well records from Tabasco injector well 2T-210. At this time it does not look like this well is a viable candidate for annular disposal on 2T Pad due to the topset of the surface casing immediately above the Tabasco formation. Consequently, as we discussed this morning, all incidental fluids developed from drilling operations on well 2 T-204 will be hauled to the nearest permitted disposal well as there are currently no open disposal annuli available on 2T Pad. If you have any further comments or questions, please do not hesitate to give me a call. Thanks, Thomas A. Brockway Operations Drilling Engineer 263-4135 ', ~,': '~ 11/17/00 3:42 PM 0 I~! I I_1_ I IM I~S S ~m I:t ~d I r' ~m S To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 13, 1999 MWD Formation Evaluation Logs 2T-210, AK-MM-90018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention ot~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/¢G, Anchorage, AK 99518 2T-210: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20273-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20273-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 I:! I Cl--I I~ G S E FIL/I r" E S WELL LOG TRANSM1TFAL To: State of Alaska January 6, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2T-210, AK-MM-90018 1 LDWG formatted Disc with verification listing. API#: 50-103-20273 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPY OF TH]g TRANSMITYAL LETYER TO THE ATrENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEtVED Date: JAN 0 6 t999 ,qaslm ~ & Gas Cons. C0mm~ion signed 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-210 (Permit No. 98-203) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tabasco 2T-210. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader PM/skad RECEIVED OCT 14 1999 Naslm 011 & Gas Cons. commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT ANB LOG 1 Status of Well Classification of Service Well OIL [] GAS ~1 SUSPENDED [] ABANDONED~ SERVICE [] Injector 2 Name of Operator 7 Permit Number ARCO AJaska, Inc 98-203 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20273 4 Location of well at sudace ~,~.,,--~% ,-,,u,,,¢~.,~ 9 Unit or Lease Name 667' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM ~] .;~1~I¢,,i¢¢i~-._ ~ I Kuparuk River Unit At Top Producing Interval r ".'~..~. ' _~~~.. 10 Well Number 1561' FNL, 491' F EL, Sec. 2, T11N, R8E, U M ;' / ~'~'"'~-~ 2T-210 At Total Depth i ~. 11 Field and Pool 1176' FNL, 586' FEL, Sec. 2, T11N, R8E, UM ~ ....... ,~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Tabasco Oil Pool RKB 33', Pad 80'I ADL 25569 ALK 2667 2 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 18-Nov-98 28-Nov-98 03-Dec-98I NA feet MSL 1 5340' MD & 3275' TVD 5271' MD & 3242' TVD YES __ NO __ NA feet MD 1577 APPROX 22 Type Electric or Other Logs Run GR/Res, CBL, CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WI' GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 105' 24' 9 cu yds High Eady 7.625" 29.7# L-80 SURF. 4397' 9.875' 415 sx AS II1 L, 530 sx Class G & 60 sx AS I 5.5" x 15.5# L-80 SURF. 4811' 6.75' 115 sx Class G 3.5" 9.3# L-80 4811' 5337' 6.75" included above) cement retainer set @4975' MD 24 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE iDEPTH SET (MD) PACKER SET (MD) 3.5" 4802' N/A 4984'-4990' MD 3100'-3102' TVD 6 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4820'-4830' MD 3019'-3023' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4887'-4907' MD 3052'-3062' TVD 6 spf see attachments see attachments 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL= '--C~O~E~i~E!' '--- ----~,i~.(~iLIRA~-i~ TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-EO CONi'INUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Tabasco 4883' 3050' Base Reservoir 5190' 3202' Annulus left open - freeze protected with diesel. 31. LIST OF A~ACHMENTS Summary of Daily Driliincd Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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". Form10-407 Date: 2/8/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-210 WELL ID: AK9693 TYPE: -- AFC: AK9693 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:il/18/98 START COMP: RIG:DOYON %19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20273-00 11/11/98 (D1) TD: 0'( 0) SUPV:D L. WESTER 11/12/98 (D2) TD: 0'( 0) SUPV:D L. WESTER 11/13/98 D3) TD: 0' 0) SUPV:D L. WESTER 11/14/98 D4) TD: 0' 0) SUPV:D L. WESTER 11/15/98 D5) TD: 0'( 0) SUPV:D L. WESTER 11/16/98 (D6) TD: 0'( 0) SUPV:D L. WESTER 11/17/98 (D7) TD: 105' (105) SUPV:D.L. WESTER 11/18/98 (DS) TD: 922'(817) SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TRUN KEY RIG MOVE FORM DEADHORSE TO 2T PAD Start rig move. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CONINTUE TRUN KEY RIG MOVE FROM DEADHORSE TO 2T PAD Continue rig move. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CONTINUE TRUN KEY RIG MOVE FROM DEADHORSE Continue rig move. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CONTINUE TRUN KEY RIG MOVE FROM DEADHORSE TO 2T PAD Continue rig move. Drilling module on location. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CONTINUE TO MIRU Move rig over 2T-210. MW: 8.3 VISC: 0 PV/YP: 1/ 0 APIWL: 28.0 PREPARING TO SPUD Continue to rig up. Accept rig @ 1200 hrs. 11/16/98. MW: 8.6 VISC: 200 PV/YP: 37/43 APIWL: 10.8 DRILLING @ 210'. ACTUAL SPUD TIME 0500 HRS 11/18/98 510 GPM NU diverter and function test. MW: 9.0 VISC: 168 PV/YP: 38/42 APIWL: 8.2 DRILLING AHEAD Drilling 9-7/8" hole from 105' to 922' Date: 2/8/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/19/98 D9) TD: 2373' 1451) SUPV:FRED HERBERT MW: 9.5 VISC: 220 PV/YP: 46/52 RIH AFTER SHORT TRIP TO HWDP Drilling 9-7/8" hole from 922' to 2373' APIWL: 7.8 11/20/98 D10) TD: 3447' 1074) SUPV:FRED HERBERT MW: 9.6 rISC: 150 PV/YP: 50/52 TRIP OUT FOR BIT APIWL: 7.0 Drilling 9-7/8" hole from 2373' to 2564'. Back ream from 1743' to 1362' Drilling from 2564' to 3447' 11/21/98 Dll) TD: 4283' 836) SUPV:FRED HERBERT MW: 9.5 VISC: 110 PV/YP: 39/34 POOH FOR CLEAN OUT RUN W/ ROLLER REAMER APIWL: 6.8 Back ream from 2441' to 1458' Wash and ream from 1494' to 1558'. Drilling 9.875" hole from 3447' to 4283' 11/22/98 (D12) TD: 4283'( 0) SUPV:FRED HERBERT MW: 9.6 VISC: 95 PV/Y?: 31/33 RIG UP TO RUN CASING Drilling 9.875" hole from 4283' to 4410' APIWL: 6.5 11/23/98 (D13) TD: 4410'(127) SUPV:FRED HERBERT MW: 9.5 rISC: 60 PV/YP: 28/19 APIWL: 6.5 CIRC & CONDITION MUD FOR 2ND STAGE OF CEMENT JOB Run 7.625" casing. Pump cement. 11/24/98 (D14) MW: 8.3 VISC: 0 PV/YP: 0/ 0 TD: 4410' ( 0) TEST BOPE SUPV:LUTRICK / WESTER Pump first and second stage cement. APIWL: 0.0 11/25/98 (D15) TD: 4410'( 0) SUPV:DONALD LUTRICK MW: 9.5 rISC: 49 PV/YP: 19/23 CLEAN OUT STRINGERS BELOW STAGE TOOL NU BOPE, test BOPE to 250/3000 psi. APIWL: 6.0 11/26/98 (D16) TD: 4430'( 20) SUPV:DONALD LUTRICK RIH MW: 9.5 VISC: 45 PV/YP: 17/17 APIWL: 6.0 Drill out cement to stage tool at 1888' Drill out stage tool. Drill out cement stringers to 1918' Drill out hard cement from 3807' to 4261' Drill out cement, landing collar, float collar, float shoe and 20' new hole to 4430' perform LOT to 13.7 EMW. Pump dry job. Check flow. Blow down top drive. Change relays in top drive. Unable to back 'out of DP. Date: 2/8/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/27/98 (D17) TD: 4786'(356) SUPV:DONALD LUTRICK MW: 9.5 VISC: 45 PV/YP: 18/15 DRLG TABASCO SANDS. PACKING OFF. Repair top drive. Drill from 4430' to 4786' APIWL: 5.4 11/28/98 (D18) TD: 5340' (554) SUPV:DONALD LUTRICK MW: 9.7 rISC: 55 PV/YP: 22/26 PUMP OUT TO SHOE APIWL: 4.2 Drilling from 4786' to 4900'. Tight hole and packing off. Back ream to clean hole. Drilling from 4900' to 5340' Backream hole every 30'. Pump sweeps. Increase mud wt to 9.7 ppg. Reamed several tight spots. 11/29/98 (D19) TD: 5340'( 0) SUPV:DONALD LUTRICK MW: 9.7 rISC: 55 PV/YP: 22/28 APIWL: 4.0 WIPER TRIP FOR LOGS. ADD ADDITIONAL LUBRICANTS Back ream from 5000' to shoe at 4395'. Circ, rotate and reciprocate pipe to clear sand from casing. RIH. Hit bridge at 4816'. Ream and work pipe. Pump hi-vis sweep. Circ hole clean. Well Static. Attempt to RIH. Drill string taking wt. CBU. POH. Attempting to swab. Pump out slow to shoe. No problems. RIH w/4 arm caliper and GR. AMS malfunctioning. POH and remove AMS. RIH. Unable to work tool below 4437' 11/30/98 (D20) TD: 5340'( 0) SUPV:DONALD LUTRICK MW: 9.7 VISC: 55 PV/YP: 23/27 PREP TO RUN CSG APIWL: 3.6 Work log to 4437'. Unable to work past this point. Wash and ream casing from 3700' to 4397'. Circ and condition mud. Pump lo/hi sweeps. Add lubricants. POH. Hole swabbing. RIH to shoe. CBU no gas or oil in returns. POH. Swabbed on 1st 5 stands. Suspect formation breathing slightly. 12/01/98 (D21) TD: 5340'( 0) SUPV:DONALD LUTRICK MW: 9.7 VISC: 49 PV/YP: 18/19 INSTALL TBG HEAD APIWL: 4.6 RIH w/4 arm caliper. Unable to work tool below 4600'. Hole not tight or sticky. Log from 4600' to shoe. RIH w/3.5" x 5.5" casing string. Lost 69 bbls mud to formation. 12/02/98 (D22) TD: 5340'( 0) SUPV:DONALD LUTRICK MW: 9.7 VISC: 50 PV/YP: 19/17 POH LD 2 7/8" DP Pump cement. NU BOPE. APIWL: 4.6 12/03/98 (D23) MW: 8.5 VISC: 0 PV/YP: 0/ 0 TD: 5340'( 0) ND BOPE SUPV:DONALD LUTRICK+ RIH w/3.5" completion assembly. APIWL: 0.0 Date: 2/8/99 ARCO ALASKA INC. Page: 4 WELL SUMMARY REPORT 12/04/98 D24) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 5340' 0) MOVE RIG TO 2T-207 SUPV:DONALD LUTRICK+ Freeze protect well. ND BOPE. NU master valve and test to 5000%. Rig down. 12/05/98 (D25) MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 5340' ( 0) RIG RELEASED SUPV:DONALD LUTRICK+ Move to 2T-207. Release rig at 0200 hrs. 12/5/98. ARCO Alaska. Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT '~' K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-210 CEMENT SQUEEZE 0624990453.1 DATE DAILY WORK UNIT NUMBER 06/25/99 SET BRIDGE PLUG & PERF SQZ HOLES 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-ELMORE JOHNS FIELD AFC# CC# Signed ESTIMATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 300 PSI 300 PSI 125 PSI 125 PSII 200 PSII 200 PSI DAILY SUMMARY I SET BP AT 5020' AND PERF'D SQZ HOLES AT 4984'-4990'. TIME LOG ENTRY 08:00 MIRU SWS 2128 ELMORE, TGSM, PT 3000#. I-J[-] 09:30 RIH W/SWIVEL,CCL,WTBAR,2.5" ROLLER,WTBAR,BST#10,EZ-DRILL BP. MAX OD IS BST#10 @ 2.75", HALIBURTON SETTING MANDREL @ 2.70". OAL=27' 10:15 LOG TIE UP THROUGH JEWELRY, RIH TO 5100'. 10:43 LU SET BP AT 5020'. LU...PULLED TENSION AT 4900', CAME FREE. DROPPED BACK DOWN AND TAGGED BP. POOH. 12:10 RIH W/SWIVEL,CCL-WTBAR-ROLLER-WTBAR,2.5" X 6' SQZ GUN, SLICKLINE ROLLER STEM. 6SPF, 35C UP BIG HOLE CHARGES. 60 DEG PHASED. OAL=35'. 13:15 RECHECK TI, SHOOT SQZ HOLES AT 4984'-4990', POOH. 13:40 AT SURFACE, RD. 14:00 RDMO TO HOUSE. Date 07/21/99 Well Na 2T-210 Service Type ELECTRIC LINE Upcoming Job Num 0624990453.1 AFC AK9693 Unit 2145 0 Prop 38TB2T601 Uploaded to Sen Desc of Work SBHP, SQZ PERF & BRIDGE PLUG Supervisor LIGENZA Contractor Key Perso SWS-STEPHENSON Complet r~ successful F Accident I~ Initial Tbg Press 0 Final Tbg Press 75 Injury r- Initial Int Csg Press 250 Final Int Csg Press 150 Spill ~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary SBHP = 1264 PSi PERFORATED INTERVAL FROM 4820' TO 4830'. UNABLE TO SET EZSV. UNABLE TO DROP PAST 4877'. [Perf, Cement~Poly Squeeze] Date printed: 09/20/99 at: 13:27:35 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~ K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUI(/1BER ' " 2T-210 CEMENT SQUEEZE 0624990453.1 DATE DAILY WORK UNIT NUMBER 08/06/99 CEMENT RETAINER RING SETTING SWS 2145 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESI YES SWS-STEPH ENSON FERG USON FIELD AFC# CC# Signed ESTI MATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 150 PSI 150 PSI 100 PSI 100 PSII 0 PSII 0 PSI DALLY SUMMARY CEMENT RETAINER SET AT 4975' TIME LOG ENTRY 07:00 DEPART FOR DS 2T-210 07:30 ARRIVE ON LOCATION - HOLD SAFETY MEETING - START RIG UP 08:15 PRESURE TEST TO 3000# 08:30 RIH WITH SWIVEL/2X100# WEIGHTS/CCL/BST#10/CEMENT RETAINER 09:20 LOG TIE IN PASS 09:30 LOG INTO SHOOTING POSITION & SET CEMENT RETAINER @ 4975' 09:35 RUN SLACK BACK INTO CEMENT RETAINER AND LOG OFF 09:45 POOH 10:30 START RIG DOWN 11:00 RELEASE RADIO SILENCE 11:30 COMPLETE RIG DOWN - LEAVE LOCATION 12:00 RETURN TO KCC ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUMBER " 2T-210 CEMENT SQUEEZE 0624990453.1 DATE DAILY WORK UNIT NUMBER 08/14/99 BREAKDOWN SQUEEZE PERF'S DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 9 YESI YES CHANEY FIELD AFC# CC# Signed ESTIMATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 750 PSI 975 PSI 200 PSI 0 PSII 25 PSII 200 PSI DAILY SUMMARY BROKE DOWN SQUEEZE PERF'S. PUMPED 90 BBLS OF DIESEL, MAX RATE 5 BPM, MAX WHTP 2250 PSI.[HPBD] TIME 07:30 07:55 LOG ENTRY MIRU LRS HOT OIL UNIT. HELD SAFETY MEETING (3 PEOPLE ON LOCATION). PT'D LINES AND EQUIP TO 3000 PSI. 08:00 PUMPING DIESEL @ 2 BPM & WHTP 1600 PSI. PUMPED 5 BBLS AT THIS RATE & PRESSURE. 08:05 RAMPED RATE UP TO 5 BPM & WHTP 2000 PSI. MONITORING IA AND OA. 08:10 RATE CONSTANT @ 5 BPM & WHTP 2250 PSI. IA = 700 PSI & OA = 275 PSI. 30 BBLS AWAY 08:15 RATE CONSTANT @ 5 BPM & WHTP 2250 PSI. IA = 800 PSI & OA = 325 PSI. 50 BBLS AWAY 08:20 RATE CONSTANT @ 5 BPM & WHTP 2250 PSI. IA = 900 PSI & OA = 350 PSI. 70 BBLS AWAY 08:25 RATE CONSTANT @ 5 BPM & WHTP 2250 PSI. IA = 950 PSI & OA = 375 PSI. 90 BBLS AWAY 08:30 S/D. ISlP 1350. STOOD-BY AND MONITORED PRESSURES. 08:40 WHTP AFTER 10 MINS HAD DROPPED TO 975 PSI. 08:45 BLEED IA DOWN TO 0 PSI AND OA DROPPED DOWN TO 200 PSI. 09:15 RDMO LRS HOT OIL UNIT. WELL SECURED AND NOTIFED DSO OF STATUS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4, WELL SERVICE REPORT '' K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUI~IBER " 2T-210 CEMENT SQUEEZE 0624990453.1 DATE DAILY WORK UNIT NUMBER 08/21/99 CEMENT SQUEEZE UNIT #3 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 10 NO NO DS-NEWELL LIGENZA FIELD AFC# CC# Signed ESTI MATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 50 PSI 900 PSI 2200 PSII 420 PSII 600 PSI DAILY SUMMARY PUMPED 200 BBLS 3% KCL DOWN TUBING THROUGH TOP SQUEEZE PERF. PUMPED 115 BBLS DOWN COIL THROUGH BOTTOM PERF. LESS THAN FIFTY BBLS RETURNS. CEMENT SQUEEZE TOMORROW.[Cement-Poly Squeeze] TIME LOG ENTRY 07:00 MIRU DS CTU, HES. ENERGY ISO HEAT TRACE. 09:00 PRESSURE TEST LUBE / LINES. BAD O-RING. REPLACE, RETEST TO 4,000 PSI. TGSM. GRAVEL CREW NEXT TO UNIT. 09:30 RIH W/2.20 MHA, 2.20 XO, STINGER ASSY. TOTAL LENGTH. 7.02'. 10:15 WT CHECK AT 4200', 9,000#. 10:35 STING IN TO PACKER AT 4958.9. STACK 5,000#. PUMP 2 BBLS DOWN COIL TO VERIFY WE ARE IN PACKER. PUMP 15 BBLS DOWN 3'X 1.75 BACK SIDE. ESTABLISHED RETURNS UP THE COIL. 10:50 START PUMPING 3% KCL WATER DOWN BACK SIDE AT .5 BPM, 780 PSI. 11:15 20 BBLS PUMPED, PRESSURE SPIKED FROM 635 TO 1100 PSI. SHUT DOWN PUMP. LINE UP TO PUMP DOWN COIL. PUMPED 2 BBLS DOWN COIL. LINE UP TO PUMP DOWN BACK SIDE. 11:50 RETURN RATE FALLING OFF. SLOWLY INCREASED PUMP RATE TO .95 BPM 1480 PSI. 12:20 CUT RATE TO .5 BPM. VERY POOR RETURNS. LESS THAN 1 FOR 10. 12:40 INCREASED RATE TO 1.2 BPM. 1500 PSI. NO CHANGE IN RETURNS. PRESSURE SLOWLY FALLS OFF TO 1125 PSI. 13:00 RETURNS DROPPING OFF. PUMP 2 BBLS DOWN COIL AT .5 BPM, 900 PSI. SWITCH BACK TO PUMPING DOWN ANNULUS. FLOW STOPPED. PUMP TWO MORE BBLS DOWN COIL. SWITCH BACK TO PUMPING DOWN ANNULUS AT .5 BPM. 15:00 SHUT DOWN PUMP. 160 BBLS OF KCL WATER PUMPED. ONLY 12 BBL IN RETURNS. START PUMPING DOWN COIL AT .5 BPM 850 PSI. TIME LOG ENTRY 16:00 GETTING BETTER RETURNS. DISCUSSED PROCEDURE CHANGE WITH ENGINEERING. 35 BBLS IN RETURNS. 230 BBLS PUMPED TOTAL. 18:20 PUMPED 115 BBLS DOWN COIL. RETURNS DROPPED DOWN TO A TRICKLE, POH, 07:00 ON SURFACE. RIG DOWN FOR THE NIGHT. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~, K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUI~IBER 2T-210 CEMENT SQUEEZE 0624990453.1 DATE DAILY WORK UNIT NUMBER 08/22/99 CEMENT SQUEEZE UNIT #3 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 11 YES YES DS-NEWELL LIGENZA FIELD AFC# CC# Signed ESTI MATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 50 PSI 50 PSI 500 PSI 1100 PSII 100 PSI 250 PSI DAILY SUMMARY PUMP 70 BBL CEMENT SQUEEZE. PUMPED 55 BBLS INTO PACKER. SQUEEZED 5 BBLS BEHIND PIPE IN TOP PERF. LEFT CEMENT IN TUBING TO 3982'. SET UP HARD, UNABLE TO CIRCULATE OUT.[Cement-Poly Squeeze] TIME LOG ENTRY 08:00 MIRU DS CTU, CEMENT CREW. 09:00 PRESSURE TEST LUBE / LINES TO 4,000 PSI. TGSM. 12 PERSONNEL ON LOCATION PLUS 2 DOWELL HSE AND MANAGER. 09:20 RIH W / 2.20 MHA, 2.20 XO, AND HES STINGER ASSY. TOTAL LENGTH 7.02'. 10:00 MEETING TO DISCUSS PUMP SCHEDULE CHANGES BASED ON CIRCULATION PROBLEMS ENCOUNTERED ON 8/21. 10:40 BEGIN PUMPING 3% KCL AT ONE BPM FROM 4900' TO REMOVE ANY POTENTIAL DEBRIS FROM TOP OF PACKER. 10:50 WT CHECK 11,000#. SHUT DOWN PUMP AT 10 BBLS. STING INTO PACKER. 11:00 PRE JOB / SAFETY MEETING. JOB PLAN CHANGE TO PUMP 70 BBLS. 11:20 PRESSURE TEST CEMENT LINES TO 4,000 PSI. 11:33 START PUMPING CEMENT AT 1.3. 12:02 CEMENT AT NOZZLE. 2670 PSI AT 1 BPM. 12:40 TOTAL OF 68.9 BBLS OF CEMENT PUMPED. SWITCHED TO 5 BBL FRESH WATER PAD. 12:45 START PUMPING SEA WATER. 12:55 WITH 15 BBLS OF CEMENT IN COIL, SHUT DOWN PUMP. PULL OUT OF PACKER. SAW IMMEDIATE RETURNS AT SURFACE. LAY IN 1:1 TO 4802' CTM. 13:05 BLOCK IN CHOKE. SQUEEZE 3 BBLS INTO TOP PERF. OPEN CHOKE.LAY CEMENT TO 3680'. ALL CEMENT OUT OF NOZZLE. PULL UP TO 3400'. TIME LOG ENTRY 13:30 PUMP UP TO 1500 PSI. PUSH 2 MORE BBLS BEHIND PIPE. SWITCHED TO BIO ON SURFACE. 14:00 DROP 5/8" BALL TO OPEN CIRC SUB. 14:50 JET DOWN TO 3982 CTM. HARD TAG. CEMENT SETTING UP. CIRCULATE BIO/CONTAMINANTE. 16:00 PULL UP TO 2500'. FREEZE PROTECT WITH DIESEL. 17:00 ON SURFACE. RIG DOWN DS CTU. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(2T-210(W4-6)) WELL JOB SCOPE JOB NUI(/IBER " 2T-210 PERFORATIONS-E-LINE 0917991858.7 DATE DAILY WORK UNIT NUMBER 10/09/99 INITIAL PERFS, 4887'-4907' 2145 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESJ YES SWS-STEPHENSON SCHUDEL FIELD AFC# CC# Signed ESTI MATE AK9693 38TB2T6CL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 250 PSI 0 PSI 1500 PSI 500 PSII 0 PSII 0 PSI DAILY SUMMARY INITIAL PERFS 4887'- 4907'. 1ST SHOT W/WHP @400 PSI AS REQUESTED. LRS PUT 1500 PSI ON 7" FOR PRE-INJ MIT. MITIA (7") PASSED TO 1500 PSI (STATE DECLINED TO WITNESS). STATE TO WITNESS IN 2 WEEKS AFTER INJECTION. TAG DEPTH 4956' ELM.[Perf] TIME LOG ENTRY 08:45 DEPART FOR 2T-210 09:30 ARRIVE ON LOCATION - WAIT FOR SLICKLINE TO FINISH TAG RUN 10:30 11:15 SLICKLINE COMPLETE (TAG @ 4928' WLM - NOTE: HAD TO RIH @ 200 FPM TO GET THROUGH RESTRICTION @ 4687') - HOLD SAFETY MEETING - START RIG UP CALL FOR RADIO SILENCE 11:30 PRESSURE TEST FAILED - BAD CONNECTION 11:45 PRESSURE TEST TO 3000# 12:00 RIH WITH CCL-WGT BAR-SAFE-10' 2.5" HSD @ 6 SPF & 60 DEG PHASING 12:30 TAG BOTTOM AT 4956' ELM. TIE-IN PASSES. TIE INTO CBL DATED 5-23-99. 12:38 1ST SHOT 4897'-4907'. WHP=400, IA=1475. WHP DROPPED TO 250 AFTER SHOT. FLUID IN HOLE WAS SLICK SW FROM TD TO 2500', DIESEL ABOVE. GOOD SHOT INDICATION. POOH. ALL SHOTS FIRED 13:15 RIG DOWN GUN #1 13:25 RIG UP GUN #2 13:30 RIH WITH CCL-WGT BAR-SAFE-10' 2.5" HSD @ 6 SPF & 60 DEG PHASING 13:50 WHILE RIH, SETTING DOWN AT 4160'. TRY DIFFERENT RIH SPEEDS. 14:02 LOG TIE-IN PASSES FOR 2ND PERF RUN. 14:06 2ND SHOT, WHP=0 PSI, 1550 PSI IA. GOOD SHOT INDICATION. 14:08 START PRE-INJECTION STATE MIT. ZERO TIME READING= 1535 PSI 14:10 POOH 14:30 AT SURFACE. 14:23 15 MINUTE MITIA READING= 1535 PSI, 0 PSI PRESSURE DROP. TIME 14:35 14:40 14:50 15:15 15:30 16:15 LOG ENTRY START RIG DOWN FINAL MITIA READING=1535 PSI, ZERO PSI PRESSURE DROP FOR 30 MINUTE TEST. TEST PASSED. RELEASE RADIO SILENCE. NOTIFY DSO TO PLACE WELL ON INJECTION. BLEED IA DOWN TO 500# COMPLETE RIG DOWN - LEAVE LOCATION RETURN TO KCC North Slope Alaska ASP Zone 4 Kuparuk 2T, Slot 2T-2~0 2T-2~0 Job No. AKMM900f8, Surveyed: ~8 November, ~998 ORIGINAL S UR VEY REPORT 9 December, 1998 DEC 1~ 1998 Your Ref: API-50f032027300 KBE- 117.30' MWD Survey Instrument Surface Coordinates: 5970647.7~ N, 498944.73 E (70° ~9'51.7380" N, fSO° 00'30.8~39" HO sp~r~m~-sum D RI, L I~1 HI~ SERVICES Survey Ref: svyf f 5 Sperry-Sun Drilling Services Survey Report for 2T-210 Your Ref: API-501032027300 Job No. AKMMgO0'IS, Surveyed: 18 November, 1998 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -117.30 170.03 0.540 139.400 52.73 230.74 0.550 150.260 113.43 293.48 0.640 146.520 176.17 354.52 0.710 153.080 237.21 442.43 0.500 199.900 325.11 469.44 0.740 237.260 352.12 503.18 1.170 257.840 385.86 532.35 1.600 267.830 415.02 561.83 1.940 265.690 444.48 618.89 2.700 274.170 501.50 650.08 3.600 280.330 532.64 679.73 4.840 286.760 562.21 709.38 6.260 292.780 591.72 739.49 7.530 298.170 621.61 772.08 8.990 302.690 653.86 800.66 10.640 303.970 682.01 830.61 12.860 306.740 711.32 858.81 14.850 307.500 738.70 889.54 15.580 309.540 768.36 918.42 16.660 310.540 796.10 945.44 17.860 311.670 821.90 977.4~, 18.470 312.330 852.31 1010.30 19.210 312.960 883.41 1040.52 20.370 313.840 911.84 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5970647,71 N 498944.73 E 170.03 0.61 S 0.52 E 5970647,10 N 498945.25 E 230.73 1.08 S 0.85 E 5970646,63 N 498945.58 E 293.47 1.63 $ 1.19 E 5970646,08 N 498945.92 E 354.51 2.25 S 1.55 E 5970645.46 N 498946.28 E 442.41 3.10 S 1.67 E 5970644.61 N 498946.40 E 469.42 3.31 S 1.48 E 5970644.40 N 498946.21 E 503.16 3.50 S 0.96 E 5970644.21 N 498945.69 E 532.32 3.57 S 0.27 E 5970644.14 N 498944.99 E 561.78 3.63 S 0.64 W 5970644.08 N 498944.09 E 618.80 3.60 S 2.95 W 5970644.11 N 498941.78 E 649.94 3.37 S 4.64 W 5970644.34 N 498940.09 E 679.51 2.85 S 6.76 W 5970644.87 N 498937.97 E 709.02 1.86 S 9.45 W 5970645.85 N 498935.28 E 738.91 0.29 S 12.70 W 5970647.42 N 498932.03 E 771.16 2.09 N 16.72 W 5970649.80 N 498928.01 E 799.31 4.80 N 20.83 W 5970652.51 N 498923.90 E 828.62 8.37 N 25.84 W 5970656.08 N 498918.89 E 856.00 12.45 N 31.22 W 5970660.16 N 498913.51 E 885.66 17.47 N 37.53 W 5970665.19 N 498907.20 E 913.40 22.63 N 43.67 W 5970670.35 N 498901.07 E 939.20 27.90 N 49.70 W 5970675.62 N 498895.03 E 969.61 34.58 N 57.12 W 5970682.30 N 498887.62 E 1000.71 41.77 N 64.92 W 5970689.49 N 498879.81 E 1029.14 48.80 N 72.35 W 5970696.52 N 498872.38 E Dogleg Rate (°/'tOOft) 0.318 0.171 0.156 0.171 0.589 1.694 1.611 1.685 1.175 1.458 3.079 4.470 5.170 4.729 4.900 6.518 7.005 7.086 2.946 3.861 4.611 2.012 2.336 3.963 Vertical Section (ft) 0.00 -0.74 -1.29 -1.92 -2.62 -3.46 -3.60 -3.62 -3.49 -3.26 -2.54 -1.81 -0.67 1.08 3.55 7.04 10.86 15.77 21.29 27.98 34.75 41.60 50.20 59.41 68.35 ASP Zone 4 Kuparuk 2T Comment Continued... 9 December, 1998 - 9:08 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-210 Your Ref: AP1.501032027300 Job No. AKMM90018, Surveyed: f8 November, ~Dg8 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 1072,26 20.980 315.420 941.54 1099.25 22.420 317.500 966,62 1132,21 23.220 318.510 997.00 1163.93 23.940 321,520 1026.07 1198.04 25.930 323.140 1057.00 1227.06 28.120 324.660 1082.85 1261.45 29,060 326,010 1113.04 1294.20 30.900 326.750 1141.41 1323.20 33.120 328.140 1166.00 1354.44 33.680 330.150 1192.08 1389.47 35.190 331.710 1220.97 1419.44 35.540 332,510 1245.41 1445.30 36,490 333.370 1266.33 1482.72 36.790 334.670 1296.36 1514.95 37.280 335.300 1322.08 1547.07 38.310 336.060 1347.47 1580.14 39.000 337.420 1373.29 1610.49 39.200 339.380 1396,84 1641.02 40.510 342.110 1420.28 1673.00 42.330 345.250 1444.27 1708.34 44.760 346.840 1469.88 1738.84 46.850 347.150 1491.14 1768.41 49.030 347.080 1510.95 1802.04 50.450 347.710 1532.68 1834.83 51.570 347.800 1553.31 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1058.84 56.67 N 80.33W 5970704.39 N 498864.41E 1083.92 63.91 N 87.20W 5970711.63 N ' 498857.54E 1114.30 73.41N 95.75W 5970721.13 N 498648.99 E 1143.37 83.13 N 103.89W 5970730.86 N 498640.85 E 1174.30 94,52 N 112.68W 5970742.24 N 498832.07 E 1200.15 105.18 N 120.44W 5970752.90 N 498824.31E 1230.34 118,71 N 129.80W 5970766.44 N 498814.95 E 1258.71 132.34 N 138.85W 5970780.07 N 498805.90 E 1283.30 145.30 N 147.12W 5970793.03 N 498797.63 E 1309.38 160.06 N 155.94W 5970807.79 N 498788.82 E 1338.27 177,37 N 165.55W 5970825.11N 498779.20 E 1362.71 192,71N 173.67W 5970640.44 N 498771.09 E 1383.63 206.25 N 180.58W 5970853.98 N 498764.17 E 1413.66 226,32 N 190.37W 5970874.06 N 498754.40 E 1439.38 243.91N 198.57W 5970891.65 N 498746.19 E 1464.77 261.85 N 206.68W 5970909.59 N 498738.09 E 1490.59 280.83 N 214.83W 5970928.57 N 498729.94E 1514.14 298.62 N 221.88W 5970946.36 N 498722.89 E 1537.58 317.09 N 228.32W 5970964.83 N 498716.45 E 1561.57 337.39 N 234.26W 5970985.14 N 498710.52 E 1587.18 361.02 N 240.12W 5971008.76 N 498704.66 E 1608.44 382.32 N 245,04W 5971030.07 N 498699.74 E 1628.25 403.72 N 249.94W 5971051.47 N 498694.85 E 1649.98 428.77 N 255.53W 5971076.52 N 498689.26 E 1670.61 453.68 N 260.94W 5971101.42 N 498683.85 E Dogleg Rate (°/100ft) 2.604 6.048 2.702 4.422 6.168 7.912 3.316 5.731 8.065 3.969 4.992 1.937 4.162 2.223 1.923 3.519 3.309 4.126 7.158 8.635 7.542 6.891 7,374 4.458 3.422 Vertical Section (ft) 78.27 87.24 98.88 110.60 124.11 136.61 152.34 168.07 182.91 199.65 219.06 236.12 251.12 273.21 292.46 312.00 332.56 351.65 371.20 392.35 416.64 438.44 460,32 485.89 511.26 ASP Zone 4 Kuparuk 2T Comment Continued... 9 December, 1998 - 9:08 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-210 Your Ref: AP1-501032027300 Job No. AKMM90018, Surveyed: 18 November, 1998 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 1866.58 53.050 347.270 1572.72 1896.05 54.900 346.820 1590.06 1925.74 56,680 345.670 1606.75 1956.12 57.940 345.370 1623.16 1988.59 59.340 344.490 1640.05 2021.17 60.940 343.050 1656.27 2053.97 62.020 342.210 1671.94 2116.51 64.550 341.700 1700.05 2181.70 64.200 341.500 1728.24 2244.61 64.340 341.700 1755.55 2307.27 63.830 341.890 1782.94 2337.04 63.360 341.570 1796.18 2368.57 63.640 342.050 1810.24 2430.38 63.760 341.580 1837,63 2493.80 63.830 342.380 1865,64 2561.51 63.300 341.320 1895.78 2625.40 63.400 341.830 1924.44 2719,41 63,000 342.610 1966.83 2815.74 63.210 342.640 2010.40 2908.60 63.890 343.850 2051.76 2999.59 63.750 343.840 2091.91 3102.10 63.510 344.200 2137.44 3193.06 63.140 344.930 2178.28 3291.08 63.290 345.510 2222.45 3392.06 63.200 345.660 2267.91 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) 1690.02 478.21 N 266.36W 5971125.95 N 498678.43 E 1707,36 501.43 N 271.71W 5971149.18 N 498673.09 E 1724.05 525.28 N 277.55W 5971173.03 N 498667.26 E 1740.46 550.03 N 283.94W 5971197.78 N 498660,87 E 1757.35 576.81N 291.15W 5971224,56 N 498653.66 E 1773.57 603.93 N 299.05W 5971251.68 N 498645.76 E 1789.24 631.44 N 307.65W 5971279,19 N 498637.16 E 1817.35 684.55 N 324.96W 5971332.30 N 498619,87 E 1845.54 740.32 N 343.51W 5971388.08 N 498601.32 E 1872.85 794.10 N 361.40W 5971441.86 N 498583.44 E 1900.24 847.63 N 379.01W 5971495.40 N 498565.84E 1913.48 872,95 N 387.37W 5971520.72 N 498557.48 E 1927.54 899.76 N 396.18W 5971547.53 N 498548.68 E 1954.93 952.40 N 413.47W 5971600.17 N 498531.39 E 1982.94 1006.51N 431.07W 5971654.29 N 498513.80 E 2013.08 1064.13 N 449.96W 5971711.90 N 498494.92 E 2041.74 1118.30 N 468.01W 5971766.08 N 498476.88 E 2084.13 1198.21 N 493.63W 5971845.98 N 498451.27 E 2127.70 1280.20 N 519.28W 5971927.98 N 498425.63 E 2169.06 1359.80 N 543.25W 5972007.59 N 498401,67 E 2209.21 1438.24 N 565.97W 5972086.02 N 498378.96 E 2254.74 1526.53 N 591.25W 5972174.32 N 498353.69 E 2295.58 1604.89 N 612,89W 5972252.69 N 498332.07 E 2339.75 1689.48 N 635.21W 5972337.28 N 498309.76 E 2385.21 1776.81 N 657.66W 5972424.62 N 498287.32 E Dogleg Rate (°/'~00ft) 4.845 6.398 6.797 4.230 4.893 6.230 3.988 4.110 0.604 0.363 0.858 1.849 1.626 0.709 1.137 1,606 0.730 0.854 0.220 1.377 0.154 0.392 0.824 0.550 0.160 Vertical Section (ft) 536.29 560,04 584.54 610.07 637.77 666.01 694.83 750.69 809.46 866.13 922.48 949.15 977.36 1032.77 1089.67 1150,29 1207.39 1291.30 1377.21 1460.34 1541.97 1633.78 1715.02 1802.40 1892.43 ASP Zone 4 Kuparuk 2T Comment Continued... 9 December, 1998 - 9:08 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-210 Your Ref: API.50f032027300 Job No. AKMM90018, Surveyed: ~8 November, ~998 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 3484.70 64.940 345.900 2308.41 3580.49 64.470 343.520 2349.35 3675.55 64.550 344.170 2390.26 3770.98 63.990 342.170 2431.69 3867.31 63.580 342.170 2474.24 3960.63 63.000 342.420 2516.19 4054.86 62.760 341.480 2559.14 4150.14 64.600 342.750 2601.39 4246.48 63.980 342.810 2643.18 4341.41 63.770 342.580 2684.98 4464.55 63.110 344.740 2740.05 4527.53 63.500 343.990 2768.34 4586.81 64.140 343.260 2794.49 4651.47 65.140 342.710 2822.19 4716.83 62.630 340.730 2850.96 4781.00 59.400 340.060 2882.05 4841.34 60.370 339.630 2912.32 4911.58 60.760 340.860 2946.84 4980.31 60.630 343.230 2980.49 5036.50 59.590 344.300 3008.49 5104.48 60.920 347.020 3042.22 5166.63 59.750 349.250 3072.98 5227.75 60.200 349.140 3103.57 5272.23 61.110 348.660 3125.36 5340.00 61.110 348.660 3158.11 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2425.71 1857.57 N 678.12W 5972505.38 N 498266.87 E 2466.65 1941.10 N 700.95W 5972588.91N 498244,05 E 2507.56 2023.52 N 724.83W 5972671.33 N 498220.19 E 2548.99 2105.80 N 749.71W 5972753.62 N 498195.31E 2591.54 2188.07 N 776.17W 5972835.89 N 498168.86 E 2633.49 2267.49 N 801.53W 5972915.31N 498143.52 E 2678.44 2347,23 N 827.51W 5972995.05 N 498117.55 E 2718.69 2428.50 N 853.73W 5973076.33 N 498091.34 E 2760.48 2511.41N 879.43W 5973159.24 N 498065.66 E 2802.28 2592.78 N 904.78W 5973240.62 N 498040.32 E 2857.35 2698.47 N 935.77W 5973346.31N 498009.34 E 2885.64 2752.65 N 950.93W 5973400.50 N 497994.18 E 2911.79 2803.69 N 965.93W 5973451.54N 497979.19 E 2939.49 2859.56 N 983.03W 5973507.41 N 497962.10 E 2968.26 2915.28 N 1001.43W 5973563.13 N 497943.71E 2999.35 2968.16 N 1020.25W 5973616.01N 497924,89 E 3029.62 3017.15 N 1038.24W 5973665.01N 497906.92 E 3064.14 3074.73 N 1058.91W 5973722.58 N 497886.25 E 3097.79 3131.73 N 1077.39W 5973779.60 N 497867.78 E 3125.79 3178.51 N 1091.01W 5973826.37 N 497854,17 E 3159.52 3235,68 N 1105.62W 5973883.55 N 497839.57 E 3190.28 3288.53 N 1116.73W 5973936.39 N 497828.47 E 3220.87 3340.51 N 1126,85W 5973988.37 N 497818.55 E 3242.66 3378.55 N 1134.11W 5974026.42 N 497811.09 E 3275.41 3436.73 N 1145.78W 5974064.60 N 497799.44 E Dogleg Rate ('/'tOOft) 1.893 2.299 0.623 1.977 0.426 0.666 0.924 2.271 0,646 0.310 1.658 1.231 1.545 1.727 4.706 5.116 1.722 1.623 3.013 2.480 3.987 3.642 0.753 2.252 0.000 Vertical Section (ft) 1975.60 2062.13 2147.91 2233.87 2320.29 2403.65 2487.51 2572.91 2659.71 2744.94 2855,05 2911.28 2964.47 3022.90 3081.57 3137.66 3189.80 325O.93 3310.85 3359.55 3418.47 3472.21 3524.76 3563.28 3622.27 ASP Zone 4 Kuparuk 2T Comment Projected Survey Continued... 9 December, 1998 - 9:08 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-210 Your Ref: API.50f032027300 Job No. AKMM90018, Surveyed: 18 November, 1998 North Slope Alaska ASP Zone 4 Kuparuk 2T All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.056° (16-Nov-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 342.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5340.00ft., The Bottom Hole Displacement is 3622.70ft., in the Direction of 341.562° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E Tie-on Survey 5340.00 3275.41 3436.73 N 1145.78 W Projected Survey 9 December, 1998 - 9:08 - 6 - DrillQuest r'lFllll I_II~CS c:~:::I::IUII--~:S 09-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-210 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,340.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company - . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMiSsION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging __ Time extension _ Stimulate__ Pull tubing__ Variance__ Perforate__ Other X Change of Ri.qs 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory __ Stratigraphic __ Service X 4. Location of well at surface 667' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM At top of productive interval 1543' FNL, 494' FEL, Sec. 2, T11 N, R8E, UM At effective depth At total depth 1200' FNL, 603' FEL, Sec. 2, T11 N, R8E, UM 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tabasco Oil Pool 8. Well number 2T-210 9. Permit number 98-203 10. APl number 50-103-20273 11. Field/Pool Kuparuk River Field/Tabasco Oil Pool 12. Present well condition summary Proposed as per Permit to Drill 98-203 Total Depth: measured 5303' feet Plugs (measured) (approx) true vertical 3277' feet Effective depth: measured 5303' feet (approx) true vertical 3277' feet Casing Length Size Structural Conductor 82' 16" Surface 4359' 7.625" Intermediate Production 4789' 5.5" x Liner 486' 3.5" Junk (measured) None Cemented 9 Cu High Early 417 sx ASlIILW & 365 sx Class G 242 sx Class G Measured depth True vertical depth 110' 110' 4387' 2838' 4817' 3035' 5303' 3277' Perforation depth: measured true vertical N/A Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 5303' Packers and SSSV (type and measured depth) Baker CSR, No SSSV 13. Attachments Description summary of proposal __ Contact Tom Mc Kay at 265-6890 with any questions. 0 R IGINAL --; Alas.ka 0ii & ¢ as Cons. O0mmis¢.o ', Anchom~e Detailed operation program ~ BOP sketch 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is trt,~e and. correct to the best of my knowledge. ./_.., Signad / (,,,..,,~.~ ~/(,,,/. (..//~ Title Tabasco Drilling Team Leader f / FOR COMMISSION USE ONLY Conditions of approval: Notify Commissid~/so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-__~ Approved by the order of the Commission Original Form 10-403 Rev 06/15/88 pprov6 ,-....,.. .... David W. d0hnsm Returned Commissioner IAppr~9'v~l~°~ ~ ~ Date //'/l~l/~ ~ SUBMIT .N RpL,OATE Drilling Fluids System - Doyon Rig 19 Triple Derrick Shale Shakers Centrifuge, Mud Cleaner Desander, Degasser Pit Level Indicator (Visual/Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner 2T-210 (E) 1 TAB, 11/04/98, vl ,- Suo!)e~edo ooseqel )!un Je^!hl HnJednN 6'1, ,la ,,gL 13-5/8'" [~ ~.10 psi BOP Stack--C~jon Rig 19 Kuparuk River Unit Tabasco Operations - Producer Wells 1 $ 0 1/4' 1' 10 CHOKE UNE 1/s' ~ ~ HCR VAL~ 3 1/8' 5000 F~ ~ v~vE:~ ' DOp STACK -.! · ! 3~ 13 5/8'. 5000 PSI H'YORIL ANNULAR BOP, STUDDED TOP/F1.ANGE0 BOll'OM -. $1NCrLE 13 5/8", 5000 PSI, 10" UPL OPERATORS, ~RIL PIPE ~ FLANGE BOI'rOI~¢y%'T1JDDED TOP' SIi~G'LE 13 5/8', 5000 PSI, 14' UPL OPERATORS, BUND SHE~ RA~ 3 1/s' ~ ~ NCR v~. . 2" mU. HE FLANGE BOll'OM/STUDDED TOP · HYDRIL PIPE ~ ADAPTER S~OOL HUB ,, FLANCE .i BOP STACK ELEVATION ARCO Alaska, Inc. '~" Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 4, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Revision of Application for Permit to Drill Permit # 98-203 Tabasco 2T-210 Tabasco Injector, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby requests a revision of permit #98-203 referencing Tabasco well 2T- 210 located in the Kuparuk River Unit. Due to rig scheduling issues, ARCO proposes to drill and complete this well using Doyon Rig 19 rather than Nordic Rig 3 as stated in the original permit application. No changes from the original permit application are planned in the drill and complete procedure, fluid program, casing program, or directional profile. Please find attached a listing of the Doyon 19 Drilling Fluids System and schematics detailing the diverter and BOP systems which Doyon 19 will use on this well. Please note that the revised anticipated spud date for this well is November 1 have any questions or require further information, please contact Tom Brockway at (907) 263- 4135 or Tom McKay at (907) 265-6890. Sincerely,..?' . /' ( >..' Thomas A. Brockway -.~ Operations Drilling Engineer Attachments: cc: Tabasco 2T-210 Well File Tom McKay ATO-1202 Jack Walker ATO-1266 Steve Kranker ATO-1252 Lewis Ledlow ATO-1282 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED r,: 0v - 5 1998 Alaska 0it & Gas Cons. Commission Anchorage TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION October 16. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska. Inc. P 0 Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-210 ARCO Alaska. Inc. Permit No: 98-203 Sur. Loc. 667'FSL, 556'FWL, Sec. 1, T1 IN, R8E, UM Btmhole Loc. 1200'FNL. 603'FEL, Sec. 2, TllN, R8E, UM Dear Mr. McKav: Enclosed is thc approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2T-210. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2T must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Thc blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, nmst be given so that a representative of the Commission may witness the tests. Notice max- be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ S Chairman BY ORDER OF THE COMMISSION dlf/Enclosure Department of Fish & G,'une. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMM[§~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RED 28', Pad 85' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool (proposed) P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 667' FSL, 556' FWL, Sec. 1, T11 N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1543' FNL, 494' FEL, Sec. 2, T11N, RSE, UM 2T-210 #U-630610 At total depth 9. Approximate spud date Amount 1200' FNL, 603' FEL, Sec. 2, T11N, RSE, UM 10/21/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-32 5303' MD 494' @ Target feet 98' @ 700' feet 2560 3277' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 63.5 ] o Maximum surface ]985 psig At total depth (TVD) 2337 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 82' 28' 28' 110' 110' ___200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 4809' 28' 28' 4387' 2838' 373 Sx Arcticset III & 510 Sx Class G & 60 sx AS I 6.75" 5.5" 15.5# L-80 BTCM 4789' 28' 28' 4817' 3035' 123 sx Class G 6.75" 3.5" 9.3# L-80 EUESrd 486' 4817' 3035' 5303' 3277' (included above) 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 sCu°r~adcU;t°r R E C E IV E D ~nrt°~u%~i°;ante 0 ~ ! G ! N A L 0C'~ 0r' 199 Liner Perforation depth: measured Oorm-nissi011 true vertical F-~4~ 0i! & Oas t~ nnhnr,~aP, 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X ....... '" Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is t~ue and correct to the best of my knowledge _.., ~, -- Signed' ~/'~ //~'~',/¢;' ~/// Title Shallow Sands Team Leader Date /~>~/'"" ~J Comrfiission Use Only Permi, L,N_umber~;~_2,..(:::~ ~ I API50_/'/~,.~' '-"number -,~ (::~) 2_ ~ ~ I Approval date /0 '"'*/~,- ¢~ ]SeeotherCOVer letter fOrrequirements Conditions of approval Samples required Yes Mud Icg requirbd Yes Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure for DOPE 2M ~"~ 5M 10M 1 5M Other: dng~nal Signed By Approved by David W, Johnston by order of Commissioner the commission Date /~ "-'/~ Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 85' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool (proposed) P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 667' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1543' FNL, 494' FEL, Sec. 2, T11 N, R8E, UM 2T-210 #U-630610 At total depth 9. Approximate spud date Amount 1200' FNL, 603' FEL, Sec. 2, T11 N, R8E, UM 10/21/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-32 5303' MD 494' @ Target feet 98' @ 700' feet 2560 3277' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 63.51° Maximum surface 1985 psig At total depth (TVD) 2337 psig 16. Casing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 82' 28' 28' 110' 110' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOL 4809' 28' 28' 4387' 2838' 373 Sx Arcticset III & 510 Sx Class G & 60 sx AS I 6.75" 5.5" 15.5# L-80 BTCM 4789' 28' 28' 4817' 3035' 123 sx Class G 6.75" 3.5" 9.3# L-80 EUE8rd 486' 4817' 3035' 5303' 3277' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cerr~t~l C [IV [~- Measured depth True Vertical depth Structural ~% ~ ~ U~ Conductor Surface Production ~ ~ ~ Liner Perforation depth: measured ~]~,S~, 0]] ~: [~-$ C0~S, true vertical ~ ,,luh0, 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is tEue and c. orrect t~ the best of my knowledge ~., ~- ___.,~. ' Signed (,~,/(~" ~"/~--/~'~- Title Shallow Sands Team /~'~//'''' ~;;~ I // ~ ~/~ .,~.. _. Leader Date f,~ Commission use umy Permit Number ~;>-- .~ ~'~ ~' IAPl number50- ~(:~'-- .2._~:~ ,,~....~._~ I Appr°val date//~-/~' ',~ ISee c°ver letter f°rother requirements Conditions of approval Samples required Yes Mud log required Yes ~) Hydrogen sulfide measures Yes (~ Directional survey required ~ No Required working pressure for BOPE 2M (3M9 5M 10M 15M Other: dr~g~-~a.~ signed By Approved by 0avid W. Johnston byorder of /~) "/' Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor September 30, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-210 Tabasco Injector, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, a seal bore, and 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-210, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. Alaska. Inc. is a Subsidiary of AflanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is October 21, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. ~'~.Thomas A. B" roc~a--~~~y Operations Drilling Engineer Attachments: CC: Tabasco 2T-210 Well File Tom McKay ATO-1202 Jack Walker ATO-1266 Steve Kranker ATO-1252 Lewis Ledlow ATO-1282 Drill, Case and Completion Plan for Tabasco 2T-210 (E) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. Move in / rig up drilling rig. Install diverter & function test same. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/4387') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Condition hole for casing, trip out. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. Pick up 6-3/4" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to well total depth (+/- 5303') according to directional plan, running LWD logging equipment as needed. Run open hole wireline logs as needed. Run and cement a tapered production casing string consisting of 5-1/2" 15.5# L-80 BTCM with a 3- 1/2" 9.3# L-80 EUE8RD tail across the Tabasco formation. Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Clean out to top of 3-1/2" casing. Pressure test 5-1/2" x 3-1/2" casing string to 3000 psi for 30 minutes. Record results. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 13si. Set tubing hanger. Install back pressure valve. Nipple down BOP stack. Install production tree and pressure test same. Secure well, release rig. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired Tabasco intervals. Rig down E-line unit. ~ ~, :~:~ Install back pressure valve, shut in and secure well. ocr c . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 2T-210 (E) Page 1 TAB, 09/30/98, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-210 (E) Drillincl Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casin~l 8.5-9.6 16-26 25-50 150-250' 10-20 10-30 8-15 8-10 4-6% Drill out to TD 9.5 8-15 5-8 70-140 2-4 4-8 8-15 9.5-10 4-7% Drillin~ Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 14.1 ppg EMW (0.73 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,811 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' TVD (0.73 psi/fi). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3202 ft)(0.73 - 0.11) = 1985 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/fi). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.1 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3069'. Well Proximity Risks: The nearest existing well to 2T-210 is 2T-32. As designed, the minimum distance between the two wells would be 98' at 700' M D. Drilling Area Risks: Risks in the 2T-210 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 7-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-210 7-5/8' casing annulus will be filled with kill weight brine and diesel after setting the 3-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco 2T-210 (E) Injector Completion 16" Conductor @ 80' Weatherford Gemoco 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/-1868' MD / 1691' TVD) 7-5/8" Surface Casing 29.7# L-80 BTCM (+/- 4387' MD / 2838' TVD) Production Csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-70' above top perf (+/- 4817' MD) Production Csg. 3-1/2" 9.3~ L-80 EUE 8RD-Mod run TD to XO/SBE, (+/- 5303 MD / 3277' -I'VD) · 3-1/2" FMC GEN IV tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel'w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. I jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2' Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2' x 6' L-80 pups installed above and below. EUE 8RD-Mod B. I jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 8' handling pup installed on top. EUE 8RD-Mod box up Baker XO Coupling w/Iocator shoulder, BTC x SBE Baker 5" OD x 4' ID Seal Bore Extension Baker XO, SBE x 3-1/2" EUE 8RD TAB, 9/28/98, v.2 250 250 500 750 lOOO _ 125o- 15o0- 1750 2000 2250 25O0 2750 3000 3250 3500 - ICreated by f~nch For: BROCKWAY Date plaid, ed: 23-$cp-98 Plat Reference i'~ 210 Vcrlian Caord~atea are in feat reference elot j210, [True Vert;co, O.pth~ .... ~ce 7KB (Nordic III)./ RKB ELEVATION: 113' ARCO Alaska, Inc. Structure : Pad 2T Well : 210 Field : Kuporuk River Unit Location : North Slope, Alaska TD LOCATION: J ' 1200' FNL, 60`3' FEL SEC. 2, T1 IN, RSE ITARGET LOCATION: 1543' FNL, 494' FEL SEC, 2, T11N, TBE KOP TVD=500 TMD=500 DEP=500 4.00 BEGIN TURN TO TARGET TVD=650 TMD=§50 OEP=5 7.33 10,64 14.30 18.10 21.98 DLS: 4.00 deg per 100 ft 25.89 29.82 33.76 .37.72 41,68 B/ PERMAFROST 'rVD=1491 TMD=1577 DEP=350 45.65 ~9,65 T/ UGNU SNDS '1'VD=1647 TMD=17gB DEP=507 55,60 57.58 LOC TVD=1840 TMD=2149 OEP=798 341.12 AZIMUTH 3245' (TO TARGET) ***Plane of Proposal*** MAXIMUM ANGLE 63.51 DEG K-l`3 TVD=2084 TMD=2696 DEP=128B T/ W SAK SNOS TVD=222`3 TMD=3007 DEP=1567 TARGET TVD=5069 TMD=4887 OEP=3245 NORTH 5070 WEST 1050 B/ W SAK SNDS TVD=2688 TMD=4050 DEP=2499 BEGIN ANGLE DROP WD=2961 TMD=4662 DLS: 2,00 deg per 100 ft END ANGLE DROP - CSG PT TVD=3044 TMD=,1.8`37 DER=`3201 62.74 TARGET - T/ TABASCO SNDS TVD=3069 TMD=4887 DEP=324.5 ~__ B/ TABASCO SNDS TVO--`3202 TMD=5,~ ~P=3',7~ ",. TARGET ANGLE T~ - CSG PT TVD=3277 TMD=5303 DEP=360~ ~ 60 DEC, I I" '1 I I ' ~ I I I J I ! I I I I I I I 't "1 I I ~ I I I I I I ..... I I 0 250 500 750 lO00 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Vertical Sect[on (feet) -> Azimuff~ 341.12 wilh reference 0.00 N, 0.00 E from slo! ~1210 <- West (feet) 1250 1000 750 500 250 0 I I I I II I I II I I TD - Casing Pt Tabasco Sands TARGET - Top Tabasco Sand End Angle Orop- Casing Pt Begin Angle Drop Base Wes[ Sak Sands Top West Sak Sands K-13 LOC Top Ugnu Bo~c Permafros SURFACE LOCATION: 667' FSL~ 556' FWL SEC. 1, TllN, RBE Begin Turn to Target ~0 250 3500 3250 3000 275O 2500 2250 2O00 1750 1500 1250 1000 750 50O 250 250 Z 0 50 ~_ ~0 ~- 2o 0 Z c~.~ ~ ~o, For: BROCKWAY Dote plotted : 24-Sep-98 Plat Reference is 210 Version ~g. Caordlnates are in feet reference slol t~210. rr~e Ver'dcal Deptha ore reference RKB (Nordic riO, ARCO Alaska, ....... Inc. Field = Kuparuk River U.if LocaHon = North Slope, (- West (feet) 1 O0 90 BO 70 60 50 4-0 ,30 20 10 0 1 0 20 ,30 4-0 50 60 \\, .... ~/ / · ', 1 ~o 1 '5 "; o \ /' / '\\,\\ " ',, /900 lOO / 90 ,.\ 11 O0 / ;; //' ; \ ~ 3OO "~, 1000 ',, '~, 1200 800 9 od,., \, '.;,1 11 .... . '~,-,,8o~ 80 '""\\,\,, 70 "\\, '"-.. 700 10 1200 1600 6OO / 600 ! ~" 500 //500 ~oo 50O '"'",i 1~oo 1000'~, "-....700 1100 '-.. 900 ....... ~ 500 6OO 120 110 1 O0 90 80 7O 60 50 40 20 10 Z 0 30 1100 1400'"~ 20 3O 40 50 700 .~. 6OO 5oo ....... -~ 60 1 O0 90 80 70 60 50 40 30 20 10 0 <- West (feet) 1000 500 6OO 10 20 30 40 50 60 40 50 60 420 400 38O 360 340 320 300 28O 260 240 220 200 180 160 ~ '~"~'"" For: BROCKWAY D~te plotted : 24-Sep-98 Plot Reference is 210 Version ~g. Coord/nat~ am ;n feet refet~ce ~ot ~210. Vedical Dep~a ere reference RKB (Nordic 140 12o 100 80 Structur~: Pod 2T Field : Kuparuk River Unif h Slope, Alaska <- West (feet) 280 260 240 220 200 180 160 140 120 1 O0 80 I ~ I[~l I I I I I \ ~ ~8oo 1600~ ~ 2100 '"~ 2000 I \ I \ 1800 2300 2000 1900 2400 1600 1700 t ~ 1500 16oo '\ ~, 1400 \, i 200 t 700 '~ 1600~ 2000 1900 % I I I I I 280 260 240 I 220 1500 1400 ~9oo '~1300 60 40 20 0 20 40 1800 420 400 380 360 340 320 1700 300 280 260 240 \"\ ",,",,o /7oo , ; '~ 1300 1500~ 1800 / 180 '"'"",,,,,, ',. 12oo \, ~ ,.. ] 6oq:~oo .... \, : '-.. 600 / ~ '"--.. 11 O0 \", 1200 ~ '"""'--~ 500 / ;/ ~ 40 lOOO ~%~,--~\__ \ 1.oo .... ' , ,' 800 12o 1800 '",,, ~,," 100 · % 1100\ · , ',,, ,,' soo 80 ,,, ",\ ... 1600 1600 I I I ! I I 200 180 160 140 120 1 O0 80 <- Wesf (feet) % 60 40 20 0 20 40 220 60 /x Z 0 ~.o~ ~ ~ For: BROCKWAY O~te plotted: 24-Sop-g8 Rot Reference is 210 Version Coord[na[~ am in fe~ reference slot ~210. [rue VerUcal Depths ere relerence RKB (Nordic III). <- West (feet) 11 O0 1000 go0 800 700 600 500 400 300 200 1 O0 2200 2100 2000 1900 1800 1700 1600 1500 1400 "*- 1300 1200 0 Z 1100 4100 ~, 2500 3900 ARCO Alaska, Inc.[ / Field: Kuparuk River Unit Location: North Slope, AlaskaI I I O0 ~ 2900 3100 3700 , 2 O0 2700 ~23u0 2900 ~ 2500 },2500 270~ i2300 2~00 ', I 400 300 OhO 1 O0 <- West (fete ~ 2100 \, 2500 2500 3100\ 230~ 1000 9OO 290~1900 700 210' ~ 27~ ,oo 5oo, ioo 300 ~ ~ ~ ~ ~ ~ , 1100 1000 900 800 700 600 500 Cons. Anchoyag~ ~ 0 1 O0 200 300 400 500 I I I I I i 2300 l / : i / i ! ; ! ,' ! 1700 i 2100 / ! ! 29od I ! ,, I 2500 / ,,' i ! , I I ; I I ! / ; / ~190o ~7oo I , i i 15oo 2300 / ; ! I 2300 ,,' i ,,' 1700 2100 1900 1 lOOj 2200 2100 2000 1900 1800 1700 1600 15OO 14oo Z 1300 0 1200 --I- 1100 v 1000 900 800 700 6OO / 400 ~' 3o0 )200 300 400 500 190~ · ' 500 ~.,~ ~ ~- For: BROCKWAY Dote plotted: 24-Sep-~8 Plot Reference is 210 Version ~or~nates em in leer r~ence slot ~210. r~e Vertical Oep~s ere reference RKB (Nord~ Ill), 3000 2900 2800 27O0 ARCO Alaska, lnc. I ............ Structure: Pad 2T Well: 210 Field: Kuporuk River Unit Location: North Slope, <- West (feet) 1~30 1600 1500 1400 1300 1200 1100 1000 g~ 800 700 600 500 4~ 300 200 1< 3700 I I I I I I I I I I I I I I I I ! I I I ! I I I I I ~1 I I I I 3600 3500 3500 3400 3200 , 3300 5300 \ ~ ~oo 3100 \ 2600 3100 4700 Xi 2300 ~ i 2aoo 4300 ~ ~ 3~00 2200 ' [ 2200 3300 2100 ', i 2100 2900 4100 \ \ 2000 ~ 2500 ~ 2000 ~ 2900 ', 3100 1900 1 1900 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 ¢00 300 200 100 <- West (feet) 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 27OO 26OO 25OO 2400 /x I Z 0 ARCO Alaska, Inc. Pad 2T 210 slot #210 Kuparuk River U~it North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 210 Version #9 Our ref : prap3052 License : Date printed : 23-Sep-98 Date created : 14-Jul-98 Last revised : 23-Sep-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.172,w150 0 47.034 Slot location is nT0 19 51.732,w150 0 30.800 Slot Grid coordinates are N 5970647.069, E 498945.194 Slot local coordinates are 667.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object wellpath PMSS <893 - 12977'>,,23,Pad 2T PMSS <469-10632'>,,18,Pad 2T POMS <0-7897'~,,3,Pad 2T PMSS <0-9298'),,27,Pad 2T PMSS <0-4175'),,201,Pad 2T PMSS <918 - 10193'),,22,Pad 2T PNSS <741-15471'),,36,Pad 2T PMSS c0 - 9210'),,26,Pad 2T PMSS <0-12821'),,21,Pad 2T PMSS <921-10235'),,20,Pad 2T PMSS <918' - 10890'),,28,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PONS <0-8262'>,,14,Pad 2T PONS <0-7625'>,,15,Pad 2T PMSS <1604-3625'>,,16,Pad 2T POMS <0-8947'>,,16B,Pad 2T PMSS <5917-7957~>,,16A, Pad 2T PONS <O-7650~>,,8,Pad 2T PGTIS <O-8250~>,,10,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PMSS <0-9845~>,,19,Pad 2T PMSS <0-10570~>,,29,Pad 2T POMS <0-8890'>,,2A, Pad 2T PMSS <1287-1725'>,,2,Pad 2T PMSS <4757-6800'>,,12A, Pad 2T POMS <0-6725~>,,12B,Pad 2T PMSS <3115 - 3645~>,,12,Pad 2T PGHS <O-6789~>,,11,Pad 2T Closest approach with 3-D MinimumDistance method Last revised Distance M.D. Diverging from M. D. 25-Aug-98 235.0 100.0 5100.0 1-Apr-98 701.7 400.0 400.0 26-Aug-98 289.9 300.0 300.0 23-Jan-98 172.9 550.0 550.0 26-Aug-98 427.5 100.0 100.0 23-Jan-98 249.3 700.0 700.0 23-Jen-98 652.0 100.0 100.0 23-Jan-98 189.7 500.0 500.0 23-Jan-98 749.9 200.0 200.0 23-Jan-98 700.3 975.0 975.0 23-Jan-98 152.5 675.0 675.0 23-Jan-98 756.5 550.0 550.0 23-Jan-98 612.1 525.0 525.0 23-Jan-98 639.6 500.0 500.0 23-Jan-98 665.0 0.0 0.0 23-Ean-98 665.0 0.0 0.0 23-~an-98 665.0 0.0 0.0 23-~an-98 414.3 525.0 525.0 23-~an-98 514.4 650.0 650.0 23-~en-98 98.3 600.0 600.0 23-Jan-98 718.2 550.0 550.0 23-~an-98 145.0 100.0 100.0 26-Au9~98 239.0 850.0 850.0 26-Aug-98 239.0 850.0 850.0 23-~an-98 561.6 550.0 550.0 23-~en-98 561.6 550.0 550.0 2B-Jan-98 561.6 550.0 550.0 23-Jan-98 539.9 300.0 300.0 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 16-Jul-98 16-Jul-98 24-Feb-98 24-Feb-98 24-Feb-98 26-Aug-98 590.0 689.9 313.9 338.3 346.0 389.9 439.9 602.0 105.5 105.5 98.0 98.0 98.0 166.2 0.0 100.0 500.0 525.0 800.0 525.0 200.0 100.0 800.0 800.0 700.0 700.0 700.0 1050.0 500.0 100.0 500.0 525.0 800.0 525.0 500.0 100.0 800.0 800.0 700.0 700.0 700.0 1050.0 16" DIVERTER SCHEMATIC - Nordic Rig 3 Kuparuk River Unit Tabasco Operations ,, [ I '~~ ~. To Accumulator / ! ! ! ! ~ ~. ....From ~ 5 ~ ',' , ', Accumulator I I c~os~ ,, [ Maintooanco & Opomtion Open 1. ~n initial installation: - Cioso prov~nlor to wri~ operation and that tho valvo opons immediatol~ 2. GIoso annular pmvontor in tho ov~nt that an influx well~oro fluids or ~as is dot~od. Opon va~ to achiovo diw~ion DO ~OT 8H~T-I~ DI~T~ ~D 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange 8. 13-5/8" Hydril GK 5000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line 7-1/16" b 000 psi BOP Stack-- N rdic Rig 3 Kuparuk River Unit Tabasco Operations -Injector Wells Kill Line 3 I. Choke Line Accumulator Capacity Test 1, Check and fill accumulator reservoir to proper level with hydraulic fluid, 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16' Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8' 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3' 5000 psi Manual gate, 2 Kill valves each are 3' 5000 psi gate 5. 7-1/16' 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAR 1R/i31/gfl. v.2 -~--e 218 --4 215 '" 62.5' o 210 o 209 o 208 . . . i · ~1 ' . ~o ~ONI~ MAP ~'= 2 · 29 e 28 · 27 SEE SHEET 2 F~ NO~S ~D e 26 LOCA~ON INFORMA~ON ~ 202 e 23 . 7 201~ 8 · 9 - ~ e 12 I 38®e 13 < · 14 (NO SCALE) 2 1 ' · 15 I 11 I 12 i e. ~7 , e DRILL SITE . ~9 e 20 , 2-T . . o NEW CONOUCTm L~AnONS ~ LOUNSBURY' e EXiS~NG CONDUCTUS ~/~[ R ~SOC~TES, INC. AR~: 2T M~U~ XX UNIT: D2 Subsidiary of Atlantic Richfield Company AS-BUILT LOCA~ ~.nn c,, c k,n I [ n=~Mc mn. REV l OATE I e~' i CK I APPI PER KSB~ K98075ACS NOTES 1. BASIS OF LOCATION AND ELEVATION ARE ORILLSITE 2--'1' MONUMENTS PER LHD &: ASSOCIATES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4. N.A.D. 27. ALL DISTANCES ARE TRUE. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. 4. WELLS ARE LOCATEO ~THIN PROTRACTED SECTION 1, T. 11 N., R. 8 E., UMIAT MERIDIAN, ALASKA. 5. OATE OF SURVEY: 9/13/98, FIELD BK. L98-71 PG. 14-25. 6. DRILl. SITE 2-T GRID NORTH IS ROTATED 179' 59' 40' WEST FROM A.S.P. ZONE 4 GRID NORTH. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2--17 LOCATIONS, CEA-D2TX-6220D7 FOR CONDUCTOR 18-2,], 26-32. 36-`]8 & TABASCO LOCATIONS, AND CEA-D2TX-6220D9 FOR CONOUCTOR 202. VICINITY MAP ,' = 2 u.zs LOCATED IN SECTION 1, T 11 N, R 8 E, U.M. SEC. SEC- - WELL UNE UNE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L F.W.L 207 5,970,610.10 498,945.02 70'19'51.568' 150'00'30.805" 650' 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70'19'51.492' 150'00'50.610' 642' 556' -75.2' 80.4' 209 5,970,655.10 498,944.90 70'19'51.614" 150'00'50.809" 655' 556" 74.9' 80.4' 210 5,970,647.69 498,944.75 70'19"51.758" 150'00'50.814" ~67' 556' 74.7' 80.4' 215 5,970,709.72 498,94 4.99 70'19'52.`]48' 150-00'50. 807' 729' 556' 74.2' 80.4' 21B 5,970,747.74 498,944.97 70'19'52.722' 150'00'30.807" 768' 556' 74.1' B0.4' 220 5,970,772.57 498,944.90 70'19'52.966' 150'00'50.810' 792' 556' 74.1' B0.4' SURVE¥~°S CERTIFICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company ~· I"~l&"~l~ 1""11 L' m. ll"~ I I IP~OA~I.I~"'~' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND_ THAT ALL DIMENSIONS AND OTHER DETAILS'ARE CORRECT AS OF SEPTEMBER 16, 1998. . LOUNSBURY & ASSOCIATES, INC. ERS PLANI~I~S SURVEYO~ ARE~ 2T MODULE: XX UNIT: D2 DRILL E~TE 2-T WELL CONDUCTORS 207-210,215,218 & 220 AS-BUILT LOCATION ARCO Alaska, Inc. ~" Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor September 30, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-210 Tabasco Injector, Kuparuk River Unit Dear Sirs: RECEIVFD 0CT O 2 q998 Anchorage ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, a seal bore, and 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2'1'-210, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. Please note that the anticipated spud date for this well is October 21, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincer.,~ ~ .,/,' Thomas ^. Brockway ~ Operations Drilling Engineer Attachments: CC: Tabasco 2T-210 Well File Tom McKay ATO-1202 Jack Walker ATO-1266 Steve Kranker ATO-1252 Lewis Ledlow ATO-1282 RECE VFD OCT 0 '\9 g Anchorage Drill, Case and Completion Plan for Tabasco 2T-210 (E) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/4387') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Condition hole for casing, trip out. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. Pick up 6-3/4" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to well total depth (+/- 5303') according to directional plan, running LWD logging equipment as needed. Run open hole wireline logs as needed. Run and cement a tapered production casing string consisting of 5-1/2" 15.5# L-80 BTCM with a 3- 1/2" 9.3# L-80 EUE8RD tail across the Tabasco formation. Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Clean out to top of 3-1/2" casing. Pressure test 5-1/2" x 3-1/2" casing string to 3000 psi for 30 minutes. Record results. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. Nipple down BOP stack. Install production tree and pressure test same. Secure well, release rig. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired Tabasco intervals. Rig down E-line unit. RECEIVED . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Install back pressure valve, shut in and secure well. 2T-210 (E) Page 1 Alaska 0il & Gas Cons. 6ommissioB TAB, ,~g~/a~, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-210 (E) Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 8.5-9.6 16-26 25-50 150-250' 10-20 10-30 8-15 8-10 4-6% Drill out to TD 9.5 8-15 5-8 70-140 2-4 4-8 8-15 9.5-10 4-7% Drillinq Fluid System' Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 14.1 ppg EMW (0.73 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,811 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' TVD (0.73 psi/fi). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3202 ft)(0.73 - 0.11) = 1985 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.1 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3069'. Well Proximity Risks: The nearest existing well to 2T-210 is 2T-32. As designed, the minimum distance between the two wells would be 98' at 700' MD. R £ .IVED OCT 0 2 i.998 Alaska 0il & Gas Cons. Drilling Area Risks: Risks in the 2T-210 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 7-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-210 7-5/8" casing annulus will be filled with kill weight brine and diesel after setting the 3-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco 2T-210 (E) Injector Completion 16" Conductor @ 80' Weatherford Gemoco 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/-1868' MD / 1691' TVD) 7-5/8" Surface Casing 29.7# L-80 BTCM (+/- 4387' MD / 2838' TVD) Production Csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-70' above top perf (+/- 4817' MD) Production Csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 5303 MD / 3277' TVD) · 3-1/2" FMC GEN IV tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3~ EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Baker XO Coupling w/Iocator shoulder, BTC x SBE Baker 5" OD x 4" ID Seal Bore Extension Baker XO, SBE x 3-1/2" EUE 8RD Oas Cons. Oo .... Anchorage TAB, 9/28/98, v.2 25O 250 5OO 75O 1000 1250 1500 1750 2000 225O 25O0 2750 3000 5250 RKB ELEVATION: 113' 3500 m-T--,---r--.-.--.-r--,r---,-~---I 0 250 500 ARCO Alaska, Inc. Structure : Pod 2T Well : 210 Field : Kuporuk River Unit Location : North Slope, Alosko TD LOCATION: I 1200' FNL, 603' FEL SEC. 2, TllN, RSE (- West (feet) 1250 1000 750 500 250 I I I I I I I I I . I TARGET LOCATION: 1543' FNL, 494' FEL KOP TVD=500 TMD=500 DEP=500 SEC. 2, T11N, TSE 4.00 TARGET BEGIN TURN TO TARGET TVD=650 TMD=650 DEP=5 TVD=3069 7,33 TMD=4887 10 64 NORTH 3070 \ 1~ 30 34 1.1 ~ AZIMUTIt OEp=324s ~'~;.lO 3245' (r0 TARGET) wes, ~o5o '~t21.98 BLS: 4.oo de9per 100 rt ***Plane of Proposal*** X25.89 ~ 29.82 xX 33.76 X, 37.72 "X. 41.68 B/ PERMAFROS]' TVD=1491 TMD=1577 DEP=550 ',,, 45.65 -.~.'"'- %~6ov UON~ SNOS ~0=1~,~ T~O=,~ 0E,=~0~ A~~1840~1 ~ TMD=2149 DEP=798 MAXIMUM~*WU~u ANGLE ~ ~-1; w~=:os,,u~=2s~ ~=l:Sa 63 51 DEG 63.51 DEG 5 TMD=5007 OEP=]567 B/ W SAK SNDS TVD=2588 TMO=4O50 DEP=2499 BLS': 2..00 de~ per 100 ~t 62.74 TARGET - T/ TABASCO SNI)S TVD=3069 TMD=4887 DEP=3245 TARGET ANGLE 60 DLG SURFACE LOCATION: ~---~'~---~ ...... ~ ...... ~ ~ "-~-~--~---r ..... ~ ....... ~--'~ ....~-"~--~ ........ r--~-'--i ....~ .... T~'r~-r-'~ ~ 667' FSL, 556' FWL SEC ] TllN RSE ~o ~o~o ~o VeHicol Section (feet) -> TD - Casing Pt Base Tabasco Sands TARGET - Top Tabasco Sand End Angle Drop - Casing Pt Begin Angle Drop 0 25o I I I Base West Sok Sands Top West Sak Sands K-13 EOC Top Ugnu Sonds Bose Perrnofr~ Begin Turn to Forget 2'90 Azimuth 34.1.12 with reference O.00 N, 0.00 E from slot ./t210 3500 3250 3000 275O 25OO 2250 A 2000 I 1750 1500 1250 lOOO 750 5o0 250 250 c,,~ ~ ~,~ For: BROCKWAY Dote plotie6: 24-~ep-98 Plot Reference ).~ 210 Version Coordln~tes ~re in feet reference ~lot ~210. F~e Vert~coJ Depths ore reference RK~ (N~rd[: Iff). l~Tg~ 100 90 80 70 60 50 40 120- 110 lO0 8O 60 5O Q~ ~ 50 V 2O 0 3O 40 5O 60 1 O0 \ ". 11 O0 8OO -. 12OO --%700 lO0 ARCO Alaska, Inc. Structure: Pad 2T Well: Field: Kuporuk River Unit Locaffon: North Slope, Aloska 17O0 <- West (feet) 30 20 10 RECEtYE ^I%¢;~, Oij~. ~.s Cons. c ....... ;8 40 5o ,// // /'600 /' ; 500 " .(~i~000 1000 ',, 1600 .- ; ." '"',, '"~ ~2oo .~..,..-" s~'~,, '"',, ~ · ,~:¢,oo~ ~oo '"'""'""-.. lO~'~,~'""",.2oo "'.. 600 "'"'-.. % 900 " ....... .~ 500 '~ 400 ,/ ,/ 700 ,, /9oo · ,,,' /, // / / ../800 // / ?' /*' / /,,."~'00 /' 1200 6O0 1100 700 90 80 70 60 600 5O 40 5OO 3O 2O <- Wesf 1(] o 10 20 1000 6OO ~)' .... 900 ,30 40 50 6O 80 120 110 100 go 7o 60 4O 3O 20 5o 40 50 I Z 0 Coord;nQtes ore in feet reference slot ~210. True Verticel Depths ~nce RKB (Nordic 28O 260 ,4- 240 "~ 220 0 ~r~=. For: BROCI<~AY Dote plotted : 24-Sep-98 P~ot Reference is 210 Version ARCO Alaska, Inc. Structure: Pad 2T Well: 210 Field: Kuparuk River Unit Location : Nodh Slope, Aloska <- West (feet) 280 26(] 240 220 200 180 160 140 120 100 80 60 40 20 16oo\ ~ 21oo \'~ 2000 """',,, 1800 2300 2000 1900 1600 1500 400 '~,900 1800~ i i 1200 1700i 2000 9OO 420 400 380 2400 360 340 32O 300 200 180 1600 160 140 120 100 80 I i i I I 280 260 240 17OO ' I 22O 0 20 40 I I I I I I I I I 1800 1700 "~ 1400 1600~ ,, ',, ,, ,, ";8 0 ', 1300 1500~ "\ t \,,,\,, '"', ",,,,, 18 O0 , 700 ',. 1500 200 '"'""'-. 600 '%.. "'"""-~...500 "--.. 11 O0 \' 1 200 '" ............... '\" °00 ",1400 -.... ,\\\,,,,, - .....~?- .... 600 ~ aoo ",, \,, ~/' ". 1100", ,,, ,,,, '". ..' 500 '"',,,, ,\,\, 1600 1600 1300 "-,~ 1000 '-. 1 40t . , , . 200 180 160 140 120 1 O0 80 60 40 20 0 <- West (feet) % 420 400 380 360 34O 320 3OO 28O 260 I z o 240 220 / / I 200 700 ,, 180 /¢ 1~00 .., 160 6oq"6oo // / 8oo 120 lO0 80 60 20 40 ~,o~ ~ ~'~o~,o~ For: BROCICffAY [ Dote plotted : 24-$ep-98 [ Plot Reference is 210 Version ~g. [ Coordinates are in feet reference slot ~210. I True Vertical Depths ~nce RKB (Nordic 111)1 Structure: Pad 2T II Field : Kuparuk River Unit Location : North Slope, Alask~i OCT 07. <- West (feet) Alaska Oil & Gas Cons. Oommi~iO~ 11 O0 1000 go0 800 700 600 500 400 500 200 1 O0 0 0 300 400 500 22OO 2100 2000 1900 1800 1700 1600 15OO A 1400 I "+- 1300 1200 Z 1100 lOO0 9OO 800 7OO 6OO 5OO 400 300 41 O0 \ ~ 2500 39oo ",,,,,,,,,,, 3700 2700 2500 230 25OO 2700 ~, 2900 3100 ~ 2900 2100 51 O0 \, 2300 · 2700 i 2500 2700\ 25OO ~ 2300 2~500 2900'~~900 270N ;, \, i2300 / / / / / / i21 O0 / i i i i i i i i 19oo / 2500 / / ." 1700 2100 25OO 2500 / ! 1900 / 110~ 2200 I i I I I i i i i i I i i 100 1000 900 800 700 600 500 2100 2OOO 1900 I 1800 ! 1700 i / / 1700 I 2900 / 1600 / ! ! 1500 I I / / ! I ! ~700 1500 1 14oo Z 1300 0 --I- 1200 ~ 1100 ~ 1000 / 900 70O 800 7o0 600 19o6 · ' 500 ,/ 400 ~, 300 400 300 OflO 1 O0 0 10C ~200 300 400 500 <- West (f~f) ARCO Alaska, Inc. o~0~v.~o~.~. For: BROCKW'AY Structure: Pad 21 Well : 210 Plot Reference is 210 Version ~9. I Field : Kuparuk River Unit Location : North Slope, Alaska Coord[nates are ;n feet reference slot ~210. T~e Ve~COI Oep~ Cm RK8 (Nord)~ imm). ~ ~ t ~.~t~ (~ ~ ] <- West (feet) ~nch. qra~. 1~20 1600 1500 1~00 1~00 1200 1100 1000 900 800 700 600 500 ~00 300 200 3~00 3500 3500 3400 ~200 5~00 3300 ~, 3100 3100 3ooo ~X ~ ~00 5100 3~00 2goo 2700 490C O0 2600 $100 4700 2500 ~~ ~ ~ 3300 ~, ~ 3soo ~ 2~oo 2~00 2300 ~ "',, ' ~ 2500 2ooo ~ h 2500 ~ 2ooo ~ i 2900 1 go0 ~ ' 1 go0 1700 1600 1500 1 ~00 1 ~00 1200 11 O0 1000 900 800 700 600 500 ~00 ~00 200 1 O0 <- West (feet) 3700 3600 3500 3400 3500 3200 3100 3OOO 2900 2800 2700 2600 25OO /'x I Z 0 ARCO Alaska, Inc. Pad 2T 210 slot #210 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 210 Version #9 Our ref : prop3052 License = Date printed = 23-Sep-98 Date created : 14-Jul-98 Last revised : 23-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.172,w150 0 47.034 Slot location is nT0 19 51.732,w150 0 30.800 Slot Grid coordinates are N 5970647.069, E 498945.194 Slot local coordinates are 667.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object wellpath PMSS <893 - 12977'>,,23,Pad 2T PMSS <469-10632'>,,18,Pad 2T PGMS <O-7897~>,,3,Pad 2T PMSS <O-9298~),,27,Pad 2T PMSS <0-4175~),,201,Pad 2T PMSS <918 - 10193'~,,22,Pad 2T PMSS <741-15471~>,,36,Pad 2T PMSS <0 - 9210~>,,26,Pad 2T PMSS <0-12821'>,,21,Pad 2T PMSS <921-10235~>,,20,Pad 2T PMSS <918' - 10890'~,,28,Pad 2T PMSS <650 - 11080'),,37,Pad 2T PGMS <0-8262'>,,14,Pad 2T PGMS <O-7625~>,,15,Pad 2T PMSS <1604-3625~>,,16,Pad 2T P~MS <O-8947~>,,16B,Pad 2T PMSS <5917-7957~>,,16A, Pad 2T PGMS <0-7650~>,,8,P&d 2T PG~S <O-8250'>,,10,P&d 2T PMSS <380 - 11400~>,,31,Pad 2T PMSS <0-9845~>,,19,Pad 2T PMSS <0-10570~>,,29,Pad 2T PGMS <0-8890~>,,2A,Pad 2T PMSS <1287-1725~>,,2,Pad 2T PMSS <4757-6800~>,,12A, Pad 2T PGMS <0-6725~>,,12B,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PGMS <O-6789">,,11,Pad 2T Closest approach with 3-D Last revised Distance 25-Au9-98 1-Apr-98 26-Aug-98 23-Jan-98 26-Aug-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 26-Aug-98 26-Aug-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 235 0 701 7 289 9 172 9 427 5 249 3 652 0 189 7 749 9 700 3 152 5 756 5 612.1 639.6 665.0 665.0 665.0 414.3 514.4 98.3 718.2 145.0 239.0 239.0 561.6 561.6 561.6 539.9 Minimum Distance method 100.0 400.0 300.0 550.0 100.0 '700.0 100.0 500.0 200.0 975 0 675 0 550 0 525 0 500 0 0 0 0 0 0 0 525 0 650 0 600 0 550 0 100.0 850.0 850.0 550.0 550.0 550.0 300.0 Diverging from M.D. 5100.0 400. 300. 550. 100. 700. 100. 500. 200. 975. 675. 550. 525. 500. O. O. O. 525. 650 600 550 100 850 850 550 550 550.0 300.0 PGMS <0-7868~>,,13,Pa=~l.z PGMS <O-8445~>,,17,Pad 2T PGMS <O-8160~,,4,Pad 2T PG~S <0-7670~>,,5,Pad 2T PG~S <0-8208'>,,6,Pad 2T PG~MS <0-6975~>,,7,Pad 2T PG'MS <0-6370~),,9,Pa~ 2T PMSS <12144-13360t),,38A, Pad 2T PMSS <4627 - 10686t>,,30A,Pad 2T PMSS <0-4749~>,,30,Pad 2T PMSS <5497-13787~),,32B,Pad 2T PMSS <0-5924~>,,32,Pad 2T PMSS <4850 - 5918~),,32A, Pad 2T MSS <4046-4427~>,,202,Pad 2T 23 23 23 23 23 16 16 24 24 26 -Jan-98 -Jan-98 -Jan-98 -Jan-98 -Jan-98 -Jan-98 -Jan-98 -Jan-98 -Jul-98 -Jul-98 -Feb-98 -Feb-98 -Feb-98 -Aug- 98 590.0 689.9 313.9 338.3 346.0 389.9 439.9 602.0 105.5 105.5 98.0 98.0 98.0 166.2 0. 100. 500. 525. 800. 525. 200. 100. 800. 800. 700. 700. 700. 1050. 0 0 0 0 0 0 0 0 0 0 0 0 0 500.0 100.0 500.0 525.0 800.0 525.0 500.0 100.0 800.0 800.0 700.0 700.0 700.0 1050.0 16" DIVF=RTER SCHEMATIC- I~ordic Rig 3 Kuparuk River Unit Tabasco Operations Closed I I I I I I I ~_ .... From , , Accumulator I I I I ! Closed I I Maintenance & Operation Open 1. Upon initial installation: i-~l - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange 6. 13-5/8" Hydril GK 5000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line TAB, 07/29/98, v.1 7-1/16" r300 psi BOP Stack-- I . .rdic Rig 3 Kuparuk River Unit Tabasco Operations -Injector Wells Kill Line [/ 3 Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 REVi DATE I By I CK J APPJ DESCRIPTION K98075ACS ~: CK lAPPI DESCRIPTION 1 19/16/98 MET JM PER. ..~B# , . o ~0 ~$.0' I ~ 215 ~ , m ~ ~0~ e 31 e 3o ~ClNI~ MAP · 29 · 28 · 27 SEE SHEET 2 FOR NOTES AND e 26 LOCA~ON INFORMA~ON · 202 · 2~ · 22 i ' 8 4 · 5 e 6 i ~8 ee ~ 4 i[.I(NO SCALE) ! · 15 11 :~[ : l I I ~ 18 ~ D~ILL SITE e 2-T , ~ ~ A~chorag~ ~ND o.~w co.~UCTOR Loc,~o.s ~ LOUNSBUR'Y' e EXISTING CONDUCTORS ~/J~ ~ ASSOCIATES, INC. AREA: 2T ~ULE: XX UNIT: D2 ~ DRI~ SI~ 2-T Subsidiary of Atlantic Richfield Company AS-BUILT LOCA~ CADO FILE NO. ~ I DRA~NO NO:IsHEET: ~K6~2o~2 ~/~/~ C[~-D2~-~22OD12 oo~ 9/16/98J MRT JM PEk .... SBt~ K98075ACS ; ; ; NPTES 1. BASIS OF LOCATION AND ELEVATION ARE DRILLSI~ 3. ELEVATIONS SHO~ ARE B.P.M.S,L, T. 11 N., R. B E., UMIAT MERIDIAN, ALASKA. 5. DATE OF SURLY: 9/13/98, FIELD BK. L98-71 pg. 14-23. 6. DRILL Sl~ 2-T GRID NOR, IS ROTA,D 179' 59' ~" ~ST FROM A.S.P. ZONE 4 GRID NOR~. 7. SEE REFERENCE DRA~NCS: CEA-D2TX-866, FOR CONDUCTOR 2--17 LOCATIONS. CEA-D2~-6220D7 FOR CONDUCTOR 18-25, ~CINI~ M~ 26-52. 56-58 ~ TABASCO LOCATIONS, AND CEA-D2~-6220D9 FOR CONOUCTOR 202. LOCA~D IN SEC~ON 1, T 11 N, R 8 E, U.M. SEC. SEC. ~LL LINE LINE O.G. PAD NO. Y X LATI~OE LONGI~OE O~S O/S ELEV. ELEV. F.S.L F.W.L. 207 5,970,610.10 498,945.02 70~ 9'51.568" 150~0'30.805" 650' 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70~ 9'51.492" 150~0'30.810' 642' 556' 75.2' 80.4' ,. . 209 5,970,655.10 498,944.90 70~ 9'51.614" 150~0'50.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.75 70~9'51.758" 150~0'30.814" ~67' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70~ 9'52.~48' 150~0'50.807" 729' 556' 74.2' 80.~' 218 5,970,747.74 498,944.97 70~ 9'52. 722" 150~0'30.807' 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70~9'52.966' 150~0'50.810" 792' 556' 74.1' 80.4' ., ~ ~,,, ~ '*,~_~& I HEREBY CERTIFY THAT I ~ PROPERLY REGISTERED AND ~ ~ ~ ~. LICENSED TO PRACTICE LAND SURVEY-lNG IN THE STATE OF ~ ~ 49~h ~ ~t ~ ~L~SKA AND THAT THIS PLAT REPRESENTS A SURLY .... .~..... .. .... .~..... ~ ' ~' " OONE By ~ OR UNDER ~ OIRECT SUPERVISION AND ~ ..... ~,~' .... ~ THAT ALL OI~NSIONS ANti OTHER OET~ILS ARE CORRECT ARE~ 21 M~ULE: XX '" UNII: 02 ARCO Alaska, Inc. D.u Sim 2-T ~ ~ CONDUCTOES 207-210,215,218 ~ 220 Subs~diory of AUontic Richfield Compony AS-BUILT LOCA~ON II I kK~22012 0/1~/~ C[~--~2~--~220~1 2 O02 WELL NAME ,,~z~7-_-.~ .~ ~'"'.2-./~ PROGRAM: exp [] dev [] redrll [] serv,,~wellbore seg II ann. disposal para req ~ FIELD & POOL INIT CLASS ADMINISTRATION 1. Perrnit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operalor only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued wilhout conservation order ........ 12. Permit can be issued withoul administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CM I' vol adequale to tie-in long string to surf csg ........ 18. CM I' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation .............. 26. BOPE press rating appropriate; test to ~c:~> psigl 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA ~'74:~ UNIT# ON/OFF SHORE ~ .... .. N N N N IN N N N ~N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seisnlic analysis of shallow gas zones ..... ' ........ 33. Seabed condition survey (if off-shore) ............. 34. Con, lacl,nam, elphon,e.for weekly progress reports ....... J Y N lexp~ora~ory on~yj ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) Will not contaminate freshwater; or cause drilling waste.. · 1o surface; (C) wiii'~ibtimpair._mechanical integrity of the well used for disposal; (1~) will nol damage producing formation or impair recovery from a pool; and (.E) will not circumvent 20 AAC 25.252 or 20 AAC 25,412. Y N GEOI~..GY: ENGi~EERiN(~i UIC/Annular ' c°i~iviissi°N: JDH~ RNC~, co Co ~/~ ~lcheklisl lev 05129198 dlf C ~fll,;¢)fli( (~wc~rdinrl~dlnfi;l\, h~ I, h,I Y N Y N Comments/Instructions: Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Jan 04 17:07:16 1999 Reel Header Service name ............. LISTPE Date ..................... 99/01/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/01/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KAPARUK RIVER (TABASCO POOL) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 A_K-MM-90018 J. SACK F. HEBERT RECEIVED 0AN 06 · · ~ 2T-210 m~ 501032027300 ~CO ~~, INC. SPERRY-S~ DRILLING SERVICES 04 -J~-99 MWD RUN 2 MWD RUN 3 AK-MM-90018 AK-MM- 90018 J. SACK J.SACK F. HEBERT D. LUTRICK 1 liN 8E 667 556 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 117.30 80.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 117.0 24.000 7.625 4410.0 9.875 4410.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER' S DEPTHS. DEPTH CORRECTION OF MWD DATA IS WAIVED AS PER DEDE'S E-MAIL ON 12/29/98. MWD IS PDC. 3. MWD RUNS 1, 2, AND 3 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR4) . 4. 7.625" CASING WAS SET AT 4410'MD, 2833'TV]D. DATA ACQUIRED WHILE IN CASING NOT PRESENTED. 5. MWD RUNS 1 THROUGH 3 REPRESENT WELL 2T-210 WITH API# 50-103-20273-00 . THIS WELL REACHED A TOTAL DEPTH (TD) OF 5340' MD, 3275' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMA~IY PBU TOOL CODE START DEPTH FET 100.5 RPD 100.5 RPM 100.5 RPS 100.5 RPX 100.5 GR 100.5 ROP 111.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 5295 0 5295 0 5295 0 5295 0 5295 0 5288 0 5340 0 EQUIVALENT UNSHIFTED DEPTH ......... BIT RUN NO MERGE TOP MERGE BASE 1 117.0 3449.3 2 3449.3 4410.0 3 4410.0 5340.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 ROP MWD FT/H 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 100.5 5340 GR 8.4541 145.084 RPX 0.0758 2000 RPS 1.0528 2000 Mean Nsam 2720.25 10480 68.9705 10376 28.3422 10390 43.437 10390 First Reading 100.5 100.5 100.5 100.5 Last Reading 5340 5288 5295 5295 RPM 0.0804 2000 118.27 10390 RPD 0.0719 2000 196.987 10390 ROP 5.3874 5705.42 253.93 10458 FET 0.2242 135.586 2.41296 10370 100.5 100.5 111.5 110.5 5295 5295 5340 5295 First Reading For Entire File .......... 100.5 Last Reading For Entire File ........... 5340 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLTMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 100 5 3396.5 RPD 100 5 3396.5 RPM 100 5 3396.5 RPS 100 5 3396.5 RPX 100 5 3396.5 GR 100 5 3404.5 ROP 111.5 3449.0 $ LOG HEADER DATA DATE LOGGED: 20-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: ISC 5.07 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: FDXXI~ kNGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (0HMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3449.3 117.0 3449.3 .5 64.6 TOOL NUMBER Pl150CRG6 Pll50CRG6 9.880 9.9 SPUD 9.00 168.0 10.0 300 8.2 .7OO .710 .600 1.200 23.9 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 O}{MM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 100.5 3449 1774.75 6698 GR 8.4541 122.187 60.8871 6609 RPX 2.6606 2000 35.0183 6593 RPS 3.5927 2000 52.1907 6593 RPM 5.5279 2000 137.522 6593 RPD 2.2238 2000 230.663 6593 ROP 6.3227 5705.42 287.88 6676 FET 0.2242 8.2738 1.04818 6573 First Reading 100.5 100.5 100.5 100.5 100.5 100.5 111.5 110.5 Last Reading 3449 3404.5 3396.5 3396.5 3396.5 3396.5 3449 3396.5 First Reading For Entire File .......... 100.5 Last Reading For Entire File ........... 3449 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N-UMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3395 5 RPX 3395 5 FET 3396 0 RPD 3396 0 RPM 3396 0 GR 3405 5 ROP 3449 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 4357.0 4357.0 4357.0 4357.0 4357.0 4365.0 4410.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AATD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3kTURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 22-NOV-98 ISC 5.07 ISC 5.07 MEMORY 4410.0 3449.3 4410.0 62.8 64.9 TOOL NI/MBER Pll50CRG6 Pll50CRG6 9.880 9.9 SPUD 9.50 110.0 9.3 300 6.8 .700 .700 .600 1.200 23.9 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 LogginH Direction ................. Down Optical loH depth units ........... Feet Data Reference Point .............. Undefined Frame SpacinH ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 3395.5 4410 3902.75 2030 GR 36.2319 123.188 85.5633 1920 RPX 4.2459 67.8099 10.5752 1924 RPS 4.7058 384.293 11.4356 1924 RPM 4.8664 2000 13.2542 1923 RPD 5.1444 2000 12.7834 1923 ROP 7.7627 1936.23 243.309 1922 FET 0.3001 16.2321 1.49608 1923 First Reading 3395.5 3405.5 3395.5 3395.5 3396 3396 3449.5 3396 Last ReadinH 4410 4365 4357 4357 4357 4357 4410 4357 First Reading For Entire File .......... 3395.5 Last Reading For Entire File ........... 4410 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4361.5 5288 0 FET 4367.0 5295 0 RPD 4367.0 5295 0 RPM 4367.0 5295 0 RPS 4367.0 5295 0 RPX 4367.0 5295 0 ROP 4411.5 5340 0 $ LOG HEADER DATA DATE LOGGED: 28-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: ISC 5.07 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 5340.0 TOP LOG INTERVAL (FT) : 4410.0 BOTTOM LOG INTERVAL (FT) : 5340.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM Ai~GLE: 59.4 MAXIMUM ANGLE: 65.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY Pl168GR4 EWR4 ELECTROMAG. RESIS. 4 Pl168GR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.630 DRILLER' S CASING DEPTH (FT) : 6.6 BOREHOLE CONDITIONS MUD TYPE: LSND-LT MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 450.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : 300 FLUID LOSS (C3) : 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.900 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.504 1.800 2.000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 35.2 First Name Min Max Mean Nsam Reading DEPT 4361.5 5340 4850.75 1958 4361.5 GR 17.6976 145.084 80.526 1854 4361.5 RPX 0.0758 576.35 23.201 1857 4367 RPS 1.0528 2000 45.8276 1857 4367 RPM 0.0804 2000 149.501 1857 4367 RPD 0.0719 2000 259.73 1857 4367 ROP 5.3874 5241.8 142.768 1858 4411.5 FET 0.2307 135.586 7.53607 1857 4367 Last Reading 5340 5288 5295 5295 5295 5295 5340 5295 First Reading For Entire File .......... 4361.5 Last Reading For Entire File ........... 5340 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/01/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/01/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File