Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
193-044
CAUTION: 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); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:1H PAD Witnessed and non witnessed 10-426 forms from 8-22-25 Date:Saturday, August 23, 2025 9:15:03 AM Attachments:image001.png MIT KRU 1H PAD 08-22-25.xlsx MIT KRU 1H PAD SI TESTS 08-22-25.xlsx Good Morning, Please see the attached 10-426 forms from the witnessed and non witnessed shut in MITIA’s that were conducted on 8-22-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 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 1821150 Type Inj N Tubing 960 970 970 970 Type Test P Packer TVD 6205 BBL Pump 1.7 IA 290 2020 1930 1920 Interval 4 Test psi 1551 BBL Return 1.7 OA 5 5 5 5 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930290 Type Inj N Tubing 2725 2725 2725 2725 Type Test P Packer TVD 6468 BBL Pump 1.7 IA 1030 2020 1960 1950 Interval 4 Test psi 1617 BBL Return 1.4 OA 400 510 510 510 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1930440 Type Inj N Tubing 280 2030 2010 2010 Type Test P Packer TVD 6085 BBL Pump 1.9 IA 220 2030 2000 1990 Interval 4 Test psi 1521 BBL Return 1.8 OA 0 0 0 0 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 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 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: 1H-12 Notes:CMIT T x IA. Open pocket at 7921' Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1H Pad Arend 08/22/25 Notes: Notes: Notes: Notes: 1H-03 1H-09 Form 10-426 (Revised 01/2017)2025-0822_MIT_KRU_1H-12 9 9 9 9 9 99 999 9 9 9 9 -5HJJ 1H-12 CMIT T x IA. �� ► 1�,a�i4c. Regg, James B (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> _7 Sent: Thursday, August 12, 2021 8:39 AM To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AUC Prudhoe Bay Subject: Recent KRU SI MITIAs Attachments: MIT KRU 2C-03 SI TEST 08-10-21.xlsx; MIT KRU 1 H PAD SI TESTS 08-09-21.xlsx; MIT KRU 2D PAD SI TESTS 08-09-21.xlsx; MIT KRU 1H PAD SI TESTS 08-08-21.xlsx w Recent non -witnessed SI MITIAs performed in Kuparuk. Please let me know if you have any questions. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1 9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: im.regg(a)alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks(cilalaska.gov chris.wallace@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1 H Pad 08/09/21 Z� (l (cl ZcILI Hills / Green ` Well 1H-12 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I = Initial Test P = Pass PTD 1930440 Type Inj N Tubing 530 2010 - 1975 - 1965 I = Industrial Wastewater Type Test P Packer TVD 6085 BBI -Pump 1.3 IA 530 - 2010 - 1980 - 1970 - Interval 4 Test psi 1521 BBL Return 1.3 OA 0 0 0 0 Result P v Notes: CMIT due to dummy valve removed from station # 1 Well 11-1-19A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2130020 Type Inj N Tubing 275 275 275 275 Type Test P Packer TVD 6369 BBL Pump 1.4 IA 50 1900 1870 1860 Interval 4 Test psi 1592 BBL Return 1.2 OA 330 350 350 350 Result P Notes: Well 11-1-20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1921290 Type Inj N Tubing 60 100 100 100 Type Test P Packer TVD 6489 BBL Pump 1.6 IA 170 1900 1865 1855 Interval 4 Test psi 1622 BBL Return 1.8 OA 85 310 310 310 Result P 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: Form 10-426 (Revised 01/2017) MIT KRU 1H PAD SI TESTS 08-09-21 INTERVAL Codes Result Codes TYPE INJ Codes TYPE TEST 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 Form 10-426 (Revised 01/2017) MIT KRU 1H PAD SI TESTS 08-09-21 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): 10172' 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:7/6/2021 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 10113' 121'121' 10152' 81'16" 9 5/8" 7" 5258' Length TVD Burst 9336' MD 4323' 6806' 5298' 6812' PRESENT WELL CONDITION SUMMARY 7999' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL002568 193-044 P.O. Box 100630, Anchorage, Alaska 99508 5002922354-0000 ConocoPhillips Alaska, Inc. KRU 1H-12 Kuparuk River / Kuparuk River Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 6609' - 6755' Perforation Depth TVD (ft):Tubing Size: 9418' - 9962' 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 Baker HB Retrievable NA 7982' MD 6085' TVD NA Size Authorized Signature: 7/20/2021 3 1/2" Perforation Depth MD (ft): J-55 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 1:37 pm, Jul 06, 2021 321-337 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: 2021.07.06 13:27:00-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Photo document pre and post extension SFD SFD 7/6/2021 50-029-22354-00-00 10-404 X VTL 7/14/21 X ext conductor ADL0025639, ADL0025638 SFD 7/6/2021 DSR-7/6/21 VTL JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 12:43:51 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 06 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 KUP 1H-12 (PTD 193-044) to extend conductor. Summary: Conductor has subsided or well has grown 9” 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: 2021.07.06 13:26:39-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 9” or more Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 40.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 39.8 Set Depth (ftKB) 5,298.0 Set Depth (TVD) … 4,322.8 Wt/Len (l… 36.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 38.7 Set Depth (ftKB) 10,151.7 Set Depth (TVD) … 6,806.2 Wt/Len (l… 26.00 Grade J-55 Top Thread AB-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 37.6 Set Depth (ft… 9,336.4 Set Depth (TVD) (… 6,589.1 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.6 37.6 0.50 HANGER FMC GEN IV HANGER 3.500 1,802.5 1,767.4 19.73 NIPPLE OTIS SELECTIVE LANDING NIPPLE 2.813 7,968.4 6,077.8 56.03 PBR BAKER PBR w/ 10' STROKE (TOP OF PBR HAS 4 1/2" RH SQ. THREAD FOR PKR RETRIEVAL) 3.000 7,982.0 6,085.3 56.55 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,998.5 6,094.3 57.07 NIPPLE OTIS XN NIPPLE, 2.81" x 2.75" NO GO 2.750 9,335.6 6,589.0 75.93 WLEG BAKER WIRELINE ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,999.0 6,094.6 57.08 PLUG 2.81" XXN PLUG (2.81" w/ 2.75" NG, 4- 1/8" & 4- 3/16" EQUALIZING PORTS, 2.82" PACKING w/ METAL CENTER RING) 2/6/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 9,418.0 9,548.0 6,609.1 6,643.8 UNIT D, C-4, 1H-12 6/23/1993 5.0 IPERF 4.5" HyperJet II; 60 deg. ph 9,566.0 9,600.0 6,648.9 6,658.3 C-4, 1H-12 6/23/1993 5.0 IPERF 4.5" HyperJet II; 60 deg. ph 9,630.0 9,660.0 6,666.5 6,674.6 C-3, 1H-12 6/23/1993 5.0 IPERF 4.5" HyperJet II; 60 deg. ph 9,859.0 9,962.0 6,727.7 6,755.4 C-1, UNIT B, 1H-12 6/23/1993 5.0 IPERF 4.5" HyperJet II; 60 deg. ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,921.3 6,050.9 CAMCO MMG-2 GAS LIFT OPEN 2/6/2017 Notes: General & Safety End Date Annotation 9/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE1H-12, 2/7/2017 5:13:00 PM Vertical schematic (actual) PRODUCTION; 38.6-10,151.7 IPERF; 9,859.0-9,962.0 IPERF; 9,630.0-9,660.0 IPERF; 9,566.0-9,600.0 IPERF; 9,418.0-9,548.0 WLEG; 9,335.6 PLUG; 7,999.0 NIPPLE; 7,998.5 PACKER; 7,982.0 PBR; 7,968.4 GAS LIFT; 7,921.3 SURFACE; 39.8-5,298.0 NIPPLE; 1,802.5 CONDUCTOR; 40.0-121.0 HANGER; 37.6 Annotation Last Tag: SLM Depth (ftKB) 9,690.0 End Date 2/6/2017 Annotation Rev Reason: TAG, GLV C/O Last Mod By pproven End Date 2/7/2017 KUP INJ KB-Grd (ft) Rig Release Date 3/22/1993 Annotation Last WO: End Date 1H-12 H2S (ppm) Date ... TD Act Btm (ftKB) 10,172.0 Well Attributes Wellbore API/UWI 500292235400 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 75.94 MD (ftKB) 9,333.01 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. /~.~-¢/Z//~ile Number of Well History File PAGES TO DELETE Complete RESCAN [] 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 vadous kinds [] Other COMMENTS: Scanned by: Bevedy Dia~athan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '7, , DATE: Tuesday,August 27,2013 P.I.Supervisor r--,efry Citroji 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-12 FROM: Jeff Jones KUPARUK RIV UNIT 1H-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 0"2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-12 API Well Number 50-029-22354-00-00 Inspector Name: JeffJones Permit Number: 193-044-0 Inspection Date: 8/11/2013 Insp Num: m0.1130822143938 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min , Well; 1H-12 .- !Type lnj ; N 1TVD ; 6085 . i IA ; 280 71 2040 •1 1980 7 1960 ,I 1 —L. p-rDi 1930440 - Type Test;SPT;Test psi' 1521 OA 1 190 ] 420 . F Interval 4YRTST lli 71 F P - Tubing 1150 . 1 1200 1200 1200 - Notes: 1 well house inspected,no exceptions noted. - SCANNED DEL 0 9 2013 1 Tuesday,August 27,2013 Page 1 of 1 ~ MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-12 KUPARUK RIV UNIT 1H-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv _ Comm Well Name: KUPARUK RIV [JNIT 1H-12 API Well Number: 50-029-22354-00-00 Inspector Name: Bob Nobie Insp Num: mitRCN090815100325 Permit Number: 193-044-0 ~ Inspection Date: 8~14/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wgil 1H"12 Type Inj. N Z'~ 6085 / IA 50 2200 " 2150 - 2140 `~ p.T.D 1930440 TypCTCSt SPT Test psi 2200 ~/ Q[~ 0 0 0 0 Interval 4~TS? P/F p '~ Tubing 375 aso aso aso Notes: ~ I~l I A~ ~G -~?- ~35uu.~ i J Zi QS i I yL j j ,_ _ ».~J4t.s ': ~ °':Wx.a.~ ... Monday, August 17, 2009 Page 1 of 1 . ConocJPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 ]\IIr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 6 2007 O~~ \ o.?J" Dear ]\IIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were fIrst filled with cement to a level of approximately 1. 0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water trom 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 cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-40 1 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10' 8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder /I/_L~vt.,,~O) Phillips Alaska Inc. P.I. Supervisor/~ f'~="- ' 1H Pad ~,~\-1 \b'~;;)C~\ 1H-12,1H-18, 1H-19, 1H-20, 1H-22 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pre{est Initial 15 Min. 30 Min. w.,I 1H-12 I YY,e,~j.I..s" I T.v:o. I ~0~ I Tu""~ I 2~0 I 2~ I 2~0 I. 2~0 I,e{e.~,l 4 P.T.D.I 1930440 ITypet. tl P ITestpsil 1521 I Casingl 475 ! 19501 19251 190O1 P/F I --P I~es- Monitored casi ressure additional 15 min & ressure stabilized at 1900 ' · . ncjp ..... . p , , pa , , , we, I 1H-la ITy.~.,nj.I..S I T.V.D.I..6333 .ITubingl 2O60 .I 20601 2O6O1 2060 I*nt~all 4 P.T.D.I 19392O0'lTypetestI P IT..~,t~il 'i~ I c=,~.~,l soo I '24~o I2440 I 2440 I P/F I _~ Notes: .. w~,I 1.-1o ITypeJnJ. I. s, I T.V.D. I s'~9 IT"~"~'I 2~°1 2~01"2~0 I ~0 I,.t~a,I 4 P.T.D.I 1921280 ITypetestI P, ITestP~l 15S2 I Casi.~l 8OO I l,S~0, I lS40 I 1840, I P/F I E .Wa~I 1H-20 I TypelnJ. I s I T:V.D-I s4ss I TuUngl 2725 I 272~ I 2725 I 2725' I~nt~aJl 4 Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVarience W= Test during Workover O= Other (describe in notes) Te~t's Details F. riday~ .J..uly 6_a 2001: I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed the 4-year MIT's on wells 1H-12, 1H-18, 1H-I9, IH20 and IH-22. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary: I witnessed successful 4-year MIT's on PAl's wells 1H-12, 1H-18, 1H-19, 1H-20, and 1H-22 in the Kuparuk River Field / KRU. M.I.T.'s performed: 5 Attachments: Number of Failures: _0. Total Time during tests: 3 h~. cc....A MIT report form 5/12/00 L,G. MIT 1H Pad KRU 7-6-01 JJ.xls 7/16/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E P L W M ATE IA L UNDER TH IS M ARK ER C:LOPd~,fF~M.DOC Geo]og'¥ca'J k~a't:er'~ia'ls Invenl:or'y DA'TA T DATA._,F'LLIS 566 ~. ~ C D R/C [)N ~.07 ~CONP DATE~06--25~,93 / DAILY WELL OP, ~I}R~LLZNG I-,II:STORY S I. [~: V E~ Y ~ .. D I R E C F I O N A L S I..I E V E Y ~;S D I R E C T I C, N A L C D N /'7800"'8889 317~-.1103l~ 2ORREC"r'ED ,S D F,' C E T' ~. [5317.-'11 ENHANCEB'IENT ~796.~-10002 ~,-~. 7800,~8909~0H Il) h. /" 1 '1 / 9.5 [) A ]' E ..,..R E C V D 05/26/1993 07/28/1993 07 /";" 9 9 Oa/29/199S 07/28/1993 Oa / i 2/'199 ? o 6 / o 'z / 'l 9 9 s 06/07/1993 08/~ 0/1993 0~ / 12/'1993 Are dr'y d'itch sarnples r'equi'r'ed? yes ~~cl r"ece'i~ yes ,~t~s 't;he we'tl cor'ed? yes ~ Ana]ysi's & descr'i'~ei'ved? Ar'e wel'l tzes'ts r'equli ~¢,..~,: ;~ ~Rece'i'ved? no J'l ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 October 12, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is and Application for Sundry Approval (Form 10-403) and in duplicate a Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. FORM WELL ACTION 10-403 3F-02 10-404 1H-12 Other(Profile modification) Inj Valve Waiver If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (atch only) RECEIVED OCT 1 4 1994 Alaska Oil & Gas Cons. Commission Anchora~ ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1'.'" Operations Performed: Operation Shutdown __ Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _ ARCO Alaska, Inc, Exploratory ..... RKB 96.. feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service . X. Kuparuk River Unit 4. Location of well at sudace 8. Well number 599' FNL, 800' FEL, Sec 33, T12N, R10E, UM ._ 1H-12 At top of productive interval 9. Permit number/approval number 717' FSL, 574' FEL, 'Sec 27, T12N, R10E, UM 93-44/93-130 At effective depth 10. APl number 914' FSL, 308' FWL, Sec 26, T12N, R10E, UM 50-029-22354 At total depth 11. Field/Pool 938' FSL, 411' FWL, Sec 26, T12N, R10E, UM Kuparuk River Field/Oil Pool 1'2'.' Present well condition summary Total Depth: measured 101 72 feet Plugs (measured) None true vertical 6812 feet Effective depth: measured 1 0062 feet Junk (measured) None true vertical 6782 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 2 1 ' 1 6" 200 SX PF 1 21 ' 1 21' Surface 5254' 9.625" 1040 SX PF 'E' & 5298' 4323' Intermediate 490 SX Class G Production 10113' 7" 329 SX Class G 10150' 6806' Liner Perforation depth: measured true vertical · 6609'-6548', 6649'-6658', 6666'-6674', 6728'-6755' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9336' Packers and SSSV (type and measured depth) PKR: Baker 'HB' Retr. @ 7982'; SSSV: Camco A-1 (W/X-Lock) Valve @ 1802' ~3. Stimulation 0r cement squeeze summary RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure OCT 1 4 Ran Camco Injection valve duri%l completion Al~,~ t~i~ ~ ~__ 14. Reoresentative Daily Average Production or Iniection'l~.~ .... -.,~-~. ~u~l~. IJ(IrlllillS81011 OiI-Bbl Gas-Mcf Water-Bbl Casing PressuC~""~fllC~10rE'-a'~ilbing--~ressure Prior to well operation 0 0 0 975 1500 Subsequent to operation 0 0 0 1200 2500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil _ Gas Suspended Service H20 Injector 1'~. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned~~//~'~'~j Title Wells Superintendent Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. .... Subsidiary of Atlantic Richfield Company WELL 1H-12 DATE 4/24/94 DAY I TIME 1300 1330 DESCRIFrION OF WORK SET MCX CONTRACTOR / KEY PERSON HES/SCHNIEDER PBTD (RKB) [LAST TAG (RKB) - DATE 10,062 ! 10062 / 3/26/93 LOG ENTRY TBG 1500 PSI FIELD COST EST. $1,830 SSSV TYPE I STATUS KUPARUK RIVER UNI' WELL SERVICE REPOR' AFC/CC# - SCA# 230DS 10HL / 40115 ACCUMULATED COST $1,830 OTIS SLN W/CAMCO A- 1 INJ. VALVE 7" 975 PSI 9 5/8 425 PSI MIRU, HELD SAFETY MEETING, TEST LUB. TO 4000 PSI DISPL. 20 BBLS Rill W/1 7/8" RS,QC,5',KJ,5', KJ,LSS,QC, W/X-LINE RT W/CAMCO INJ. VALVE W/ X-LOCK SN HJS 960, 21271-000-04000, 3.5 A-l, W/P 5000PSI 1430 RIH W/CHECK SET, CHECK SET MCX, POOH. 1445 CLOSURE TEST W/500PSI DIFF. ( BLEED OFF F/2500 TO 1800 PSI) 15 MIN. FINAL PRESS TBG 2500 7" 1200 9 5/8 - 850 SUMMARY INSTALL 3 1/2 A-1 CAMCO INJECTION VALVE W/X LOCK, SN HJS 960, 21271-000- 04000 CLOSURE TEST W/500 PSI DIFF PRESS. GOOD TEST [CHECK TInS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather m~t mphtLEWIS B. AIKEN Report iNCOMPLETE ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage, Alaska 99510-,0360 Telephone 907 278 1215 May 20, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The well is listed below. WELL ACTION 1 H-12 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED Well Files (Arch only) FTR052096 (w/o atch) MAY 2 4 1994 At;~ska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242 2503 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging ~ Perforate Pull tubing Alter casing ,,, Repair well Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _ ARCO Alaska, Inc. Exploratory _ RKB 96 feet 3_.p Address Stratigraphic _ 7. Unit or Property name O. Box 100360, Anchorage, AK 99510 Service X Kuparuk River Unit 4. Location of well at surface 8. Well number 599' FNL, 800' FEL, Sec 33, T12N, RIOE, UM 1H-12 At top of productive interval 9. Permit number/approval number 717' FSL, 574' FEL, Sec 27, T12N, RIOE, UM !~ ECEIVED 93-44 At effective depth 10. APl number 914' FSL, 308' FWL, Sec 26, T12N, R10E, UM MAY 2 4 1994 50-029-22355 At total depth 11. Field/Pool 938' FSL, 411' FWL, Sec 26, T12N, R10E, Ul~iaska 0il & Gas Cons. C0mmi: ii~)~uparuk River Field/Oil Pool 12. Present well condition summary Anchorage Total Depth: measured 1 0 1 72 feet Plugs (measured) Nolle true vertical 6 8 1 2 feet Effective depth: measured 1 O0 62 feet Junk (measured) None true vertical 6782 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 21 ' 1 6" 200 SX PF 1 2 1 ' 1 21 ' Surface 5254' 9.625" 1040 SX PF 'E' & 5298' 4323' Intermediate 490 SX Class G Production 1 01 1 3' 7" 329 SX Class G 1 01 5 0' 6 8 0 6' Liner Perforation depth: measured 9418'-9548', 9566'-9600', 9630'-9660', 9859'-9962' true vertical 6609'-6548', 6649'-6658', 6666'-6674', 6728'-6755' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9336' Packers and SSSV (type and measured depth) PKR: Baker 'HB' Retr. @ 7982'; SSSV: Camco A-1 (W/X-Lock) Valve @ 1802' 13. Stimulation or cement squeeze summary High pressure breakdown on 5/7/93, well will still not take water injection. Intervals treated (measured) 9418'-9548', 9566'-9600', 9630'-9660', 9859'-9962' Treatment description including volumes used and final pressure Pumped 138 MSCF of N2 down tubing, sheared plucj @ 7950 psi. 14. Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1400 2350 Subsequent to operation 0 0 0 1400 2350 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations )~ Oil _ Gas ~ Suspended Service H20 Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned "~~~,' ~%'/~ Title Senior Engineer Date ¢,,~-~'"?~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL 'nME OPERATIO~p~T flE~OfiT-TIME DESCRIPTION OF WORK CONT~OR / I~rt~' PER$i3N ~' -_~_ I ^Fc/~cp~2.&' /? FIELD EST: AC~UMOI~,T~D COST LOG ENTRY' PAGE I OF t\ IL_ %., I-- I · I.- ,~,,' MAY 2 4 1994 ,2,1~,~.Ka UIi & Gas Con.~. Commi~.~inn Anchorage Weather Report AR3B-7~I THIS BLOCK IF sUMMARY CONTINUED ON BACK miles I Wind Vel. knots REMARKS CONTINUED: SERVICE COMPANY SCA # DAILY ACCUM. TOTAL / R ECE VED AlaSka ~JJ & Gas ~,ns. ~o~J~Jfl~ TOTAL FIE~ ESTIMATE /2 . .~ ~ ARCO Alaska, Inc~'~ Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 12,1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. John-ston' Attached in duplicate are multiple Reperts of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~b-~/~ 1H-12 °/%-cG 1H-1 5 ~,-t~ H-16 · H-16 ~%~%~ ~/11HH:18 18 Stimulate Perforate Perforate Stimulate Perforate (C3,4) Perforate (C1) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer~ Kuparuk Petroleum Engineering ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMIS~,.)N REPORT OF SUNDRY WELL OPERATIONS I1. Operations Performed: Operation Shutdown __ Stimulate X Plugging_ Perforate Pull tubing __ Alter casing __ Repair well Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _ ARCO Alaska. Inc. Exploratory _ RKB 96 feet 3. Address Stratigraphic _ 7. Unit or Property name :P. O. Box 100360, Anchorage, AK 99510 Service X Kuparuk River Unit 4. Location of well at surface 8. Well number 599' FNL, 800' FEL, Sec 33, T12N, R10E, UM~.~ 1H-1;~ At top of productive interval (/ ,)/~ 9. Permit number/approval number 717' FSL, 574' FEL, Sec 27, T12N, R10E, UM',-//~r-'/~.~/,/¢///~¢%~ 93-44 At effective depth 10. APl number 914' FSL, 308' FWL, Sec 26, T12N, R10E, UM 50-029-2235~. At total depth 11. Field/Pool 938' FSL, 411' FWL, Sec 26, T12N, R10E, UM Kuparuk River Oil Field/Pool 12. Present well condition summary Total Depth: measured 1 01 72 feet Plugs (measured) None true vertical 6 8 1 2 feet Effective depth: measured 1 0 0 6 2 feet Junk (measured) None true vertical 6 7 8 2 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 21 ' 1 6" 200 SX PF 1 21 ' 1 21 ' Surface 5254' 9.625" 1040 SX PF 'E' & 5298' 4323' Intermediate 490 SX Class G Production 1 01 1 3' 7" 329 SX Class G 1 01 5 0' 6 8 0 6' Liner Perforation depth: measured 941 8'-9548', 9566'-9600', 9630'-9660', 9859'-9962' true vertical 6609'-6548', 6649'-6658', 6666'-6674', 6728'-6755' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9336' Packers and SSSV (type and measured depth) PKR: Baker 'HB' Retr. @ 7982'; SSSV: Otis MC Inj. Valve @ 1802' Ft I' f' 13. Stimulation or cement squeeze summary ~ L ~ L IIV "C" Sand Acid Stimulation on 9/27/93. Intervals treated (measured) J/~I~ 9418'-9548', 9566'-9600', 9630'-9660', 9859'-9962' Treatment description including volumes used and final pressure /~.12~.5~'(.8. 0ii & 6as Cons. C01flmissiot~ Pumped 16 bbls of NH4CI, 84 bbls 12% HCL @ 3300 psi. .Anchorage 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1500 2200 Subsequent to operation 0 0 0 1400 2200 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil _ Gas ~ Suspended~ Service H20 Iniecto_zr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ¢~~0, ~ Title Senior Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICA-fE REMARKS CONTINUED: DESC RI PTION DAILY ACCU M. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS HALLIBURTON - ARCTIC 'COIL TUBING FRACMASTER B. J. HUGHES Roustabouts D iese I .~/~ ~.2~/¢ ,/'..~', ~f .... Methanol -- ' -- Supervision Pre-Job Safety Meeting AFE ~'~'~,~ ,,, ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL tPBDT . //Y ~/~- I /~. ~-~ CONTR.~,CTOR / REMARKS FIELD- DISTRICT. STATE DAYS DATE []~'~HECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weath.Re.. J Temp. OF Chill Factor VlslbJlltYoF miles IWlfld Vel' REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL JcAMco ....... OTiS SCHLUMBERGER "DRESSER-ATLAS ...... HALLIBURTON , ARCTIC COIL TUBING , , ' "FRAcMASTER ...... ' ' RoustaboUts ,, , Supe~ision Pre-Job 'Safety Meeting '~~ ...... AFc, , .~~~-- , .... ",, ' .......,,, ~~ T~ ' ,, ., ,, /~~' ~ ~ ., ,,, , , , ,, , , ......... ,, , Signed' ' .... ARCO Alaska, Inc. Date: August 27, 1993 Transmittal #: 8845 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 .... Transmitted below are the following t~pen ~ items. receipt and return one signed copy of this transmittal. Please acknowledge 1H-15 ," CDR Enhancement 2-27-93 LWD/Depth Corrected 1 H- 17 -."' CDR Very Enhanced 2-26-93 LWD/Depth Corrected '"CDR Very Enhanced LWD/Depth' Corrected -- CDR Enhancement LWD/Depth Corrected ~ CDR Enhancement LWD/Depth Corrected .-- CDR Enhancement LWD/Depth Corrected --'CDR Enhancement LWD/Depth Corrected .,., CDR Enhancement LWD/Depth Corrected · ,- CDR Enhancement LWD/Depth Corrected Receipt Acknowledged: 5-02-93 1-21-93 1-12-93 3-26-93 4-05-93 4-12-93 4-14-93 DiSTRiBUTION: D&M Drilling Date: 9678-10337 7848-8422 7052-7320 9568-9802 8398-8993 7988-8632 4392-7512 5960-9772 5296-10002 //,'FO Catherine Worley(Geology) STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMI~,51ON WELL COMPLETION OR RECOMPLETION REPORT AND L 1 Status of Well Classification of Service Well OIL [~] GAS ~ SUSPENDED ~ ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-44 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-03( ~.~_,_.._~___~ ...... ~. - - 50-029-22354 4 Location of well at surface ~A~'[10~ ~1~~! 9 Unit or Lease Name At Top Producing Interval I'~i1~:~...ll~,~~ i10 Well Number 799' FSL, 382' FEL, SEC 27, T 12N, R 10E, L~M/~,/~,~ ~~u 1H-12 , At Total Depth - 11 Field and Pool 978' FSL, 411' FWL, SEC 26, T 12N, R 10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 96', PAD 54' GLJ ADL 25638 ALK 463 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 13-Mar-93 20-Mar-93 06/25/93.(Comp) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set ] 21 Thickness of permafrost 10172' MD, 6812' TVD 10062' MD, 6782' TVD YES X~J NO UI SLN 1802' feet MDI 1600' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CET,CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 47#/36# L-80/J-55 SURF 5298' 12.25" 1040 SX PERM E, 490 SX G 7" 26# J-55 SURF 10150' 8.5" 329 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9.3# J-55 9336' 7982' 9418'-9962' @5 SPF W/4-1/2" CSG GUN MD 6609'-6756' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED d U L 2 8 199 Alaska 0il .& Gas Co,Is..Commlsslo~ ~,nchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED 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 OF KUPARUK C 9328' 6587' 31. LIST OF A~ACHMENTS RE~RT OF OPERATIONS, 2 COPIES OF DIRECTION~ SURV~S 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~~ Title ~ ~ ~ DATE ~2¢' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATION/ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-12 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 25638 463 50-029-22354' 93-44 ACCEPT: 03/13/93 06:30 SPUD: 03/13/93 10:30 RELEASE: 06/25/93 06:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 03/14/93 ( 1) PARKER 245 TD: 950' ( o) 03/15/93 (2) PARKER 245 TD: 4289' (3339) 03/16/93 (3) PARKER 245 TD: 5317' (1028) o) 03/17/93 ( 4) PARKER 245 TD: 5317'( DRILL & MWD SURV 16"@ 121' MW:10.5 VIS: 74 MOVE RIG F/1H-11 TO 1H-12. (30'). NU DIVERTER SYSTEM. FUNCTION TEST. TEST WITNESS WAIVED BY LOUIS GRIMALDI. PU BHA. ORIENT TOOLS. CLEAN OUT CONDUCTOR F/l13' TO 121' DRLG & MWD SURV.F/121'-950'. ADT=6.8 HRS. TRIP FOR BIT 92 16"@ 121' MW:10.5 VIS: 53 DRILL & MWD LOG TO 3530' REPAIR SHUTTLE VALVE FOR TOP ? DRIVE. DRILL & MWD SURVEy TO 4289'. SLUG PIPE, POH FOR BIT #2. PIPE PULLING TIGHT & SWABBING. POOH FOR 9-5/8" CSG 16"@ 121' MW:10.5 VIS: 48 REAM OUT OF HOLE W/TOP DRIVE F/2787'-1400'. POH F/1400', NO SWABBING. LD M/ND, BREAK & CHANGE BIT, ORIENT TOOLS. RIH, FILL PIPE & CHECK MWD @ 1275', REAM TIGHT HOLE F/1800'-1895' AND F/2800'-2847', WASH 95' TO BTM, NO FILL. DRILL & MWD SURVEY TO 4317' CIRC & COND HOLE @ 5317' DROP SURV, PMP SLUG. POOH FOR 9-5/8" CSG. LD TEST EQUIP 9-5/8"@ 5297' MW: 9.4 VIS: 35 FIN POH. LD BHA. RU CASERS-HOLD SAFETY MEETING. RAN 52 JTS 9-5/8" 36# J-55 CSG & 75 JTS 9-5/8" 47# L-80 CSG. SHOE SET @ 5298'_ CIRC & COND MUD, RECIP CSG, PMP TOTAL OF 828 BBLS-6 BPM-400 PSI. TEST LINES TO 3000 PSI. SET & CMT'D 9-5/8" CSG W/SHOE @ 5298' & FC @ 5213'. HOWCO CMT'D PUMPING 25 BBLS WATER AHEAD, 1040 SX PF "E" LEAD, 490 SX PREM "G" TAIL W/ADDITIVES. DISPLACED W/20 BBLS WATER & 369 BBLS MUD. CIRC'D 220 SX 12.0 PPG CMT TO SURF. PLUG DOWN & JOB COMPLETE @ 21:30 HRS. PLUG DID NOT BUMP. FLOATS HELD. LD LANDING JT. RD CSG TOOLS. WASH OUT STACK. ND DIVERTER. INSTALL PACK-OFF. SCREW ON 11"-3000 PSI BRADEN HEAD. TORQUED TO 17,000 FT/LBS. NU 13-5/8"-5000 BOP'S. TEST BOP TO 250 PSI & 3000 PSI. TEST WITNESSED BY BOBBY FOSTER OF AOGCC. PULL TEST PLUG. SET WEAR BUSHING. RECEIVED JUL 2 8 199 Alaska Oil & Gas Cons. Commissior~ Anchorage WELL: 1H-12 API: 50-029-22354 PERMIT: 93-44 PAGE: 2 03/18/93 (5) PARKER 245 TD: 7452' (2135) 03/19/93 (6) PARKER 245 TD: 9320' (1868) 03/20/93 (7) PARKER 245 TD:10034' ( 714) 03/21/93 ( 8) PARKER 245 TD:10172' ( 138) 03/22/93 ( 9) PARKER 245 TD:10172' ( 0) DRILLING 9-5/8"@ 5297' MW: 9.2 VIS: 38 BLOW DN CHOKE & KILL LINES. CUT DRLG LINE. PU BHA. ORIENT TOOLS, PROGRAM LWD TOOLS-TEST MWD-RIH TAG CMT STRINGERS @ 5130' C/O CMT F/5130'-5175'. CIRC 10 MIN. RU & TEST 9-5/8" CSG TO 2000 PSI FOR 30 MIN. HELD. (LOST 50 PSI). DRLG CMT PLUGS, FC @ 5213', & FS @ 5298' & 10' NEW FORM TO 5327' CIRC & COND MUD FOR EMW TEST. RAN 13.0 EMW TEST-890 PSI W/9.1 PPG MUD-HELD. DRLG 8.5" HOLE F/5317'-6984' REPAIR GLYCOL HOSE ON TOP DRIVE. DRLG 8.5" HOLE F/6984'-~452'. DRILLING 9-5/8"@ 5297' MW:ll.9 VIS: 41 52 ' DRLG DRLG 8.5" HOLE F/74 -7972'. SERV RIG & TOP DRIVE. 8.5" HOLE F/7972'-8690'. REPAIR GLYCOL HOSE ON TOP DRIVE. DRLG 8.5" HOLE F/8690'-9320' POH TO RUN 7" CSG 9-5/8"@ 5297' MW:ll.9 VIS: 41 · DRLG 8.5" HOLE F/9320'-10034'. ADT=10.75 HR. MWD FAILED @ 9890'_ CBU. MADE 25 STD SHORT TRIP. HOLE TIGHT F/8950'-7700'-SOME SWABBING. HOLE FILL 5 BBLS LESS THAN CALC. TIH-NO FILL. CBU. NO GAS. COND MUD & HOLE-ROTATE PIPE. POOH TO RUN 7" CSG-SLM RU TO RUN 7" CSG 9-5/8"@ 5297' MW:ll.9 VIS: 42 FPOH-SLM NO CORR-REMOVE RA SOURCE-DOWN LOAD LWD TOOLS-LD BHA. CDR LOG INDICATED 74' RATHOLE BELOW "C" SAND. PU BHA & START RIH. SERV RIG. CONT RIH-TIGHT F/9700'-9808' WASH & RMR 9808'-10034', NO FILL. DRLG 8.5" HOLE F/10034'-10172' ADT=3.5 HRS. CIRC & COND MUD @ 10172' POOH TO 8355' RIH TO 10172' NO FILL. CBU @ 10172' DROP SURV. POOH. LD 84 JTS DP & BHA. RETRIEVE SURV. PULL WEAR BUSHING. RU TO RUN 7" CSG. ND BOPE 7"@10150' MW:ll.8 VIS: 42 RU TO RUN 7" CSG. HOLD SAFETY MEETING. RUN 129 JTS 7" 26% CSG TO 5271'. CBU @ 5271' RIH W/7" CSG TO 7600' ATTEMPT TO CIRC @ 7600' LOST RETURNS W/107 BBLS PMP. LOST 60 BBLS TOTAL. RIH SLOWLY TO 10150' NO RETURNS WHILE RIH. CIRC @ 10150' NO RETURNS WHILE RIH. CIRC @ 10150'. PMP 544 BBLS @ 3 BPM & 400 PSI. NO RETURNS. TEST HOWCO LINES TO 4000 PSI. PMP 20 BBL PRE FLUSH, 50 BBL SPACER, 19 SX LEAD CMT + ADDITIVES, 310 SX TAIL CMT + ADDITIVES. DISPLACE W/385.5 BBL 11.9 PPG BRINE. BMP PLUG W/3500 PSI. CIP @ 21:15 HRS 03/21/93. TEST 7" CSG TO 3500 PSI FOR 30 MIN. TEST GOOD. WELL FLOWING. BLEED OFF. WELL FLOWING 4 BBL/HR. SHUT IN. PRESS BUILD TO 80 PSI. BLEED. WELL STILL FLOWING. SHUT IN. PRESS BUILD TO 40 PSI. WOC. BLEED OFF. WELL DEAD. ND BOP. WELL: 1H-12 API: 50-029-22354 PERMIT: 93-44 PAGE: 3 03/23/93 (10) PARKER 245 TD:10172' ( 06/23/93 (12) TD:10172 PB:10062 06/24/93 (13) TD:10172 PB:10062 06/25/93 (14) TD:10172 PB:10062 06/26/93 (15) TD:10172 PB:10062 o) RIG RELEASED 7"@10150' MW:ll.8 VIS: 42 FIN ND BOP. SET SLIPS W/250K. MAKE ROUGH CUT ON 7" CSG. LD LANDING JT. MAKE FINAL CUT ON 7" CSG. INSTALL PACKOFF & UPPER TREE ASSY. TEST TO 3000 PSI FOR 15 MIN. TEST GOOD. FLUSH ANN W/100 BBL WATER. FREEZE PROTECT W/70 BBL DIESEL. INITIAL RATE OF 3.5 BPM @ 800 PSI. FINAL RATE 2.5 BPM @ 1450 PSI. SLIP & CUT 115 FT DRLG LINE. RIG RELEASED @ 12:00 HRS 03/22/93. MOVING RIG TO 1H-21. RIH W/PERF GUNS 7"@10150' MW:ll.9 NaCl/Br MOVE RIG F/1H-13 TO 1H-12. ACCEPT RIG @ 17:30 HRS, 06/22/93. SET FMC TEST PLUG. NU BOP & CHOKELINE. FUNCTION TEST & PRESS TEST BROKEN FLANGES W/3000 PSI. LOAD 4-1/2" TCP GUNS IN PIPE SHED. MU & RIH W/GUNS. RIH W/3-1/2" DP. RACK & TALLY 95 JTS DP. PU & RIH W/SINGLES. RACK & TALLY COMP EQUIP 7"@10150' MW:ll.9 NaCl/Br FIN RIH W/PERF GUNS. RU. SWS WL & RIH W/CORRELATION GR. CORRELATE RA SUBS TO CET' LOG. POH. RD SWS, SPACE OUT W/PUP, SHOOT PERFS. PERF F/9418'-9548', 9566'-9600', 9630'-9660', & 9859'-9962' W/ SWS 4.5" TCP GUN, 5 SPF, 60 DEG SPIRAL PHASING, NON-ORIENTED, LOADED W/51B HJ2 RDX CHARGES. MONITOR WELL-STABLE. CBU. CIRC OUT GAS. MONITOR WELL-STABLE, FLUID LEVEL STATIC. RU TO LD DP. POH W/3-1/2" DP & LD. POH & LD SWS PERF GUNS. PULL WEAR RING. LOAD 3-1/2" COMPLETION EQUIP IN PIPE SHED. DRIFT & STRAP. PREPARE FOR RIG MOVE 7"@10150' MW:ll.9 NaCl/Br FIN RACK & TALLY OF 3-1/2" COMP EQUIP. MU NIPPLE & BAKER PKR & RIH W/298 JTS OF 3-1/2", 9.3# J-55 EUE 8RD MOD IPC TBG. MU FMC HGR & LAND. RILDS. 69K UP 49K DN. RU OTIS SL. TEST LUB & RIH W/2.750" STANDING VALVE & SET IN XN NIPPLE @ 7974'. POH W/SL. SET PKR W/3500 PSI ON TBG. PRESS ANN TO 2000 PSI. HGR CAME UNSET & SHEARED LOCK DOWN SCREWS. RD SL. BOLDS & PULL HGR TO FLOOR. REDRESS & RELAND. REPLACE & RILDS. TEST ANN & TBG TO 2500 PSI FOR 15 MIN. INCREASE TBG PRES TO 3000 PSI FOR 15 MIN. RIH & PULL STANDING VALVE. RD OTIS. SET BPV. ND FLOW RISER & BOP. PULL BPV. NU FMC TREE. SET TEST PLUG. TEST TREE & PACKOFF TO 5000 PSI. UNABLE TO TEST PACKOFF. REMOVE TREE. REPLACE SEALS & RETEST PACKOFF. TEST TREE TO 5000 PSI. PULL TEST PLUG. RU & DISPLACE ANN W/12 BBLS OF DIESEL @ 2200 PSI @ 1.5 BPM. BULLHEAD 4 BBLS DOWN THE TBG. CHECK VALVE NOT HOLDING. WILL REPLACE W/DUMMY AFTER RIG MOVES OFF. SET BPV & SECURE WELL FOR MOVE. RELEASED RIG 7"@10150' MW:ll.9 NaC1/Br SET BPV. SECURE WELL. RELEASED RIG @ 0630 HRS ON 06/25/93. RECEIVED J U L 8 t995 Alaska Oil & Gas Cons, Anchorage WELL: API: PER~4IT: 1H-12 50-029-22354 93-44 PAGE: 4 SIGNATURE: DATE: RE E VED JUl. ~199~ Alaska Oil & Gas Cons. Anchorage SUB - S URFA CE DIRECTIONAL SURVEY ~l UIDANCE r~ ONTINUOUS ~ OOL C OFILMED Company Well Name ARCO ALASKA, INC. 1H-12 (559' FNL, 800' FEL, SEC 33, T12N, RIOE, UN) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93144 Locjged By: FORMICA Date 26-NAR-93 Computed By: SINES * SCHLUvlBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 26-MAR-93 ENGINEER' JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 76 DEG 50 MIN EAST COMPUTATION DATE' 14-APr-93 PAGE ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 26-MAR-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1OO FEET 0f MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 oo 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 499 599 699 799 899 -96 O0 4 O0 104 O0 204 O0 304 O0 99 403 99 99 503 99 95 603 95 71 703 71 04 803 04 0 0 N 0 0 E 0 10 N 89 34 E 0 13 S 80 34 E 0 19 N 84 17 E 0 23 N 68 35 E 0 23 N 65 17 E 0 45 N 71 24 E 2 43 N 77 2 E 5 6 N 79 7 E 8 17 N 80 44 E 0 O0 0 22 0 52 0 97 I 59 2 25 3 06 5 79 12 56 23 95 0 O0 0 35 0 O0 0 O8 0 O0 0 O0 I 24 I 9O 2 24 3 70 0 O0 N 0 05 N 0 O1 S 003S 0 13 N 0 40 N 0 70N 1 40 N 2 80N 4 72 N 0 O0 E 0 21E 0 54 E I O1E I 60 E 2 22 E 2 98 E 5 62 E 12 25 E 23 49 E 000 N O 0 E 0 0 1 1 2 3 5 12 23 22 N 75 33 E 54 S 89 9 E O1 S 88 9 E 61 N 85 29 E 26 N 79 54 E 06 N 76 52 E 79 N 76 2 E 56 N 77 7 E 96 N 78 38 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 997 52 O0 1095 O0 1192 O0 1289 O0 1385 O0 1480 O0 1576 O0 1670 O0 1765 O0 1858 901 52 11 29 11 999 30 1096 O1 1193 27 1289 95 1384 12 1480 80 1574 09 1669 65 1762 11 13 20 30 14 4 O1 15 17 27 16 17 95 17 26 12 18 19 80 19 15 09 19 42 65 21 53 N 78 20 E N 78 55 E N 79 39 E N 80 44 E N 83. 51 E N 81 50 E N 79 50 E N 76 40 E N 76 37 E N 77 SE 41 26 63 05 86 53 111 95 138 94 167 89 198 50 230 67 263 99 299 25 1 64 0 71 1 36 0 6O 1 31 0 99 1 O1 0 61 0 84 2 81 7 gl N 12 16 21 25 29 34 4O 48 56 40 52 E 31N 61 74 N 84 11N 110 21N 136 24 N 165 08 N 195 59 N 227 32 N 259 34 N 294 41 29 N 78 57 E 87 E 63 95 E 86 04 E 112 79 E 139 58 E 168 89 E 198 40 E 231 81E 264 15 E 299 08 N 78 45 E 58 N 78 51E 04 N 79 8 E 09 N 79 34 E 14 N 79 59 E 83 N 8O 8 E O0 N 79 53 E 27 N 79 28 E 50 N 79 9 E 2000 O0 1950.48 1854.48 24 41 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2040 66 1944.66 26 26 O0 2129 O0 2215 O0 2300 O0 2382 O0 2462 O0 2542 O0 2620 O0 2698 23 2033.23 28 48 84 2119,84 31 10 19 2204.19 33 38 43 2286.43 35 35 90 2366.90 37 7 15 2446.15 37 50 86 2524.86 38 32 22 2602.22 40 14 N 77 47 E N 77 33 E N 76 53 E N 77 14 E N 76 50 E N 76 16 E N 75 38 E N 75 29 E N 75 37 E N 75 29 E 338 81 382 02 428 41 478 39 532 O9 588 648 709 77O 834 96 32 3O 95 3O 1 50 1 55 2 14 2 35 2 o2 2 10 1 53 0 02 1 47 2 16 64 92 N 332 77 E 339 04 N 78 58 E 74 84 95 107 120 135 150 165 181 09 N 375 42 N 420 55 N 468 64 N 521 87 N 576 29 N 634 56 N 693 97 N 752 71N 814 O0 E 382 23 E 428 96 E 478 28 E 532 59 E 589 17 E 648 23 E 7O9 94 E 771 31E 834 25 N 78 49 E 63 N 78 38 E 59 N 78 29 E 27 N 78 20 E 12 N 78 10 E 44 N 77 57 E 39 N 77 45 E 01 N 77 34 E 34 N 77 25 E 3000 O0 2773 72 2677 72 41 41 3100 3200 3300 34OO 3500 3600 3700 3800 3900 O0 2848 O0 2921 O0 2990 O0 3058 O0 3126 O0 3193 O0 3259 O0 3325 O0 3392 08 2752 26 2825 85 2894 50 2962 02 3030 55 3097 70 3163 91 3229 51 3296 08 42 1 26 44 32 85 47 11 50 47 31 02 47 23 55 48 6 70 48 41 91 48 17 51 48 16 N 75 54 E N 75 56 E 966 N 75 49 E 1034 N 75 59 E 1106 N 76 6 E 1180 N 76 12 E 1254 N 76 43 E 1327 N 77 7 E 1402 N 78 5 E 1477 N 78 17 E 1552 899 85 70 83 62 26 O1 76 76 69 26 .96 .39 .31 74 34 42 35 35 71 15 198 10 N 877 80 E 899 88 N 77 17 E 214 230 248 266 283 301 318 334 349 26 N 942 92 N 1008 41N 1078 17 N 1149 80 N 1221 18 N 1293 08 N 1366 35 N 1439 28 N 1512 68 E 966 75 E 1034 39 E 1106 86 E 1180 48 E 1254 15 E 1327 23 E 1402 37 E 1477 46 E 1552 72 N 77 12 E 84 N 77 6 E 63 N 77 2 E 27 N 76 58 E 02 N 76 55 E 76 N 76 53 E 77 N 76 54 E 69 N 76 55 E 27 N 77 0 E COMPUTATION DATE: 14-APR-93 PAGE 2 ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKa DATE OF SURVEY- 26-MAR-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER- JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 4000 O0 3459 26 3363 26 47 49 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3526 O0 3595 O0 3663 O0 3730 O0 3796 O0 3862 O0 3927 O0 3993 O0 4059 80 3430 01 3499 44 3567 13 3634 25 3700 20 3766 89 3831 61 3897 88 3963 80 47 15 O1 46 41 44 47 22 13 48 34 25 48 42 20 48 48 89 48 59 61 48 40 88 48 22 N 77 26 E 1626.72 N 77 24 E 1700.45 N 77 14 E 1773.58 N 76 35 E 1846.50 N 75 14 E 1920 99 N 75 20 E 1995 98 N 75 28 E 2071 13 N 75 17 E 2146 51 N 76 27 E 2221 86 N 77 3 E 2296 75 O. 87 .40 O. 64 86 12 31 50 17 83 21 365 19 N 1585 20 E 1626 73 N 77 2 E 381 397 413 432 451 470 489 507 524 22 N 1657 24 N 1728 61N 1799 07 N 1871 15 N 1944 16 N 2017 14 N 2090 86 N 2163 75 N 2236 18 E 1700 53 E 1773 59 E 1846 78 E 1921 33 E 1995 06 E 2071 03 E 2146 04 E 2221 O0 E 2296 46 N 77 3 E 59 N 77 3 E 51 N 77 3 E O0 N 77 0 E 98 N 76 56 E 13 N 76 53 E 51 N 76 50 E 86 N 76 47 E 75 N 76 48 E 5000 O0 4126 29 4030.29 48 27 5100 O0 4192 5200 O0 4257 5300 O0 4324 5400 O0 4391 5500 O0 4458 5600 O0 4525 5700.00 4591 5800.00 4656 5900.00 4722 31 4096.31 49 0 96 4161.96 48 47 13 4228.13 48 7 24 4295.24 47 48 41 4362.41 47 47 51 4429.51 48 4 50 4495.50 49 7 91 4560.91 49 7 28 4626.28 49 13 N 77 16 E 2371 5O N 77 26 E 2446 N 77 29 E 2522 N 77 8 E 2597 N 76 29 E 2671 N 76 20 E 2745 N 76 24 E 2819 N 77 44 E 2894 N 77 38 E 2970 N 77 45 E 3045 61 O4 O1 15 23 37 50 13 8O 0 28 0 53 0 27 1 79 0 37 0 46 1 54 0 3O 0 32 0 25 541 37 N 2308 88 E 2371 50 N 76 48 E 557 574 590 607 625 642 659 675 691 87 N 2382 22 N 2455 67 N 2528 64 N 2601 13 N 2673 75 N 2745 37 N 2818 56 N 2892 68 N 2966 16 E 2446 80 E 2522 95 E 2597 12 E 2671 11E 2745 13 E 2819 40 E 2894 29 E 2970 23 E 3045 61 N 76 49 E 04 N 76 50 E O1 N 76 51E 15 N 76 51E 23 N 76 50 E 37 N 76 49 E 5O N 76 5O E 13 N 76 51E 8O N 76 52 E 6000.00 4787 70 4691 70 49 1 6100 O0 4853 6200 6300 6400 6500 6600 6700 6800 6900 O0 4918 O0 4984 O0 5051 O0 5118 O0 5185 O0 5252 O0 5318 O0 5383 23 4757 59 4822 37 4888 13 4955 16 5022 23 5089 16 5156 23 5222 60 5287 23 49 4 59 49 16 37 48 22 13 47 57 16 47 55 23 47 52 16 48 9 23 49 6 60 49 10 N 77 29 E 3121 42 N 77 25 E 3196 N 77 28 E 3272 N 78 48 E 3347 N 79 6 E 3422 N 78 55 E 3496 N 79 8 E 357O N 78 16 E 3644 N 75 48 E 3719 N 75 44 E 3795 96 64 94 33 49 61 87 92 57 0 22 0 33 0 37 1 64 0 43 0 14 0 O9 0 49 3. 30 0 29 707 93 N 3040 09 E 3121 43 N 76 53 E 724 740 756 770 784 798 813 830 848 31N 3113 80 N 3187 56 N 3261 63 N 3334 83 N 34O7 88 N 3480 37 N 3553 08 N 3626 83 N 3699 83 E 3196 69 E 3272 34 E 3347 45 E 3422 29 E 3496 12 E 357O O0 E 3644 17 E 3719 48 E 3795 96 N 76 54 E 64 N 76 55 E 95 N 76 56 E 34 N 76 59 E 51 N 77 2 E 64 N 77 4 E 91 N 77 6 E 96 N 77 6 E 61 N 77 5 E 7000 O0 5448.95 5352 95 49 10 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5514.60 5418 O0 5581.10 5485 O0 5647.76 5551 O0 5714 36 5618 O0 5781 05 5685 O0 5847 83 5751 O0 5914 28 5818 O0 5978 06 5882 O0 6038 48 5942 60 48 40 10 48 1 76 48 19 36 48 11 05 48 7 83 48 3 28 49 22 06 S1 41 48 54 2 N 75 43 E 3871.26 N 75 57 E 3946.68 N 75 51E 4021.35 N 74 29 E 4095.85 N 74 46 E 4170.40 N 74 56 E 4244.87 N 74 45 E 4319.26 N 75 13 E 4393.94 N 75 57 E 4470.93 N 75 46 E 4550.60 0 10 0 88 0 68 0 50 0 29 0 08 0 58 3 oo 3 10 2 56 867.46 N 3772.85 E 3871.29 N 77 3 E 885 92 N 3845.98 E 3946.70 N 77 2 E 904 923 942 962 981 1001 1020 1039 06 N 3918.43 E 4021.37 N 77 0 E 19 N 3990.47 E 4095.87 N 76 58 E 96 N 4062 40 E 4170.40 N 76 56 E 39 N 4134 34 E 4244.87 N 76 54 E 85 N 4206 18 E 4319.26 N 76 52 E 29 N 4278 33 E 4393.94 N 76 50 E 39 N 4352 93 E 4470.93 N 76 48 E 78 N 4430 22 E 4550.60 N 76 47 E ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 14-APR-93 PAGE 3 DATE OF SURVEY: 26-MAR-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG 8000 O0 6095 17 5999 17 57 6 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6147 O0 6198 O0 6248 O0 6293 O0 6336 O0 6377 O0 6413 O0 6445 O0 6475 46 6051 86 6102 87 6152 94 6197 67 6240 20 6281 69 6317 47 6349 03 6379 46 59 15 86 59 0 87 61 39 94 64 13 67 65 4 20 67 1 69 69 57 47 72 4 03 73 33 N 75 20 E 4632.94 N 75 35 E 4718.14 N 75 21E 4803.90 N 76 23 E 4890.46 N 75 54 E 4979 72 N 75 21E 5070 11 N 73 51E 5161 42 N 73 31 E 5254 37 N 74 27 E 5349 05 N 77 5 E 5444 52 2 45 2 10 0 85 3 61 2 21 3 24 3.28 4.11 0.17 1.90 1060.33 N 4509.97 E 4632 94 N 76 46 E 1081.73 N 4592.47 E 4718 15 N 76 45 E 1103.27 N 4675.50 E 4803 90 N 76 43 E 1124.40 N 4759.46 E 4890 48 N 76 42 E 1145 64 N 4846 16 E 4979 73 N 76 42 E 1168 04 N 4933 75 E 5070 13 N 76 41 E 1192 85 N 5021 72 E 5161 45 N 76 38 E 1219 18 N 5111 02 E 5254.42 N 76 35 E 1245 47 N 5202 11 E 5349.13 N 76 32 E 1268 92 N 5294 67 E 5444,60 N 76 31 E 9000 O0 6502 44 6406 44 74 36 9100 92OO 9300 9400 9500 9600 9700 98OO 9900 O0 6528 O0 6554 O0 6580 O0 6604 O0 6630 O0 6658 O0 6685 O0 6711 O0 6738 66 6432 66 74 58 60 6458 60 74 58 03 6484 03 75 36 69 6508 69 75 49 63 6534 63 74 0 21 6562.21 74 3 24 6589.24 74 37 89 6615.89 74 26 72 6642.72 74 26 N 77 38 E 5540 68 N 77 24 E 5637 17 N 77 58 E 5733 74 N 77 26 E 5830 43 N 78 20 E 5927 N 77 20 E 6023 N 77 11E 6119 N 77 24 E 6216 N 76 55 E 6312 N 76 55 E 6408 33 87 99 26 64 98 1 58 0 8O 0 59 1 22 I 84 2 87 1 O8 0 54 0 57 0 42 1289 88 N 5388 52 E 5540 75 N 76 32 E 1310 1331 1351 1372 1392 1413 1434 1456 1478 78 N 5482 37 N 5577 91N 5671 35 N 5766 57 N 5860 80 N 5954 99 N 6048 37 N 6142 18 N 6236 73 E 5637 08 E 5733 58 E 5830 31E 5927 73 E 6O23 48 E 6120 40 E 6216 37 E 6312 21E 6409 24 N 76 33 E 79 N 76 34 E 48 N 76 36 E 37 N 76 37 E 91 N 76 38 E 02 N 76 39 E 29 N 76 39 E 67 N 76 40 E O0 N 76 40 E 10000.00 6765.54 . 6669.54 74 26 10100.00 6792.37 6696.37 74 26 10172.00 6811.68 6715.68 74 26 N 76 55 E 6505.31 N 76 55 E 6601.65 N 76 55 E 6671.01 0.26 0.11 O. O0 1499.98 N 6330,04 E 6505.34 N 76 40 E 1521.78 N 6423.88 E 6601.67 N 76 40 E 1537.48 N 6491.44 E 6671.03 N 76 41 E COMPUTATION DATE: 14-aPr-g3 PAGE 4 ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 26-MAR-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 997 O0 1950 O0 2773 O0 3459 O0 4126 O0 4787 O0 5448 O0 6095 O0 6502 52 90! 48 1854 72 2677 26 3363 29 4030 7O 4691 95 5352 17 5999 44 6406 -96 O0 0 0 52 11 29 48 24 41 72 41 41 26 47 49 29 48 27 70 49 95 49 10 17 57 6 44 74 36 N 0 0 E 0.00 N 78 20 E 41.26 N 77 47 E 338.81 N 75 54 E 899.85 N 77 26 E 1626.72 N 77 16 E 2371,50 N 77 29 E 3121.42 N 75 43 E 3871.26 N 75 20 E 4632.94 N 77 38 E 5540.68 0 O0 1 64 1 50 I 96 0 87 0 28 0.22 0.10 2.45 1.58 0 O0 N 0.00 E 0 O0 N 0 0 E 7 91N 40.52 E 41 29 N 78 57 E 64 92 N 332.77 E 339 04 N 78 58 E 198 10 N 877.80 E 899 88 N 77 17 E 365 19 N 1585.20 E 1626 73 N 77 2 E 541 37 N 2308.88 E 2371 50 N 76 48 E 707 93 N 3040.09 E 3121 43 N 76 53 E 867 46 N 3772.85 E 3871.29 N 77 3 E 1060.33 N 4509.97 E 4632.94 N 76 46 E 1289.88 N 5388.52 E 5540.75 N 76 32 E 10000.00 6765.54 6669.54 74 26 10172.00 6811.68 6715.68 74 26 N 76 55 E 6505.31 N 76 55 E 6671.01 0.26 0. O0 1499.98 N 6330.04 E 6505.34 N 76 40 E 1537.48 N 6491.44 E 6671.03 N 76 41 E COMPUTATION DATE' i4-APR-93 . PAGE 5 ARCO ALASKA, Inc. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 26-MAR-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER- JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 O0 196 O0 296 O0 396 O0 496 O1 596 01 696 05 796 28 896 93 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 O0 696 O0 796 O0 896 O0 -96 O0 0 O0 100 O0 200 O0 30O O0 400 O0 50O O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 10 N 84 46 E 0 13 S 79 10 E 0 19 N 85 10 E 0 23 N 68 55 E 0 23 N 65 14 E 0 43 N 71 14 E 2 38 N 76 56 E 5 1 N79 0 E 8 11 N 8O 44 E 0 O0 0 21 0 51 0 95 I 56 2 3 5 12 23 23 O0 6O 23 52 O. O0 0 53 0 O0 0 11 0 O0 0 O0 I 47 I 98 2 16 3 68 0 O0 N 0 05 N 0 01S 0 04 S 0 12 N 0 38 N 0 68 N 135 N 2 74 N 4 65 N 2 2 5 11 23 0 O0 E 0 20 E 0 52 E 0 99 E 1 58 E 20 E 93 E 43 E 92 E 07 E 0 O0 N 0 0 E 0 0 0 1 2 3 5 12 23 21 N 74 45 E 52 S 89 23 E 99 S 87 58 E 58 N 85 46 E 23 N 8O 5 E O0 N 76 58 E 60 N 76 0 E 23 N 77 4 E 53 N 78 36 E 998 45 1100 1203 1307 1411 1515 1620 1726 1832 1940 996 O0 92 1096 81 1196 25 1296 18 1396 78 1496 95 1596 70 1696 89 1796 40 1896 9O0.00 11 27 O0 1000.00 13 20 O0 1100.00 14 7 O0 1200 O0 15 20 O0 1300 O0 16 26 O0 1400 O0 17 35 O0 1500 O0 18 30 O0 1600 O0 19 22 O0 1700 O0 20 11 O0 1800 O0 23 2 N 78 21E N 78 55 E N 79 43 E N 8O 48 E N 81 58 E N 81 46 E N 79 19 E N 76 34 E N 76 47 E N 77 25 E 40 96 63 26 87 45 113 86 142 07 172 60 205 12 239 5O 275 21 314 65 1 77 0 72 1 26 0 47 1 24 0 89 1 18 0 40 2 O0 2 98 7 85 N 12 35 N 62 16 91N 85 21 42 N 111 25 65 N 139 29 91N 170 35 28 N 202 42 64 N 235 50 90 N 270 59 74 N 309 O8 e 63 86 E 87 93 E 113 91E 142 26 E 172 4O E 2O5 99 E 239 73 E 275 17 E 314 40 22 E 40 98 N 78 57 E 29 N 78 45 E 5O N 78 52 E 96 N 79 10 E 24 N 79 37 E 87 N 8O 2 E 45 N 80 7 E 81 N 79 46 E 47 N 79 21E 89 N 79 4 E 2050 30 1996 O0 1900 O0 25 38 2162 2276 2394 2516 2641 2768 2897 3O29 3164 21 2096 87 2196 96 2296 69 2396 64 2496 30 2596 09 2696 91 2796 96 2896 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 28 0 O0 30 39 O0 33 32 O0 35 56 O0 37 37 O0 38 9 O0 40 10 O0 41 59 O0 43 15 N 77 49 E N 77 0 E N 77 17 E N 76 51E N 76 g E N 75 29 E N 75 32 E N 75 3O E N 76 6 E 36O 21 410 43 466 50 529 29 598 68 673 751 832 919 N 75 48 E 1010 58 29 43 8O 56 1 93 2 6O 2 11 1 93 2 35 0 75 0 99 2 16 0 24 3 82 69 44 N 353 69 E 360 44 N 78 54 E 80 92 107 123 141 161 181 202 224 35 N 4O2 93 N 457 O0 N 518 18 N 586 6O N 658 O7 N 733 24 N 812 93 N 897 97 N 985 72 E 410 36 E 466 55 E 529 O3 E 598 64 E 673 89 E 751 5O E 832 16 E 919 22 E 1010 66 N 78 43 E 7O N 78 31E 47 N 78 2O E 84 N 78 8 E 69 N 77 52 E 36 N 77 37 E 47 N 77 26 E 83 N 77 15 E 58 N 77 8 E 3307.59 2996.00 2900 O0 47 16 3455.57 3096.00 3000 3603.67 3196.00 3100 3754.91 3296 O0 3200 3905.24 3396 O0 3300 4054.53 3496 O0 3400 4201.44 3596 O0 3500 4348.55 3696 O0 3600 4499.62 3796 O0 3700 4651.40 3896 O0 47 34 O0 48 11 O0 48 32 O0 48 15 O0 47 28 O0 46 41 O0 48 16 O0 48 42 O0 3800.00 48 59 N 76 0 E 1112 20 N 76 11E 1221 N 76 45 E 1330 N 77 27 E 1443 N 78 12 E 1556 N 77 27 E 1667 N 77 14 E 1774 N 75 33 E 1882 N 75 20 E 1995 N 75 27 E 2109 27 50 96 17 O0 62 51 69 84 1 27 0 28 2 18 0 80 1 21 0 57 0 62 1 61 0 31 0 42 249.76 N 1083 80 E 1112 21 N 77 1E 275.99 N 1189 301.81N 1295 327 17 N 1406 350 08 N 1516 373 94 N 1624 397 47 N 1729 422 33 N 1834 451 07 N 1944 479 87 N 2054 68 E 1221 82 E 1330 41E 1443 29 E 1556 53 E 1667 56 E 1774 53 E 1882 05 E 1995 55 E 2109 27 N 76 56 E 50 N 76 53 E 96 N 76 54 E 17 N 77 0 E O1 N 77 2 E 64 N 77 3 E 52 N 77 2 E 69 N 76 56 E 84 N 76 51E COMPUTATION DATE' i4-aPR-93 PAGE 6 ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 26-MAR-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG WIN DEG WIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 4803 62 3996 O0 3900 O0 48 39 4954 5105 5257 5407 5555 5706 5859 6012 6165 37 4O96 62 4196 64 4296 08 4396 97 4496 88 4596 78 4696 65 4796 38 4896 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 46O0 O0 4700 O0 48 22 O0 49 2 O0 48 38 O0 47 48 O0 47 5O O0 49 7 O0 49 12 O0 49 2 O0 4800.00 49 15 N 76 32 E 2224 57 N 77 10 E 2337 N 77 26 E 2450 N 77 19 E 2565 N 76 27 E 2676 N 76 11E 2786 N 77 43 E 2899 N 77 43 E 3015 N 77 29 E 3130 N 77 24 E 3246 38 85 35 39 69 70 36 98 41 I 73 0 33 0 38 0 17 0 35 0 38 0 33 0 52 0 34 0 53 508 48 N 2165 68 E 2224 57 N 76 47 E 533 558 583 608 634 660 685 710 735 83 N 2275 60 E 2337 79 N 2386 30 E 2450 68 N 2498 06 E 2565 87 N 2606 21 E 2676 98 N 2713 38 E 2786 48 N 2823.48 E 2899 22 N 2936.47 E 3015 O0 N 3049.41E 3130 10 N 3162.09 E 3246 38 N 76 48 E 85 n 76 49 E 35 N 76 51E 39 N 76 51E 69 N 76 50 E 70 N 76 50 E 36 N 76 52 E 98 N 76 54 E 41 N 76 55 E 6317 48 4996 O0 4900 O0 48 14 6466 6616 6766 6918 7071 7222 7372 7522 7672 93 5096 O6 5196 13 5296 96 5396 78 5496 28 5596 45 5696 39 5796 16 5896 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 47 54 O0 47 53 O0 48 50 O0 49 10 O0 48 52 O0 48 2 O0 48 13 O0 48 6 O0 48 33 N 79 2 E 336O 98 N 78 55 E 3471 96 N 79 7 E 3582 51 N 76 42 E 3694 37 N 75 46 E 3809 92 N 75 53 E 3925 N 75 41E 4037 N 74 43 E 4149 N 74 55 E 4261 N 74 59 E 4372 45 91 87 53 95 1 04 0 14 0 24 2 92 0 28 0 66 1 34 0 21 0 14 3 11 759 07 N 3274 15 E 3360.99 N 76 57 E 780 801 824 852 880 908 937 966 995 11N 3383 13 N 3491 O0 N 3601 36 N 3713 76 N 3825 14 N 3934 55 N 4042 72 N 4150 89 N 4258 20 E 3471.98 N 77 1 E 82 E 3582.54 N 77 5 E 35 E 3694.42 N 77 7 E 38 E 3809.95 N 77 4 E 39 E 3925.48 N 77 2 E 48 E 4037.93 N 77 0 E 58 E 4149.88 N 76 57 E 44 E 4261.53 N 76 53 E 04 E 4372.95 N 76 50 E 7829 16 5996 O0 5900 O0 52 21 8001 8194 8404 8650 8975 9364 9740 10113 10172 53 6096 44 6196 74 6296 07 6396 68 6496 45 6596 34 6696 54 6796 O0 6811 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 68 6715 O0 57 9 O0 59 0 O0 64 18 O0 68 45 O0 74 25 O0 75 53 O0 74 35 O0 74 26 68 74 26 N 76 0 E 4493 92 N 75 20 E 4634 N 75 21E 4799 N 75 52 E 4983 N 73 3O E 5207 N 77 51E 5517 N 77 38 E 5892 N 77 14 E 6255 N 76 55 E 6614 N 76 55 E 6671 23 13 98 76 23 86 14 69 O1 1 54 2 31 0 67 2 31 1 93 1 78 1 67 o 54 0 09 0 O0 1025 96 N 4375 24 E 4493 92 N 76 48 E 1060 1102 1146 1205 1284 1365 1443 1524 1537 66 N 4511 06 N 4670 68 N 4850 90 N 5066 83 N 5365 14 N 5732 6O N 6086 73 N 6436 48 N 6491 22 E 4634 89 E 4799 29 E 4984 25 E 5207 62 E 5517 60 E 5892 31E 6255 59 E 6614 44 E 6671 23 N 76 46 E 14 N 76 43 E O0 N 76 42 E 79 N 76 37 E 31 N 76 32 E 91 N 76 36 E 17 N 76 39 E 72 N 76 40 E 03 N 76 41E COMPUTATION DATE: 14-APR-93 PAGE 7 ARCO ALASKA, INC. lh-12 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING GCT LAST READING MWD FIRST READING BASE KUPARUK C PB'I'D 7" CASING DATE OF SURVEY: 26-MAR-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 599' FNL ~ 800' FEL, SEC33 T12N RlOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5298 O0 8829 O0 8868 O0 9922 O0 10062 O0 10150 O0 10172 O0 4322 80 6454 39 6466 05 6744 62 6782 17 6805 78 6811 68 4226 80 6358 39 6370 05 6648 62 6686 I7 6709 78 6715 68 590.34 N 1252.86 N 1262.15 N 1482.97 N 1513.49 N 1532.68 N 1537.48 N 2527 49 E 5228 70 E 5264 71E 6256 85 E 6388 22 E 6470 80 E 6491 44 E ARCO ALASKA, INC. 1H-12 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER BASE KUPaRUK C PBTD TD COMPUTATION DATE: 14-APR-93 PAGE 8 DATE OF SURVEY: 26-MAR-93 KELLY BUSHINg ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY **~.~.~ SURFACE LOCATION = 599' FNL & 800' FEL, SEC33 T12N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9922.00 6744.62 6648.62 1482.97 N 6256.85 E 10062.00 6782.17 6686.17 1513.49 N 6388.22 E 10172.00 6811.68 6715.68 1537.48 N 6491.44 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10172.00 6811.68 6715.68 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6671.03 N 76 41E DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA, INC. KUPARUK RIVER WELL 1 H-12 COUNTRY USA RUN ONE DATE LOGGED 26 - MAR - 93 DEPTH UNIT FEET REFERENCE 931 44 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not. except in the case of gross or wlffull negligence on our part. be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any Interpretation made by any of our officers, agents or employees, These interpretations are also subject to our General Terms and Conditions as set out tn our current price Schedule. ltELL: 1H-:-12 (559' FNL, 800' FEL, SEC 33, T12N, RIOE, UR) HORIZONTAL PROJECTION NORTH 8000 REF 931 ~ 6000 4000 2OOO -2000 -4000 -6000 SOUTH -8000 -4000 -2000 0 2000 SCALE = I / 2000 IN/FT .:: .. : ::: :::. · ::. : ::i:::: ;: ':' ': ':: .... ..... :: ..:. . ................................... '' .. , .:.. :::: :::: : .:. · . : ......... .......... ................. ::,: ~::. :.: .::: ......................... :::: ....... 4000 6000 8000 10000 12000 WEST EAST k'ELL' 1H, 12 (559' FNL, 800' FEL, SEC 33, T12N, RIOE, UM) VERTICAL PROdECTION 257.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 77.00 PROJECTION ON VERTICAL PLANE 257.00 77.00 SCALED IN VERTICAL DEPTHS _. I-K;)RIZ SCALE = 1 / 2000 IN/FT ARCO Alaska, inc. Date: June 04, 1993 Transmittal #: 8¢55 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~ items. receipt and return one signed copy of ~-trar~mittal. ~%~.__.,/1 H- 10 _ ., '"'4 H-lO ~~1H-12 .,_ "~1H-12 '~2-'" ~:) - 2M-07 ~~{ -- 1B-12 2M-29 CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected HLDT, Corrected CH Density HLDT-Corrected CH Density HLDT-Corrected CH Density Please acknowledge Receipt. Acknowledged: DISTRIBUTION- D&M NSK 3/2-5/93 4414-7561 3/2-5/93 4414-7561 3/17-20/93 5317-11 034 3/! 7-20/93 5317-11 034 1/9/93 8000-9336 5/18/93 8030-8682 1/8/93 10448-12014 Drilling S~ate .. of. Alaska(+S e pi a) ARCO Alaska, Inc. Date: May 21, 1993 Transmittal Cf: 8¢48 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 1H-18~(~'LIS Tape and Listing 02-10-93 0~..~u''' CDR/CDN in 2 Bit Runs, QRO Processed 1H-1 % LIS Tape and Listing 03-05-93 _--~~ CDR/CDN & Enhanced Resistivity 1H-:J~ LIS Tape and Listing 03-26-93 o~ LIS Tape and Listing 3-20-93 H.I~., U~~''~ CDR/CDN & Enhanced Resistivity 1 H-09 ,~°¢'- · CDR/CDN & QRO Enhanced Resistivity 1 .p~,~ LIS Tape and Listing 02-25-93 CDR/CDN In 1 Bit Run, QRO Processed Receipt Acknowledged' Please acknowledge receipt 93067 93112 931'15 93128 93088 Date: DISTRIBUTION: Bob Ocanas State of Alaska STATE OF ALASKA ALA~~ OIL AND GAS CONSERVATION COMMI,5~,ON APPLICATION FOR SUNDRY APPROVALS Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate Pull tubing __ Variance ~x Perforate __ Other __ 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 599' FNL, 800' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 717' FSL, 574' FEL, Sec. 27, T12N, R10E, UM At effective depth 914' FSL, 308' FWL, Sec. 26, T12N, R10E, UM At total depth 938' FSL, 411' FWL, Sec. 26, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 10172 6812 feet feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-12 9. Permit number 9;~-44 10. APl number ~ 5o-029-~235.~ ~, 7z2. 11. Field/Pool Kup~ruk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 1 0 0 6 2 true vertical 6782 feet feet Junk (measured) None Casing Length Size Structural Conductor 1 21' 1 6" Surface 5 25 4' 9 - 5 / 8" Intermediate Production 1 01 1 3' 7" Liner Perforation depth: measured Cemented 200 Sx PF 1040 Sx P F 'E'& 490 Sx Class G 329 Sx Class G Measured depth 121' 5298' 10150' True vertical depth 121' 4323' 6806' RECEIVED true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) MAY 20 199; Alaska 0il & Gas Cons. Comm~Ssio~ Anchorage.' 13. Attachments Description summary of proposal X Install sub-surface, spring controlled safety valve in water 14. Estimated date for commencing operation 15. June 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ injection well. BOP sketch Status of well classification as: Oil __ Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned C-~)· ~ Title FOR COMMIS'~ION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- ~'&~'__ Origina~ R~,~n~.d By David W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned IAppro, y,val..~No. _ SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1H-12 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 1H-12. This injection valve will act as a one-way check valve allowing downward injection of water while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This well's completion design, scheduled to be installed in June, will not include a hydraulic control line from the surface to the subsurface valve, however a landing nipple will be installed at approximately 1800' to accept the spring-controlled injection valve. Installation of the valve would be~'ormed following the original completion and prior to initial water injection. Attached is a schematic of the proposed injection valve. RECEIVED ~AY ~ 0 199,~ AJaska Oil & Gas Cons. Oorr~missior~ Anch0rag~ TOP SUB FICE GUIDE .--J'.-.- SEAT SEAT INSERT FLAPPER VALVE AND SPRING ASSEMBLY Otis MC Injection Valve RECEIVE ~ AY 2 0 '~99~ Alaska Oil & Gas GoDs. Oommissio~ ~nchorage ARCO Alaska, Inc. Date: April 23, 1993 Transmittal #: 8718 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. q.'~¢~ 1H-12 ~/~ 1H-11 ~;r~/:;~O 1H-lO Sub-Surface Directional 03-26-93 93144 Survey Sub-Surface Directional 03-26-93 93145 Survey Sub-Surface Directional 3-26-93 93146 Survey Receipt Acknowledged' DISTRIBUTION: Date' D&M State of Alaska (2 copies) ARCO Alaska, Inc. Date: April 08, 1993 Transmittal #: 8708 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Cement Bond Log Cement Evaluation Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Receipt ' Drilling Acknowledge: Please acknowledge receipt and 03-26-93 03-26-93 03-26-93 03-26-93 03-26-93 03-26-93 6050-7410 6050-7430 7800-8909 7800-8889 8200-9552 8200-9532 Date' State of Alaska(+sepia) NSK MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Johns~o¢~ date: Chairman '~ file: thru' Blair E Wondzell ~'--~ subject: :~1~¢(~ 8r Petr EngJneer from: Bobby Foster Petr InSpector March 25, 1993 031793.doc BOP test - Parker 245 AAI KRU 1H-12 Permit #93-44 Kuparuk River Field Wednesday, March 17, 1993: The BOP test began at 3:00am and was concluded at 5:30am. There were no failures. The rig was' in very good condition. This rig is equipped with three P1600 mud pumps, which are more than adequate. The location was clean and accessible. Summary: I witnessed the BOP test on Parker rig 245. Test time was 2½ hours with no failures. STATE OF ALASKA Operator: ......_~,~/~' . Ddg Contractor: ,//~_,~ ......... Casing Size: ~'5//,~, Set ~ Test: Initia~ ~ Weekly BOPE Test Report Pmt.#~_~-~ Rig P.h,# /~ ~- ~ 7¢ Rig No~.~.~. Rep.: ~, ~~ / ~?~ Location: Se~ T./~ ~/ R. /~ ~ Meridian ~ ........... Other ......... :'::::!:! ::!::; .i:: ' ':; :: '::;:::.: .: ::::.;:'. .... :' .'-.'.-"-;.',;' ::, ..... :::!~: ........ ; ...~;,~;.L.,~:L,~.~L.":': :~'."'~'.:.i: ::::: ::::::::::::::::::::: ...... ~:::::~.:~ ~ ........ Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P_j/F Location Gen.: ~'"'~.- Well Sign ~"/ Upper KELLY/IBOP _/..__L_~¢ z~ ! Housekeeping: ~ {gan) Drl, Rig .~.-'~' Lower KELLY/tBOP /"~'~'~-~- .... Jr>- ' Reserve Pit ,,// B.I, Type ~..~L~'" ,' Inside BOP -/'.'- :1 ,,~--~ ....... Test Pre~sure ~F CHOKE MANIFOLD: QU~, Visual BOP STACK: Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valve~ Kill Line Valves Check Valve MUD SYSTEM: Alarm Trip Tank / Pit Level indicators / Flow Inclic~tor / Gas Detectors .~.. ~ Manual Chokes ~ Hydraulic Chokes / 1/u" ACCUMULATOR SYSTEM: System Pressure ~,~ ~ j Pressure After Closure ,//~ ~"'z> i ..... 200 psi A~ained After Closure - minute~ ..~ sec. System Pressure Affained ~ minutes ~ sec: Blind Switch Covers: M~ter: ~- Remote: ~' Nitgn. Btl's: ~Oo/~ ~o, ~¢'~ Equipment shall b~ m--~e ~ ----- days. Notify the Inspector on duty and foil0;~ ~il~ Written or Faxed verification to the AOGCC Commission Office at: Fax No.: 276-7542 inspector North ,Slope Pager No. 6~9-3607 If your call is not returned by the inspector wil~in 12 hours, please contact t~e P. I. Supervisor at 2711t-1433. REMARKS: Distribution: orig-Weil File c - Open/Rig c - Database c. Trip Rpt File c ~ Inspector YES /~ NO 24 HOUR NOTICE GIVEN / YES NO Waived By: Witnessed ALASKA OIL AND GA ~ CONSERVATION COMMISSI~ ~ WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 12, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-12 ARCO Alaska, Inc. · Permit No. 93-44 Sur. Loc 559'FNL, 800'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 882'FSL, 80'FEL, Sec. 26, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permi~ to drill the 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechaniCal integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure CC.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~'~ p,inted on recycled paper STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry Fl Deepen r'l Service X Development Gas r'l Single Zone X UultipleZone [-~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25638, ALK 463 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 559' FNL,800' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 700' FSL, 700' FEL, Sec. 27, T12N, R10E, UM 1H-12 #UG630610 At total depth 9. Approximate spud date Amount 882' FSL, 80' FEL, Sec. 26, T12N, R10E, UM 3/1 3/93 $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 1H-1 1 9,840' MD 4,398 @ TD feet 30' @ 500' MD feet 2560 6,694' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 75 0' feet Maximum hole angle 7 5 o Maximum surface 2,5 5 7 psig At total depth (TVD) 3 90 0 psJg 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 80' 42' 42' 121' 121' _+200 CF 12.25" 9.625" 36.0# J-55 BTC 5,302' 42' 42' 5,344' 4,320' 650 Sx Permafrost E & HF-ERW 490 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 5,382' 42' 42' 5,424' 4,373' HF-ERW 8.5" 7" 26.0# J-55 BTC 4,416' 5,424' 4,373' 9,840' 6,694' 230 SxClass G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structuralj~ E~I~hE DTrue Vertical depth Conductor Surface IntermediateMAR - 9 t99: Production Liner Alaska 0il & Gas Cons. Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee X Property plat~ [] BOPSketch 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 true and correct to the best of my knowledge Sig~~u~';'~;/ ~ ~'~ ,~,1~, /k~¢,~r,'~'~.. Title Area Drilling Engineer Date ~,-~. Commission Use Only Perm~.,~mbe~_[//~.,.. IAPl number50- 0,~- 2 .,q~. ~ ~'~-7~ I Appr°val dat~,~'""/~;~'-- ~ ISee c°ver letter f°rother requirements Conditions of approval Samples required [-1 Yes [] No Mud Icg required F1 Yes ~[~ No Hydrogen sulfide measures D Yes ]~ No Directional survey required '~ Yes [] No Required working pressure for BOPE [] 2M J~ 3M Fl 5M Fl 10U [] 15M Other: 0RIG~[~D BY 'RUSSELL A'~O'0UGLASS by order of Approved by Commissioner the commission Date ~-"~/t~ ARCO ALASKA, Inc. Structure : Pod 1H Well : 12 Created by : jones For: D STOLTZ Date plotted : 5-Mar-93 Plot Reference is 12 Version #8. Coordinates are in feet reference slot #12. True Vertical ~:~~~~~~. 350 _ g 0 .. 350 to - 700 _ _ 1050 _ - (- - ,-I'"-- 1750_ O_ _ (~ 2100_ - 2450_ 0 - 2800_ - 315o_ - 35OO _ -- (],)3850_ L 4200 m _ 4550- - i 4900_ V - 5250_ _ 5600_ _ 5950_ _ · 6300_ - 6650 _ Field : Kuparuk River Unit Location : North Slope, Alaska N 76.83 DEC E 5525' (TO TARGET) 7.oo East --> 350 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6500 6650 I I I I I I I I I I I I I I t t I I I I I I I I I I I I I I I I I I I I I I I I . SURFACE LOCATION: 559' FNL, 800' FEL SEC. 33, T12N, RIOE RKB ELEVATION: 96' KOP %/D=750 TMD=750 DEP=O 4.00 8.00 BUILD 2 DEG / 100' TARGET LOCATION: 700' FSL, 700' FEL SEC. 27, T12N, RIOE TARGET 7VD=6479 TMD=9011 DEP=5525 _1750 - _1400 - _1050 - _ 700 _ T/ ZONE C TVD=6557 TMD=9312 DEP=5816 '[3) / LOGGING PT TVD=6694 TMD=9840 DEP=63f>6 ~ 78O0 350 0 350 700 1050 1400 1750 2100 2 0 2800 31 0 38 0 4200 45 0 49 0 5250 56 59 6300 6650 Scale 1 : 175.00 Vertical Section on 76.83 azimuth with reference 0.00 N, 0.00 E from slot #12 20.00 B/ PERMAFROST 1VD=1612 TMD=1626 DEP=133 24.00AA TD LOCATION: 0.00 4.00 RECEIVE ~~/48.g6 DSC w s~ SNOS ~g=4120 TMD=5040 DEP=2575 Alaska ~nshorageGas Cons. ~ 9 5/8" CSG PT ~D=4320 TMD=5344 DEP=2602 M~R - q 1993 TAN~Z ~LE ~A/B MODIFIED CSG ~D=4373 TMD=5424 DEP=2663 ........ 6ommissio~ BEGIN FINAL B~LD WD~73 TMD=7709 DER=4586 ~ ~0' O0 ~A~ A~T~IW K~6 T~8059 D~4664 %" 5~' aa ~ 75 DEG ~o. ~. T~GET - T/ ~P SNDS (EOC) TVD=6479 TMD=90II DEP=5525 Scale 1 · 50.00 1 O0 50 0 I I I I 50 1 O0 I I I I I ,/oo -0500 900 150( 21 1100 29 Z 1 O0 3300 3500 150 I 2500 27O0 1300 East 200 250 I I I 1500 ,300 350 400 450 500 550 I I I I I I I I I I I 6OO I 65O ' l ARCO ALASKA, Ilq_C, 200 150 .. C) C) 0 1 O0 0 ~ ~o I I 100V Structure : Pad 1H Well : 12 Field : Kuparuk River Unit Location : North Slope, Alaska 200 t250 o . o 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1H-12 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,344')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9,840') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED MAR - 9 199 Alaska 0il .& Gas Cons. Oon~rnisskOr~ ~nchorage DRILLING FLUID PROGRAM Well 1H-12 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,557 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1H-12 is 1H-11. As designed, the minimum distance between the two wells would be 30' @ 500' MD. The wells would diverge from that point. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. RECEIVED MAR - 9 Alaska Oil & Gas Cons. Oomfc'tssiOr~ Anchorage C'asing Design / Cement Calculations 8-Mar-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 1H-12 5,344 ft 4,32O ft 5,424 ft 4,373 ft 9,840 ft 6,694 ft 4,388 ft 9,011 ft 6,479 ft 12.0 ppg 3,500 psi ** See Page 4 For Casing Choices Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5*0.052)-0.11}*TVDshoe Anticipated Mud Weight = Top of Target Zone, 'I'VD = 100 psi Overbalance = =1 4,320 ft 2,557 psiJ 12.0 ppg 6,479 ft 4,043 psi 3943 psiJ Surface lead: Top West Sak, TMD: 4,388 ft Surface tail: Design lead bottom 500 ft above the Top of West Sak = Annular area = Lead length * Annulus area = Excess factor = Cement volume required = Yield for Permafrost Cmt = Cement volume required =[ TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt. inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required 3,888 ft 0.3132 cf/If 1,218 cf 15% 1,400 cf 2.17 650 sxJ 5,344 ft 456 cf 80 ft 0.4340 cf/If 35 cf 491 cf 15% 564 cf 1.15 490 sx[ Casing Design / Cement Calculations Production tail: TMD = Top of Target, TM D = Want TOO 500' above top of target = Annulus area (9" Hole) = (TD-TOC)*Annulus area = Length of cmt wanted in csg = Internal csg volume = Cmt required in casing = Total cmt = Excess factor = Cement volume required = Yield for Class G cmt = Cement volume required =[ 8-Mar-93 9,840 ft 9,011 ft 8,511 ft O. 1745 232 cf 8O ft 0.2148 17 cf 249 cf 15% 286 cf 1.23 230 sxJ TENSION - Minimum Desitin Factors are: T(.ob)=1.5 and TOs)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production, A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud RE E V D :Anchorag-o 2 Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 564000 lb 5,344 ft 36.00 Ib/ft 192384.0 lb 34158.6 lb 158225.4 lb 3.6J 639000 lb 5,344 ft 36.00 Ib/ft 192384.0 lb 34158.6 lb 158225.4 lb 4.0i 415000 lb 9,840 ft 26.00 Ib/ft 255840.0 lb 46303.2 lb 209536.8 lb 2.0] 490000 lb 9,84O ft 26.00 Ib/ft 255840.O lb 46303.2 lb 209536.8 lb Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST-Minimum Desiqn Factor E)I, E E ~V ~ Surface Casing: t\ L~ -= Burst = Maximum surface pressure MAR - 9 1993 Alaska 0il & Gas Cons. 0omf¢~ss~or~ Production Csg A: Anchorage 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Max Shut-in Pres = Design Factor =! Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating/Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Desic_in Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom'= Design Factor =1 Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 8-Mar-93 415000 lb 4,416 ft 26.00 Ib/ft 114816.0 lb 20780.0 lb 94036.0 lb 4.41 490000 lb 4,416 ft 26.00 Ib/ft 114816.0 lb 20780.0 lb 94036.0 lb 5.21 3520 psi 2557.4 psi 1.41 4980 psi 6229 psi 2024 psi 4205 psi 1.21 4980 psi 7677 psi 3098 psi 4579 psi 1.1J 2020 psi 0.624 Ib/ft 1760 psi 1.11 4320 psi 0.624 Ib/ft 2729 psi 1 .si 4320 psi 0.624 Ib/ft 4177 psi 1.01 Casing Design/Cement Calculations 8-Mar-93 Surface Casing Choices (30 ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276. 26 J-55 .7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi RECEIVED Al~chorage ,6 , 13 5/8" 5000 PS, BOP STACK 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 CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACKTEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR 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 AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 1 3-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ^]aska Oil & Gas Cons. Anchoraga SRE 8/22/89 kUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 2, UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"-2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER fEC[IV D ^.iaska Oil & Gas Cons. Cor~ .Anchorage EDF 3/10/92 iH-12CMT.XLS S t ate: At~,,~/,~a Engineer: t4'eii: !t1-12 Work Shee~: Field: Kupafuk Rivet D ate: State Permit ~ .93-44 N. Ebmen! Voluble £alou/ation,~~ Casing Type Condu¢.or Surface Casing Size -Inches 1G. O00 9. G25 Casing LenCh - Feet 80.000 5,302.000 Hole Diamete~ -Inches 24.000 12.250 Cement- Sacks ~tl 0.008 650.000 Cement- Yield ~1 0.080 2.170 Cement- Cubic ft~'I O. OOO 1,410.500 L.,,ment- Cubic tt ~!! 200.000 1,410.500 Cement- Sack~ ~12 0.000 490.000 Cement- Yield ~2 0.000 1.150 Cement - Cubic ,~t ~t2 0.000 56,3.580 Ce~'nent - Cubic ft ~2 O. OOO 583.500 Cement- S acks ~I3 O. 000 Cement- Yield ~3 O. 000 Careen( - Cubic f( ~3 O. OOO Cement- Cubic ft~13 O. OOO Cement.. Cubic It /Vot 200.000 1,974.000 Cement~ Fill Factor 1.432 1.189 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! Casing Type tnte.~mediate ~1 Intermediate ~2 Casing Size -Inches 0.008 0.080 Casing Depth - Feet O.80O 0.000 Hole Oiamete~ -Inches 0.080 0.0~i Cement- Sacks Cement- Yield ~! 0.00 0.00 Cement- Cubic It~i O. O0 0.08 Cement - Cubic ft ~1 O. O0 O. 08 Cement- Sacks ~I2 0.00 0.00 Cement- Yield ~2 0.00 0.00 Cement- Cubic it~I2 0.00 0.08 Cement- Cubic l~, M2 0.08 O. OO Cement-. Sacks ~3 0.00 0.08 Eerr~nt - Yield ~ 3 O. O0 O. O0 Cement- Cubic It~3 O. OO 8.08 Cement-Cubic It ~I3 0.00 0.00 Cement- Cubic It / ¥ol 0.08 0.08 Cement- Inte~vat ft Top of Cement-~ Feel: ~DiV/O! ~DiV/O! P~inted 3/10/93 < I Produdion 7.000 9,840.000 8.500 ~0.00 ! .23 282.90 282.90 O. OO 0.00 0.08 0.08 0.00 0.00 0.08 0.00 282.90 2,230.96 -% !,,,1 r:,~tsure,:l 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, informati~)n 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. MICROFILMED chlumberqer A18ska Computinq Center 07:55 OP!GIN .: CO~ENT : ARCO AI~ASK~, i~C. **** TAPE P/~.T ~ : 93104114 O~I~tN : FL!C PPEVlOUS TAPE : CO~ENT : ,~RCO ~LASKA, I~qC.,~UPAR[.~% DIVE~ [t~I:r,IH-12,50-O29-~2354-O0 AP! OPEPAT[.)P: LOGGING CO?!PANY: TAP~ JOB SU~wS, C~ 5ECTIO~C: FSf,: F4I.,: k'PLLY [}~RPlCk FLOOR: GPOI~r~ LEVEl,: 559 96.00 96.00 5 4.0 0 SIZE (IN) sIZE (I.~¢) DFPT[% (FT) 5r, o .cl.. 625 52q,~, 0 PAGE: IS Tape ver.lfJcat~op !,ist]nq chlumberceT .A]askla Co~)t!t.i~o ('e~)t. er BiT TD RE8 4:1,31', BIT TO GP 5i,73', BIT TO DEl:.1 J07,~3' 6~T T(~ ~4EUT 114.~!'.. DRIt.,bED Jk~TERV,~L 5317' T(2 !0034', AvE~'~AGE HObE !)EVI~TI[J~: 49 D[:TG 53!7' - 7735' 75 DEG 7735' - I0034} TO b~IJD SYSTEtq, I~TA FR['.!}~ DOw~.~bL~bE ~,~F~ORY. DOWNHOLE FTLF ~e~th shifted and clipped curv~s; all. bit runs merc.~ed, # K~Ii TOOL C~DF gT/l~'r P~Tp'?a 5300, 0 B3S~I.,TNV CI.j~VE FOP SPlF'TS: GR .... ....... F:~52,0 g765,0 ~673.5 [~61P,5 8457,0 g42~.0 ~D ~53.0 R760.0 8674.5 e620.5 ~425.5 chlU~berqer Al~sk:~ ¢omt:~utinc }.S-APR-!993 07:~5 8354.0 8270.5 8222.0 8!87.0 8!09.0 8086.0 ~044'0 80~0,5 .9o::o 7831,5 !00,~ ~U TOO'[, CODE 8355.5 8272.5 8223.5 817t.5 8!!1o0 8089.0 80~.0 80!3,0 7935°0 7903,5 7~86.5 7832.5 ~O!.O EDITED F!I~E APE AT ,5 S~IPbI~G RATE, T~;E SA~4PII~G TICKS IN FILE ~2 WILL BE CLOSER TO ACTU.hL .~.CQ(.{ISITI~¢~' RATE. TF*5; ENHAf~CED RESIST,IVITY CURVES PRESENIED IN THIS FILE COPz P [.;T .I' ~G DATA PAGE 'TS 'Paoe VerIf.icatJoP histinn chl. umberc]er AlasKa .O. omput~.nq Center 15-'.~PP-! 993 07:55 6 0 . St:i:RV UN'.[T S... VIC TD ORDER t) g K ~ ~, I 8 ~ 04 00 RHOD ~4~D G/C] 61~9~4 O0 DRH~ VWD G/C3 ~lH994 O0 PKF ~,~wO BN/K 61~994 O0 CILN' awb I.N 61aqO4 aPal ~n DU-8 61a99a O0 RA ~wP OHt~ ~ RD ~ND OHH~ 61~904 aDP *~WD F/hR CD ~,~wO GAPI 61Rgq4 OD NSI ~wn 61 ag94 OO RSI ~WD alRgg4 O0 HKNA N~D CPS ~- 1. ggg4 O0 TI~ a~'D 61a994 O0 TABD ~WD 61R994 O0 GTCK M~[') S 6189~4 OO NTCK ~{D S 6]. ~904 O0 DTCK ~,~WD 8 61 g994 UO A~TP M~I! OHt4h~ A1~994 O0 PSER ~"wD OH~:M ~,l~gq4 _h'rV~ ~,~:}b 9HHY 6i~9q4 O0 ....... ..... ... -.. , ,. 6t~¢: ..... TYP~ CLA8~,3 ~:~:]D ~i~. SA?.iP ~t~E~ CODE (HEX) ~ I IIi film ~ !i I m.. ~ iii ~ m I ii I ii it il iill ~ i ~. i il I iii ~ ii iii ~. I ilIlIilIliitliii ** DA'I A DWPT. ! O035. (,0 CtlT.,N. ~WD -9q9.2 -. u RtlD. MWD 21 5.959 ~CW. ~ K~ r~ -9q9. 250 ATDH. ~!~h -9~9. 250 -999,250 -999,250 -999,250 -999,250 -999°250 -999,250 IS 7ape verificat!orc, !~istlnq chlumbe~oer Alaska ComDut~!nC~ Center DEP?. 100no. RO¢, ~4WD 174,752 GTCK.*~¢~D -999.259 GTCK. ~wp !. o00 ~TV~,~WD 9,742 DEPW. 9900.000 GTC~ .~wO -9q9.250 ATV~,~WD 3.44U B~PT. 9700,000 C~L~.~, MWP ~,705 G~CK. M~I> 1. ATPN.'~WD 3.g~0 AT':VR, MWD 4.001 DFP7, 9600. GTCO. M~;9 i. ATPH. N¢!D 3.a12 ATV~. ~;,~P 3. 472 DEPT. qS00. OO0 C ~ b ~,~. ~,I w p ~. 603 PCP. MW[) 29.9Ou GTCk, f4 i.; P -q99. 250 ATPH. q~ D 3. !TVP.S~D 3,774 DVPT. 9400. GTCK . ~4 L,J P !. 15-ape-!993 07:55 -999.250 '999,250 '999.230 TAiS.~WD '999.250 DTCK,~WD '999,950 AT~R.;4WD -999.250 2 · 50 ~ 9RH0, 30 400 R A , ~7: 966 t, lS!' ~.940 TAB,i.{WD !,.000 2.563 25.500 aA.iq~D 95,329 9.640 TAB.?IW'D t.O00 BTCK,a~D 3.7~6 ATER.aWO 2,494 DPH0.!~4WD 22.7u0 RA,~D 87.574 10.805 TAg,~WD -999,250 DTCK.b~WD 4.02~ ATER.~WD 4.179 2.4.63 22.400 76.018 10.3g! TAB.M~D -999,250 t)TCK. ~WD 3. 649 ATF~.{. '4WP 3. 504 2.332 25.gOn q, 07 ~ TAB. 1. ~O0 !)TCK. 3.901. 3,776 2.531 ~NHQ.~'Wi' 31.500 RA.~WD -999.~%,) OTCK,MwD 4.?~9 ~TEF~.?qWD -999.250 2999.~5o 999,250 - 9 9 9 ,2 5 o -§99:250 -999.250 -0.005 ~.309 0.000 063! -999:25o 9,49t -0.007 3 421 o:ooo 0,714 -999.250 3,450 -n.O06 3,~92 0.000 0,675 -999,250 4,004 -0.008 3.621 0,000 0.971 -999.250 3.509 -0.010 3.892 0. 0 675 -999~250 3,819 -0.031 3.a06 0.000 1.81.0 -990.250 3.758 PEF.MWD R$I.~WD TARD,~WD PSgR,gwP PEF,gWD RP,~WD TABD.~WD RTC~,~WD PSER.~WD PEF.MWD RP.gWD RSI,~D TA. BD,~WD RTCK.$WD PSER,MWD PEF.MWD RP,gWD RSI.~WD TABD.MWD RTCK,MWD PS~R.~WD PEF.MWD RP MwD TAmD.MWD RTCK,M~D PSER.~WD PEF.~D RSI.~D TABD.~WD RTC~.aWD PSER.M~D PEF.~WD CP.~wD RSI.gWD RTCg.NWD PSER.~WD PAGE:: 999,250 -999,250 999,250 999.250 999.250 5,76! 9,269 0.000 1,626 -999,250 9,744 5453 0o000 .99~ '531 .250 3.703 4,398 4.~02 0,000 2.024 -999,250 4'185 5 218 0,000 1,883 -999,250 3.545 4,771 3,801 0,000 1 564 -999~250 3.820 5,458 5.2~0 0.000 4.625 -999.250 4.672 !S Ta..ne veri..f.ication Listino chl!]mberger AlasKa ComPutinq Center DEPT, 920{}.0n0 CALN.NWD 8.746 HEa~.~W0 300.938 GTCO. M~:D 1..000 ATPH.awD ~T'V~. aWD 3. 053 DEPT. 9100.000 POP. NWD 63. 303 NEN~, ~w'P 273.000 GTCK. ~ ~ D -999. 250 ~TPN. ~q. WD 2.38i AT'V~. ~,~ ~D 2 22I C~,LN. MWD 8,592 NPHI. POD. ~WD 1.27. 354 GR. M.W[) ATPH. ~'~D 2.257 PCP. ~'~ P 74. ~EN.~. ~wD 261 GTC~. ~D -909.25,9 ATp~. ~Wf) ATVP. ~{r) 2.5 ! 5-APR-I 9c)3 0'!:55 .2 , 70 0 29. 600 t10.509 8. C68 -999,250 4.6~0 5.418 0.012 3. 609 0. 000 0 ~.8 ! 3.920 2.502 DR HO, ~<iW D -0.012 30. 500 ~A. MW'D 3.139 !31.112 .!~S I. ~W O 0.000 7,89B TAB, ~.4WD 0.561 ] .000 DTCK. ~4WD -999.250 3.840' ATER, ~WD 3'774 2.599 39. 200 12o.262 6,~98 i. 000 3.723 39,200 t2'5.548 6.00{) -999.250 DTCK.?4W[) 4.444 4.341 -0 00.4 2 :,4.62 000 -999. 250 2.332 -0.0 2 . 3 §:ooo 572 -99~.250 2,245 2.318 DR~O.MWD -0..015 4..4.,700 ~,~. :~WO 2.462 21. 096 l,~S'!. ~',. W O 0. 000 5,3,35 TA~!.,~WD 0.412 1.000 DTCK.~qWi) -q99 250 5.091 ATER.MwD 2:495 5.69~ 2. 359 I 17. goo ~.!8I. -q99.~5C DTCK.:qWO 3,256 3,450 2,4°3 r)RHi]. MWD 39. 090 RA. qWO 120. 397 NSI, :q~.~O 6. 190 TAb..'~wo -999.2bO DTCK. ~!~ a, 17~ ATEP. ~:!w~) -0.044 1.774 1.000 0.32l -999.25n I .815 -0.0!2 2.621 0,000 0.422 -99-9. 250 2.604 PEF MWD RSI .NWD TABD.~WD RTCK,~wD PSER. ~{'WD RSI,~WD TABD.~WD RTCK.~WD PSE~.MWD PEF.M'WD RP,~WD RSI.MWD TA aD. RTCK. PSER.~D PEF.MWD RP.~WD RSI.~WD TABD.MWD RTCK.MWD PSER.~WD PEF.MWD RP.MWD RSI.~wD TABD.~WD RTCK.MWD PSER.MWD PEF.~qWD RP.MmD RSI.~WD TABD.MWD aTCK.~WD RP.~wD RSI.~WD T~D.~WD PTCK.,WD PSE~.~WD PAGE: 7 51135 0.,000 2,183 1.:000 4.835 4,852 3.792 0,000 -999:50 &'SS6 5.828 3,359 0,000 0.954 -999,~50 4.077 4,686 4.259 0,000 1.,296 -999,250 4.399 4,116 5,460 0.000 1 551 -999:250 5.642 3.564 3,615 0.000 1.500 -999.250 t.283 4.299 4.022 0,000 t.261 -999.250 4.0~7 lis Ta~e Verif!ication Listtnq chl,.!mber<~er A18sKo CO~:~otttj.~q Cer-~ter C g~.l,N. N :ND 8.500 HE ~ ~. ~'.',~ D 256.965 GTCK.~WD -999.250 ATPN.~qWD 3. 350 PSPH,~4WD 264,5~7 -999,250 ~TCK. t4 WI) DEPT. ~30().000 C g. L[;. ~4 tql3 8.5.09 NPNt:. ~WD BE~A.~D 261.000 GTCO. ~t~O -999. 250 ?f~CK. ~.) ~TVP, ~:,OD 2.603 !5-~PR-I993 07:55 4,030 41,525 RA,)~wD i. 25.934 NS!.3wD 5,559 TAS.~WD -999.250 3.092 ATER.~WD 2.995 30.098 !.46.852 5.655 -999,250 4,779 ATER.~WD 4.889 0.Olt 2.225 1.000 0,663 '999.250 2.~06 -0.01,7 3.270 1.O00 0.569 -999.250 3.362 2,385 DRHO,~:) -0,028 39.420 P~,HWO 2.603 !~9.340 ~!SI,i~lWO l.O00 5.7"73 TAB.~wO 0 363 -o90,250 DTCF.~wO -999!250 3.3~6 ATgR..~O ~ 634 ],525 2.377 DRND,~WD 40.708 RA.~WD 515.8!3 ~:SI,gwD 5,6~3 TAG.MWO -~99.250 DTCK.M~D 4.320 ATEP.4WD 3.~3~ 45. 460 4.878 -990.250 F)TCK. ¢4 ~D 4.034 9.96 ! 3.737 -0,024 037 ~' O00 . , . 0.640 I.. 000 2.786 -0.019 1.000 0.260 -999.250 2.732 -0.015 2.998 0.000 0.277 -999.250 O. 00~ 1. 807 O.OOO 0.994 -999.~50 PEF.MwD RP TA~D.~D RTCK.~WD PSER.MWD PEF.MWD RSI.~WD TABD.~WD RTCK.MWD PSER.~D PEF.MWD RP,MWD R$I,MWD TABD,~WD RTCK.MWD PSER.~D PEF,MWO RP.~WD RSI.~WD TABD.MWD RTCK.MWD PSER.MWD PEF.~WD PP,~WD R$I.MWD TABD.~ND RTCK.U~D PSER.~WD PEF.MWD RP.MwD RST.~wD TABD.~aD RTCK.~WD PSER,~WD PEF.~wD RP.gWD RSI.~MD RTCM.~wD PAGE: 5,229 ~:046 :000 2.419 '999,250 3,130 3,~45 4, 29 0..000 1.322 -999,250 4,804 3,814 3457 0:000 0 ?0 3.456 4,204 1,327 1.000 3, :6~ 6 5¸8 1.000 1 399 -999:250 3,683 3.553 3,909 0.000 0.647 -999.250 3.738 2.923 2.186 1,000 1.427 1.000 Verification bistln~ chlumber<~er Alaska Computinq Center HFN~.?~wD 253.750 ATPH. ~WO 2,276 POP. ~,~f) 18 !. 220 HE~:A.~¢~D 263.750 AT'FP. ~,SWP, 2. 569 PSVR. P ~ F ,'r · '75 ¢'¢ 0.000 a H O F:.. ?.I W D POP. ~' WP 2 ] a. 553 GR. ?,WI) HF, N a, ~%~:p 244. 250 HEFq. k~D ATDP. ~Wn 1 .¢44 PSPH. ?.WD O F: p T. 740 f'} 0 0 (':, p H ~ :.:% POP. ,v. ~.,' D 239. 977 (:;P (;mC~.",~P -')~9 2'{C, OTC:< . · '. · - ~ · ATDp. !qWP 3. i)q5 PSP~ /', ? V P. u ,:,., D 2.993 P $ v p !.5-APP-199.] :)7:55 2.511 ATER 2. ,40 6 2 44[4 BF~H'3 '"~, 6.t. 57 -999,250 DTCK. ~W[) 2.298 2,354 DRHO. !!6.970 5.760 TAS..:iWD I .000 OTCE, ~4WD 2. 368 ATE~q 2,368 1.848 0.012 2.434 0.000 0.552 -999.250 2.435 -0.008 2.227 !.000 0.429 -999.250 2.258 2.40? 41.900 .1, b7. 666 5.39~ -999. 250 1.9 75 1.3a(~ 2. 506 151 .789 -~99. 250 DTC<. ~ ~'.~ [:) 3.127 ATFR. 3.0~ -0.009 I..970 1.000 0.253 -999.250 2.424 0.005 1.750 0.000 0.256 -999.250 1.540 O.nOg 3.050 0.000 r'.211 !. OOn 2.996 0,006 1.951 0,000 PSER.~WD PEF.gWD RP.gWD RSI,~WD TABD.M~D RTCK.M~D PSER,M~D PEF,.gWD RP,MWD RS!.MWD RTCK,MWD PS~R.~WD RP.~WO RS!,NWD TAOD,MWD RTCK.~WD PSER.gWD PEF,~WD RP.~WD RSI.MWD RTCK.~WD PSER.~WD PEF.MWD R$I.~D TABD.MWD RTCK.~wD PSER,~WD PEF.M~D RP.MwD RS!.MWD RTCK.~WD PSEF.~WD RP.UWD RSI.[{wD TABD.MwD 2,452 .,272 ,275 0.000 !,440 -999,250 2,317 3,229 2,309 0,000 1.336 -999.250 2,348 2.852 1838 0~000 1,485 -999,250 1.770 2 999 2149. 0.000 1.226 -999.~50 2.930 2.978 1.497 0,000 0,758 -999.250 1,630 3.256 3.074 0.000 0.642 -999.250 3.066 4.296 2.388 0.000 0.653 P~P, ~ ~' [) 279.42 ~ .,~ H~NA. ~'~W[> 250,000 GTC~ .~D t .000 ~4TC~. ~4wg ATVp . ~W[> I. 567 D~PT, 6900. 000 RHO8. POP.~[: 301.921 ~ ~'.~ ~l ~, .~WD 263,500 HEFA. ~, D GTC~,~D I. ,000 NTCK, Y~WD g~ P~. ~l~:I) 2,20A PSP~,~, gkD ATV~.~wB 2,189 DFPT. 68 O0.000 ~OP. ~'~E, 147. 537 GR. C;mC~, vwO -999,250 b~TCE, tqi~'D ATPN. ~WF, 2.69~ PSPH. Y, WD ATV~~. ~ 4D 3. 194 ! 5--/,~, PR- ! 993 07:55 ,!...0O0 DTCK. ;~vP 2.179 ATER. i~WD 2.360 2~ 45. ~,82. 5, -q99, 2. 1. 1 37. 147. 5. 2. 1. . 39. 1.52. 5. -999. 1. 37 . 9~, 5. -999. 2. 2. 35. 3. . 35. 96. 6. -999. 2. . i05 T~B.MWD 250 DTCK. ;qWD R58 AT.E;R, FiWO 95O 600 RA.~WD 128 ~$I,~w9 B45 250 DTCK.g~D 279 987 357 DRHO, Mt~!D i,', ,, I . D 5O0 250 DTCK, N!WD 664 895 4.1.2 DRN9. N~WD ? 00 R a. ;4 w I.) 378 ~$I. MwD 920 T ~, },~. ;,-~ W O 250 DTCK.HWO 299 a'.rF~ . rqwr) 466 DPHO. i,iWD 900 020 Tn. ~'~. 725 ATFP, ~?U 43, 0 DRF9 . 240 250 67!. 690 -999.250 1.932 -0.020 2. 377 0.000 0.450 -999.250 2.055 -0.02! !. e55 o]ooo 0 :gTO O0 1.724 -0 015 .14 s 0.000 n2o6 -99 22so !.500 0.006 2.2!8 0.000 0.2!7 1.000 2.176 -o.003 .787 ..000 0.169 1.000 3.022 0.002 2.603 0.000 0,264 -099.250 2,642 RTCK.~WD PSER.M~D PEF.~iD RP.MWD TABD,gWD RTCK,MWD PSE~.~D PEF.~WD RP.~WD TABD.MWO RTCK.~WD PSER.gwD PEF..~WD RP.~WD TABD.~WD RTCK.gWD PSER.~WD PEF.~WD RP.MwD RSI.gWD TABD.UWD RTCK.MWD PSER.~D PEF.MWD RP.MWD R$I.~WD TABD.MWD RTC'K.MWD PSER.~WD RP.MWD TARD.~WD RTCK.~WO PSER.~B PAGE: -999.250 2.135 3,012 1,961 1o000 ,228 .000 2'193 3.17! 2,037 o'ooo 0,917 -999,250 2,016 ~.887 0.000 0726 -999:250 1,785 2,938 2,242 0,000 1 281 -999:250 2.26~ 2,931 2,940 0,000 0,669 -999.250 3.064 3,003 2.6el 0.000 1,671 1.000 2,690 IS Taee Yerificat::~on hist!ns chlumberqer ;~],aok~,~ "a Com[~uti.~:~ Ce.~ter. . ATP~'.MWD 2.775 PSPH, ;.:iWD ATV~. ~,~WD 2.757 PSVR.~WD D K P T. 6400,000 R H 0 F!.. ~' W D GECK. ~:dD -999, ~:56 NTCK. :wO ATP~'. ~ W'O .4.'178 P8PE.NWD DKPT. 6300, O0 CSLN.~W!'~ 8.643 ROP. ~WD 298,294 (;TCK, M~<D -999,250 ATp~.NWD 3.393 DKPT. 6200.000 POP. ~WD 354.3~7 (:;R. ~E~i,~. ~ WD 267,500 GTCK. ~V:D 1.. GO0 ~:TCK. ATPN. ~wD 2,756 POP[-!, ~TV~, MWD 2. 756 PSVR. ~(']v. ~,~WD 405,96a GR. MWD ......... . zSO NTCK. i~wF; AT P~. f,~ .,, D 3.524 PS P:t. ?,: w D ATVP. N, wi:) 3. "~ !. ::~ 2 PSVp. Mkf) 15-APR-1993 07:55 2,3S2 DRHO. ~WD 33,300 RA,MWD 100'619 ~,~ S I.,. ~,~ w f_) 6,67~ TAB, M~;D -999,2b0 2,815 ~TER. 2,789 2. 320 34 . 300 97.307 6. 504 TAB. YWD -999. 250 DTCK 2 · 797 ATEE . 2.863 2.419 DRHO.MWD 29. 700 RA,'MW!) 109,506 N5I. ~!WD 7.3!3 1 .000 DTCK,aWD 3,370 ATER. 3.1!3 2 329 D":.., ,,, 34.400 P,A. 4.920 *: S I, ''~ w O 6.432 TA.B, MWD q99,2bO OrCa. WD 2.743 ATE.a, ~.747 32,960 RA.MWD 114.116 6.733 3.475 ATER.,~WD 3.4u5 339 21 ! 6e2 -qgq.2~5o 3.f)1¢ 0. 002 2.791. 0,000 0.2.47 -999,250 2.755 0.000 2.750 0.000 0,326 -999,250 2.79.4 0 01,1 4:132 0.000 0. 244 -999.250 4. :l 19 0,015 3.3 I~ 0.000 0.214 -999.250 3.193 -0.0!6 2.774 0.000 0.278 -999.250 2.75q 0.000 3.517 0.000 0.414 -999.250 3.481 -O.001 3.17~ 0.n00 o.144 -909.250 2.997 PEF,~!~D RP.MND R$!.~WD TABD.~WD RTCK.~D PSER.~wD PEF,MWD RP.MWD RSI,M~D TABD.~WD RTCK.MWD PSER.MWD PEF,~wD RP.MWD RS!,~ND T,ABD,MWD RTCK.MWD PSER.MWD PEF.MWD RSI.MWD TABD.MWD RTCK,~D PSER.MWO PEF.MWD RP.MWD RSI.M~D TABD.gWD RTCK.~WD PSER.MwD PEF.~WD ~P.~WD RSI.~wD TABD.MWD RTCK.~WD PSER.MWD PEF.~WD RP.~WD RSI.~WD TABD.~WD RTCK,MwD PSER.~D PAGE:: 10 3,014 2.793 0.000 0,766 -999,250 2"794 2.945 2,~30 0',00 0.568 '999,250 2,843 4¸7 2'~1o :ooo 0-492 -999.250 4,023 g.000 . 495 -999,250 3,182 3,040 2.737 0.000 0.767 -999.250 2.746 3.041 000 0.633 -999.250 3.435 2.882 2.912 0,000 0.459 -999.250 2,896 IS ~a~e 'Ver!.~lca..t:.i. on List, inO :h!uF,.he_.r~er i,~,!aska Computti. nq Cent:er ~.,) , ~ · 3.2a, o . 3.167 700,0 O 0 !. 00 ¢) ...... 0 886 . 6 O O, 000 302,597 2.9~,.. ,55,750 3,779 3 [~ 14 ~ 5 C n 544.7 I r, 255,5oo . 4.3~f.) I 5-APR-!993 07:55 92,47,4 -999.2b0 DTCK.MWD 3.04t 3.042 35. 900 99,792 6.073 -Q99.250 DTCK, ~4WD 3.103 2.228 37,500 I{)5,505 f'4Sl, ~WD 5,77] T.~B, MWD -999,~50 DTCK,.NWD 1.047 0,881 2,395 35.90fi 6,098 TA~,MWO -999,250 DTCR.~WO 2.97 8 ATF;R. 2.962 "22r' DR~4n,MWD ~; . ,~ .... 35. 300 RA. 1 03. ~4~ ~,~Sl .~WD 6.145 TAB, ~.(wO 3,750 3. 796 2. 325 3~. 300 p r~. ~wO 102. 690 5.730 'o9o.250 DTCK, 4.304 4,383 0,0 ! 6 3.1.55 ,000 . 122 O0 0 ~'1.41 0 007 0. 000 0.093 -999.250 3.!81 -0.012 0,536 0 000 0:079 -999,250 0 .R2! 0.030 3.067 0.000 0.175 -999,250 2,984 -0.019 3.72,3 O,00O 0.! 35 -999.250 3.~15 -0. 007 4,265 0.000 0,083 -999.'?50 4,400 3,430 i'" P F, ]. ~,', ~'.-~ r~ -0,O77 1,500 R ~. ~!~:; -90o, 250 4.1 'l 3 TAS. ,'~WO 0. 956 ! . 0OO !.':~TC~-, ~t~O -0O9. 250 o. 250 t, T E ~. :',. t~,) - q q 9.250 PEF.~D RP'~WD RSI,MWD TA.~D.MWD RTCK.NWD PBF,~WD RP,~D RSI,MWD TABD,NWD RTCK,~WD PSER,~WD PEF,NWD TABD,gWD RTCK.,~WD PEF.~WD R$I.~WD RTCK.~WD PSER.~WD PEF.M~D ~,~WD RS!.MWD TAE~.~WD PEF.~WD RP.MwD RSI.~WD RTCK.~WD PSER.~WD PEF.gWD RP.~WD RTCK.~WD PSER.gwD PAGE: 1! 2,904 3,02! 0,000 0,.414 '999,250 3,043 2. s 4 6 3'! 00 0,000 . 0.41! .472:600 0~000 0.616 -999,:250 0.958 · 3:.4]2 2.934 1.000 0.422 1.000 2°978 906 0 000 0~]86 -999.250 3.756 3.112 4.415 0,000 0.392 -999.250 4.382 -999,250 -999,250 0.000 1,152 -999,250 -999,250 l,$ Ta.n.e verification List, in.~ r. hlum~erger ~].aska Ccmout~.n.a. Center !5-APR-199~ 07:55 PAGE: SERVICE : FLIC VER8IO~.~ : 001~07 D~T~ : 93104t14 ~A.X PEC S~ZE F?L~ TYPE L.~S~ FILE SFRVICE VFRSION ~X RFC SIZE FILE TYP~] [, ~ $ T F I 1., E RAW ~'urves and loa header data for each bit run in seoarate files. v~'!3oR T(li]L COD~] STApq' DEPTH 5317.0 LOG }iF:AD~R I)A~A DATE !,OCGE[?.: DaT~ TYPE ('.iF{-4f']PY f)R PF:AL-TT.~!E): ~t) DPI[,I..~P CF'f): ~np !_,GG TN'rE~V~L f~(';TTO¢4 !..,f)G iCq.'EP~AL [FT): PiT Pr)TAmING S~EE[:) (PP~,~): 1O034.0 10034.0 v4. oC 531.7.0 I'S ~$oe Veriffcati. o~ cbtumber.oer A.lssR~ Com[~tJtina Center 13 V~'J~DO~ TOOb CUDE TOOL Cb ~ RES ! ST ?,:iUD D~NSiTY fl,B/C:)= ~':uO V!SCOSI?¥ (8): MUD PHI F!.,0!D LOSS (C3): MUD AT ?'.:~:ASLi~ED T~i~P~RATUR~:', ~:UD CA~:K AT 8,500 5298.0 !1.90 3,020 3,070 68.0 ~: Et!TP, ON Ti:]OL .~' ATRIX SANOSTONK ~.65 8,500 'r[.)OL 8TANDnFF ( PE~AR~:S: TMI~ F'I!,K C[:'!~'~ ... :. ............... ~.~W!) Flbg. THIS DATA lS AS CL[JSE TO TaE ACTUnL RAT~7 OF LIS ** SFT TYPE - 64E~ ** ! 66 0 4 66 ! chlu,T'~'berqer AlasKa ComF.,L!tJn~ Cgnt:er 15-APR.,,~ 903 07;55 14 ~ 73 7 65 8 68 0.5 9 65 ~3 66 0 i5 6~ 0 66 GTC~ ~D S 61, DTC~ ~D S 6! RTC~ ~ 5 61. t APi P Flit,~: ~u g N~i~ $ t;; REPR P :~CgSS 94 oo 0 O0 2 ! 1 4 6~ ~994 O0 000 O0 0 $ 1 I . 4 68 0000000000 ~994 ('}0 GO0 O0 0 2 1. I 4 68 0000000000 R994 O0 0~0 OO O 2 I I 4 68 0000000000 ~994 O0 OOG O0 0 2 1 ~ 4 68 0000000000 O F P ?. 1 () 035.00 C~ RTCR. i'~NP -9.o. 9. 250 [::, ~' p'l'. 100 O O. 0 O 0 R'rCK. MWD -999. 250 D?P~. 9900.00() ~TCw. ~ ~ !] -999.2S0 RTCK. ~, ,.iD -999. 250 D F p w. 97 n (1. (~; o C: D~PT. -~50h. 009 RTCK . ~,h -999. 250 - ~TCK. M ~.': D -999. -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 Tape Veri. flcation bist~,r,a chlumber,.,.~er Alaska Comout, ing Center RTC~. H~D -999. 250 DEPT, 9100,000 GTCk.i'4WO RTC~. ~; i,"~ D -999. 250 DVPT. .~9©0.fi0O ~TCI< . ~4 !~ D -999 . 250 ,RTCI~. a~D -999. 250 DFPT, R7fl0.O0(i ~TCK. u¢:O -999. 259 DFPT. 8500. ...... RTC~< . ~W'D -999 , DEPT. a4OO.000 GTCK. ~iwD RTC~. ~ifiD -999,250 DF;mT. 8300. 009 GTCK. i-~<D RTC~, ~WD -999. 250 DEPT. 8100.90(> RTCK. ~i~,D -9q9. 250 DF'PT. 80n0, (} 00 GTCK. ~vi t,,~ D RTCI<. ~t~,~O 1 . 000 [>rpT. 790(), ©a0 GTCK. !!wi) RTCZ. r~wp -9q9. 250 D ~ m T. 78 O i;. (; 0 C' G T C K. ~" t,; i') Rq'CW. ~?!D -9q9.25C:, 77 O 0 -999 IS-APR-!993 07:55 -~99.~50 -999.250 1.0UO NTCK.aWD -999.250 NTCK.~D 1.. 000 NTCK. I~W[) -999,~50 ~TCK.aWD -999.250 NTC~i,~iO -999.250 ~TC~.~WO -999.250 NTCK. q~[) . -999.250 ~TCK.NWD -090.250 1o00© -q90.250 NTCK.~W9 -999.250 -999,250 I. 000 ,ooo -999.250 ~.000 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -9a9.250 -999.~50 1.000 1. 000 DTCK.~D DTCK.a~D DTCK.~D DTCK.~WD DTCK.~WD DTCK.~D DTCK.~WD DTC[.~WD DTCK.~WD DTCK.MWD DTCK.M~D DTCK.~WD DTCK.MWD DTCg.~WD DTCK.MWD DTCF.~WD DTCK.MWD DTCK.~D PAGE: 15 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999,250 -999.250 1.000 '999,250 -999.250 -999.250 -999.250 -999.250 -999.250 IS ~rane V~r~:~f...catton Listlnq chlumberqer ^lasKa Com[',.utin(~ Center PTCK, ~.~¢iD -999, ~50 DEPT. 7500,000 RTCK, gt4D -9~9,250 D~p~, 7400,000 R T C K. M RTCK, ~ RTC~. ~.~WD -999,250 D ~ P T, 69 ~TcK :~WD 999 ~ 250 DEPT. RTCK. ~t~l) -9q9. RTC~. RTCW. ~4¢/D 1. 5-~PR-I 993 07:55 -999,250 -999,~50 ~tTC~, UWD -999,250 hTCK. ~4WD -999,250 NTCK.bWD J. 000 hTCK. !. 000 NTCK, ~qWD -q99.2:50 NTCK 1,000 NTCK. ?4v~D 1.. O00 NTCK. -999.250 -999.~50 i,~TCF, ;.lt~ D ]..000 ~JTCK,NWD -99q.250 NTCI<. Y,lW D -999.250 -999,250 -999,250 1.000 -999,250 -999.250 -999,250 -999.250 -999.250 -g99o~50 -99g.250 -999,250 -99g,250 1.000 -999.~50 1.000 -999.250 DTCK.gWD DTCK.g~D DTCK.MWD DTCK.~WD DTCK,~WD DTCK.gWD DTC[.~wD DTCK.gWD DTCK.~WD DTCK.~WD 0TCK.~WD DTCK.~WD DTCK.MWD DTC~.~WD DTCK.MND DTCK.~D PAGE. 1.6 -999.250 -999,250 1,000 -999,250 -999.250 !'000 -999.250 1.000 1.0o0 .-999'250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 IS Taoe Veri, f!,.cat!,on L,.istinq ~hlumberc~er Alaska Computin~ Center DE'PT. 5~00.000 GTCK.MWD RTCI{. ~-~WD -999. ~50 DEPT. 5700.000 RTC~.gW[> -999.250 DEPT. 5500.000 GTCKoMY[) RTCKoMWD -999.250 D~PT. 5400.000 RTCK.~:~wn -999.250 DEPT. 5300.000 GTCK.~WD RTC~<.g~:~ -999.25fl DEPT. 5200.000 RTCK.g~ D~PT. 5156.000 07:55 -999.250 F!TCK. M!~D 1.000 STCK.~WD -999.250 ~TCK.MmD -999.250 NTCK.~WD '999.250 NmCK,~WD '999.250 gTCK.~WD '999.250 NTCK.~WD -999.250 NTCK,MWO -999.250 -999.~50 -999o250 -999.250 1. 000 -999. 250 -999.250 -999.250 '999.250 DTCK.MWD OTC~ .~WD oTc~.' MWD DTCK.~WD D~C~.MWD DTCK.MWD DTCK.~WD DTCK.~WD PAGE: !7 1.000 '999,250 '999,250 -999,250 -999.250 -999.250 -999.250 !.000 -999.250 **** FILE TR A I [..,M~. **** SERVICE : ~'LIC V ~:PS 107,~ : 001 gO7 MaX RFC S!Z.F : J. 024 F T L ~' .u, ~ A F) E; R rhlumberoer ~la~.ka Computino Center 15-~PR-lg93 07:55 PAGE: Curve~ and loc :,~.e~,~t~..r da,..a ~or each bit run in separate ~f. les. FTLF CDN 5.3! 7,0 ~TE LOGGED: .~OFTWARE: TD DRIbbER (~T): TOP LOG I~:~TERV~L (FT): g[)l"rfl~4 LOG I~TRRVAL (FT): RIT ROTATING SPEED O,[,,, STR!NG (TOP '?O bOTTOf'4) VENDf)P TOOI..~ C00E TOC) L TYPE CDN NEtJT~(')~'~/DENSIT ~ CDR RES~ ST I V ITY OPEN HOLE AIl' .S!Z[: (iN): bR!LLERS CASt~,,G PEPTF ~kbO DE¢.~S!TY Cf,B/G): '4!~0 VTSC[].q/T~' (S): ~[,lg CHbORI[;F~5 (PP~) ~ Ff,iJ!~ IjOSS CC3): P;~S!STIVfTY (Ot'i~! AT TE:"~PEF~.TUR~ STOP DEPTH 10034,0 10034,0 20 -, ~,~ A R -,9 3 FAST 2,3E V4,0C 53!7,0 10034,0 ~DS0 t 8 R6S042 8,500 1!,90 3.02~) 6~.0 68.n 500 !S Ts~e vet. Irt. cation !~,tst~n~ chlumber~Ter .Al..aska Comr::ut. inm Center PAGE: tq AVERAGF/7 HflLE DEVI.~TION: 4o DEG 5317' -7735' 75 D[{G 7735' - 10014' q'r'~ v. hl.,b fa 20:52 <.}N 19 MA~'-1993~ ROTATIONAb BUI~ DF~SSITY P~[2CE;SbI~;~G USED. F~AR,IT~] ADD~iD SO~'T?/AR~7 vE~S!{3?i V4.0C . RESISTIVITY h~}O DE:NSITY N:EASUPE POINTS, :bl, u~berqer Al. asPca Co~putinc Center 2O OPlf~ T L, i~ ,l Pi! h189 ps~ Lw1 O H~,~ u 612994 O0 000 O0 GP I,,W1 GAPI 61~99a. O0 000 O0 }{ ~'~' ~.~ ~ L~I CPS ~t8994 00 000 O0 aFF~ LW1 CPS 61~994 nO o00 O0 TABD bW1 6189q4 O0 000 DO NSI t, Wl 618O94 ~1 Lw! fiI~994 O0 000 O0 n 3 !, I 4 68 0000000000 0 3 1 1 ~ 68 0000000000 0 3 I I 4 68 0000000000 0 3 ! 1 4 6~ 0000000000 0 3 1 1 4 68 0000000000 0 3 I. !. 4 68 0000000000 0 3 1 1 4, 68 0000000000 0 3 1 I 4 68 0000000000 0 ] ~ 1 4 68 0000000000 0 3 1 I 4 68 0000000000 DEPT. 10034,000 DCA!~.LW1 -999,250 DP~I,LW1 DSP.LW1 -999.~50 PST.LWI -999.250 DC A [.,,.. L ~i 1 0.729 DO'f!!.hW! PSP.Lwl 9,603 RL, PE. bw 1 PS I, b'~ ] 0, COO -q99.250 DR}~O.bW! -999.250 PEF.LWl -999.250 TNDH.LWl -999.250 ATR.LWt ~15.959 GR,Lwl -999.250 HENA.LW1 -999.250 TASD.:LWi -999.250 NSI.I~W1 -999,250 DR~O.bWl -999.250 PEF.LWl -99o.250 TNPM.LWt -099.~50 ATR,LW1 173,1.11 Gk.hw! -999.250 NENA.LW1 -Q99.250 TAB~.bw1 -999.~50 uSI.hWl 2.50~ DRI.{~.LWl -0..008 PEF.LW1 8.6(,0 T~Pii. LW1 28.800 ATP,LWl 72.581 GR.LW! 47.366 [4ENA.LWI 0.632 TAPQ.L~i 1,622 NSI.LW1 2.545 DRHO.Lw1 O.OlO PEF.LWl. 6.400 TNP~i.I,~I 26.000 ATR.!,,Wl 63.947 (;a.bW!~ 100.025 HENA.LWl 0.714 TABO.Lwl ~.528 NSI.L~I 2.490 DPHF].LWl -0.009 PEF.LW1 o.200 TNPH.LWl 22.400 ATP.Lwl !U7.147 ~P.I.,~I B4.918 HEN~.LW!. 0.669 TA~F,.LWl 2.021 NSI.I, w1 -999,250 -999,250 -999-250 -999.250 -999,250 -999.250 -999.250 -999,250 7,078 7.781 307.250 0.000 5.802 3 517 0.000 4,379 3.951 342.000 0.000 IS ~a~ne Yeri. f.l. catlon !~ist:l.n~ cblu~berqer Alaska Com~utin.,g Center DEPT. 96©0.000 DC~[ ![:. L 5:g I 0,3~5 DPHI,L~I ~S~.Lt~! 3,621 PS!,L~,;! O, DEPT. 9300.000 ~, t~O:~3. [.,W 1 DCaL.LWl 0,294 DPP, !. LI,~ 1 PSP. t,.:W l 4,269 aO~E.LWl ~8!. L~ ! O, 000 15-,~..PR- 1993 07:55 2.4~0 10,300 TNPI~:i, Lw 1 ~{ g. 669 0.957 2.736 DRFO,LWI -5.200 TNPH.LW! ~1.082 GR.L~I 1.8,16 TABO.bWl 2.5a0 DR~O,LWl 4.200 T~PH.LWl 48.649 GR,LWl 0.285 TABD.LWl 2.438 D~HU,LWl 12,800 THPa,bW! 0.474 ~ggO.bWl 2.420 DPHO.bWl 13'900 T~:Fa. LWl 123.977 Ga..~l 0.531 TABD.L~I 19.&O0 64.215 da.LW'! n.40g 13.700 Ti'~FH, .Lw 1 175.1.18 0.322 T~F, 9.LW! -0.002 23 .400 1.876 - 0 003 25 In0 s .14$o 1,558 -0.125 29.500 t15.603 4.618 0.ol0 29.100 116.707 2.162 -0.019 30. 900 129.4.30 2.393 0. 000 4!.. !.00 !23. 564 0.953 40.200 1.24.811 1.256 -0.0!4 44.500 119.911 1.543 -0. 029 3 @. 400 !19.120 1.. 504 PEF.I, Wl ATR.t, Wl HENA.I.,W! PEF.bWl ATR.LWl HENA.LWl PE¥.LW! ATR.LWl HENA.L:~I NSI.LWl PE~.LW! ATR.LWI HE:NA.LWl NSI.I,W! ATR.LW! HENA,LW1 ~$!.LWl PEF.LWl ATR.L~I HENA.LWl N$!.LWt ATR.Lwl HENA.I, W1 PFF. L ~ 1 A'?g. LW 1 HENI.LW1 NSI .I,Wl 160 31, 8.250 0,000 83 :322. 333 0,000 i:898 496 37~. 750 0.000 6. 706 3 '723 30 i · 750 0. 000 4.813 3.1,19 306.143 0.000 5,133 2.449 271.750 0.000 4.880 2.321 272.250 0.000 4.099 2 503 sl:?$o 0.000 4.221 1.836 262.625 1.000 ~hl.u~,be.r. cler Al..ask'a COm[:~t.]t into Center DCAL;LW! O. 2Et;; 9PHI:LWl ~,q~. [,W ! 4.030 ~,3PE.Ltt ! .HEF/~.L~I 5.173 TAB.!,Ia:I ~$I. b:^' 1 0. nO(; 15-AF:R-] 993 07:.55 ~.417 DRFO,UWl !,4.100 0,417 2.410 DRN[I.LW1 14.500 TNPH.I,W! 37.578 6R.LW! 0.5!~ TABD.LW1 2.3~5 318.00! GR.bW1 0.271 TAF~.hWI 2 391 BRH("~, b~:~ 1 238 4 . .... 4 ..0 GR.I,Wl ().2~5 TABU.AW1 2.395 Ic,4bO ,. NPH.LW1 ],004 T~BO.L~I 2.497 DRHg.bW! 9.300 101.122 GR,LWl 0.549 TABD.bWi 7.80O !20.326 1,256 - 0 007 15.863 2.271 -0.004 43.900 143.923 1.400 -0,023 38,200 184.130 1.012 -0.040 39,200 456.084 1.340 300 1. 90. 657 1.3~2 -0.005 40.800 171.602 0.644 -0.01,9 35.300 {74.25@ 1.419 0.010 34.600 112.467 1.436 PEF.LWI ATR.L~I EF,I.,Wl NSI PEF · LW 1 ATR.LWl H g N A, I,, W ! PEF N$I. I, .' 1 ATR.LWl HENI.LWl NSI.LWl PEF.LW! ATP.DWi H~N~.LW! N$!.LW! PEF I, Wl AT~:LWl PEF.LWl AT~.LWl HENA.LW! HST.LWI PEF.L~I ATP.Lwl HENA.I.,Wl ~iSI.LWl PAGE: 22 603 271,750 0,000 2,220 26~'b67 .000 581 259,000 1. 000 3:. 18 2;~35 263',000 1.000 4.527 2.893 268.500 1',000 3 4!6 246,500 1.000 O7 l:gso 243.500 0.000 700 256.648 0.000 3 325 256.000 0. 000 Center i5-~PR-1993 07:55 2,4°3 DRHO,hW1 1!.300 T~P[!,hWt ~11,¢02 gR.hWl 0.426 2.37n DRNO.LWJ !7,000 TMPH.bwI !30,434 Ga,bWl 0.253 TABD,L~! 2.419 I 4 000 234: 0.30 0.256 2.4-90 DRHO,bWl 9.700 T~PH.LWl 228.261 GR.LNI 0.2t.t. T~D.bW! 2.476 DRHf.~,!jWl 10,600 TNP8,LWl ~63,640 GR.LW1 0.200 T~BD.Lwl 2.3!3 DFHO.LW1 20,400 'F~]PH.LW1 148.758 GR.LWI 0.478 TA~D,Lwl 2.33(> DRHO,LWl 19.400 TFPH.I.,~I 171.42! GR.LWl 0.276 TAFO.LWi 2.39! 15.700 27.~. 172 G.P.. I:t 1 0.203 0 022 352900 1~7,:26! !,339 -0.012 41,800 !07.502 1.479 -0 01! ss:4oo l O~. 927 ! .232 0.006 46.!00 .369 6C,: 758 0 001 ~72 J. 48.924 0. 725 0.022 47.100 168.631 0.65 -0.028 37.500 189.886 1.22~ -0.030 38.000 166.944 0.919 0.005 39.700 146.702 0.732 PEF,LW! ATR.LW! HENA,LWl NS!.LWl PEF.LWl N$I PEF.Lw! ATR.LMI HENA.LWl PEF.LW{. A T R, L w 1 NSI:LWl PEF.LWl ATR.LWl HENA.LWl N$I.LwI PEF.LWI ATR.LWl HENA.LWl N$I.bWl PEF.L,W! ATR.LN! HENA.LW! ~;SI.Lw! gT~.bW1 HENA.L~I N$I.BWl PEF.I, Wl AT~.Lwl }iENA.I.,W! PAGE: 23 . 83 243' 250 1,000 ~,805 24 , 750 0,000 3,067 1,998 263,7.5.0 1,000 3,0!1 !,7t3 250,250 0,000 3.150 3,025 255'000 0,000 4.346 1.830 244,000 0,000 3.100 2,545 253.000 0,000 3 215 260.875 0.000 3,789 1.454 250.000 0.000 IS Ta~.e Verifi, e,at!or~ Llst~.nq D~PT. 6700,Oo0 RHOB.b~I DCAL.LW~, 0,369 DPM!.LWi DSP.LW! 2.fl~8 ROPE.L~I ~FFA.L~I 6.473 TIB.L~I ~S!.LWl 0.000 DFPm 6600. 000 PHO[~.LW !, DCAL ~ L!.,~ ! 0.190 DpN I. h~ l ~ $ ~. L w .1 2.793 P 0 P E. L.~ I !,5-~P~-1993 07:55 2.406 DRHC.L~! 14,.800 TNPH.LWi 255.849 GP.L~! 0.2i. 7 TABD.I,W~. 2.429 DRHO.L~I 13.400 TNP~{.LWi !14.150 GR.L!~i 0.155 TABD.L~I 2.~23 DRHO.L~I 13. O0 TNP~,I.L~I. 259.998 GR.LW1 0.406 TABD,L~! ? ~72 i6i 00 285773 2.3~0 DR}iO.B~I 17.600 T~iPH.Bh! 264.000 GR.B~I 0.325 TAgO.L~l 2 369 17; !, 00 257. ~55 0.244 2.423 !)RHO.I, W1 13.~00 T~!PH.bW1 302.844 G~.L~! 0.214 TABP.LW1 2.355 !7.~00 TNPE.I,Wl 0.279 2.346 DRHn. LW! !9.400 TNPh.[,~I 39P.249 CR.LN1 0.4!4 TABD. L,~ 1. 0.005 3~.100 97.222 !.284 -0.00! 34.400 9!'089 0.653 0.0il 34.1.00 93.705 t.669 -0 003 3.5:ooo !00 676 0:765 0,008 34. 700 99. 393 0 O06 ,:soo !21.44t 0.492 0.019 31.000 108.307 0.494 -0.006 32.600 92.890 0.769 -0.002 31.800 !.13.988 0.636 ATR.L~I NSI.L~t. PgF.bW! AT~.LWl HE~A,b~I N$!.LWl PgF.b~l ATR.I,W! H E N A o L W 1 PEF HENA. !,,, W 1 N$I HENA..LWl. PEF.LWl ATR.L~I HENA.LW1 PEF.LW! ATP.LW! HENA.b~I ~SI.LWI PEF.LWl AT~.L~I HENA.I.,Wl PEF.LWl ATR.LW! NSI.LWl PA, GEl 24 2.940 2'227 262. 000 0.000 3,059 2'633 263,71:2 0.000 3.106 2.633 266.250 0.000 2. 850 2.791 ,Tg: ooSO . . 0 2. 922 2.7!0 270,000 0.000 2. 909 4 027 278:soo 0.000 3.138 3,243 271.500 0.000 3.108 2.759 267.500 0.000 3.090 3.567 268.250 0.000 000'0 0~'~ 000 O0 t 000'0 O00'g~ OLI'E 000'0 00~'~ 6))') OS)'E 000'0 [:iCL'[ 6cj8. 000'0 O0~'09g 9/.O 000'0 000'9~ ~6~'I gLO' 000'0 000'0 O§t~'Lg~ 000'0 O00'Lg~ 868~ I~q'VNSH I~q'~NSH 0~'666- Og~'666- OOE'E~ 9IE'O LEE'LL O0~'lq ggI'O E6E'O O00'SE lO0'O 98E'0 611'66 oOI'L£ oo61s 900 0 Li9'O O0'['gE 0[0'0' EO~, 66 006 "0E 000 ~I~'O O0~'§E 8S~"0 00~'~ gO0'O [~q'HdNi OOI'LT [Nq'CHaG 89E'g (,~lq' O~t v£ fgO'O I~lq' ~tO LL9' I aq ' Hd;'.'J. I~q'aD ~60'61~ laq'osV,.L SL'['O I ,~ q ' H d i~ & 00 ~ ' 6 [ I a"l ' OH~:iG 6ZE'a i~q'sD 0~L'969 I~q'OH~q L6'['~ iaq'aO 8Pg'£Ig I~q'SO 990'L9£ ; f,~ ri ' 0 H a q 9 ,:.] g ' Z ~:LO g6~i-adV-qt 09g'666- O~g'666- 0~g'666- 0~g'666- tg'l'IRN O~g'666- tM'i'¥NMM 0~g:'666' "[~q'A~d 0~'666- i3q'sD O~g'a66- ~q'~dN~ 0~'666~ [~ri'(]dg~ 0~g'666- l~q'2d08 ¢Sg'666- I~q'~OH8 O00'SSiS 9~
