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Home My WebLink About186-110MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-09 KUPARUK RIV UNIT 2T-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-09 50-103-20071-00-00 186-110-0 G SPT 5631 1861100 1500 3850 3850 3850 3850 140 140 140 140 4YRTST P Adam Earl 6/21/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-09 Inspection Date: Tubing OA Packer Depth 170 1825 1745 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625072643 BBL Pumped:1.2 BBL Returned:1 Tuesday, July 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, July 7, 2021 P.I. Supervisor �C�Bq 7�j(o(�� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-09 FROM: Jeff Jones KUPARUK RIV UNIT 2T-09 Petroleum Inspector Well Name KUPARUK RIV UNIT 2T-09 Insp Num: mitJJ210628154830 Rel Insp Num: Sre: Inspector Reviewed By: P.I. Supry 3512 -- NON -CONFIDENTIAL Comm API Well Number 50-103-20071-00-00 Inspector Name: Jeff Jones Permit Number: 186-110-0 Inspection Date: 6/5/2021 Packer Well 2T-09 Type Inj w- TVD PTD 1861100 Type Test SPT Test psi BBL Pumped: 1.3 BBL Returned: Interval 4YRTST !P/F Notes: I well inspected, no exceptions noted. . Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5631 Tubing 2380 2380 2380 2380 1500 IA zoo 1820 - 1760 1740 1.2 OA 0 0 0---i P ✓i — —0 — Wednesday, July 7, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 P.I.Supervisor 'j(J(I i' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-09 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv� L-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-09 API Well Number 50-103-20071-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-110-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607151324 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-09 Type Inj W, TVD 5631 - Tubing 2500 2500 2500- 2500 PTD 1861100 Type Test SPT Test psi 1500 - IA 1160 1900 - 1860 - 1860 - BBL Pumped: 0.5 - BBL Returned: 0.5 - OA 20 20 20 - 20 Interval 4YRTST P/F P / Notes: SCANNED ` Er J 3 20!? Thursday,June 15,2017 Page 1 of 1 STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed. Abandon r Repair w ell p. Rug Perforations r Perforate r Other r Alter Casing p Pull Tubing r' Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-110 3.Address: 6.API Number: Stratigraphic r Service r' P. O. Box 100360,Anchorage,Alaska 99510 50-103-20071-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25569 2U 2T-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CBL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6370 feet Plugs(measured) 5882 true vertical 6141 feet Junk(measured) none Effective Depth measured 6266 feet Packer(measured) 5851 true vertical 6040 feet (true vertical) 5631 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 110 110 SURFACE 1958 10.75 1992 1989 PRODUCTION 6321 7 6351 6122 RECEIVED C 3 0 2014 Perforation depth Measured depth: 6022'-6058' �w True Vertical Depth: 5799'-5834' AG GC Tubing(size,grade,MD,and TVD) 3.5 x 5.5, L-80/H-40,6012 MD,5789 TVD Packers&SSSV(type,MD,and ND) PACKER(TUBING)-BAKER FHL RETRIEVABLE PACKER 47B @ 5851 MD and 5631 TVD SSSV-CAMCO TRMAXX-CMT-5SR @ 2026 MD and 1805 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r- Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 314-379 Contact Theresa Lee(c 263-4837 Email Theresa.M.Lee@conocophillips.com Printed Name Theresa Lee Title Workover Engineer Signature 1 .(0.. A „A ...4...efL. Phone:263-4837 Date 1/ ii 9 / 1 Li vii- RSC MS OCT 31 741- 3/as// Form 10-404 Revised 10/2012 Submit Original Only T.Lee T , Workover Engineer Drilling&Wells P.O. Box 100360 1111VRECEIVED Anchorage,907263483 99510-0360 ConocoPhuHups• OC1 Phone: 7 3 2014 October 30, 2014 AOGCC AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-09 Dear Commissioner: Attached for your review is Report of Sundry Well Operations to convert 2T-09 from suspended status to WAG injector. If you have any questions, please feel free to call me at anytime. Sincerely, j_eb T. Lee Workover Engineer CPAI Drilling TUskad KUP INJ 2T-09 ConocoPhillips m Well Attributes Max Angle&MD TD Ala-ka.Inc. Wenbore API/UWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) („„,„„A hibps 501032007100 KUPARUK RIVER UNIT INJ 25.70 3,600.00 6,370.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 27-09,10/27/2014 11 A3.40 AM SSSV:TRDP Last WO: 7/102014 40.69 7/5/1986 • Vemcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date . _ Last Tag:SLM 6.268.0 9/1/2014 Rev Reason:SET WHIPSTOCK lehallf 9/14/2014 - HANGER;28.3 I II y' _. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread SURFACE 103/4 9.950 34.8 1,992.3 1,988.7 45.50 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... 1M/ion(I...Grade Top Thread PRODUCTION TIE- 7 6.276 30.3 1,795.3 1,794.3 26.00 L-80 TC-II LUILSBWHINSININIIIIIMIRMANWM BACK 1 088ul LL Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread WINDOW 7 6.276 5,990.0 6,000.0 5,777.4 as-Ad CONDUCTOR;35.0-110.O1W ` Casing Description OD((n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread PRODUCTION 7 6.276 1,795.3 6,351.1 6.122.1 26.00 J-55 BUTT = Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WD 3 1/2 x 5 3 1/2 2.992 28.3 6.012.0 5,789.2 9.30 L-80 EUE 1/2 @5926.1 3 PRODUCTION TIE-BACK;311Completion 1,795.3 " p tion Details Nominal ID ' Top(ftKB) Top(ND)(ftKB) Top not(9) Item Des Com (in) 28.3 28.3 0.03 HANGER MacEVOY GEN 4 TUBING HANGER 2.992 1 2,022.2 2,018.2 9.32 SAFETY VLV -TRMAXX-CMT-SSR SAFETY VALVE 2.812 SURFACE;34.8.1.992.3-J l 5,820.5 5,601.7 12.84 LOCATOR SEAL ASSEMBLY LOCATOR SUB 2.980 5,820.8 5,602.0 12.83 SEAL ASSY SEAL ASSEMBLY"Stick-Up"(21.69'total length) 3.000 5,827.8 5,608.8 12.71 PBR 80/40 BAKER POLISH BORE RECEPTACLE 2.990 SAFETY VLV;2,022.2 AI 5,851.0 5,631.3 12.30 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 5.882.9 5,662.6 11.73 NIPPLE HES"X"NIPPLE 2.813 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT,26043 Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 5.985.0 5.762 7 11.23 WHIPSTOCK WHIPSTOCK AND 2 RA TAGS 9/7'2014 Perforations&Slots Shot Dens GAS LIFT;3,815.2 Top(ND) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn • 6,022.0 6,040.0 5,799.0 5,816.6 A-4,A-3,21- 10/13/1986 1.0 (PERF 90 Deg.Phasing;4" 09 HyperJet 6.040.0 6.058.0- 5.816.6 5,834.3 A-3,2T-09 10/13/1986 4.0 (PERF 90 Deg.Phasing;4" HyperJet GAS UFT 4.680.7 Cement Squeezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 44.0 1,784.0 44.0 1,783.1 CEMENT SQZ 7" 7/26/2014 PUMP 152 BBL of 15.7#CLASS G CEMENT x 10-3/4" PressureNet.TOC 44.3'RKB GAS LIFT;5,329.9 Mandrel Inserts St at( on Top(TVD) Valve Latch Port Size TRO Run L N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 2,604.3 2,592.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 GAS LIFT;5,7645ii_ ,: 2 3,815.3 3,730.4 CAMCO MMG 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 8/2/2014 3 4,680.7 4,532.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 4 5,329.9 5,131.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 5 5,764.5 5,547.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/31/2014 Notes:General&Safety LOCATOR;5,820.5 End Date Annotation 12/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 REAL ASSY;5.620.8 = 7/10/2014 NOTE:DRILLED OUT CEMENT SQZ @ 5,700'DURING 2014 WO PER;5,827.8 1 PACKER;5,851.0 NIPPLE;5,882.9 00 Enlarging(Tubi g);5926.1 ii SLOTS;5,939.8-8,047.1 I 1 LINER LI-01;5,915.7-8,047.5 ' 1 , WHIPSTOCK;5.985.0 \\\\]]] WINDOW;5.990.06,000.0 CMT PLUG;5700.0 (PERF;8,022.0.8,010.0I - IPERF;6,040.0.6,058.0- I PRODUCTION;1,795.36.351.1 `a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T-09 Oper.Rep: Ian Ives PTD No.: 1861100 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified, How? ter(specify in commei Onshore/Offshore: Onshore Suspension Date: 10/09/09 Date AOGCC Notified: 08/28/10 - Sundry No.: 309-337 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 2550 Photos Taken? Yes IA 150 OA 40 SCANNED AUG 1 4 2015 Condition of Wellhead: Wellhead location was verified with a plot plan. Wellhead looks to be in good wokinq condition with no signs of leaks. IA and OA were both blinded with gauges. Flowline was attached with 950 psi.Wellhouse was removed for on-going dirt work. The well has a wooden cellar box that was dry and free of any oil.- Condition of Surrounding Surface The surface location looked good,on-going dirt work in progress. Location: Follow Up Actions I ask CPA to find out why the wellhead pressure was so high. I received and email from CPA MJ Loveland on 8/30/10 telling me Needed: "2T-09-Current pressure 2550 psi completed 8-30-10(all methanol,bled to zero,clearly was thermal in nature)" Attachments: Photos(2) - REVIEWED BY: Insp.Supry „T( Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-09_bn.xlsx . 1 L P Ali* : A op Pik f c. _ , ______),,, , , i 0 ... ,-, ' ,,,ir 1 i /frit .t.), ,...i Ilk t a r Ny � k y ‘ 1r, x *Eli M ., o ji� .,,,, Nit *2 I r o - 440 p. oN f` Z. PO tr E-4 cD 0 r C) ° 0 r- 0 4 , i , Nw 0on � ( c-41 PLI Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. 11'.6- 1 ¿ {) Well History File Identifier Organization (done) ~o-Sided 1111111111111111111 RESCAN DIGITAL DATA 0 Color items: 0 Diskettes, No. 0 Grayscale items: 0 Other, No/Type )( Poor Quality Originals: j¡ ~ II ~ 1 * ~. Other: ~ <1. U~"""'<7 TOTAL PAGES: 11 f NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing 1111111111111111111 PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Scanned (done) 11III1I111111111111 PAGES:!7 ~ (at the time of scanning) SCANNED BY: BEVERLY BREN~HERYL MARIA LOWELL ReScanned (done) 1111111111111111111 RESCANNED BY: BEVERLY Bt- ) SHERYL MARIA LOWELL '"" General Notes or Comments about this file: PAGES: !( Rescan Needed 1111111111111111111 DATE: 1111111111111111111 DATE: DATE: DATE: OVERSIZED (Scannable) 0 Maps: 0 Other items scannable by large scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other Isl 0 Staff Proof By: Date: Isl 151 151 Quality Checked (done) 1111111111111111 ~I UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~ ~( l ~ (~ FILE # ~ ~~. To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission = 333 W. 7th Ave., Ste. 100 ; Anchorage, Alaska 99501 Voice (907) 279-1433 ~ Fax (907) 276-7542 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 19, 2010 Nov Sly Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission Z� 333 West 7 Avenue, Suite 100 lr,.►1 � Anchorage, AK 99501 Amhft Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -09 (PTD 186 -110) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2T- 09 (PTD 186 -110). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, / MJ L veland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA . ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [7, Repair well r Plug Perforations r Stimulate r Other r Suspended Well Alter Casing ull Tubing Inspection g � g � Perforate New Pool � Waiver r Time Extension Change Approved Program Operat. Shutdown Perforate Re -enter Suspended r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen Exploratory r—' \ 186 -110 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphi r Service r -% 50- 103 - 20071 -00 7. Property Designation: 8. Well Name and Number: ADL 25569 2T -09 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 6370 feet Plugs (measured) 5700 - Cement true vertical 6141 feet Junk (measured) NONE Effective Depth measured 6268 feet Packer (measured) 5888 true vertical 6040 feet (true vertucal) 5668 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110 110 SURFACE 1992 10.75 1992 1988 PRODUCTION 6351 7 6351 6122 Perforation depth: Measured depth: 6022'-6058'- cemented True Vertical Depth: 5799' -5834' -cemented \, f_ °> ?0 Tubing (size, grade, MD, and TVD) 2.875, J -55, 5936 MD, 5715 TVDt�a�, li]I�ii Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB -1 PACKER @ 5888 MD and 5668 TVD TRDP - CAMCO TRDP -IA -SSA @ 1806 MD and 1805 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Develo ent Service F 15. Well Status after work: .Saopoldfd ar Oil F Gas r WDSPL Daily Report of Well Operations X GSTOR F WAG F GASINJ r WINJ r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact MJ Loveland /Perry Klein Printed Name MJ Loveland /Perry Klein Title Well Integrity Project Supervisor Signature Ph :659 -7043 Date q RBDMS SEP 2 3 214�- Form 10 -404 Revised 7/2009 O T Z 7/D Submit Original Only 4e /0 /tv • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riv Unit 2T -09 Field /Pool: Kuaaruk River /Kuuaruk River Pool Permit # (PTD): 186 -110 Sundry 309 -337 API Number: 50103200710000 Operator: ConocoPhillips Date Suspended: 10/9/2009 Surface Location: Section: 227' FSL, 556 FWL, sec 1 Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: 4.CXA7 Pad or location surface: Location cleanup needed: Wo Pits condition: 11 Surrounding area condition: /gyp Water /fluids on pad: A10 Discoloration, Sheens on pad, pits or water: Samples taken: lye> Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: 7(„Q UR),X ATr C ellar description, condition, fluids: Rat Hole: Wellhouse or protective barriers: r V Well identification sign: j�- PAJ ow L i a iL; Tubing Pressure (or casing if no tubing): _ p sa 1E+5 Of) Annulus pressures: /eo/ ew Wellhead Photos taken (# and description): 7XE t o Work Required: e'PfAGpybo`rtG -TZ5 Dd l" Rnre 56CAjZc- es Pf2 � t tea/ 'TdtBd/i/ . Tuh 0 Operator Rep (name and signature): z mz--- AOGCC Inspector: Other Observers: .&& Nm—'- 1 Inspection Date: I / z AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: 1&W KU P 2T -09 ConocoPhillips Well Attributes 7Max Angle & MD 1TD AIA4^ Wellbore API /l1Wl Fleltl Name Well Status Incl ( °) MD (kKB) Act Btm (ftKB) 501032007100 KUPARUK RIVER UNIT INJ 25.70 3,600.00 6,370.0 Comment H2S (ppm) Date Annotation Entl Date KB-Grd (k) Rig Release Date ••• WeII Conk: 2T -09 10/10/20091:05:19 PM SSSV: TRDP Last WO: 40.69 7/5/1986 Scheme6c -AcWal Annotation Depth (ftKB) End Date Annotation Last Motl By End Data Last Tag: SLM 715.0 4/25/2009 Rev Reason: CEMENT PLUG Imosbor 10/10/2009 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (1b/[t) Grade String Top Third --- CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H40 SURFACE 103/4 9.794 0.0 1,992.0 1,988.4 45.50J55 PRODUCTION 7 6.151 0.0 6,351.0 6,122.0 26.00 J -55 CONDUCTOR, 110 Tubing Strings String OD String ID Set Depth Set Depth (TVD) String String Tobin Descriptlon lint Ilnl Top ftKB) (ftKB) (ftKB) (Ibs/tt) Grade String Top Third TUBING 27/8 2.441 0.0 5,936.0 5,714.7 6.50 J -55 EUE8rdA8MOD Other in Hole All Jewelry: Tybing Run & Retrievable, Fish, etc. Top Depth SAFETY VLV, (TVD) Top Incl 1,806 0 Top (k(B) (ftKB) P) Description Comment Run Dab ID (In) 1,806 1,805.3 10.49 SAFETY VLV Carnco TRDP- 1A-SSA 10/13/1986 2.312 5,826 5,607.0 12.74 GAS LIFT MMH/2 7/8 X 1.511.5/DMY /RK/ // Comment: WATER INJ. 911311996 2.347 PKG STA 1 5,871 5,651.0 11.94 PBR Brown PBR 10/13/1986 2.500 SURFACE, 5,888 5,667.6 11.64 PACKER Brown HB-1 PACKER 10/13/1986 2.441 1.992 5,926 5,704.91 11.44 NIPPLE Camco'D' Nipple NO GO 10/1311986 2.250 5,935 5,713.7 11.41 SOS Brawn 10113/1986 2.441 5,936 5,714.7 11.41 TTL 10/13/1986 2.441 Perforations & Slots Shot Top (TVD) St. (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh °• Type Comment 6,022 6,040 5,799.0 5,816.7 A4, A -3, 2T -09 10/13/1986 1.0 IPERF 90 Deg. Phasing; 4" HyperJet GAS LIFT, 6,040 6,058 5,816.7 5,834.3 A -3, 2T -09 10/13/1986 4.0 IPERF 90 Deg. Phasing; 4" HyperJet 5,826 Notes: General Safety _ End Data I Annotation 12/112001 NOTE: LOST SPANGS @ 5901 SLM 1211/2001 NOTE: REAL TIGHT TBG FROM 59W TO 3000' SLM. POSSIBLE CORKSCREW TBG. 7/21/2007 NOTE: ATTEMPTED TAG w /1.54" G/R - TAGGED @ 203' 41251'2009 NOTE: DRIFT w/1.75" SLINKY TOOL, TUBING DEFORMED PBR, 5,871 i PACKER, 5,888 NIPPLE, 5,926 SOS, 5,935 • TTL, 5,936 IPERF, 6,0228,040 IPERF, 6,0908,068 - CEMENT SOZ, 5,700 PRODUCTION, 6,351 TD, 6,370 + } + I I + + + E 16 +00 0 0 0 00 00 I0 o a N o � + N Z Z Z Z Z Z Z OS NORTH - - - DRILL S 2T I I I + E 14 +00 ACCU r I I I y r -xa¢ T -3t i� znn e o _ T 4 ' 13 10 6 16 Ia�a22 _ _ _ �RI _ _ _ •k.4 s . . • ^ .p�1 RA0IIR>nNi T !CQ l Nil; F $F $ t I + I I + + + E 10 +00 SCALE 700 0 50 100 LEGEND • O THERMOSIPHONS 1 "= 100' 0 WELLS FORM: BSIZE DRAWN: DESIGN: ECM NO: ✓ AREA: 2T MODULE0000( UNIT: D2 CHECKED: AJR APPROVAL CC N0: ConocoPhillips OUT PLAN — — Alaska, Inc. 1 130 10 Updated Thermosi hon and Well Asbult locations NRB JFC +JOBPIOJ SCALE. DATE: CARD FILENAME: JOB NO: SUB JOB NO: DRAWING NO: PART., REV: REV DATE REVISION BY CHK 1" = 100' 3113109 DS2T PLT PLN 3/13/09 NSDK 0000 DS2T PLOT PLAN 1 OF 1 1 r� ((i C� l u f S r i I w , iZ y. Y d " V 2T -09 PTD 186 -110 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska w x C�) C - � e r AA a m ° 01 1 MAL- Ab t E4� 6 J - ;, 2T -09 PTD 186 -110 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska STATE OF ALASKA - ~/.~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI~~L(~C~~a9 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended o 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1 ~I ~~ Q~$, ®Ci1111iS~1~ Development ~~~~~f~6loratory Service 0 Stf4r##atigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 9, 2009 12. Permit to Drill Number: 186-110 / 309-337 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 20, 1986 13. API Number: 50-103-20071-00 4a. Location of Welt (Governmental Section): Surface: 227' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 7. Date TD Reached: July 3, 1986 14. Well Name and Number: 2T-09 Top of Productive Horizon: 1244' FSL, 1355' FWL, Sec. 1, T11 N, R8E, UM 8. KB (ft above MSL): 41' RKB GL (ft above MSL): 82' AMSL 15. FieldlPool(s): Kuparuk River Field Total Depth: 1303' FSL, 1400' FWL, Sec. 1, T11 N, R8E, UM 9. Plug Back Depth (MD + TVD): 6268' MD 16040' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498945 y- 5970208 Zone- 4 10. Total Depth (MD + TVD): 6370' MD / 6140' TVD 16. Property Designation: ADL 25569 TPI: x- 499743 y- 5971224 ZOne- 4 Total Depth: x- 499788 - 5971283 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 1806' MD / 1805' TVD 17. Land Use Permit: 2667 18. Directional Survey: Yes ^ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDl1VD: approx. 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/Lateral Top Window MD/TVD not applicable Y3, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 255 sx CS II 10-3/4" 36# J-55 Surf. 1992' Surf. 1988' 12.25" 850 sx AS Ilf, 160 sx Class G 7" 26# J-55 Surf. 6351' Surf. 6122' 8.5" 54o sx Class G, 175 sx AS I Open to production or injection? Yes ^ No O If Yes, list each 24 25. TUBING RECORD . Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDl1VD) 2.875" 5936' 5888' MD / 5668' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 5700' 8 bbls 15.8 ppg Class G 47, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1550' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 5979' 5757' Base Kuparuk C 5986' 5763' Top Kuparuk A 6006' 5783' Base Kuparuk A 6146' 5920' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam ,, J. Ennis Title: Wells Enoineer ~~ ~ ,~ ` 0 ` 1 Signature Phone 265-1544 Date Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 7/2009 ~G~`t v ~~ ~ STATE OF ALASKA '`-'` OCT 2 S 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION9~aska0il&GasCons.Commissiun 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter spended Well ^ 2. Operator Name: 4. Well Class Before Work: Permit to Drill tuber: InC. ConocoPhillips Alaska Development ^ Exploratory ^ 1 ~10 / , 3. Address: Stratigraphic ^ Service ^/ .API Nu er: P. O. Box 100360, Anchora e, Alaska 99510 -103-20071-00 ,KB Elevation (ft): Well Name and Numbe . RKB 117' 2T-09 . Property Designation: .Field/Pool(s): ADL 25569 Kuparuk River Fi / paruk River Oil Pool 11. Present Well Condition Summary: ©~ Total Depth measured • ~ 6370' feet }}~~ ~ 6141' feet Itmb~(measured) 5700' true vertical OOOO00 k (measured) Effective Depth measured 6268' feet `l n true vertical 6040' feet Casing Length Size MD ~ TVD Burst Collapse tttTTT Structural CONDUCTOR 110' 16" 110' ~ 110' SURFACE 1875' 10-3/4" 1 ~ 1988' PRODUCTION 6234' 7" 35 6122' •°--°- ~ ~~ Perforation depth: Measured depth: 6022'-6058' ~ ~ ~~~~ ~U ~ ~ ~ 2009 true vertical depth: 5799'-583 \ th) 2 d d 5936' MD 55 d 8 J measure ep . , . - Tubing (size, grade, an Packers &SSSV (type & measured depth) Br B-1 pkr C~ 5aas' co TRDP-1A-SSA SSSV @ 1806' 12. Stimulation or cement squeeze um Intervals treated (measured) cement plug @ 5700' ~,-~ pump 8 bbls of 15.8 ppg Class G cement Treatment descriptions in udk(g ~8olumes used and final pressure: ~ Representative Daily Average Production or Injection Data 13. Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well op ation SI Subsequent operation SI 14. Attachmen .Well Class after work: Copies Logs and Surveys run _ Exploratory ^ Development ^ Service Dail eport of Well Operations _X .Well Status after work: Oil^ Gas^ WAG GINJ^ WINJ ^ WDSPL^ 17. ereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 309-337 ontact Jim Ennis @ 265-1544 Printed Name im is Title Wells Engineer ~ Date ~ (~ ~-$` Signature Phone: 265-1544 Pre ared b S ron AIlsu -Drake 263-4612 ~~~'d"1S ~\ ~o-z3-bf Form 10-404 Re d 04/2006 /~ Submit Original Only /io~~/~ 2T-09 Well Events Summary DATE - SUMMARY 10/9/09 PUMPED 8 BBLS OF 15.8# C G CEMENT TO SECURE WELL. ESTI~E TOC @ 5700' (TTL @ 5936'). DISPLACED CEMENT WITH 6" OD NERF WIPER, 5 BBLS OF FRESH WATER AND 28 BBLS OF DIESEL. TRAPPED 1650# OF WHP. WILL RETURN FOR MIT-T AT A LATER DATE. 10/12/09 Post cement plug MIT passed. Tested the tubing down to the TOC @~5700' (TTL = 5936') to 2500 psi. Ready for AOGCC witnessed test. 10/14/09 BLEED T DOWN TO 0 PSI, TUBING DD TEST - PASSED 10/16/09 BLEED IA / OA TO 0 PSI 10/17/09 BLEED IA & OA TO 0 PSI. Cona~oPhiilipS :,:,,K_~; ~,~:. r Top Dapth ~~ I (T~D) Top lnel ~ Top (HKB) („KB) (°) Description Commant Run Date ~ ID (in) 1,806 1,805.3 10.49 SAFETY VLV Camco TRDP-IASSA 10/73/1986 '~ 2.312 5,826 5,607.0 12J4 GAS LIFT ~ MMH/2 7/8 X 1.5/t5/DMY/RK/I/ Comment: WATER INJ. 9/1 311 9 9 6 ~ ~ 2.347 PKG STA 1 5,871 5,651.0 11.94~PBR - 46rownPBR ~ ~ 70/13f1986 ~ 2500 ~ 5.888 5.667.6 11.64 ;PACKER - Brown h18-1 PACKER .. -.. . - . - 10/13/1986 2.441 .-__ __. 5,926 . 5,704.9 11.44 NIPPLE .____ Camco'D' Nipple NO GO .____.-. 10/13/1986 2250 ...__- 5,935 ._ 5,713J. 11.47ISOS ...._._., Brown '-_-. 10/13/1986 2.441 5.936 ___.._ 5.774J~ _.. ~. 11.47~~iiL ., . ._. ... __ ...__ .... .. .. -- 10/13/1986 ~ _.._.. . _.: 2441~ Perfora --- tions & Slots - -- - _ .._. _. - _. . snoc ' Top (TVD) Btm (TVD) ~ Dens Top (ftK8) 84n (kKB) (flKB) (ftK6) Zone Data (sh~~~ Type Commerit , 6p22 6,040 5 799A 5,816J A-0, A-3, 2T-09 10/13/1986 1.0 IPERF 90 Deg. Phasing; 4" HyperJet 6.640 ~ fA58 5,816J 5,8343. A-3,2T-09 ~10l13/7986~, 4.O, IPERF 90Deg.Phasirg;4"HyperJet Notes: General 8 Safet E tl Date I Annotation 12/12001 NOTE~ LOST SPANGS a~ 5901 SLM I 12/12001 N R L TIGHT TBG FROM 5900' TO 3000' SLM. POSSIBLE CORKSCREW TBG. I7/21/2007 !NOTE~ ATTEMPTED TAG wlt54" G/R - TAGGED @ 203' I425/2009 _. _- . INOTE: DRIFT w/1 JS" SLINKY TOOL, TUBING DEFORMED .._ -.. _ _ _. `,~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~ ~. ~ZI ~a ~~ P. I. Supervisor X11 FROM: Lou Grimaldi Petroleum Inspector DATE: November 05, 2009 SUBJECT: Wellbore Plug ConocoPhillips Alaska Inc. KRU 2T-09 ~ Kuparuk River Field/Unit PTD #186-110 ~- Tuesday, November 03, 2009; I witnessed the pressure test of a wellbore plug placed to isolate the wellbore from formation on ConocoPhillips Kuparuk River Unit well # 2T-09. The plug had reportedly been down squeezed from surface prior to my arrival. The tubing was pressured up with diesel to 2600 psi. The following pressures were observed during the test; Pretest Initial 15 min. 30 min. IA 92 92 92 92 OA 20 20 20 20 Tubing 0 2600 2500 ~ 2480 The test pressure was bled to zero at the conclusion of this test with approximately the same amount returned as was pumped (.85 Bbl's). The plug has apparent :~ integrity although the negative test should help to confirm this. Ian Ives (KRU DHD) was very helpful with information and background on this well. Ian has a good attitude and seems intent on understanding the differences of our requirements between types of test's, why they are performed and the importance of .. -~.r...~..., . reliable results. Attachments: None ~ Non-Confidential ~ ~~~' ~ ~ 2009 Wellbore Plug KRU 2T-09 11-03-09 LG.doc 1 of 1 • • `~~ ~~ ~ ~~ '~' c F ~ ~ , ~ ~ r 9 E l t 2 ~k ~. ~ ~ ~s rh~p ~ r ~ ~ ~~ ~~ ~~ ~ ., , 4 ,~ ~ "r; t II 6 ~ K ~x ~:~ f`~~ ~ ~" ¢~~ ~ L ~ ~~~~ ~ ~ ~ ~i ~" SEANPARNELL, GOVERNOR : ~ v ~~=.; ' ~. ~ ~ t ~ ~ ~ ~- i y ,~ $ ~ s -7~~ OIL ~ t]rn--7 ~ ~N 333 W. 7th AVENUE, SUITE 100 rm C~~S"~i RQAi10~ COr~IIS'~7'I~~ a'' ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ~ ~ ~ Anchorage, AK 99510 :; ~~ ~ ~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-09 Sundry Number: 309-337 ~~~~~~~~ ~~'~'•'' ~ "~~ 20G~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, y`~ Cath P. Foerster Commissioner DATED this ~~ of September, 2009 Encl. • STATE OF ALASKA _~~~ • - , ~~3'0~ ALASKA OIL AND GAS CONSERVATION COMMISSION ;~ i ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ` 1. Type Of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~- ' Other ~ Altercasing ^ Repairwell ^ Plug Perforations Q' Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhilli s Alaska, InC. Development ^ F~cp~oratory ^ 186-110 ' 3. Address: Stratigraphic ~ Service ~, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-2Q071-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ 2T-09 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25569 ' RKB 117' Kuparuk River Field / Kuparuk River Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6370' ' 6141' • 6268' 6040' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" ~ ~0' 110' SURFACE 1875' 10-3/4" 1992' 1988' PRODUCTION 6234' 7" 6351' 6122' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6022'-6058' 5799'-5834' 2.875~~ J-55 5936' Packers and SSSV Type: Packers and SSSV MD (ft) Brown HB-1 pkr @ 5888' Camco TRDP-1A-SSA SSSV @ 1806' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exptoratory ~ Development ^ Service ~' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat September 28, 2009 Oil ^ Gas ^ Plugged ~~ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. 1 hereby certify that th regoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Name Ennis Title: Wells Engineer Signature ' Phone 265-1544 Date 9 ~ Commission Use Onl Conditions of approi I: Notify Commission so that a representative may witness Sundry Number: Q y- Plug Integrity (~ BOP Test ~ Mechanical Integrity Test ~ ~~, Location Ciearance ^ Other: ~ 1 1 /'eSscc,r~ .2s'~'~ COw~~~ ~h$~GGTO/' -~O GJ~•ThCS's' ~ Subsequent Form Required: L~~~ ~k ~~:R~~~~ ~~~, `~~~ ~' ~ t' t.Q~~ 1 (/ APPROVED BY Q ~ O~ - 7 s Approved by: OMMISSIONER THE COMMISSION Date: / ~ i Form 10-403 Rev~ ed 06/2006 / Submit in Duplicate ~I.~L ~ ~~.Z(-~~ /~ zy.p~ • Well 2T-09 Kuparuk Injector • Pump cement plug for well control barrier Network 10258890 Well History: 2T-09 was originally completed as a single Kuparuk `A' sand water injector in 1986. In September 1995, the well's service was changed to a WAG injector and it injected gas through August 2008. While on water injection, it failed an MITOA in March 2009. Subsequent diagnostics indicate corkscrewed tubing will not allow access beyond 715' SLM. The corkscrewed tubing is believed to be the result of well ~ subsidence. The procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover to ~ restore injection or P&A can occur. TOC for the plug is targeted for 5800' MD. Work accomplished to date: 6/4/09 4 Year State Witnessed (Chuck Scheve) MIT-IA (passed), T/I/0= 1900/940/110. Pressured up IA with 2.4 bbls diesel. T/I/0= 1900/2620/120. 15 min T/I/0= 1900/2560/120. 30 min T/I/0= 1900/2560/120. Bled IA, final T/I/0= 1900/640/120. 6/1/09 2T-09--4 Year State Witnessed MITIA - Failed, (AOGCC - Jeff Jones). Initial T/I/0=(si) 1900/820/100. Attempted to pressure up IA, pumped 10 bbls with little gain in psi. state man failed test. Final T/I/0=(si) 1900/1400/100. 5/30/09 RAN GYRO SURVEY WITH GYRODATA 4-AXIS TOOL. RESULTS: TAGGED AT 54' RKB ON 2 DESCENTS. DESCENT 1 WITH CENTRALIZED GYRO AND DESCENT 2 WITH SLICK GYRO. DATA RECORDED FROM 54' BACK INTO TREE. 5/20/09 MITIA - passed; Initial T/I/0= 1960/960/120; Initial IA FL @ 180ft. Rigged up LRS to IA and pressured up to 2500psi. with 6.8bbls. of diesel. Start T/I/0= 1960/2500/120; 15min. reading T/I/0= 1960/2490/120; 30min. reading T/I/0= 1960/2490/120; Bled IA to 730psi. 90min. fluid; Final T/I/0= 1980/730/120 4/25/09 RAN 1-1/4" SLINKY TOOL STRING. DRIFTED TBG WITH 1-3/4" SAMPLE BAILER TO 715' SLM, LOST SPANG ACTION. APPARENT CORKSCREWED OR DEFORMED TBG. COMPLETE. 4/1/09 T-POT (PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED) 3/31/09 (WP) MIT-IA ( PASSED ), IC-POT ( FAILED ) 3/28/09 SCLD; Initial T/I/0= 2425/1600/120; Rigged up bleed hose to OA and began charging with lift gas; shot OA FL @ 300ft. (600fps) Waited 15min. shot second FL @ same location; Waited 30min. shot third FL @ same location Final T/1/0= 2425/1600/180 3/27/09 MITOA 2T-09 - FAILED. Initial T/I/O = 2400/1600/30. Established LLR @ 2 bpm @ 600 psi using 16 bbl diesel. Final T/I/O = 2400/1600/30. Remaining work: 1. RU SLB cementer. Bullhead 50 bbls fresh water down tbg at max rate below 2500 psi followed by 40 sx Class `G' cement w/ additives. Launch "nerf" cmt plug and displace w/ 5 bbls fresh water, 16.5 bbls 9.6 ppg brine and 12 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg & IA pressure to zero. Jim Ennis Page 1 9/17/2009 Cartt~coPhillips , ` r'1~i _~ ~ ... ~ellGOfg ~10'I,Ar6IlG(I»-.;fi,~"'•A __ _ . . Srl i.iliC ~ A' '.I CqNDUCTOR, 1~0 snFETV v~v. i.sos SURFACc, 1.992 GAS LIFf. S,E26 aeR, s,e~i NIPPLE, 5.926 SOS. 5,935 TTL,5.936- -... -..-- IPERF,_ 6,022-6,060 IPERF, _ _ 6,060-6,056 PRODUCTION. Q35~ \ TD.6,3]0 KUP • 2T-09 Vell Attribut IellboreAPVUWI es Fieltl Name Max Angle & MD I T~ Well Sta~us Prod/Inj Type Incl (°) MD (ftKB) 'ACt Btm (flKB) 507032007100 IKUPAHUKRIVERUNIT IINJ I 25J0 I 3,600.00 I 6,3/0.0 ment H2S(ppm) I I?iSReleaseData KB-Grd(ft) Mnotation EntlDate Dzte SSV~ TRDP I ~~ I l I I Last WO: 40.69 7/5/1986 nnotation I Depth(ftK8 IEntlDate ~ Annotstion E l~ate ast Tag~ SLM I I 4I25/2009 IRev Reason~ ~fAG w/1J5' Sample Bailer, TBG Deformed I __ a12612009 715.0 _asing Strin s _ ~ String OD String ID Sa~ Depth Set Depih (ND) ! String SWt 4ing CasingDescripti on (~n) (in) Top(ftKB) (NKB) (flK8) ' (IbslR) ~ Grzde StringTopThrd ~ ~.ONDUCTOR 16 15.062 0.0 110.0 110.0 6250''.H-00 URFACE ' 103/4 9J94 0.0 1992.0 1,988.4I 45_S0~ SS RODUCi ION "ubing Strin ~ 7 6.151 . _. .. gs 0.0 . . _ .__- 6,351.0 6.122.01 26.OOIJ-55 __-_ . . .. I _ _.__ 1_ __ ... . _...__ 5,826 5,607.0 72J4 GAS LIFT MMHl27/8 X 1.5lt5/DMY/RK/// Comment: WATER INJ. 9~7:111yg6 Z.;59/I PKG STA 7 5,871 5,651.0 77.94 PBR BrownPBR i(1~13;1986 2500Ii 5,888 5,667.fi 11.64 PACKER BrawnHB-iPACKER lp.~l;,'1986 2.441~, 5.926 5704.9 11.44 NIPPLE Camr,o'D'NippleNOGO .....~._.-.... ..---~-~ -~ iD;13;7986 ~2250''. . 5.935 SJ13J' 11A1~ ..~___ SOS IBrown '-__ _- _. 10!13,'1986 _ - 2.447 5.5.',6 5.714J 11.41 __.__ ._ iTl i _'_-_ _- 10;13;1986 __- 2.441 'erforat _ io~s & Slots ------ _ Shot ~ I __._. . _-- .. ~ -..... - _ ToP(TV I Dens , D) Btm(TVD) fop(ftKB) Bhn (kKB) (ttK8) (ftKB) 7qne Date (sh... ~`Type Comment GA22 6.040 S, i99.0 5,816] A-4, A3, 2T-09 10/13/1986 1.0 IPERF 90 Deg. Phasing; 4" HyperJet 6.040. 6,OS8 ~ 5,876J 5,834.3 A-3, 2T-09 10/1311986 4.0 IPERF 90 Deg. Phasing; 4" HyperJet Votes: G eneral & Safety __ End Date ' _ ~ _ ~ Annotation 12l1/2001 NO I~E~ LOST SPANGS ~nl 5501 SLM 121V2001 -. ____ ._ _..__ ~~NOTE REAL 11GHT TBG FROM 5900' TO 3000' SLM. POSSIBLE CORKSCREW TBG. 421/2007 INOTE~ ATTEMPTED TAG w/1.54" G!R - TAGGED @ 203' 1252009 , NOTE: DR~FT w/1 J5" SLINKY l OOL, TUBING DEFORMED . _____......._ ~ ~ age r T ks in adva `~~ om Maunder, PE ~ AOGCC I ~~ ~ t~~ r~~ D i~ l ; ~..c~,~ 1 '~~ ~ c~ ~..vc~ ~ e-+c~ G:~1~S~~ O~ SC~V ec~~ vJ F t~ Zs S~ ~~ ~ ~ d' ~ ~„ ~- ~'c'fJJ`~~~ . ~ ~,r~~r~ -S'c~ c-(c ~bS~ cl~l~~c P ~ ~S SJ ~5 -~ ~c~.~ ~~ c~S~ c~-t S~J ~c~c~.. ~ WQ ~ ~.~. 4~s ~o ~.c~. ~ c~.~ ~~~ ~ «.~--~~~.~- ~-~- `f S ~ p~.~...~~..~~\ y~, ~Q, ~~~o~~.~~ ~-•. ~' ~ .~ ~ S~~ ~x.~ ~ ~~-~ ~~ ~ ~~.~.~~. ~ ~~ S 1lJ~~~ ~J~S~I `l ~j vS ~f~ ~~ ~~ ~ ~ a ~ ~Y'~_ ~-~-~'~--~ CG-..5~ ,~, ~ d ~ ~ L~.~~IC ~C ~~~ p~ '~'' C~~\ _ ` ~ C-~ ~cj~'~ ~ ~ ~~1~1 t~x- ~ \ ~ S ~. ~~S..JL A ~ ~ ~ y ` l ` ~.3 ~ ~ h ~' `J~-~ ~ ~ ~C~' ~' ~Ct` ~ ~ Y~~l''~ ~ ~ ~~ ~ ~ ~ ~ ~..1~, ~~. ~ ~ c~ w~~ ~--.. ~~ c-Qo Sc~ ~ . .~ ~ ~ ~~~~ r 5 ~~~ 9/200 ~ MEMORANDUM To: Jim Regg ~~~ 7~z~~~ P.L Supervisor FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-09 KUPARUK RIV UNI'I' 2T-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv y]'~~ Comm Well Name: KUPARUK RN iJNIT 2T-09 Insp Num: mitCS09o6o5070201 Rel Insp Num: API Well Number: 50-103-20071-00-00 Permit Number: 186-110-0 . Inspector Name: Chuck Scheve Inspection Date: 6/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 2T-09 Type Inj. I W '1'VD 5667 / jA 940 2620 2560 2560 ' - p~ is6iioo TypeTestISPT Testpsi i isoo ~ pA iio izo _i2o izo Interval a~rsT p~-, r ~ Tubing i9oo i9oo i9oo ~900 NOtes: Pretest pressures observed and found stable. ,,;~,fg, ~ a r ~r~ ~; ~s ~i}~'Et <, .,, . . a ,.. ,_ r ~ „ . ~ . Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM To: Jim Regg j~@~ 6IGb~~ P.I. Supervisor I ~ FRObtc Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-09 KUPARUK RIV UNIT 2T-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ' t Comm Well Name: KUPARUK RIV UNIT 2T-09 API Well Number: 50-103-20071-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608121024 Permit Number: 186-110-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2T'09 Type Inj N7 TVD s66s~IA ago Isoo P.T.D Ia6I loo TypeTest ~ sPT Test psi isoo 'I OA loo -~_~-- Interval anzTST p~ 1: ~ Tubing I9oo - -- ~ ~ Notes: Pumped 10 BBLS diesel; IA did not pressure up. ,~ Wednesday, June 10, 2009 Page 1 of 1 RE: KRU DS2T Suspected Surfac: asing Leaks Page 1 of 3 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, April 20, 2009 2:48 PM ~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: KRU DS2T Suspected Surface Casing Leaks ~ t ZT- Og- ~ ~ ~ 1~3 Follow Up Flag : Follow up . ~ t ~' _ ~ I ° Flag Status: Green ~~ 2T_ ' ' ~`~ D`1~ Attachments: 2T-11.pdf K(~C,t zr - ~ Q (' ~ k(zC,l ZT - l ( ~ ~'~(~ - d 9'7 Jim, ~ ~ _ DLL KR-t,(. Zi - /lam ~ On 4/19/09 CPAI shut in wells 2T-04, 2T-09, and 2T-15. Additional diagnostics indicate tubing obstructions exist in these wells preventing mechanical secure. On 4/18/09 CPAI shut in well 2T-11. The path forward for 2T-11 will to harvest a SBHP then attempt to secure with a plug in the AVA sleeve at 5801' md. All of the above wells will remain shut in until they can be repaired. We will not be submitting a request for Administrative Approval to continue, water only injection for these wells. These wells will be shut in long term. Do they need to be carried on the monthly failed injector report? 2T-10 remains online in water only service. We completed a drift, tag, and caliper of the tubing and intend to pursue and AA for continued water injection. 2T-16 remains online in water only service and is scheduled for a drift and tag with subsequent caliper to follow. If our plans change with regard to 2T-16 I'll inform you immediately. Let me know if you have any questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 ,. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 03, 2009 3:47 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly 2/23/2010 RE: KRU DS2T Suspected Surface Casing Leaks Page 2 of 3 A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.rnm] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, ] J Subject: KRU D52T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. 2/23/2010 RE: KRU DS2T Suspected Surface Casing Leaks Page 3 of 3 • Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf» « File: 2T-04 TIO Plot.pdf» « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf» « File: 2T-11 TIO Plot.pdf» « File: 2T-15 TIO Plot.pdf» « File: 2T-16 TIO Plot .pdf» « File: 2T-02 Wellbore Schematic.pdf» « File: 2T-04 Wellbore Schematic.pdf » « File: 2T-09 Wellbore Schematic.pdf» « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf» « File: 2T-16 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 2/23/2010 KRU 2T-11 Canoe~Phltips A~a$ka, tnc. RE: KRU DS2T Suspected Sure Casing Leaks • Page 1 of 2 Regg, James B (DOA) ~(~tt zT= ~ From: Regg, James B (DOA) ~, ~ ! ~5~° ! 1~ Sent: Friday, April 03, 2009 3:47 PM ~~ ~ (~~0~ To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPA! may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~~. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of M IA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Surf Casing Leaks • Page 2 of 2 the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf » « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf » « File: 2T-15 TIO Plot.pdf » « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « Fife: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell. 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Well Name 2T-09 Notes: End Date 4;1!2009 Days 90 Start Date 1;1!2009 wHP Annular Communicaton Surveillance IAP 3000 120 - - ------- - OAP -~..------ ------- - --- WHT 2500 - - 100 2000 -- - -- - - - 80 1500 60 d o. ---- -- - - -- .a 1000 40 500 -- 20 - ----- 0 0 Jan-09 Feb-09 Mar-09 Apr-09 2000 ~DGI 1800 ~MGI 1600 ~PWI 0 1400 SWI - ~ 1200 - ~BLPD m 1000 __ 0 ~ 800 ~ 600 400 ?00 0 • I ConocoPhillips Alaska, Inc. sssv (,606-,807. OD:2.875) TUBING (0-5936, OD:2.875, ID:2.441) Gas Lift 3ndrel/Dummy valve 1 (5826-5827. OD:5.500) PBR (5871-5872, OD:2.875) PROD. CASING (0-6351, OD:7.000, W t26.00) PKR (5888-5889, OD:6.151) NIP (5926-5927. OD:2.875) SOS (5935-5936. OD:2.875) TTL (5936-5937, OD:2.875) Perf (6022.6040) Perf (6040-6058) KRU 2T-09 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg n bl t P.I. supervisor')<.,é'1~ 7 D 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-09 KUPARUK RIV UNIT 2T-09 \Q' \\ 0 \CB FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-09 API Well Number: 50-103-20071-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 143339 Permit Number: 186-1I0-0 Inspection Date: 6/2/2007 ./ ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-09 Type Inj. w TVD 5668 IA 1790 I 2540 2530 2530 P.T.D 1861100 TypeTest SPT Test psi 1500 OA 150 I 150 150 150 Interval 4YRTST P/F P / Tubing 2150 i 2150 2150 2150 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity/ sCANNED JUN' Z () 2007 Wednesday, June 06, 2007 Page I of 1 MEMORANDUM TO: .~ 1.-t'1( tli'1fa\ ] im Regg P.I. Supen'isor FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT H-09 Insp Num: mllCS040619192459 Rellnsp Num: Packer G I TVD SPT I Test psi p Well ~T-09 Type Inj. P.T. 1861100 1!~'peTest Inten'al -1YRTST PIF Alaska Oil and Gas Consen'ation Commission State of Alaska DATE: Wedne~day. June 23. 2004 SlIBJECT: Mechanicallmegmy Tests CONOCOPHILUPS .o\lASK..o\ rNC ~T -09 I\.UPARUK RIV UNIT 21-09 Src: InspectOr Reviewed 8,.: -~ --r '"'? 11' Pol. Supno vÞ"""- Comm NON-CONFIDENTIAL API Well Number: 50-103-20071-00-00 Permit Number: 186-110-0 Inspector Name: Chuck Scheve Inspection Date: 6/19/2004 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Depth 61-10 IA OA Tubing 1150 2330 2300 1-117 2310 100 100 100 100 Notes: Pretest pressures observed for 30+ minutes and found stable. \\iell demonstrated good mechanical integrity. 3650 3650 3650 Wednesday. June 23. 2004 3650 Page I of I MICROFILMED 9/11/00 DO NOT PLACE · ANY NEW MATERIAL UNiDER THIS PAGE STATE OF ALASKA ALAU,,A OIL AND GAS CONSERVATION COMMISb,,.,N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Alter casing __ Repair well __ Plugging __ Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown__ Re-enter suspended well__ Time extensi°n Stimulate Pull tubing __ Variance X Perforate __ Other __ 6. Datum elevation (DF or KB) 5. Type of Well: Development __ Exploratory Stratigraphic __ Service X 4. Location of well at surface 227' FSL, 556' FWL, SEC 1, T11N, RSE, UM At top of productive interval 1244' FSL, 1355' FWL, SEC 1, T11N, RSE, UM At effective depth 1284' FNL, 1373' FWL, SEC 1, T~IN, RSE, UM At total depth 1303' FSL, 1400' FWL, SEC 1, T11N, RSE, UM RKB 117 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-09 9. Permit number 86-110 10. APl number 50-103-20071 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth' measured true vertical 6370' feet Plugs (measured) 61 40' feet 6268' feet Junk (measured) 6043' feet Casing Length Size Structural 1 1 0' 1 6" Conductor Surface 1 922' 9 5/8" Intermediate Cemented 255 SX CS II 85O SX AS III & 160 SX CLASSG ORIG'INAL Measured depth True vertical depth 110' 110' 1922' 1989' Production 6 3 5 1 ' 7" Perforation depth: measured 6022 '-6040', true vertical 5799'-5816', Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 @ 5936' Packers-and SSSV (type and measured depth) PKR: BROWN HB-1 @ 5888', SSSV: Camco TRDP-1A-SSA @ 1806' 540 SX CLASS G 6040'-6058' 5816'-5834' 6351' SEP ,5 0 1996 Anchorage 13. Attachments Description summary of proposal X Detailed operation program n BOP sketch VARIANCE TO CONTINUE INJECTION. 14. Estimated date for commencing operation 15. Status of well classification as: Oil __ Gas Suspended 16. If proposal was verbally approved To be reclassified as: Name cCCap~rover Date approved Service WATER INJECTION 17. I hereCy c/rtify that the~,~cis true and correct to the best of my knowledge. Signed /~~/I / ¢~"'~/~ -~-'-"~"/~f(' ~ FoRTitleCoMMISSIoNWeIISusE ONLySUperintendent Date Conditi,C's of approval: Notify Commission so representative may witness ' / Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form req'u'ire 10- ~C~"~ David W. J0hrlSt0i3 Commissioner Approved by order of the Commission Form 10-403 Rev 06/15/88 IApproval N~ , Date l~ _~ ...c:~ 6~ I SUBMIT IN TRIPLICATE Approved Copy Returned Application for Sundry Approval for 2T-09 Suspected Tubing by Production Casing Communication By way of this Sundry Application, a variance is requested to continue injection into Kuparuk Well 2T-09 with suspected tubing to production casing communication In July, 1996, increasing production casing pressures suggested that there was communication between the tubing and the casing. Diagnostics with slickline and pressure testing, performed on 7/20/96, indicated that the leak was small enough that detection with conventional electic-line logging was not practical. Pressure testing in conjunction with this wireline work indicated the production casing has integrity. See attached ARCO Well Service Report, dated 7/20/96. Subsequent to the wireline and pressure diagnostics, a mechanical integrity test was performed and witnessed by a representative of the AOGCC on July 21, 1996. The MIT indicated the production casing has pressure integrity. See attached AOGCC MIT form. ARCO Alaska, Inc. requests a variance to continue injection into this well with suspected tubing to production casing communication. RECEIVED SEP 3 0 1996 Alaska Oil A Gas Cons. Commission) Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Arco Alaska Inc. FIELD I UNIT I PAD: Kuparuk Rv. / KRU / 2 T DATE: 7/21/96 5,667 1,000 !,350,, 1~8, 5,0, , 1,15o, .1,250 1,850 1~825, 5:30 PM COMMENTS: This test was conducted at the re( ,uest of Arco rep. Jeff Rugen to document the existence of a tubing to annulus leak. The results of this test indicate thatthe, annulusandDackerhaveinte ... with communicationthrou~hthe3 1/2"tubingtothe 7"aqnulus. . . COMMENTS: COMMENTS: COMMENTS: I'l COMMENTS: Ill ,I., ,I *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I= INJECTION N = NOT INJECTING ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. 6.8 Grad. 0.35 0.00 0.00 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other X Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c -Inspector AOGCC REP SIGNATURE OPERATOR REP SIGNATURE JB9HGUDD.XLS ARCO Alaska, Inc. KUPARUK RIVER UNIT .k. WELL SERVICE REPORT ~' K1(2T-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-09 TUBING LEAK: DIAGNOSE, PATCH 0708960706.2 DATE DAILY WORK UNIT NUMBER 07/20/96 LEAK DETECTION 70356 ,, DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR I C) Yes ~ NoI ® Yes C) No HES-SCHNEIDER FITZPATRICK FIELD AFC,~ CC~ DALLY COST ACCUM COST S~gn ESTIMATE KAWWRK 230DS28TL $5,219 $5,219 Initial Tb.(:i Press Final Tb.(:l Press Initial Inner Ann Final Inner Ann, Initial Outer A~/I Ek~l Outer Ann 2900 PSI 1200 PSI 3000 PSI 1200 PSII 0'PSII 0 PSI DALLY SUMMARY SET 2.25" MXN PLUG @ 5926' RKB. SET 1-1/2" DV (INJ. PKG) @ 5826' RK.I=j. PRESSURE TESTED TBG & CSG; CONFIRMED I TBG/CSG COMMUNICATION BELOW SSSV. JOB SUSPENDED. TIME 07:00 07:50 09:35 10:00 11:10 12:00 13:30 15:00 15:55 16:00 16:03 16:10 16:25 16:35 16:45 17:00 17:30 17:35 18:25 18:30 18:45 LOG ENTRY TGSM:MIRU APC & HES.STD TS.LEAKING SWAB STANDBY FOR GREASE CREW. GREASE CREW SERVICED ALL GATE VALVES. PT EQUIP. DISPLACE TBG W/40 BBLS DIESEL. RIH W/2 1/2" GS & 2.25" CAT SV (EXT F/N) TO 59i2' WLM, (5926' RKB) SET CAT POOH. RIH W/2 1/2" OM-1 & 1 5/8" JDC TO 5818' WL, (5826' RKB) LATCH VALVE POOH W/1 1/2" DV NO SIGNIFICANT SIGNS AS TO CAUSE OF LEAK. RIH W/2 1/2" OM-1 & 1 1/2" DV ON ARK LATCH TO 5818' WLM,POOH VALVE SET. PRESSURE TEST TBG TO 3000~ LOST 350# IN 15 MIN.NO TEST. RIH W/2 1/2" GS TO 5912' WLM,LATCH CAT POOH.W/CAT. RIH W/2 1/2" RXN & 2.25" MXN PLUG 0N/EQ SUB)TO 5912' WLM (5926' RKB) SET POOH (THIS PLUG TAKES STANDARD 2.5" GS & 2.25" CRX PRONG TO EQUALIZE) PT TBG TO 3500#- 7" CSG 1725# TBG 3000#- 7" CSG 1775# BLED TBG TO 1000#- 7" CSG @ 1775# TBG 1400#- 7" CSG @ 1800# BLED 7"' CSG TO 1100~ TBG TRACKED DOWN TO 1175# 7" CSG 1175#- TBG 11254t 7" CSG 1225#- TBG 1100# 7" CSG 1200~- TBG 1100~ 7" CSG 1200#- TBG 1100~ DUMPED SSSV & BLED TBG DOWN TO 200#- 7" CSG STAYED @ 1200~ TBG PSI 200#- 7" CSG 120Off RE-OPEN SSSV RDFN- *PLUG LEFT IN 'D' NIPPLE* SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $176.00 $176.00 APC $1,950.00 '$1,950.00 HALLIBURTON $3,093.00 $3,093.00 TOTAL FIELD ESTIMATE $5,219.00 $5,219.00 I ARCO ALASKA, INC. DEV. & EXT GEOSCIENCE TI~,N SM I TTAL TO: LARRY GRANT - AOGCC FROM: ADDRESS: 3OO1 PORCUPINE DR. DATE: ANCHORAGE, AK 99501 DOUG HASTINGS - AAI APRIL 3.0, 1991 Transmitted herewith are the following: ONE COPY ARCO- KRU 2T-9 (W.Sak) OCTOBER, 1986 CORE ANALYSIS DATA (West Sak Formation) FiLE //70025 ACKNOWLEDGMENT:/~-7-. ///~~ ~// ~/x~/~/ :'.>" - ,. / -. 1-/~.-~, RETURN RECEIPlr~O:. ARCO ALAS/I([A, INC'.~ DEV & EXT GEOSCIENCE ATTN: LUCILLE ,JOHNSTON P.O. eox ~oo36o ANCHORAGE, ALASKA 9~$]0 DATE: Processed By: L. Johnston · DEPT. OF NATUR~L RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER J. HICKEL, GOVERNOR P.O. BOX 1o7034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in TI iN R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, (J~.mes E. Eason "Director cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska 0il .& Gas Cons. Commission ~nchorage 9.~ ~;r,r,~eo ~,~r'~ u;c','z:ed paper Z / G.~. STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown m Stimulate m Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development '"X- Exploratory _ Stratigraphic Service Location of well at surface 227' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1244' FSL, 1355' FWL, Sec. 1, T11N, R8E, UM At effective depth 1288' FSL, 1388' FWL, Sec. 1, T11N, R8E, UM At total depth 1303' FSL, 1400' FWL, Sec. 1, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6370' 6140' 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-09 9. Permit number/approval number 86-110 / 7-132 10. APl number 50-103-20071 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet Cement: 6268'-6370' Effective depth: measured 6268' true vertical 6040' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 1957' 10 3/4" 6321' 7" measured 6022'-6040' 6O40'-6O58' true vertical 5799'-5818', Cemented Measured depth True vertical depth 255 Sx CS II 110' 1 10' 850 Sx AS III & 1992' 1988' 160 Sx Class G 540 Sx Class G & 6351' 6122' 175 Sx AS I 1/2 SPF, 90 degree phasing 4 SPF, 90 degree phasing 5818'-5834' Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 5936' Packers and SSSV (type and measured depth) HB-1 Pkr @ 5888', Camco TRDP-1A-SSA @ 1806' 13. Stimulation or cement squeeze summary Convert well from A & C Sand production service to A & C Sand injection service ,~. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1662 2915 0 - 800 317 Subsequent to operation -0- 0- 5500 1250 2030 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned Form 10-404 Rev 09/12/90 Date I - <:::/---~ I SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date: July 28, 1989 Transmittal #: 7523 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 T- 0 9 Post Frac Job Report 1 0 - 1 1 - 8 9 3 B - 04 .... Kupai'uk F!uid Level Report 7- 21 - 8.9 3 J' 0 2' Kuparuk , :id Level' RepOrt ,-" 7_ 1 9- 8 9 3 H - 1 8 Kuparuk Fluid Level Report 7 - 2 5 ~ 8 9 3 H- 1 1 Kuparuk Fluid Level Report 7 - 2 4 - 8 9 '409747 .asing Casing Casing Casing Receipt Acknowledged. DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M ARCO Alaska, Inc. Post Office 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL . hand-carried SHIPPED TO: , State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE- 5 - 12- 8 8 OPERATOR: ARCO NAHE' see below S:%x-IPLE TYPE' core chips, plug ends NU%fBER OF BOXES' 63 S~\IP LES SENT: Lisb L5-21:11 boxes 12088/89 - 12133/34 12123 - 12144 12145/46 - 12149/50 12151/52 - 12198/99 12151/52 - 12198/99 12200/01 - 12223/24 12230/31 - 12288/89 12290/91 - 12371/72 12373/74 - 12390/91 12396/97 - 12406/07 12422/23 - 12425/26 12435/36 - 12445/46 12449/50 - 12463/64 12467f68 - 12471/72 12473/74 -- 12581/81.5 12482/83 - 12490/91 12492/93 - 12510/11 12520/21 - 12614/15 !KRU?~9;%t::box~= KRU 3J-9:12 boxes 2150.8 --~ 6320 - 6393 '~'250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are available)6459.- 6503 6507 - 6545 KRU 3H-9.: 9 boxes' 6868 - 6908 6911 - 6958 6971 - 7058 KRU 3H-11:2 boxes 3941 - 3954 3970 --3974 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 4061 - 4081 6548 - 6570 KRD 3K-9:16 boxes 3365.2 - 3501.3 6967 - 7009 7027 - 7060 7060 - 7099 7102 - 3174 7199 - 7243 · KRU 3M-9:5 boxes 6531 - 6577.0 6579- 6618 6637 - 6650 -KRU 3M-16:7 boxes 7580 - 7614 7617 - 7690 , Bayview Facility Coordinator SHIPPED BY' ...~. - UPON RECEIPT OF THESE SA~iPLES, PLEASE NOTE ANY DISCREPANCIES AND ~I&IL A SIGNED COPY'OF THIS FOPs%! TO' ARCO. ALASKA,. INC. ANCHORAGE, ALASKA 9'9510' ATTN: Paleo Lab · -. RECEIVED BY' D~T~~,, _~ · ARCO Ala'~ka, Inc. i~ a Subsidiary o~ AtlanticRichfioldCompan¥ DEI~XI~T~IENT OF NATUI~AL I{ESOUI~CES DIVISION OF OIL AND GAS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 STEVE COWPER, RO. BOX 7034 ANCHORAGE, ALASK, Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staf'f, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, Eason amesE irecto[ cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR /tUG - 5 1988 '... I; ARCO Alaska, Inc.' Post Office BOt10360 ~' Anchorage, Alaska 99510 Telephone 907 276 1215 S,.~.',IP LE TP~INS:IIT'I'AL · SHIPPED TO- State of Alaska Oil & Gas Consv. Comm. 3001 Porcupine Dr. Anchorage, Ak 99501 Hand-Carried DATE' Dec. 21, 1987 OPERATOR: ARCO TYPE' Core Chips · SAHPLES SENT: 5965-5997 5998-6025 6026-6058 6059-6085 6086-6115 6116-6145 Lisburne L2-29 9849-9865 9865-9874 9880-9886 9887-9896 9897-9918 9918-9931 9929-9945 9946-9985 9986-10001 10001-10006 10008-10016 10041-10048 10052-10061 10062-10080 10081-10090 10090-10093 SHIPPED BY-~ N~%IE' Kup. 2T-9, Lis. L2-29,L3-12 NUHBER OF BoxEs. 9 Lisburne L3-12 11130-11170 11170-11211 11211-11262 11262-11287 11287-11323 11323-11363 11368-11428 11429-11467 11468-11519 11520-11580 11581-11634 * * sample no. 11615-11616 could not be located. Paleo Lab Tech UPON RECEIPT OF THESE SAHPLES, PLEASE NOTE ANY DISCREP.%NCIES AND ~[KIL A SIGNED COPY OF THIS FOP~Xl TO' ARCO ALASKA, INC. P.O. BOX 100360 ANCHOKaGE, ALASKA 99510 ATTN: Pal=-o Lab ABV/100 DATE' ARCO Alaska. Inc. is a Subsidiary of AtlanlicRIchfieldCompan¥ ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INdECTION __....i__i.---- 2B-11 21089 11/19/85 2H-O1 20033 03/15/86 2H-O~ 20027 03/15/86 50-103 27-04 20074 03/30/87 27-09 20071 03/30/87 27-11 20075 03/30/87 27-15 20062 03/30/87 27-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 3A-04 21433 01/21/87 3A-10 21457 01/21/87 ~.~ 21458 01/21/87 DATE OF PROFILE/ SURVEY __ _ 06/16/87 06/05/87 06/07/87 06/13/87 06/16/87 06121/87 06/16/87 06/16/87 DATA TYPE PROFILE/ SURVEY SPINNER SPINNER SPINNER SPINNER SURVEY SPINNER SURVEY SURVEY SPINNER SURVEY SURVEY 05/25/87 05/87 05/87 05/27/87 REASON FOR WELL ZONES PROF I LE/ COMPLET I ON TAK I NG SURVEY WATER C 3A- 14 21490 0ti./14/87 05/87 SURVEY ~Y-lb FOLLOWUP ABC S FOLLOWUP A&C S FOLLOWUP A&C S INITIAL A&C SS INITIAL A S INITIAL ABC SS INITIAL ABC SS INITIAL ABC SS INITIAL ABC SS INITIAL ABC SS INITIAL A S INITIAL ABC SS INITIAL A S ABC A&C A&C A&C A A&C A A A&C A A A&C A I NJ ECT I ON BWPD 3485 1833 590 2500 1200 1650 RECEIVED AUG 6 i9 ,7 Alas~ Oil & Gas Cons. Commission Anchorage ~,/zs.ka 0ii & Gzs Cons. r. c,/I ATTACltMENT 1 PACE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE It - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR WELL NUMBER NUMBER I N I TIAL PROF I LE/ PROF I LE/ PROFILE/ COMPLETI ON 50-029 I NJ EOT ION SURVEY SURVEY SURVEY '%~2B-11 ~ 21089 11/10/85 06/16/87 SPINNER FOLLOWUP A&C S ""~2tt-O1~ 20033 03/15/86 06/05/87 SPINNER FOLLOWUP A&C S ~21'1-04"'-'/ 20027 03/15/86 06/07/87 SPINNER FOLLOWUP A&C S 50-103 "'J27-04~/' 20074 03/30/87 06/13/87 SPINNER INITIAL A&C SS 27-09 20071 03/30/87 06/16/87 SURVEY INITIAL A S "XJ2T-11 ~ 20075 03/30/87 06/21/87 SPINNER INITIAL A&C SS 27-15 20062 03/30/87 06/16/87 SURVEY INITIAL A&C SS 27-16 20063 03/30/87 06/16/87 SURVEY INITIAL A&C SS 50-029 '"'"'J3A-02 ~ 21h31 01/21/87 05/25/87 SPINNER INITIAL A&C SS 3A-04 211133 01/21/87 05/87 SURVEY INITIAL A&C SS 3A-10 21457 01/21/87 05/87 SURVEY INITIAL A S ~-~J~~ 21458 01/21/87 05/27/87 SPINNER INITIAL A&C SS 3A- 14 21h90 0h/14/87 05/87 SURVEY I N ITIAL A S ZONES TAKING WATER A&C A&C A&C A&C A A&C A A A&C A A A&C A INJECTION BWPD 3~85 1833 590 25OO 1200 1650 RECEIVED AUG 1987 Alaska Oil & Gas Oons. OoraBission Anchorage STATE OF ALASKA ALASI._ OIL AND GAS CONSERVATION COMN SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Q Operation Shutdown ~ Re-enter suspended well ~ Alter casing ii Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate ~ Other/~. 2. N,c.,,rrke,.,of. CPerator /~KL, U AlaSKa, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 227' FSL, 556' FWL, Sec. 1, TllN, R8E, UM At top of productive interval 1244' FSL, 1355' FWL, Sec. 1, T11N, R8E, UM At effective depth 1288' FSL, 1388' FWL, Sec. 1, T11N, R8E, UM At total depth 1303' FSL, 1400' FWL, Sec. 1, TllN, R8E, UM 11. Present well condition summary Total depth: measured 6370' MD feet true vertical 6140' TVD feet 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-9 8. Permit number Permit #86-110 9. APl number 50-- 103-20071 10. Pool Kuparuk River 0il Pool Plugs (measured) None feet Effective depth: measured 6268' MD feet true vertical 6040' TVD feet Casing Length Size Structural 80' 16" Conductor 1957' 10-3/4" Surface Production Liner 6321' 7I' measured 6022'-6058' MD true vertical 5799'-5834' TVD Junk (measured) None Cemented 255 SX CSII 850 SX ASIII & 160 SX Class G 1992' 540 SX Class G& 6351' 175 SX ASI Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 5936' Packers and SSSV (type and measured depth) HB-1 Packer @ 5888' & TRDP-1A-SSA SSSV @ 1806' Measured depth True Vertical depth 110' MD 110' TVD MD 1988' TVD MD 6122' TVD RECEIVE Iv AR - 2 1987 Alaska 0ii & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal Convert well from A and C Sand only production service to A Sand only water inj. servic~ 13. Estimated date for commencing operation .,~ March 3, 1987 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowled~ :./~ ~...~ m ~ Sr Operations Engineer 2/26/87 ¢ ..... - <~¢~. ~ mLL-~]~~ ~.~ ,2,-~-~-' Title' Date Signed ..--~/ ~/~:;7 ~5']) _,- Commission Use Only Conditions of approval Notify commission so representative may witness © Plug integrity [] BOP Test ~ Location clearance I Approval No...-~ _~/ J~ Approved by Form 10-403 Rev 12-1-85 -':':' '-' COflh~mi s'siO'rl eT"' by order of the commission Date Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 28, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2T-9 Dear Mr. Chatterton' Enclosed is a copy of the 2T-9 Core Description to include with the Well Completion Report, dated 01/26/87. If you have any questions, please call me at 263-4944. Sincerely, j. Gruber ~ Associate Engineer JG'db GRU1/56 Enclosure RECEIVED r: ~ B 0 2 ]981 Anchomg~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA u1L AND GAS CONSERVATION C,.,,,,;MISSION .;~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-110 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20071 4. Location of well at surface 9. Unit or Lease Name 227' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1244' FSL, 1355' FWL, Sec. 1, T11N, R8E, UM 2T-9 At Total Depth 11. Field and Pool 1303' FSL, 1400' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool RKB 117' ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D, Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/20/86 07/03/86 1 2/1 6/86* N/A feet MSL 1 17. TotaIDepth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6370'MD 6140'TVD 6268'MD 6040'TVD YES~] NO [] 1806' feet MD 1550' (Approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/Cal, LSS/GR, D I L/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, D I L/ SFL/ GR/SP/FDC/CNL/Cal, GR/LSS, SHDT, WS~P, RFT, GR/CCL/CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD ,_ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110" 24" 255 sx CS II 10-3/4" 36.0# J-55 Surf 1992' 12-1/4" 850 sx AS Ill & 160 sx Class G 7" 26.0# J-55 Surf 6351' 8-1/2" 540 sx Class G & 175 si AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 5936 ' 5888 ' 6022'-6040'MD w/1/2 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6040'-6058'MD w/4 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5799'-5816'TVD See attached Addendum, dal;¢¢ 1/13/87, for 5816 ' -5834 ' TVD 2~/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description to be submitted when received ~"'~'.'/',. ¢'? .~!"'-, --.~:' ,;...? ~*~ ~1 '~; %"; r, .'?:'::a -~ .. .., .'..: , . - f' ; ~; *Note: Drilled RR 7-5-86. Well perforated & tubing run 10-13-86. ¢~eo~& ..... Form 10-407 WC1:1 81: DAN I Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MAR 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 Kuparuk C 5979' 5757' HYDRO, FORM~ Base Kuparuk C 5986' 5763' DEPTH PRESSURE PRESSURE Top Kuparuk A 6006' 5783' Base .Kuparuk A 6146' 5920' 6056' 3675 psi 3423 psi 6051' 3673 psi 3421 psi 6043' 3669 psi 3417 psi 6037' 3669 psi 3416 psi 6029 ' -- 1 psi 6023' 3660 psi 3414 psi 5983' -- 27 psi 3202' -- 1485 psi 3136' 1979 psi 1871 psi 31. LIST OF ATTACHMENTS Addendums (dated 11/15/86 & 1/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~/.,~ Title Associate Engineer Date 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- lng and t~he location of thecementing tool. Ite~L'27.: Me}'h~-':'of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jectiori,Gas [~jection, Shut-in, Other-explain. Item 28:' If,no cores taken, indicate "none". . . Form 10-407 WELL: 7/22/86 ~0/~0/86 ADDENDUM 2T-9 Arctic Pak w/175 sx AS I, followed by 87 bbls Arctic Pak. Rn GR/CCL/CBL f/6178' WLM , surf. - 2900 WLM. Rn gyro f/6178' _ RECEIVEI) FEB 0 2 1987 Alaska Oil & Gas Cons, Commission Anchorage ADDENDUM 10/10/86 12/~04'i86 2T-9 Rn GR/CCL/CBL f/6178' WLM - 2900' WLM. Rn gyro f/ 6178' to surf. Frac'd "A" sand perfs 6022'-6040' (1SPF) & 6040'-6058' (4 SPF) in 8 stages per 12/4/86 procedure using gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann to 2350 psi w/diesel. Tst ins to 8300 psi; OK. Pmp'd 30 bbls 5% Musol, followed by 36 bbls cln diesel @ 2 BPM, 1900 psi. Stage 1: Pmp'd 70 bbls gelled diesel pad @ 20 BPM, 5900 - 3290 psi Stage 2: 32 bbls gelled diesel pad @ 20 BPM, 3320 psi Stage 3: 20 bbls gelled diesel w/1 ppg 100 mesh @ 20.6 BPM, 3290 psi Stage 4: 155 bbls gelled diesel spacer @ 20.6 BPM, 3250 psi Stage 5: 36 bbls gelled diesel w/3 ppg 20/40 mesh sand @ 20.7 BPM, 3280 psi Stage 6: 39 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 20 - 16 BPM, 3290 - 6030 psi Stage 7: Pmp'd 20 bbls gelled diesel w/8 ppg 20/40 mesh @ 15 BPM, 6350 psi Stage 8: 36 bbls gelled diesel flush @ 16 - 22 BPM, 6000 - 4800 psi Total sand in formation: 800# 100 mesh & ±20,300# 20/40 mesh sand. Approx 675# 20/40 mesh left in csg. Load to recover 408 bbls of gelled diesel, 30 bbls 5% Musol & 36 bbls cln diesel. Job complete @ 1249 hfs, 12/16/86. Drilling ~J~pe~visor 2T-9 CORE DESCRIPTION CORE # 2O 21 22 LITHOLOGIES' MD CUT RECOVERED 5965'-6026' 61' 60.5' 6026'-6086' 60' 59.7' 6086'-6146' 60' 59.8' ! Interbedded sandstone, siltstone and Shale of the upper and lower members of the Kuparuk. GRU1/55 B o 2 1987 Gas gons. ~ommisslo~ Anchorage /f& -Iff) '- va CORE LABORATORIES Western Atlas International L A LittonfDresser Company 1- L ARCO ALASKA, INC. ~ - .L CORE AN~~RT KRU 2Z-15, 3K-9 _ 3C-4 KUPARU V IT NORTH SLOPE, ALASKA CL FILE NO. BP-3-1292 ~ Performed by: Core Laboratories 8005 Schoon st. Anchorage, AK 99518 (907) 349-3541 Final Report Presented September 30, 1988 These analysis, oplnlons or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (all errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oil, gas or other mineral well or formation in connection with which such report is used or relied upon. - 8005 Schoon Street. Anchorage. Alaska 99518-3045. (907) 349-3541 '- j , J~ ]- 1-- ~- j ; j 1- J, \- L .1- " ""'" L ~ , .... --' L )- l.-- INTRODUCTION L Core Laboratories was requested to perform a core analysis study on behalf of Arco Alaska, Inc. for whole core samples recovered from KRU 2Z-15, 3K-9, 2T-9, and 3C-4 West Sak formation in the Kuparuk River unit, North Slope, Alaska. Presented herein are the results of this study. 1 ...... L The whole core sections were left preserved and unsampled at the time of the original analysis of each well. This analysis was performed in an effort to complete core data bases where the preserved whole core sections were removed. Service description and methodology are presented in section 1. The core analysis results are presented in section 2. Detailed lithological descriptions are presented in section 3. Also three sets of white light, and ultraviolet light photographs are provided. l 1 We sincerely appreciate this opportunity to be of service and hope these data help complete your core data base for the development of this reservoir. ~ , - - ~ L L. 1- J,.. Section 1 .- 1 .1. 2 3 .L TABLE OF CONTENTS DEAN-STARK CORE ANALYSIS, SERVICE DESCRIPTION DEAN-STARK CORE ANALYSIS AND CMS-200 OVERBURDEN PRESSURE ANALYSIS, TABULAR RESULTS DETAILED LITHOLOGICAL DESCRIPTIONS - ...:.;. ""'" - -= ....... ,-. *'<. - - SECTION 1 DEAN-STARK CORE ANALYSIS, SERVICE DESCRIPTION - ~ ..- - ~, ..-.. - ~ - 1,.... J-.. SECTION 1 CONVENTIONAL CORE )... J- Core Processing J.- Slabbing .l- The one foot whole core sections were slabbed lengthwise 3/4, 1/4 cut with liquid nitrogen used as the blade coolant. The 1/4 slab surface was cleaned of fines resulting from the slabbing process, photographed, and covered with transparent lucite to allow for visual examination and to be utilized as a library set. The 3/4 slab sections were kept frozen awaiting plug sampling. ,..L. , -- Pluq Sampling , .-.-:- From the 3/4 slab of core one-inch diameter plugs were drilled from selected intervals for helium porosity, air permeability, and Dean Stark method fluid measurements. Plugs were taken from the center of the core with liquid nitrogen used as the bit coolant. The remaining 3/4 slab sections were placed in frozen storage at the Anchorage Core Lab facility. 1 -- -. The plugged samples were trimmed to right cylinders approx. 1.5 inches in length, wrapped with 2 full wraps of teflon tape, placed in lead sleeves with 120 mesh screens at each end, and seated frozen at 500 psi. Chips ,-. One cubic inch chips were taken from each foot, wrapped in foil, placed in plastic bags, and shipped to the Arco warehouse in Anchorage, Alaska to be utilized as the state Of Alaska chip sample. -- .-. '-j ...- .l-- 1-. Analysis Techniques ,l.. Plug Analvsis - Atmosµheric Conditions ,.J.. Fluid Saturations .L Fluid saturations were determined by the Dean-Stark method. Fresh weights of the samples were measured and then samples were placed in a Dean-Stark apparatus for a minimum of 12 hours. Dean- stark water readings were then recorded . The samples were then saturated in toluene and an Archimedes Bulk volume measured and corrected for fluid density. The samples were placed back in the Dean-Stark apparatus for hydrocarbon extraction approx. 10 days or until thoroughly clean, indicated by no fluorescence under a U.V. light. Once cleaned, the samples were dried in a vacuum oven for a minimum of 48 hours at 150 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. , -- ~ , -- Saturations by Dean-stark methods were calculated using Equations 1 and 2. ,- So = [«WI - W2 - H20)/Do)/Vp] x 100 Sw = [H20/Vp] x 100 (1) (2) Where: So = Sw = WI = W2 = H20 = Do = Vp = oil saturations, Percent Pore Space Water saturation, Percent Pore Space Natural Weight Extracted and Dried weight Extracted Water, Density Assumed 1.0 gm/cc Density of Oil Pore Volume ,- ...... -- Atmospheric Porosity -. Grain volumes were determined with a Boyle's Law-Helium Heise Gauge Porosimeter upon completion of all other measurements and after removing the lead sleeve from each sample. Atmospheric porosity was calculated using Equation 3. Patm = [(Vb-Vg) / Vb)] x 100 (3 ) ,-- Where: Patm = porosity, Percent Vb = Bulk Volume Vg = Grain Volume -, '- I i r r Grain Density Grain density was calculated using the grain volume results as described above and using Equation 4. 1- Dg = Mg/Vg (4) ,.... Where: Dg = Grain Density Vg = Grain Volume Mg = Grain Mass J-- Atmospheric Permeability to Air ~ 'J.- Samples were loaded into a Hassler type core holder at a confining pressure of 400 psig. permeability calculations were performed as defined by Darcy's Equation for compressible fluids, Equation 5. )... Pa x v x 1000 Qa x L x L K = -------------------- x ----------- (5) (PI - P2) (PI +P2) Vb -------- )... 2 J... , -'" Where: K = Permeability v = Gas Viscosity PI - P2 = Differential Pressure PI + P2 ------- = Mean Pressure 2 pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb = Bulk Volume ..J.... ^ .À -- - , ,- ~ y- y-~, ]~ r r Plug Analysis - Overburden Conditions Porosity Pore volumes were measured at 1000 psi confining stress utilizing a hydrostatic holder and a Boyles Law - Helium Heise Gauge Porosimeter. The overburden porosity is calculated using equation #6 . (Vp cor) Povb = ------------- X 100 (6) Vg + (Vp cor) t- j Where: Vp cor = Pore Volume, corrected for pore volume of the sreens. Vg = Grain Volume J- }- CMS-200 Overburden Porosity }-. Each sample reported had pore volumes measured in the CMS-200 hydrostatic holder at each of the two recorded overburden pressures. Overburden porosity was calculated using Equation #7. ~ P = [Vp / (Vp + Vg)] x 100 (7) 1- Where: Vp = Pore Volume at Overburden Vg = Grain Volume .J-.. Permeability ,l- Horizontal permeability to air was measured utilizing a steady state permeameter with a 1000 psi overburden boot pressure in a hydrostatic holder. Permeability was calculated using the atmospheric permeability equation #5. ~. Overburden Klinkenberq Air Permeability ,.\.. The samples were loaded into the CMS-200 hydrostatic holder where a slippage corrected unsteady state permeability to gas was measured at the stated overburden pressures. This permeability is equal to a non-reactive liquid permeability. Permeability calculation were performed using modified Darcy's and Forchheimer's equations for unsteady-state flow. (Refer to SPE Journal October 1972. A Rapid Accurate Unsteady-State Klinkenberq Permeameter, by Stanley C. Jones. , ,..... ..... ;....i-. - ...- ~ Core Photographs }- The 1/4 slabbed section of each interval was photographed using a one foot of core = six inch format. As requested three sets of laminated white and ultraviolet core photographs are submitted. ~ ~ 1 ¡",.,.. Sample Disposition 1 - The 3/4 slab sections were kept frozen and put back into frozen storage with its appropriate well. The 1/4 slab library sections and plugged samples are currently being stored at our Anchorage facility awaiting further instructions. ...J-, ,l- , r- ,"'" .-- --... ~, - ,--- ~ ,-- - "... ,.- --- ~ ,"- .- SECTION 2 DEAN-STARK ANALYSIS CMS-200 OVERBURDEN PRESSURE ANALYSIS TABULAR RESULTS --- ~ r-" ,...... ..-, -.. ~.. ,-. ..-.. ~ 1?5&-IlO ,,-- ',.-.. 1 KRu ~/- I j , )-- }-- ~ DEAN-STARK CORE ANALYSIS RESULTS J-- .J-. ~ ~ ,;l- ,l- ~- ,.-...., ,-" --- ~ J 1 ì ) 1 } t " 1 }- 'r- }.- 1"" Ì'" 'r- .r- 1 COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, Inc. Date: 28-SEPT-88 File No: BP-3-1292 KRU #3K-9,2Z-15,2T-9,3C-4 Formation: West Sak Laboratory : Anchorage Kuparuk River Unit Drlg Fld: Bland Mud Analysts TLS;TDT DEAN STARK CORE ANALYSIS Sample Depth Kair Hor Kal r Hor Porosity(%) Porosity(%) OIL% YTR% Grain Number (atm) (1000 psi) (hel ium) (hel ium) PORE PORE Density DescriptlOns (ft) md md atm 1000psi gm/ee .------ .... .. .. .... .. .-......_- .. .. .. .. ...... .... ...... .. ..... .. .. .. .. .. ........ .. .... .. .. .. .. .. .. ... .. .. ........ ................ .. .... .. .. .. .. -- .. 1 3467.4 432 374 38.7 35.3 57.6 21.2 2.73 SS,ltolvgy,vfgr,vwsrtd,sbang-sbrd,fr 2 3467.9 711 609 41.8 37.5 58.4 17.5 2.72 SS,olvgy,vfgr,vwsrtd,sbrd,vfri Well KRU #2Z-15 3 2901.6 1529 1120 44.4 40.8 49.9 28.0 2.71 SS,olvgy,vfgr,wsrtd,sbang-sbrd,vfri-uneons sd 4 2991.5 2.32 1.93 32.2 29.0 0.7 91.9 2.72 MDST,ltgy,sdy,slty,mod cons,sl eale,tr earb frags 5 3058.9 577 493 39.2 36.0 42.2 33.9 2.70 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,fri 6 3059.4 648 551 38.9 35.8 40.5 34.3 2.70 SS,olvgy,vfgr,arg,vwsrtd,sbrd,fri Well KRU #2T-9 7 2250.2 739 549 44.0 40.3 49.8 29.2 2.67 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,vfri-uneons sd 8 2250.8 66 20 38.1 32.2 5.1 88.2 2.73 SS,ltolvgy,vfgr,arg,vwsrtd,sbang-sbrd,fri,eale,20% mdst 9 2318.7 1357 947 44.7 40.8 57.0 18.1 2.69 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,vfri-uneons sd 10 2319 1074 836 44.2 40_0 59.6 25.6 2.68 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,vfri-uneons sd 11 2385.5 2121 1610 44_0 40.1 60.0 30.0 2.65 SS,olvgy,vfgr,tr fgr sd,wsrtd,sbrd,vfri-uneons sd 12 2385.9 2649 2107 43.7 40.1 64.3 28.0 2.71 SS.olvgy,vfgr,tr fgr sd,vwsrtd,sbrd,vfri-uneons sd Note: Samples mounted in lead sleeves and squeezed frozen at 500 psig. ,1'" 'ï J \ File No: BP-3-1292 Laboratory : Anchorage Analysts TLS;TDT ~ ) 1 ) } } 'r- 'r 1-- t' COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, nc. Date: 28-SEPT-88 KRU #3K-9,2Z-15,2T-9.3C-4 Formation: West Sak Kuparuk River Unit Drlg Fld: Bland Mud DEAN STARK CORE ANALYSIS . Sample Depth Kair Hor Kalr Hor Porosity(%) porosity(%) OIL% WTR% Grain Number (atm) (1000 psi (helium) (helium) PORE PORE Dens i ty DescriptIons (ft) md md atm 1000psi gm/cc _w.._..... .. .. .... .. .... ........ ...... ...........--- .. .. ...... .. .. ... .... .. .. ...... ...... .. .. .. .. .. ...... .. ......... .. .. .. .. .. ... .. .. .. ....... .. .. .. -. - Well KRU #3C-4 13 3372.5 533 473 38.9 36.2 48.3 19.8 2.68 SS,olvgy,vfgr,arg,vwsrtd,sbang-sbrd.vfri Note: Samples mounted in lead sleeves and squeezed frozen at 500 psig ì -....---... '1 J 1 1 o <: I:!j ::d ê ::d tJ I:!j Z I'd ::d I:!j [,Q [,Q q ::d I:!j ~ ~ t'i t< [,Q H [,Q I () ~ [,Q I t'V o o 1 J ! 1 t -j' } } ). 1 1 ì ,-- ì ) 1 ì 1--- l' 1 r- r r c 0 R E l A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 28-SEPT-88 File No BP-3-1292 KRU #3K'9,2Z-15,2T-9,3C-4 Formation: West Sak Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska OVERBURDEN PRESSURE ANALYSIS - CMS-200 Sample Depth Pressure Poros i ty HorIzontal Permeability Grain Number (Ovbd) (Helium) Kl Kair(est) Density Description (ft) psi % (md) (md) gm/cc Þ.. ........ -........ -......--..-- ..........- .... .. ... .. .. ... .. .... ...... .... ...." .. .. -----....----........-----....... 1 3467.4 ATM 38.7 432 2.73 SS,ltolvgy,vfgr,wsrtd,sbang-sbrd,fri 1000a 35.3 374 1000 35.1 357 376 1500 34.7 345 363 2 3467.9 ATM 41.8 711 2.72 SS,olvgy,vfgr,vwsrtd,sbrd,vfri 1000a 37.5 609 1000 36.9 543 570 1500 36.2 499 526 Well KRU #2Z-15 3 2901.6 ATM 44.4 1529 2.71 SS,olvgy,vfgr,wsrtd,sbang-sbrd,vfri-uncons sd 1000a 40.8 1120 1000 39.8 786 849 1500 38.8 692 747 4 2991. 5 ATM 32.2 2.32 2.72 MDST,ltgy,sdy,slty,mod cons,sft,sl calc.tr carb frags 1000a 29.0 1.93 1000 28.8 1.17 1.79 1500 28.4 0.72 1.17 5 3058.9 ATM 39.2 577 2.70 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,fri 1000a 36.0 493 1000 35.1 413 438 1500 34.6 397 421 Note - ATM and 1000a data are taken from the dean stark core analysis results. 1 1, 1 } 1 } 1 r 1 1 1 1 ~-,,~ .....,-- -- ___.......oJ 1 - ··1 1 1 C 0 R E L A B 0 R A T 0 R ] E S Arco Alaska, Inc. Date : 28-SEPT-88 File No : BP-3-1292 KRU #3K-9,2Z-15,2T-9,3C-4 Formation : Yest Sak Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska OVERBURDEN PRESSURE ANALYSIS - CMS-200 Sample Depth Pressure Porosity Horlzontal Permeability Grain Number (Ovbd) (Hel iurn) Kl Kair(est) Densi ty Description eft) psi % (md) (md) gm/cc .------ ..---- .... ...... .... .... .. .... .... .. .. .... .. .... .. ...... .... .. .. .. .. .. .. .... ........ .. .. .. .. .. .. .. .... .... .. .. .. .............. 6 3059.4 ATM 38.9 648 2.70 SS,olvgy,vfgr,arg,vwsrtd,sbrd,fri 1000a 35.8 551 1000 34.8 447 478 1500 34.2 427 455 Yell KRU # 2T-9 7 2250.2 ATM 44.0 739 2.67 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,vfri-uncons sd 1000a 40.3 549 1000 38.8 423 467 1500 37.9 379 417 8 2250.8 ATM 38.1 66 2.73 SS,ltolvgy,vfgr,arg,vwsrtd,sbang-sbrd,fri,calc,20% mdst 1000a 32.2 20 1000 31.6 12.4 15 1500 30.8 7.9 9.7 9 2318.7 ATM 44.7 1357 2.69 SS,olvgy,vfgr,vwsrtd,sbang-sbrd,vfri-uncons sd 1000a 40.8 947 1000 40.0 726 759 1500 39.0 627 657 10 2319.0 ATM 44.2 1074 2.68 SS,olvgy,vfgr,vwsrtd,sbang-sbrd.vfri-uncons sd 1000a 40.0 836 1000 39.5 666 714 1500 38.5 595 636 Note - ATM and 1000a data are taken from the dean stark core analysis results. 1 t } 1 J .1 1 '1-- ¡.. ¡.. J.- }- r 1'" r C 0 R E L A B 0 R A T 0 R I E S Arco Alaska, Inc. Date : 28-SEPT-88 File No BP-3-1292 KRU #3K-9,2Z-15,2T-9,3C-4 Formation : West Sak Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska OVERBURDEN PRESSURE ANALYSIS - CMS-200 Sample Depth Pressure Porosity Horizontal Permeability Grain Number (Ovbd) (Helium) Kl Kair(est) Density Description eft) psi % (md) (md) gm/cc --........... .. ........ .. .... ........ .... ......--.. .. ...... .. .... .... .... .. .. ............... ..--.... -----..-................-........., 11 2385.5 ATM 44.0 2121 2.65 SS,olvgy,vfgr,tr fgr sd,wsrtd,sbrd,vfrl-uncons sd 1000a 40.1 1610 1000 39.5 1436 1465 1500 38.5 1227 1258 12 2385.9 ATM 43.7 2649 2.71 SS,olvgy,vfgr,tr fgr sd,vwsrtd,sbrd,vfri-uncons sd 1000a 40.1 2107 1000 39.6 1873 1949 1500 38.8 1566 1683 Well KRU #3C-4 13 3372.5 ATM 38.9 533 2.68 SS,olvgy,vfgr,arg,vwsrtd,sbang-sbrd.vfri 1000a 36.2 473 1000 36.0 423 444 1500 35.5 399 420 Note - ATM and 1000a data are taken from the dean stark core analysis results. - ,...-. SECTION 3 DETAILED LITHOLOGICAL DESCRIPTIONS :- r--, ~ ,.-- .1- L ~ .J- .L DETAILED LITHOLOGICAL DESCRIPTIONS ;L .1.. .L 1 -- 1 , --- - -- ,- I i j Field: KUPARUK RIVER UNIT Formation: WEST SAK File Date Lab BP-3-1292 28-SEPT-88 ANCHORAGE ARCO ALASKA, INC. KRU 3K-9,2Z-15,2T-9,3C-4 NORTH SLOPE, ALASKA J~ 1- ..I -- ').-- '- --- ;1.- "- --- ...... ~ ..... - Detailed Litholoqical Descriptions West Sak 3K-9 1 3467.4 Sandstone - Itolvgy, vfgr, vwsrtd, sbang-sbrd, fri, composed of 60-70% qtz, 20-30% sIt, 2-3% mica, 3-5% dk frags. 2 3467.9 Sandstone - olvgy, vfgr, vwsrtd, sbrd, vfri, composed of 80-90% qtz, 10-15% sIt, 3-5% dk frags, 1% mica. West Sak 2Z-1S 3 2901.65 Sandstone - olvgy, vfgr, wsrtd, sbang-sbrd, vfri-uncons sd, composed of 80-90% qtz, 10-15% sIt, 3-5% dk frags, 1% mica. 4 2991.5 Mudstone - Itgy, sdy, slty, mod cons, sft, sl calc, tr carb frags. 5 3058.9 Sandstone - olvgy, vfgr, vwsrtd, sbang-sbrd, fri, composed of 80% qtz, 10-15% sIt, 5% dk frags, 2-3% mica. 6 3059.4 Sandstone - olvgy, vfgr, arg, vwsrtd, sbrd, fri, composed of 80-90% qtz, 5-10% sIt, 3% dk frags, 2-3% mica. West Sak 2T-9 7 2250.2 Sandstone - olvgy, vfgr, vwsrtd, sbang-sbrd, vfri-uncons sd, composed of 80% qtz, 10-15% sIt, 3-5% dk frags, 1-2% mica. 8 2250.75 Sandstone - Itolvgy, 20% Itgy mdst, ss is vfgr, arg, vwsrtd, sbang-sbrd, fri, calc, composed of 60-70% qtz, 30-40% cly and sIt, 2-3% dk frags, 1-2% mica. 9 2318.7 Sandstone - olvgy, vfgr, vwsrtd, sbang-sbrd, vfri-uncons sd, composed of 90% qtz, 5-10% sIt, 3-5% dk frags, 1% mica. 10 2319.0 Sandstone - olvgy, vfgr, vwsrtd, sbang-sbrd, vfri-uncons sd, composed of 90% qtz, 5-10% sIt, 3-5% dk frags, 1-2% mica. 11 2385.5 Sandstone - olvgy, vfgr, tr fgr sd, wsrtd, sbrd, vfri- uncons sd, composed of 90% qtz, 5-10% sIt, 5% dk frags, tr mica. ,--. .l- ARCO ALASKA, INC. KRU 3K-9,2Z-15,2T-9,3C-4 NORTH SLOPE, ALASKA Field: KUPARUK RIVER UNIT Formation: WEST SAK File Date Lab BP-3-1292 28-SEPT-88 ANCHORAGE ..L Detailed Litholoqical Descriptions ~ .Jt .J.. 12 2385.9 Sandstone - olvgy, vfgr, tr fgr sd, vwsrtd, sbrd, vfri- uncons sd, composed of 90% qtz, 5% sIt, 5% dk frags, tr mica. - ~ West Sak 3C-4 13 3372.5 Sandstone - olvgy, vfgr, arg, vwsrtd, sbang-sbrd, vfri, J composed of 85-90% qtz, 5-10% sIt, 3-5% dk frags,· tr-l% mica. ...1. 1 -- .-- - ! ~ ~[~"~[~'~'~ 12051 RIVERA ROAD ,,~[~1~.~9 .~, SANTA FE SPRINGS, CA 90670-2289 ARCO ALASKA, INC. WELL: 2T-9 FIELD: KUPARUK RIVER WEST SAK FORMATION ROUTINE AND OVERBURDEN CORE ANALYSIS OCTOBER 1986 FILE ~70025 Ms. Renee Hannon Arco Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 Dear Ms. Hannon: 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 October 9, 1986 Re: Core Analysis Data Well: 2T-9 Field: Kuparuk River Formation: West Sak Our File ~70025 Herewith are final routine and overburden core analysis data on core material ~ecovered from your Well 2T-9, Kuparuk River Field, West Sak Formation, Alaska. · The core material, which was cut in the presence of a water base drilling fluid and recovered with a 5 1/4" fiberglass inner sleeve, was received at our Anchorage, Alaska laboratory in a frozen C6ndition. Core processing included a surface gamma radiation .log, slabbing, routine core analysis samples cut on a two per foot basis, and one sample taken each foot for the state of Alaska. The 1/3 slabbed portions were photographed under white and ultraviolet lights using our one foot per print, 1/2 scale format. Core oil gravity was estimated to be 18°API by visual fluorescence. Routine core analysis samples were wrapped with pre-weighed teflon tape/aluminum packages which were individually seated to the samples (300 psi) prior to analysis. Fluid saturations were determined by Dean-Stark extraction with toluene, followed by a chloroform/methanol azeotrope mixture. Routine porosities were determined by the Archimedes method, using toluene as the saturating fluid. Overburden porosities were measured by the Boyle's Law Helium method while hydrostatically' stressing the samples with 1000 psi. Air permeability measurements were made with a calibrated flow tube-type permeameter using confining pressures" of 300 and 1000 psi. We sincerely appreciate ~his opportunity to be of service and trust these data prove beneficial in the ~evaluation of this reservoir. Questions are always welcome. Sincerely, CEH/ch Encl. PETROLEUM TESTING SERVICE, INC. ~Peter T. Schuyler President COMPANY CORE BARREL HUD TYPE Arco ALaska 5 1/4" FibergLass Nater Base PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL FIELD COUNTY STATE PAGE 1 FILE No. 70025 DATE September 26, 1986 Nest Sak 2T-9 Kuparuk River - ~est Sak ALaska ARCHIMEDES Air DEPTH POROSITY PermeabiLity FEET PERCENT mci. SATURATION APPARENT ~ PORE SPACE SAND GRAIN .............. DENSITY OIL NATER gm/cc CORE NO. 1 (2150 - 2180) : REC. (2150 - 2180.75) 2150.2 29,0 1.8 0.0 99.3 2,68 2150.8 28.2 2.0 ** 0.0 99.6 2.69 2151.05 28.2 1.4 0.0 99.? 2.69 2151.55 26.8 i.3 0.0 99.5 2.68 2152.05 26.4 7.0 0.0 99.8 2.68 2152.65 27.9 27. 0,0 99.3 2.68 2153.1 31.8 12. 0.0 97.4 2.72 2153.55 31.2 13. 0.0 96.4 2.71 2154.05 30.9 8.0 0.0 99.0 2.71 2154.6 30.5 6.9 0.0 99.8 2.72 2155.05 32.7 6.0 ** 0.0 99.4 2.72 2155.6 30.7 3.3 0.0 98.5 2.71 2156.05 30.6 5.0 0.0 99.5 2.72 2156.75 30.9 10. 0.0 99.1 2.71 at SIHULATED RESERVOIR STRESS SIHULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL NATER 1000 27.1 0.4 0.0 109.4 1000 26.7 1.0'* 0.0 107.3 1000 26.2 0.3 0.0 110.2 1000 24.4 0.5 0.0 113.0 1000 24.3 2.5 0.0 111.2 1000. 25.5 12 0.0 112.0 1000 29.1 6.6 0.0 110.6 1000 28.9 6.2 0.0 107.8 1000 28.2 3.3 0.0 112.8 1000 27.2 2.0 0.0 117.0 SAMPLE FAILED 1000 IS.? 1.2 0.0 108.1 1000 28.5 3.1 0.0 109.9 1000 29.5 6.6 0.0 105.8 DESCRIPTION cry; cry-sit, cty; cry-sit, C[y; cry-sit, cry; cry-sit, Cry; cty-stt, Sit; c[y-s[t, Stt; cry-sit, Sit; cry-sit, CLy; cLy-sLt, CLy; cty-stt, cty; cry-sit, Cry; c[y-stt, cry; cry-sit, Slt; cty-stt, mod cmtd mod cmtd mod cmtd mod cmtd . mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd ** FRACTURED, ESTIMATED AIR PERHEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL Nest Sak 27-9 PAGE 2 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi[|t¥ .............. DENSITY FEET PERCENT md. OIL ~ATER g~/cc at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi(ty ............... psi PERCENT md. OIL NATER CORE NO. 1 (CONTINUED) (2150- 2180) : REC. (2150 - 2180.75) 2157.25 30.8 7.1 0.0 98.8 2.71 1000 2157.75 30.8 8.5 0.0 99.4 2.71 1000 2158.25 30.1 4.0 0.0 98.7 2.71 1000 2158.75 28.9 2.3 0.0 99.1 2.71 1000 2159.2 28.6 2.3 0.0 99.6 2.71 1000 2159.75 28.6 1.2 0.0 99.1 2.71 1000 2160.05 31.3 10. ** 0.0 99.4 2.72 1000 2160.5 27.3 0.8 0.0 99.6 2.70 1000 2161.05 27.6 3.0 0.0 99.1 2.70 1000 2161.6 27.7 3.3 0.0 99.6 2.70 1000 29.0 28.5 28.5 26.7 26.7 25.6 30.0 26.3 25.7 25.9 ~,.? 5.1 2.7 1.2 1.6 0.6 6.0** 0.5 1.7 1.5 0.0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 107.7 110.9 106.3 110.2 109.5 115.9 105.9 105.1 109.3 109.4 2162.05 28.9 8.8 0.0 99.6 2.71 1000 2162.7 29.3 12. 0.0 97.8 2.71 1000 2163.05 30.3 15. 0.0 99.1 2.71 1000 2163.5 29.7 4.8 0.0 99.4 2.68 1000 2164.05 29.4 6.5 0.0 98.4 2.71 1000 2164.5 29.6 5.5 0.0 98.4 2.71 1000 2165.05 29.8 8.5 0.0 98.1 2.70 1000 2165.65 30.3 10. ** 0.0 99.4 2'.71 1000 27.2 27.1 27.8 27.9 26.8 25.0 27.1 27.1 2.0 3.3 3.3 0.8 2.4 2.4 3.4 5.0'* 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 108.5 108.9 111.7 108.4 112.0 123.8 112.1 116.6 DESCRIPTION Sit; c[y-stt, mod cmtd Sit; c[y-stt, mod cmtd Cty; cty-stt, mod cmtd Cty; cry-sit, mod cmtd Cty; cty-stt, mod cmtd CLy; cty-stt, mod cmtd Cry; cry-sit, mod cmtd cry; cty-stt, mod cmtd C[¥; cty-stt, mod cmtd cry; cry-sit, mod cmtd cry; cty-stt, mod cmtd Cry-sit; cry-sit, mod cmtd Cty-stt; cty-stt, mod cmtd Ciy; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cty; cry-sit, mod cmtd Sit; cty-slt, mod cmtd ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 3 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 1 (CONTINUED) (2150 - 2180) : REC. (2150 - 2180.75) 2166.05 29.9 10. 0.0 98.6 2.70 2166.55 28.0 4.0 0.0 96.1 2.71 2167.05 28.9 8.5 0.0 99.6 2.70 2167.55 27.4 1.9 0.0 98.0 2.71 2168.05 27.5 3.3 0.0 98.7 2.71 2168.55 27.2 2.1 0.0 99.2 2.70 2169.05 26.6 1.4 0.0 98.5 2.70 2169.55 26.7- 1.7 0.0 98.7 2.70 2170.05 27.4 2.2 0.0 98.1 2.70 2170.55 26.4 0.9 0.0 99.2 2.70 2171.05 27.2 6.4 0.0 99.8 2.70 2171.55 28.9 5.0 ** 0.0 98.Z 2.70 2172.05 27.3 1.3 0.0 99.1 2.71 2172.55 27.2 1.3 0.0 99.2 2.71 2173.05 27.7 1.6 0.0 99.5 2.70 2173.55 27.9 2.5 0.0 98.8 2.71 2174.05 29.8 2.2 0.0 ~9.4 2.71 2174.45 28.9 1.0 ** 0.0 99.0 2'.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY PermeabJ[ty ............... psi PERCENT md. OIL WATER 1000 27.4 5.0 0.0 111.3 1000 25.9 1.6 0.0 106.8 1000 26.3 2.5 0.0 113.2 1000 25.2 0.8 0,0 109.7 1000 26.4 1.6 0.0 104.5 1000 25.2 0.9 0.0 109.9 1000 24.8 0.7 0.0 108.0 1000 24.7 0.7 0.0 109.6 1000 25.3 0.8 0.0 109.5 1000 24.7 0.4 0.0 108.1 1000 25.3 1.6 0.0 1'10.5 1000 26.2 1.0'* Q.O 113.0 1000 24.9 0.6 0.0 112.2 1000 25.8 0.5 0.0 106.2 1000 25.8 0.5 0.0 109.5 1000 26.3 1.1 0.0 107.1 1000 27.1 0.5 0.0 113.5 1000 27.3 0.5** 0.0 107.5 DESCRIPTION cry; cty-stt, cry; c[y-stt, cty;.cty-stt, cry; cty-stt, cry; cry-sit, Cry; cty-stt, Cry; cry-sit, Ct¥; cty-stt, Cry; cty-stt, Cly; ct¥-s~t, cry; cty-stt, Cry; cty-stt, cry; cty-stt, cW; cty-stt, Cry; cty-stt, cry; cry-sit, cry; cry-sit, cry; cry-sit, mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco ALaska PETROLEUH TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 2T-9 PAGE 4 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi[|ty .............. DENSITY FEET PERCENT md. OIL WATER g~/cc CORE NO. 1 (CONTINUED) (2150 - 2180) : REC. (2150 - 2180.75) 2175.05 28.4 7.6 0.0 98.2 2.71 2175.55 28.4 1.0 0.0 98.5 2.71 2176.05 29.4 0.7 0.0 , 99.3 2.72 2176.55 28.7 1.0 ** 0.0 99.5 2.71 2177.05 28.0 1.0 0.0 97.6 2.70 2177.5 28.5 2.2 0.0 99.0 2.70 2178.05 28.1 2.0 0.0 99.6 2.70 2178.55 27.4 0.8 0.0 99.2 2.70 2179.05 27.6 1.4 0.0 98.3 2.71 2179.55 27.8 2.1 0.0 99.4 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OiL WATER ........ ........ .....~..... ... 1000 27.4 0.? 0.0 103.1 1000 27.0 0.2 0.0 105.6 1000 27.4 0.3 0.0 109.4 SAMPLE FAILED 1000 26.0 0.5 0.0 108.4 1000 26.6 0.4 0.0 109.0 1000 26.4 0.7 0.0 108.4 1000 26.3 0.3 0.0 105.0 1000 26.0 0.2 0.0 106.7 1000 26.0 0.5 0.0 109.0 2180.0 RUBBLED MATERIAL - NO SAMPLE CORE NO. 2 (2180 - 2200) : REC. (2180.75 - 2197.75) 2180.85 27.3 3.0 0.0 95.4 2.70 2181.05 31.7 54. 0.0 93.1 2.67 2181.55 34.3 316. 0.0 86.9 2.68 2182.05 27.5 4.8 0.0 99.6 2~69 2182.55 29.1 9.8 0.0 99.0 2.68 2183.05 28.9 6.8 0.0 97.2 2.68 2183.55 29.7 15. 0.0 98.9 2.69 1000 25.9 0.6 0.0 102.4 1000 30.0 31 0.0 100.8 1000 31.3 193 0.0 99.8 1000 25.9 0.9 0.0 108.1 1000 26.8 3.2 0.0 111.0 1000 26.6 2.2 0.0 109.5 1000 27.6 4.7 0.0 109.5 DESCRIPTION Cty; ciy-sit, mod cmtd Cty; ciy-sLt, mod cmtd CLy; cLy-stt, mod cmtd Cry; cty-stt, mod cmtd CLy; c[y-sLt, mod cmtd C[y; cLy-sLt, mod cmtd CLy; cLy-sLt, mod cmtd C[y; cLy-s[t, mod cmtd C[y; cLy-s[t, mod cmtd c[y; cL¥-sLt, mod cmtd Cry; cty-stt, mod cmtd Stt; cty-vfsd, mod cmtd Stt; stt-fsd, prty cmtd Cty; cty-stt, mod cmtd cly; cLy-stt, mod cmtd Cry; cly-sLt, mod cmtd Slt; cty-sLt, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE~ INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 5 FiLE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT . md. Ol L WATER gm/cc CORE NO. 2 (CONTINUED) (2180 - 2200) : REC. (2180.75 - 2197.75) 2184.05 29.4 6.8 0.0 96.7 2.69 2184.55 29.2 6.1 0.0 98.5 2.69 2185.05. 28.7 6.7 0.0 99.6 2.69 2185.55 28.8 3.8 0.0 97.9 2.69 2186.05 29.2 6.2 0.0 98.0 2.69 2186.55 28.5 3.3 0.0 96.0 2.69 2187.05 28.2 3.2 0.0 96.9 2.69 218?.55 28.1 3.2 0.0 99.2 2.68 2188.05 28.8 4.3 0.0 98.3 2.69 2188.55 27.8 2.1 0.0 96.7 2.69 2189.05 28.1 1.3 0.0 97.8 2.69 2189.55 28.3 2.4 0.0 99.4 2.69 2190.05 27.9 1.5 0.0 94.9 2.70 2190.55 27.9 1.8 0.0 98.2 2.70 2191.05 29.2 1.1 0.0 99.4 2.72 2191.55 29.2 1.7 0.0 98.5 2.71 2192.05 26.3 0.3 0.0 98.1 2.69 2192.55 26.2 0.5 0.0 97.1 2'.70 2193.05 27.8 1.8 0.0 98.2 2.69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 27.1 2.4 0.0 108.0 1000 27.3 2.5 0.0 107.9 1000 26.7 2.5 0.0 109.9 1000 26.8 1.7 0.0 108.2 1000 27.5 2.2 0.0 106.4 1000 27.0 1.4 0.0 103.6 1000 26.9 1.1 0.0 103.5 1000 26.8 1.3 0.0 106.1 1000 27.1 1.7 0.0 106.9 1000 26.3 1.0 0.0 104.7 1000 26.9 0.5 0.0 104.0 1000 26.8 0.9 0.0 107.3 1000 26.4 0.7 0.0 102.4 1000 26.6 0.8 0.0 104.8 SAMPLE FAILED 1000 27.3 0.7 0.0 108.1 1000 24.9 0.2 0.0 105.4 1000 24.9 0.3 0.0 104.3 1000 26.0 0.9 0.0 107.8 DESCRIPTION Cry; cty-stt, mod cmtd Cry; cty,stt, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; c[y-stt, moclcmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd Cry; c[y-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; c[y-stt, mod cmtd Cry; cty-stt~ mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t~ mod cmtd Cry; c[y-s[t, mod cmtd Cry; c[y-stt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-stt, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 6 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN · DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIl ~ATER g~/cc CORE NO. 2 (CONTINUED) (2180 - 2200) : REC. (2180.75 - 2197.75) 2193.55 24.8 0.1 ** 0.0 99.8 2.70 2194.05 25.5 0.1 0.0 97.1 2.70 2194.55 26.9 1.3 0.0 98.7 2.69 2195.1 28.7 2.0 ** 0.0 97.8 2.68 2195.55 29.2 4.0 0.0 96.1 2.72 2196.05 28.2 4.1 0.0 96.0 2.69 2196.55 27.9 5.0 0.0 97.4 2.70 2197.05 29.2 3.7 0.0 92.4 2.68 2197.55 26.7 3.8 0.0 96.8 2.69 CORE NO. 3 (2200 - 2227) : REC. (2197.75 - 2228.9) 2198.05 29.6 3.1 0.0 95.0 2.73 2198.55 30.7 2.3 0.0 96.6 2.71 2199.05 29.3 7.5 0.0 98.0 2.73 2199.55 30.1 5.5 0.0 98.0 2.74 2200.05 29.3 0.? 0.0 99.4 2.71 2200.55 28.2 1.0 0.0 97.6 2.71 2201.05 31.5 5.0 ** 0.0 95.9 2~72 2201.55 28.1 1.0 0.0 98.5 2.71 at SIMULATED RESERVOIR STRESS SIMULATED ................ ,- ........................ RESERVOIR , Air SATURATION % STRESS POROSITY Permeabi lty ............... ps i PERCENT md. 01L 14ATE R 1000 23.8 < 0.05'* 0.0 105.8 SAMPLE FAILED 1000 25.1 0.5 0.0 108.7 1000 26.9 1.0'* 0.0 107.1 1000 2T.1 2.1 0.0 106.4 1000 26.3 2.1 0.0 106.0 1000 26.2 1.4 0.0 106.6 1000 27.1 2.4 0.0 102.1 1000 24.8 1.1 0.0 106.7 1000 28.3 0.6 0.0 101.4 1000 27.4 0.5 0.0 113.3 1000 28.0 0.9 0.0 104.8 1000 27.9 1.1 0.0 109.1 1000 27.4 0.3 0.0 109.0 1000 26.7 0.4 0.0 105.2 1000 29.2 2.0** 0.0 106.8 1000 26.8 0.4 0.0 104.9 DESCRIPTION Cry; cty-stt, mod cmtd Cry; cry-sit, mod cmtd cry; cly-stt, mod cmtd Cry; c[y-slt, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-slt, mod cmtd Cly; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[yi c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd Cly; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco ALaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 7 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 3 (CONTINUED) (2200 - 2227) : REC. (2197.75 - 2228.9) 2202.05 28.3 0.9 0.0 98.2 2.70 2202.55 28,0 0.5 0.0 95.6 2.70 2203.05 28.9 0.8 0.0 97.5 2.70 2203.55 28.3 0.8 0.0 99.0 2.71 2204.05 28.7 1.2 0.0 99,6 2.70 2204.55 28.5 1.6 0.0 99,4 2.71 2205.05 28.2 1.7 0.0 99,8 2.71 2205.55 27.2 0.9 0.0 99.2 2.70 2206.05 27.7 0.5 0.0 94.4 2.69 2206.55 29.1 0.8 0.0 99.2 2.70 2207.05 28.3 0.4 0.0 97.0 2.71 2207.55 28.4 0.5 0.0 97.8 2.70 2208.05 28.1 0.5 0.0 97,6 2.70 2208.55 28.1 0.8 0.0 95,8 2.70 2209.05 28.9 2.2 0.0 97,8 2.73 2209.55 28.5 1.1 0.0 99,1 2.70 2210.05 28.8 0.9 0.0 98.6 2.71 2210.55 28.7 1.8 0.0 98.6 2'.73 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY PermeabiLty ................ psi PERCENT md. OIL WATER 1000 27.1 0.4 0.0 104.7 1000 26.5 0.2 0.0 103.1 1000 26.0 0.4 0.0 112.4 1000 26.8 0~4 0.0 106.5 1000 27.1 0.4 0.0 107.8 1000 26.7 0.5 0.0 108.5 1000 26.9 0.6 0.0 106.9 1000 25.7 0.3 0.0 107.6 1000 26.2 0.1 0.0 101.5 1000 27.5 0.2 0.0 107.0 1000 27.1 0.1 0.0 102.9 1000 27.0 0.2 0.0 104.8 1000 26.2 0.2 0.0 107.1 1000 26.2 0.3 0.0 105.3 1000 26.8 1.0 0.0 108.2 1000 26.2 0.4 0.0 111.0 1000 27.0 0.4 0.0 107.7 1000 26.7 0.9 0.0 109.4 DESCRIPTION Cry; cty-stt, mod cmtd Cry; cry-sit, mod cmtd Cty;.cty-stt, mod cmtd C[y; c[y-s[t, mod cmtd Cty; cty-stt, mod cmtd C[y; c[y-sLt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd. Cty; cty-s[t, mod cmtd Cry; cty-s[t, mod cmtd Cly; cty-sLt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd CLy; cLy-s[t, mod cmtd Cty; cLy-slt, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 2T-9 PAGE 8 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi{ity .............. DENSITY FEET PERCENT md. OIL WATER 9,m/cc CORE NO. 3 (CONTINUED) (2200 - 2227) : REC. (2197.75 - 2228.9) 2211.05 29.0 0.9 0.0 99.5 2.72 2211.55 29.3 1.1 0.0 98.1 2.72 2212.05 28.5 1.3 0.0 94.6 2.71 2212.55 28.4 4.1 0.0 99.2 2.74 2213.05 29.5 2.4 0.0 99.6 2.71 2213.55 33.0 18. ** 0.0 99.2 2.72 2214.05 32.3 18. 0.0 99.8 2.?2 2214.55 29.1 1.4 0.0 98.6 2.71 2215.05 30.1 2.9 0.0 99.4 2.73 2215.55 28.5 0.9 0.0 99.8 2.71 2216.05 30.5 1.2 0.0 97.7 2.70 2216.55 28.5 2.1 0.0 98.1 2.71 2217.05 27.9 0.4 0.0 98.6 2.71 2217.55 28.4 1.8 0.0 98.3 2.71 2218.05 27.7 0.4 0.0 99.1 2.70 2218.55 27.8 0.8 0.0 98.0 2.70 2219.05 29.5 3.5 0.0 99.0 2.71 2219.55 28.2 0,7 0,0 99,2 2'.70 2220.05 28.7 1.4 0.0 99.8 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL WATER 1000 27.2 0.5 0.0 109.1 1000 27.4 0.5 0.0 107.7 1000 26.0 0.6 0.0 107.4 1000 25.9 0.7 0.0 112.5 1000 28.0 0.9 0.0 107.2 SAMPLE FAILED 1000 29.3 7.4 0.0 114.5 1000 27.3 0.7 0.0 107.6 1000 28.3 0.6 0.0 108.6 1000 27.0 0.4 0.0 107.5 1000 28.8 0.5 0.0 106.1 1000 26.9 0.9 0.0 106.4 1000 26.8 0.2 0.0 104.3 1000 25.2 0.8 0.0 115.7 1000 26.6 0.2 0.0 104.7 1000 26.6 0.4 0.0 104.1 1000 27.9 1.1 0.0 106.9 1000 26.2 0.3 0.0 109.5 1000 27.4 0.7 0.0 106.3 DESCRIPTION Cry; cty-stt, Cly; cly-stt, Cty; cty-stt, Cry; cty-stt, Cry; cry-sit, Cty; cty-stt, Stt; cly-slt, Cty; cty-s{t, Cry; cly-slt, Cly; cly-slt, Cly;.cty-stt, Cry; cry-sit, Cry; cly-slt, Cly; cly-stt, Cty; cly-slt, cry; cty-stt, cry; cty-stt, Cry; cty-stt, Cly; cly-slt, mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUH TESTING SERVICE, INC. CORE ANALYSIS ~ELL Nest Sak 2T-9 PAGE 9 FILE No. 70025 DATE September 26, 1985 SATURATION APPARENT ARCHIMEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT mci. OIL NATER g~/cc CORE NO. 3 (CONTINUED) (2200 - 2227) : REC. (2197.75 - 2228.9) 2220.55 28.9 1.0 0.0 99.4 2.70 2221.05 29.6 1.0 ** 0.0 99.1 2.73 2221.55 28.9 O.Z 0.0 99.4 2.71 2222.05 28.7 1.7 0.0 97.7 2.71 2222.55 28.2 0.7 0.0 98.2 2.70 2223.05 28.9 i.2 0.0 99.2 2.70 2223.55 28.8 0.9 0.0 99.6 2.71 2224.05 30.0 2.8 0.0 95.9 2.70 2224.55 29.6 1.4 0.0 97.1 2.70 2225.05 28.8 1.2 0.0 97.4 2.70 2225.55 29.0 3.7 0.0 98.4 2.70 2226.05 28.8 2.4 0.0 98.8 2.70 2226.55 28.1 1.8 0.0 97.8 2.70 2227.05 28.2 1.7 0.0 98.0 2.69 2227.55 29.1 2.7 0.0 98.2 2.69 2228.05 32.0 15. 0.0 94.8 2.69 2228.55 32.3 15. ** 0.0 97.7 2.74 CORE NO. 4 (2227 - 2240) : REC. (2228.9 - 2242.7) 2229.05 30.8 3.9 0.0 98.5 2.73 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Pemeabi[ty ............... psi PERCENT mci. OIL WATER 1000 27.1 0.4 0.0 108.5 SAMPLE FAILED 1000 24.1 0.3 0.0 127.3 1000 28.0 0.7 0.0 101.0 1000 27.3 0.3 0.0 102.9 1000 27,4 0.7 0.0 106,5 1000 27.3 0.4 0.0 107.0 1000 26.7 1.4 0.0 112.8 1000 26.4 0.4 0.0 113.8 1000 26.4 0.7 0.0 110.0 1000 27.0 1.6 0.0 108.8 1000 26.6 1.1 0.0 110.4 1000 26.5 1.1 0.0 105.8 1000 26.1 0.8 0.0 109.4 1000 25.6 0.7 0.0 117.1 1000 27.0 2.8 0.0 120.4 SAHPLE FAILED IOO0 27.5 0.9 0.0 115.9 DESCRIPTION cry; cry-sit, mod cmtd cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-s~t0 mod cmtd cLy; crY-sit, mod cmtd C[y; cry-sit, mod cmtd Cry; c[y-sit, mod cmtd C[y; cty-stt, mod cmtd Cty; c[y-stt, mod cm:d Cty; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cry;' cty-stt, mod cmtd cry; cty-stt, mod cmtd cry; cty-stt, pyr, mod cmtd Cly; cly-stt, mod cmtd ** FRACTUREDt ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 10 FILE No. 70025 DATE September 26, 1986 ARCNIMEDES Air DEPTH POROSITY Permeability FEET PERCENT md. SATURATION APPARENT % PORE SPACE SAND GRAIN .............. DENSITY OIL WATER gm/cc at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER CORE NO. 4 (CONTINUED) (2227 - 2240) : REC. (2228.9 - 2242.7) 2229.55 30.3 3.0 ** 0.0 99.3 2.72 2230.05 30.3 43. 0.0 96.1 2.71 2230.55 28.6 5.0 ** 7.6 82.8 2.69 2231.05 27.4 6.0 0.0 94.4 2.70 2231.55 27.1 4.8 0.0 98.4 2.70 2232.05 32.7 71. 0.0 94.1 2.73 2232.55 26.5 1.8 0.0 98.3 2.70 2233.05 31.0 49. 0.0 95.9 2.70 2233.55 34.0 90. 18.6 71.9 2.70 2234.05 26.3 8.5 7.4 85.1 2.67 2234.55 24.8 3.0 ** 0.0 97.2 2.73 2235.05 29.7 4.2 4.0 94.3 2.72 2235.55 40.2 1300. 5.4 80.9 2.69 2236.05 43.4 900. 5.8 85.3 2.69 2236.55 40.2 1360. 9.7 67.8 2.69 2237.05 45.6 1710. 6.0 91.5 2.68 2237.55 39.7 928. 62.9 30.3 2.68 2238.05 32.2 83. 39.9 50.0 2.69 2238.55 43.2 1500. 54.8 28.3 2.68 2239.3 40.8 1320. 63.8 28.2 2.70 SAMPLE FAILED 1000 28.0 7.0 0.0 107.2 1000 26.8 2.0'* 8.3 90.4 1000 25.2 1.9 0.0 105.6 1000 25.0 1.5 0.0 109.4 1000 30.1 19 0.0 106.2 1000 24.1 0.7 0.0 111.2 1000 28.6 8.0 0.0 107.7 1000 30.5 23 21.9 84.3 1000 24.5 4.3 8.2 93.9 SAMPLE FAILED 1000 28.0 2.1 4.4 102.1 SAMPLE FAILED 1000 38.7 410 7.1 103.9 1000 37.2 379 11.1 77.0 1000 38.9 427 7.9 120.3 1000 37.2 699 69.7 33.6 1000 28.8 44 46.8 58.7 1000 39.4 900 64.3 33.1 1000 37.9 946 71.7 31.8 DESCRIPTION C[y; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Cry; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y-s[t; c[y-vfsd, mod cmtd C[y; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd ely; c[y-s[t, mod cmtd Sd; c[y-vfsd, pr[y cmtd Sd; c[y-vfsd, pr[y cmtd Sd; c[y-vfsd, pr[y cmtd Sd; sit-lsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; slt-fsd, pr[y cmtd Sd; slt-fsd, pr[y cmtd Sd; sit-lsd, pr[y cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 11 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER g~/cc CORE NO. 4 (CONTINUED) (2227 - 2240) : REC. (2228.9 - 2242.7) 2239.55 40.6 657. 68.1 24.1 2.66 2240.25 43.6 920. 61.2 25.5 2.68 2240.5 44.4 1640. 59.2 21.7 2.68 2241.1 41.8 1570. 63.9 24.6 2.69 2241.7 4.7 0.1 4.9 67.8 2.71 2242.0 RUBBLED MATERIAL - NO SAMPLE CORE NO. 5 (2240 - 2243) : REC. (2242.7 - 2244.65) 2243.3 4.2 0.1 0.0 88.3 2.71 2243.7 4.4 0.1 2.7 91.0 2.72 2244.05 4.8 0.1 13.7 85.9 · 2.71 2244.5 6.0 0.1 43.6 47.7 2.70 CORE NO. 6 (2243 - 2274) : REC. (2244.65 - 2276.2) 2245.05 35.3 63. 19.3 74.5 2.71 2245.55 32.8 20. ** 10.5 89.3 2.70 2246.05 33.5 1.2 15.8 82.1 2.76 2246.55 36.5 50. ** 24.6 68.8 2.70 2247.0 46.5 1620. 45.1 47.3 2.69 2247.55 44.4 1210. 52.5 40.1 2.69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabilty ............... psi PERCENT md. OIL WATER 1000 37.9 494 76.3 27.0 1000 39.0 192 74.0 30.9 1000 38.5 947 75.6 27.8 1000 37.8 509 75.5 29.0 1000 4.3 < 0.05 5.3 74.7 1000 3.9 < 0.05 0.0 94.4 1000 4.1 < 0.05 2.9 97.3 1000 4.4 < 0.05 14.9 93.6 1000 5.5 < 0.05 48.0 52.5 1000 32.0 19 22.4 86.4 SAMPLE FAILED 1000 32.0 0.4 16.9 87.8 1000 33.7 30** 27.8 77.6 1000 41.8 1080 54.8 57.4 1000 40.8 821 60.9 46.5 DESCRIPTION Sd; stt-fsd, prly cmtd Sd; slt-fsd, prly cmtd Sd; slt-fsd, prly cmtd Sd; s[t-fsd, pr[y cmtd Ls; we[[ cmtd Ls; well cmtd Ls; well cmtd ls; well cmtd Ls; well cmtd Slt; c[y-vfsd, mod cmtd Cly; cly-slt, mod cmtd Cly; cly-vfsd, mod cmtd C[y-sd; c[y-vfsd, mod cmtd Sd; slt-vfsd, pr[y cmtd Sd; slt-vfsd, prly cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 12 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY . FEET PERCENT md. OIL ~ATER gm/cc CORE NO. 6 (CONTINUED) (2243 - 2274) : REC. (2244.65 - 2276.2) 2248.0 RUBBLED MATERIAL - NO SAMPLE 2248.95 42.0 980. 58.2 33.2 2.68 2249.45 43.8 1540. 53.2 45.9 2.69 2249.95 42.6 1270. 60.3 33.0 2.68 2250.0 SECTION PRESERVED 2251.0 SECTION PRESERVED 2251.05 34.9 46. 26.9 72.2 2.72 2251.55 35.6 17. 3.2 95.8 2.73 2252.05 35.2 6.0 0.9 97.5 2.72 2252.55 31.3 8.0 1.3 95.1 2.73 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL ~ATER 1000 38.9 1000 38.3 1000 39.3 1000 33.4 1000 33.3 1000 29.9 716 66.2 37.8 766 66.6 57.4 773 69.2 37.9 SAMPLE FAILED 12 3.6 105.3 4.0 1.0 106.3 2.4 1.4 101.4 2253.05 36.4 80. 36.8 58.3 2.71 1000 34.1 63 40.8 64.5 2253.55 35.5 42. 24.1 73.1 2.72 SAMPLE FAILED 2254.05 36.5 70. ** 13.9 84.4 2.74 1000 34.7 50** 15.1 91.2 2254.55 39.7 300. ** 45.4 47.2 2.70 1000 36.9 150'* 51.2 53.2 2255.05 34.0 21. 12.2 84.6 2.71 1000 31.9 11 13.4 93.1 2255.55 40.1 400. ** 8.9 71.5 2.70 1000 37.9 200** 9.8 78.4 2256.2 41.1 1150. 54.1 33.6 2.69 1000 36.4 786 66.1 41.0 2256.5 39.6 350. 45.2 43.6 2.68 1000 37.2 140 50.1 48.4 2257.05 43.3 1480. 44.4 44.1 2.67 SAMPLE FAILED 2257.55 41.8 1790. 47.8 41.9 2.68 1000 39.7 1370 52.0 45.6 2258.2 40.9 793. 57.5 33.7 2.68 1000 38.5 503 63.7 37.4 DESCRIPTION Sd; s[t-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd SEt; cly-vfsd, mod cmtd Slt; cly-vfsd, mod cmtd ely; cly-slt, mod cmtd Cly; cly-slt, mod cmtd Slt; cly-slt, mod cmtd Slt; cly-slt, mod cmtd Slt; cly-slt, mod Cmtd Slt; cly-slt, mod cmtd Slt; cly-slt, mod cmtd Slt; cly-s(t, mod cmtd Sd; slt-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd Sd; slt-vfsd, prly cmtd COMPANY Arco Ataska PETROLEUM TESTING SERVICEw INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 13 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 6 (CONTINUED) (2243 - 2274) : REC. (2244.65 - 2276.2) 2258.65 42.3 1170. 39.9 47.7 2.68 2259.35 39.7 458. 45.9 44.4 2.68 2259.55 38.2 354. 41.6 50.2 2.67 2260.0 HUDDLED MATERIAL - NO SAMPLE 2260.95 39.2 185. 43.2 47.2 2.69 2261.0 RUBBLED MATERIAL - NO SAMPLE 2261.85 39.9 590. 41.0 43.7 2.70 2262.45 37.9 234. 44.1 46.5 2.68 2262.5 RUBBLED MATERIAL - NO SAMPLE 2263.0 RUBBLED MATERIAL - NO SAMPLE 2263.55 33.2 101. 13.5 82.1 2.69 2264.05 34.0 30. 26.4 68.3 2.74 2264.55 33.8 30. 22.9 72.4 2.70 2265.25 31.3 28. 19.9 75.3 2.68 2265.55 36.0 167. 40.2 53.9 2.70 2266.05 39.4 573. 60.0 30.5 2.71 2266.55 29.8 6.3 5.0 93.6 2.69 2267.05 31.7 12. 8.0 88.1 2.71 2267.55 30.7 10. 6.6 90.3 2.70 2268.05 32.1 28. 16.5 77.7 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[t¥ ............... psi PERCENT md. OIL WATER 1000 39.0 460 45.8 54.9 1000 37.2 177 51.0 49.4 1000 36.0 201 45.8 55.3 1000 36.7 98 48.1 52.5 1000 37.0 261 46.3 49.4 1000 35.3 98 49.5 52.2 SAMPLE FAILED 1000 31.7 24 29.3 75.8 1000 31.2 21 25.8 81.7 SAMPLE FAILED 1000 33.4 126 44.9 60.3 1000 37.7 359 64.6 32.9 1000 28.3 3.8 5.4 100.6 1000 29.5 5.5 8.9 97.8 1000 29.3 4.6 7.0 96.7 1000 29.8 20 18.4 86.6 DESCRIPTION Sd; s[t-vfsd, Sd; s[t-vfsd, Sd; s[t-vfsd, Sd; s[t-vfsd, Sd; s[t-vfsd, Sd; s[t-vfsd, Sit; c[y-s[t, Sit; c[y-s[t, Sit; c[y-s[t, Sit; c[y-s[t, Sd; s[t-vfsd, Sd; s[t-vfsd, Cry; c[y-s[t, Cly; c[y-s[t, Cly; cLy-sLt, Slt; c[y-slt, prty cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd 2268.55 33.3 28. 18.4 76.8 2.70 1000 30.3 19 21.1 88.3 Slt; cly-slt, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 14 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 6 (CONTINUED) (2243 - 2274) : REC. (2244.65 - 2276.2) 2269.05 35.7 150. ** 33.4 60.8 2.71 2269.55 33.4 147. 19.8 77.4 2.69 2270.05 39.4. 491. 51.3 41.7 2.70 2270.55 39.3 515. 56.6 37.3 2.71 2271.05 40.9 759. 60.4 32.9 2.72 2271.55 36.4 412. 39.1 54.8 2.72 2272.05 34.8 38. 22.1 72.4 2.71 2272.85 34.6 39. 23.3 72.2 2.74 2273.15 34.4 39. 17.6 76.8 2.71 2273.55 34.1 22. 7.3 87.1 2.70 2274.0 RUBBLED MATERIAL - NO SAMPLE 2275.0 RUBBLED MATERIAL - NO SAMPLE 2275.55 37.6 368. 37.3 55.6 2.70 2276.05 34.4 63. 23.0 70.4 2.70 CORE NO. 7 (2274 - 2303) : REC. (2276.2 - 2299.7) *2276.2 SECTION PRESERVED *2277.7 SECTION PRESERVED 2277.75 33.9 13. 0.0 95.7 2.73 2278.05 35.4 17. 0.0 97.7 2.75 2278.6 33.6 5.5 0.7 98.5 2.72 *PRESERVED @ WELLSITE at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL WATER 1000 32.7 100'* 38.1 69.4 1000 30.8 61 22.3 87.1 1000 36.5 358 58.1 47.2 1000 36.4 357 64.1 42.3 1000 37.7 489 68.9 37.6 1000 34.2 236 43.2 60.5 1000 33.5 19 23.3 76.4 1000 33.2 19 24.8 76.7 1000 32.9 14 18.9 82.1 1000 32.4 8.9 7.9 94.2 1000 35.3 140 41.0 61.2 1000 31.3 24 26.5 81.2 1000 32.5 2.5 0.0 101.8 1000 33.2 2.6 0.0 107.5 1000 32.6 2.0 0.8 103.0 DESCRIPTION Sit; c[y-s[t, mod cmtd cry-sit; cly-stt; mod cmtd Sd; stt-vfsd, mod cmtd Sd; slt-vfsd, mod cmtd Sd; slt-vfsd, mod cmtd Sd; s[t-vfsd, mod cmtd Slt; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; slt-vfsd, mod cmtd SLt; sLt-vfsd, mod cmtd cry; cry-sit, mod cmtd Cly; cty-sLt, mod cmtd Cly; c[y-s[t, mod cmtd COMPANY Arco Ataska PETROLEUH TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 15 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL MATER gm/cc CORE NO. 7 (CONTINUED) (2274 - 2303) : REC. (2276.2 - 2299.7) 2279.05 32.1 6.0 0.0 97.3 2.78 2279.55 32.8 0.8 0.0 98.1 2.73 2280.05 33.8 1.0 ** 0.0 98.4 2.72 2280.6 33.0 2.3 0.0 99.6 2.76 2281.05 31.6 1.7 0.0 98.6 2.74 2281.55 31.1 0.9 0.0 98.9 2.74 2282.05 31.9 1.7 0.0 98.4 2.73 2282.55 31.1 1.3 0.0 97.7 2.74 2283.05 31.1 2.0 0.0 97.6 2.72 2283.5 30.6 1.1 0.0 98.4 2.72 2284.05 31.9 0.8 0.0 98.2 2.74 2284.5 31.1 0.7 0.0 99.8 2.72 2285.05 31.1 6.3 0.0 99.6 2.71 2285.5 30.2 1.1 0.0 96.6 2.70 2286.05 33.3 11. 0.0 99.3 2.71 2286.6 32.9 9.0 0.0 96.9 2.71 2287.15 32.5 47. 0.0 96.6 2.70 2287.6 31.7 16. 0.0 98.6 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi try ............... ps i PERCENT md. O! L WATER 1000 31.6 1.2 0.0 99.6 1000 32.3 0.3 0.0 100.0 1000 32.8 0.5** 0.0 103.3 1000 31.9 0.8 0.0 104.7 1000 31.2 0.5 0.0 100.4 1000 30.6 0.5 0.0 100.9 1000 31.0 0.7 0.0 102.8 1000 29.0 0.9 0.0 108.0 1000 30.5 0.7 0.0 100.0 1000 29.4 0.5 0.0 104.2 1000 31.2 0.5 0.0 101.5 1000 29.6 0.4 0.0 107.6 1000 29.1 2.2 0.0 110.0 1000 28.5 0.5 0.0 104.8 1000 29.9 7.1 0.0 116.3 1000 29.7 3.4 0.0 112.1 1000 30.7 8.0 0.0 105.0 1000 29.9 3.4 0.0 107.3 DESCRIPTION cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; cry-sit, mod cmtd C[y; cry-sit, mod cmtd Cry; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-stt~ mod cmtd Cry; cry-sit, mod cmtd cry; cty-stt, mod cmtd Cty; cry-sit, mod cmtd Cly; c[y-stt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cly-s[t, mod cmtd C[y-S[t; c[y-s[t, mod cmtd Cly; cry-sit, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 16 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 7 (CONTINUED) (2274 - 2303) : REC. (2276.2 - 2299.7) 2288.1 32.3 5.0 ** 0.0 97.6 2.69 2288.65 30.0 5.6 0.0 98.1 2.69 2289.1 29.3 5.0 ** 0.0 98.9 2.70 2289.6 31.3 3.5 0.0 97.7 2.75 2290.05 32.3 6.2 0.0 96.7 2.72 2290.55 30.1 0.7 0.0 97.5 2.73 2291.05 31.9 5.3 0.0 98.4 2.75 2291.55 34.3 5.0 ** 0.0 87.9 2.74 2292.05 30.2 4.2 0.0 99.0 2.73 2292.5 29.2 0.8 O. 0 98.8 2.72 2293.05 29.2 0.7 2.5 96.1 2.74 2293.55 30.2 2.4 0.0 96.4 2.72 2294.05 33.5 2.0 ** 0.0 98.1 2.72 2294.55 30.8 2.3 0.0 98.3 2.75 2295.05 29.9 0.4 0.0 98.1 2.72 2295.5 31.1 0.9 0.0 98.9 2.73 2296.05 30.2 2.0 0.0 98.5 2.71 2296.55 29.2 0.3 0.0 98.6 2~72 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 29.6 3.0** 0.0 110.4 1000 29.4 2.9 0.0 101.2 1000 28.3 1.0'* 0.0 104.0 1000 30.6 1.3 0.0 100.9 1000 31.2 2.1 0.0 102.0 1000 28.7 0.4 0.0 104.5 1000 31.4 1.6 0.0 100.9 1000 32.8 3.0** 0.0 93.6 1000 29.5 0.8 0.0 102.4 1000 27.9 0.3 0.0 105.7 1000 27.6 0.4 2.7 104.2 1000 28.7 0.6 0.0 103.7 1000 28.6 1.0'* 0.0 123.6 1000 29.2 0.5 0.0 105.7 1000 27.1 0.3 0.0 112.6 1000 29.2 0.4 0.0 108.2 1000 29.4 1.0 0.0 102.2 1000 27.7 0.2 0.0 106.2 DESCRIPTION Cly; cLy-sLt, mod cmtd Cly; c[y-slt, mod cmtd Cly; cty-sLt, mod cmtd Cky; c[y-$lt, mod cmtd Cly; c[y-s[t, mod cmtd Cry; c[y-s[t, mod cmtd CLy; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd CLy; cry-sit, mod cmtd CLy; c[y-s[t, mod cmtd Cly; cly-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd Cly; cly-slt, mod cmtd Cly; c[y-$[t, mod cmtd Cly; cly-slt, mod cmtd C[y; cly-slt, mod cmtd Cly; cly-slt, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska ,, PETROLEUM TESTING SERVICE, INC, CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 17 FILE No. 70025 DATE September 26, 1986 ARCHIMEDES Air DEPTH POROSITY Permeabitity FEET PERCENT md. SATURATION APPARENT % PORE SPACE SAND GRAIN .............. DENSITY OIL WATER gm/cc CORE NO. 7 (CONTINUED) (2274 - 2303) : REC. (2276.2 - 2299.7) 2297.05 31.7 4.5 0.0 95.8 2.73 2297.5 29.2 0.9 0.0 97.4 2.72 2298.0 37.9 137. * 0.0 91.6 2.72 2298.55 28.5 0.4 0.0 97.8 2.71 2299.05 28.6 0.9 0.0 99.4 2.71 2299.5 31.5 2.9 0.0 98.5 2.74 CORE NO. 8 (2303 - 2334) : REC. (2299.7 - 2330.4) 2300.05 31.7 2.2 0.0 97.4 2300.55 30.7 0.9 0.0 99.0 2301.05 29.8 0.4 0.0 99.3 2301.55 30.1 1.0 0.0 97.9 2301.95 30.0 0.5 0.0 96.5 2302.5 30.0 2.3 0.0 98.7 2302.55 SECTION PRESERVED 2303.55 SECTION PRESERVED 2303.6 30.0 0.8 0.0 98.3 2304.05 30.7 1.0 ** 0.0 98.5 2.71 2.73 2.72 2.72 2.72 2.72 2.72 2.71 2304.55 29.7 1.4 0.0 97.7 2.71 2305.05 31.6 1.4 0.0 98.4 2.77 * FRACTURED at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 30.9 3.4 0.0 99.5 1000 27.9 0.3 0.0 104.0 1000 34.0 59 * 0.0 108.4 1000 28.3 0.1 0.0 99.0 1000 27.5 0.4 0.0 105.3 1000 30.1 O.T 0.0 105.1 1000 31.0 1.0 0.0 100.9 1000 30.2 0.2 0.0 101.4 1000 29.4 0.1 0.0 101.4 1000 29.7 0.2 0.0 100.0 1000 29.8 0.1 0.0 97.2 1000 29.6 0.8 0.0 100.2 1000 29.8 0.2 0.0 99.1 1000 30.0 0.5** 0.0 101.8 1000 29.5 0.5 0.0 98.6 1000 31.3 0.3 0.0 100.0 DESCRIPTION Cry; cty-stt, mod cmtd Cty; cty-stt, mod cmtd Stt; cty-stt, prty cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd cry; cry-sit, mod cmtd ely; cty-sLt, mod cmtd CLy; cty-stt, mod cmtd Cry; cty-stt, mod cmtd cry; cry-sit, mod cmtd cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd cry; cry-sit, mod cmtd Cly; cly-slt, mod cmtd Cly; cry-sit, hvymin, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 18 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 8 (CONTINUED) (2303 - 2334) : REC. (2299.7 - 2330.4) 2305.5 30.0 1.6 0.0 99.2 2.71 2306.05 29.3 1.3 0.0 97.7 2.70 2306.55 30.7 2.8 0.0 99.4 2.71 2307.05 34.2 1.5 ** 0.0 95.4 2.73 2307.55 30.3 1.1 0.0 99.2 2.73 2308.05 29.3 4.1 0.0 99.2 2.73 2308.5 28.5 0.5 0.0 98.4 2.70 2309.05 30.3 4.5 0.0 97.0 2.70 2309.55 29.3 1.9 0.0 98.0 2.70 2310.05 30.9 2.9 0.0 95.9 2.70 2310.55 29.0 7.4 0.0 99.4 2.69 2311.05 28.3 2.0 0.0 98.0 2.69 2311.5 27.7 6.9 0.0 98.5 2.68 2312.05 30.7 7.3 0.0 96.0 2.69 2312.55 30.7 2.3 0.0 97.0 2.69 2313.05 30.7 3.1 0.0 97.7 2.69 2313.55 29.9 47. 5.9 93.8 2.67 2314.1 39.5 3910. 21.5 52.9 2'.68 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL WATER 1000 29.4 0.4 0.0 102.3 1000 28.4 0.5 0.0 102.0 1000 29.8 0.5 0.0 103.5 1000 30.9 1.0'* 0.0 111.0 1000 28.8 0.3 0.0 106.5 1000 28.2 1.2 0.0 104.6 1000 26.6 0.2 0.0 108.0 1000 29.3 1.3 0.0 101.5 1000 28.0 0.5 0.0 104.4 1000 29.4 1.4 0.0 102.8 1000 27.6 2.6 0.0 106.8 1000 27.1 0.8 0.0 104.1 1000 26.9 2.6 0.0 102.8 1000 29.7 1.5 0.0 101.0 1000 29.6 0.9 0.0 102.4 1000 29.6 1.1 0.0 103.0 1000 28.4 10 6.4 100.6 1000 36.0 3190 25.0 61.5 DESCRIPTION CLy; cLy-sLt, mod cmtd Cly; cLy-sLt, mod cmtd Cly; cLy-sLt, mod cmtd Cly; cLy-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd CLy; cty-stt, mod cmtd Cly; cLy-sLt, mod cmtd CLy; cLy-sLt, mod cmtd C[y; c[y-sLt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cty-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sd; s[t-vfsd, pr[y cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 19 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 8 (CONTINUED) (2303 - 2334) : REC. (2299.7 - 2330.4) '2314.45 SECTION PRESERVED '2316.45 SECTION PRESERVED 2316.5 . 43.9 1660. 61.5 21.7 2.70 2317.05 39.0 799. 68.9 28.0 2.70 2317.55 40.8 1220. 71.9 24.7 2.69 2318.05 40.7 1110. 76.5 22.6 2.70 2318.45 SECTION PRESERVED 2319.45 SECTION PRESERVED 2319.5 44.3 1570. 67.9 28.3 2.68 2320.05 41.3 1150. 76.5 21.1 2.69 2320.55 48.6 1610. 48.2 47.9 2.69 2321.05 46.1 1590. 56.9 41,1 2.69 2321.55 44.3 1650. 63.4 34.7 2.68 2322.05 36.7 236. 9.4 89.6 2.90 2322.45 38.9 525. 30.5 61.3 2.75 2323.05 41.8 1130. 71.9 25.4 2.70 2323.7 41.6 608. 68.7 24.7 2.70 2324.05 40.1 470. 69.9 28.6 2.70 2324.65 38.6 326. 36.4 52.3 2.67 2325.15 42.4 1370. 22.5 68.4 2.68 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 37.8 1030 79.0 27.8 1000 35.9 587 78.9 32.0 1000 37.4 889 82.7 28.4 1000 37.0 853 89.3 26.3 1000 37.8 1100 88.8 37.0 1000 37.7 787 89.3 24.6 1000 40.4 537 67.3 66.9 1000 39.4 768 74.9 54.1 1000 38.9 958 79.5 43.4 1000 34.7 10 10.2 97.8 1000 35.6 202 35.2 70.8 1000 37.8 807 84.9 30.0 1000 36.7 281 84.2 30.3 1000 36.8 248 80.5 32.9 1000 35.8 227 40.9 58.8 1000 38.2 856 26.8 81.4 DESCRIPTION Sd; vfsd-fsd, prty cmtd Sd; vfsd-fsd, prty cmtd Sd; vfsd-fsd, prty cmtd Sd; vfsd-fsd, pr[y cmtd Sd; vfsd-fsd, pr[y cmtd Sd; sit-lsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; sit-lsd, pr[y cmtd Md-sd; sit-lsd, hvy min, mod cmtd Sd; sit-lsd, mod cmtd Sd; vfsd-fsd, mod cmtd Sd; vfsd-fsd, mod cmtd Sd; vfsd-fsd, mod cmtd Sd; vfsd-fsd, mod cmtd Sd; vfsd-fsd, mod cmtd *PRESERVED @ WELLSITE ~ COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 20 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY PermeabJE)ty .............. DENSITY FEET PERCENT md. OIL NATER g~/cc CORE NO. 8 (CONTINUED) (2303 - 2334) : REC. (2299.7 - 2330.4) 2325.55 34.3 41. 0.0 93.7 2.71 2326.05 33.7 19. 0.0 99.0 2.72 2326.55 32.7 13. 0.0 96.9 2.73 2327.15 37.2 50. ** 40.2 51.4 2.70 2327.5 39.8 498. 49.8 40.4 2.69 2328.05 38.8 295. 44.1 49.3 2.70 2328.5 38.4 683. 66.3 29.3 2.68 2328.95 40.1 939. 63.5 28.7 2.68 2329.7 42.9 1660. 56.2 31.7 2.68 2330.2 26.8 14. 17.3 77.8 2.72 CORE NO. 9 (2334 - 2364) : REC. (2330.4 - 2359.75) 2330.55 32.5 57. 2.6 93.8 2331.05 33.1 37. 5.0 91.1 2331.45 33.1 30. ** 0.0 95.2 2332.05 34.8 200. ** 17.0 82.8 2332.55 36.0 316. 23.5 76.2 2333.05 34.7 27. 10.8 88.8 2333.55 34.5 25. ** 0.6 97.6 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY PermeabJEty ............... psi PERCENT md. OIL NATER 1000 32.2 9.3 0.0 103.0 1000 31.9 6.4 0.0 107.5 1000 31.5 4.8 0.0 102.3 1000 33.7 10'* 46.9 59.9 1000 35.9 257 58.7 47.6 1000 36.1 181 49.5 55.4 1000 35.3 540 76.0 33.6 1000 36.5 691 73.9 33.4 1000 36.8 804 72.6 41.0 1000 25.1 6.6 18.8 84.8 2.72 1000 31.1 5.3 2.8 100.3 2.74 1000 31.8 4.9 5.3 96.3 2.75 1000 32.6 18 * 0.0 97.1 2.71 1000 33.2 26 * 18.3 89.0 2'.71 1000 33.9 111 25.8 83.6 2.71 1000 33.6 13 11.3 93.2 2.73 SAMPLE FAILED DESCRIPTION SEt; set, mod cmtd SEt; set, mod cmtd SEt; set, mod cmtd SEt; sEt-fsd, mod cmtd Sd; sEt-fsd, mod cmtd Sd; sEt-lsd, mod cmtd Sd; stt-fsd, mod cmtd Sd; s[t-fsd, mod cmtd Sd; stt-fsd, mod cmtd Cty-stt; c[y-s[t, mod cmtd Cly; cly-slt, mod cmtd C[y; cly-slt, mod cmtd CLy; c[y-s[t~ mod cmtd SEt; c[y-s[t, prty cmtd C[y-sd; cty-vfsd, mod cmtd C[y-s[t; c[y-slt, mod cmtd C[y; c[y-s[t, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL ~est Sak 2T-9 PAGE 21 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL ~ATER gm/cc CORE NO. 9 (CONTINUED) (2334 - 2364) : REC. (2330.4 - 2359.75) 2334.05 33.4 6.0 0.0 96.4 2.70 2334.55 32.7 5.0 ** 15.6 78.6 2.71 2335.05 29.1 5.0 ** 18.0 80.0 2.70 2335.55 34.9 5.0 ** 11.7 84.3 2.71 2336.05 30.6 5.3 0.0 98.7 2.73 2336.55 33.6 5.4 0.0 92.4 2.72 2337.05 35.3 3.0 ** 0.0 92.0 2.72 2337.55 32.4 3.0 ** 0.0 94.0 2.73 2338.05 33.1 3.0 ** 0.0 90.7 2.74 2338.55 32.4 2.9 0.0 94.9 2.73 2339.05 33.6 1.6 0.0 93.4 2.73 2339.55 33.3 1.6 0.0 95.1 2.74 2340.05 35.7 1.5 ** 0.0 92.1 2.70 2340.55 34.1 1.5 ** 0.0 97.3 2.71 2341.05 31.8 1.6 0.4 91.7 2.72 2341.55 31.3 2.0 0.0 92.4 2.71 2342.05 33.2 1.8 0.0 91.7 2.72 2342.55 31.7 1.7 0.0 93.6 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL ~ATER 1000 32.4 1.0 0.0 100.6 1000 31.3 1.0'* 16.7 83.8 1000 27.5 1.0'* 19.4 86.4 1000 31.5 1.5'* 13.6 98.0 1000 29.8 2.0 0.0 102.4 1000 30.0 0.7 0.0 109.0 1000 30.6 1.0'* 0.0 113.7 1000 27.4 1.0'* 0.0 119.8 1000 30.5 1.0'* 0.0 102.3 1000 30.3 0.5 0.0 104.7 1000 30.7 0.3 0.0 106.6 1000 31.3 0.4 0.0 104.4 1000 28.6 0.5** 0.0 127.3 1000 32.0 1.2 * 0.0 106.9 1000 29.2 0.7 0.4 103.9 1000 28.4 0.8 0.0 106.1 1000 27.4 0.6 0.0 120.9 1000 30.2 0.8 0.0 100.2 DESCRIPTION C[y; c[y-stt, mod cmtd Cry-sit; cry-sit, mod cmtd Cry-sit; cry-sit, mod cmtd C[y-stt; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cty; cLy-stt, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd * FRACTURED ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE~ INC. CORE ANALYSIS ~ELL ~est Sak 27-9 PAGE 22 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 9 (CONTINUED) (2334 - 2364) : REC. (2330.4 - 2359.75) 2343.05 32.1 1.6 0.0 92.9 2.72 2343.55 27.7 6.1 0.0 93.4 2.86 2344.05 31.2 1.2 0.0 95.6 2.71, 2344.55 33.2 1.5 ** 0.0 92.0 2.72 2345.05 31.8 1.2 0.0 94.2 2.71 2345.55 32.8 1.3 1.8 90.4 2.73 2346.05 33.4 3.7 0.4 94.6 2.85 2346.5 32.0 1.5 ** 0.0 93.1 2.72 2347.05 33.4 1.5 ** 0.0 94.4 2.73 2347.55 33.7 1.5 ** 0.7 89.1 2.73 2348.05 32.7 2.0 0.6 93.9 2.80 2348.55 31.4 1.9 0.0 93.6 2.71 2349.05 32.9 2.0 ** 2.5 89.1 2.70 2349.5 32.3 2.0 ** 0.0 93.6 2.72 2350.05 34.0 4.? 0.0 93.7 2.71 2350.55 33.5 2.0 ** 0.0 94.3 2.71 2351.05 29.7 1.3 0.8 92.1 2.68 2351.55 29.8 2.0 ** 4.6 86.3 2'.67 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 29.9 0.4 0.0 103.4 1000 23.2 0.5 0.0 118.1 1000 29.8 0.7 0.0 102.3 1000 30.4 0.5** 0.0 104.7 1000 30.0 0.4 0.0 102.6 1000 30.5 0.6 2.0 100.9 1000 30.0 1.2 0.4 111.0 1000 26.4 1.0 * 0.0 121.8 1000 31.4 1.0'* 0.0 103.2 1000 27.9 1.3 * 0.9 i16.8 1000 28.7 0.8 0.7 113.4 1000 26.9 0.7 0.0 116.5 1000 28.5 0.9 * 3.1 109.4 1000 28.9 0.9 * 0.0 109.9 1000 28.9 1.2 0.0 118.8 1000 30.1 1.7 * 0.0 110.7 1000 26.3 0.6 1.0 108.8 1000 28.3 0.9 * 5.0 92.7 DESCRIPTION cry; cty-stt, mod cmtd Cty; cty-stt, hvymin, mod cmtd cty; c[y-stt, mod cmtd C[y; cry-sit, mod cmtd cry; c[y-stt, mod cmtd C[y; cry-sit, mod cmtd cry; cty-stt, hvymin, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, hvymin, mod cmtd Cry; cry-sit, mod cmtd C[y; cty-s[t, mod cmtd cry; c[y-stt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd cry; cry-sit, mod cmtd C[y; cry-sit, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 2T-9 PAGE 23 FiLE No. 70025 DATE September 26, 1986 ARCHIMEDES Air DEPTH POROSITY Permeabitity FEET PERCENT mci. SATURAT I ON APPARENT % PORE SPACE SAND GRAIN .............. DENSITY O! L WATER g ,m/cc CORE NO. 9 (CONTINUED) (2334 - 2364) : REC. (2330.4 - 2359.75) 2352.05 30.6 1.7 2.7 90.7 2.69 2352.55 30.8 1.5 2.3 91.2 2.70 2353.05 31.3 2.0 ** 2.0 89.6 2.69 2353.55 39.3 100. ** 29.3 56.8 2.71 2354.05 32.5 3.9 21.4 68.2 2.71 2354.55 32.7 6.0 16.4 76.6 2.73 2355.05 31.5 3.2 13.4 81.5 2.71 2355.55 31.1 2.8 23.8 73.2 2.70 2356.05 30.5 13. 18.8 75.1 2.70 2356.55 32.3 1.3 18.1 78.9 2.73 2357.05 31.7 6.1 20.4 73.9 2.71 2357.25 SECTION PRESERVED 2358.15 SECTION PRESERVED 2358.5 RUBBLED MATERIAL - NO SAMPLE 2359.05 45.3 1440. 52.3 24.3 2.70 2359.6 44.2 1410. 57.6 21.4 2.70 CORE NO. 10 (2364 - 2394) : REC. (2359.75 - 2390) 2360.05 36.1 78. 24.6 72.4 2.72 2360.55 37.5 147. 40.7 49.4 2.72 at SIMULATED RESERVOIR STRESS SIMULATED .... .~ .................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi [ty ............... ps i PERCENT md. OIL WATER 1000 28.4 0.5 2.9 100.6 1000 27.8 0.4 2.6 105.4 1000 29.3 0.5** 2.3 98.8 1000 32.9 50** 38.8 75.1 1000 29.6 1.3 24.6 78.2 1000 31.5 1.6 17.8 83.2 1000 29.8 1.0 14.5 88.4 1000 30.6 1.3 24.4 75.0 1000 29.3 3.8 20.0 79.7 1000 30.8 0.4 20.3 88.7 1000 30.4 '1.7 21.7 78.6 1000 36.1 698 76.8 35.6 1000 36.8 699 78.3 29.0 1000 32.0 18 29.6 87.0 1000 35.0 65 45.4 55.0 DESCRIPT[ON C[y; c[y-s[t, mod cmtd Cly; c[y-s[t, mod cmtd CLy; cLy-sLt, mod cmtd Sd-c[y; c[y-vfsd, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cty-s[t, mod cmtd CLy; cLy-sLt, mod cmtd CLy; c[y-sLt, mod cmtd C[y; cly-s[t, mod cmtd cry; cry-sit, mod cmtd Sd; stt-fsd, prty cmtd Sd; s[t-fsd, prty cmtd Sit; cty-vfsd, mod cmtd Sit; cty-vfsd, mod cmtd ** FRACTURED,'ESTIMATED AIR PERMEABILITY COMPANY Arco ALaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 27-9 PAGE 24 FILE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY PermeabiLity .............. DENSITY FEET PERCENT md. OIL tiATER gm/cc CORE NO. 10 (CONTINUED) (2364 - 2394) : REC. (2359.75 - 2390) 2361.05 41.7 1080. 51.9 33.7 2.71 2361.45 32.1 10. ** 1.1 96.8 2.73 2362.05 40.9 1240. 46.3 35.6 2.70 2362.55 44.0 1780. 49.4 36.3 2.70 2363.05 44.9 1150. 50.2 36.3 2.68 2363.55 41.9 1000. ** 18.1 65.9 2.70 2364.05 40.4 1010. 36.9 44.4 2.71 2364'55 38.T 276. 27.8 59.3 2.70 2365.05 43.7 1000. ** 47.1 44.1 2.70 2365.55 32.1 139. * 17.4 79.5 2.70 2366.05 34.9 15. 14.6 71.2 2.73 2366.55 36.3 20. 15.8 67.0 2.74 2367.05 32.7 38. 15.6 80.4 2.73 2367.55 34.6 42. 23.8 69.4 2.71 2368.05 44.5 1520. 46.8 35.1 2.72 2368.55 34.6 6.4 10.6 84.0 2.72 2369.05 35.5 64. 25.8 66.0 2.71 2369.55 35.6 42. 25.1 68.9 ~.71 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OiL WATER 1000 39.6 993 56.6 36.7 1000 31.8 3.2 * 1.2 99.8 1000 38.0 685 52.3 40.2 1000 39.6 837 59.4 43.6 1000 37.2 732 69.1 50.0 1000 37.5 557 * 21.8 79.4 1000 36.7 250 43.2 52.0 1000 35.5 54 31.0 66.1 1000 37.6 419 * 60.7 56.9 1000 31.5 36 * 17.9 82.0 1000 32.2 1.9 16.5 80.6 1000 32.8 2.7 18.4 78.1 1000 31.2 6.4 16.7 86.2 1000 32.8 11 25.8 75.1 1000 38.0 586 61.2 45.9 1000 32.8 1.4 11.5 91.1 1000 33.5 18 28.2 72.2 1000 33.6 12 27.3 75.0 DESCRIPTION Sd; stt-vfsd, mod cmtd Cty; cry-sit, mod cmtd Sd; sLt-vfsd, prty cmtd Sd; s[t-vfsd, prty cmtd Sd; stt-vfsd, pr[y cmtd Sd-cry; cty-vfsd, mod cmtd Sd; s[t-vfsd, mod cmtd Sit; cty-vfsd, mod cmtd Sd; s[t-vfsd, mod cmtd Sd-c[st; cry-sit, foss, mod cmtd Cty; cry-sit, mod cmtd Sit-cry; cry-sit, mod cmtd Cty-sLt; cty-stt, mod cmtd C[y-stt; c[y-sLt, mod cmtd Sd; stt-vfsd, prty cmtd Cry; cty-s[t, ~ cmtd S[t-c[y; c[y-s[t, mod cmtd Sit-cry; c[y-s[t, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AiR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 25 FILE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi [ it¥ .............. DENSITY FEET PERCENT md. OIL NATER gm/cc CORE NO. 10 (CONTINUED) (2364 - 2394) : REC. (2359.75 - 2390) 2370.05 34.0 28. 19.8 75.8 2.72 2370.55 36.7 71. 30.2 60.2 2.71 2371.05 35.4 39. 22.4 72.2 2.72 2371.55 31.9 2.4 12.5 85.6 2.70 2372.05 33.0 1.8 3.5 91.1 2.70 2372.55 34.1 12. 16.3 77.0 2.71 2373.05 34.0 5.0 ** 21.6 72.4 2.71 2373.55 31.9 3.6 13.5 83.3 2.68 2374.05 32.1 2.0 ** 18.8 78.5 2.69 2374.55 31.2 1.9 8.4 90.8 2.69 2375.05 32.3 3.2 3.5 93.5 2.71 2375.55 31.8 7.2 5.3 92.5 2.70 2376.05 32.4 2.5 6.1 92.0 2.73 2376.55 33.3 2.0 ** 3.0 92.5 2.70 2377.05 33.2 2.1 0.0 98.6 2.69 2377.55 31.4 3.5 10.6 86.7 2.69 2378.05 31.5 11. 22.0 73.2 2.69 2378.55 31.6 23. 18.8 73.2 2~69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION STRESS POROSITY Permeabilty ............... psi PERCENT md. OIL NATER 1000 32.2 5.5 21.5 82.2 1000 34.3 21 33.5 66.9 1000 33.3 15 24.5 79.1 1000 30.8 0.9 13.2 90.3 1000 31.2 0.5 3.8 99.1 1000 32.7 3.0 17.3 81.7 1000 32.8 2.0** 22.8 76.5 1000 31.4 1.3 13.8 85.3 1000 31.3 1.0'* 19.5 81.4 1000 29.6 0.7 9.1 98.1 1000 30.9 0.9 3.8 99.8 1000 30.9 1.2 5.6 96.8 1000 30.7 0.7 6.6 99.8 1000 31.5 0.5** 3.2 100.4 1000 31.4 0.4 0.0 107.1 1000 30.0 1.2 11.3 92.4 1000 30.1 3.4 23.5 78.3 1000. 30.2 7.2 20.0 77.8 DESCRIPTION Cry; cry-sit, mod cmtd Sit; cry-sit, mod cmtd CLy-stt; cty-stt, mod cmtd Cry; cty-stt, mod cmtd cry; cry-sit, mod cmtd cry; cty-stt, mod cmtd CLy; cly-stt, mod cmtd cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd CIy; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cry; c[y-stt, mod cmtd cry; cty-slt, mod cmtd Cry; cty-stt, mod cmtd Cry-sit; cry-sit, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUH TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 2T-9 PAGE 26 FILE No. 70025 DATE September 26, 1985 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabitity .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 10 (CONTINUED) (2364 - 2394) : REC. (2359.75 - 2390) 2379.05 32.3 20. ** 10.6 83.5 2.71 2379.55 33.2 20. ** 18.0 69.1 2.70 2380.05 36.3 113. 28.7 60.3 2.68 2380.55 37.4 100. ** 21.0 72.8 2.69 2381.05 28.6 1.2 16.3 82.6 2.68 2381.55 27.5 0.7 7.1 91.4 2.67 2382.05 32.1 124. 27.9 57.5 2.69 2382~55 42.2 643. 29.5 56.6 2.70 2383.05 34.2 48. 16.7 78.4 2.72 2383.55 4.9 <0.05 0.0 98.9 2.72 2384.05 45.6 2050. 51.6 36.3 2.68 2384.45 33.5 240. 22.5 68.5 2.71 2385.0 40.9 1500. ** 31.0 62.2 2.70 2385.2 SECTION PRESERVED 2386.2 SECTION PRESERVED 2386.55 42.3 1780. 67.4 27.4 2.67 2387.05 44.9 2250. 72.5 26.2 2.69 2387.6 40.4 602. 65.4 26.8 2~69 2388.0 RUBBLED MATERIAL ' NO SAMPLE 2389.0 RUBBLED MATERIAL ' NO SAMPLE at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL WATER 1000 30.2 5.0** 11.7 92.4 1000 29.6 5.0'* 21.3 81.8 1000 32.0 57 34.8 73.0 1000 34.0 50 * 24.4 84.5 1000 28.5 0.6 16.3 82.8 1000 25.3 0.4 8.0 102.5 1000 28.7 84 32.8 67.4 1000 34.9 167 40.1 76.8 1000 30.8 12 20.1 93.9 1000 4.8 c 0.05 0.0 100.0 1000 36.2 1130 76.2 53.6 1000 30.2 81 26.2 79.7 1000 31.2 116 * 47.4 95.0 1000 36.1 1320 87.4 35.6 1000 34.1 1470 114.3 41.4 1000 31.1 384 98.2 40.2 DESCRIPTION Cry-sit; cty-stt, mod cmtd Cry-sit; cry-sit, mod cmtd Sit-cry; cry-sit, mod cmtd Sit-cry; cty-stt, mod cmtd cry; cty-stt, mod cmtd Cty; cry-sit, mod cmtd Cry-sd; ct¥-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd Sit; c~y-stt, mod cmtd Ls; ueLt cmtd Sd; stt-vfsd, prty cmtd Sit; stt-vfsd, prty cmtd Sd; stt-vfsd, prty cmtd Sd; stt-vfsd, prty cmtd Sd; stt-vfsd, prty cmtd Sd; stt-vfsd, prty cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 27 FILE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROS I TY Permeabi [ i ty .............. DENS I TY FEET PERCENT md. Ol L WATER gm/cc CORE NO. 10 (CONTINUED) (2364 - 2394) : REC. (2359.75 - 2390) 2389.55 45.3 1620. 56.7 18.0 2.68 CORE NO. 11 (2394 - 2421) : REC. (2390 - 2405.9) 2390.1 44.3 2880. 29.0 61.4 2.70 2390.55 41.2 1120. 38.2 50.1 2.69 2391.05 37.0 5.0 ** 6.1 92.7 2.74 2391.55 40.6 1400. 52.2 38.6 2.70 2392.05 41.8 2580. ** 61.9 37.9 2.69 2392.55 34.4 102. 15.1 75.8 2.70 2393.05 36.7 114. 5.9 82.3 2.73 2393.55 31.4 3.5 5.7 92.9 2.74 2394.05 30.7 1.5 0.0 98.2 2.73 2394.55 32.0 2.2 7.2 89.9 2.70 2395.05 32.0 11. 14.7 80.4 2.73 2395.55 34.1 886. 38.9 43.1 2.72 2396.05 31.9 16. 26.0 60.2 2.75 2396.7 39.4 918. 52.9 25.9 2.63 2397.2 39.5 602. 57.0 21.2 2.68 2397.5 43.6 710. 48.3 24.7 2.68 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 40.6 1060 68.7 21.8 1000 33.5 732 45.9 97.0 1000 35.6 325 48.4 63.4 1000 27.6 3.0** 9.5 142.7 1000 36.2 539 ' 62.7 46.4 1000 30.0 806 * 103.6 63.5 1000 30.9 11 17.6 88.6 1000 33.0 12 7.0 96.7 1000 29.5 0.8 6.2 101.6 1000 29.5 0.1 0.0 103.9 1000 30.4 0.6 7.8 97.1 1000 29.9 2.5 16.2 88.6 1000 30.2 601 46.5 51.6 1000 29.5 2.9 29.1 67.4 1000 33.9 583 67.0 32.7 1000 34.8 361 69.6 26.0 1000 34.7 383 70.1 35.9 DESCRIPTION Sd; stt-vfsd, prty cmtd Sd; s[t-vfsd, prty cmtd Sd; s[t-vfsd, pr[y cmtd C[y; mod cmtd Sd; s[t-vfsd, pr[y cmtd Sd; s[t-vfsd, pr[y cmtd C[y-sd; cty-vfsd, pr[y cmtd. Cry-sd; c[y-vfsd, pr[y cmtd C[y; mod cmtd Cry; mod cmtd C[y; mod cmtd Cly; c[y-s[t, mod cmtd Sd; vf-fsd, pr[y cmtd Cly-sd; c[y-fsd, mod cmtd Sd; sit-lsd, pr[y cmtd Sd; sit-lsd, prly cmtd Sd; slt-fsd, pr[y cmtd * FRACTURED ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 27-9 PAGE 28 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL NATER g~/cc CORE NO. 11 (CONTINUED) (2394 - 2421) : REC. (2390 - 2405.9) 2398.05 44.9 938. 52.2 25.2 2.69 2398.45 42.9 1410. 46.2 31.1 2.67 2399.05 42.4 633. 48,8 17.5 2.66 2399.55 42.5 931. 50.8 26.5 2.68 2400.05 41.7 610. 48.2 20.5 2.66 2400.55 42.8 933. 35.2 36.4 2.68 2401.05 42.4 453. 49.6 27.1 2.69 2401~8 40.4 1030. 53.7 8.7 2.69 2402.05 46.0 1150. 46.7 21.4 2.68 2402.55 45.5 1040. 44.6 26.9 2.72 2403.05 45.8 1230. 44.6 24.7 2.71 2403.55 45.5 1160. 44.5 25.6 2.72 2404.05 49.0 1170. 35.4 24.7 2.73 2404.55 46.9 1020. 42.2 25.6 2.72 2405.05 45.2 1200. 44.8 25.4 2.72 2405.55 47.2 1420. 42.2 21.7 2.71 CORE NO. 12 (2421 - 2440) : REC. (2405.9 - 2433.65) 2406.05 34.0 9.5 4.3 90.2 2.71 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi [ty ............... ps J PERCENT md. OIL NATER 1000 38.0 637 69.4 33.5 1000 36.2 572 61.2 41.1 1000 31.8 417 77.3 27.7 1000 36.2 617 66.1 34.5 1000 32.9 329 70.3 29.9 1000 36.7 683 45.4 47.0 1000 36.1 299 6~.7 35.3 1000 35.7 505 65.5 10.6 1000 37.7 753 65.5 30.0 1000 39.3 663 57.5 34.7 1000 39.8 776 57.0 31.5 1000 39.4 683 57.0 32.8 1000 38.1 670 55.5 38.6 1000 36.9 540 63.7 38.6 1000 38.6 697 58.7 33.2 1000 35.7 825 67.9 35.0 1000 31.5 0.7 4.9 103.0 DESCRIPTION Sd; stt-fsd, prty cmtd Sd; stt-fsd, pr[y cmtd Sd; s[t-fsd, pr[y.cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; sit-lsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; stt-fsd, prty cmtd Sd; stt-fsd, prty cmtd Sd; sttTfsd, prty cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, pr[y cmtd Sd; s[t-fsd, prty cmtd C[y; cry-sit, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICEw INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 29 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER g~m/cc CORE NO. 12 (CONTINUED) (2421 - 2440) : REC. (2405.9 - 2433.65) 2406.55 36.4 114. 2.8 89.9 2.73 2407.05 34.0 26. 2.6 89.1 2.75 2407.55 36.0 93. 34.6 56.0 2.73 2408.35 36.2 81. 7.3 88.0 2.73 2408.75 38.5 5.0 ** 8.1 80.3 2.71 2409.05 34.4 5.0 ** 5.3 89.7 2.71 2409.55 41.5 5.0 ** 9.7 88.2 2.71 2410.05 42.5 5.0 ** 8.1 89.2 2.72 2410.55 43.9 5.0 ** 24.2 61.3 2.73 2411.45 35.3 5.0 ** 14.7 75.1 2.72 2411.75 34.2 4.4 4.6 92.4 2.71 2412.05 37.4 5.0 ** 19.3 72.8 2.71 2412.55 36.7 5.0 ** 23.3 63.8 2.71 2413.05 33.5 10. 4.8 90.1 2.71 2413.55 35.5 5.0 ** 10.3 84.6 2.71 2414.05 40.4 5.0 ** 23.0 70.4 2.70 2414.55 32.5 10. 0.0 97.3 2.71 2415.05 36.1 10. ** 4.4 88.1 2.70 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT mci. OIL WATER 1000 30.5 8.4 3.6 117.0 1000 30.2 2.9 3.1 , 106.3 1000 30.1 4.1 45.2 73.2 1000 31.6 5.8 8.9 108.0 1000 28.6 1.0'* 12.7 125.8 1000 29.7 3.1 * 6.6 111.3 1000 34.9 1.0'* 12.8 116.9 1000 34.6 1.0'* 11.3 124.6 1000 35.0 2.0** 35.1 88.8 1000 31.7 1.0'* 17.3 88.2 1000 32.2 0.8 5.0 101.0 1000 34.1 1.0'* 22.3 84.3 1000 31.5 1.0'* 29.3 80.6 1000 31.9 1.8 5.1 96.9 1000 33.1 3.8 * 11.4 93.8 1000 35.2 2.0** 28.7 87.8 1000 30.9 1.5 0.0 104.8 1000 31.3 8.0 * 5.5 108.9 DESCRIPTION Sit; cly-vfsd, prly cmtd Cty; cty-sLt, mod cmtd Sit; cty-vfsd, prty cmtd Cty-stt; cly-vfsd, mod cmtd Cry-sit; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry-sit; cly-slt, mod cmtd Cry-sit; c[y-stt, mod cmtd Cry-sit; cly-slt, mod cmtd Cty-stt; cly-s[t, mod cmtd Cry; cry-sit, mod cmtd Cty-stt; cry-sit, mod cmtd Cty-stt; cly-stt, mod cmtd Cry; cty-stt, mod cmtd Cty-sLt; cly-sLt, mod cmtd CLy-slt; cLy-sLt, mod cmtd Cry; cty-stt, mod cmtd Cty-stt; cty-slt, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY A~co Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL ~est Sak 2T-9 PAGE 30 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIHEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 12 (CONTINUED) (2421 - 2440) : REC. (2405.9 - 2433.65) 2415.55 32.8 8.5 3.5 95.0 2.71 2416.05 36.2 10. ** 10.2 86.2 2.72 2416.55 35.8 10. ** 8.8 87.2 2.71 2417.05 34.5 10. 1.7 97.2 2.72 2417.55 38.8 10. ** 18.9 68.0 2.69 2418.05 36.5 10. ** 4.8 87.5 2.69 2418.55 34.1 9.0 1.7 97.7 2.71 2419.05 31.8 2.0 0.9 98.9 2.72 2419.55 32.2 10. ** 1.6 96.7 2.71 2420.05 33.8 10. 0.0 97.7 2.71 2420.55 34.2 2.0 ** 0.0 96.1 2.73 2421.05 33.0 2.0 ** 0.7 96.0 2.73 2421.55 33.2 2.0 ** 2.5 94.9 2.74 2422.05 32.1 2.0 ** 1.7 97.6 2.72 2422.55 33.9 2.0 ** 4.7 87.8 2.73 2423.05 34.7 2.9 4.6 91.1 2.73 2423.55 32.6 2.0 4.9 90.0 2.72 2424.05 36.1 2.0 ** 15.3 73.7 2.72 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURAT ION % STRESS POROSITY Permeabi [ty ............... ps i PERCENT md. Ol L 14ATER 1000 31.2 1.4 3.7 102.1 1000 31.5 5.0** 12.6 106.5 1000 33.0 5.0** 10.0 98.4 1000. 32.2 1.5 1.9 107.7 1000 34.7 5.0** 22.6 81.3 1000 32.5 5.5 * 5.7 104.7 1000 32.2 1.9' 1.9 106.8 1000 27.9 0.6 1.1 119.5 1000 30.8 3.3 * 1.7 103.1 1000 30.6 2.0 0.0 113.1 1000 32.2 1.0'* 0.0 104.9 1000 31.6 1.8 * 0.8 102.4 1000 31.4 1.4 * 2.7 102.8 1000 30.0 0.8 * 1.9 107.5 1000 31.4 1.0'* 5.2 98.3 1000 30.5 1.1 5.5 109.9 1000 31.0 0.4 5.3 97.2 1000 33.6 1.0'* 17.0 82.0 DESCRIPTION Cry; cry-sit, mod cmtd Cry-sit; cry-sit, mod cmtd cry-sit; cry-sit, mod cmtd C[y; c[y-stt, mod cmtd C[y-s[t; c[y-s[t, mod cmtd C[y-s[t; cry-sit, mod cmtd CLy; cry-sit, mod cmtd C[y; cry-sit, mod cmtd C[y; cry-sit, mod cmtd C[y; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cLy-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; c[y-slt, mod cmtd C[y; c[y-s[t, mod cmtd C[y-stt; cly-s[t, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 31 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 12 (CONTINUED) (2421 - 2440) : REC. (2405.9 - 2433.65) 2424.55 35.3 2.0 ** 14.0 75.5 2.72 2425.05 35.0 2.0 ** 0.7 95.7 2.74 2425.55 34.3 2.0 ** 4.6 90.6 2.72 2426.05 33.5 5.0 ** 1.7 97.9 2.73 2426.55 31.8 5.0 ** 22.1 72.2 2.66 2427.05 32.2 6.5 0.0 97.1 2.71 2427.55 32.0 5.5 6.4 89.1 2.72 2428.05 30.7 1.5 9.9 80.0 2.70 2428.55 29.8 1.3 9.1 83.4 2.70 2429.05 31.6 3.0 ** 15.0 79.5 2.69 2429.55 35.7 3.0 ** 17.4 65.2 2.69 2430.05 34.2 2.9 1.6 97.2 2.75 2430.55 32.6 3.0 ** 7.3 90.4 2.71 2431.05 31.7 50. ** 28.4 62.6 2.69 2431.45 34.1 58. 26.5 60.8 2.64 2432.05 30.9 8.5 25.9 67.6 2.69 2432.55 31.8 16. 18.0 73.2 2.68 2433.05 33.2 32. 30.2 55.7 2'.69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 32.6 1.0'* 15.8 85.4 1000 33.4 0.3 * 0.7 102.7 1000 32.2 1.0'* 5.1 99.8 1000 30.1 1.0'* 1.9 114.4 1000 29.8 2.4 * 24.3 79.4 1000 30.9 1.3 0.0 103.2 1000 30.1 0.9 7.0 97.2 1000 30.5 0.4 10.0 80.8 1000 28.4 0.4 9.7 88.9 1000 30.3 1.0'* 16.0 84.5 1000 31.3 1.0'* 21.3 79.5 1000 32.2 0.6 1.7 106.4 1000 30.7 1.0'* 8.0 98.8 1000 29.3 24 * 31.8 70.1 1000 31.4 16 30.0 68.9 1000 29.3 2.5 27.9 72.7 1000 30.1 2.5 19.5 79.3 1000 30.6 5.9 34.0 62.6 DESCRIPTION Cry; cry-sit, mod cmtd Cry; cty-sLt, mod cmtd Cry;' cty-sLt, mod cmtd Cry; cLy-stt, mod cmtd cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cty; cty-stt, mod cmtd Cry; cty-stt, mod cmtd cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cty; c[y-stt, mod cmtd Cty; cty-stt, mod cmtd Cty-stt; cly-vfsd, mod cmtd Sit; cty-vfsd, mod cmtd C[y; cry-sit, mod cmtd Cry; c[y-vfsd, mod cmtd Cly-stt; c[y-vfsd, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 32 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabitity .............. DENSITY FEET PERCENT md. OiL NATER g~/cc CORE NO. 12 (CONTINUED) (2421 - 2440) : REC. (2405.9 - 2433.65) 2433.4 33.4 29. 30.8 54.1 2.68 CORE NO. 13 (2440 - 2440) : REC. (2433.65 - 2435.1) 2434.0 RUBBLED MATERIAL ' NO SAMPLE 2435.0 37.2 328. * 19.0 68.3 2.68 CORE NO. 14 (2440 - 2464) : REC. (2435.1 - 2465.6) 2435.4 34.3 10. ** 18.0 ?7.2 2.?0 2436.0 30.8 3.8 13.5 84.6 2.70 2436.55 32.5 5.3 7.2 91.4 2.72 2437.05 31.5 6.3 12.4 85.7 2.71 243T.55 34.9 4.4 0.0 98.8 2.74 2438.05 30.4 3.6 7.9 89.8 2.70 2438.55 30.0 4.3 4.4 94.9 2.69 2439.05 30.9 1.9 4.6 92.6 2.71 2439.55 36.3 77. 32.4 51.5 2.68 2440.05 31.6 4.0 0.0 99.5 2.70 2440.55 35.3 3.0 ** 16.0 73.4 2.69 2441.05 32.9 5.4 11.0 84.7 2.71 2441.55 29.4 8.0 24.3 70.1 2.61 * FRACTURED at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION STRESS POROSITY PermeabiLty ............... psi PERCENT md. OIL NATER 1000 30.8 7~2 34.8 61.0 1000 32.5 26 * 23.4 84.0 1000 31.2 1.1 * 20.7 88.8 1000 29.2 1.2 14.5 91.4 . 1000 27.5 1.3 9.2 116.0 1000 24.4 1.7 17.7 122.5 1000 33.1 1.6 0.0 107.3 1000 28.9 1.2 8.5 96.4 1000 29.1 1.1 4.6 98.9 1000 29.1 0.5 5.0 101.2 1000 33.7 44 36.3 57.7 1000 31.0 0.9 0.0 102.2 1000 32.6 1.0'* 18.0 82.8 1000 31.9 1.7 11.5 88.4 1000 28.3 1.8 25.6 74.0 DESCRIPTION Stt; cty-vfsd, mod cmtd Stt; stt-vfsd, prty cmtd Cry-sit; cry-sit, mod cmtd Cry; cry-sit, mod cmtd cry; cry-sit, mod cmtd C[y; c[y-stt, mod cmtd Cry-sit; cry-sit, mod cmtd Cry; c[y-stt, mod cmtd Cly; c[y-stt, mod cmtd C[y; cry-sit, mod cmtd Sit; c[y-vfsd, mod cmtd CIy; c[y-s[t, mod cmtd Cty-stt; cty-stt, mod cmtd CLy; cLy-stt, mod cmtd Cly; cly-slt, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 33 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIHEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeabttity .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 14 (CONTINUED) (2440 - 2464) : REC. (2435.1 - 2465.6) 2442.05 33.4 ' 2.3 1.9 94.7 2.70 2442.55 30.8 3.0 ** 5.3 88.8 2.67 2443.05 33.3 3.0 0.4 97.5 2.72 2443.55 32.8 5.6 9.2 87.2 2.69 2444.05 35.2 46. 26.2 63.8 2.68 2444.55 36.5 114. 24.6 59.2 2.69 2445.05 34.0 14. 10.3 86.8 2.70 2445.55 34.5 11. 9.3 88.5 2.71 2446.05 35.3 46. 13.1 80.1 2.71 2446.55 34.8 21. 14.4 80.4 2.70 2447.05 36.8 50. ** 32.6 55.2 2.68 2447.55 36.9 66. 21.5 67.5 2.70 2448.05 35.6 68. 26.9 61.8 2.69 2448.55 32.2 14. 8.8 87.4 2.69 2449.15 36.7 55. 16.2 74.7 2.68 2449.55 36.4 150. * 32.5 50.4 2.66 2450.05 30.6 43. 30.4 61.8 2.67 2450.55 -33.2 5.7 18.9 67.8 2'.71 at SIMULATED ' RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeabi[ty ............... psi .PERCENT md. OIL WATER 1000 31.7 0.7 2.0 102.5 1000 30.0 1.8 * 5.5 92.6 1000 30.9 0.5 0.5 109.1 1000 31.1 2.3 10.0 94.2 1000 32.7 14 29.3 71.2 1000 34.5 87 26.8 64.5 1000 32.8 4.7 10.9 91.5 1000 33.2 4.8 9.8 93.8 1000 33.3 9.8 14.4 87.8 1000 33.4 8.2 15.3 85.5 1000 34.5 20** 36.1 61.1 1000 34.7 27 23.8 74.5 1000 33.5 44 29.5 67.8 1000 31.2 5.6 9.2 91.6 1000 33.5 44 18.7 86.2 1000 33.0 98 * 37.7 58.5 1000 26.9 10 36.5 74.2 1000 30.7 2.4 21.2 76.1 DESCRIPTION Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd sit; c[y-stt, mod cmtd Sit; s[t-vfsd, mod cmtd C[y-stt; c[y-s[t, mod cmtd C[y-stt; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; cry-sit, mod cmtd Sit; stt-vfsd, mod cmtd Sit; s[t-vfsd, mod cmtd C[y-stt; c[y-stt, mod cmtd Sit; s[t-vfsd, mod cmtd sit; s[t-vfsd, mod cmtd Sit; c[y-stt, mod cmtd C[y; c[y-s[t, mod cmtd * FRACTURED ** FRACTUREDw ESTIMATED AIR PERMEABILITY , . COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 34 FILE No. 70025 DATE September 26, 1986 ARCHIMEDES Air DEPTH POROSITY Permeabitity FEET PERCENT md. SATURATION APPARENT ~ PORE SPACE SAND GRAIN .............. DENSITY OIL ~ATER gm/cc CORE NO. 14 (CONTINUED) (2440 - 2464) : REC. (2435.1 - 2465.6) 2451.05 31.9 3.? 22.7 64.0 2.68 2451.55 31.6 2.8 12.1 77.0 2.69 2452.05 33.4 3.0 ** 13.? 69.1 2.?0 2452.5 33.0 3.0 ** 8.1 82.5 2.72 2453.0 32.8 3.0 ** 13.6 ?4.2 2.?2 2453.5 33.8 4.7 15.9 71.3 2.72 2454.0 34.2 3.0 ** 21.2 59.5 2.74 2454.5 33.6 3.0 ** 13.8 68.0 2.70 2455.0 32.6 5.5 8.1 81.5 2.71 2455.55 32.0 1.9 23.5 68.7 2.71 2456.05 34.4 3.0 ** 9.5 T5.7 2.72 2456.55 31.? 2.8 1.5 92.9 2.70 2457.05 31.1 3.8 2.1 93.9 2.70 245?.55 31.9 3.0 ** 13.1 ?4.3 2.72 2458.05 32.1 4.0 3.5 87.2 2.70 2458.55 30.6 4.0 ** 8.5 82.2 2.?0 2459.05 31.2 4.7 1.7 93.3 2.69 2459.55 31.5 5.0 ** 0.2 94.1 2.69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY PermeabJ[ty ............... psi PERCENT md. OIL MATER 1000 29.2 1.9 25.8 ?2.8 1000 29.3 1.1 13.5 85.9 1000 30.1 1.0'* 16.0 80.6 1000 30.3 2.0** 9.2 93.6 1000 29.8 2.0** 15.? 85.4 1000 30.4 1.1 18.5 83.2 1000 29.8 1.0'* 25.9 72.7 1000 29.6 1.0'* 16.6 81.8 1000 29.8 1.6 9.2 93.0 1000 29.2 0.8 26.9 ?8.? 1000 30.8 1.0'* 11.3 87.2 1000 29.2 0.7 1.7 105.0 1000 28.6 0.8 2.4 105.9 1000 29.3 2.6 * 14.8 84.2 1000 29.3 0.9 4.0 99.4 1000 28.7 0.7 * 9.2 89.9 1000 29.1 1.2 1.9 103.0 1000 28.8 2.0 * 0.2 106.6 DESCRIPTION Cry; cry-sit, Cry; cLy-sLt~ Cry; c[y-stt, Cty; c[y-s[to C[y; c[y-s[t~ C[y; c[y-s[t, C[y; c[y-s[t, C[y; c[y-s[t, C[y; c[y-s[t~ C[y; c[y-s[t~ Cry; cry-sit, Cry; cty-stt~ Cry; cLy-sLt, Cry; cLy-sLt~ C[y; c[y-s[t, C[y; c[y-s[t, C[y; c[y-stt, C[y; c[y-s[t, mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd. mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd mod cmtd * FRACTURED ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco Alaska PETROLEUH TESTING SERVICE= INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 35 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 14 (CONTINUED) (2440 - 2464) : REC. (2435.1 - 2465.6) 2460.15 32.5 5.0 ** 4.6 85.2 2.70 2460.55 34.7 5.0 ** 4.4 82.5 2.71 2461.1 40.8 107. 31.2 37.1 2.70 2461.6 32.1 16. 17.2 79.6 2.79 2462.05 36.4 101. 15.9 66.9 2.72 246Z.4 41.9 559. 16.8 51.5 2.71 2463.05 41.5 238. 26.4 45.3 2.71 2463.6 42.1 258. 26.6 45.8 2.71 2464.2 45.9 506. 32.5 30.1 2.72 2464.5 RUBBLED MATERIAL - NO SAMPLE 2465.4 43.2 279. 35.6 31.4 2.70 CORE NO. 15 (2464 - 2494) : REC. (2465.6 - 2495.25) 2465.7 41.1 359. 25.8 43.9 2.71 2466.15 44.3 ~99. 27.2 46.2 2.73 2466.6 39.7 158. 21.3 55.9 2.72 2467.1 43.3 998. 29.6 51.4 2.71 2467.6 41.6 384. 32.1 43.3 2.71 2468.05 42.2 404. 36.4 37.1 2.71 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 29.7 1.0'* 5.2 97.0 1000 31.2 1.0'* 5.1 96.6 1000 34.1 41 41.6 49.4 1000 29.5 0.6 19.4 89.8 1000 29.7 18 21.5 90.7 1000 34.7 66 22.8 69.8 1000 35.9 120 33.5 57.5 1000 35.6 109 34.9 60.2 1000 37.8 293 45.4 42.0 1000 35.8 189 48.5 42.8 1000 33.7 58 35.5 60.4 1000 35.8 279 38.8 65.8 1000 34.8 45 26.3 69.0 1000 36.8 334 38.9 67.4 1000 36.5 178 39.8 53.6 1000 36.3 217 46.7 47.6 DESCRIPTION cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Sit; stt-vfsd, mod cmtd cry; cly-s[t, mod cmtd Sit; c[y-stt, mod cmtd Sit; cty-vfsd, prty cmtd Sit; cty-vfsd, pr[y cmtd sd; stt-vfsd~ mod cmtd Sd; s[t-vfsd, mod cmtd Sd; slt-vfsd, mod cmtd Sd; slt-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd Sd; s[t-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd ** FRACTURED,. ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE~ INC. CORE ANALYSIS ~ELL ~est Sak 2T-9 PAGE 36 FILE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi [ ity .............. DENSITY FEET PERCENT md. OIL WATER g ,m/cc CORE NO. 15 (CONTINUED) (2464 - 2494) : REC. (2465.6 - 2495.25) 2468.55 40.8 316. 19.6 49.4 2.71 2469.05 37.1 108. 42.6 31.8 2.67 2469.55 32.2 6.2 5.9 83.3 2.72 2470.05 39.0 200. ** 38.9 36.3 2.69 2470.55 40.0 246. 46.2 28.4 2.69 2471.05 34.2 497. 26.7 57.2 2.70 2471.55 34.3 10. ** 16.6 62.1 2.71 2472.0 33.3 16. 13,0 73.4 2.71 2472.5 30.9 1.0 0.5 94.6 2,71 2475.0 31.7 1.9 0.2 93.6 2.71 2473.55 32.8 6.0 5.8 84.7 2,71 2474.0 33.3 5.3 8,8 81.3 2.?2 2474.6 34.9 31. 14.3 65.5 2.71 2475.05 30.2 35. 28.3 52.6 2.67 2475.55 33.8 30. ** 15,4 70.3 2.72 2476.1 31.9 21. 15.5 67.0 2.67 2476.55 33.1 2.2 0.0 97.4 2.78 2477.1 28.5 29. * 29.8 51.5 2~63 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY PermeabJ[ty ............... psi PERCENT mci. OIL WATER 1000 32.8 55 27.6 69.5 1000 32.6 57 52.1 38.9 1000 28.7 2.1 6.9 98.2 1000 33.9 93 * '48.5 45.3 1000 35.0 169 57.2 35.2 1000 31.0 122 31.0 66.4 1000 29.3 1.0'* 20.9 78.4 1000 29.7 1.2 15.4 86.8 1000 29.4 0.3 0.6 101.3 1000 29.3 0.4 0.2 104.7 1000 30.3 1.0 6.5 95.0 1000 30.3 0.9 10.1 93.5 1000 30.8 4.1 17.2 78.8 1000 27.0 4.7 33.1 61.7 1000 31.0 6.0 * 17.5 79.9 1000 28.4 5.4 18.3 78.9 1000 29.6 0.5 0.0 114.4 1000 27.4 8.7 * 31.6 54.5 DESCRIPTION Sd; cty-vfsd, mod cmtd Sit; cty-vfsd, mod cmtd Cry; cry-sit, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, mod cmtd Sit; c[y-s[t, foss, mod cmtd C[y; c[y-s[t~ mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cty-sLt; c[y-stt, mod cmtd C[y-s[t; c[y-s[t~ mod cmtd C[y-s[t; c[y-stt, mod cmtd C[y-s[t; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd S[t; cLy-s[t, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco ALaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL Nest Sak 2T-9 PAGE 37 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY PermeabiLity .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 15 (CONTINUED) (2464 - 2494) : REC. (2465.6 - 2495.25) 2477.7 38.9 54. 26.3 42.0 2.69 2478.05 32.1 4.9 28.4 69.5 2.72 2478.55 34.4 17. 21.5 67.4 2.67 2479.05 36.9 45. 19.2 62.9 2.69 2479.55 35.8 33. 14.1 71.4 2.69 2480.05 39.3 50. ** 3.2 87.9 2.69 2480.65 33.8 108. 20.5 67.1 2.64 2481.05 31.0 9.3 15.8 76.3 2.68 2481.55 30.9 4.6 20.9 71.1 2.69 2482.05 33.1 15. 14.9 8~.7 2.67 2482.55 32.7 34. 16.0 77.5 2.70 2483.05 30.9 12. 19.2 77.8 2.70 2483.55 36.0 817. 30.3 46.1 2.69 2484.05 34.7 120. 24.9 59.5 2.71 2484.55 36.8 1940. 51.8 21.2 2.65 2485.05 31.8 11. 1.7 98.2 2.73 2485.55 29.9 11. 5.9 93.7 2.69 2486.05 32.2 39. 27.0 67.0 2'.54 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY PermeabJ[ty ............... psi PERCENT md. OIL WATER 1000 33.0 27 34.1 54.3 1000 29.1' 1.3 32.8 80.1 1000 31.1 9.3 24.9 78.0 1000 32.5 23 23.3 76.2 1000 32.1 20 16.7 84.4 1000 35.7 17 * 3.7 102.7 1000 31.6 43 22.5 73.8 1000 29.9 2.4 16.7 80.1 1000 29.5 2.5 22.3 75.8 1000. 32.1 1.4 15.5 88.6 1000 31.2 4.4 17.1 83.0 1000 30.3 2.0 19.9 80.3 1000 33.5 664 33.8 51.5 1000 31.2 14 29.1 69.6 1000 35.2 1280 55.7 22.8 1000 30.4 0.4 1.8 104.7 1000 29.8 0.8 5.9 94.0 1000 30.5 8.6 29.1 72.2 DESCRIPTION Sit; cry-sit, mod cmtd cry; cry-sit, mod cmtd Sit; cry-sit, mod cmtd Sit; cry-sit, mod cmtd Sit; c[y-s[t, mod cmtd Cry-sit; cry-sit, mod cmtd Sit; cry-sit, mod cmtd Cry; c[y-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cly-stt, mod cmtd Cty; cty-sLt, mod cmtd Sd; cty-vfsd, mod cmtd C[y-s[t; c[y-s[t, mod cmtd Cry-sd; cLy-vfsd, pr[y cmtd C[y; cry-sit, mod cmtd Cry; cly-s[t, mod cmtd Slt; c[y-slt, c, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 27-9 PAGE 38 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIHEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 15 (CONTINUED) (2464 - 2494) : REC. (2465.6 - 2495.25) 2486.55 35.2 24. 23.7 63.1 2.67 2487.05 37.5 69. 29.5 53.4 2.71 2487.55 37.6 237. 50.8 31.2 2.70 2488.05 39.3 385. 52.1 31.1 2.72 2488.55 34.4 55. 25.0 66.0 2.72 2489.05 39.2 556. 42.5 36.8 2.72 2489.55 39.2 291. 41.2 48.4 2.72 2490.05 32.1 11. 4.0 92.0 2.74 2490.55 35.7 28. 46.3 37.4 2.71 2491.05 31.6 27. 49.6 41.2 2.68 2491.55 32.7 86. 30.4 58.5 2.71 2492.05 36.8 438. * 43.3 37.6 2.70 2492.55 33.5 30. 18.2 69.7 2.73 2493.05 38.6 184. 32.6 52.9 2.73 2493.55 41.9 587. 32.2 53.4 2.73 2494.0 RUBBLED MATERIAL - NO SAMPLE 2495.0 RUBBLED MATERIAL - NO SAMPLE CORE NO. 16 (2494 ' 2524) : REC. (2495.25 - 2506.7) 2495.55 39.7 702. 38.9 49.9 2.71 * FRACTURED at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY PermeabJ[ty ............... psi PERCENT md. OIL WATER 1000 32.5 3.8 26.8 71.3 1000 33.7 32 34.7 62.8 1000 34.5 115 58.1 35.6 1000 36.3 271 59.2 35.4 1000 32.8 11 27.0 71.1 1000 35.9 233 48.9 42.4 1000 34.5 190 50.5 59.3 1000 31.5 1.2 4.1 94.2 1000 33.2 17 51.5 41.7 1000 29.7 11 54.2 45.1 1000 31.0 21 32.8 63.2 1000 33.3 69 * 50.4 43.8 1000 32.3 10 19.3 73.6 1000 35.5 51 37.2 60.4 1000 32.2 157 49.0 81.4 IOO0 36.4 608 44.8 57.5 DESCRIPTION Sit; cry-sit, c, mod.cmtd Sit; stt-vfsd, mod cmtd Sit; stt-vfsd, mod cmtd Sit; stt-vfsd, mod cmtd Sit; cry-sit, mod cmtd Sit; cty-vfsd, mod cmtd Sit; cty-vfsd, mod cmtd Cry; cry-sit, mod cmtd Sit; cry-sit, mod cmtd Sit; stt-vfsd, mod cmtd Stt; cty-sLt, mod cmtd Sit; cty-stt~ mod cmtd Sit; cty-sLt, mod cmtd Sd; s[t-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd Sd; stt-vfsd, mod cmtd CORPANY Arco Alaska PETROLEUH TESTING SERVICE~ ]NC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 39 FILE No. 70025 DATE September 26, 1986 ARCHIHEDES Air DEPTH POROSITY Permeabitity FEET PERCENT md. SATURAT I ON APPARENT % PORE SPACE SAND GRAIN .............. DENSITY Ol L WATER g,m/cc CORE NO. 16 (CONTINUED) (2494 - 2524) : REC. (2495.25 - 2506.7) 2496.05 30.3 31. 6.5 92.6 2.72 2496.55 33.8 394. 41.1 46.9 2.67 2497.05 28.8 13. 21.8 72.6 2.71 2497.55 30.7 13. 1.0 98.5 2.76 2498.05 31.5 24. * 12.6 78.6 2.73 2498.55 30.3 4.3 18.5 79.7 2.73 2499.05 32.0 5.6 9.8 84.3 2.74 2499.55 29.7 1.3 0.0 95.4 2.75 2500.05 32.1 7.7 14.2 76.3 2.73 2500.55 30.1 7.2 4.7 94.4 2.73 2501.05 31.2 5.0 ** 0.0 97.5 2.75 2501.55 31.1 6.8 5.3 89.8 2.76 2502.05 29.3 1.0 0.2 99.0 2.74 2502.55 30.3 2.3 3.8 94.4 2.72 2503.05 34.7 2.0 ** 18.2 63.5 2.73 2503.55 33.0 2.0 ** 16.8 72.9 2.72 2504.05 34.5 2.0 ** 15.4 71.7 2.68 2504.55 29.0 3.0 26.7 70.1 2~72 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURAT ION % STRESS POROSITY Permeabi [ty ............... ps i PERCENT md. OIL WATER 1000 29.1 1.9 6.9 98.4 1000 30.8 86 47.0 53.7 1000 27.8 1.8 22.9 76.3 1000 28.7 0.5 1.1 108.4 1000 28.3 4.3 * 14.7 91.4 1000 29.7 1.0 19.0 81.8 1000 30.5 2.8 10.5 90.4 1000 28.1 0.1 0.0 103.0 1000 30.8 1.6 15.0 80.9 1000 29.6 1.4 4.8 96.4 1000 .30.1 1.3 * 0.0 102.9 1000 29.4 1.2 5.7 97.5 1000 28.0 0.4 0.2 105.5 1000 28.5 0.7 4.2 102.8 1000 31.3 0.5** 21.3 74.2 1000 30.2 0.5** 19.1 83.1 1000 32.2 1.0'* 17.1 79.7 1000 27.2 0.8 29.2 76.8 DESCRIPTION Cry; cry-sit, mod cmtd Sit; cty-vfsd, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-stt, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cly; cry-sit, mod cmtd C[y; c[y-stt, mod cmtd Cry; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COHPANY Arco Ataska PETROLEUM TESTING SERVICEm INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 40 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY PermeabJtJty .............. DENSITY FEET PERCENT mci. OIL WATER gm/cc CORE NO. 16 (CONTINUED) (2494 - 2524) : REC. (2495.25 - 2506.7) 2505.05 31.1 30. 13.1 81.6 2.72 2505.55 31.8 5.4 10.3 83.7 2.71 2506.05 .31.0 8.0 4.4 94.0 2.72 2506.5 36.0 469. * 31.4 51.0 2.71 CORE NO. 17 (2524 - 2536) : REC. (2506.7 - 2512.55) 2507.05 37.8 5.0 ** 5.3 73.4 2.70 2507.65 30.1 2.7 2.4 91.5 2.72 2508.05 29.9 2.7 0.0 93.9 2.75 2508.55 31.3 177. * 24.2 69.1 2.69 2509.05 31.5 5.0 ** 21.3 71.8 2.69 · 2509.55 32.1 42. 14.6 76.6 2.72 2510.05 31.4 6.3 0.0 96.9 2.70 2510.55 31.3 11. 0.0 98.9 2.70 2511.05 33.5 22. 0.0 95.7 2.72 2511.55 33.0 15. ** 0.0 97.6 2.72 2512.05 35.0 '103. 26.5 58.3 2.71 2512.55 30.7 7.6 4.5 88.4 2.71 CORE NO. 18 (2536 - 2538) : REC. (2512.55 - 2528.75) 2513.05 32.4 15. ** 15.6 77.5 2.69 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL WATER 1000 29.4 5.1 14.2 88.4 1000 28.1 1.3 12.3 100.2 1000 28.8 0.8 5.0 106.3 1000 31.5 219 * 37.5 61.1 1000 33.2 1.0'* 6.5 89.7 1000 29.4 0.8 2.5 94.8 1000 28.4 0.6 0.0 101.0 1000 ~ 29.1 15 * 26.8 76.7 1000 29.6 1.0'* 23.2 78.2 1000 29.4 5.5 16.5 86.7 1000 29.4 0.8 0.0 106.5 1000 28.8 1.3 0.0 111.2 1000 31.5 3.0 0.0 104.9 1000 31.2 2.0** 0.0 106.3 1000 31.9 20 30.4 67.0 1000 29.7 1.4 4.7 92.8 1000: 26.8 9.6 * 20.4 101.2 DESCRIPTION Cry-sit; cty-stt, mod cmtd Cty; cly-sttm mod cmtd cry; cry-sit, n~i cmtd Sit; cty-vfsd~ mod cmtd Cry; cty-stt, mod cmtd Cry; cry-sit, mod cmtd Cty; cty-stt, mod cmtd Sit; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Sit; cry-sit, mod cmtd Cry; cry-att, mod cmtd Cty; cry-sit, mod cmtd Cty; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Sit; cry-sit, mod cmtd cry; cry-sit, mod cmtd Cry-sit; c[y-stt, mod cmtd COMPANY Arco Alaska PETROLEUH TESTING SERVICE~ INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 41 FILE No. 70025 DATE September 26, 1986 SATURAT I ON APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabi [Jty .............. DENSITY FEET PEECENT md. OIL 14ATER gm/cc CORE NO. 18 (CONTINUED) (2536 - 2538) : REC. (2512.55 - 2528.75) 2513.55 31.4 17. 2.9 95.3 2.71 2514.05 30.6 35. 4.7 93.8 2.69 2514.55 30.1 15. 21.3 70.7 2.69 2515.05 28.2 1.2 0.0 93.6 2.71 2515.55 30.0 2.0 ** 21.9 74.3 2.70 2516.05 30.2 1.5 0.0 97.5 2.74 2516.55 29.5 1.0 0.0 98.5 2.74 2517.05 28.5 2.1 0.8 96.5 2.72 2517.55 30.8 4.9 3.2 93.7 2.71 2518.05 28.7 1.0 0.4 97.0 2.71 2518.55 2519.05 2519.55 2520.05 2520.55 2521.05 2521.35 2522.35 2522.55 30.8 2.0 ** 3.6 94.4 2.71 29.1 4.2 3.5 95.9 2.70 29.4 2.0 ** 3.7 95.8 2.70 29.0 1.6 1.8 96.7 2.70 28.9 2.0 3.6 93.9 2.69 29.5 3.0 10.8 87.2 2.70 SECTION PRESERVED SECTION PRESERVED 29.3 2.5 0.0 93.5 2.66 at SIMULATED RESERVOIR STRESS SIMULATED ............ . ............................. RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md. OIL ~ATER 1000 29.1 2.1 3.2 106.1 1000 29.0 3.1' 5.1 101.2 1000 26.8 3.1, 24.1 79.7 1000 26.4 0.3 0.0 107.4 1000 27.1 0.3** 25.3 85.7 1000 29.0 0.3 0.0 103.5 1000 26.3 < 0.05 0.0 115.7 1000 27.7 0.3 0.8 100.2 1000 29.4 0.8 3.4 100.0 1000 26.4 0.5 0.4 108.6 1000 28.8 1.0'* 4.0 103.8 1000 26.8 0.9 4.0 107.3 1000 28.1 1.9 * 3.9 101.8 1000 26.8 0.3 2.0 108.2 1000 28.2 0.7 3.8 97.4 1000 27.6 0.6 11.8 95.4 1000 27.8 0.4 0.0 100.5 DESCRIPTION Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-stt, mod cmtd C[y; c[y-s[t0 mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-slt, mod cmtd Cty; cty-stt, mod cmtd . Cty; cty-stt, mod cmtd Cty; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; c[y-stt, mod cmtd Cry; c[y-stt, mod cmtd C[y; c[y-s[t, mod cmtd * FRACTURED ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL West Sak 2T-9 PAGE 42 FILE No. 70025 DATE September 26, 1986 ARCHIMEDES DEPTH POROSITY FEET PERCENT SATURATION APPARENT Air % PORE SPACE SAND GRAIN Permeabitity .............. DENSITY md. OIL WATER gm/cc CORE NO. 18 (CONTINUED) (2536 - 2538) : REC. (2512.55 - 2528.75) 2523.05 31.3 3.0 ** 15.2 77.2 2.63 2523.55 26.1 9.8 0.0 98.0 2.63 2524.05 27.7 2.8 0.0 96.4 2.66 2524.5 30.1 2.0 ** 3.4 96.4 2.66 2525.1 28.7 1.3 0.4 98.0 2.69 2525.6 28.9 1.2 0.0 99.2 2.66 2526.15 30.0 1.5 0.0 96.9 2.68 2526.6 29.3 7.4 1.8 98.1 2.61 2527.05 30.9 10. ** 0.0 99.2 2.63 2527.5 30.5 13. 12.2 80.0 2.56 2528.05 30.7 10. 0.0 95.7 2.58 2528.6 31.7 5.6 0.0 98.2 2.62 CORE NO. 19 (2538 ' 2563) : REC. (2528.75 - 2558.45) 2529.25 30.6 6.4 2.9 92.6 2.59 2529.7 28.9 3.4 0.0 94.7 2.63 2530.1 29.8 10. 0.0 99.1 2'.60 2530.55 29.2 10. 1.8 96.4 2.62 2531.05 28.8 3.5 1.5 97.6 2.60 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER SAMPLE FAILED 1000 25.1 2.6 0.0 113.7 1000 26.9 0.5 0.0 100.2 1000 27.7 0.5** 3.9 108.4 1000 27.7 0.3 0.4 102.5 1000 27.8 0.4 0.0 104.8 1000 28.4 0.1 0.0 104.4 1000 25.3 3.5 2.2 120.2 1000 28.6 5.2 * 0.0 111.1 1000 28.0 7.4 13.8 90.2 1000 28.9 6.0 0.0 104.5 1000 29.4 2.4 0.0 109.9 1000 28.7 3.2 3.1 101.4 1000 28.2 0.7 0.0 98.0 1000 28.2 1.3 0.0 107.0 1000 27.9 4.3 1.9 102.6 1000 28.0 0.5 1.5 101.2 DESCRIPTION CLy; cly-slt, mod cmtd CLy-stt; c[y-sLt, mod cmtd CLy; cky-stt, mod cmtd C[y; cLy-s[t, mod cmtd C[y; c[y-slt, mod cmtd C[y; cty-sLt, mod cmtd C[¥; cly-stt, mod cmtd CLy-s[t; cty-sLt, mod cmtd C[y-s[t; cty-s[t, mod cmtd C[y-sLt; c[y-s[t, mod cmtd Cly-slt; cly-s[t, mod cmtd Cly; c[y-s[t, mod cmtd CLy; c[y-s[t, mod cmtd CLy; cly-sLt, mod cmtd CLy; cLy-sLt, mod cmtd C[y; c[y-s[t, mod cmtd Cly; c[y-slt, mod cmtd * FRACTURED ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY Arco Ataska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 43 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeabitit¥ .............. DENSXTY FEET PERCENT md. OIL WATER gmfcc CORE NO. 19 (CONTINUED) (2538 - 2563) : REC. (2528.75 - 2558.45) 2531.5 30.7 11. 1.4 98.0 2.63 2532.0 31.7 27. 15.4 T3.4 2.65 2532.55 29.5 4.0 0.8 96.5 2.63 2533.0 30.2 5.4 6.7 91.8 2.64 2533.45 33.0 58. 4.2 86.7 2.62 2534.05 31.5 14. 1.1 92.7 2.62 2534.55 30.9 6.2 0.0 98.8 2.64 2535.05 31.4 10. 0.0 99.4 2.63 2535.55 27.1 6.0 0.0 96.2 2.61 2536.05 30.0 4.9 0.0 96.1 2.64 2536.45 31.1 4.1 0.0 98.4 2.64 2537.05 30.8 5.8 0.0 98.5 2.63 2537.55 31.2 5.8 0.0 98.9 2.62 2538.05 31.5 7.7 0.0 99.7 2.64 2538.55 29.5 5.6 0.0 98.3 2.62 2539.05 31.0 5.1 0.0 96.4 2.63 2539.5 30.8 8.0 0.0 95.7 2.64 2540.05 30.6 7.0 0.8 98.9 2164 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY PermeabJ[ty ............... psi PERCENT md. OIL WATER 1000 28.8 4.8 1.5 107.5 1000 28.9 4.4 17.5 83.5 1000 27.9 0.7 0.8 104.6 1000 29.2 1.4 7.1 96.5 1000 30.2 13 4.8 98.7 1000 29.8 3.0 1.2 100.4 1000 29.9 0.1 0.0 103.9 1000 29.8 3.1 0.0 107.3 1000 26.8 0.8 0.0 98.0 1000 28.5 1.3 0.0 103.1 1000 30.1 1.3 0.0 103,3 1000 29.6 2.1 0.0 104.6 1000 27.3 1.8 0.0 119,3 1000 29.7 1.7 0.0 108,3 1000 28.7 1.4 0.0 102,1 1000 29.1 1.2 0.0 105,5 1000 28.6 1.6 0.0 106.2 1000 29.3 1.6 0.8 105,2 DESCRIPTION Cty; cry-sit, mod cmtd Stt; cty-stt, mod cmtd Cry; cry-sit, mod cmtd CLy; cLy-sLt, mod cmtd Sit; cLy-s[t, mod cmtd Cty; c[y-s[tw mod cmtd CLy; cty-stt, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd C[y; cry-sit, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd C[y; c[y-s[t, mod cmtd Cry; c[y-s[t, mod cmtd C[y; c[y-s[t, mod cmtd COMPANY Arco Alaska PETROLEUH TESTING SERV[CE~INC. CORE ANALYSIS WELL West Sak 2T-9 PAGE 44 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL ~ATER g~/cc CORE NO. 19 (CONTINUED) (2538 - 2563) : REC. (2528.75 ' 2558.45) 2540.5 29.8 2,5 0.0 97.5 2.62 '2541.1 29.4 2.8 0.0 97.3 2.62 2541.5 29.3 .2,2 0.0 95.8 2,61 2542.05 28.8 3.6 0,0 96.1 2.59 2542.55 28.3 6.5 0.0 99.0 2.60 2543.05 23.5 5.8 0.0 98.6 2.60 2543.55 28.3 2,8 0,0 95.9 2,62 2544.05 27.6 8.3 0.0 97.5 2.65 2544.55 28.0 1.6 0.0 98.0 2.64 2545.0 26,2 2,5 0.0 98.5 2.66 2545.55 6.8 <0,05 0,0 86.4 2.67 2546.05 4.8 <0,05 0,0 94.7 2.66 2546.55 26.5 2.7 12.7 80.5 2.62 2547.05 29.5 112, 32.9 52.2 2.63 2547.65 31,9 100, ** 34.0 46.8 2.60 2548.05 27.7 86. * 15.5 75.7 2.63 2548.5 26.1 1,2 0.0 97.0 2.64 2549,05 30.2 2,0 ** 0.0 99.4 2'.63 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabitty ............... psi PERCENT md, OIL ~ATER 1000 29,5 0.5 0.0 98.6 1000 28.9 0.7 0.0 99.8 1000 28.9 0.5 0,0 97.7 1000 28.6 0.9 0,0 96.9 1000 27.8 1.6 0,0 101.6 1000 20.5 0.9 0.0 117.7 1000 27.0 1.0 0.0 102.2 1000 27.2 2.0 0.0 99.3 1000 26.6 0.8 0.0 104.8 1000 25,0 0.9 0,0 104.6 1000 6.3 < 0,05 0.0 93.9 1000 4.6 < 0.05 0.0 98.9 1000 24,9 1.3 13.8 87.2 1000 27.5 16 36.4 57.6 1000 28,9 79 * 39.2 53.8 1000 23.3 21 * 19.5 95.6 1000 25.6 0,4 0.0 100.0 1000 27,2 0,5** 0.0 114.7 DESCRIPTION Cty; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cty;,'cty-sLt, mod cmtd, Cry; c[y-s[t, mod cmtd Cry; cry-sit, mod cmtd Stt; cLy-sLt, mod cmtd C[y; c[y-s[t,'mod cmtd C[y; cty-sLt, mod cmtd C[y; cty-sLt, mod cmtd Cty-stt; cry-sit, mod cmtd Ls; weft cmtd Ls; wet[ cmtd Cry; cty-stt, mod cmtd Sit; cty-stt, wet[ cmtd Sit; c[y-s[t, weir cmtd Sit; c[y-s[t, weir cmtd C[y; c[y-slt, mod cmtd Cry; cLy-stt, mod cmtd * FRACTURED ** FRACTURED~ ESTIMATED AIR PERMEABILITY COMPANY Arco ALaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL Nest Sak 2T-9 PAGE 45 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air % PORE SPACE SAND GRAIN DEPTH POROSITY PermeabiLity .............. DENSITY FEET PERCENT md. OIL WATER g~/cc CORE NO. 19 (CONTINUED) (2538 - 2563) : REC. (2528.75 - 2558.45) 2549.55 26.4 2.4 0.0 96.0 2.65 2550.0 26.7 3.7 0.0 98.3 2.65 2550.5 26.9 9.3 0.0 97.9 2.69 2551.05 28.5 11. 11.3 84.0 2.63 2551.55 26.8 3.3 0.0 96.7 2.64 2552.05 27.7 3.2 0.0 95.6 2.65 2552.55 26.7 6.1 0.0 98.6 2.62 2553.05 28.1 3.0 0.0 96.8 2.65 2553.55 28.7 5.1 0.0 95.0 2.65 2554.05 28.6 10. 0.0 99.4 2.65 2554.65 28.0 2555.05 26.7 2555.55 29.4 2556.05 25.9 2556.7 21.1 2557.05 22.3 2557.7 29.7 2558.05 27.8 5.4 0.0 98.8 2.63 1.6 0.0 97.9 2.64 7.8 7.0 89.0 2.64 62. 19.7 62.8 2.54 0.7 3.0 92.7 2.54 13. 16.5 81.2 2.53 58. 27.1 62.2 2.60 5.0 21.8 70.7 2;56 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION ~ STRESS POROSITY Permeab|tty ............... psi PERCENT md. OIL WATER ........ . ..... .. ......... ........... 1000 25.6 0.5 0.0 100.0 1000 26.1 0.6 0.0 101.7 1000 24.7 1.2 0.0 109.9 1000 26.6 2.1 12.5 92.3 1000 24.9 0.7 0.0 106.8 1000 24.8 0.6 0.0 111.1 1000 25.4 4.5 0.0 105.3 1000 27.1 0.7 0.0 101.7 1000 24.9 1.0 0.0 115.0 1000 26.6 2.0 0.0 109.7 1000 26.8 0.7 0.0 104.7 1000 24.5 0.3 0.0 109.8 1000 28.2 1.2 7.4 94.2 1000 24.1 11 21.7 69.2 1000 21.0 0.1 3.1 93.4 1000 21.0 1.8 17.7 87.3 1000 27.4 10 30.4 70.0 1000 25.9 1.5 24.1 77.9 DESCRIPTION Cty; cry-sit, mod cmtd Cly; cLy-stt, mod cmtd Cty;.cty-stt, mod cmtd Cty; cry-Sit, mod cmtd Cty; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cry; cty-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; cry-sit, mod cmtd Cry; cty-stt, mod cmtd Cry; cry-sit, mod cmtd Cry; cky-stt, mod cmtd Sttst; cty-stt, weLL cmtd SLtst; cLy-stt, welt cmtd SLtst; cty-sLt, weLL cmtd SLt; sLt-¥fsd, mod cmtd Sit; stt-¥fsd, mod cmtd COMPANY Arco Alaska PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS NELL West Sak 2T-9 PAGE 46 FILE No. 70025 DATE September 26, 1986 SATURATION APPARENT ARCHIMEDES Air ~ PORE SPACE SAND GRAIN DEPTH POROSITY Permeability .............. DENSITY FEET PERCENT md. OIL WATER gm/cc CORE NO. 19 (CONTINUED) (2538 - 2563) : REC. (2528.75 - 2558.45) 2558.4 25.2 5.1 17.0 76.4 2.55 at SIMULATED RESERVOIR STRESS SIMULATED ......................................... RESERVOIR Air SATURATION % STRESS POROSITY Permeabi[ty ............... psi PERCENT md. OIL WATER 1000 23.8 1;3 18.2 82.1 DESCRIPTION Sttst; sit, foss, we[[ cmtd TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERMEAMETER = 300 psi OIL GRAVITY ESTIMATED BY VISUAL FLUORESCENCE = 18 AP! Frequently, APPARENT SAND GRAIN DENSITY data are [ess than the expected value for the rock type encountered. This may be caused by one or more of the following reasons: 1. The presence of Toluene insoluble organic material. 2. Water soluble compounds left behind in the extraction process. $. Isolated pores that appear to be part of the sand grain volume as determined during the measurement of effective porosity. 4. The presence of tow density clays or minerals. To obtain accurate sand grain density values suitable for log interpretation, it is necessary to completely disaggregate the sample to expose isolated pores and to extract or treat the sample with additional solvents or methods to remove entrained organic material and water soluble compounds prior to making the measurement of ABSOLUTE SAND GRAIN DENSITY. ARCO Alaska, Inc. July 8, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2T-9 Core Description (Shallow-Sands) Dear Mr. Chatterton' Enclosed is a copy of the 2T-9 Core Description. Since this information is confidential, we would appreciate it if you could store it in a secure area. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/18 Enclosure cc' 2T-9 Well File 14Bin %' Intensity ColOr oolor ooIor _ ~ (,~,/~ ~~ ~o~'~ ...... , ........................ ..... .............. ~ .......... .......... ,, i ......................... ~ ~O,,,st~~~' ~/~, ,, 0 o,,' 0 ............. ............. i" ' "' ~ 'ud' u j: ' '' ~ "' ¢ /' E ," / ~ " ~ ......... . ..... , ............... ~ . ~ O , AR3B-23g0-B o.w-q AR3B-23cjo-B CONFiDEJ [iAL l~llin % Intet~,ity ] O°lor ~ ' ' ' 0 ~' 0 /' ' ' ........ ~ ! / ......... , , , .. ' 0 }'~ ) ........ ..................... ~ . ~~ ~ /~ .... ~' , ......... ....... f~, n'~ ......... ~ q ' , .... ~ I , ................ ,,2 ~,,Sg ...... ~:~ ' ~/a ~ ~o//o3& 0 .... O, 0 .. " ........... t ............. ...... , , '~ (+ o o ~ 0 ........ g . ................... ~ ..... ~ t2 / ' ' ~" ...... , ~p u ~ ~ ,.... .... , , ......... AR3B-2390-B Descri_bed by I . I Z 7_00 - 2-2Z UONI"IIJI:.N ]iAL ~ ~/~ ~/Sfi ~_ '¢ "~" / , - AR3B-2390-B ~ 5 22q0- z/--~ I 22qS.5- 9'7.,5 Described by ~~, r. t/~~ AR3B-2390-B Depth I1~. Dmc=r~n % Oil Od.( ' I~ln % Inten~ity Color ~r AR3B-23cj0-B CONFIDENT!,~,L AR3B-2390-B ,~/2~/'~(m 2 z ~'t 5 1 t-~.~, fl.: ~, .... [.4 ~,,,,~,~ I0 tu~._ ~td. ...~,~,,.,..,~:. ~ f I ] ........ . ... 0 / ............ ............. ., , ., .... ~ .............. - ' / " ' ........ ~ ' ,, , ......... 2~5o n~¢,'.. ~ ~ ... 0 ....o ' d5 .,, ......... ,, ........ . .......... , " .................. ,'C;:: '" ' I,'¢/; ~ - ~ -. ......... ~ .... · . ~ . ~ , . ,, q .... , ,, i JOe$c~ed by ,,/ AR3B-2390-B GONFIDENfiAL De~h I~:. ~ % MI OdM Oil IMM M C~ M ~1~ % ~l~r ~ t I ...... ~ ........ ................ ~ ....... ................... ~,O,Ote~ ................... ....... ~ ......... 1 I .......... : .............. ~ ........ ...... ....... ~ . . , ...... ....... i ...... ............... ...... .... .. ................ IC)e~d by AR3B-2390-B IlIln %' " Inten~it~ Oolor oolor IIKJlor '~./ / , .......x. ~/;~"' ~,..:, z~'~--~,,..~,~ ~,~ ~ c .,, ~bu,.., , ......... ,. .... ....... j ..... O. ' .... ,' /. ..... ~. ' , , ~' } · ,. / ......................... , , , ! - ,, , ......... - ' "'" I ~ ......~ ,, ~,, ~,/, / ' / '" , r' ........ ' "~' ~ J I ...... / .... . . , ,,, [()~.~,~,,,,~ ~,,~A~ AR3B-2390-B ii.scribed by .~ VI~Ii IL/L. rYI i~L- ~ I~. ~wlpUon % Oil Odo~ ..... ~ln % Intensity Oolor ~r ~or . - ~,.~, /04 i _ j .... t i AR3B-2390-B IDescribed~ CONFiDENTiAL ........... ., , ........ ........... ~ ~k ' ] ~ - . . / ',. I . . ,, .,~6~ .~ "2 ~ . / ....... '-. ~ l' ~ i~ "' , , ] U / t'' i .... I , .......................... 2.3qC ~~~.' ~/~ o .... o ..... C / . ........ ~,~ ~ ~{ .' ~ .,, ~ c~ ......... .............. ~~ ~ .... ~~ .... ]~ , ............. ............ ~ ~55~~f,' ~_./~- .~ ..... ~ o....... ........... ~ ~ ~ " IIImlrk$ AR3B-2390-B &R3B-2390-B ~ lie(:. 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CUt .... .... ........ .............. , .................... "' ' ' ~ ' ~ ' A~ ........ FA / ~ .:,. .~, .................. rA /~ .................. ......................... ~ .... . ~ 'i I / ,~ ............... ..... ~,~ s,~, ~s/~~ fi~x ... Poo ~_,, .......... ~., ~marks AR3B-23gO-B RECEIVED JUL ~ uUi~lr II./I, I111 I~L .... , I f / / ..... ~ / ' '" f I .... , .............. , · ............ ' / Pool .............. ...... ~ , ~' , ........ ~ "~ , [ . ....... " t ' .... / ~ ~~, .......... .. ............... ............. ,,_ , ............ ,,i ' ,. , ,, ..... , ...... AR3B-2390-B ~ "% ~nter~ay COlor odor ~ ~z__ s~ · ~6,',' v~ ?,,,.,. -~~ /oo ~-,~ ~~' 90,'{ ~,~. Hz / - / ~/~. X ,', ~. ~~ ~.~ FA t ~ o,, ~.~ ,, ,~ .............. ...... , , , , ~.... /) ), ,, ........ ...... "' ~ ' // ' '/ ............. ..... ....... v .... , ,,. ~. - .. _ !/r ~' L/ v~ ,, ~, Jill ~ . ~ /~ ~ ~,'. ...... g , ., 2 AR3B-2390-B i...... . AR3B-23cjO-B -7 Z5Zq- 25~ ~,,~--~ Z5,2- Ikli't,£E~k~T£~ V II~II,/LI Ii,ii I LL I M~ln % Inlenst~ ..... COl°r ~ ~ eem ,,, , ,, ~ .... ~. ~ '~ ~ T ........... ~ ...... . ........... , ,, ......... I / ~ ........ .... ........ i / I , , ........... .................... ,,, ... .~. ,- 5~ ~ ..... zs~ ~~f' o__/~ ,, ~ ,,o o ..... ................ ............ _.~,. - .. II II./LI il 111 ii I~ IDescribed ~ 4.~,,~_~ AR3B-2390-B ~ loc. ~ % 011 Odor MIM % bdlflOlty Color o01or IklM Illin ....... ~'! ~ .............. ...... ~ , , , · .... / ......... ~, .. ....... .... I ................. / ..... · .......... ~ ,, ..... , , ~ ........ .......... ......... , ....................... ¢: C' c' ' 2 AR3B-2390-B AR3B-2390-B . Kuparuk River Unit 2T-9 The Kuparuk interval will be cored using a fresh water, low solids, nondisperesed drilling fluid. ._ _ ,~t-- ,, - - UK F[ELD.i EAs'rI~ WHI.~S'I:OCI~ ; NORTH S~O_PE. INC' :._:_:_ ! ............ :_i .... '_, .... : ........ : ....... i , 0 1 000 2000: ' l ..... ARCO-ALASKA, - -- _:'_ ~ _. PAD 2T_, WEI~ NO! 9 PROPOSED .... :-. - KUPARUK-FIELD.- NORTH-' :SLOPE. ALASKA ............. · ~ ...... EASTHAN-WHiP~TOCK.-- INC.- I ' I P~ 2T, ,L NO' 9 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALAS_K_A__ ; i : -' I 000 KUPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C 8 DESCR I PT I ON 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. G. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. ?. 10" HCA 8ALL VALVES OIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN 8E REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS . APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2E;. 03S (b) S MR I NTENRNCE & 0PERRT I ON 4 . 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER ANO VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOHNWINO DIVERSION. DO NOT SHUT IN NELL ANY CIRCUMSTANCES. ,,_. -: RI( ._1 L_ 6 ACO. NIJLATOR ¢4~A(;:~,TY TEST I. (]-ECX At~ FILL A~TCR RESERVOIR TO ~ LEVE3. WITH ~IC FLUID. 2_. ASSI. RE THAT _AO3__Ii~=ATC~ PRC_..%,~LRE IS 3000 PSI WlT~ CI~ ?Ih~o ~ CL__K~_ ALL LI~TS SIkiA. TAhEOUSLY 4. R~CI~ Ct4 NADC RE):~o TIE AC~ABI.E LONER LIMIT I8 4S SE~ CLOSlN~ TIIV[ ~ 1200 PSI RE)aAINING 5 4 3 1~-5/8" BOP STACK TEST I. FILL B(~P STACK ~ CNO(E MANIFOLD V~ITH ARCTIC DIESEL. 2. (]-ECX THAT ALL LOO( ~ ~ IN ~ AR~ FULLY RL:'FRACTED. SEAT TEST PLUG IN ~tS. LI-F. AD WITH RtJN~IN~ dl' ~ ~ IN LO(]<I:X]AN LIhE VALVES ~ TO ~ STA(](. ALL OT~ 4. PI~ UP TO 2.50 P~! ~ i..EI..D FOR I0 MIN. IN- ~ PR~'_._~I___~ TO ~ PSI ~ H(lO FOR I0 MIN. BLEED ~ TO 0 I:~JI. LI~ VALVES. (:LOSE TC:P PIPE RN~S ~ HCR VALVES ON KILL AN3 ~ LIt¢.S. 6. TEST TO ~50 PSI ~ 30133 PSI AS IN STEP 4. 7. ~[NI..~ TESTING ALL VALVES,, LIl",F. So ~ WITH A 2.50 PSI LON ~ ~ PSI HI6H. TEST AS iN NOT A FULL CLOSING POSITIYE SEN_ ~. CN_Y Fl.~II~ TEST Q4~ THAT BO NDT F'I. ILY CLCC::)E. 8. C:PEN TOP PIPE RNVlS AN:) CLOSE BOTTQ~I PIPE TEST BOTTCM PIPE 1:~ TQ 2.50 PSI ~ ~ PSI. 9. 0PE;N BOTTOM PIPE R.Na8o BA(::X OUT I:~N~IN6 JT I0. CLOSE BLIN3 ~ AN3 TEST TO 250 PSI AN3 3000 PSI. II. (2~ BLII'~ R.~ ~ RETRZEVE 'TEST PLUG. MAKE MN~FOLD At~ LII~,E$ ARE FI.JI..L 6¢ FLUID. ~ ALL VALVES IN DRILLING I:::~ITI6N. 12_' TEST STAN:~IPE VALVES, KF! kY, KI=I I y COCX$o DRILL PIPE ,~AFETY VALVE. At',D II',,6IBE ~ TO 2..58 PSI _3000__ PSI. 13. I:~C~ TEST II'~='(2RMATICI~ ~ BL0~ ~ENTF_.E TEST F61~4o $I61No ~ SEN::) TO DRILLING 14. PEEF(~ C~ B(~ TEST AF'TE~ NIPPI. ING LI3 ~EEXLY THEREAFTER ~I(3qN.LY ~TE ~ C~ILY ~EV. h4AY 15o GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE DEOASSERt HUD CLEANER SHAKERS STIR ~.-p, STIR ._~ STIR ICLEANER LWK4/ih TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 YP Viscosity Initial Gel 20-40 50-100 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih October 22, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60068 Well: 2T-9 Field: Kuparuk, Alaska Operator: E. Sellers Survey Date: October 10, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry,Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 SPERF~Y-.SI...IN WEL. L.. :i.:.';LIRVEYING COMPANY F'AGE' 1 2'T.-'~P COMPUTATION DATE BOSS E~YRo.:~uuF IL, SURVE~ KUF'ARLII< ................................... . ............................. OCTOBER 14, 1986 ,JOB NUMBER AK-BO-60(:;~,~'i;~;;¢::~;:~;;'~;;;:]:.;?, :.. 'AI....ASK]~ .... KEL. LY BI..ISHZNG Ei_EV. = 117.0C) F'T'. .................................................................. 0 P ER A TOR--E. SELL E RS VER T I C A L S E C'T' I 0 N C A L C I.JL ~'~E[i' "~ L ON G C L. 0 S LIRE ..................................................... TRUE MEASLIRED VERT I CAI_ VERT I CAL I NCL INA T I ON D I RECT I ON SEVER I TY RECTANGLILAR COORD I NA.TE~::?~'~::~(; MERT I C:AL DEF"I'H DEF:'TH DEF:'TH DEG M I N DEGREES DEG/]. 00 IqORT'H/SOLITH EAST/WEST SEC:T I ON ........................... 1 O0 200 300 · '1. 0 () 5()0 600 700 ?00 1 C)00 1 1 00 1 ';i: 0 0 13 () 0 1400 1500 1600 1700 18 0 0 2000 2100 '-2200 2300 2400 2600 2700 :.2 :--', C) 0 :2'.-7 C..~ 0 0. i 0()~ ';:'0 C). :300, 4. ()0 ,, 500 ,, C)0 6 () 0, ()() 6 'F".:..~, '.-.-/'? '7 '.:.'> '.-.-,, '!;; '? 8 ?;":.-~, '.-.-~ .:.7,,!?.?. 'i?'? :1. ()'.-:)'.:.~. '?'.:.') 1 I 'i.-'¢ ?. '.?'i.:¢ () 15 I',1 7:3. :1. () [ii; (), 0'.:.'/ (), ()./:, S 1,47 E O, :5:./: () 16 N 6:1.. :3(-) E'" 0,, C)/_-, (). 12 hi 1. E',':.:, IE 1.2('.-. ........... 0 J.'7 I',1" .~f.';4, 10 E' .........i] :"' i'i 21; ............................. ['i'-'?-ii{'"'"~ ................................ :~":"?~i'~'i'-'"~- 1 : .......... 72 0 17 N 46. :':~'::~ E O.. 04.. 0,. '70 N '":' .6'? ES 2 .,~.'-" I (") 4 N .37. lO E 0 21 (), 9:':: N 2 91 E '-' .=;,:.3 ............ b '? t~i ![3, E:,? 't~ ................ ~:'i'L' 'iTi ................... -KY.f. c5-~- ............ ~--~-'-~ .................................... ].'::.. .............. ,.:-., 7 (':. ':;... I',1 1:1. . 5_ 0 W (')_ , (").. 4 :1. , .::,""..., =' N ~:_":'. 87 E ;:::, :.:: :3 (':~ 10 N ('). :3'? W 0, 04 1.6:7, N 2.84 E :3.04 1 :--:'-T, 9_. . .9';, .... 12::-:'.~'~. , 9':',. .. ('). 11 .._,'::' ::::/., ...... ,, lO.. '- 0 .05 1 . 70 N :3 .28 E ._,'-'. :36 J. 4.':/':)..... 99. .1 ._,c":'":',_,=. ,:~,:~.... () 19. N 47 . ~')_. _= 0 . ~.z,""'-' 1, ,_oR° N ,,'~, 65 E .::'- .73 1 =;'::~':) '?;':3 :1. 4:32 - ':)": .... :'6 4 ~1 N ""':' - ....... 5, 1 '7 E A 4 ................... : ..... 0 = '> 45 4 0'::~ N _.. 1/-,':/':) /:, 4 1 f:~:::";' ,64 P; ~ 1 N 28 ',::':) .... :3.11 1 ("~ F~::', N 8. ':) ~ E 1 '-' :35 ~- .- 1 ~, '::).. 8 .9 ..... (-) 1/.. :::: ~ . 9. (]. 7 ._, 4 N :31 . 50 _ ~'>. 07 20... ,~/...~9 N 1 ._, ~ . ('). 1 E ~,~._.,. ~ 9':)/-, ......... 25 1877 25 9 2:3 N 'q-/, 10. _= O. ~,~o.~ 47.70 N 3:3.10 E 57, 96 20'?4. ?5 1777.'75 ? 6 N 37.60 ~ 0, 30 60,47 N 42.84 E 74, 02 21':~':: /-,'2 ...... ~:0'76 A'2 ':~ :34 N :::A 50 - (') ~1 ~'-' 42 N ~2 6,2 E '?(-~ 2 22'F/"2, 24. 2175.24 'F' 27 N :36.30 E O. C)'? 86.75 N 6,2.45 E 106. :30 23'?0.84 227:3.84 '? 4:3 N :36.3'? ] ...... (~'~' 2:3 100. 1'? N 72. :34 E 12:3.48 24:=:';,, 40 :~:~:~', 4(~ .......... ,¢, ....... ~]~ ........... N ":e~,-' ' 0 E O. 07 '~ 13.84 N 82. :32 E 14C..:,,_, 2587 ?7 2470 ?7 'P 36 N o=,. 10 E O. 1~ 127 4:3 N ?2.zI E 157 2/-,F:/-, /-. 1 '-'~ ' ...... z ._, ¢,_ ? ./-, .... 1 9 19 N '-':, ~:,. 80 E 0 . ~';' o.. 14 o.. ~_, ._M N 1 o. 1 . 9. :=:_ E 173 .61 ................................. "-' '~-' ~? .... n ..¢ . · .' .- .. ~ ~:., .::: ..... 27 :26/:.:~,'~ ........... '~-- '~l~ ....... -6~-]?Z'. 0 E 0 1'4 1.~:3. '71 N 1 1 1 ~":, E 1::::':~ · ":, ,:, c, -'::, . ...."::":>.. 27,5.6 . ...'7":~.. 1:3 1 ...., ~= N :37 . 1° E':' . 78 16'? . 42 N 12:3 . 67 E 2:'(')'::/.. A:':: ..... .,L. '...' '...~ -_.' ..' . ARF:O 'A[_A:::;I<A, INC:. 2T-9 L. UMF tJT AT I ON [lATE t, ~ .' K'UPARt. I.-'. OCTOBER 14 ~ cma .................................................................................. ~ i i'; A L.. A S K ~ ................ F:'Ar3E. z. .... DATE OF.:,URVEY'" I' """ B_l~., UYR J~E, OP I C: SLIR~EY lI : . JOB NUMBER ' : l' Ill ~ ' '~I'l :' l~ ' ....... Il ~ [:~;F L.!:.:. Y ....B L!S H :[ .N CJ... g.L.F.Y..: ........ 5.~ ........ i. rL'.E,..()O..F.'"r"~ ......... OF'ERA]"OR--E .... ELLERo 'r'RUE ;.SLtB.~:~E~ -'c " FIEnSURE[: VERT ZC:AL VBRTZCAL ......Z..M~j;:.~=!,bJ~.]E~_Obl ..... ~{!!~FC:TZ ON SEVERZ TY RECTAN6ULAR DEPTH DEP]"H [)EPTH DEG M I N BEGREEE; DEEG/]. O0 NORTH/E:E!LI]"H .... E;A~TI/~.E,{EEE ............................ ~;~} !;;;:'F ~ ON 300C) 31 O0 :3200 :'::250 3:3 C) 0 ::ii: 40 :3500 :3600 3700 :3800 .. - ...' :.:: '.':.,' (...~ 0 4000 4 i. C) O 42C)0 4:_::(:)(:) 4400 4- 5 C) 0 4. 600 47 C) 0 48(:)(:) 4.9C)0 5C)00 .5200 .... _-, 00 54Cio 5._=,(:)(:) 5/_-,0C) 57 00 5 ',..:.: 00 :36'24. .74 .:,""'=.._,(.) 7, 74 ,..'-'._,:' 41 N 4.5 ........ ~c) :: 0 09 '-"~: ...... ,, ._P?'-'-'o N :..4- L--'- 1 . 7.5 E 501. 96,_ :3 716. 17 ::/: 5 9.9. 1 7 2 2 5 N ::'.':.9. :'::'.::) :'" 4. :.R 6 41 F,. :'::'::' N ..,':' 4 ¢¢... 16 E' ._:'] 4 ..'.'-' ..:'"' 7 ::::: ::--_.: C)::::, E:.9 :.".:: 6, 91. :i:::'!--"; 2:1. 5 4 N :3 :.:.:, .':.'5 0 :.: (), :3 8 4 4 4,4'.":"; N :3 7 2, '71 L:.: 5 '7'i;;. '7:3 :::.' 9 C) :1.. 64 :37 84.. 64 21 5 E N 38.69 ::: O. 1 C) 47:3.66 hi :3.96. ():3 E 617. 1 () .........."::'-;':~ 4 :::: 1 :::": ::: '7 '7 .................. :':: 1 '::' ? 1 c) N :3 :iii: :::: 9 .... 0.2 (") ,--, ....... ()...,. o.: .-,,- N 4' 1 ":¢': 5 '7 a c' ....... '="~ · "-':::' .......... · . .C..,:.. , ..~, *_-'~ - ._o~ 2:7 N 443. 19 E 692.40 ~ "::' lA N :.'-_',:E: A':? 00:E: ~ '-' 417.9. 54 404, 2, ._ 4 '> '- ,-"] 4 466 75 E ..... ,61 N 7:30. 1 4272 1.~ 41.~;S. iR ?? a N 3'.'--;. 0 :_' 0 11 " - . ..... - 7 ...... _'.~ ......L~_ _.'~._ ..... _- ...................................... 4:364 ,'-~ 7 4:24'7. '77 2'2 'E: N :38.89 E O. 0:3 62('-). 5:3 N 514. 11 - :.::(] 5.5: 4457 4:2 4:34 (-) 42 '":"-:' '-' ........... :,; ...... 84:3. 18 4.54-.9..9'? 4432. '--~ 9 ...... 21 N :R:::. 10 E O. '4642. ........... ~';"~ ...... '-"-, c, - 44 4._,-.'._,. 44 ..'z. .6 N .'_--:7. :::0 E O. 14 709, 64 N 584.5'2 _ 919.11 47:--:4.70 4617· 7C) 2';.' 57 N :_--:7. 19 -- O, 57 740, 26 N 608, 01 : 957.70 4826 65 4'7(')'~ /- ~ '-'"" ......... ..,:, 19. N 37. 0 _-- 0.37 771,60 N ~'~1.72_,._, _= 9.96,'.~9. . ................ 4 '? 18.2.~ 4 ::: c) 1 '-' ~' 7:3 .~ 7 N 37 _ _ .." ._1 .. ................ :,._, - 10:37. C) ........... 501 O. 09 4-L::'? 3.0'.:; 22 :2', 8 N 36.6. 9 ........... .... 5102.'.:.~1 4.98!5.91 21 2 N 33.80 E 1·.9:3 865.6:2 N '701.C) 6 E 1113.76. ~l ~,/_,~/:.:~. .......... .~y~7-'~- .... 1 .9 4~, N--'._-.o 2_-:;.~ --1 6~, ,-,,-).~. . ............... <:,.,. 09 N 719 6.9 E 1148.44 ~?'=~1 ~? 5174 52 16 ~ "'1 0 - 9';'2.13 N . . · . .. 6 N .:, ::,2,, 84 . ._ '-'~' .......... · ........ ..: 7.:,.., :-'::3 E I 17.9 6.9 F, .=i, '-, ' - '~'" ?~:::A7 .._7 15 . '1 60 o4~ 91 N 750...-.:: E 1207. ....... · .-7o. 57 2(] N 31.3.9 ........ ""'- 28 54'84. :24~' - 5.:_-:i~:'-!~,.;.i ............. ~ 17 .......... -~i-"~-~-EiO _~ ..~. I 1 'i.--~ 67.5'.7N 767-:. 8 C) E 12:3 :.3, 71 · q ?~ E: 1:2, 7 :=~ 4/.. 4:3'7 1. 3 ~. 2 N :.:.', 4 /-. ....................... .:,._, N 7'76 '? ~":: E' 1 ? F;;'-. 40 ..... S.';F'EFtF:<.Y-E;LII',I WEL. L. ~i::;LII::;tVEYING C'.'OMF'ANY A R C ()'-'A LA Si':::"-3, i'NC:. ' 2T-9 COMPUTATI CJN ELATE K!_-.!_P~..R..'.U?![ ................................................................. _O CT ,-'_, BE F~ 14, 19o6 P,L.A SK~'.~ .. V EI:?'I" I I"? ~-"~ i .... E;IS liE:']" I I")N C: ~ I.... I.-.:l_l L. A T E £1 A L I..EI N G C I.... ('~l'.iii;l_l F: E TRLIE '"" :~UB-oEA F'A('~E '-' ME A...-.,L I',ED VERTIC:AL VERTICAL D E F' 1" H 1.') E F' '1' H D E F' T H BOSS GYROSCOPIC; S'.DBME¥"~.:;:' JOB ..N.L.!MBE~ AK-B0~"~;~;~8~ii?,i;?~'.:.;:::i~!i);.'i:. ,--_ _ ~,.'.'E:t...!:.. ¥ E.U !.=.-.iH !N.O ....E.:..L....~.V...,. ......... .-..-.-. ........ L.~....7....,....P!;! ...F' T, OF'ER~TOFt--E;. SELLERS .. "1' i": .... C:O L~R SE L: JL RoE DOG-L.E G '1"0 T AL. .I_.Nj.Z.':.L.:_:'['_.N._.(:~_.r..]::f.!_.N._ ..... I_.'.!..I...R...!!E.!?_'!i I.E!.w ............ !:=;_E_'y_E_R_I_T_Y_. R_..E._.L.-:Tn_NjZ~JJL. a.R .... C00.RD~ NA [)E):3 M 11'4 I:)EEC~F, tE;E:SDE:I'_'.i / 1 O0 NOF~:TH/SOLITH E'AST/WEST SEI'_':I" ........................ 5'.;' () 0 U E.'79.0 E; 6000 5777. 11 6,1 (> 0 '="'-'"' '"-- ..... ._,,:, 7..~,, ";":~ .620 0 597.3, 46 6 :.300 6, 07 i'. E, '7 6,370 .4:, 140 ,, 4. :l THE F:ALF:I.IL_A]"IOIXl F:'ROCEI'HIRES ARE BASED ON THE I...ISE' OF ]"HREE I)IMENSIONAL. RADII IS OF F:LIRVA'rLIR£ ME"FHFID. · .- _" ' ' .' '~ .'~ " ............................................................................................................ L ............. ~'_ ._- '-_ ........ ~. .................... '- ' '..._.,'7-..::--:. .............. SPERRY-SLIN WE. ELi .... SURVEYING COMF:'ANY F'AGE 4. A N E!..IO RAG E A L A S I-::.~ ARCO ALASKA~ INC. '":' --':'~ -'1' ' KLIPARUK .................... OCTOBER 14, 1 ~6 dOB NUMBER AE~BOd:600~ili!iii~i?:';:!ii,~:ii:f.:: i ' AL. ASKA KEL, LY BI i'.:;HINR El EV. == 117.0() FT, ............................................ · ; ..?:...;,~ ........... , ........ ~: ........ :: ,.".] OPERATOR-E, ::;EI_I_E~RS .......................................................................................................................................................................................... ZNT~.~E:~E£1 VALLIES Fi]R EVEN 1OOO FEE]" OF MEASURED DEFTH ': iii!~i!ii!ii!!!!i!i~iiil;i!~i: ,~ , :.~?~i~:!!i:: : ::.ii:::~i~:~i::!i~!!~ ::::::::::::::::::::::::::::::::::::::::: .......... ME]ASI.JRED VERT I CAL. ... ~.~R'I" I.CAL. RE:CTANGL.IL. AF~ E:OORD I NATES MI - ~9 D VERT I F:AL.. 'l ' I - .......... ~ .................................................................... DEF:'TH DEF'"I"H DEPTH NORTH/E;OLITH EAE;T/WES'T' KI I F'FEREN(~:E CI:IRRE:CT I CIN .......................................................................................................................................................................................................................... 0 '.1. 000 2:000 '.:?'.:.?'F.~. '.:.)'F~ 882.99 1. 10 N 2:. 9:3 E 0.01 0.01 1 'iF/?96......":'._.~1:3 '79 . ,.'~ :;._ 47.70 N ,.,":' ....,':'. 10 E :':: .75 3 .75 :300(-) 2'.:.~ 8 C), 2:.E: 4000 ::.:.: '.9 (") 1.6, 4 500(".) 4:..:.:26,, 65 6000 5777. 11 6,:370 6140.4.1 286:3.2:7: _'l E:9,, 14. hi :':::7E:4.64 4'7:3, .,'.:,E, 1'4 4. "7 ()'i? ,, 65 7'71.., 60 N l'i .................... N 602:3.41 1076.25 N T'HE CALCULAT I'O~ ,.~;~iE~.~RE~i::;~../~.i:i~;....-B-`~i~;.]ii~:~-~L.~i~:i.N.~..~.]::j~Ei''' "i:}'iii;~'"' oF:" i'i:~R"EE-"~i-~' HEN::_-'; I ,::,NAi_ RAD I LIS FU-- CURVATURE METHC,[,. ARco ALASKA~ liNC. 2T-'.~) KLIPARUK A L A S I< A E;I:::'ERF~/Y-.--E';I...IN WE:[._[. E;L.IRV.F.-.;Y I N('ji CL]MPANY A I',1C I--I (] R A Iii E A I.._ A S I< A COMPUTA'f'I ON DATE OCTJBER 14 DATE OF ..LIRVEY OCTOBER 10 ,JOB NUMBER AK-BO=60(~tSi:;:/&;;iL;.:~: KEI..I...Y BI_ISH I NG ELEV. = 11 '7.00 F' T. 0 F:' E F( A T OR-E. ' ' SEL.'.E 'E R i~i .......................................... M E A S I..I R E I) I:) E P T I-..I TRL.IE S;UB-$EA TL]TAL VI.'.C R"I' I (':'idd., ' VERT I CAL RE_'C'I'ANGLII._AF;t COr-~RD INA ]'iL::S MD-TVD VER'T I CA/... ......... I"~E:'F::' T H ............. I)EPTH N n F;~"I"I..-I/,.:::; A I I'I'H I::. A.::,'"" '"" '/1. WE. !:,"F D I F'F E.:R E::NF: E:. ...... CARFi:EC T I ON :1. 17 "-'-. ' 1 7 :3:1. '7 417 51. 7 ,'_'-,17 71 '7 81 7 'i? 17 10:1. '7 1'--'1.- 7 1:31 7 1417 1.=517 161 '7 17~7 181,_, i)] 00" 1 1 7 ,, 00 ":' 1'7 00 ':' 1. 7 C~C.~ .,.,~ ~ .... 4 :l '7. AO 717. ()0 817.00 '.:) :17. (?0 1. 01. '7. ()() 1:1. 1. 7 ,, O0 121 '7. AO 1:317.00 1417.00 :1.517.00" 161 '7. (')A :I. 717.00 1~::17.00' ARCO ALASKA~ '-" T - · ALA.z,I'... g ........................ :::IZ'ERRY-'-'-6,':I..,IIH WE".I..L.. SLII:;~V[i-"Y I NG COMF:'ANY PAGE 6 ~ N C H 0 R A G F_:: A I._ A S K ~ DATE OF ~,LIRVEY COMPUTATION DATE F;CTCIBER 14 1 o,-,/. ..... :.-oo dOB NUHBER .. . K ~ !.~ !.~ Y .BLJ S.i.H.,..,!,.N.f.'..t..,E...[.,-..E..~..... ......... :..=_..,K{..'_7.,.,.. 0 C.!. ,,...IF T, I":ll::'E R A"I" 0 R-. E. S E L.i_ E R S ................................................................................................................................. M E A :.-"!: I..I R E D [) E F::' 'T' H i!~:~:~': ~:~ ,(4::: ~.~:.~4:':f:.:,":. T' R !:-.I E. E;UB~- SEA ...................................... T..Q ~Og L,,,,,,. ::~? ~?::::~' ?,:.:::: ::?::'~?:~?:~:: VERT l CAI .... VERT l CAI_. REC:"I"AIqGUL..AR CO01:~D I NA'I'ES MD--TVD VER'I' I CAL. Ii E F'-I" k.I D E F' T H N Cl R 'T' H / :~; CI I...I T HE: A S 'T' / W E S 'f'D I F:' F' E R E N C E CCi R R E C T ICI N ......................................................................... 1 '!'-.~ 19 2 C):2:1 :2:1 ""'-' .C-'. · ') '") "], "D ..-, .-.. ~:.. -._~ · "* .'"f .'". .,S...:) .,::. -...I 2 4. 2 6 ..... _ d. 2/z, 2'.~ 27 :'3 0 2::i::32 2 9:3 4 :30:38 ':;'1 '4 2 :324'? ...-, ..:, f~ ,.--, ._1 ._~ ._ :3 4 6, '.:.:' -Z, ._' ,25 :_3 6, 5;' 1 1917. O0 2017.00 2117.00 22:1. 7 ,, 00 2 :.'.:.': 17. C> C'> 2 4.1 7 ,, () 0 2517. O0 2617.00 271 '7.00 26.': 17. O0 2'.::) i '7. ()C) 1 '.:.?00.00 .50.4.'.51 N ::::5. 1 7 ,:.r. 4.. 04 1.4 1 2:0 0 0.0 0 6:3 .2 7 N 4,5 .00 _'- 5 . ._"::,...,":' 1 . :3 0 :i?:t"O0 :' 60 .......................................... 7/-.7.":::..-:=,':~ ..... r,i ........ !!:~;.'["::'-;f;'~ ....... :' ............... /-, .... 71 1 .. ::-.'::.--.: 21210 (). ()0 90.09 I'-J 64. ';?0 :::: :.'.-'.:. 10 1. 139 230(). ()0 103. :30 N 7.5,, 00 7:;: 9.54 ].. 44 :24o0.00 ........... i'.t':, ?:.61.: ~ ' :::5.1 1 -:~ .................... i' i'"': :5"f .......................................... -f:"'~a-: ................................................................................ 2 5 0 ().,, 0 O. 1 3 ]. . ..,":"-?. Ixl '?.=; .1 1 ._'" 1 ...'--'. 4 4 1 . ,el :3 2,6 0 0.0 0 :i 4. 4.6.5 N 1 0 4.9 7" 1:3.7'.-7; 1.3 6 27()o. oo ........ :[ .5-::-'?:'!:!114' "iq' ' 1 i !'?,": 2'1' !':: ~...5. 211-: J.. 44 218 00. 0 0 :1 '7 5. '7 4 N 11218.4'7 .::i 1 7.6,:::-': 2 ,, 4 (") :3 0 :il. 7. O0 2 9() 0 ,, 0 0 1 9'7.2 1 N 1. 4- 4.0 1 i.'.i 2 1. () 9 :3.4 6 :::: 1 17. 'o6' ' '~:i500", 0-6 ............. ?2 i'-:"%:Y" N ............ i'?:121 :~;?' ::: ............................. ~t:;~':-]!~.~ ........................................ 4~ ................................................. 64 .:, ~ 17, 00 .-, 1 O. 0 . c.~. 0 :,-:'.. ~_ O.. 1 ._~-'i N 1 :'--: ..... 5 .42 ._ .:,'-' .."-', 20 6 .47 35:17 ...... O0 3200 , O0 282. 18 N 216, o._,'"'= _ = 41 , R":',_ .. 9.. 62 3417. . oc~ ..... ;33Cic~-' C'C~ ........ 315.54 N 250.77 .'C '_,..-'. F:~/-, .... 10.74 3617.()0 3500.00 382.77 N 31°. 10 S ' 74.4-1 10.9 37I 7' CiO !Y.:i'?~:Cici: i}O ................. 415.5::.: N ............ ::-;-~5-"'~;._, 4 ...._. ........ 7 'i:_ ................... -~::~;"o._.,. ,':"~ .... ....................................................................................................... '?. 48 ARco AL. AsIt:A, INC. 2]~--9 KUPARIJK AL.A'.F.:KA E:PERRY-EaJI',I WELL.. SLIRVEiYING COMF'ANY A N C H 0 R A G E A L. A S':; K A C'OMPLITAT I ;'_'iN DATE OCTOBER 14, 1'-'-' PA G E '7 DATE OF SURVEY OCTOBER 'I0, 1986 ,JOB NLMBER AK-,BO-6OQ~:~i::i.~ :...' :-. KE-"I....I...Y BI~iSH I NG EL..EV, = I 17. c)0 F'l". (] F' E R A 'T' 0 R'-E. '..:.; E L. L E R S MIFAE;LIRED DE:.F'I"H .INTenD VAL. UEo FL R EVEN T R I_1E 8 LIB- :, E A 1 J 1 A L :: '~:i:~'~'::?::: ~-::'. ".':':'" .......................... : . . ..................................... ,, .:....,.._.~.. ...... VERT I C:AL.. VERT I CAL I:~E:C'T'ANGL.IL. AR C:OORD INA TES MD..-TVD VER'I" I C:AL ................ DEF'I"H DEPTH NORTH/SOLITH EAE;T/WES-I" D I F'FE:RENCE CORRECT I ON ........................... :2:908 40.1. 6 41:2:4 4 '2:2:2 4:340 4448 455/0 4664 47'72 · 5 ()'.:.~ :-]: ...... · _ .--'0 7 '::'i":' 1 · .....,, P;4"" -_ .~L1 . fq -'::; 5.:'/~, .:.~ · .--, - ._, l:, .--, (..) 57:.3.':: .................. 5:--::36 :3:317.0 c) ::ii: 9 J. 7.00 4017.00 41. 17.00 421 '7 ,, 4 :"5:1 '7 ,, 00 :2:800.00 478.50 N 39C)C).0C) 510. I4 N 40()(), i50 ........... ~!14]1-7";.:~4' N 41 (').. (].. ().. c). ._,=' '73. '75 N 4200.0 () 6,() :5.4 () N 4417.00 .... 4300, C~) 4517. ()0 4400. O0 /:.6E:. 91 N 461 '7° ()('~ 450 ('). 0 () '701 · :3,.1. N 4 7 J. '7,, oo .... 4 ',!~: 17.00 4 '70,:'). 00 '768. :28 N .I.. 9 J. 7. ()0 4-:---:00.00 80:3. 1:3 N . . '- --"{ 7.._',:, "'N ....... 6 0'=; ....... 1 . .,:2'~:;'=:;/ ............................... E 1 ;='";:.-.! {.} ....... 4 ,~'"---~ ............................... . '------' ................ 5117.00 5000.00 E:70.1 '3 N 7()4.~),:,_" '-' E 1'~'~.:.-" 10 7.61 521 '7. O0 5100.00 "~'.. 01. :27 N '72:3 .... ':'6', E 204.61 6.52 541 '7, 00 5:.300.00 5517. O(b 5400.00 ~,:4 i ?]-i?Ci .......... -.~-i5i5 766-- ............ 9'28.78 N '? 52. :.-.:0 N 974 =;':' N · -.. ,_, 7:39. :3::: E 754.4::: E 768..32 E 209.64 5. (':)2 21:2:. 5'.'.:_' :.5:. 88 '216.. '8'C~ ':' :':"--, 219. .60 ~.":' 79 ARCO.. AL. ASI<A, INC, 2'1"-? KUF'ARLIK A I_ A S'; K A M E A S I_1R EL] D E F:' "1" H V E R 1" I C A L_ D E I:::' "1" I-..I F:OMPLITAT'I ON DATE OCTOBER 14, lC-' ELATE OF .SLIRVEY 5938 5717. 604 0 5817. 6142 5917. 624 4 6017 ,, 6 :.34,6. 611 '7, 637() 6140. ..... 00 5700 00 1 0 (] ...... H :::: (")(') . (")_ (;) 1041 . '.'.'? 4 N 8 `17 .7 7 E ~ ~:.,.,'-"-' :'. 51 1. '~"o 4 ()(_) .59()(). 00 105'7 ,, 30 Ixl ::.!::2'F.>, 30 E 227. :34 ;I, 82 () 0 60 C.) 0. () 0 1072,,'-,..'...., '=' N 840. 8:3 E ~,.."."".,_'-~' ':'"~... 1/:, 1 ,. 82 41 602:3 ,, 41 1 ()7 ............................................................................................................................................................................................................................................................... .......... I'HE CALC:LILAI"IrlN F'IROCEDLIRIES IJS;E A I_INEAR INTERF'OLATION BETWEEN THE NEAREST ;'2,r:, F:'O01" MD (FROM R('4.[)II_IS (;iF CLIRVATURE) POINTS SPERRY-SUN WELl. SURVEYING COMPANY ANCHOI:~AGE AI_ASKA ARCO ALASKA, INC. 2T-9 COMPUTATION DATE KUPARUK OCTOBER 14~ 1986 AI_ASKA F'AGE '~> , DATE OF SURVEY ObTCBER;:'~ ';':'":'i~'?'':::''''':'''''''''~10, ...................... 19o6;~ .............. KEL!_:.¥ .BU!i~;HI N!~. EbE.V... ......... Z.........!....~.. ..7. ..?.--.! !;!. F"T.? OF'ERATOR-E, '..:.;EI...LERS TRLIE ~,LIB-SEA TOTAL . ..................... MEASURE'D ......... VE~'Fi :F'i'~i~!i:i'~.~ VERT I J-:Al .... F:~EC TANGUI_AR BEP'I'I-~ DEPTH DEF'TH NORTH/SOLll"H EAS'T'/WEST MARKER 5979 5986 6006 6.tOo 614./::, 6:370 57/_-.3.37 564/:, 37 10 :I 8 17 N 7.99 66 E BASE i-:,LIF ARL I,:, C ~]'7,:,.s, '-.-~'T~ .=,/-/-=; 9'~) 1021 24 N L--.:02 r)4 E TOP KLIPARLIK A .... ,,::, / ........ -:..., ...,/ ...... - .... ....., .~, ,.- ....... -,~,~ 8 J. 2, . E: t.'.-i.';I. IRVEY DEF"I"H !:_-- '-:-, '2 0 , 4:3 5:F:0:..'-.:, 4::.-': 1042, 47 N :.'.-.':18, 1'7 E BASE KLIF'ARUK A /-. 0,:.].0,, 24 .5'.:.>23, :!:4 1060, :3'7 N 8:.'-.': :1 ,, 98 E F:'LLIG BACK 'I"L] 2T-~2 oTRArlGRAPHIC oLMMARY [~E~I__V.F_~_['£._!=I:::, I NO D I L £ EF 1 H._-, AND S;F'ER__RY .;,LIN SURVEY_ DATA '. :... c:,,.:;i';..?,.?::;~!?~;~:~i;?.~:!::!~:;,i~?...... :' .............. - ......... MAF;;I<Ii.:;F;; ............................. ' ........... 'i;i'~'iiii'i~ll:{£::I.) I.]['£F'TH . ........................... 1-VD ....................... ___ '~.' .]']:]Ic:i<NESS '~~']}-~ R~F',~ TO~WEI_LHEAD . TOF:' KLIPARI_IK C: ....... . ?..?.?'~!-~ ,':;--,':;, ,= ..... ,,.-, ............... ...... . ._ 7... ,':-,. ?'; 1 ._,c,..:, ::~ 51 101 I.':'.'{ A '.:.'i; [i~ I':.'.' I_1F' (-i R I...I K C: ~:--";'"" . ................. · .....,::...!..:.....,.._?.? ......... . .~:'~ '7 ,':, ::: :37 "::iz-,4/-, :5.-':7 ....................... 'l"i:)F' I-:::I..IF'i.'..~RI...II.::: A /::,(:)C)/:, !5 '7 :":~: ::-'i: , '!?'.'.'? 566,5 ,, i?'i.:~ 1 ('~'21 BASE K.'L~F'AF;:L;K A 614/_', ,'::;'~'~'--"('). 4:3 ="-' ' '-' 4:_:: "* '" ....... ,oU._-,, 1¢ 4..'. 47N 81R~. 17£ P I.... U G B A C I< T' D 62/"-, R 604 F) 24 =;':> """" ........ ,:..:,, 24 1060 87N '-"" TOTAL [')FiP'I"H DR 1LLER 6370 .6140.4.1 ~:,u.:..:,, 41 1076...: 1) FROM LINE:AR EXTRAPOL. ATIL-~N BEI....C,W DEE'F;Er-:;T'L'-.'i"FATI'C,N'~ .......................................................................................................... 2) L-:OMF'LITER F'RF.3RAM - ::;PERRY .:,_IN THREE DIMENSIONAL RADILIS OF C:LIRVATURE DATA CALCULATION AND INTERPOLATION BY RADILIS OF CLIRVATLIRE COP1F'LI"FATION DATE F..~A T E OF S.;t_.IRvE y OCT oB E R Iii(:)' I 1 '~] :~:~` OCTOBER 14, l'F~:-':6 ,_lOB NLIMBER AK-BO-60068 KELLY~.BUSH:!NG ELEV. = 117.00 FT. · · . 5CqLE ;- i INCH T8 500.00 / 500.0 Kd~qRdK qRco qLRSKq, !NC. 2T -9 OCTOBER lO. 1986 TRUE NORTh t~O00. CO 1-500 CC 6370 5CRLE ;- i INCh TO i500.00 / i500.0 KUPqRUK qRco RL9SK9, 2T-9 OCT8SE8 I0, qK-80-60068 O. CC - t986 6000. ~6370 NEW PROJECTS ENGINEERING TRANSMITTAL # 1031 TO: John Boyle DATE: Dec. 16, 1986 FROM: H. D. White/P. S. Baxter WELL Name: 2T-9 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of final bluelines and sepia for each: ~'~2T-9 2" Natural Gamma Spectroscopy ~2T-9 5" Natural Gamma Spectroscopy ~2T-9 2" Dual Induction SFL - GR ~2T-9 5" Dual Induction SFL - GR ~2T-9 2" Long Spacing Sonic - GR ~2T-9 5" Long Spacing Sonic - GR ~2T-9 2" LDT-CNL-NGT (Porosity) ~--2T-9 5" LDT-CNL-NGT (Porosity) ~2T-9 2" LDT-CNL-NGT (Raw Data) '~'-2T-9 5" & 25" LDT-CNL-NGT (Raw Data & Hi-Res) '~-2T-9 5" & 25" Electromagnetic Propagation ~2T-9 5" Dual Dipmeter - GR ~2T-9 Cyberlook 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 6/27/86 run 2 RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: DATE: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, AT P. O. Box 100360 Anchorage, Alaska 99510 · STATE OF ALASKA ALASKI ,L AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown ~ Stimulate ~ Plugging ~- PerforateY~ Pull tubing Alter Casing C Othery,.~: Com._p_-Lete 2. Name of Operator ARCO Alaska, Inc 3. Address Po O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 227' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1244' FSL, 1355' FWL, Sec. 1, T11N, R8E, UM At effective depth 1288' FSL, 1388' FWL, Sec. 1, T11N, R8E, UM At total depth 1303' FSL, 1400' FWL, Sec. 1, TllN, R8E, UN 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number ?T-9 8. Approval number 168 & 279 9. APl number 50-- 103-20071 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 1957' feet 6370'MD feet 6140'TVD 6268'MD 6040'TVD Size 1 6" 1 0-3/4" feet feet Production 6321 ' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth ~ue Verticaldepth 255 sx CS I I 1lO'MD 110'TVD 850 sx AS I I I & 160 sx Class G 1992'HD 1988'TVD 540 sx Class G & 6351'MD 6122'TVD 175 sx AS I Perforation depth: measured 6022' true vertical 5 799 ' Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 5936' Packers and SSSV (type and measured depth) 6058'MD 5834 'TVD HB-1 pkr ~ 5888' & TRDP-1A-SSA SSSV ~ 1806' 12. Stimulation or cement squeeze summary InteNrv/a/~s treated (measured) Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Injectio~;~.t'%'" OiI-Bbl Gas-Mcf Water-Bbl Casin~l P~es'Sure ',~ _:~ '. 13. Prior to well operation Subsequent to operation 14. Attachments (Completion Well History, w/Addendum, dated 7/28/86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~' Form 10-404 Rev. 12-1-85~" Associate Engineer Title Date //-/c¢.~, j ~,L~^M~ 5Wf¢/~2 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Inatructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is avaiiabie. District Alaska Field Kuparuk River Accounting cost center code ICounty or Parish State North Slope Borough Alaska JLease or Unit IWeI, no. ADL 25569 2T-9 ITitle Auth. or W.O. no. AFE AK0766 Completion Nordic 1 API 50-103-20071 Operator A.R.Co. W.I. 56.24% ARCO Alaska, Inc. Spudded or W.O. begun Complete 10/12/86 thru 10/13/86 10/14/86 Date and depth as of 8:00 a.m. Date Complete record for each day reported 10/12/86 I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 1630 hrs. 7" @ 6351' 6178' PBTD, MU hgr 12.0 ppg brine Accept rig @ 1630 hrs, 10/12/86. ND master vlv. NU & tat BOPE to 3500 psi. RU Schl, perf 6040'-6050' w/4 SPF & 6022'-6040' w/1SPF. RD WL. RU & rn 2-7/8" compl string. 7" @ 6351' 6178' PBTD, RR 6.8 ppg diesel Set pkr @ 5887', tat ann to 2500 psi, tst SSSV; OK. ND BOPE. NU & tat tree to 250/5000 psi. Displ w/diesel. RR @ 1330 hrs, 10/13/86. (Rn 187 jts, 2-7/8", 6.5# J-55 AB Mod 8RD EUE tbg w/SSSV @ 1806', HB-1 pkr @ 5888', TT @ 5936') Old TD New TD Released rig Date 1330 hrs. Classifications (oil, gas, etc.) Oil I PB Depth 10/13/86 IKindOfrig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 6178' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day _ -~ump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 7/22/86 2T-9 Arctic Pak w/175 sx AS I, followed by 87 bbls Arctic Pak. I~rilling Supervisor ARCO Alaska, Inc. Post Office B6x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE· 11-7-86 Transmittal #5819 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records.Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-2 CBL 10-12-86 7000-8786 Run 1 2T-3 CBL 10-12-86 3135-7780 Run 1 2T-5 CBL 10-11-86 3842-7548 Run i' 2T-6 CBL 10-13-86 3400-8007 Run 1 2T-8 CBL 10-10-86 5100-7475 Run 1 2T-9 CBL 10-10-86 2900-6174 Run i Receipt Acknowledged' Distribution' BPAE(1 bl) Unoc~ Mobil(1 bl+l se, .Drilling(1 bl · Naska 0il & Gas Cons. Anchorage SSlOn bl+ Chevron(1 bl+l se) NSK(1 bl) se) L. johnston(1 bl+l se) Vault(1 film) ARCO Alaska, Inc. Extension Explorat. ion TRANSMITTAL_ TO: ADDRESS: · FROM DATE:_.0rt_ ~n; Transmitted herewith are the following: Well Data ARCOi" Kuparuk 2T-2(K-lO sands) 9-25-86 ~~Tap~Edit Lis 3555.0-.4600.0 - 9-25-]~6/ ~-~-N-~Poro Blu/$epia ' ~'-Z'~'$ 5" 3561~,4500 ixr~- ~ CNFD/Raw " ~ ~ 97~5-86 ~DIL/Sfl Blu/Sepla 3561-4500 s Tape ~ · 7-3-86 -' '~- ~600 BPI 2666 5 - 3~00,0 7-3-86 ON/Poro Blu/Sepia ~2"~" 2666-6~ 7-~-86 OlL/5~] Blu/Sepia ~2,~ S~5,, ~668-6~60 2680-6354 '11 ~ I Run 1 II II Run 3 II Run 3 II RECEIPT ACKNOWLEDGMENT Return receipt to: '------- ' ~ ARCO Alaska, Inc. Anchorage Extenstion Exploration ATTN: Lucille Johnston A~JO P. O. Box 100360 Anchorage, Alaska 99510 R E C ),ea ,_L. ,,o,,r,,,:o- DEC 2 4 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Extension Exploration TRANSMITTAL TO: Bi I 1 VanA1 ~n -Anr, r. ADDRESS: 5OO1 Pgrcupine Dr. FROM '. DATE'. Craio Moselev -Arm · 0~*_3n~ 1996 Transmitted herewith are ARC~~ Kuparuk 2T-2(K-10 sands) the following: Wel 1 Data 9-25-86 !"<:Eis~ Ta~-~---~Edit Lis 3555.0- 46OO.0 9-25=,86'- ~4CNFD/Poro Blu/Sepia ~2'~&_ 5" V -~ CNFD/Raw " ~- 97"~5-86 .... ~ DIL/Sfl Blu/Sepia ' ~2' (~5'' / 3561-4500 Run 1 II II 3561-4500 " :~3 Kuparuk 2T-9(K-10 sands) 7-3-86 : ...... ~§ Tape ~-~ 1600 BPI 2666.5- 3400.0 7-3-86 DN/Poro Blu/Sepia '~ 2" ~&~x5'' " DN/Raw " ~ "~ 7-3-86 DIL/Sfl Blu(Sepia ~2" &~5" " LSS-Gr " .... '~ 2666-6334 Run 3 II II ~668-6360 Run 3 2680-6354 " RECEIPT ACKNOWLEDGMENT: Return receipt to' Anchorage, ARCO Alaska, Inc. Extenstion Exploration ATTN: Lucille Johnston P. O. Box 100360 Alaska 99510 At,JO Processed By: L. Johnston ! >-, L''' , -. . ,.~_~ ..,£i- , ARCO Alaska, Inc. Extension Exploration TRANSMITTAL TO: B i 11 VanA l an - AOCC. ADDRESS: 3001 Porcupine Dr. FROM: Craiq Mo,~elev - Arr_n DATE: Oct. ~0_ ]qF~ Transmitted herewith are the following: Well Data ARCO: Kuparuk~T-3(K-lO sands) 9-12-86 Lis Tape Open Hole Kuparu~2T-6(K-lO sands) 8-21-86 Lis Tape Open Hole Kuparuk 2T-8(K-10 sands) 7-22-86 Lis Tape Open Hole 3160.0 - 4100.0 3874- 4210 2948.5 - 4000.0 RECEIPT ACKNOWLEDGMENT: Return receipt to: ARCO Alaska, Inc. ~-'~'- Extenstion Exploration ATTN: Lucille Johnston P. O. Box 100360 Anchorage, Alaska 99510 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-20-86 TRANSMITTAL # 5801 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole Logs: One * of each 2T-9 *These are combination Run #1&3 Logs. To save space they are listed as Run #3. '"45" DIL/SFL 07-03-86 Run #3 2668-6360 ~"~2" -DIL/SFL ""~5" Comp.Neu/Form. Den (poro) ""~2" Comp.Neu/Form. Den (poro) "'~5" Comp.Neu/Form. Den (raw) ~-~2" Comp.Neu/Form. Den (raw) %"'A5" LSS-GR ~.-3~, LSS-GR '"~Cyberlook ~"~5" Dual Dipmeter-GR "-~-RFT Log 2T-1~5" DIL/SFL-GR ~'- ~'O2" DIL/SFL-GR x"35" Den/Neu-GR (poro) ""~2" Den/Neu-GR (poro) "'~5" Den/Neu-GR (raw) ~"~2" Den/Neu-GR (raw) '"-O Cyberlook 07-03-86 Run #3 2668-6360 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2680-6354 07-03-86 Run #3 2680-6354 07-03-86 Run #3 5800-6300 07-0~-86 Run #3 2680-6364 07-04-86 3112-6056 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7690-8140 3N-1~5" DIL/SFL-GR ~'~2" DIL/SFL-GR x~,, Den/Neu-GR '"~2" Den/Neu-GR '"'~5" Den/Neu-GR ~'~2" Den/Neu-GR "-~Cyberlook Receipt Acknowledged: (poro) (poro) (raw) (raw) 05-04-86 Run #2 2579-7451 05-04-86 Run #2 2579-7451 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7400 NSK Files*bl Rathmell*bl D &M *bl Vault*films ARCO Alaska. Inc. is a Subsidiary of AtlanticRichtieldCompany ARCO Alaska. Inc. Post Office B,.,~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE 07-30-86 TRANSMITTAL # 5 72 7 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Open Hole LIS Tapes Plus ' ~2T-8 ' 07-21-86 ~ 2T-9 ~ 07-03-86 -~ 2T-12A/07-12-86 ~ 3K-3f 06-27-86 -~ 3K-4/ 07-04-86 ---~3K-5~ 07-12-86 Run #1 Run #3 Run #1 Run ~1 Run #1 Run #1 Listings: Schl: 0097.5-7669.0 3300.0-6389.0 4885.5-6756.0 0187.0-8929.0 2992.0-8937.5 2388.5-8168.5 Please acknowledge receipt and One copy of each EDIT EDIT EDIT EDIT AlaskaOil & Gas Cons. Com~,ssion Anchorage Receipt Acknowledged: state -of Alaska -- ARCO A|IIII, Il'lC, ,I · SuOl,O,ary of AllafltlcR1chf~elclCc~mDlnY Date: ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 07-12-86 TRANSMITTAL # 5702 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes: Schl: One tape plus listing for each ~2T-9 Edit LIS 06-22-86 Run #1 0067.0-2023.5 ~2T-10 Edit'LiS 06-18-86 Run ~1 0995.0-8314.5 ~2T-11 Open Hole 06-05-86 Run #2 1441.5-6812.0 ~ 3K-1 Open Hole 06-10-86 Run #1 2992.5-9025.0 ~ 3K-2 Edit LIS 06-19-86 Run ~1 0994.0-9974.0 Alask,~ 0il & Gas Cons. Commissio;~ Anchora~ Receipt Acknowledged: ARCO Alaska. Inc. is a Subsidiary o! AllanticRichlieldCompany Date: STATE OF ALASKA ALASt,,., OIL AND GAS CONSERVATION COMi,..J, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend % Operation Shutdown ~ Re-enter suspended well -- Alter casing -' Time extension _--.. Change approved program ~ Plugging '~ Stimulate 'Z. Pull tubing- Amend order-- Perforate-' Other - 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska,_ Inc. 117'RKB feet/ 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 227'FSL, 556'FWL, Sec.1, T11N, R8E, UM At top of productive interval 1350'FSL, 1309'FWL, Sec.1, T11N, R8E, UM (approx.) At effective depth 1284'FSL, 1373' FWL, Sec.1, T11N, R8E, UH (approx.) At total depth 1300'FSL, 1385'FWL, Sec,1, T11N, R8E, UN (approx.) 7. Well number 2T-9 8. Permit number 86-110 9. APl number 50-- 103-20071 10. Pool KuCaruk River Oil Pool 11. Present well condition summary 6370 Total depth: measured true vertical 6143 Effective depth: measured 6268 true vertical 6043 %sin. g nductor Surface Length 80' 1 957 ' 6321 ' Production feet feet feet feet Plugs (measured) None Junk (measured) None Size Cemented Measured depth 16" 255 sx CS I I 1lO'MD 10-3/4" 850 sx AS III & 1992'MD 160 sx Class G 7" 540 sx Class G 6351 'MD True Vertical depth 110'TVD 1 989 ' TVD 61 24 'TVD None Perforation depth: measured true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None RECEIVED J U L 2 4 1986 Alaska Oil & Gas Cons. C0mmissI011i Anchorage 12.Attachments 13. Description summary of proposal [] Well History & Core Description Estimated date for commencing operation September, 1 986 14. If proposal was verbally approved Name of approver Detailed operations program ~ BOP sketch ~ ..¢. ? ~' ";" ' .. :. ,. .:: ~,.~. I 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~0~.~f4-J-L~ Title Associate Engineer Date Commission Use Only (DAN) SA/081 Conditions of approval Notify commission so representative may witness i Approval No. ~ '¢ ~ Plug integrity ~ BOP Test ~ Location clearanceI ~ ~ ~. , ~,~f~.~ ~;~'~ ,~ ~_.~. ............... by order of Approved by :' Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 2T-9 CORE DESCRIPTION Core #20 Core #21 Core #22 5965' - 6026'; cut 61', recovered 61' 60' shale, 1' sandstone 6026' - 6086'; cut 60', recovered 60' 39.7' shale, 20' sandstone 6086' - 6146'; cut 60', recovered 60' 57.8' shale, 2' sandstone RECEIVED J U L 2 z~ 1986 Alaska 0il & Gas Cons. Commission Anchorage GRUl/20.tw 07/16/86 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0766 Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 6/21/86 thru 6/23/86 6/24/86 6/25/86 6/26/86 Date and depth as of 8:00 a.m. County, parish or borough North Slope Borough Lease or Unit ADL 25569 Title Drill API 50-103-20071 State Alaska Well no, 2T-9 IDate 6/20/86 IHOur Complete record for each day reported 2200 hrs. ARCO W.I. Prior status if a W.O. 56.24% 16" @ 110'/10-3/4" @ 1992' 2010', (1900'), DO cmt Wt. 9.3+, PV 11, YP 32, PH 9.5, WL 5.6, Sol 5 Accept rig @ 1530 hrs, 6/20/86. NU diverter sys. Spud well @ 2200 hrs, 6/20/86. Drl & surv 13-1/2" hole to 2010', wiper trip to 1566', C&C, POH f/logs. RU Schl, rn DIL/FDC/CNL/GR/CAL POH. Rn LSS/GR f/1996'-110', RD Schl. Make cond'g rn. RU & rn 48 its, 10-3/4", 45.5#, J-55 HR/ERW csg w/FC @ 1907', FS @ 1992'. Cmt w/850 sx AS III w/10#/sx Gilsonite, follwed by 160 sx C1 "G" w/2% S-l, .2% D-46. Displ using rig pmps, bump plug. CIP @ 1700 hrs, 6/22/86. ND diverter. NU &tst BOPE. RIH w/BHA, DO cmt & FC. 1576', Assumed vertical 1683', 3.9°, N32.7E, 1682.94 TVD, 3.64 VS, 3.02N, 2.03E 1960', 10.0°, N31.3E, 1957.70 TVD, 37.99 VS, 32.53N, 19.77E 10-3/4" @ 1992' 2240', (230'), RIH f/core #5 Wt. 9.2, PV 12, YP 10, PH 9.5, WL 6.0, Sol 5 DO cmt & FS + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 9-7/8" hole to 2150', CBU, POH. RIH & core #1 f/2150'-2180', 100% rec'y. Core #2 f/2180'-2200'; 90% rec'y. Core #3 f/2200'-2227'; 100% rec'y. Core #4 f/2227'-2240'; 100% rec'y. RIH w/core #5. E C E I V E D 2130', 9.8°, N38E, 2125.17 TVD, 67.22 VS, 56.57N, 36.39E --- 10-3/4" @ 1992' JUL 2 4 1986 2394', (154'), RIH f/core #11 Wt. 9.2, PV 14, YP 14, PH 10.0, WL 5.8, Sol 5 Core #5 f/2240'-2243'; 100% rec'y. Core #6, 2243'-227~k~0%~ & G~s Cons, Commission rec'y, core #7, 2274'-2303'; 100% rec'y. Core #8, Anch0ra~e f/2303'-2334'; 100% rec'y. Core #9 f/2334'-2363'; 100% rec'y. Core #10 f/2363'-2394'; 100% rec'y. RIH w/core #11. The above is correct Title 10-3/4" @ 1992' 2524', (130'), TOH w/core #16 Wt. 9.2, PV 15, YP 14, PH 9.5, WL 5.0, Sol 5 Rec'd 103% f/core #10. Core #11, 2394'-2421'; rec'd 55% (left 12' of core on btm). Wsh'd over 12' core left in hole, cut core #12 f/2421'-2440', core fell out, 3% rec'y. Core #13, cored over core #12; 0%.rec'y. Core #14, 2440'-2465', servicing core bbl, 129% rec'y. Core #15, 2465'-2494'. Core #16, 2494'-2524', POOH. ~.~,..... ", .... For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. Alaska County or Parish North Slope Borough Kuparuk River Lease or Unit ADL 25569 Complete record for each day while drilling or workover in progress IState Alaska IWell no. 2T-9 District Field Date and depth as of 8:00 a.m. 6/27/86 6/28/86 thru 6/30/86 7/01/86 10-3/4" @ 1992' 2851', (327'), Logging Wt. 9.2· PV 10, YP 9, PH 9.5, WL 5.4, Sol 5 Rec'd 14' f/core #16. Core #17, 2524'-2536'; rec'd 6'. Core #18, wsh'd over core #17 + 2'; rec'd 28'. Core #19, 2538'-2562'; rec'd 30'. Drl 9-7/8" hole f/2562'-2851', short trip to 1991', TIH, wsh to TD, TOH. RU Schl, rn DIL/SP/GR/LSS. 2831', 9.3°, N35.5E, 2816 T%~, 183 VS, 150N, 106E 10-3/4" @ 1992' 5965', (3114'), Coring Wt. 11.8, PV 16, YP 13, PH 9.0, WL 6.0, Sol 14 Rn LDT/CNL/NGT/EPT f/2856'-1994' WLM. Rn SHDT, RD loggers. TIH w/BHA, wsh 2789'-2851', slide to 3053', TOH to 1863'. Conduct formation tst @ 3032' to 12.1 ppg EMW & @ 1863' to 13.55 ppg EMW. Drl & surv 8½" hole to 5471', TOH, conduct formation tst to 12.5 ppg EMW. Fin TOH. PU BHA, TIH to 1900', conduct formation tst to 10.1 ppg EMW, drl & surv 8½" hole to 5965'. , N37.8E, 2959 TVD, 214 VS, 174N, 124E · N39.2E, 3228 TVD, 298 VS, 241N, 175E · N37.9E, 3777 TVD, 536 VS, 420N, 335E · N39.9E, 4422-TVD, 798 VS, 623N, 502E , N37.1E, 4739 TVD, 929 VS, 726N, 584E , N30.4E, 5418 TVD, 1192 VS, 942N, 734E , N35.3E, 5717 TVD, 1267 VS, 1003N, 777E 2977', 14.5° 3259', 20.6° 3858', 22.1° 4554', 22.2° 4897', 22.9° 5626', 15.5° 5935', 12.3° 7/02/86 7/03/86 10-3/4" @ 1992' 6026', (61'), Circ on BTM Wt. 12.0, PV 26, YP 14, PH 8.5, WL 5.6, Sol 20 TIH w/C. #1. Washed 5905-5965. Cored 5965-6026. TOH. Inner BBL broke between 2 Jts. Rec. 60.5' core. Svcd core BBL. TIH. Circ B/U & dropped orient tool. 10-3/4" @ 1992' 6120', (94'), Coring Wt. 12.0+, PV 24, YP 14, PH 8.5, WL 5.2, Sol 19 Core #2, 6026'-6086'; rec'd 59.7'. Core #3, 6086'-6120', incompl. RECEIVED J U L 2 4 19B6 Alaska Oil & Gas Cons, commission. Anchorage RU 10-3/4" @ 1992' 6370', (250'), RU Schl Wt. 12.0+, PV 25, YP 10, PH 8.5, WL 5.6, Sol 20 Core #3, 6120'-6146'; rec'd 59.8'. RIH w/BHA, wsh f/6056'-6146', drl to 6370', 10 std wiper trip, CBU, POOH. Schl. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date Title Drilling Supervisor 'ARco Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an o[ficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District JCounty or Parish I Alaska Field ~Lease or Unit Kuparuk River I ADL 25569 Auth. or W.O. no, ~Title AFE AK0766 I Drill Rowan 34 AP1 50-103-20071 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 6/20/86 Date and depth as of 8:00 a.m. 7/04/86 thru 7/07/86 Complete record for each day reported Accounting cost center code State North Slope Borough Alaska I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well our I Prior status if a W.O. 2200 hrs. I 7" @ 6351' 6370' TD, RR Wt. 12.0 NaC1/NABR Run #1 - DIL/SFL/GR/SP/FDC/CNL/CAL - Had tool failure/work on line out of hole. RIH & logged fr/6366-2700'. R/D combo & RIH Run #2 GR/LSS fr 6358-2700'. Run #3. Problems w/shot so ran WSP. Checkshot survey from 6360-200. Run #4 SHDT fr 6360-2700'. Finish Run #4 SHDT. R/D S.O.S. RIH Break circ @ 1990'. Wash 90' to bottom. Circ & condition mud. Drop survey. POH. Retrieve survey. Run RFT. 1 good Record # 3202 for K-10. 6 recordings of "A" sand pressures. Caught one core sample from each zone. POH. Retrieve samples & R/D S.O.S. RIH. Circ/condition mud. POH 20 stands. L/D BHA. Change Kelly 5" for 3-1/2". R/U & run 156 jts 7" 26# casing'w/marker jt @ 5948', FC @ 6269', FS @ 6351'. Circ/rec'p. Lost 378 bbls mud. Mix/pump 340 sx lead, 200 sx tail cmt, of class G cmt. Displaced with 240 bbls brine. Bump plug 3000 psi. CIP @ 1630 hrs 7/05/86. R/D cmt. hd. Change 5" rams to 3". N/D stack. Set slips. Cut 7". Install PACKOFF. N/U C.I.W. tubing head. Test packoff 3000 psi OK. Injected 80 bbls diesel in 10-3/4" x 7" annulus. Cleared 120' Brine from 7". Ri~ Released @ 2400 hrs. 7/05/86. Old TD Released rig 2400 hrs. New TD Date Classifications (oil, gas, etc.) Oil Producing method Flowing PB Depth 6370' TD 6268' PBTD Kind of rig 7/05/86 Rotary Type completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected The above is correct ,~"-~ t Title ~/~7- Drilling §up',ervzsor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. MEMORANDUM State of Alaska ALAS~_A OIL Ai~ GAS CONSERVATION CO,~ISSi~..,~~ TO: C.V. Chatt~/~~ DATE: June 26, 1986 Chairman FILE NO.: D.ADA.28 THRU: Lonnie C. Smith / F?7 TELEPHONE NO.: Commissioner FROM: Doug Amos Petroleum Inspector SUBJECT: BOP Test ARCO KRU 2T-9 Permit No. 86-110 Kuparuk River Field SeturdaY, June 21, 1986: I traveled this date from Prudhoe Bay to Knparuk to stand bY for the BOp test at ARCO's KRU 2T-9 well. Sunday, June 22, 1986: The testing was delayed because of surface h01e problems. Monday, June 23 1986: The testing commenced at 12:15 a.m. and was ~OnCin~&d at 2 '~'5 a.m The lower pipe ram master accumulator valve failed, but was replaced and retested this date. I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test at ARCO's KRU 2T-9 well. 32-001 A ( Rev 10-84) _ O&G 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report · . Well Location: Sec,. I T J l ~R~__M ~A, ~' Drillin~ Contractor. ~,~O~-~ R.i~ ~/ ~ Representative Location, General ~)~ Well SiEn ~; ~' General Housekeeping D~ Rig. Audio Representative . ~J, :~VW~Y~F'~ Permit ~/ ~;~- -'~ ~ C~ Set I 9.V-- Reserve Pit ~.~< Mu,d Systems Visual Trip Tank ~ Pit Gauge ~_~ Fl°w Monitor ~ ~ Gas Detectors . ~ . Test Pressure BOPE S tack Annular Preventer Pipe Rams ~dq ~.w'~Z Blind Rams ~ Choke Line Valves~ H.C.R. Valve ~ Kill Line valves ~'_~ Check Valve ?'~" l ACCUMULATOR SYSTEM Test Results: Failures Full Charge Pressure ~O~O. PreSsure After Closure ~~ . Pump incr clos. pres. 200 psig Full Charge Pressure Attained: psig psig I rain ~; sec. min_gCkse . N2 ~.~-~} ~,~;~ Controls: Master 'No. flanges .. Adjustable Chokes Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. ~ Test Pressure Lower Kelly~/i Test Pressure Ball Type ~w I..Test Pressure Inside BOP ~ I Test Pressure · Choke-Manifold ~ ~ Test Pressure No. Valves / .Q~ ~, . Hydrauically operated choke Test T'~ne__ ~ -hrs ,, Repair or Replacement Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector . ~ STATE OF ALASKA AP'PLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing/~ Time extension' [] Change approved program ~ Plugging [] Stimulate [] Pull tubing E Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB 82' PAD feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchora.qe~ AK 99510 KHnarLJk River Ilni~-_ 4. Location of well at surface 7. Well number 227'FSL~ 556~FWL~ Sec.l~ T11N~ R8E~ UM 2T-9 At top of productive inte~al 8. Permit number 1305'FSL~ 1309'FWL~ Sec.l~ T11N~ R8E~ UM 86-110 At effective depth 9. APl number 50--1 03-20071 total depth 10. Pool At1369~FSL~ 1356'FWL, Sec.l~ T11N~ R8E~ UM Kuparuk River Oil Pool 11. Present well condition summa~ Total depth: measured feet Plugs (measured) N/A true vedical feet Effective depth: measured feet Junk (measured) N/A true ve~ical feet Casing Length Size Cemented Measured depth True Vedical depth Conductor 80' 16" 200 cf 115'MD 115'TVD / , Perforation depth: measured Nu~, ~,~,. ~,~ ~ E C 5~~[ true vertical ~, JU~ ~ O '~'4~ Tubing (size, grade and measured depth) Al~s'ka 0il & G~.:. ~ns. Packers and SSSV (type and measured depth) 12.Attachments Description summa~ of proposal ~ Detailed operations program ~ BOP sketch 13. Estimate~ date for commencing operation '" June 16, 1986 ,, ,ro,o.a, was versa,,, a,,rov., Name of approver Date al 15. I hereby certify that the foregoing is true and oO~t to the best of my knowledge Commission Use Only (HRE) SA/060 ~ Plug integrity ~~c~e~t d~yLocation clearance By ordor of Approved by ~ [:~ C. S~tT~ Commissioner the commission Date ~ ~//-~ Form 10-403 Rev 12-1-85 [ 2T-9 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to the addition of a West Sak core in well 2T-9, ARCO Alaska, Inc., proposes to: 1. Drill 13-1/2" hole to 2004'MD (2000'TVD) with a kickoff point at 1550'MD. 2 Run 10-3/4" 45 5# J-55 BTC surface casing @ 2004'MD and cement with 792 sx AS Ill and 158 sx Class G. 3. Drill 9-7/8" hole to West Sak core point. 4. Core West Sak and K-lO Sands interval. 5. Drill 8-1/2" hole to Kuparuk core point. 6. Core Kuparuk Sands. 7. Drill 8-1/2" hole to TD ~ 6377'MD (6142'TVD). 8. Run 7", 26.0#, J-55, BTC production casing @ 6377'MD. Cement with Class G. Note required cement volume will be determined from caliper log measurements and all hydrocarbon zones will be covered. 9. Complete well as per original drilling permit. SA/O6Oa:tw ARCO =ALASKA-. tNC. PAD 3T. WELL NO, 9 REVISED_PROPOSAL K UP A__R. _UK_ _E !~ L D _,, __ £ASTHAN WHIPSTOCK*- . BUILD 3 DEl3 PER 100 FT' EOC TVD"'1881 THD=1883 DEP'29 2000] -~'1 ~* T! WEST SAK SNDS TVD-2271 TI"ID-2279 'DEP-98 ~ AVERAGE ANGLE. -' K:i 2- -' TVD~26i i' THD~2624- DEp= 157 KOP TVD-2800 TrlD-2816 DEP-191 EOC TVD=3209 TMD=3243 DEP=311 AYERAOE ANOLE 22 DEO 48 HIN K-5 TVD=4311 TMD=4438 DEP=774 10 DEG 5000 __ 6( ...... 7000 I - BEG~l~-A~E'--DROP-!-TVD=5'~)85 Tl"ID=5278 DEP=I 1 O0 ' DROP ! 1/2 DEG PER ! O0 FT TI ZONE C (END ANGLE DROP) TVD-5771 TrlD-5998 DEP"1315 ', T/ ·ZONE A TVD-TVD-5826 TrlD,-6054 DEP=1327 ..... TARGE-T-'-CNTR- TV-D--5859 TI'ID-6088- DEP= 1:3:34- B/ KUP SNDS TVD=5946 TrlD=6177 DEP=1::352 TD (LOG PT) TVD=6142 TrlD=6377 DEP=1394 i 1000 VERTICAL- SECTION TARGET ANGLE 12 DEG 2000 ~ ~oo ~oo ~oo ~ootoo : m~-~ ~.~.~:--~ ' ~.~ . :'" .200 ,, -. ~.~ ,,_, ~'.~ ~,_.~ ...~.lO0-~ 3OO 20O poO) ooo , / I ~ i,, ............. 7// , '"'*~737 ~700 ) , ! : Foo Boo i ' ' J 400 500 600 900 _ I ,1000 I t100 _ 201 Z 2DO0 1000 ~F/d::::E: L(X::AT [ ~ ~ 22?" FSL. 556' FWL SEC- 1. T11H. RI~E I Z O NI.AL ....... PRDJ E O T, i. 13N .... SCALE i5IN. - 1000 FEET - .. 'RCO 'LASK . INC. ': :' '"~ ~ ~AD 2f. "E~L NO' 9: "EVISED'PROPOSAE KUPARUK FIELD, ,OETHiSLOPE' ALASK^ : EASTMAN WHIPSTOCK. INC. i , WEST.EAST 1)00 O ~ 1000 SUR. FAOE ! ._ , . ,, TAR~'ET CE#TER .......... TIt'D~58,59 TtlD-6088 D~= 1 ~ m E&Sr ?64 ..................... N 34 DEG 57 M::IN E' ,.. 1334..' ~'(TO TARGET) TAROI[T LOCATIO#~ !3~' FSL. !320' FWL SEC1 1. T11N. RSE i ................. i TD" i.:OCAT ~ON', ' i369' FSL.: 1354' .F~. I b"EC. ~. TIt#. RSE June 3, 1986 Mr. J. B. Kewin Regional Drilling Engineer ~RCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 2T-9 .ARCO Alaska, Inc. Permit No. 86-110 Sur. Loc. 227:FSL, 556'F!:U~, Sec. 1, TllN, R8E, Ul.i. Btm2ao!e Loc. t369'FSL, 1354'F~L, Sec. 1, TllN, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C, V. Chattegton Chairman of ' Alaska Oil and Gas Conservation Commission BY ORDER OF ~{E COPH'%ISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enci. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C,.. _.4MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill Re-Entry .~, Deepen[]1 Service [] Developement Gas ~ Single Zone'~ Multiple Zone L~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po(: P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 227'FSL, 556'FWL, Sec.1, T11N, R8E, UN Kuparuk River Unit 5tatewide At top of productive interval 8. Well nu .mber Number 1305'FSL, 1309'FWL, Sec.1, T11N, R8E, UM 2T-9 #8088-26-27 At total depth 9. Approximate spud date Amount 1369'FSL¢ 1354'FWL¢ Sec.l~ T11N~ R8E~ UM 06/10/86 $500¢000 12. Distance to nearest 13. Distance to nearest well 14..Number of acres in pr0pert:/ 15. Proposed depth (MD aodTVD) property line 6499 ' MD '~911 ' ~ TD feet ?T-lf') ?.~'¢ .~,rfa¢.~. feet 2.560 (6142'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2960 feet Maximum hole angle 38 0 Maximum surface 1 664 psig At total depth C-VD) 3324 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' :1:200 cf 12~" 9-5/8" 36.0# J-55 BTC 2776' 35' 35' 2811 ' 2811 ' 670 sx AS I I I & HF-ER~/ 325 sx Class G blend 8~" 7" ?~ fl~ .I-~;c; RT~ ~b-Rc,' '~b-' ~4' ¢;b.c~c~' Rlb.?~ ?¢)C) .~x CI~_~_~ G fminim,~n HF-[R¢ T0C 500' above toD of 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Kupa ruk. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural · , . _ Conductor . ~ .... ~ - .', -.,:. Surface · Intermediate Production Liner '--.-.. Perforation depth: measured ~ % i~ .~.,. ;; ~-, ;::. ..' " ...... true vertical 20. Attachments Filing fee Drilling fluid program 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'.-8. ~'~~,~ l¢~,~'.~_TitleRegional Drilling Engineer Date4~2~, / Commission Use Only PD/PD273 ( 2 ) Permit Number ¢.~ APl number I Approval date I See cover letter ,J ~-f(',b 50-- /O.~-' ~ ~:' '~'7 ( 06/0.3/86 for other requirements I I Conditions of approval Samples required ~., Yes ~' No Mud log required ~ Yes '~ No Hydrogen sulfide measures C Yes .~, No Directional survey required ~Yes .,~ No Other:Required working~~.8~~~pres e for BOPE ~2M; i 3M; ~ 5M; [] 10M; ~ 15M by order of ~.~~, Approved by Commissioner the commission Date · Form 10-401 Rev. 1~ Su bmit/a'q triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure If RECEIVED 0il & G-~s C0r:~. u~: ......... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , ~ · ~4 I 6 LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. I~ ~IIN~8[~ ~.~. SEC. I~ TII~ES[~ U.~. ~ - Y - ~,~7O,~Sl.I~ LAI. 70~l~'t9.l~7'' l0 - Y = ~,970,l~.6~ MT. ~0~lg't~.~ll~ X ' 498,944. ~3 L0~. iS0o00' 30. 807" X = 498, ~45. ~7 L0~. 150°00' 30. ' 402' FSL, 556' F~L 0G = ~7' PAD = 81.5 iS~'FSL, 556' F~L O~ · 76.0 ~AD 3 - Y - 5,9~0,357.~2 ~T. 70ol~'~a.aa~s'' Il = Y = ~,970,101.7l LAT. 70~[9'46.4~67" X = 498,944.~l L0~G. lS0~00"30.808'' X = 4~,~4~. l0 LON~. l~O°0O 377' FSL, 556' F~L 0G = 77' P~D = 81.5 [27' FSL. 556' F~L 0G · 7~,~ ,~D I, I- Y = ~,910,33~.46 L~T. 70~l~'4~.~7~'' l~- Y = ~,970,0~.~a L~T. ~0ol~'~.ll~l X : 498,944.84 LONG.150°00'30.809" ~ o X : 498,9~4.98 L0~G.150000'30.804" 352" FSL, 556' FWL 0G = 77' PAD = 81.6 '~ 102' FSL, 556' FWL OG = 75.7 PAD = 81.7 I co 5- Y = 5,970,307.52 ~T. 70~19'48.3919'' '~ 13 - Y = 5,970,057.59 ~T. 70°19'45.9336" X = 498,944.91 LONG. 150000' 30.808" ~ ~ X = 498,945.08 LONG. 150000' 30.801" , , , o 77' FSL, 556' F~L 0G = 75.5 PAD : 81.6 327 FSL, 556 FWL 0G = 77 PAD = 81.6 ~o 6 - Y = 5,970,282.50 LAT 70~19'~.1459'' ~ ~ 14 - Y : 5,970,032 60 LAT 70~19'45.~79' ~ ~ X = 498,944 91 LONG.150°00'30.806' X = 498,944.95 LONG. 150°00' 30.806'' ~ ~ ~ - 302' FSL, 556' FWL 0G = 77' PAD = 81.7~ ~ ~ o" 52' FSL, 556' FWL OG = 75.3 PAD = 81.7 7 - Y = 5,970,257.54 LAT. 70~19'47.9003'' ~ ~ ~ ~ 15 -'Y = 5,970,007.69 LAT. 70019'45.4428" ~ ~ X 498,944.93 LONG. 150°00' 30.806" X : 498,944.95 LONG'150oO0'30'806" ~ ~ 27' FSL, 556' FWL 0G = 75 2 PAD : 81.6 277' FSL, 556' FWL OG : 77' PAD = 81.6 ~ · 8 - Y = 5,970,232.63 LAT. 70~19'47.6553'' .~ 16 - Y = 5,969,982.85 LAT. 70~19'45.1985" ' X : 498,944.96 LONG. 150o00'30.806'' ~ ~ ~ X : 498,944.88 LONG. 150000' 30.807" ~ 252' FSL, 556' FWL 0G = 76.9 PAD : 81.6 ~ 2' FSL, 556' FWL 0G = 75.1 PAD = 81.7 ~ LOCATED IN PROTRACTED 9 - Y = 5,970.207.62 LAT. 70~!9'47.4093'' x = 498,945.01 LONG. 150o00'30.804'' ~ SEC.12, TI I N, RSE, U.M. 227' FSL, 556' FWL 0G : 76.3 PAD : 81.6 17 - Y : 5,969,957.72 LAT. 70~19'44.9514" x: ~,~.~ ~0,~. ]~0°00'~0.~0~'' I. ALL COORDINATES ARE A.S.P.,ZONE4. -'j :~ ;: 2. SECTION LINE DISTANCES ARE TRUE. ~,j.~ '~ .', 5. HORIZ; POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WEST & 2T;~MIDDLE PER;'EH~E ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 & NI9+75, Eli+ 52 PER F.R.B. ~ ASSOC. 5.0. G. ELEVATIONS 'INTERPOLATED FROM S/C DRAWING CED- RIXX-5140 rev.~, CER~FICATE OF SURVEYOR: i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ~ ~ M~DE BY ME OR UNDER MY SUPERVISION , ~ND I~ atI' THat ALL DIMENSIONS AND OTHER DETAILS ~,ee ', ;~ SURVEYED FOR' ~ ~u ~,u~u,l,~. ~* -~ - ~ KUPARUK PROdECT ~ m D~TE ~e JAN ~S ~ ~ , ~ ~WN W, DRILL SITE 2T CONDUCTOR ~.~'. No 3335 Arctic Boulevard, SuRe 201, Anchorage, Alaska 99503 ~S~LE N.T.~. 2 I 6 ~/"L.. THIS '111 I I ~..~ I ~. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee < r'- (2) Loc ( ru 8) (3) Admin . (14 thru 22) me 3. 4. 5. 6. , ~ /.../ 7. u,.~ "ff~' :.,,'~ :..,"...:'?';11. (lO'and 13) ~ 12. 13. 14. ]5. 16. 17. 18. 19. 20. (5) BOrE ( 23 t h r · ..:~:" 23. ~,%~::;~.,~ ...~;,~:"' '".~ ~'~';: 27 ~'~:~"'"'~ ~'~:'-:'":' ::" 28. .. - ,':.:. (6) OTHER: : ~ ; '" :-::..~.:, 29. (29 thru 3 ~ [~'~':~ 30. 31. Company YES Is the permit fee attached .......................................... ~ · Lease& Well No. NO REMARKS Is well to be located in a defined pool ....................... ~ Is well located proper distance from propert~ line .~..i...i..i i Is well located proper distance from other wells .................... ~ Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. ~ Can permit be approved before ten-day wait .......................... ~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore'. ............ Is old wellbore abandonment procedure included on 10:473 Is adequate wellbore separation proposed .................. i..~. Is a diverter system required ..., ........................ Is the drilling fluid program' schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOrE attached. Does Bore have sufficient pressure rating - Test to _~~_~__ psig .. Does the choke manifold comply w/API RP-53 (May 84) ............... '' Is the presence of H2S gas probable ................................. . exploratory and Stratigraphic Wells: ' Are data presented on potential overpressure zones? . ......... Are seismic analysis data presented on shallow gas zones [ .i. i. .. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Geology: Engineering: .~ LCS ]~W- WVA ~..q>?~ MTM ltJIt ~ JAL~.- ~ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. /t'/o ~ ON/OFF SHORE Additional Remarks: 8005 SCHOON ST. ANC~ORAGE. ALASKA 99518 19071 349.3541 CORE LABORATORIES, INC. ----1- ." --,-- - <l':~,'_", ~ , I ~, --.'. '~~,~ti! ~J --f , ~Tl/~vtLI #=- jcgt;-//o Core Analysis Report Area Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska ]-Oct-B6 TABLE OF CONTENTS I. SECTION A - SUMMARY OF PROCEDURES 1.} Introduction 2.} Methodology a. Core Gamma Surface Log b. Laboratory Sampling. c. Laboratory Procedures: Plug Analysis, Porosity, permeability, Plug Analysis - Overburden conditions, Fluid saturation measurements, oil Gravity Analysis, Core Photography. 3.} Special Conditions II. SECTION B - CORE ANALYSIS RESULTS - TABULAR DATA 1.} Conventional Analysis Results 2.} CMS-200 Overburden Pressure Analysis Results 3.} Detailed Lithological Descriptions III. section C - CORE ANALYSIS RESULTS - GRAPHIC DATA 1.} Water Plateau Curves 2.} Correlation Core graph IV. SECTION D - APPENDICES 1.} Refractive Index vs API Gravity plot 2.} oil Correction Chart 3.} Technical Paper - Automated Core Measurement System for Enhanced Core Data at Overburden Conditions (Keelan). 4.} Shipping and Receiving Transmittals. v. SECTION E - Data Diskette 80ú5 SCHOON S"T. ANCHORAGE. ALASKA '.:!'J518 \9071 :1J',;1.3541 CORE LABORATORIES, INC. SECTION A Summary of Procedures Arco Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska 1-Oct-B6 ., .- - -..~ 't"L\ , .I\;Ö:¡" iJ¡¡ ~ Introduction Whole Core samples from the Kuparuk #2T-9 well were submitted to the Anchorage, Alaska Core Laboratories facility for core analysis measurements. The following is an outline of the procedures utilized in analyzing the Kuparuk #2T-9 samples. Methodologv Core Gamma Surface Log Gamma radiation was measured on the entire core utilizing the Core Lab Surface Gamma Logger instrument. The results are reported on the Core Analysis Correlation Coregraph. Laboratorv Sampling A one and a half inch length by one inch diameter plug was extricated from a lithologically representative section of each foot for helium porosity and air permeability measurements. Plugs were taken from the center of each section and parallel to the bedding strike, with water utilized as the bit coolant. Approximately 150 grams of sample was extracted adjacent to the plug for fluid saturation measurements. To minimize invasion effects the sample was taken from the center of the core. Laboratory Procedures Plug Analysis The samples were placed in a toluene centrifuge extractor for hydrocarbon extraction until no fluorescence was observed, a minimum of three days. Once cleaned, the samples were dried in a convection oven for a minimum of 24 hours at 220 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. Porosity Grain volumes were determined by a Boyle's Law - Heise Gauge Helium Porosimeter. Bulk volumes were measured by mercury displacement. Permeability Horizontal permeabili ty to air was measured utilizing a s tea d y state permeameter with a 400 psig. boot pressure. Plug Analysis - Overburden Conditions In order to simulate reservoir stress conditions, plug samples were run at requested overburden pressures in the CMS-200 Automated Core Measurement System. For each sample, a measured Klinkenberg equivalent liquid permeability, an estimated air permeability, and a helium porosity is reported for overburden pressures of 1000 and 3000 psig. Fluid Saturation Measurements Of the 150 gram sample, 100 grams is broken into "peanut" size pieces for the retort process. The 100 gram samples were retorted in a conventional retort oven at 400 deg. F. for 40 minutes where an initial water reading* was measured. The temperature of the oven was then increased to 1200 deg. F. An observed oil# and final water was then read after an additional 15 minutes at this temperature. The remaining piece is used for bulk and gas volume measurements. Gas volume for each sample was determined by mercury injection at 750 psig. * To substantiate the initial water readings, water plateau curves were generated and are refX)rted in section C. In cases where a plateau was not not reached within 40 minutes, the initial water reading was taken where a plateau was reached. # Observed oil readings were corrected for coking utilizing the oil correction chart in section D. oil gravity Analysis The refractive Index of the recovered oil was measured every fifth foot* and the API gravity (60 deg. F.) was determined utilizing the appropriate correlation chart derived from previously analyzed Kuparuk crude samples. See section D. * As requested by Area, an API gravity was measured every foot for depths 2113 - 2117 and 2120-2130. Core Photography The core was photographed in white and ultraviolet light using a 15 ft. of core/Bx10 in. print format. As requested, 2 sets of white light and one set of U.V. core photographs are submitted. Special Conditions The Kuparuk #2T-9 core was frozen at the wellsite. Samples that were not received in fiberglass tubes or had a break in the end cap seals are denoted as unpreserved in the description. 8005 SCHOON ST. ANCHORAGE, ALASKA 99518 19071349.3541 CORE LABORATORIES, INC. '-.- -- --~';-,~ , , . ''''''~'' ~:.~~ . U. ~ - -~ . ~~.~ SECTION B CORE ANALYSIS RESULTS - TABULAR DATA Arco Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska 1-0ct-B6 s~rnsa~ sTsÁreuv reuoT~uaAuoJ CORE LABORATORIES, INC. Petroleum ReserJ'oir Engineering DALLAS. TEXAS CORE ANALYSIS REPORT FOR Arca Alaska~ Inc. Kuparuk .:I=2T-9 KUPARUK FIELD NORTH SLOPE~ ALASKA Tht';,è "nJI)'se~. OPlllh):1S (If IIlltrprt'ta!lons Jre based on üb~r\aIIOnS Jnd materials supplied by the client to whom,and for whose excluSIve and (()[lfldenliallJse, !hJ, reporllS mJùl' The IrII'>ir'I,'I,'¡'"n' "r 'f";,I"r,- t'xpressed represt'nI I hl' beqjudgmt',lI or Core ubora wries. In..:. (J IJ errors and omissions excepted); but Core Laboratories, Inc. and its officers and eril plüyees, a>sume no respomlbllJl \ .:I nJ l1la~'> 1'1" '^.:Ii!.ln I'. "I representations. a" 10 ¡he prüdUl'llvil)'. proper 0perations. (Ir pr0fllablenes.s oì any oil, gas or other m.tJJera1 weD or sand in connection with which ~uch ri'nml .<. ",...-I '-" ,o>li"ri IIn,~n CORE LABORATORIES, INC. Pel' 0 / e u m Res e r J' 0 i, E n g i 12 e e r i n g DALLAS, TEXAS 'co Alaska, Inc. aruk 12T-9 'ARUK FIElD 'TH SLOPE, ALASKA DATE : 1-0CT-86 FORHATIOH : Kuparuk DRlB, FLUID: WBH LOCATION: TllH RBE Seel FILE NO. : BP-3-1173 LABORATORY: Anchora~e API NO, : 50-103-20071-00 ELEVATION : CONVENTIONAL CORE ANAlYSIS iPlE DEPTH PERH HD HE OIl% WTR% API GRAIN iBER FEET HORIZ Ka POR PORE PORE OIL DEN K DESCRIPTION .--- -------- -------- ---- ---- ---- NOTE - CORE FROZEN AT WELLSITE CORE t20 5965.0 - 6026.0 11 5965.4 <0.01 3.3 1.1 96.5 2 5966.3 19.7 1.2 93.5 3 5967,3 0,19 14.8 1,8 79.6 4 5968.1 16.1 L5 90.4 j 5969.0 18.1 1.3 90.0 '6 5970.0 17.7 1.3 90.8 7 5971.7 2.0 14.6 L 4 85.6 r8 5972.3 0.54 14.7 ItS 91.7 9 5973.6 15. 13,8 2.3 92,1 0 5974.6 0.13 15.1 1.3 86.9 1 5975.4 1.9 15.8 0.7 96.2 2 5976.1 0.36 15.1 1,3 90.7 3 5977 . 1 0.16 13,9 2.0 92,2 5978.6 0.06 14.7 1.5 91.8 j 5979.2 0.64 14.7 1.4 91,4 5980~8 0,11 13.4 0.7 85.0 5981,4 3.4 13.3 1.5 91.4 5982.4 0,20 12.2 O~O 88.1 5983.3 0.13 H,5 0.0 85.8 5984.3 0.08 11.1 0.9 85.3 5985.5 4.1 12.4 14,9 74.5 5986.2 0.01 619 24.1 68.9 5987.2 Of 03 9,6 16.1 69,7 598812 0,39 18,1 16,2 67,0 5989,4 0.23 15.0 12,1 76.3 5991)13 0,15 15,4 26.6 58.0 --- ----- ------------------------------------------------ 3.28 HDST DKGY-ÐLK TR SD SID CHT VHS TR PYR 2.71 SH BLK SLSLTY TR PYR *SUH FLUIDS' 14 2,68 SH BLK SLTY CALC 6LAUC TR PYR 2.ò7 SH BlK SLSLTY TR SD 6LAUC TR PYR *SUH FLUIDSt 2.69 SH ÐLK SlSLTY SOY 6LAUC TR PYR *SUH FLUIDSi 2.71 SH BLK SLSlTY SOY l'R PYR .SUH FLUIDS' 2.70 SH BLK SLTY SDY PYR FILLED BURS ** 2.69 SH BLK StTY SDY TR 6LAUC TR PYR 13 2.69 SH ÐLK SLTY TR SD GLAUC TR PYR i* 2.71 SH BLK SLTY TR SD PYR FILLED BURS 2.83 SH DKBRH-ÐLK SLTY TR SD PYR it 2169 SH DK6Y-BLK SLTY SDY 6LAUC TR PYR 5S FILLED BURS 2.70 HDST BLK SLTY SDY 6LAUC BOD HDST PYR 2.70 HDST DKGY-DKBLK StTY SDY 6LAUC TR PYR 2.72 HDST DKGY-BLK SLTY ABHT SD 6LAUe TR PYR ** 2.71 HDST DKGY-BlK SLTY TR SD TR 6LAUC PYR <10 2.71 SlTST DK6Y-ÐLK SDY ARG GLAUe BIOTURF ** 2.72 SLTST HBY SDY ARB TR 6lAUC BlOTURB ** 2.71 SlTST H-DK6Y TR GLAUe SDY ARB 2.71 SlTST H-DK6Y TR GLAUC SDY ARB 29 2,69 SS H6Y-LTBRH VF-CGR ASHT SLT CLY 6LAUC ** 3,07 55 LTBRN HGY F-CGR TR 6LAUe SID CHT SLCAlC DHS GLAUC BIOTURB 2.71 S5 6N-HaY F-CGR SLTY SID CMT SLCALC 6LAUC 2,74 SS LTBRN-lTGY F-H6R SID CHT SLCALC FIOTURB 25 2,70 SLT5T Hay SDY CALC IMTDD 55 BIOTURB 2167 SLTST HGY INTÐD SS CALC AR6 FIOTURB ,,~ :Jnal:>,~,>. ÜPInIL';h 01 Inlt'rpTel3tion<, "Ie based on 0b~ervJtlons and ma¡erlal,> supplied by the cüent to whom. and for whose e:o.c!uSlve and clntld~n¡131 u<,e. ~ru~ repon I'> m.2l:t'. T ¡-It' 11l1.'q-'II"JII"n. "I "["'Inl' .n' rf'~<,ed I~rlesenl ¡he' beH .luJgmeoll of C'orf' u.b~ratolies, 111~. I,"U errols _and ~mi~ons excepted); but Core La~ralories,I~lc. Jnc..II" ':':::: Jnd e'mplc.yees, a<,su~e no responSlbllJf~ Jnd 1ll.J~~ n., \'-Jfl.lni'. "I 'es~nta[ons. as 10 ¡he pIOdU~II\iIlY, proper operallons, ,11 pfl"lIabl~ne:>.., 01 any oil, gas or other mJDeral weU or sand In connection \l,'1If1 ch such reDOn 1<, lI~ed ", ,,,,,ør! ,,"',..... "-=;'8IIi..:"~ ..........," - ......~ -=- - - CORE LABORATOR IES, I NC. Pel r 0 leu m Res e r J' 0 irE 1'1 gin e e r i n g DALLAS, TEXAS Area Ala5Ka, IncJ DATE : I-DCT-86 FILE NO. : BP-3-1173 Kuparuk '2T-9 FORHATIOH : Kuparu~. LABORATORY: Anchorage CONVENTIONAl CORE ANALYSIS SAHPtE DEPTH PERM HD HE OIL% WTRY. API GRAIN HUHBER FEET HORIZ Ka POR PORE PORE OIL DEN H DESCRIPTION ------ ------- -------- ---- ---- ---- --- ----- ------------------------------------------------ 2027 5991.2 0.37 14,0 19,8 69,8 2,67 55 LT-HBRH VF-CGR ABNT HDST LAHS BIOTURB TR PYR 2028 5992.1 26. 6,1 13,9 75,5 2.66 MDST DKGY CALC SLTST LAMS VFGR SS BURS BIOTURB ** 2029 5993.1 4,9 13.4 16.8 69,1 2,68 "PST DK6Y CALC SlTST LAMS SPY TR PYR BIOTURB ** 2030 5994.1 0.04 13.2 26.1 57.2 26 2.77 HDST DK6Y CALC 55 BURS BIOTURB SID CHT (UNPRESERVED) 2031 5995.6 0.58 15.0 38.2 51J9 2.68 S5 LT6Y VF-H6R VSLTY ABHT IHTBD HDST BIOTURB 2032 5996,4 54. 13.7 15.5 74.5 2.67 SlT5T lT6Y SDY CALC IHTBD HDST BIOTURB ** 2033 5997.3 4.5 14.1 9.3 74,1 2,67 HDST DK6Y SlTY CALC ABNT THNlY INTBD 55 BIOTURF ** 2034 5998,1 0.66 13.5 15.8 70.8 2.66 SS LTGY IJF-"BR ABNT LAM HDST S5 FILLED BURS BIOTURB 2035 5999.3 0.17 13.9 18.7 70,4 26 2.65 SLTST MD-DKGY ABHT WVY LAM "PST 55 FILLED FURS BIOTURF 2036 6000J4 0,59 13,5 12.9 75,7 2,71 HDST HD-DKY CALC AFNT IHTlAM SLTST BIOTURF TR SD 2037 6001.1 15,7 9.2 75.1 2,71 HDST DK6Y-BLK CAlC LA" SLTST BIOTURF 'SUM FLUIDS' 2038 6002~S 2,63 13,9 8,7 81.5 2.69 HPST DKGY-BLK SLTY 55 LAMS SID BIOTURB ** 2039 6003.4 0,61 13,8 8.3 77.4 2.80 HDST HGY-HBRH CALC LTFRN SDY LAMS SID CHI DISH PYR FIOTURF ** 2040 6004,3 1.6 13.4 13.6 71,2 22 2.66 HDST DKGY-BLK CALC HNR THNLY INTBD 5S TR PYR BIOTURB ** 2041 6005,3 2.0 14.7 26.2 48,0 2.67 SS LTGY-LTBRH VFGR SLTY IHTBD "DST TR PYR BIOTURB 2042 6006,2 33, 15,0 14.7 77.9 2.67 S5 LTBR~ VFGR ABHT SLT ~JY "PST LAMS BIOTURB ** 2043 6007.~ S.6 14.4 10,0 84,0 2.69 S5 lIGY VfGR ABHT SLT INTBD HD5T MICA BIOTURB *t 2044 6008,1 0262 13.8 13,0 77,5 2,67 StTST LTBRH AFNT SLT IHTÐD HDST "ICA BIOTURB 2045 6009,1 14.2 11.5 81.5 16 2.68 "DST DKGY-BlK CALC SlTY INTÐÐ SLTST HICA B!OTURB ** 2046 6010,2 0.35 13,6 5,4 87,1 2,69 HDST DKGY CALC SLTY IHTBD SS BIOTURB ** 2047 6011 .4 0.54 12.5 5,1 86,0 2.69 HDST DKGY-BlK CAlC SLTY KHR SDY LAMS H~R PYR '* 2048 6012,3 0,37 12,4 14.7 67,6 2.68 HDST DKGY-BtK CALC SLTY HHR LTBRN SlTY LAMS TR PYR 2049 6013.2 1.4 13.0 21.2 70,6 2165 SS LTBRH-LTGY VFGR HDST LAHS HNR CARB FRAGS BIOTURF ** 2050 6014:1 1.1 12.5 5J2 86.8 19 2,73 "DST DKGY-DKBRH CALC SLTY INTBD SS TR PYR MICA BIOTURB ** 2051 6015.2 13, 12,7 4.5 87.4 2¡69 MDST DK6Y SLTY THNLY BDD 55 S5 FILLED BURS CALC FOB BIOTURB 2052 6016,2 12.9 5.3 80.9 2.72 HDST MDGY CALC SLTY 55 FILLED BURS DISM PYR BIOTURB i* 2053 6017.2 1).12 12.6 2B.1 48.3 2,69 HDST DKGY CALC SLTY KHR LTBRH SLTST ÐIOTURB 2054 601812 3.6 14.6 23.7 ';5.3 2.67 55 LTGY-DKBRN VF6R THNLY INTBD "DST BIOTURB ** 20S5 6019.2 0,46 17.7 31.9 41,4 2S 2,67 SS LTBRN VF6R ABNT SLT ABHT BURR HVY MDST LAHS BI0TURF 2056 602012 0,60 18.8 35.1 48,S 2.67 5LTST lTGY SPY HHR MDST BIOTURB ** 2057 6021.4 0.17 14.6 24.9 61.4 2.73 SLTST LTBRN SDY ABNT IHTLAH HOST BIOTURB PYR 2058 602212 0,96 14.3 28~1 62,1 2.68 SS LTBRN VF6R ABHT SlT IHTLAM HDST BIOTURB Tho:'~r .;n:JI~ ~e~. Oplnhl;JS or Inlerprelallons are based on ,)bsef\:lIlons and malerials supplied by the client to whom, and for whose exdusJ\e and ,"Jnfld...nlial use, this repOrl IS m.Ju"'. Tlie I rli,'rr'rl"", ",n' "1 '1''11'11' -1'1, t"xpre5seJ rt'presenl Ih... be51 Jul1gmelll of Core I...¿¡boraiorles. In.:. (311 errors and omissions excepted); but Core Laboratories, Inc. and its olïkers and empl0yees. assume no respomlbllJl~ JnJ 11'13"': 1'1" \.1..1 ri.lIi1'. lor representa[lon~. a~ to the produCli"'lt~. proper operations. nr prolïlablenes.s of any oiJ, gas or other mineral weU or sand in connection with which such reDOrllS LI,ed nr r~lipn IInnn J"nUJ; " CORE LABORATOR IES, I NC. Pet r 0 / e u m Res e r J' 0 irE 11 gin e e r i n g DALLAS, TEXAS Area Alaskar Inc. DATE : 1-0CT-86 FILE NO. : BP-3-1173 Kuparuk 12T-9 FORMATION : Kuparuk lABORATORY1 Anchorase CONVENTIONAL CORE ANALYSIS SAHPlE DEPTH PERH HD HE OIL% WTR% API GRAIN NUHBER FEET HORIZ Ka POR PORE PORE OIL DEH H DESCRIPTION ------ -------- -------- ---- ---- ---- --- ----- ------------------------------------------------ 2059 6023.3 24. 15.0 21.7 69,4 2.69 SlT8T LTGY-lTBRH SDY THHlY BDDED MPST BIOTURB ** 2060 6024.1 0.07 11. 9 29. 4 55. 1 25 2.66 HDST BlK-DK6Y ABHT SlT MICA HHR SlTY lAMS 2061 6025.3 3.8 16.1 34.4 33.2 2.68 SS LTGY-lTBRH VFGR SlTY "DST LAMS (UNPRESERVED) CORE .21 6026.0 - 6085.4 2101 6026.3 105. 15.2 26.3 46,8 22 2.68 55 LTBRH VFGR ABHT SlT "DST LAHS BIOTURB ** 2102 6027.3 13. 13,1 39.4 24.8 2.67 5S UHT lTBRH SLTY LAMS ClY lAMS CALC TR PYR 2103 6028.2 115. 21.8 42.9 18.2 2.65 55 lTBRN VF-FGR SlTY ABHT HDST lAMS SlCALC 2104 6029,1 3.5 18.7 31.1 38.2 2.67 5S L TBRN WOO ABHT SL T X-LAli MDST PYR 2105 6030.1 3.1 19.7 28.4 36,6 28 2.68 55 lTBRN VfGR ABHT SlT ABHT MDST lAMS PYR NOD BIOTURB 2106 6031,1 2.8 18.9 34.3 43.5 2.68 SS LTBRH VFGR ABNT SLT ABHT HDST LAMS MICA BIOTURB 2107 6032.4 6.4 16.0 37.2 32.8 2.67 S8 LIBRN VFGR ABHT 8lT IHTBD MDBT TR PYR BIOTURB ** 2108 603312 3.0 15.1 36,7 26.9 2.71 SS lTBRN VF6R SLT HDST LAMS "ICA PYR BIOTURB 2109 6034.2 102. 22.6 33.3 18.2 2.64 88 L T6Y L TBRN Vf6R "HR SL T HHR HDSI lAMS HHR BIOTURB 2110 6035,1 66. 22~4 38.7 22.7 29 2.67 S5 VF6R StIY HDST LAMS CARB FRAGS CALC HODS MHR BIOTURB 2111 6036.3 79. 21.6 36.5 46.5 2.71 8S lTBRN ~F6R 5lTY HHR HDST LAH8 BIOTURÐ ** 2112 6037.1 7,4 16.8 38.8 11.6 2,66 5S LTBRH VFGR SLTY HDST LAMS PYR BIOTURB ** 2113 6038.2 1.3 13.9 32!5 46.2 26 2,68 58 lTBRH VF6R SLTY THHlY BDD HDST TR PYR BIOTURÐ ** 2114 6039.3 4.1 15.0 42.3 12.5 29 2.66 55 lTBRN VF6R SLIY THHtY IHTBD HDST 2115 604ft. 1 67. 23.7 40.2 23.4 26 2,67 5S lTBRH VF6R HHR SlT THNLY BDDED 8LT5T TR PYR 2116 6041.2 17, 20.6 28.7 38.8 25 2 167 55 LTGY-lTBRH t}fGR SLTY HHR HD5T 2117 6042.2 265. 25.8 42.6 10.9 26 2,66 55 LTBRH VF6R StTY 2118 6043.1 <0.01 L9 0.0 84.5 2.68 5S LTGY WH VF6R CALC CHT 2119 6044.3 <0.01 1.2 0.0 BO.l 2.67 SS LT6Y WH VFGR CALC CMI 2120 6045.7 116. 30.4 46,8 10.5 26 2.68 58 LTBRH VFGR FRI SlTY 2121 6046.4 1.6 21.6 57.1 11.5 26 2.76 S5 IT-HGY VfGR CALC CHT SlTY 2122 6047.1 77. 24.4 42.5 11.9 26 2.70 55 LTGY LTBRH VFGR SLIY fRI 2123 604B.1 74. 25.1 49.7 10.1 26 2.67 S5 lTBRH Vf6R FRI SLTY HNR HDST lAHS 2124 6049.1 192, 26.0 44.2 11.1 26 2.68 SS LTBRN VFGR FRI SLTY HNR HDST LAMS 2125 6050.1 251. 28.1 45.5 11.6 26 2.67 SS lTBRH VF6R FRI SlIY 2126 6051.1 49. 25.3 40.7 10.0 26 2.66 5S LTBRH VF6R SLFRI SLTY Tht'~e In:ilj ses, üpmlQ:1S or lnlt"pretJtlons :He based on (lbSfI\JttOn~ Jnd mJter13ls supplied by the client to whom,and for whose exdushe :ind è.:.nfldential lise, llu, repür! IS mJGt' TIll:' lnl~rç'r..I~I" '1'1" '-Ir 'Ir,r,I' '1'1; expressed repre'>é'nt I he best judgmelll of Core ubora lOr ie~. In.::. f,JU er rors and omissions excepted); but Core Laboratories, Inc. and ils oitKè'rS J nd elllf'lllj'ees, assume no respünslbllJl.\ ~ nJ nn"'~ 1'1" w~ II" n" "r represenlarilln5. a~ to the prodU(,II~I!j'. propi'r operations. 1.)[ profllJblenei>.S oi any oil, gas or other mineral weU or sand in connection with whirh tlll'h .P...n.1 1< ,.,.." ,.... ...I...rI ..n~" ~CI Alaska, Inc. aruk t2T-9 DATE : 1-0CT-86 FORHATION : Kuparuk CORE LABORATORIES, INC. Pet r 0 leu m Res e r ~' 0 irE n gin e e r i n g DALLAS, TEXAS FILE HO. : BP-3-1173 lABORATORY: Anchorage CONVENTIOHAL CORE ANALYSIS ~PlE DEPTH PERH HD 1BER FEET HORIZ Ka ---- -------- -------- --- ----- 6052.1 56. 22.5 24.7 47.0 27 2.67 6053~1 112. 26.3 52.8 11.8 26 2.66 6054.2 1.8 18.0 39.5 42.6 28 2.66 6055~3 48, 25.8 51. 6 12.1 25 2,66 6056.1 13. 14.9 46.6 16.1 2.71 6057,0 74~ 25.6 52,4 12.2 2.66 6058.1 2.0 16.2 34.1 51.0 2.71 6059.3 1.7 16.3 35.8'46~5 2.66 6060.2 4.9 21.9 40.1 23.5 25 2.66 6061,1 8,1 16.0 42~6 32.3 2.64 6062.1 1.8 11.2 53.4 17.0 2.67 6063.5 5.8 14.4 38.8 31,9 2,68 6064.2 5.4 15.5 34.2 33.0 2.63 6065.1 13. 19.1 40.9 32,8 22 2.67 6066.4 1.8 17.1 39.0 2B.7 2166 6067.2 3.7 16,7 29.3 51,9 2.66 6068.1 3.8 15.9 37.3 30.6 2.74 6069.2 2.7 16.7 42,8 37.0 2.65 6070.3 1.2 14.1 23.1 65.3 18 2,73 6071.2 0.98 17,6 34.6 45.2 2,68 6072.4 16. 13.3 36.3 45.7 2.71 6073.4 22. 14.9 25,0 60.6 2.68 6074.4 4.8 15.6 20.2 67.0 2.65 6075.2 3.2 15.2 30, 7 47.8 25 2.64 6076.4 2.6 14.6 24.7 6419 2.64 6077,2 22. 13.7 18,3 69.0 2.71 6078.2 7.0 14.1 20.8 60,6 2.71 6079,3 9.6 13.9 14.1 78.6 2.68 6080.4 1,6 14.1 14.2 77.8 18 2.67 6081.2 15,2 21.7 64.4 2.68 6082.1 1.6 14.9 15.4 74.9 2.67 6083,1 1.7 14.0 14.1 76.3 2,69 HE OIL% WTR% API GRAIH POR PORE PORE OIL DEH H DESCRIPTION ---- ---- ---- .27 28 29 30 31 32 33 34 35 36 37 38 9 0 1 .2 3 4 5 6 7 ~ ------------------------------------------------ SS lTBRH VF6R SlFRI SLTY FHT LAH SS LTBRH VF6R FRI SlTY VTHN LAMS SS lTBRH VFGR SLTY HDST BIOTURB (UNPRESER~ED) 55 lTBRN VFGR SLTY HNR HDST X-LAHS 5S lT6Y WH VFGR CALC CHT ABHT HDBT lAMS FRI BIOTURB SS LTBRN VF6R SLTY TR HDST LAHS BIOTURB 55 lTBRH LTGY VFGR SlTY ABHT IHTLAH MDST TR PYR BIOTURÐ 5S LTBRH LTOY VF6R SLTY WVY HDST LAHS TR PYR BIOTURB SS LTBRH lT6Y VFGR SlTY HHR HPST lAMS HHR BIOTURB SS LT6Y VF6R SLTY ABHT THHlY IHTBD HDST HHR BIOTURB *t S5 lTGY WHT VF6R SlTY CALC CHT HDST H-DK6Y CALC ABHT 5S BUR HHR SLTY lAHS HHR PYR BIOTURB 55 lTBRH VFBR SlTY ABHT HDST lAMS BIOTURB ** SS lT6Y-LTBRH VFGR ASHT SLT INTBD HD5T TR PYR 5S LT6Y-LTBRH VFGR SlTY ABHT IHTLAM HDST BIOTURÐ SLTST lTBRH SDY IHTBD HDST TR HICA BIOTURB HDST H-DK6Y CAlC THHlY BDDED SLTY 55 SS FILLED BURS PYR HOD BIOTURB 5S LTGY VFGR SLTY AÐHT IHfLAM HDST ÐIOTURB HNR PYR HDST M-DK6Y CALC ABHT 55 BURS BIOTURB ABHT PYP. *t SS LTBRN-LT6Y VFGR ABNT YVY HDST lAHS BIOTURB HDST DK6Y CALC HHR SLIY S8 lAMS BIOTURB *, MPST DK6Y-BLK CALC SlTY THHLY BDDED SLfY 5S TR PYR ** S5 LTBRH VFGR 5LTY THHlY IHTBD HDST ** HDST H-DK6Y CALC SLTY ABHT 55 FILLED BURS 5S LAMS ABNT BIOTURB S5 LTBRH VFGR SLTY IHTlAM HDBT ft HDST DK6Y CALC ABHT SS BURS BIOTURB ** HDST H-DKGY CALC ABHT INTlAH 5S HHR FIOTURB HDST DKGY-BLK CALC SLTY SDY FILLED BURS BIOTURB ** HDST DKGY CALC AFHT 5S FILLED BURS TR SDY lAMS BIOTURB "DST DKGY CALC SL TY THNL Y INlBD 55 IIIOTURB ** HDST DKGY SlTY IHTLAH 55 BIOTURB HDST DKGY CALC SLTY MNR 5S LAMS SS FILLED BURS HNR BIOTURB ** <,è ..IlJI~ ~e~, °PIllII):H or IIllerprt'13liom ar~ based on ùbser"a(lon~ Jnd m;!,enals $upplied by the client to whom, and for whose e>.clusJ\e 3nJ .:,:>nfldenl1al U$e, ltu< repoll I~ mJJt'. The 1J1I'~ip"1:t1 "'Ii' "I'r'III' ,;,,; le'>$.;d repre~lIt Ihe he~1 .iudgnH'1lt of (ore l.<IboraiOrlö, Ine l,aU errors and omissions excepted); but Core Laboratories, Inc. and its officers and t'rilplt'yees, a~sume no resp(lmlhllJl~ Jill! m;;.,.,,: r", '.....IL,Il" "I 'öent:Jllnns, a~ I~' the prL'ducll\lIY. proper operations. or prolll¡;blene!.) of any oil, gas or other mbJeral weU or sand in connection with which su~'h repollls u~ed or relied upon. -. ---...,---.-....~ -- ---~ ----- -.--.-.-_-co_.- - - - ..' CORE LABORATOR I ES, IN C. Pet r 0 / e u m Res e r J' 0 irE n gin e e r i n g DALLAS, TEXAS Arca Alaska, Inc. DATE : 1-0CT-86 FILE HO. : BP-3-1173 f(upa r~ .2T -9 FORMATION : KuparlJk LABORATORY: Anchorage CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERH HD HE OIL% WTR% API GRAIN NLHœER FEET HORIZ f(a POR PORE PORE OIL DEN H DESCRIPTION ------ -------- -------- ---- ---- ---- --- ----- ------------------------------------------------ 2159 6084.1 983. 14.6 14 .3 78. 1 2.69 "DST H-DKGY CAlC ABHT SLT HNR S5 BIOTURB *' 2160 6085.2 2.8 12.9 28.8 48.0 18 2.65 KDST DKGY SLTY CALC HNR IHTLAH 5S BIOTURB *t (UNPRESERVED) CORE .22 6086.0 - 6145.8 2201 6086.5 68. 20.0 25.7 58.8 22 2.69 55 LTGY-LTBRH VfGR SLCALC SLTY THHLY BDD HDST ** 2202 60872 7.9 15.5 35,5 41.6 2.67 SS LTGY-LTBRN VFGR SLTY ABHT INTBD HOST HNR BIOTURB ** 2203 6088.2 19. 19.1 42.3 37.3 2.68 SS lTBRN-LT6Y VfGR SLTY THNLY BDD MDST BIOTURB ** 2204 6089)2 6.2 18.6 35~8 39.7 2.67 5S LTGY VfGR SLTY HNR INTlAH DK6Y HDST BIOTURB 2205 6090.4 2.8 17.3 37.2 29,8 26 2.66 SS LTBRH VFGR ABHT SLT THNLY IHTBD HDST BIOTORD 2206 60911 4.0 18.0 42.6 27.1 2~67 SS LTBRH VFGR ABHT SLT IHTBD OK6Y HDST MNR BIOTURB 2207 6092.2 4.7 21.0 22.5 57.5 2.65 55 LTGY VFGR SlTY HHR HDST lAHS TR BIOTURB 2208 6093,2 2.0 17,9 50.4 20.0 2.65 55 LTGY VFGR SlTY MHR HDST LAMS 8IOTURB 2209 6094.2 16. 20.2 39.5 35.8 2.65 S5 LTOY LTBRN VFGR SLTY HHR HDST LAMS 2210 60951 4 73. 18.5 36,8 45.5 25 2c&5 5S LTBRN VFGR SLTY HDST LAHS ** 2211 6096.1 3.5 15.6 29.1 31.9 2194 5S lTGY VF6R CALC CHT PYR HOD HDST lAMS 2212 6097.6 3t6 18.3 36,3 28,8 2,65 SS lTGY VFGR SLTY ABMT HDST lAHS BIOTURB 2213 6098,5 21, 18.4 39.5 28.8 2,69 S5 LTGY VFGR SLTY ABHT HDST LAHS BIOTURF *t 2214 6099,1 11. 19,9 37.2 33,7 2.64 SS Lr6Y VFGR SLTY HHR IHTLAM HDST BIOTURB 2215 6100.2 6,3 18.9 38.4 31.7 26 2,64 S5 lTGY VFGR 5LTY ADHT IHTBD HPST BIOTURB 2216 6101,1 17. 22,4 43.0 19,4 2.66 SS LTGY LTBRN VF6R SlTY HHR HDST LAHS BIOTURB 2217 6102.2 30, 16.0 32.4 36.2 2.65 HDST DKGY SlTY CALC ABHT IHTBD 55 HNR TR PYR BIOTURB ** 2218 6103,2 3.6 17.4 39.7 44.7 2.64 SS lT6Y VFGR SLTY ABHT DK6Y HDST TR PYR BIOTURB 2219 6104.4 1,8 17.9 30,4 38,7 2.66 SS lTGY Vf6R SLTY ABHT IHTLAH HDST rR PYR BIOTURB 2220 6105.3 53, 20.7 3403 51.0 27 2.66 5S LT6Y VFGR SLTY HHR HDST lAMS X-LAMS ** 2221 6106,3 169, 20.4 35,7 34.8 2.66 S5 LTGY VfGR 5LTY ASHT DKGY HD5T LAMS ** 2222 6107,2 28. 16.7 36.0 45,5 2.66 55 LTGY VFGR SLTY ASHT BDD HD5T BIOTURB ** 2223 6108,3 ",8 15.8 30.5 57,7 2.64 S5 LTGY VFGR StTY ADHT IHTLAM HDST ABHT 55 FILLED BURS HDST BIOTURB 2224 6109,5 0.45 15,0 28.4 54.3 2.66 5S lTGY ABHT THHLY BDD HDST ABNr SS FILLED BURS HNR BDD SS BIOTURB 2225 6110.2 2,8 15.6 28.9 54.2 23 2166 HDST DKGY SLTY CALC SS FILLED BURS HNR THNlY FUD 58 TR PYR BIOTURF 2226 6111. 7 86. 14.2 24.7 68.2 2.65 HDST DKGY CALC SlTY ABNT IHTLA" S5 ABHT FIOrURB TR PYR ** 2227 6112.4 0.90 14.7 24.3 62.6 2.67 HDST DKGY CAlC SLTY ABHT IHTLAH S5 ABNT FIOTURB TR PYR Thest' .; IlJ I} ses. Oplnll):1S or Inlerpreta tions are based on obst'na!lons and ma [t'rlJls supplied by the client to whom, and for whose excJus.i\e :; nd l,:on trdent ial u~e. [1m report IS rn:IlJ<" The In I !:,r rid ,,¡,, ',n' "í ,'r'1"I Ii '1"1, exprè'ssed represent [he best jl.ldgmè',lt of Core ~boratorlè's. Ine, (aU errors and omissions excepted); but Core Laboratories, Inc. and its olïiœh and <"mpk')'ee~. aSi.ume no re~ponslbILJI) Jnd m,]~~ n,l y,~rl.-.rll'. ,'I ¡epresentatlons. as wlhe producll\it)'. proper operations. or profitableness of an} oil, gas or other mineral weU or sand in connection with which such report IS used or relied UDon -..---- -- --- Areo Alaska, Inc. Kuparu~. 12T-9 r nul:. I:) CORE LABORATORIES, INC. Pet' 0 , e u m Res e , J' 0 i, E 11 gin e c , i n g DALLAS, TEXAS DATE : 1-OCT-86 FORMATION: Kuparuk FILE NO, : BP-3-1173 LABORATORY: Anchorase CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERH HD HE OIL% WTR% API GRAIN HUMBER FEET HORIZ Ka POR PORE PORE OIL DEN H DESCRIPTION ------ -------- -------- ---- ---- ---- 2228 6113.5 0.75 17,5 45,7 24.7 2229 6114.0 7.8 16.9 23.2 67.3 2230 6115.6 1.3 14.5 21.4 67.9 2231 6116.2 4.8 15.4 32,9 55.8 2232 6117.2 17. 15.4 27.0 56.9 2233 6118,3 3.0 14.2 24,6 47,5 2234 6119, 1 12. 15.9 24.9 59,0 2235 6120,3 0.42 1412 19,8 70.4 2236 6121.1 17.4 24.8 65,3 2237 6122.1 1e3 14,6 2412 66.9 2238 6123,2 13.6 42.9 43.2 2239 612415 119. 17,2 46:0 22,2 2240 6125.1 0,68 15.7 49.2 19,3 2241 6126.6 0.78 14,2 30,2 50,1 2242 6127.1 0.56 13.7 28.8 60.5 2243 6128.3 14,1 19,8 71.0 2244 6129.3 14.7 19.9 74.5 2245 6130~1 0.37 13.0 23.0 65.5 2246 6131.3 0.21 17.7 30.0 63,0 2247 6132,3 10. 12,2 22, 4 70.1 2248 6133,1 0.63 11.6 11 .8 84 10 2249 6134,5 0.55 12,5 6.4 89.2 2250 6135.2 0.61 12.1 10.8 85.4 2251 6136,3 0.10 13.1 10.9 85,3 2252 6137,3 0.29 16.2 5.0 89.9 2253 6138,2 0,15 15.0 7.6 88,S 2254 6139.2 0.11 11.9 9.8 86.6 2255 614013 3,2 13.6 10,3 86.5 2256 6141. 3 1,6 14,5 8.7 87.1 2257 6142.2 0.61 12.2 9.2 82,7 2258 6143,6 0.29 15.7 9,3 84,7 2259 6144.3 0.06 10,9 11.4 B3,7 ..-- ----- ------------------------------------------------ 2.77 SS LTGY VfGR SLTY SID CHT AFHT MHR XLAHS 2.65 55 LTGY VFGR SLTY ABHT INTLAM MDST HHR BIOTURB TR PYR 11 2.66 MDST DKGY CALC TR PYR ABHT SS FILLED BURS MNR 5S LAMS BIOTURF 2.67 HDST OKGY CALC SlTY ABHT IHTlAH SS TR PYR ** 2.67 MDST DK6Y CAlC SLTY MHR IHTLAH SS SD FILLED BURS TR PYR ** 2.64 SS LTGY-LTBRH VFGR SLTY HDST LAHS BIOTURB TR PYR ** 2.65 SS LTGY-LTBRH VF6R SLTY VTHH MDST LAHS CALC CMT FIOTURF TR PYR 14 2.68 MDST DKGY SLIY ABHT SS LAHS BIOTURB SLCALC TR PYR 2.68 HDST DKGY SLTY CAlC 55 LAMS 'SUH FLUIDS' 2.~5 HDST DK6Y CAlC SLTY KHR VTHN BDD S8 SDY BURS TR PYR 2.60 MDST DK6Y StTY SS LAMS CAlC KHR BIOTURB *SUH FLUIDSt 2,70 HDST DKGY SLTY CALC THNLY IHTBD 5S HNR BIOTURB ** 27 2.70 MDST DKGY SLTY CAlC ABHT SS FILLED BURS BIOTURB TR PYR 2.65 MDST DKGY SLTY CALC ASHT IHTLAH 5S HHR SDY BURS TR PYR 2,65 HI~T DKGY SLTY SLCALC SS LAHS HNR SDY FURS FI0TURF 2.65 MOST DKGY SLTY CALC ABHT INTLAH SS HNR TR PYR BIOTURB *t 2.63 MOST DKGY SlTY CAlC S8 LAHS TR PYR BIOTURB fSUM FLUIDS* 17 2.64 HIrsT DKGY-BLK SlH CALC MICA SDY LAMS lR PYR BIOTURB 2.65 SLTST lT6Y SDY MICA HHR HDST LAMS 2.69 HDST DKGY-BLK SLTY CALC HNR SS FILLED BURS TR PYR ** 2.65 HDST DKGY-BlK SlTY CALC MICA PRLY FISS HNR PYR BIOTURB ** 2,71 MDET DKGY-DKBRH SLCALC TR SLIY LAHS TR PYR 11 2166 HDST DK6Y-BLK SLCALC TR SLTY LAMS TR PYR 2.65 HDST DKGY SLCALC HHR SLTY LAHS TR PYR BIOTURB 2.72 HDST DK6Y SLCALC TR SLTY LAMS TR PYR BIOTURB 2.70 HDST I~GY SLCALC TR SLTY LAMS lR PYR BIOTURB 2.66 MOST DK6Y SLCALC MHR S5 LAMS TR PYR FI0TURB 11 2,72 HOST HD-DK6Y SLCALC MHR SS LAMS TR PYR BIOTURB ** 2,77 MDST MD-DK6Y DHS MICA MHR S5 FILLED BURS BIOTURB ** 2,65 MDST OKGY CALC TR PYR SS LAHS SS FILLED BURS BIOTURB 2,74 HDST MD-PKGY SlCAtC SID CHT PHS TR PYR MHR BIOTURB 2.65 HDST HD-DKGY SlCALC ABHT PYR TR SS FILLED BURS BIOTURB ** Th~~e .J /I.i I~ se~, (lplnl~l;¡S or inl~rpr~IJ lions are based on ,)bst'r\ 3tlom and ma lerlals supplied by the client to whom, and for whose exdushe J nd ,:ünflùentla I us~, :1m r~pùrt IS maut' T h~ Ifw'rf'l 0'1,11 "'1"1 "r 'f"lll' .11', expresstd r~prest'nI t ht' hestiudgmt'.11 of Core ~bora!Orrt'~, I n~~. I aU errors and omissions excepted); but Core Laboratories, Inc. and its ofGœrs J nd .:-mrloyees, assume no responsibJlII" .J f,J n'J~' II" ....... i I, n I., "i r~prest'nt:J[lon~. J~ 1':1 the produ~livil~. proper operallons. ,)r profllablt'ness of any oil, gas or other nùDcral well or sand in conneclion with which ~Ih'h rr""Ii~" I~ ",,,n nr r"lipn IInnn CORE LABORATORIES, INC. Petroleum ReserJ'oir Engineering DALLAS, TEXAS =0 Alaska, Inc, aruk 12T-9 DATE : 1-0CT-86 FORttATIOH : Kuparuk FILE HO, : BP-3-1173 LABORATORY: Anchora~e CONVENTIONAL CORE ANALYSIS fPlE :ER DEPTH PERM HD HE OIl% WTRX API GRAIN FEET HORIZ Ka POR PORE PORE OIL DEN M DESCRIPTION .--- -------- -------- ---- ---- ---- --- ----- ------------------------------------------------ ',0 6145.1 3.8 9.6 8.9 86,9 13 3,00 HDST HD-DK6Y SlCALC ABNT PYR TR SlTY BURS BIOTURB ** ) Denotes Fractured SalPle FLUIDS' Denotes Summation Fluids Anal~5is ,at ion of Fluids Grain Densities Are Calculated .., ~se JnJI~ses. (lprnlL':1S l~r Jnlerpre!a[on~ are based on r,l:1ser\3110nS :wd nUlerwls suppUed by the client to whom, and for whose exclus.ive and ..:'~'nfldenllal use, ttu~ r,;>porl h m,j,je. The InI<:,rl'rl'I,j1 ,,'n' . ,r "P'ÍlI' .n' ressed represent (he besl judgme,lt of Core uboratories. In..:. (aU errors and omissions excepted); but Core Laboratories, Inc. and its officers Jnd ,;>mplo)'ees. assume no respclmlblUI) Jnd IlJJ¡"" rh' v."rl.lnl\ "r eSenlalJons. JS ll~ the producti~'IIY. prop,;>r operatioru.. or prorllableness of any oiJ, gas or other mJDeral well or sand in connection with which such reDOrllS u~ed \~r rr'lif"n IInnn -....!........,. - - -- - s~rnsa~ sTsÁreuv a~nssa~d uap~nq~aAO OOë-SNO Arco Alaska, Inc. Kuparuk #2T-9 Kuparulc Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: Bp.3.1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CHS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR leA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ---...-. .-..-...-- --...-- ------- ------. 2003 5967.3 ATM 14.8 0.19 1000 13.1 0.02 0.05 3000 12.8 0.00 0.01 2008 5972.3 ATM 14.7 0.54 1000 13.0 0.06 0.11 3000 12.5 0.01 0.02 2011 5975.4 ATM 15.8 1.9 1000 14.7 1.6 1.7 3000 13.9 0.19 0.23 2012 5976.1 ATM 15.1 0.36 1000 13.1 0.05 0.08 3000 12.7 0.01 0.02 2014 5978.6 ATM 14.7 0.06 1000 13.0 0.04 0.07 3000 12.4 0.00 0.01 2016 5980.8 ATM 13.4 0.11 1000 12.7 0.05 0.08 3000 12.0 0.00 0.01 2017 5981.4 ATM 13.3 3.4 ** 1000 11.7 1.6 1.9 3000 11.2 0.17 0.24 2018 5982.4 ATM 12.2 0.20 ** 1000 11.0 0.07 0.13 3000 10.6 0.01 0.02 2019 5983.3 ATM 11.5 0.13 1000 10.7 0.04 0.08 3000 10.3 0.00 0.02 2020 5984.3 ATM 11.1 0.08 1000 10.6 0.04 0.07 3000 10.3 0.00 0.01 ** Denotes Fractured Sample page 1 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E See1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071'00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ------- --..----- ------ ----..-.. ..-..-..-.. 2021 5985.5 ATM 12.4 4. 1 ** 1000 10.9 1.5 1.9 3000 10.3 0.25 0.33 2023 5987.2 ATM 9.6 0.03 1000 9.5 0.02 0.05 3000 9.0 0.00 0.02 2024 5988.2 ATM 18.1 0.39 1000 17.5 0.27 0.42 3000 17.1 0.19 0.30 2025 5989.4 ATM 15.0 0.23 1000 12.7 0.07 0.12 3000 12.3 0.01 0.03 2026 5990.3 ATM 15.4 0.15 1000 14.5 0.06 0.11 3000 14.1 0.01 0.04 2027 5991.2 ATM 14.0 0.37 1000 12.8 0.07 0.12 3000 12.4 0.01 0.03 2030 5994. 1 ATM 13.2 0.04 1000 12.9 0.01 0.03 3000 12.2 0.00 0.01 2032 5996.4 ATM 13.7 54 ** 1000 11.9 5.3 6.0 3000 11.4 0.48 0.55 2033 5997.3 ATM 14. 1 4.5 ** 1000 12.6 1.3 1.4 3000 12.2 0.11 0.15 2035 5999.3 ATM 13.9 0.17 1000 13.2 0.06 0.13 3000 12.8 0.02 0.05 ** Denotes Fractured Sample page 2 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ------.. ---..---- ............ --..---- -----..- 2036 6000.4 ATM 13.5 0.59 1000 12.3 0.26 0.35 3000 11.7 0.03 0.05 2038 6002.5 ATM 13.9 2.6 ** 1000 12.0 2.0 2.2 3000 11.5 0.21 0.25 2039 6003.4 ATM 13.8 0.61 ** 1000 12.8 0.06 0.10 3000 12.2 0.01 0.02 2040 6004.3 ATM 13.4 1 .6 ** 1000 11.5 1.4 1.6 3000 10.9 0.15 0.20 2041 6005.3 ATM 14.7 2.0 1000 13.6 0.82 1.0 3000 13.1 0.15 0.25 2042 6006.2 ATM 15.0 33 ** 1000 14.2 28 31 3000 13.6 5.6 5.9 2044 6008. 1 ATM 13.8 0.62 1000 12.8 0.33 0.43 3000 12.4 0.04 0.07 2047 6011.4 ATM 12.5 0.54 ** 1000 11.1 0.23 0.29 3000 10.6 0.02 0.03 2049 6013.2 ATM 13.0 1 .4 ** 1000 11.8 0.57 0.68 3000 11.3 0.04 0.07 2050 6014.1 ATM 12.5 1.1 ** 1000 12.1 0.61 0.68 3000 11.4 0.08 0.10 ** Denotes Fractured Sample page 3 Arco ALaska, Inc. Kuparuk #2T-9 Kuparuk FieLd North SLope, ALaska Date: 1-0ct-86 Formation: Kuparuk Coring FLuid: WBM Location: Tl1N R8E Secl FiLe No: BP-3-1173 Lab: Anchorage AnaLysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure AnaLysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. ..... .------ -.------ ------ -.----- -----. 2053 6017.2 ATM 12.6 0.12 1000 11.8 0.05 0.09 3000 11.5 0.01 0.02 2055 6019.2 ATM 17.7 0.46 1000 17.1 0.16 0.30 3000 16.7 0.10 0.21 2056 6020.2 ATM 18.8 0.6 1000 18.3 0.40 0.63 3000 17.9 0.31 0.53 2057 6021.4 ATM 14.6 0.17 1000 14.0 0.06 0.12 3000 13.6 0.02 0.06 2060 6024.1 ATM 11.9 0.07 1000 11.0 0.04 0.06 3000 10.5 0.01 0.01 2061 6025.3 ATM 16.1 3.8 1000 15.5 2.9 3.8 3000 15.1 2.5 3.1 2102 6027.3 ATM 13.1 13 1000 12.7 11 12 3000 12.4 10 12 2103 6028.2 ATM 21.8 115 1000 21.1 107 114 3000 20.7 104 110 2106 6031.1 ATM 18.9 2.8 1000 18.0 2.1 2.8 3000 17.5 1.7 2.3 2107 6032.4 ATM 16.0 6.4 1000 14.3 1.9 3.0 3000 13.9 0.64 1 . 1 ** Denotes Fractured SampLe page 4 Areo Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) --..-..- -..----- ---"---.. ---..-- ---..-.... ...---..- 2109 6034.2 ATM 22.6 102 1000 22.1 90 96 3000 21.7 85 91 2110 6035.1 ATM 22.4 66 1000 21.8 58 63 3000 21.4 56 60 2111 6036.3 ATM 21.6 79 ** 1000 20.6 70 75 3000 20.2 67 72 2113 6038.2 ATM 13.9 1 .30 ** 1000 12.1 0.61 0.80 3000 11.6 0.10 0.16 2117 6042.2 ATM 25.8 265 1000 25.5 227 241 3000 25.1 220 233 2115 6040.1 ATM 23.7 67 1000 23.2 59 64 3000 22.8 57 62 2116 6041. 2 ATM 20.6 17 1000 20.0 14 16 3000 19.7 12 15 2120 6045.7 ATM 30.4 116 1000 29.8 104 112 3000 29.4 98 107 2121 6046.4 ATM 21.6 1.6 1000 21.1 0.93 1.8 3000 20.9 0.89 1.7 2122 6047. 1 ATM 24.4 77 1000 23.9 66 73 3000 23.6 64 70 ** Denotes Fractured Sample page 5 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk F;eld North Slope, Alaska Date: 1-0ct-86 Format;on: Kuparuk Cor;ng Flu;d: WBM Locat;on: T11N R8E Sec1 F;le No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analys;s - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ....----- --..----- ............ ------- ----.. 2123 6048. 1 ATM 25.1 74 1000 24.8 66 72 3000 24.4 63 69 2124 6049. 1 ATM 26.0 192 1000 25.5 174 184 3000 25.1 168 177 2125 6050.1 ATM 28.1 251 1000 27.6 234 247 3000 27.2 225 238 2126 6051. 1 ATM 25.3 49 1000 24.7 42 47 3000 24.4 40 45 2127 6052.1 ATM 22.5 56 1000 21.9 49 54 3000 21.5 47 51 2128 6053.1 ATM 26.3 112 1000 25.7 100 109 3000 25.3 97 105 2129 6054.2 ATM 18.0 1.8 1000 17.3 1.0 1.5 3000 16.8 0.74 1 .1 2130 6055.3 ATM 25.8 48 1000 25.2 39 44 3000 24.9 37 42 2131 6056. 1 ATM 14.9 13 1000 14.5 11 13 3000 14.1 11 12 2132 6057.0 ATM 25.6 74 1000 25.2 65 71 3000 24.8 62 68 ** Denotes Fractured Sample page 6 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) ... ... .... ------- ..--....--- ............ ------- ..-..---- 2133 6058.1 ATM 16.0 2.0 1000 15.0 0.99 1.3 3000 14.5 0.62 0.82 2134 6059.3 ATM 16.3 1.7 1000 15.4 0.38 0.60 3000 15.0 0.21 0.36 2135 6060.2 ATM 21.9 4.9 1000 21.2 2.7 3.8 3000 20.8 2.1 2.9 2136 6061.1 ATM 16.0 8.1 ** 1000 15.3 4.1 4.8 3000 14.7 1.8 2.2 2137 6062.1 ATM 11.2 1.8 1000 11.2 1.4 1.8 3000 10.9 1.3 1.7 2138 6063.5 ATM 14.4 5.8 1000 13.3 0.79 0.92 3000 12.8 0.08 0.12 2139 6064.2 ATM 15.5 5.4 1000 14.9 1.0 1.3 3000 14.4 0.29 0.47 2140 6065.1 ATM 19.1 13 1000 18.6 7.5 8.8 3000 18.2 6.1 7.2 2141 6066.4 ATM 17.1 1.8 1000 16.2 0.73 1.0 3000 15.8 0.40 0.60 2143 6068. 1 ATM 15.9 3.8 1000 15.1 1.4 1.7 3000 14.5 0.69 0.92 ** Denotes Fractured Sample page 7 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071.00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ------- -..-..---- ------ .. .. .. .. .. .... ------- 2144 6069.2 ATM 16.7 2.7 1000 15.5 0.50 0.65 3000 15.1 0.09 0.16 2145 6070.3 ATM 14.1 1 .2 ** 1000 12.5 0.25 0.34 3000 12.0 0.03 0.06 2146 6071.2 ATM 17.6 0.98 1000 16.9 0.37 0.64 3000 16.5 0.23 0.43 2149 6074.4 ATM 15.6 4.8 ** 1000 14.6 3.6 4.0 3000 14.2 0.69 0.91 2150 6075.2 ATM 15.2 3.2 1000 14.7 0.98 1.2 3000 14.2 0.18 0.28 2151 6076.4 ATM 14.6 2.6 ** 1000 14.0 1.1 1.3 3000 13.3 0.26 0.39 2153 6078.2 ATM 14.1 7.0 1000 12.9 2.0 2.2 3000 12.5 0.28 0.34 2154 6079.3 ATM 13.9 9.6 ** 1000 13.0 6.2 6.5 3000 12.4 1.2 1.2 2202 6087.2 ATM 15.5 7.9 ** 1000 14.1 4.8 5.2 3000 13.6 0.66 0.86 2203 6088.2 ATM 19.1 19 ** 1000 18.4 9.3 10 3000 17.9 1.8 2.2 ** Denotes Fractured Sample page 8 Arco Alaska, Inc. Kuparuk #2T'9 Kuparuk Field North Slope, Alaska Date: 1-0et-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E See1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... ------- .. .. .. .. .. .. .. .. .. .. .. .. .... ------- ------- 2204 6089.2 ATM 18.6 6.2 1000 17.5 2.2 2.8 3000 17.1 1.2 1.6 2205 6090.4 ATM 17.3 2.8 1000 15.8 1.0 1.4 3000 15.4 0.41 0.62 2206 6091.1 ATM 18.0 4.0 1000 16.5 1.7 2.0 3000 16.0 0.28 0.42 2207 6092.2 ATM 21.0 4.7 1000 20.8 3.2 4.2 3000 20.2 2.8 3.8 2208 6093.2 ATM 17.9 2.0 1000 17.2 0.77 1 . 1 3000 16.7 0.52 0.79 2209 6094.2 ATM 20.0 16 1000 19.6 11 13 3000 19.2 10 12 2210 6095.4 ATM 18.5 73 ** 1000 17.9 24 26 3000 17.5 6.8 7.5 2211 6096. 1 ATM 15.6 3.5 1000 14.3 1.7 2.2 3000 13.9 0.88 1.2 2212 6097.6 ATM 18.3 3.6 1000 17.5 2.0 2.7 3000 17.1 1.6 2.1 2213 6098.5 ATM 18.4 21 1000 17.5 19 20 3000 16.9 4.7 5.0 ** Denotes Fractured Sample page 9 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk n eld North Slope, Alaska Date: 1-0ct-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS¡RGC¡TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... -----..- ---..-..-- ..----- ------- ------- 2214 6099. 1 ATM 19.9 11 1000 19.4 7.9 9.3 3000 18.9 7.1 8.4 2215 6100.2 ATM 18.9 6.3 1000 18.4 3.3 4.2 3000 18.0 2.6 3.4 2216 6101.1 ATM 22.4 17 1000 22.1 13 16 3000 21.8 13 15 2218 6103.2 ATM 17.4 3.6 1000 16.5 0.99 1.4 3000 16.0 0.43 0.66 2219 6104.4 ATM 17.9 1.8 1000 17.2 0.63 0.89 3000 16.7 0.23 0.39 2221 6106.3 ATM 20.4 169 ** 1000 19.7 78 82 3000 19.1 22 23 2222 6107.2 ATM 16.7 28 ** 1000 14.9 10 10 3000 14.4 1.6 1.8 2224 6109.5 ATM 15.0 0.45 1000 14.4 0.13 0.24 3000 14.0 0.05 0.11 2225 6110.2 ATM 15.6 2.8 1000 14.5 0.72 0.93 3000 14.0 0.14 0.23 2226 6111. 7 ATM 14.2 86 ** 1000 12.9 21 23 3000 12.3 4.2 4.4 ** Denotes Fractured Sample page 10 Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slope, Alaska Date: 1-0et-86 Formation: Kuparuk Coring Fluid: WBM Location: T11N R8E See1 File No: BP-3-1173 Lab: Anchorage Analysts: TLS;RGC;TDT API No : 50-103-20071-00 Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR KA (est) NUMBER (FT) OVBD (%) (MD) (MD) .. .. .... -----..- -------- ------ .. .. .. .. .. .... .-......-.. 2227 6112.4 ATM 14.7 0.90 1000 13.7 0.20 0.28 3000 13.1 0.03 0.06 2229 6114.0 ATM 16.9 7.8 1000 15.7 1.6 2.1 3000 15.2 0.43 0.65 2230 6115.6 ATM 14.5 1.3 1000 13.1 0.23 0.34 3000 12.7 0.03 0.07 2231 6116.2 ATM 14.5 4.8 ** 1000 14.0 0.96 1.2 3000 13.6 0.17 0.26 2232 6117.2 ATM 15.4 17 ** 1000 14.2 2.4 2.6 3000 13.6 0.30 0.37 2234 6119.1 ATM 15.9 12 ** 1000 15.0 2.3 2.6 3000 14.6 0.36 0.51 2235 6120.3 ATM 14.2 0.42 1000 13.2 0.06 0.10 3000 12.6 0.01 0.02 2242 6127. 1 ATM 13.7 0.56 1000 12.8 0.10 0.16 3000 12.3 0.01 0.03 2246 6131.3 ATM 17.7 0.21 1000 17.4 0.09 0.21 3000 17.0 0.07 0.18 2248 6133. 1 ATM 11.6 0.63 ** 1000 11.1 0.20 0.26 3000 10.6 0.02 0.04 ** Denotes Fractured Sample page 11 suor~dT~Dsaa ardmes reDrDrrOq~r7 parre1ôa Detailed Lithological Descriptions Lithological descriptions were performed on plugs extricated from Kuparuk #2T-9 whole core samples submitted by Arco Alaska, Inc. These are conventional descriptions using a binocular microscope, hand lens, grain size scales, and a comparison chart for percentage estimation and roundness determination. The following format was utilized for describing these samples: Sandstones 1.) Color 2.} Grain size 3.) Sorting 4.} Roundness 5.} Cementing and/or degree of consolidation 6.} Minerals present 7.} Percent (%) minor rock type B.) Sedimentary structures or features 9.} Fracture descriptions Mudstones/Shales/Siltstones 1.} Color 2.} Grain size modifiers 3.) Cementing and/or degree 4.) Accessory minerals 5.} Percent (%) minor rock 6.} Sedimentary structures 7.} Fractures descriptions of consolidation type or features Area Alaska, Inc. Kup3IUk #2'1'-9 Kup3IUk Field North Slo¡;e, Alaska Date: l-oct-B6 Kup3IUk Fonnation Drlg Fld: WBM IÐcation : T1lN RBE See1 File No: BP-3-1~73 Laboratory: Anchorage Geologists: p. Brcwn API No: 50-103-20071-00 Detailed Lithological Descriptions 2001 Mudstone dkgy-blk, tr sd, sid cmt, v well cmt, tr pyr 2002 Shale(r} 2003 Shale 2004 Shale(r} 2005 Shale (r) 2006 Shale(r} 2007 Shale 2008 Shale 2009 Shale 2010 Shale 2011 Shale 2012 Shale blk, slty, well cmt, pyr 1%, P fis blk, slt, tr sa, well cmt, glauc 7%, pyr 5%, tr calc, p fis blk, slty, sdy, well cmt, glauc 7%, qtz 2%, pyr 1%, P fis blk, slty, well cmt, glauc 3%, pyr 2%, P fis blk, slty, sdy, well cmt, pyr 1%, tr qtz, p fis blk, slt, tr sa, well cmt, pyr 7%, tr qtz, p fis, pyr filled bur blk, slt, say, well cmt, vfg glauc 10%, pyr 1%, qtz 1%, p fis blk, slt, say, well cmt, pyr 2%, qtz 1%, glauc 1%, p fis blk, sIt, tr sd, well cmt, pyr 1%, tr qtz, P fis, pyr filled bur dkbrn-blk, tr sd, well cmt, pyr 1%, tr qtz, p fis dkgy-blk, slty, sdy, sbrd ra;¡r qtz and glauc, well cmt, glauc 5%, qtz 1%, tr pyr, P fis, glauc and qtz ss filled bur. 2013 Mudstone blk, slty, say, sbrd vc-fgr qtz and glauc, pred fgr, well cmt, glauc 5%, qtz 1%, tr pyr, thn lam, lam dkgy-blk with less glauc and vfgr sd 2014 Mudstone dk-blk, slty, say, rd vf-rrqr qtz and glauc, well cmt, glauc 5%, pyr 1%, tr qtz 2015 Mudstone dkgy-blk, slty, sdy, sbrd vf-rrgr qtz and glauc, pred fgr, well cmt, glauc 10%, qtz 1%, tr pyr, m-vcgr qtz and glauc filled bur. 2016 Mudstone dkgy-blk, slty, sdy, sbrd vf-¡nrrr nT'7 ::,nrY rr7-n... - - 7 Area Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slopa, Alaska Date: l-oct-B6 KUparuk Formation Drlg Fld: WBM Location: T11N RBE See1 File No: BP-3-1173 La1x>ratory: Anchorage Geolcqists: P. .Brcwn API No: 50-103-20071-00 Detailed Li tholCX]ical Descriptions 201B siltstone rrdgy, sdy, rd vf-m;¡r qtz and glauc, pred vfgr, well cmt, tr qtz, tr glauc, v t1m lam, bioturb, arg 2019 siltstone rrr-dgy, sdy, subrd vf-cgr qtz and glauc, pred vfgr, well cmt, tr glauc, tr qtz 2020 siltstone rrr-dgy, sdy, subrd vf-cgr qtz and glauc, pred vfgr, well cmt, tr qtz, tr glauc, indistinct lam, arg 2021 Sandstone JIdgy-ltbn, slty, vf-cgr, pred fgr, P srtd, sbrd, rrod cmt, qtz 40%, glauc 20%, clay matrix 40%, lam 2022 Sandstone ltbn-Jrgy, f-cgr, pred fgr, m:x1 well srtd, sbrd, well cmt, sid cmt, qtz 73%, glauc 2%, matrix 25%, bioturb, slcalc 2023 Sandstone gn-Jrgy, f-cgr, pred fgr, :rocx1 well srtd, sbrd, well cmt, sid cmt, qtz 75%, glauc 10%, Jratrix 15% 2024 Sandstone ltbn-ltgy, f-nqr, pred fgr, m:xi well srtd, sbrd, well cmt, sid cmt, qtz 70%, glauc 10%, matrix 20%, bioturb 2025 siltstone m;¡y, ltgy vfgr ss, well cmt, calc, intl:xi ss 20%, bioturb 2026 siltstone rrgy, ltgy vfgr ss, well cmt, calc, thn intl:xi ss 20%, bioturb 2027 Sandstone 1 t-ned brn, dkgy wvy lam rrdst, vf-cgr, pred fgr, mXl well srtd, sbrd, well cmt, qtz 75%, t.r pyr, matrix 25%. WAVY 7 ~m rrn +- - .' Area Alaska, Inc. Ku¡:aruk #2T-9 Ku¡:aruk Field North Slope, Alaska Date: 1-<Jct-86 Ku¡:aruk Fonnation Drlg Fld: WBM Location: T11N R8E Sec1 File No: BP-3-1~73 Laboratory: Anchorage Geologists: P. .B.n:wn API No: 50-103-20071-00 Detailed Lithological Descriptions 2034 Sandstone ltgy, dkgy intbd and lam rrdst, vf-rrgr, pred vfgr, well srtd, well cern, qtz 75%, matrix 25%, intbd and lam Jrdst 25%, rrgr ss filled bur, bioturb 2035 siltstone m-dkgy, c1kgy lam rrdst, sdy, vfgr, well srtd, well cmt, lam rcdst 40%, bioturb 2036 Mudstone m-dkgy, It-m;¡y lam sltst, well cmt, calc, lam sltst 20%, bioturb 2037 Mudstone(r)dkgy, ltgy-Irgy lam sltst, well cmt, calc, bioturb 2038 Mudstone dkgy-blk, ltbrn lam vfgr ss, slty, well cmt, calc, tr py, lam vfgr ss 20%, bioturb 2039 Mudstone rrqy-mbrn, ltbrn lam vfgr ss, slty, well cmt, sid cmt, tr pyr, lam vfgr 55 20%, bioturb, vfgr ss filled bur 2040 Mudstone dkgy-blk, ltgy lam vfgr ss, well cmt, calc, tr pyr, lam vfgr ss 30%, bioturb 2041 Sandstone ltgy-ltbrn, dkgy-blk int1:xi rrdst, slty, vfgr, well srtd, sbang, well cmt, qtz 82%, mica 3%, tr pyr, matrix 15%, intbd:rrdst 30%, bioturb 2042 Sandstone ltbrn, dkgy lam 1Tdst, vfgr, slty, well srtd, sbang, well cmt, zrdst calc, qtz 79%, mica 1%, matrix 20%, ww lam rrñc::r ?J;"°~ hi "'+- Arco Alaska, Inc. Kup3IUk #2T-9 Kup3IUk Field North Slo~, Alaska Date: 1-<Jct-B6 Kup3IUk Formation Drlg Fld: WBM lDcation : T11N RBE Sec1 File No: BP-3-1173 Laboratory: Anchorage Geologists: p. .Brcwn API No: 50-103-20071-00 Detailed LitholCXJical Descriptions 204B Mudstone dkgy-blk, ltbrn lam sltst, slty, well cmt, calc, tr pyr, lam sltst 15%, bioturb 2049 Sandstone ltbrn-ltgy, dkgy lam rrdst, vf-rrgr, pred vfgr, well srtd, sbang, well cmt, rrdst calc, qtz 79%, acces min 2%, tr mica, tr bit, matrix 19%, lam IIdst 40%, bioturb 2050 Mudstone dkgy-dkbrn, ltgy intlrl vfgr ss, slty, well cmt, calc, tr pyr, intbd vfgr ss 30%, mica, bioturb 2051 Mudstone dkgy, ltbrn intlrl vfgr ss, slty, well cmt, calc, vfgr ss 20%, rrrqr ss filled bur, bioturb 2052 Mudstone 1lYJY, slty, well cmt, calc, pyr 2%, tr qtz, ss filled bur, bioturb 2053 Mudstone dkgy, ltbrn lam sltst, slty, well cmt, calc, foss, lam sltst 40%, bioturb 2054 Sandstone ltgy-dkbrn, dkgy tlm bd rrdst, vfgr, well srtd, sbang, well cmt, Ildst calc, qtz 79%, acces min 1%, tr mica, tr bit, matrix 20%, thn b:1 lldst 30%, bioturb 2055 Sandstone ltbrn, dkgy-ltbrn wvy lam rrdst, vfgr, well srtd, sbang, well cmt, qtz 74%, mica 1%, tr bit, matrix 25%, wvy lam IIdst 15%, bioturb 2056 siltstone ltgy, dkgy wvy lam rrdst, sdy, well cmt, wvy lam ITdst 10%, bioturb 2057 siltstone ltbrn, dkgy lam rrdst, sdy, well cmt, nrlc:::t- t"'::37,.. YW'" ... b:i t)j-1 Jrh Area Alaska, Inc. Kuparuk #2'1'-9 Kuparuk Field North Slopa, Alaska Date: l-oct-B6 Kuparuk Fonnation Drlg Fld: WBM :üxation : T11N RBE Sec1 File No: BP-3-1173 Laboratory: Anchorage Geologists: P. Bram API No: 50-103-20071-00 Detailed Lithological Descriptions 2101 Sandstone Itbrn, dkgy lam Ttdst, slty, vfgr, well srtd, sbrd, well cmt, qtz BO%, tr mica, matrix 20%, lam Ttdst 20%, bioturb 2102 Sandstone wht, ltbrn, slty, vfgr, rocxi srtd, well cmt, calc, qtz BO%, tr pyr, tr mica, matrix 20%, v thn clay defined lam, no bioturb 2103 Sandstone ltbrn, vfgr, slty, JOCJd well srtd, sbang, well crrrt, sl calc, qtz 90%, tr mica, matrix 10%, lam, no bioturb 2104 Sandstone ltbrn, dkgy xlam ndst, slty, vfgr, well srtd, sbang, well cmt, qtz BO%, tr pyr, tr mica, matrix 20%, xlam m:1st 5%, no bioturb 2105 Sandstone ltbrn, dkgy lam rrdst, slty, vfgr, well srtd, sbarq, well cmt, IIdst calc, qtz 90%, tr pyr, matrix 10%, lam m:1st 20%, bioturb 2106 Sandstone ltbrn, dkgy lam IIdst, slty, vfgr, well srtd, sbang, well cmt, rrdst calc, qtz 80%, tr mica, matrix 20%, lam Ildst 10%, bioturb 2107 Sandstone ltbrn, dkgy lam rrdst, slty, vfgr, IOCJd well srtd, sbang, well cmt, Jrdst calc, qtz 90%, tr pyr, tr mica, matrix 10%, lam m:1st 30%, bioturb 210B Sandstone ltbrn, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, IIdst calc, qtz BO%, pyr 3%, tr mica, matrix 17%, lam Irdst 10%, bioturb 2109 Sandstone ltgy, ltbrb, dkgy lam Jrdst, slty, vfgr, well srtd, sbang, well cmt, qtz 90%, tr mica, matrix 10%, lam Ttdst 2%, ltl bioturb 2110 Sandstone 7t-hrT1 ñVrnr 1-? Area Alaska, Inc. Kup3rUk #2T-9 Kup3rUk Field North Slope, Alaska Date: l-oct-86 Kup3rUk Forma.tion Drlg Fld: WBM Iocation : T11N R8E Sec1 File No: BP-3-1~73 Laboratory: Anchorage Geologists: P. Bravn API No: 50-103-20071-00 Detailed Lithological Descriptions 2115 Sandstone ltbrn, ltgy intbd sltst, slty, vfgr, well srtd, sbang, well cmt, qtz 90%, tr mica, matrix 10%, intbd sl tst 8%, no bioturb 2116 Sandstone ltgy, ltbrn, ltgy intbd sltst, slty, vfgr, well srtd sbang, well cmt, qtz 80%, tr mica, matrix 20%, intbd sl tst 15%, no bioturb 2117 Sandstone ltbrn, slty, vfgr, well srtd, sbang, rocx1 cmt, qtz 90%, tr mica, ma.trix 10%, 2118 Sandstone 1 tgy-wht, vfgr, well srtd, sbang, v well cmt, calc, qtz 75%, tr mica, matrix 25% 2119 Sandstone 1 tgy-wht, vfgr, well srtd, sbang, v well cmt, calc, qtz 75%, tr mica, matrix 25% 2120 Sandstone ltbrn, slty, vfgr, well srtd, sbang, fri, qtz 90%, tr mica, matrix 10%, 2121 Sandstone It-ra;¡y, slty, vfgr, well srtd, sbang, IOCJd cmt, calc, qtz 90%, tr mica, matrix 10%, lam defined by clay and silt 2122 Sandstone ltgy-ltbrn, slty, vfgr, well srtd, sbang, fri, qtz 90%, tr mica, ma.trix 10% 2123 Sandstone ltbrn, dkgy lam rrdst, slty, vfgr, well srtd, sbang, fri, qtz 90%, matrix 10%, tr mica, lam rrdst 1% 2124 Sandstone ltbrn, dkgy lam lldst, slty, vfgr, well srtd, sbang, fri, qtz 90, matrix 10%, tr mica, lam IIilst 2% 2125 sandstone ltbrn, slty, vfgr, well srtd, sbang, fri, qtz 90%, tr mica, matrix 10% 2126 Sandstone ltbrn, slty, vfgr, well srtd, sbang, fri, qtz 90%, tr mica, matrix 10% 2127 Sandstone ltbrn, slty, vfgr, well srtd, sbang, fri, qtz 80%, tr mica, matrix 20% faint lam Arco Alaska, Inc. Kup:m1k #2'1'-9 Kup:m1k Field North Slopa, Alaska Date: l-oct-86 Kup:m1k Formation Drlg Fld: WBM I.Dcation : T11N R8E Sec1 File No: BP-3-11.73 Laboratory: Anchorage Geolcgists: P. .Brcwn API No: 50-103-20071-00 Detailed Lithological Descriptions 2130 Sandstone ltbrn, dkgy lam Jrdst, slty, vfgr, well srtd, sbang, fri, qtz 90%, tr mica, matrix 10%, lam Jrdst 2%, no bioturb 2131 Sandstone ltgy-wht, dkgy xlam ndst, slty, vfgr, well srtd, sbang, well cmt, calc, qtz 80, tr mica, ma.trix 20%, xlam mist 15%, no bioturb 2132 Sandstone ltbrn, dkgy lam m:1st, slty, vfgr, well srtd, sba.ng, fri, qtz 85%, tr mica, matrix 15%, lam IIrlst 1% 2133 Sandstone ltbrn-ltgy, dkgy lam m:1st, slty, vfgr, well srtd, sbang, p cmt, Irdst calc, qtz 80%, tr mica, tr pyr, matrix 20%, lam m:1st 25%, IrOd bioturb 2134 Sandstone ltbrn, ltgy, dkgy lam :ndst, slty, vfgr, well srtd, sbang, p cmt, Jrdst calc, qtz 80%, tr mica, tr pyr, ma.trix 20%, lam:ndst 10%, bioturb 2135 Sandstone ltbrn-ltgy, dkbrn lam ICdst, slty, vfgr, well srtd, sbang, p cmt, ndst calc, qtz 80%, tr mica, matrix 20%, lam Ildst 7%, 1 tl bioturb 2136 Sandstone ltgy, dkbrn lam mist, slty, vfgr, well srtd, sbang, P cmt, Jrdst calc, qtz 80%, tr mica, matrix 20%, lam Jrdst 40%, lldst calc, ltl bioturb 2137 Sandstone ltgy, wht, slty, vfgr, well srtd, sbang, well cmt, calc, qtz 75%, tr mica, matrix 25%, indist lam 2138 Mudstone m-dkgy, ltbrn lam sltst, rcr:x1 cmt, calc, pyr 3%, lam sltst 30%, sdy sltst filled bur, bioturb 2139 Sandstone ltbrn, dkgy-blk lam :ndst, slty, vfgr, well srtd, sbang, JOCXi cmt, Jrrlst calc, qtz 75%, tr mica, ma.trix 25%, lam rrdst 40%, ss filled bur, bioturb 2140 Sandstone ltgy-ltbrn, dkgy-blk intlxI rrdst, slty, vfgr, well srtd, sbang, p cmt, rrdst calc, qtz 70%, tr mica, matrix 30%, lam Irdst 25%, ss filled bur, bioturb 2141 Sandstone ltgy-ltbrn, dkqy-blk lam rrñc:r C""7rT7 T"TIT .., 'I Arco Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slo¡;e, Alaska Date: 1-<:>ct-86 KUparuk Formation Drlg Fld: WBM Location: T1lN R8E Sec1 File No: BP-3-1173 Laboratory: Anchorage GeolCX]ists: p. Brc:wn API No: 50-103-20071-00 Detailed Lithological Descriptions 2143 Mudstone m-dkgy, ltbrn thn intbd vfgr ss, slty, well cmt, calc, pyr 1%, tr mica, thn intbd ss 15%, ss filled bur, mXJ bioturb 2144 Sandstone ltgy, dkgy lam JIdst, slty, well srtd, sbang, well cmt, 11dst calc, qtz 80%, tr mica, matrix 20%, lam:mist 20%, bioturb 2145 Mudstone m-dkgy, ltgy lam vfgr ss, slty, well cmt, calc, pyr 1%, ss filled bur, bioturb 2146 Sandstone ltbrn-ltgy, dkgy wvy lam JIdst, slty, vfgr, well srtd, sbang, well cmt, 11dst calc, qtz 80%, tr mica, matrix 20%, wvy lam JIdst 15%, bioturb 2147 Mudstone dkgy, ltgy lam ss, slty, rrr:x1 cmt, calc, lam ss 15%, bioturb ** 2148 Mudstone dkgy-blk, ltbrn thn intbd vfgr ss, slty, IOCrl cmt, calc, tr pyr, thn int1x1 ss 30%, little bioturb 2149 Sandstone ltbrn, dkgy thn intbd ITdst, slty, vfgr, well srtd, sbang, m.x1 cmt, rrdst calc, qtz 80%, matrix 20%, thn intbd JIdst 30%, ltl bioturb 2150 Mudstone m-dkgy, ltgy lam vfgr ss, slty, IOCrl cmt, calc:, lam vfgr ss 20%, ss filled bur, bioturb 2151 Sandstone ltbrn, dkgy lam JIdst, slty, vfgr, well srtd, sbang, well cmt, ndst calc, qtz 75%, tr mica, matrix 25%, lam 11dst 25%, cly xlam in ss, little bioturb 2152 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, lam vfgr ss 10%, bioturb 2153 Mudstone m-dkgy, ltgy lam vfgr ss, slty, well cmt, calc, lam vfgr ss 25%, bioturb 2154 Mudstone dkgy-blk, ltbrn lam vfgr ss, slty, well cmt, calc, lam vfgr ss 10%, ss filled bur, bioturb 2155 Mudstone dkgy, ltbrn lam vfgr ss, sltv, well cmr r'::l7r 7""m T"'- - rn7r hi ....f-,.. . Aroo Alaska, Inc. Kuparuk #2T-9 Kuparuk Field North Slo~, Alaska Date: 1-<Jct-85 Kuparuk Fonnation Drlg Fld: WBM Location: T11N R8E Sec1 File No: BP-3-11.73 .z:a.lx)ratory: Anchorage GeolCX}ists: p. .B.ravn API No: 50-103-20071-00 Detailed Lithological Descriptions 2157 Mudstone dkgy, ltbrn lam vfgr ss, slty, well cmt, calc, lam vfgr ss 8%, ss filled bur, bioturb 2158 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, lam vfgr ss 15%, ss filled bur, bioturb 2159 Mudstone m-dkgy, ltbrn lam vfgr ss, slty, well cmt, calc, lam vfgr ss 20%, ss filled bur, bioturb 2160 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, lam vfgr ss 15%, bioturb 2201 Sandstone ltgy-ltbrn, dkgy intbd Irdst, slty, vfgr, well srtd, sbang, Irrx1 cmt, sl calc, qtz 80%, tr mica, tr acces min, matrix 20%, intbd Irdst 20%, ltl bioturb 2202 Sandstone ltgy-ltbrn, dkgy thn intbd m:ist, slty, vfgr, well srtd, sbang, well cmt, :rrr:1st calc, qtz 80%, tr mica, matrix 20%, thn intbd :rrr:1st 40%, bioturb 2203 Sandstone ltgy-ltbrn, dkgy thn intbd mist, slty, vfgr, well srtd, sbang, well cmt, Jrdst calc, qtz 80%, tr mica, tr acces min, matrix 20%, thn intbd TIdst 15%, bioturb 2204 Sandstone ltgy, dkgy lam Jrdst, slty, vfgr, well srtd, sbang, well cmt, rrrlst calc, qtz 85%, tr mica, tr pyr, matrix 15%, lam ndst 10%, bioturb 2205 Sandstone ltbrn, dkgy thn intlx1 Jrdst, slty, vfgr, well srtd, sbang, well cmt, rrrlst calc, qtz 80%, tr mica, matrix 20%, intbd ndst 20%, bioturb 2206 Sandstone ltbrn, dkgy thn intbd Irdst, slty, vfgr, well srtd, sbang, well cmt, JIdst calc, qtz 85%, tr mica, matrix 15%, thn intbd IIdst 20%, IOCrl bioturb 2207 Sandstone ltgy, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, qtz 75%, tr mica, matrix 25%, lam IIdst 3%, xlam, ltl bioturb 2208 Sandstone ltgy, dkgy ,lam rrdst, slty, vfqr, we77 !=:rt-ñ ror-nf'Y l' ""7 mirr- Area Alaska, Inc. Ku¡;aruk #2'1'-9 Ku¡;aruk Field North Slo¡;x=, Alaska Date: 1-<:x:t-86 Ku¡;aruk Fonnation Drlg Fld: WBM Location: T11N R8E Seel File No: BP-3-1~ 73 Laboratory: Anchorage Geologists: P. Bravn API No: 50-103-20071-00 Detailed Lithological Descriptions 2210 Sandstone ltbrn, dkgy lam ndst, slty, vfgr, well srtd, sbang, well cmt, qtz 80%, tr mica, matrix 20%, lam mdst 8%, little bioturb 2211 Sandstone ltgy, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, ndst calc, qtz 80%, pyr 3%, tr mica, matrix 17%, lam rrdst 8%, ltl bioturb, 2212 Sandstone ltgy, dkgy lam ndst, slty, vfgr, well srtd, sbang, well cmt, Irdst calc, qtz 75%, tr mica, matrix 25%, lam rrdst 20%, bioturb 2213 Sandstone ltgy, dkgy lam ndst, slty, vfgr, well srtd, sbang, well cmt, nifst calc, qtz 75%, pyr 32%, tr mica, matrix 25%, lam IIdst 20%, little bioturb ** 2214 Sandstone ltgy, dkgy lam mdst, slty, vfgr, well srtd, sbang, well ant, qtz 80%, tr mica, matrix 20%, lam rrdst 5%, 1 tl bioturb 2215 Sandstone ltgy, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, nrlst calc, qtz 80%, tr mica, matrix 20%, lam rrdst 10%, bioturb 2216 Sandstone ltgy, ltbrn, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, qtz 80%, tr mica, matrix 20%, lam mist 3%, Itl bioturb 2217 Mudstone dkgy, ltgy thn int1x1 vfgr ss, slty, well ant, calc, tr pyr, tlm intlx1 vfgr ss 40%, 1 tl bioturb 2218 Sandstone ltgy, dkgy lam mist, slty, vfgr, well srtd, sbang, well cmt, :rrdst calc, qtz 80%, tr pyr, tr mica, matrix 20%, lam IIdst 25%, bioturb 2219 Sandstone ltgy, dkgy lam mdst, slty, vfgr, well srtd, sbang, well cmt, qtz 80%, tr mica, tr pyr, matrix 20%, lam mist 25%, bioturb 2220 Sandstone ltgy, slty, vfgr, well srtd, sbang, well cmt, mdst calc, qtz 85%, tr mica, matrix 15%, xlam, lam defined by organic material and clay, no bioturb 2221 Sandstone ltgy, dkgy lam mdst, sltv, vfcrr w/:)77 ....r+rI f'Yf'"r7 Of')D . \ I 1 i ~ ~\ :' ~ !; f, I' Arco Alaska, Inc. Ku¡;:aruk #2'1'-9 Ku¡;:aruk Field North Slo~, Alaska Date: l-oct-86 Ku¡;:aruk Formation Drlg Fld: WBM Location: T11N R8E Sec1 File No: BP-3-1173 Laboratory: Anchorage Geologists: p. .BrcM1 API No: 50-103-20071-00 Detailed LitholCX;ical Descriptions 2223 Sandstone ltgy, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, rrdst calc, qtz 80%, tr mica, tr pyr, matrix 20%, lam rrdst 40%, bioturb 2224 Sandstone ltgy, dkgy thn intbd rrdst, slty, vfgr, well srtd, sbang, well cmt, mist calc, qtz 80%, tr pyr, tr mica, matrix 20%, t1m intbd rrdst 35%, bioturb 2227 Mudstone dkgy, 1 tgy vfgr ss, sl ty, well cmt, calc, tr pyr, tr mica, vfgr 55 25%, bioturb dkgy, 1 tgy vfgr ss, sl ty, well cmt, calc, tr pyr, tr mica, vfgr 55 30%, bioturb dkgy, 1 tgy vfgr ss, sl ty, well cmt, calc, tr pyr, vfgr ss 30%, bioturb 2225 Mudstone 2226 Mudstone 2228 Sandstone ltgy, dkgy lam 1ldst, slty, vfgr, well srtd, sbang, well cmt, Irdst calc, qtz 75%, tr mica, matrix 25%, xlam, no bioturb 2229 Sandstone ltgy, dkgy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, ndst calc, qtz 75%, tr mica, tr pyr, matrix 25%, lam rrdst 25%, bioturb 2230 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr 5S 15%, bioturb 2231 Mudstone dkgy, ltbrn lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr 55 20%, bioturb 2232 Mudstone dkgy, ltbrn lam vfgr ss, slty, well cmt, calc, tr pyr, vfg ss 15%, sl bioturb 2233 Sandstone ltgy-ltbrn, dkgy wvy lam rrdst, slty, vfgr, well srtd, sbang, well cmt, mist calc, qtz 70%, tr mica, tr pyr, matrix 30%, wvy lam rrdst 40%, bioturb 2234 Sandstone ltgy-ltbrn, dkgy lam rràst, slty, vfgr, well srtd, sbang, well cmt, rràst calc, qtz 70%, tr mica, tr pyr, matrix 30% 7 ~m nrlr<t- ')(1°- '.., ,.,i r"\h ,.....~ Area Alaska, Inc. Kup3IUk #2T-9 Kup3IUk Field North Slo~, Alaska Date: l-oct-86 Kup3IUk Formation Drlg Fld: WBM location: T1lN R8E Sec1 File No: BP-3-1173 Lalx>rato.ry: Anchorage Geologists: p. .Brcwn API No: 50-103-20071-00 Detailed Lithological Descriptions 2237 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr ss 15%, bioturb 2238 Mudstone(r)dkgy, ltb:rn lam vfgr ss, slty, well cmt, calc, 1IDd biot:urb 2239 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr ss 20%, 51 bioturb 2240 Mudstone dkgy, Itgy lam vfgr 55, slty, well cmt, calc, tr pyr, vfgr 55 10%, bioturb 2241 Mudstone dkgy, ltgy-ltbrn lam vfgr 5S, slty, well cmt, calc, tr pyr, vfgr ss 30%, bioturb 2242 Mudstone dkgy, ltb:rn lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr ss 5%, bioturb 2243 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, vfgr ss 10%, nrx1 bioturb 2244 Mudstone(r}dk.gy, ltbrn lam vfgr ss, slty, well cmt, calc, tr pyr, IOCXi bioturb 2245 Mudstone dkgy-blk, ltbrn lam vfgr ss, slty, well cmt, calc, tr pyr, lam vfgr ss 5%, ss filled bur, bioturb 2246 siltstone ltgy, dkgy lam Irdst, sdy, well cmt, lam mist 3%, lam sltst, little bioturb 2247 Mudstone dkgy-blk, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, lam vfgr ss 1%, ss filled bur, bioturb 2248 Mudstone dkgy-blk, slty, well cmt, calc, tr pyr, biot:urb 2249 Mudstone dkgy-blk, ltbrn lam sltst, slty, well cmt, calc, tr pyr, lam sltst 2%, no bioturb Arco Alaska, Inc. Ku¡;;aruk #2T-9 Ku¡;;aruk Field North Slopa, Alaska Date: l-oct-86 Ku¡;;aruk Formation Drlg Fld: WBM lJxa.tion : T11N R8E 5ec1 File No: BP-3-1173 Lal:x:Jratoxy: Anchorage Geologists: p. Brcwn API No: 50-103-20071-00 Detailed Lithological Descriptions 2252 Mudstone dkgy, ltgy lam slst, slty, well cmt, calc, tr pyr, lam sltst 3%, bioturb 2253 Mudstone dkgy, ltgy lam sltst, slty, well cmt, calc, tr pyr, lam sltst 1%, bioturb 2254 Mudstone dkgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, lam vfgr ss 1%, bioturb 2255 Mudstone ITKikgy, ltgy lam vfgr ss, slty, well cmt, calc, tr pyr, lam vfgr ss 2% bioturb 2256 Mudstone IlKikgy, sl ty, well cmt, calc, tr pyr, ss filled bur, bioturb 2257 Mudstone dkgy, 1 tgy lam vfgr ss, sl ty, well cmt, calc, tr pyr, lam vfgr ss 3%, ss filled bur, bioturb 2258 Mudstone m-dkgy, sl ty, well ant, calc, tr pyr, bioturb 2259 Mudstone m-dkgy, sl ty, well ant, calc, tr pyr, ss filled bur, bioturb 2260 Mudstone m-dkgy, sl ty, well cmt, calc, pyr 10%, ss filled bur, bioturb Note - Percentages (%) are estimates from visual estimation charts. 7~ 8005 SCHOON ST ANCHORAGE. ALASKA 99518 1907,349.35<11 CORE LABORATORIES, INC. -: "- -..-:Ü I. --~ - -. ..'-' SECTION C Core Analysis Results - Graphic Data Area Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska 1-0ct-86 Çüoz -,-- ~ r I - '~ - f ,-~ :-- - /,-/- ~- - - - -- . -- --- ." I oç / " TOOL ---- -- ---'.~- ,"". .-.. --' £OOZ -'-',.'- (sa+nu!w) aW!l ZOOl ~OOz: at O£ oz O~ ~ 0 .- / , / / ", ",/' ~.I /' t - Z ,,/' - £ ,/' / ~v I ../ ,', " , I L ç ¡ I I - 9 ,,' ~' " " ,- ' ",' " .,:---, ,.,""- -:"""".. / ...;Øo" . -- ,..."- .-.- I r L I I L 8 I I I 6 ,,.----_.-"""" - ...,' .,.--"~- r" ~--- - ",.-- -~ - ".." .-- -",.-- "--"':1" - ---'" --. -------- ,-- ,- ,-' ---------' ..-...-' ~ ~ ~ 6-1Z# >tnJcdn>i tJOt8d U8/\Q S 8/\j n J n 02)+ 0 I d J 8 + 0 M ~ Q r+ (t) ., ::u CD () 0 < CD ., (1) Q. ~ () 0 en "-/ Water Platea u Cu rves O\/en Retort Kuparuk #2T-9 9 8 - 7 - " rn 6 - 0 0 '-' "U Q) 5 ---, L ,, -' Q) ,. 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I ' / ./ ,/ /.. ;' / / I I I / --....:... ~ .-- I 0.8 +~-- I -_h r - - r-----¡-~~I~~--I 14 18 22 26 - 2230 r- ~ r --I ----¡-- 1-- - -1 30 34 38 2231 Time (minutes) ---- 2232 --- ---- 2233 ----- 2234 42 I i ¡----i 46 Water Plateau Curves - Oven Retort Kuparuk #2T-9 ----- ,- ~// ~--_.__._-'_._-----'-- -'-'-'------'-, .--" - " ,/'~,~-----,------- ----- _._- ----.-- - 1- ""'----. -~'- / ,,-#'-- ./,.---_.- //// ,"~ ,,/ // -------- /'~ ¿ ",."......- --- ----- -~ ....- " /' /(/ // ./'" ~ .J~" -._-_. ._~ -- ~ ,//-/---' ,-------- --.-.-,. -../. ~ _./- / .'-.-~-,--'_' ,_../ / ../ ...r---- ,--- .............J'" ~. ,,- ,,-/;' ---- --- --.-.---.. ~-- _____a____- ~-T---- I - 1 '-.----¡---r 18 22 26 30 I- -- ¡- I-"-"--'-~- I ,- --,---- I -- 34 38 42 46 2236 Time (minutes) -.-'---'.-- 2237 ,- '-- 2238 --- 2239 Water Plateau Curves - Oven Retort Kuparuk #2T-9 5 I / I I I ---"-~--=-- .--=----- --~ - _._-~ I I ì 4 _I /" .,-..-/ .~.'" . i'~" /-._-~~~~=~~,p--~-==:==~=----- .~.- ,./.~ /' / ,/ // ,/ ".----- - -..---- ~-ø - - .'-~-.' _._- ------" --.. .- 4.5 - .,- ,,,,' /' ¡ /.~~ -----::;;::--------------~------_/ .J ¡/ 3.5 -1' I , I 3 - 21 I I 1.51 1 ---I ~¡---- -r -- f -'-- 1 18 22 -r- " -1- , --,-- I 38 14 26 30 34 - 2240 2241 Time (minutes) -- 2242 ---'- 224J --- 2244 Water Plateau Curves - Oven Retort 5.8 ---- 5.6 ~ ¡ 5.4 -1 I I I 5.2 ] 5 ' 4.8 - 4.6 -i 4.4 --t i 4.2 1 41 j 3.8 l 3.6 -I I 3.4 -1 3.2 - --....JI' /1 I ,/ ,/ '/ I , ,I .. / J .' ,..., /1 ..- /' / ,.------/ .,,/ /1. /'/ 3 -J" ¿; ;' ,./ / .- " / r¡ . 2.6 1t' // " 2.8 - 2.4 -;-. . I --. 14 - 2245 18 Kuparuk #2T-9 --- - --'--=--~- .-- /--~//----~ ------ ------- ,---~_/ .."../' ----' ,--- _.;)//?~::~r/------~--_/ - - - ------ // / --. "-" ~-- - - ---" -~-'--' - /~:;;r/-~~ ---~- -~------------- ------------~_. - -.- / /' -- I" ./' . _.- - - - . - - ./ / '1' -,- -. 22 30 -1 - 34 -' I - 38 . ~'ì 26 2246 Time (minutes) ---- 224ì -~ .--_.- 2:248 - ---,- 2249 tgZG -- £,Ç.'Z ~ -,'-. -,-- Zgl6 -----.-- (sa:tnU!w) eW!l or 09 Ov - I , I ,.1-,.., ~ -"/ ,,.- -.,.,.- / I -' ,./ ,,/"- // / ,/ ..-' ,.,,/" I~'-"'" .,,r"'-- /1 /' ./' /' ./ ~.../' ...- / "..-"."'- - .--'. ~ /- _.r-~~"'- "....,-, "",-::::-,,,- ."..-' -- _.__-.!~.-/~~-- -- .-..- j ---------//-/ -- - - --, - --- ,.---------- --."- - -' - ---, -- . - - -,..,,/--- .--' ,.,/ ./ .--.. - 6-1Z# >tnJDdn>i LÇZZ OZ I I ./ ,.;.". , ~ ../.' ./" /' /' , / / I' .--~' I' +JO+8~ U8^O - S8^Jn:) n08tDld J8tDM oc.;zz - OL I 0 I - L - z I - £ -v ~ ç I ,- 9 - ! L " fJ) ò 0 '-'" 1J Q) L. Q) > 0 0 Q) (r L- a> +J 0 ~ Water Plateau Curves Oven Retort ~ ./,....- /------- ./ /.----/ -----~-~ .-- ////././/--'_//~U_' ""'¿'---'- /- .----..u..--. .'" /'" // ,,/..-,- / // " /// ,r.""''' Kuparuk #2T-9 6 .,.--- I . -~ 5 i j I 4- / ./..-, ./ /' I / 3- ,I ",// / / /'/ ,.,',.1' ,.'" J.J' I / / ;/ / I I .I 2 - 1 1 -1 I I I 0 I - -I f 10 20 2255 2256 - 1 30 I - 40 Time (minutes) 2257 ----,--.-- 2258 --- -- ~~-,------.-, I 50 --- 2259 4.4 4.3 - 4.2 - I 4.1 ~ 4~ 3.9 -,' 3.8 - 3.7 - 3.6 ~ 3.5 -! 3.4 - I 3.3 -t ; 3.2 -t I 3 of ! .1 -: I 3~ 2.9 -, 2.8 - 2.7 -' I 2.6 ~ 2.5 - 2.4 ' 14 \Vater Plateau Curves - Oven Retort Kuparuk #2T-9 ---:>. - ---~ -- - ,. .-...~---------------- - - '.... '--r- --¡-- -- r- -.- r ---- Î --1 18 22 26 -,- Time (minutes) 2260 ~ - I- - -- --- - -- -, -- .- 30 '~ r - -. - -- J 34 38 B005 5CHOOtJ 51. ANCHORAGE. ALASKA 99518 19071 3493541 CORE LABORATORIES, INC. -- - --. . -.-----,-. ;~ SECTION D APPENDICES Arco Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska 1-Oct-86 Appendix B Kuparuk oil Correction Table Oil Base and Water Base Cores Observed Correction Tr- Tr+ 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 >1.00 0.05 0.10 0.25 0.35 0.45 0.60 0.70 0.80 0.90 1.05 1.25 1.40 +0.4 ..... Refra ctive Index vs API Gravity 36 Kuparuk Formation 34 32 30 ~ IJ.. 28 . C\ (1) 26 -0 0 24 CD '--" ~ 22 +' > c 20 L.. ø a. 18 « 16 14 12 10 1 .460 1 .480 1 .500 1 . 520 Refractive Index Retorted Oil SPE 15185 SPE Sc )I.;JeU" o( PetroleulII (I ~1I"l(:et'-S Automated Core Measurement System for Enhanced Core Data at Overburden Conditions by O.K. Keelan, Core Laboratories Inc, SPE Member COPy"gf11 1986 SOClely 01 Pl'IrOI(-'urT, E n9,n'~",r!> Tnls paper ""as pr¡:,parea lor prf.>S.:-ntal,on illlne ROCky Mounlaln RegIonal Meellng of Ine SOC,e1}' ot PelrOIE'um Englnel:'r5 nela In 8.llIngs, MT. Mci~ 19-21. 1986 Tn,s paper VIlas seleclea for prE-senlatlon by an SPE Program Commltlee lallowlng review of mformallOn conta,ned In an abSlraCt submll1€'£1 by tne aut"or(s, Coments of Ine paper, as presenlea. have nol been revIewed by the Soclely at PelrOleum En910eers ana are sub/eel 10 carrechon by lhe aulhar(s. The malellal, as preSenled. aoes not necessall'y reflecl any poSlhan £If Ihe Soclely at Pelraleum Engmeers, ils offICers, or memDers Papers presented at SPE meellngs are suo/eel 1£1 publlcahon revIew by Edilorl8' Commlnees 01 1hE- Sociely £If Pelroleum Engineers PermisSIon 10 cOP)' IS restrlctea 10 an aOstrsct £If not more than 300 wOld!'. lIIuslrahans mav not be coplØd The abslraet ShOuld cantam cansplCuous aeknowledgmenl 01 whf>re ana b)' whom Ihe paper IS presented Wille Publications Manager, SPE, p.O. Bo. 833836. RIChardson, TX 75083-3836. Tele_, 730989. SPEDAl ABSTRACT A new automated, computer-directed, core meas- urement system furnishes porosity, air permeability, equivalent non-reactive liquid permeability (Klinken- berg), and Forcheimer (turbulence) factor at program- mable, sequential overburden pressures from 500 to 10,000 psi. The system is accurate, precise, and flexible and furnishes enhanced routine core data. Capabilities and limitations of the system are dis- cussed. Data are presented for selected rock types and a graphical technique is proposed to relate the system measured porosity and permeability values to uniaxial strain conditions. INTRODUCTION Formations deposited in ancient times were buried under successive layers of sediments, resulting in increasing depth of burial and subsequent coœpression of the rock pore spaces. Core cutting and retrieval relieves the reservoir formation pressure and removes the weight of the overburden deposits, allowing expan- sion of the core. Consequently, routinely measured porosity and permeability values are higher than those present 1n the reservoir. Adjustments to routine data have often been made by applying factors developed by simulating reservoir overburden stress conditions on representative but lImited Buites of cores from the formations of inter- est. Even then, air permeability data were often measured at low IDean pressure in the core sample, resulting 1n gas slippage and air permeability values that were higher than at reservoir pressures. Cor- rections for this slippage effect were often applied by using published correlations for uniform sand- stones. and 19nored in more heterogeneous carbonates where correlations were not valid. Low permeability References and illustrations at end of paper. formations have focused at tent ion on the importance of both slippage correction and overburden effects.I,2 The new automated, core measurement system offers a first-time capability to routinely and economically measure porosity and permeability at simulated over- burden stress conditions, while simul t8neously meas- uring the gas slippage corrected equivalent liquid permeability as well as the forcheimer turbulence factor required to predict flow in high-rat€: wells. When placed in the calibration mode, the system 1s self-calibrating with self-diagnosis of valve leak problems if present. Core sequencing and movement into a hydrostatic core holder, application of up to eight selected sequential overburden pressure meas- urements, interim data display while testing, calcu- lations and final data presentation are performed automatically while under IBM PC control. Pore volume is directly measured by helium injection into the pore space, while permeability and turbulence factor are determined during unste8d~-state flow utilizing principles described by Jones. . REVIEW OF FACTORS LIMITING ROUTINE CORE DATA Gas Slippage Effects Gas slippage effects werp. documented by Kl1nken- berg4, and the effect he observed is illustrated on Fig. 1. Unlike non-reactive liquid flow, where permeability of a rock is a constant, gas perme- ability Is seen to vary linearly with the reciprocal mean pressure in the core. Keen pressure 1s defined 8S the average of the up-stream and down-stream pressure of the rock sample during flow. It is analogous to the formation pressure. At incresø1ng mean pressureø the gas molecules are forced closer together such tbat the gas becomes more dense. behaves more like 8 liquid, and has a lower measured pente- ab1l1ty. At infinite mean pressure, the reciprocal of Pmeen equals zero and the gas 1s visualized a8 hav1ng condensed and 88 flowing like an equivalent Inert liquid. 155 2 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS Reservoir Turbulence (Kinetic) Effects Routine permeability data are measured using air at low mean pressure in the core sample. In contrast, gas reservoirs described as ..low pressure.. are at high enough mean pressure whereby the reservoir gas permeability approaches the equivalent liquid perme- ability from laboratory tests. Results of steady- state flow measurements seen in Fig. 1 require deter- minations at several mean pressures and then extrapo- lation of the data to infinite mean pressure. These tests are time consuming and expensive and have not been routinely determined despite the more representa- tive reservoir permeability value resulting when the slip-corrected K1inkenberg value is used. Klinkenberg also found that different gasses have different permeability at the same mean pressure but all extrapolate to the same equivalent liquid perme- ability. This results in different slopes of the gas permeabil ity versus reciprocal of mean pressure lines. This has importance in the automated core measurement system which utilizes helium as the flow- ing gas, and which determines both the slip-corrected permeability and a helium slippage factor (b) propor- tional to slope. The need exists to calculate an equivalent air permeability to serve as a common tie point to previously measured core data where nitrogen or air has been used as the flowing gas. This calcu- lation utilizes the helium determined (b) value, and adjusts it to arrive at a slippage factor of (b) for ai r. Air permeab 11i ty at commonly used laboratory instrument mean pressure conditions is then calculated using the equation shown on Fig. 1. Overburden Effects Increasing depth of burial results in increasing weight of overburden sediments tending to compress. the formation rock. An overburden gradient of 1 psi per foot of depth is commonly assumed, although a bulk density lo~ can be integrated to compute this overburden value.5.6 The difference between the over- burden pressure and the formation pressure increases with depth as illustrated on Fig. 2, and the dif- ference is commonly referred to 8S the effective or net overburden pressure (NOB). When formation pres- sure is unknown, it is often calculated by multiplying an assumed salt water gradient of approximately 0.5 psi per foot times the formation depth. The differ- ence of these gradients times depth yields the NOB. It is this NOB that primarily controls formation compaction stress, and it is this NOB that is relieved during the coring process and that is re-applied and simulated 1n the core measurement system. Re-application of net overburden pressures on core samples allows adjustment of routine non-stressed core porosity and permeability data to initial reser- voir net overburden conditions. It also allows both porosity and perm~ability reduction to be monitored as reservoir pressure declines with a resultant in- crease in net overburden. Normalized data illus- trating these changes in porosity and permeability were generated from measurements on the core measure- ment system and are illustrated on Fig. 3. Great diversity is observed, and different formations exhib- it widely differing sensitivity to overburden stress. SPE 15185 Estimates of reservoir flow can be made using Darcy equations and core permeabilities corrected for slippage, overburden and relAtive permeability effects. However. well test datA and laboratory data Bho~ thRt above a critical rate Darcy's equation does not describe fluid or gas flow. but predicts higher flow rates than the wells can deliver. The lower flow rate of the well has been attributed to an effect referred to as turbulence, inertial, or kinetic energy losses. This effect has been studied by Forcheimer and others7, an~ it can be quantified by core me;¡surements and included as an adriltional term in the Darcy equation. The turbulence factor has been used to describe pressure losses and to calculate maximum flow rate durin~ non-Darcy turbulent flow into a well bore. It has been combined with flowing well analysis to predict the economic effects of perforating conditions as well as the number and size of perforations re- quired to maximize production~. The effect of turbulence on flow is illustrated on Fig. 4 and the Darcy equation modified for tubu- tence is shown. The zero turbulence condition is illustrated by the straight line, where flow rate per unit cross-sectional area increases in a linear fashion as the pressure drop per unit length in- creases. Above a critical rate the relationship is no longer linear. and an increase in pressure dif- ferential 'results in less flow than predicted by Darcy flow. The excess pressure drop is rlue to turbulent, non-laminar flow, and can be calculated by the product of the turbulence factor (Beta) times the density of the flowing fluid and the square of the velocity.9 Relative Permeability Effects Routine core analysis permeability data are gen- erated with a single non-reactive fluid (gas) in the pores of a cleaned and dried core. In the reser- voir both hydrocarbons and interstitial water are present. The water sometimes reacts with the rock, or occupies pore space such that it interferes with hydrocarbon flow. resulting in a lower reservoir permeability to the hydrocarbon than measured during rout tne core analysis on the clean and dry core. In many reservoirs of moderate permeability with no rock-water reaction and sufficient height above water to be at a minimum irreducible water. the intersti- tial water does not move and has a negligible effect on hydrocarbon permeability reductIon. Routine core permeability ~ata corrected for slippage 1.0'111 approxi- mate reservoi r values in this case. In other situ- ations, water in the reservoir may reduce hydrocarbon permeabili ty and dry core Kli nkenberg dat Ii will be optimistically high. THE CORE MEASUREMENT SYSTEM The core measurement system routinely and rapidly overcomes all of the factors limiting conventional core data except for the relative permeabilIty effects due to the presence of irreducible water. Th19 can 156 . . SPE 15185 Dare K. Keelan 3 also be addressed in the system with additional effort and is discussed under Core Saturation Conditio~ that follows. Equipment Description The system is packaged in a compact desk top, front loading chassis approximately 28" wide by 30" high and 15" deep conta in ing back pIa te connect ions for helium, nitrogen, vacuum, power and data communi- cations. Major components include (I) an eighteen- sample carousel core plug holder, (2) an autom.1 t ic load and unload system, (3) hydrostatic core h,)lder and pressure appl ication assembly, (4) hel ium \'olum~ reference cells and pressure sensing devices, and (5) computer hardware and software. Equipment Operation The system is self-c~libratlng when the calibra- tion mode is specified, and utilizes stainless steel center-bored cylindrical standards of known pore vol- ume. It is also self-diagnostic, checking for proper valve operation and system leaks if present. Samples are manually loaded into individually numbered posi- tions within the carousel, which is then posi tloned in the chassis. Sample identification, length and area, for example, are requir!,!d input to the IBM PC, and grain volume, bulk volume and weight of the sample are optional. Up to eight overburden pres- sures can be designated, which may include both sequential increasing and then decreasing overburden values. At test initiation, Position 1 of the carousel is automatically rotated into position, a vacuum is pulled on the rubber boot wi thin the core holder, and a vertically upward moving hydraulic ram advances and lifts the sample into the rubber boot. After sample insertion, the vacuum is released and the minimum programmed hydrostatic confining stress is applied to the core. A quick permeability approxima- tion measurement is then made for selection of both the upstream volume and pressure to be used during subsequent permeability measurements. Pore volume is then determined by expansion of helium into the core sample from a known volume source at approximately 240 psi. At pressure equili- brium, Boyle's Law is used to compute pore volume. The difference between the confining stress and the equilibrium pore pressure is the net confining stress. During this operation the overburden and internal pore pressures are monitored with digital readout on the chassis, and by a real time visual display of che plot of pore pressure versus time. Permeability is then measured by flowing helium from the previously selected volume reference cell at the selected pressure through the core. The downstream end of the core Is maintained at atmos- pheric pressure. The upstream pressure decl1ne is monitored in real time, and is observed by digital readout and visually displayed in either graphical or tabular form. The difference between the confin- ing stress and the mean pore pressure during flow is the net confining stress. Unsteady-state equations developed by Jones are used to calculate the Klinkenberg slip corrected permeability, the hel1urn sl1p factor, and the For- cheimer turbulence factor.3 Air permeability is then calculated as a b.1se to be compared l..:1th other non- Klinkenb~rg measured core information from the field. Tile next pre-programmed overburden pressure is then applied to the sample and measurements are repeated. After the last permeability measurement is completed for Sample HI, the final selected overburden pressure is released, vacuum is applied to the rubber boot releasing the sample, and the core rides downward as the ram retrieves. Dat;:¡ are printed and stored on both hard Rnd floppy disks. The carousel then rotates into the next posicion and the sequence is repeated until all samples are tested. Data can then be transferred to d central computer for stßtistical manipulRtion, graphical dis- play, and core analysis final report g~neration. CAPABILITIES AND LIMITATIGrJS Sample Sizes The current carousel will hold a maximum of 18 one-inch diameter cylindrical plugs, 3/4 to 3 1/8 inches in length. Since pore volume is by direct helium injection, sample ends must be essentially parallel, and data indicate well maintained normally used preparation equipment can furnish adequate sam- ples. Co~e should have square, not rounded, corners and be free of surface vugs and chipped edges. By mid-year,' sample-size capabilities ~ill include 1 1/2 inch diameter cores, and a 100 sample holder for either diameter that can he substituted for the carousel. Stress Conditions The confining stress is applied hydrosta ticaIl y (equal on all sides) and can vary from 500 to 10,000 psi. A maximum of eight stresses can be programmed, and increasing as well as decreasing stress can be simulated. The minimum confining stress to yield porosity and permeability data comparable to routine zero stress porosity and routine 400 psi stressed core for permeability measurements is apparently a function of the hardness of the rubber boot that surrounds the core. The boot should be soft enough to conform to sample sides at low confining stress, but hard enough so that it will not flow into pore space at high confining stress and faU to properly release the sample at test conclusion. The current boot material requires at least 800 psi confining stress to conform to the samples. hut a ne~ design currently under investigation appears promising in allowing the minimum stress to be reduced to 500 psi. Accuracy and Repeatability The system was des igned to yield accurate and reproducible permeability values over a r8~ge of 0.01 mllUdarcies to 2 darcies. Test data i~dicate pore volwnes can be determined for a range of 1).02 cc to 10 cc. Tables 1, 2 and 3 and Figures 5, 6 and 7 furnish control data on both one inch dismeter steel standards and core samples substant14ting design specifications. Control data are commented on in Data and Discussion of Results. 157 4 Sample Consolidation AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 15185 Most tests to date have been made on consolidated cores. Limited data indicate (that unconsolidated rock mounted in shrinkahle tub ing 10 can be run in the device. Investigrition of applicability to these type cores as well as metal jacketed samples i9 yet to be completed. Core Saturation Condition The system was designed to test clean, dry cores. Data indicate valid permeability at irreducible water (Swir) can be measured. Multiple cores should not be batch loaded as evaporation will occur while awaiting analysis, and immob tIe wa ter is necessary to prevent water redistribution during gas flow and movement from the core. Total eva pora t ion during analysis should be monitored by sample weights. Indicated hydrocarbon pore volume (l.O-Swir) reduction due to overburden will be inval id and masked if the volume seen by injected helium increases due to evaporation. DATA AND DISCUSSION OF RESULTS Accuracy and Repeatability of Steel Standards Each core measurement system 1s calibrated at 1500 psig confining stress utilizing stainless steel cylinders of known pore volume. Each 1s sUbsequently independently checked with a set of steel standards. Typical resul ts of a pore volume accuracy and repeatability check are shown in Table 1. These tests were run overnight in a laboratory with no special temperature control. Maximum pore volume difference observed 1n 'the sequence was 0.035 cc, which yields a maximum porosity error of 0.27 porosity points (1.e. 10.0 to 10.27 percent) for' a I-inch diameter plug I inch in length. This is well within the API RP 40 accepted accuracy of + 0.5 porosi ty point. II - Table 2 illustrates pore volume accuracy and consistency between various sys tems checked wi th a set of common standards. These locations represent various elevations, barometric pressures and tempera- tures, and exce lIen t agreemen tis seen in measured pore vol umes. Permeability checks on steel standards are shown in Table 3. All fall within the + 5% industry stan- dard for plugs of modera te permeab 111 ty and reproduc i- billty is excellent. Accuracy and Repeatability of Core Plug Standards Suites of cor~s tested with steady-state perme- ability techniques were used as standards in this evaluation. Air permeability was selected for com- parison as most historical data are in this form and routinely used permeameters develop these data. Mul- tiple measurements were made on carefully calibrated equipment and cross-checked between various instru- ments to arrive at standard values. Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state ai r permeability measurements. The difference shown 18 expressed as a percentage of the steady-state value. Three measurements are presented for each sample to illustrate reproducibility. The data indicate three samples with a difference greater than 57. of the standard value. Two are lower permeability samples. of less than one mlllidarcy. The + 5% limit was set for higher permeability samples, ãnd the tolerance is normally expanded in the lower range because of the small values measured and sensitivity to mean pressures 1n the core as permeability becomes lower. For example. if the true air permeability value is 0.020 millidarcies and the tested value found is 0.025. an error of 2S¡ is indicated, although the magni tude of the difference is inconsequent ial and the permeability in both cases is quite small. A much larger (100i.) error results from the incorrect use of the air permeability value of 0.02 to repre- sent reservoir permeability rather than the slippage corrected Kl1nkenberg value of 0.01 determined for this plug. Figure 6 shows comparisons of zero stress meas- urements utilizing a small volume porosimeter (SVP) versus core measurement system porosity data at 800 psi confining stress. Porosity in the system has been calculated using various equations that require different basic data. The zero stress equation util- izes bulk volume determined by mercury displace- ment (BVHg) and grain volume (GV) measured in a U.S.B.M. modified Boyle's Law apparatus using helium as the gas. ø a BVHg-GV X 100 BVHg ............(1) The core measurement system uses equations in decreas- ing order of preference as shown below. Pore volume (PV) is by direct injection. and bulk volume is determined by one of three techniques. ø .. PV x 100 PV+GV ............... (2) ø .. PV x 100 BVHg ................(3) ø ... PV x 100 LxA ................(4) In the Fig. 6 data set all porosities agree well with mean porosity differences from the zero stress condi- tion of -0.2. -0.2 and -0.3 porosity points respec- tively. Figure 7 presents individual sample porosity differences comparing values from F.quritions 2, 3 and 4 with Equation 1. Equation 2 allows for a decrea~ing bulk volume as confining stress increases. Equation 4 typically yie Ids porosi ty values too low, as rounded corners or broken edges are often not properly accounted for tn length (L) and diameter meéisurements used to com- pute area (A). This resul ts in higher bulk \'olumes than true; hence, low porosities. Equations J and 4 can be modified as illustrated below to allow for decreasing hulk volume as confin- ing stress increases. 158 'i:, Sl-'E 15185 Dare K. Keelan 5 0 .. PV BVHg-(PVi-rVn) ............(5) \.Jhcre P\'i .. Pore volumc in cc at minirnum confining st~es5 (800 p~ig) PVn .. Pore vol ume Ln cc at -'iny succeed ing st ress Overburden Effects Table 4 presents typical system data at various confining stresses on a lo~ and moderate permeability sample. Measurements ~ere m~dc at t~o locat{on~ to evaluate consistency between instruments. Once again, repeatability is good, although Run 2 dAta indicate samples have not tully rehounòed from stres- ses imposed several days earlier during Run 1. Po- rosity and permeability decrease as expected, and these data indicate values of (b) related to slip- page are essentially inJependent of confining stress, I.Ihereas turbulence factors (Beta) tend to increase as confining stress increases. The Sample A Beta factor at 6000 psig stress decreased remarkably 1n Run L, and this anomalous behavior was seen again in a second instrument in Run 2. Reasons for this are unknown. Figure 8 presents a typical porosity comparison between system measured porosity at various confining stresses with (1) a porosity generated at zero confin- ing stress and (2) with a helium injection technique commonly employed in Special Core Analysis laborator- ies. The zero confining stress measurement is des- cribed previously as Eq. 1. The "Pore Volume by Helium Injection" was determined with the core con- fined in a hydrostatic boot of lesser hardness than used in the system. SOll1e initIal porosity differ- ences between the three techniques 1s to be expected because some finite stress is required for the direct pore volume measurement techniques to conform the boot to the core exterior. The data indicate that 250 psig yields conform- ance in the softer rubber, while approximately 750 psig confining stress was required for the system to match the zero stress porosity. All measurements agree within an acceptable tolerance of 0.5 porosity points at the initIal values reported, and the system and commonly used helium injection technique agree within acceptable limits throughout the o\l'erburden stress range investigated. INVESTIGATIONS IN PROGRESS Pore Volume Compressibility Investigation is ongoing to e\l'aluate core surface conformance effects as the rubber boot surrounding the core is subjected to increased confining stress. This has importance in evaluation of both porosity reduction observed in the system, and pore volume compressibility calculated from system measured pore volumes. Initially the boot is held away frORl the core 8urface by tops of grains and/or any high points present. As confining stress increases, the boot conforms more closely and flows into the indented spaces between A1R~ ot the core may not have compressed at all, and the pnre volume compressibillty calculated from pore vol- un'to:? reduction is erroneously high. WhL~n the hoot m:nerial fills the surf.1ce indenrions, subsequent incr~.lse in confining srr~ss docs compress tllc rock and result in actual pore volume compressibility. Samples prepared for constanr temperatur-c, pre- cise compressibility measurements are o'Jrm.11Iv jack- eted with Cj he¡:¡t shrink¡:¡hle tubing th¡:¡t ftlls surface indcntlon~ S0 th~t no conformance prohlem exist~, ¡:¡nd carly applied confining stresses see onl~ sample compression. Figure 9 tllu!>tr.1tes por0 \',)lume de- crè.1SC for d jacketed and non-.i::¡cket,~,i core. The j;¡ck.et.~d sample also contained water .',t thc time of test, ~hich sometimes softens the rod: and yields gre.'3ter and more represent:Hive pore v,)lum~ compres- sihiliry than a dry core. This sample w;:¡s tested, while jacketed, in a hydrostatically stressed comprcs- sihlliry apparatus, and the jacket ~as r~m')\'ed prior to testing the sample in the system. Curve 1 is the first system compressive eyc Ie. and greater pore volume reduction is seen at lo~ net stress than observed on the jacketed core. This is believed due to the boot conformance previously discussed. even though this sample l.Ias relatively smooth. Curve 2 is the hysteresis curve, and at the minimum net confining stress of 400 psi obtained after the, hysteresis loop, a lesser pore volume than initial is determined. This may gradually recover to initial value as a function of time, or may remain permanently reduced depending upon properties of the core and whether the elasttc limit was exceeded. Examination of other data from this reservoir indi- cated an elastic limit of slightly greater than 4500 psi, and for this reason this test was not taken above 4000 psi confining stress. Curve 3 represents the second compressive cycle and Curve 4 is the final hysteresis cur\l'e. Note that the slope of the pore volume curve is essentially the same for the jacketed and non-jacketed tests above a net stress of approximately 2000 psig. Although Cycle 3 is below Cycle I, pore volume compressib { Uties would be essentially the same at the higher pressures since the slope of the pore volume versus net confin- ing stress is similar. Figure 10 presents porosity as a function of net confining stress. Agreement is well within accepted tolerance for both tests over the range of stresses applied. Note that a net confining stress of approxt- mately 800 psi was required on the Curve 1 t:ornpres- sive cycle to yield the pore volume measured on the jacketed core at 200 psi net stress. These data indi- cate boot ~onforrnance was occurring in this sample until at least 1500 psi net stress, yet the conform- ance effect on porosity was negligible. Figure II illustrates the sensitivity of c81cu- la ted pore volume compressibility to in1 t ial boot conformance. The early systelD values do not appear to represent true pore volume compressib i lity. but conformance. While differences in compressibility at low confining stresses are significant, comnYPs ihil- i t"v i n 4 .. 6 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED ,CORE DATA AT OVERBURDEN CONDITIONS ", 'SPÈ 15185 )-: the jacketed sample., (1.e. system value .of 7.4 x 10-6 versus 9.3 x 10-6 at 4000 ps1g and much better agreement at 2000 psi.) The system can furnish large volumes of da ta rapidly which are likely to be ~uch more representa- tive of a formation or its various rock types and lithologies than average correlations in the litera- ture. The data can and should be calibrated to more precise measurements by running a Buite of water saturated Jacketed cores in a compressibility appara- tus, and arriving at a confidence and adjustment fac tor to be applied to the system ca lcula ted pore volume compressibility values. Irreducible Water (Relative Permeability Effects) Table 5 is a subset of data to illustrate the effect of irreducible water (Swir) on the Klinkenberg permeability. The data are somewhat erratic due to the unusual relationship of porosity and permeability indicated, and Swir appears quite low for two of the three samples. These cores were reported to contain kaolinite and perhaps slight changes in loose particle location in the dry core contributed to these results. In any event, irreducible water saturation of. up to 22.9 percent pore volume had a negligible effect on gas flow in all core tested. This indicates the dry core Klinkenberg permeability would represent gas reservoir permeability in zones containing irreduci- ble water. The samples were then restored with oil and oil permeabilities were determined. Sample 3'yielded an oil permeab UHy equal in value to the Klinkenberg values found both on the dry core and the core con- taining irreducible water. The total data set indi- cated that in 40% of the samples tested, Ko at Swir equaled the dry core Klinkenberg value; cònversely, 60% of the samples gave poor comparison. The conclu- sion here is that validation of the Klinkenberg value at Swir as equal to the Ko at Swir must be done on an individual formation basis with independent oil permeability measurements. Table 6 illustrates the effects of irreducible water on slippage factor and turbulence for the core identified as Sample 3 1n :rable 5. The b value decreased in this and other cores tested in the presence of Swir, while turbulence factor (Beta) remained essentially constant. Conversion of Hydrostatic to Uniaxial Strain Data The core measurement system employs a hydrostatic load to simulate stresses of the rock at net overbur- den conditions. lIowever, numerous authors have indi- cated that reservoir stresses are not hydrostatic, and the reservoir Is free to compact in a vertical direction only, with no deformation laterally. This is referred to as uniaxial strain. Teeuw showed that uniaxial pore volume compres- sibility was approximately 62% of hydrostatic val- ues12. Anderson presented data comparing hydrostatic loading to uniaxial, and equations to transform hydro- static pore volume compressibility to uniaxial strain conditions13. It follows that a hydrostatic pore volume compression that is too high will resul t in . ". ';, . ,/ .: ' ~ t~~ì;'::~~;: .. ,..' "',. ..~l~~."r~ þ~ .. I~': ~ .~ I : .'.' . fir ,. ; a laboratory porosity reduction that is too high. Similar results have bee~ reported for permeabl1ity14. If reservoir compression is only 62% of the laboratory value, then the reduction in reservoir porosity should only be 62% of the measured hydrostatic laboratory value. Nelson concluded permeability could be derived from hydrostatic confining pressure tests by calcu- lating the mean stress in the reservoir and then reading the permeability value from the hydrostatic curve at the calculated mean subsurface stress1S. Both porosity and permeability data from the core measurement system can be normalized by dividing eñch overburden value by the ini tia1 value at the minimum confining pressure. This type of data is illustrated on Fig. 12, and the curves allow'a quick approximation of uniaxial strain porosity and permea- bility. The approach illustrated employs the average correction factor of 0.62 proposed by Teeuw. ' The curves are entered at Point A, the calculated reservoir net overburden pressure computed 'as illus- trated in Fig. 2. The porosity Þfraction of original" curve intercepted at Point B represents too great a reduction. In porosity since porosity was measured under hydrostatic loading. This "fraction' of origi- nal" value is adjusted upward using Teeuw's factor by multiplying 0.62 (1.0 - normalized porosity factor read at Point B) and subtracting this product from 1. O. This adjusted value is plotted as Point C, which is the porosity "fraction of original" more representa~ive of reservoir conditions, and which approximates data that would have been measured had the core been tested in a uniaxial strain test.' We then move from Point C horizontally to the'" left. to intersect the hydrostatic curve. The net overburden pressure Point D corresponding to this intersection 1s the equivalent mean stress on the hydrostatic curve required to yield the reservoir uniaxial strain' porosity. By moving vertLcally, we intersect the normalized permeability curve at Point E at the same mean stress. We can then move horizontally to the left to Point F which represents the factor for permeability adjustment. This factor times initial pemeabllity yields the desired permeability value. Reliability of this approach for a particular formation would be improved by having uniaxial perme- ability and porosity measurements to compare with hydrostatic and to develop the actual correction factor for the formation. CONCLUSIONS 1 . Klinkenberg corrected permeability, porosity, slippage factor (b) and turbulence factor (Beta) can be accurately and routinely determined in the core measurement system at overburden pres- sures. 2. Overburden pressure effects (tnclud ing hys tere- sis) can be easily studied by designating confin- ing stresses that are automatically applied from 500 to 10,000 psi, and differences 1n properties at overburden conditions from low stress measure- ments can be significant. 160 ,;, . .. . '."'. .': '. / .:,~ ' ,~;J, , .~ :{?~- ., SPE 15185 3. Dare K. Keelan 7 Klinkenberg slippage factors (b) uere essentially the same or increased only slightly in the sand- stones tested as overburden pr¿ssure increased, and the presence of irrcducible water resulted in a decrease in (b) value. 4. The turbulence factor (Reta) increased moderately in the sand stones tested as overburden pressure increased and the prescnce of irreducible w;¡ter I¡;:ld I1tt1e effect on its 'J.:llue. ~. ^ ~inimu~ confining strcss of 800 psi is currently required for the system d~t~rmined porosir:)' and permeability to equal (I) porosity values at z,~ro stress and (2) air pèrme.Jhllir:)' values :'it .:.00 psi confining stress no\.J ~mploycd in routine core analysis. 6. Helium injec t ion porosi ty measurement techniques routinely employed in Special Core Analysis labo- ratories yield porosity values in good agreement with those measured on the system. 7. Conformance of the rubber boot to the core sur- face had little adverse effect on system poros- ity values at pressures above 800 psi confining stress, and the jacketed and non-jacketed core yielded similar values of porosity throughout the range of overburden pressures investigated. 8. Pore volume compressibility of the non-jack- eted core was extremely sensitive to boot con- formance at confining stress below 2000 psi. Above this stress compressibilities approxi- mated true values. Compressibilities determined on non-jacketed dry core should be calibrated to best technique values by comparative measure- ments on jacketed, water saturated samples tested in a compressibility apparatus. 9. Hydrostatically confined porosity and permeabil- ity determined at selected net overburden pres- sures and presented as a fraction of original values allows approximation of both porosity and permeability at uniaxial strain conditions. Note: This is likely to be restricted to well- cemented cores whose behavior follows elastic theory. 10. The system can be used to measure Klinkenberg gas permeablity with irreducible water in the core, and thereby verify whether dry core slippage corrected permeability at confining stress is representative of gas flow with connate water presen t. 11. Applicability of the system Klinkenberg gas perme- ability (with or without irreducible water pre- sent) to represent oil permeability (Ko) with irreducible water present must be verified by independent measurements of Ko. NOMENCLATURE k - permeability, md KA - permeability to air, Koo - K11nkenberg "Liquid" b . K11nkenberg slippage md permeability, md factor, psi Pmean = 3rith~etic average pressure in core, psia p = prcssure, psi;¡ L = length of flou path, ft V = vc10c(ry, ft/sec ß = Het~ = turbulence factor, ft-I W = gas viscosity, cp P = dènsity of fluid, Ib mass/cu ft ACKNOWLEDGMEt:TS The ,-wthor gratefully acknowledgcs t!¡(, <:ontri- hur ion of Brian Davis and Lisa Curry ~nci th()s(~ ",rho dev~lored ~nd implemented the theory r¿sultinr In the .1utl)m.Jr.~d core measurement system. REFF.REtJC[S I. Th.)IT],l~, R. D. and Ward, D. C.: "Effect of 'J\'er- burd¿n Pressure and Water on Gas Permeahillty of Tight Sandstone Cores," J. Pet. Tech. (F~b. ¡q72) 120-12~. 2. Jones, F. O. and Owens, I.J. W.: "A L:'!boratorv Study of Low Pp.rmeabllity G.1S Sands," AIME-SPE 7551 (May, 1979) Denver Low Permeability Gas Res¿rvoir Symposium. 3. Jones, S. C.: "A Rapid Accurate Unsteady-Stare Klinkenberg Permeameter," Soc. Pet. Eng. J. (Oct., 1972) ,383-397. 4. Klinkenberg, L. .I.: ..The Permeability of Porous Media to Liquids and Gases,.. Drill. and Prod. Prac., API (1941) 200. 5. Christman, Stan A.: "Offshore Fracture Gradients," Soc. Pet. Eng. J. (Aug., 1973) 910-914. 6. Breckels, J. M. and Van Eekelen, H. A. M.: "Rela- tionship Between Horizontal Stress and Depth in Sedimentary Basins," paper SPE 10336 presented at 56th Annual Fall Tech. Conf. and Exhibition, San Antonio, Texas, October 5-7, 1981. 7. Tek, M. R.. Coats, K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Gas Through Porous Reservoirs," J. Pet. Tech. (July, 1962) 799-806. 8. McLeod, H. 0.: "The Effect of Perforating Condi- tions on Well Performance," J. Pet. Tech. (Jan., 1983) 31-39. 9. Cornell, D. and Katz, D. L.: "Flow of Gases Through Porous Media," Ind. Eng. Chern., (1953) 45, ~1:'5. 10. Griffin, T. J. and Bush, D. C., "Core Analysis in Unconsolidated Reservoirs Using an Improved Consolidation Technique,.' 36th Annual Meering of Petroleum Society of ClM, Edmonton, AIta., Paper No. 85-36-41, June 1985. II. API-RP 40: Recommended Practice for Core Analysis Procedures, American Petroleum Institute. Dallas. 12. Teeuw, D.: "Predictions of Formatton Compaction from Laboratory CompresøibUlty Data,.. Soc. Pet. Eng. J. (1971) 11, 263-271. 161 8 , . AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDRN CONDITIONS 13. Andersen,.K. A.: "Predicting Reøervp1r Condition Pore-Volume Compressibility from Hydr08t8tic- Stress Laboratory Data" paper SP! 14213 presented at the 60th Annual Technical Conference and Exhi- bition, Las Vegas. September 22-25, 1985. 14. Gray, D. H.. Fatt, 1. and Berganini, G.: "The Effect of Stress on Permeability of Sandstone Cores," Soc. Pet. Eng. J. (1963) 2, 203. 15. Nelson. R. A.: "A Discussion of the Approximation of Subsurface (Burial) Stress Conditions in Lab- oratory Experiments." Geophysical Monograph 24 t American Geophysical Union (1981) 311-321. r.- ~>. SPE IS185 ~{~A, :'.'~~ ~ TAHL£ I A TIl' I CAL (DI{£ ,".r.ASUI'.f.MÐlY' 5 'I"::>"T1::M CALIIWA T I O~ AlID REPCA T Aßl LI n A.'I'¡AL~IS ON STI:t:L PJP£ VI')U","( SfAlltM\Rœ AT CJ'f1NI~ S11>.ESS ST M1Y>.RD '.QUJI1£ . (I. 19~ c:<: (-.:", tin I o.;¡ S'.t\IISS f'sl~ !-<un I P.un 2 Pun 3 Pun 4 P:u'lS 10'}) r). :<'07 (-. 'JI 2) 0.230 (-.03~1 0.n3 (-.o~e) fJ.n4 (4.0~9) O.2~2 '..O:7~ 20ll') 0.1':13 (-.Otl21 0.2:<':1 (-.un) 0. :<'IS I' .0~01 O. 21 ~ ('.0';>1) 0.: 13 i- .LlI>!' 3000 (I.ISt! 1- .ù07) 0.217 (4.fJ2:11 0.210 (-.015) 0.211 (- .01 /)) O. il)'I I' .01 ~) 4000 ('.1~4 1-.(11) 0.113 (+.018) O. :<'01) ,- .01 1 0.207 1-.012; 0.:0'/ '.01)) 500u Ü.I>30 (- .01 <'1 0.210 (-.OIS) 0.203 I'. OljB¡ 0.204 /'.¡)O';¡) C'.203 . . DC';; , (,O')Ú O.I7~, 1-.Ol'~1 0.20'" (+.OD) 0.201 '-.OO/;') 0.20~ (-.0(1) (I. ::00 f.. .')0:-' ~ïOJ'IûØJ>.D \"JUJ"I£ - I. ')21 cç 1 ("..Il' I . Ù 17 I - .0')4 1.'14S (+ .024) I.fJ43 (. .fJ::t' I 1.04J (".onl 1.0.¡~ (..onl :0,-11,) I .(".1'3 (-.0 I 3 1.03'::> ('.0141 1.034 (- .1313) 1.034 (-.0131 1.034 \-.OIJI 3ùLI'J I. 00'] '-.0 I "t) 1.031 (4.010 1. 0 3ù (4.0':09 1.()29 (- .(J')t! I. ()},. '. (I,~~) 4'JIJ') 0.9'1~ (-.0~31 1.0:7 1+.001j1 1.025 (+.0')4) 1.02'::> (+.0041 I.''):'::> 1-.0')41 ~')OO 0.994 \-.027\ J.0~3 '-.0231 1.022 (-.001) 1.023 (+ .O')~ I I.02¡ I- .001) 6ùOù 0.991 (-.0301 I.O~O (".020) 1.020 (-.001) 1.010 (- .')'.1 II 1.019 1-.0')2) ::.ïANQo>J-'.D V'Jll.t'\E . 3.099 C'C 10'.10 3.101 (-.002) 3.123 (+.0341 3.131 (-.032) 3.128 (+.()291 3.1~9 (-.02B) 2000 3.0!!9 (-.010) 3.121 (+.022) 3.119 (+.0:/0) 3.119 (.. .020) 3.117 (-.013) 3000 3.0133 (-.fJI6) 3.114 (+.01'::» 3.113 (4.014) 3.113 (+.014) 3.JI31-.014) 4000 3.077 (-.022) 3. 109 (+. 0 I 0) 3.]08 (+.009) 3.108 (+.009) 3. ]09 (. .ClIO) saoo 3.073 1-.026) 3.IOS (..006) 3.105 1+.006} 3.103 (+.004) 3.105 (+.0061 6000 3.0159 (- .030) 3.102 (+.003) 3.101 (+.002) 3.102 (+.003) 3.102 (+.003) I) OIS ran O\.",rnigtlt in aUt.()IMtic node In laboratory envirOl"l'lW:!'nt with Vilriao]e telTpP.r...ture. 2) Haxinum error of 0.03'::> cc WOJld result in 0.27 porœlty percent point error in a salTp1e of I indl dlNTlE'ler and ] inch length (Le. 10.0 to 10.27 poroc;ity percent). ,. ABLE 2 srANI:WU:6 OŒ:CI<. 1 UJJSTRATING CORE HEASlJREMENr SYS'I'DI PORE \IOWME N:.OJRACY AND ~ISTENCY ~ LOCATrOOS (AT 1000 PSIG ~F1NING ST'RESS) St.andard Volumes C'C Aberdeen London- Calgary" Dallas [)eonve r 0.1% 0.209 (+.014) 0.188 (-.007) 0.212 (+.017) 0.199 (+ .004) 0.~5 0.~40 (-.005) 0.51~ (-.0301 0.~47 (+.002) 0.529 (-.016) 1. 021 1.026 (+ .005) 0.999 (-.022) 1.016 (-.005) 1.014 (-.0071 1.0:'5 (".004) 3.099 3.104 (+.00'::» 3.085 (-.014) 3.092 (-.001) 3.091 (-.002) 3.105 (+.OOt) 5.109 '::>.118 (+.009) 5.101 (-.008) 5.086 (-.023) ':>.108 (".0011 5.109 10.000) -After 1 year (Ieold trial in ~rdeen uReclIlibratlon atter field repair TABLE 3 OORE I'1EASI.JRÐ1ENT 5 Y$T'Ð'I AI R PCRMEABl L ITY N::OJRACY AND RCPfATABILrTI OiOCK ~ STEI::L STANIWIDS Stf-,actl Coof I n1 nq Stat E' St ress Sð/Tp J ~ ( !we r ð-.JP. Pslq Numroer ~ ~n I Ptln 2 ~ rrror sao A 1.09 I.Q5 LOS 1.0'; -3.1\ 1000 A 1.04 1.05 1.04 -4.3\ 500 B 29.3 2B.7 28.6 28.6 -2.3\ 1000 8 28.13 28.7 28.6 -2.0\ ~OO C 48.5 46.5 46.5 <16.4 -4.2\ ]000 C 46.4 46.4 46.4 -4.1\ sao D 73.1 10.1 70.5 10.4 -4.3\ 1000 D 10.6 70.5 70.3 -4 . 3\ 500 E ]430 1480 1480 1470 +3.3\ 1000 [ 1490 1490 1480 +4.2\ . ' ~\<:.~, . t):~~i;' ',?~D: f , ' ~ ,'I TA8L8 4 TIPlCAL Q)RE fI£ASI.JRD1mr S't'Sl'Ð4 CORE 0t.TA AT cx:tIF IHI I'C STRESS IWJSTRATI~ ~ISTIN::\' ~ INS'I'Rt.Jt1fm'S SAMPu: A (~ PER!'1£AB t tITY) Cant lnlnç¡ ~llas (Run 11 Denver (~n 21. Suess ø K Ka{est! b(He) Rata ø K Kð(est b{liel ~:ï Ps1a ...!- ...!!!L ~ ~ pt-l -!.- ~ ~ ~ 500 10.7 .065 .141 56.6 2. 75xl013 10.7 .055 .no 66.6 1.16xl013 800 10.6 .057 .132 63.2 2.96111013 10.6 .052 .126 M.2 2.44xl013 1000 10.6 .054 .129 67.2 2. 74xl01) 10.5 .052 .124 67.7 :'.8hlO13 2000 10.4 .053 .122 63.0 4.52xl0n 10.4 .050 .118 65.7 3.fj8x1013 4000 10.2 .048 .Il4 66.8 4.05xl013 10.2 .047 .112 67. I J. 7lxl013 6000 10. I .043 .109 75.9 1.'5hl0lJ 10.0 .043 .109 74.0 1. 77..1013 SAMPLE B (1'ûŒ:RA TE PE'RMEAB I UTY) 500 19.6 33.9 37.3 4.88 3.46xl08 19.3 33.4 36.7 4.BO 3.55xlù8 900 19.3 32.8 36.2 4.96 3.65x108 ]9.1 32.4 35.6 4.84 3.81xIOB 1000 19.2 32.4 35.7 4.95 3.80xl08 19.0 32.0 3';.1 4.80 3.93xl08 2000 18.9 31.1 34.2 4.95 4.05xl08 18.6 30.7 33.7 4.80 4.23xl08 4000 18.5 23.6 32.6 5.04 4.33x108 18.3 29.2 32.1 4.88 4.54xl08 6000 18.3 28.5 31.5 5.05 4.56x108 18.1 28.3 31.1 4.91 4.77xl08 -Data ge't indicated pore space at tilœ of Run 2 had not. fully rebc:unded frcn 6000 psl ~res5lve for-ce irrpœed several days earli~r dlri~ Run 1. TABLE 5 lRREOOCIBlE W/U"ER (REIATIVE PERHEABILITY EPFæT) 00 OJRE: MEA5UREMENT SYSn)1 KLI~ PERHFABILITY AND OIL PERMEABILITY AT CCNPINI~ STRESS 01S Kl i nltenberv Oil Pe1:1ll8abi 11 ty:mcI Pe[1'lØabil i ty:lldu SaJrple Porosity Swir Dty Core Core EI Swi r 1<0 EI Swir N\.ITIber , 'PI 800. 4000. ~ 4000. 800" 40005' 1 15.5 5.0 545 520 543 517 400 374 2 7.7 7.2 32.2 29.5 31.3 29.3 22.3 18.5 3 17.2 22.9 30.1 28.7 31.1 29.6 30.7 29.2 -Conf ining Stress . .Stea~-State Heasur:-enent TABU: 6 IRREDJCIB[£ ~TER EI"FfX:T CN SUPPAGC (bl PACroR AND 'IURBlIt.DICE (BE:I'AI P'AC'IOR AT CX:WPlNIM:; STRESS Conflning Dry Core l rrt:dJci t> Ie Sw . 21.9 , PI Stress ø b( He ) ~~ b(HeI Beta Psig -L. ~ ~ Pt.-1 ';00 17.4 4.90 2.B4xlO8 4.11 2.8lxl08 800 17.2 5.03 2.81xl08 4.10 2.89xl0B 1000 17.2 5.06 2.83x108 4.13 2.90xl08 2000 16.8 5.05 2. 99xl08 4.16 2.99xl08 40ÙO 16.6 5.11 3.04xl0B 4.27 3.06xl08 6ÙOO 16.5 5.10 3. 19x108 4.30 3.15xl08 , . J.L ~, . ~\.. '0°'1' .r,¡ . ~ IK,=Kø >- I- ::!" ~ ':l ~ w ".-' 2 ,,~ 0:: /,- W ~~,- NON-REACTIVE LIQUID 0.. !It............... ...... II' """,, ,..,.",." ~Kø SLIPPAGE CORRECTED KLlNKENBERG PERMEABILITY --L P mean . °0 Fig, l-Peorml!'8blllly 8S 8 luncllon 01 mun prUlur!!. 1 D ;J 9 I t. .. g ~ ~ RlFt~ll<Ç( VAI,U£S ~ SOO PSI STRt~ nJlllr,E/ERG ~'.!1 ~~ 318"'0 19J'~ 01&1,1{) 11&", r I-j .. i 6- ; ~ 0 z ... ~"!OOJ. ,"""",-__~ ,f.,~ "--~ ~ It' 3 0 5 6 7 cc..r '~I'IG S 1~!:-5 . r>.e.,rs ~MJZ or 1'51 fig 3- Poroslly a"d p!!rm!!sb""v VI, conllnl"g Ilr!!ss. SURFlIC[ SU;-U.(( ov [R8u'tD[:/ PRf 5Sl.lRE , RESERVOIR PRE55URE. NET OVERBURDEN = (OVERBURDEN PRESSURE J - (RESERVOIR NOB~DEPTH 11.0~\' -O.5~\i) ~ 0 E P T H ( 0,5 ~ \' I FIg. '-Np! oyprburdcn P'PS!U'P yS depll1 UJ 1-- ~ 0: ~ 0 -J l..L... /1 00 EXCESS PRESSURE LOSS DUE TO TURBULENCE [- ~~ : V f t ß p V 21 PRESSURE DIFFEREtITIAL . rú Fig, 4-Elfecls 01 lur/JlJle"~e "n 11o... I: PRESSURE) w ~ w Ir w '- '- õ .- z w u 5 -100:::- Q. -20~ - 307. 20Y. - 10:"; - O~ ----~ - -.- CONfiNING STRESS (800 p.lliJ) ---.. -JO~ 336 262"'216-1 11~8 175 r~9;~~.-6-'--52.2 ,s.ã--r0:62o :.'90 230 203 177 157 905 71.1 22.00.73 INDIViDuAL SAMPLE PERME ABILI TV. MIL LlDARCrES - RUN 1 - RUN 2 - RuN.3 F"I. 5-01,......... of .,..-........- ANI .land- 16.0 15.0 14.0 CONFINING STRESS (800 p.lliJ) 13.0 12.0 Z 11.0 ~ 10.0 u 0::: ~ 9.0 D... 8.0 l: 7.0 iñ 0 6.0 a:. 0 Q.. 5.0 4.0 3.0 2.0 1.0 0.0 ~ =- è. Vi 0 0:: 0 Q. I u I:! û Ir w ..... I... 6 I I II I I I' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I . I I I I .' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I' I I I I I I I I 'I I I I I I I I I I I I I I I I I I I I I I I I- I I I I ..~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 'I I I I I I I I I I I I I I I I I SVP - PV/(PV+GV) 2 10 1 1 9 18 14 16 19 7 5 12 20 6 1 J 1 7 4 15 8 SAMPLE NUf..tBER - PV /8VHg - PV /(UcA) Fig --Cor. -, .y8l- poroelly... 8tand_. 1 0.9 - 0.8 - 0,7 - 0.6 - 0.5 - 04- 0.3 - 0.2 - 0.1 - CONFINING STRESS (800 p811iJ) =~:~ ~, -0.3 = I I -0.4 - -0.5 - -0,6 - -0.7 - -O.B - -0.9 - -1 1 0 1 B '" 1 6 1 1 2 9 7 1 7 1 2 6 20 1.3 5 15 4 8 19 SAMPLE NUMBER - PV /BVHt; - PI//(PI/+CN) - PI//(LxA) fig, 7-00"-.. of 8Y8I- ....-IM - 81-"'. r\ .~. . .' I' °i''''''' ~, .: . . '., ~.:~-- - .. -q, " . "...'. . .,."",«I_J__~ ~:.:_-\-¡~'~" .,;~" ",!,. I ~ ':. ~ - I~; ~I~'- i'"'' !~ ~ ;, ~ ---, -J/-~ ------------- ¡;':tN¡j~II,fjr ----~ --- ! jo ~ l'l""""" I ú,I'lJ-(J\¡¡(( ... fjA~ :' f. ....1 lll.'U ''''''l(''')''' .. .."'I . _. Í'I ~ .., ; I .. 1 (lI)c"I 3(11)(' .1)'.1(1 ,'('11)(1 ('()fIIFINI~ ~ T~f S~ r'~I( Fig B-ComparaU"t' porosities vs conllnlng slre!>s :JO ,';'l! --------- --~---_. --- '~ , -:"J E. " ' ~ L ..', 1~""C'Ai<úP()ROSlr. I ~ p, .~. ',',!11&1 &~iHÜ5'RE~~-?2~.,. ~ " . -,- /- <~..~.. j }AC.E;,;o &..,"! SATll~~~"-J ,- .. [ , ., C()lJlPAE~~ILlr't IIPfAHlfuS ¿; ., ~ ~. 0 ~ POkOSI r ~ ....... ...----. ~ ~ .. C.H[~t"cr &A~ """"'" t: '... "";:........ no -...--...;: I "üt< JACkfTED DR. I I ...., COA[ IN SISTEU .:..,-----: ~1 &- ;1.1. 0 :>000 3000 10(10 -000 10[1 C()ooF"""G SIRESS PSlG Fig. 10-Compara18ve XH'OIIUel VI. nel œnflnlng Itre... Jt~ HO . 1 . ì ------i--,-1- J ~.~, ~ JAC'{T(O ~",,,( J t! '. ~ \..""'::: SA"'HA'lO C(\H! '" J ..c. ,-'~ -'---C(II.tÞf4t~/A1Il,r. "F«'JI'~ ~ ,,' \~~~ i~ :i:' "":.":.":.":.-:':-.-:.J.~~ "~ j.o ---'- ---/-'~":7~'":.::'~.":'~¡~~'-"-' ".:'" JA,'II([, [iN. I ~-;;;.~~ ~,: (()Hi I~ S.~"lM C I j j j~ ~ (111(1 ],)0 ~ 1t)uÚ ,"'(II"r(. ).jljQ .I~rj(l ~.('O(' ~ ~ '" ('4 ~ i ~ ~O- ~ 16 ~~ i< ~ 12 ~ ~ ~ ~ ~oo~ kf , ll)NIIN'~': ~ 'wi. :~~ ~"'..""l. Fig 9-Compa.allvf' pO'f' vOlumes V5. net confIning st.t'IIS ~6 . . r., ~ 1«'" JAC>tlHd)"" I '!,' ./ I COA! OJ SYST[M , '¿~', ".... '" . ..........~ J 1 -~~-.;--_... ~ -..... I JA(;ICE1EO 811'''£ J SAtURAtED CORE OJ COMpqfSSI&ILln "P¡:A~AILrs j I 0 0 1000 ?ODO 3000 -000 ~ooo Fig. 11--Compar8t1ve pore volume comprPIIsfblllfle1 vs. nt't confinIng strell8. "[1 CONFI"''', ,>IR[~S P".,JG ¡POROSITY ADJUSTED I TO UNIAXIAL STRAIN ~ 1.0~~~_---~ ~:;;i I -V 0 I ~~ CD I I@ w_-.------- I ~~ ~ I W v c..~ PERMEABILlT'r ADJUSTEDI I ~:z: TO UNIAXIAL STRAIN I ~~ I ~~ ~~ I Doc I ~LL.. rRESERVOI~NOB I c.. ESTIMATED / I@ 00 NET OVERBURDEN PRESSURE . ~ ~ Fig. 12-Po~"y and permelblllly 8dultment fo unlutal sl.aln. )liRBORI~E'Ë' Arc: \.~.~I:'llrJT fJ':' .. ~,ErJ[lE~ S REI' rJ':' ~t=I: .:.a(:(.:'I~lfJT rJI:,1 AIRBORNE FREIGHT CORPORATlm~ P Co BO-", f.,6:' SE c. TTLE, \,,,,,t. 98'" ~I:':'C ':'IRS 'CIE":[I,[R c, REI' rJ':' QPrGu ,'. !,"d' II.. '. fJ.:. PRESS HARD A N C 3 4. 3 2 8 5 7 j 6. el/- L ': H L. HI':;~ .::, T .:" , t., i ~,' If n- ëE"I ER ,rJ.:,r.'E ..rJC' S1H¡;:E1 "DD~EÌ3:: I'IECEIVER "Jl.t.\E .:.rJ[' ;,TREP 1.[,[ RE'3::., .":"":'EC,.'::'.e~ ",.~r'[~E'" '-'''LES::' , II A ~ /' "THE"'."" "'.~' '~'~('I 'or ~ 1- . l'C,? 0/ L (VL~f1 j G (] ~<r,,-,~,, ' ~t,~,,~~~' '-'~C'~''''''T'. Ç( (, c' r:; ç::c,' /, ' / a.J"... 0 /IJ PI ~ /Ô F:" r /<J f'(\ 0 ø 0 CI~ '-' '-.; h CC ~TE '-°1:'" "~.1[:""'E':J,.~r:IT. ',~; ...11/'. '::,T':TE 'J..:L'Q"E:'r:~~''''E'' .i::,:r"',~"¿~t~,:~'~C~~"¡:¡T" 121 ' I !7 I '! I~ ,., IE ......... .. - , / /" J." " ./ v,. ." " -. r I I\. L..' ¡ I' C ( It ( e.... t , I .) ~ .'- r ~,- ¡-. --)C' (7 ~ CJ 7 ,C; ¿UI., e, Ir~~r¡1E DEpI I 1 Plj.prJ~ .. ,A TTtJ INIH..E QEPT I R f p~,~ - '" ~ ,"" I ' , ì , - , ...... , , , I' - I I ' . or-, I " ,1 -' ,.....! (. r !y<' -.V 1\/ '--/( /7\, ~ ~!..~ ._~'J '1/ \.; ~ r\~ \ r1'~'{ n¡ (1/ ;}J ~ 7 ---) 't~ - ¡~..:. ()\ THIPC' Pt.HT, BILL IrK, AD[I~ES:: PIECES DESCRIPTION OF PACK, AGES I CONTENTS WEIGHT ,LI;~" ';':'LLIE 0 DECURED VALUE F,:,R FULL IC C)G ,:..RRIt.GE 0 It~SUR¡:'~JC:E $ t',- HEI- t- 1_lrJ!:. 1.'tJL I I ,~I-'8JE':1 10 ITEt.,::. 6 "tiC' 7 (JtJ RE'/ER:,E, 5'[lEI / Lf<r If / xl/- / 'l~T :'}8.1E,': T T,:, IT IS ,oC.PEED AND UNDERSTOOD THAT THE LIA!;'LlT'r o~ AIRBORNE F~elc.HT C.ORPORATlON IS LI~ITrD TO THE VALUE SHOWN ABOVE, OR AS DEFINED II\! IT S GO~ERNIIIG TARII'"FS, WHICHEVER IS HIGHER 0 ~;;~~~t,~~D p,oC- 0 ~;~'~"'1~_~kF>U 0 ,~~:~~~~,E,;;~E~~ 0 ~':g'E1I': T.:.PE E~ 3 0ill ~ -:. 4"''v D"W'7 J ~ I í(. h plC~A~ SERI,'ICES PEC,UIR.::D J ':C,API;:C TI,:,rJ DIMEtJSIOrJS x x SENDER S COD $ .SUBJECT TO ITEM 15 orJ RE\oERSE SIDE, NON.NEGOTIABLE AIRBILL SUBJECT TO CONDITIONS ~ E,~~;-:~Ä, 0 t,~~'~~.~c:,' ~gp ~~~,~,L 0 ~g~~,~TI\~~BÛRNr SET FORTH ON REVERSE SIDE HEREOF N C ,") 4 3 2 8 5 7 3 6 J:ORWARDE 5 ~ATURE" ¡ROUTE ~.rj;cv~ I TIME" RrV'O NO Si--PTS ,PICKUP LOCATION .J ; £\Á ~ Þ /J;L r(", I,""'~él 0 ' ,'";.,"¿:' :I'~..-.=:~~: ~::,",::< rlGIN ,'''H8ILL NO X , VUJ" I .V ("'RL 0 0 SENDER'S COpy : . to""f c;. ~ '~Õ" t~s 21);:' 18'8JI ~;.::.'.. .~~~::;~:~i~l~~~<'::' :. ,.- , . :gÆ'::~0~Y~~~f~;}:~;:' !:<'::.. " ("~,;~;:.~. ~:'::"":':: ~~§.iii!ti~ii~:: --.-- . .... --.ø CORI: LABORATORUES, IHC. ',. I:rl:' TRANSMITTAL AND ACKNO\.1LEDGENENT OF RECEIPT Materials received vis TO: ~ «.co Die L ~ Crlt~ (D. . 1.30 c> úJ. P)IIfl/O fh~k\JJA~ ?}~N 0 Tt.- 750'15 MiN,' Jyqke Ri+fhn1e/1 ÚI'l-J 15'/- -b3g;J fJlÍ<. h oRAl e- ~'1 tvt ~h'D/JS P/2ese4'eJ) ~[) lee s /) 61) r-:S ,. dT1 kup I CRn¡~ 4D hnxes ..~.. 0.... ... ~.$e£- Ilf/-¡;¡e-h eJ sIJeef- loR Iv/! /;"';¡/e¡,J!tie.y! PLEASE RETURN ONE COpy Shipped by:J3il ~ for Core Lab/Date: ~-/~-K'¿' Rec~ived by: .. . ' : .<.. ":~:~;:~~~~f;';~~;~ 1s?--' .:; -'. . - ;' f - -', ... . .f'" ' . ...~ .,:~' . ',~. .,' ":..~ '/ '; :.- ' . ¡ , Company Afèq 0 ~~ell. J rc¡ IkvP .-S.on ten t 5 J.h: C ¡J f fr'ù'. y: If.. ¡Ie cP 5 Cc ./-/0 N S :: ,-,.:"':.~~~. :,:..r:..." ,.":"~: .". -. - ~ . ".' ,",- ;:~tß(~¥,f:{;:Þr~{~~;;;7(;~":\'.-. . :' . j,I~-..-;: ?: ....; ./..;- r ",' I ~ . INVENTORY COBF ., P..DX y- OEPTHS I / of . 3 ~~0S: 0 - _S 90 ~ 7 ---- - -- .------ -1- ----~-,ot- " fi9'1o 9,9 - 5 C¡1~ f ~- - - J of II - ~91i g - ~C¡'7~. <¡ I 1- Dr- II 59r¡ð.9 - 59..r 3.$ ~ . 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'1- bO 73,5 (,073,5 - ¿'o'1{,./r. bo ~.(, - /PD1r. 7 " /'I'" '? .-, ,.. COr.1pany: AR.eo \"'e 1] N 3r!1e : k R U -;:) Ie¡ Conccncs:' F;be~ ß'ASS tvb~5 4-" UJrLe.. ,1/ ~D cJ.; 'r bo '( e.s +- ¡Y1..xP '" f!'vY'f b COrtE .1 . .+vae. cox ~.~~~ .;~ t -; '..~~ff box~s. It, ~/phD"e.5 .'../. '"--':., ~"'.,,1!'~¡,,' .,JI '\' 'J :,;::, '. ~. ';.:.!~~.J - ' ,..~i:: -. : ~ '::~ ..";,\,,.,iltW'IlJOI.' (' ð¥'YJ fItII' C.ø ,¡,$:':':" . J.l.':". ;'¡¡'..',.;...r¡;,r'À,IIIJ..,'{, t..._," 3 ~.ï:~'~' '.~:. .. . . ~,,,, . :.:..... ..if~~. 'i-¡. ~~ ~ . . úEPTHS JoF.:2o . l("ItJiro /) - 4 oð'7 7 ~oi? 7 - f.DtJ9 ð.Y loó90.f-Io()9~¡ ~o'lJ.!- to09~ð foot¡1v" (,IDo. 0 t,¡oô.o - /a'tJ 3.0 (,1 ()3,ù- ¿, /°' .0 (,/O¿'.D - (PI () 9. :L ~ I () 't -:2 - /P II ;)..~ foll~.3 -1,,'15. ~ ~1/5,2 - (Pll K,~ . t, '10.:2 - 6 ';1./,3 . ¿;,1:l1. 3 - ¿ 1:2. 1/. 3 (P/:l'l3 -101 ;l~ f &,/,21 ¥ - 1,/30. S iJJ( Jo.5 - fnI3~.5 (QI3.~. S- - 6/30,7 "/3(, .7- b /39. i ¿,139.¡ -1ø/~:l3 1n112,f(-Io/lfs.3 :2 of I' , 3 of " 1- tf II 5 of II fp of II. - . 1 of J' g of- I' . , c¡ of 11 Jð of ,/ I' cF I' . I:i. of /' /3 of'' ' .f L/- of I' 15oFI' I ~ of I' J 7 of II I f of I' 19.f If .2lJ F:J. 0 ... . , .~ .' .. .-.. SECTION E Data Diskette Arco Alaska, Inc. Kuparuk #2T-9 North Slope, Alaska 1-0ct-86 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. , CONFID ,: TIAI.] INDEJ:ii ii ELY V~R~F!CATION LISTiNb LVP OiO.H02 = ~ ' o~GE 1 :',-'~ REEL HEADER SERVICE N~M5 ::DiT DATE :86/07/17 3RIGIN : REEL NAME :1~9318 CSNTINUATISN ~ :C1 PREVIOUS REEL CZMMENTS :LIBRARY TAPE ~-~: TAPE HEADER S~RViCE NAME :ESIT DATE :~6/07/17 C~iSiN :FS1A TAPE NAME ~ : CONTZNUATZON ~ :O! PR EViOUS ~T, APE : CONME. NTS :LIBRARY TAPE FiLE N~M~: :EDIT .001 : ~ 'E ~ ~ -I G. ~:- ~N.,A M E:,.: :~:.: VERSION ~ : MAXIMUM L~.NGTH ' 1024 PREVIOUS Fiche : :.'?~r.:~:: :~:<.: :~ ~. :.::~: : :~:: TGWN: lin COUN: NORTH SLOPE LVP glO.fl02 VERI~ICATION LISTING PAG5 Z :,: SCHLU~E ~ R G'2 R ~: ALASKA CDMPUTING CENTER .,. ....................................... .,..,..,..,..,..,..,..,..,..,..,..,. ;:: :;~ ::: ~;~ ;;: ;:: .,..,..,.., ..... , ............ . ....... . ....... , ....... ,. .,..,..,. .,. ... COMPANY = ARCO ALASKA INC NELL = 2T-9 FIELD = KUPA~UK COUNTY : ~',~3RTrfl SLJPE ~,2ROjGm STATE = ALASKA JOB NUMBER AT ACC: 71587 RUN =3 DATE LOGGED: 3-JUL-86 LOP: R. SINES - B I T S I Z E = 8.5" TO 63'T0' CASING = 10-75" 1994' TYPE FLUID = WTD. NATIVE gL.aY DENSITY =. 12-0 LB/G RM' = 2.69 :@ 62. DF 46.0 S R,'~,; = 2.14 @ 58 DF R,M,C = 3.0~ @6,Z-DF FLU'IS LJSS : 5.8 C3 RM ST BHT : 1.246 ~ 142 DF MATRIX SANuSTuN,: LVP 010.HOZ VE~IFiC~TIt3N LIST!N~3 ;aG~ 3 SCHLUMB~GER. L?~GS iNCLUD~2~ '~IT~ 7~I5 DUAL iNdUCTiON SPHSRICALLY FOCUSED LOG (OIL) ::: DAT~ AVAILABL~' ~'9' .. 6~ TO 3300.0' ~',~ L,JN$ SPACED S~NtC t&~:3 (LSS) -,- - DATA AVAILASLS. 6378 TO =:: ~]R'4~TION ~:NSTTy. . C~MPENS~T~D_ LOG (FDN) :;~ CuHPENSAT:D NEU,TR:ON LOG :;: 3~.TA AVA!'LABLE: ~389' TO 3300~0' ',''1~ '1' '~ 'z~ ~NTRY BLOCKS $ 4 73 60 . LVP 010 HO2 VERIFICATION LISTIN~ PAGE 4 DATUM SPECZFZC~TiDN ~L MNEM SERVICE SERVICE OEPT SFLU ~iL ILO 91L ILM 3IL SP OIL GR OIL SR LSS ~T LSS DTL LSS CALZ FDN GR FDN: NRAT FDN R HOB FDN N~H:i~ FDN 16 1 56 SCKS UNIT API API API LC$ TYPE CLAS FT O0 000 O0 CmMM O0 228 O1 OHMM O0 120 46 SHMM O0 120 44 MV O0 OlO O1 GAPI O0 310 gl GAPI O0 310 O! US/F O0 520 80 US/F 005-20 80 IN O0 250 O1 GAPI 0031:0 O0 420 O1 G,/C3~<iO0~ G/C3 O0 356 O1 PU O0 CmS AP1 S ~ 03 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 O0 330 31 0 FILE N O. 0 0 0 0 0 0 0 O~! 0 . 0 0 0 ~SiZ=. ~ SPL, REPR CODE 1 68 4 1 68 4 1 68 4 ! 68 4 1 68 4 I 68 4 1 68 4- 1 68 4 1 6B 4 1 4 1 PROCESS (OCTAL) 00000000000000 O00OO000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 30000000000000 6800000:000000000 68 00000000000000 t 68::0:0:.000000000000 1 65 00000000000000 I 6!8 O0000OO0000000 1 68 00000000000000 t 68 00000000000000 ...... DATA ...... 3.7444 ILM 2,1643 8. 5020 GR 118-8396 NRAT 3. 1682 DEPT 6300.0000 S~LU ~ · · ~.1077 I:LD 2 5706 !LM 2 6663 OiL 97.7773 CALl 8.072.3 GR 104,6523 NRAT 3.0042 DEPT 6200'.0000 SFLU 2.6897 ILO 2.06~7 ILM 2.0920 OTL LYP 010.N02 V~iPIC~TION L!3TING ~G5 5 DTL 94.0273 CALi FCNL 840.8125 NCNL o7.8353 GR ~8.7145 DT 8.7255 GR 87.8398 NRAT 0.0469 NP~i 30.48~8 OP~l 2449.5000 RNRA 2.9124 94.7773 2.7913 15.5782 OEPT 5900.0000 SFLU SP -49.3i95 GR DTL 92.2773 CALl ~HC~ 2.39Z8 DR~O FCNL 728.8125 NCNL 16.2080 ILD 3.7249 ILM 16C.4375 GR 163.1,375 DT 8.99~1 GR 160.4375 NRAT 0.0269 NPHI 25.9551 DPHi 2057.5000 RNRA 2.8206 4.0007 93.1523 2.7112 15.3762 DEPT 5800.0000 SFLU SP -56.5195 GR DTL 11:5.5273 CALI RHO8 2.2559 DRHO FCNL 504.1406 NCNL 3.5042 ILO 2.6057 ILM 158.1575 GR 153.0625 DT 9.1113 GR 158.1875 NRAT 0.0112 NPHi 40.4785 D~HI 1880-6875 RNRA 3-?288 2.7522 114.9023 3.4026 23.2910 DEPT 5700.0000 ,SFLU 6-5125 :ILD 2~:,713:1 ILM SP -62.1133 GR 355.6406 GR 255'6405 OT DTL 10~.0273~ CAL:I 8 <~:GR 3:85~:5~06 N~RAT RHOB 2.3~50 DRHO 0.0542 NPHi 38.6230 OPHI FCN.L 5 ; ~.:~< ~ 3 2 2.5706 105.9023 3--2756 18.0845 SP -84.5977 GR 105.2148 GR 104.214~ 9T 2HOB 2.4495 DRHO 0.0459 NPHI 32.3242 DPHI PC.NL~ 141.3125 12.1582 SP -34.4883 GR 109.7148 GR 109.3398 OT 99.4023 SP 102.4023 RHOB 2.3323 DRHO SP RHOB 114.7773 VERIFICATION LISTING PAGE 6 DTL 107.7773 CALl R~C~ 2.3069 DRH8 FCNL 505.6406 NCNL 133.3125 G~ 10.9395 GR 6.0i$1 NPdl 2038.6S75 RNRA 134.1~75 DT 109.0273 13~.3125 NRAT 3.5510 40.7227 DP~i 20.8008 4.0320 DSPT 5000.0000 SFLU SP -47.48~3 GR ~TL 98.5273 CALI FCN~ 730.3125 NCNL 3.5354 95.4023 10.1815 GR 0.0127 NP~i 2401.5000 RNR~ 3.5374 ILM 3.6936 9~.5273 DT 98.4023 9:8. 4023 NRAT 3. O1 O0 31.952~ DPHi 19.1406 3.2874 DEPT 4900.0000 SFLU SF -313.1094 G; DTL 109.5273 CALl q~2~ 2.3518 O2~ FCNL 523.3125 NCNL 3.5842 ILO 119.~39~ GR 1 · 0566 GR 0.0269 NPdi 5:- 68 75 RN RA 3.5608 ILM 3.5920 114.2773 DT 109.0273 11~.8398 NRAT 3.2717 35.5469 DP~i 19.0664 ~.8147 DE PT 4800.. OOO0 SFLU SP -134.4375 GR DTL 1t4, 0273 ~ CAL:I RHOE 2.3049 ORHi3 NC NL 3~ 8108 ILD 123. 5273 GR G. R 0.0234 NPHi 6675 :3-4866' !LM 3.4670 122.$39B DT 115.0273 IZ~.. 3 NRA T 3' 5413 ~0.47~5 DPHI 20.89~4 ~_ ?.5 '176.4375 GR 0.0068 NPHI i~.. :, 170.3125 3T 119.7773 >~5 40.2832 DPHI 23.4883 SP -8.6555 G:R 111.9648 GR 115.0273 RHOS 2.2952 DRHD 0.0146 NPHI 40.9668 DPHI 21.4844 SP -11.9980 GR '99.0273 GR 118.277B ~HD3 2.26'78 DR:HO LVP OlO.H02 VERIFICATION LISTIN~ °AGE 7 37 -i8.9639 Gq DTL 115.2773 CALi ~S~ 2.255i DRH5 ~CNL 502.1406 NCNL 105.2773 5R 57.4023 ~T 9.6738 GR 105.2773 NRAT 0.0044 NPHI ~1.06&5 ~r'PHi 1560.6875 RNRA 3.7053 DEOT 4100.0000 SFLU SP -21.97'95 GR DTL 115.7773 CALl qn~ 2.2795 DRmJ FCNL 477.3906 NCNL 2.0432 ILD 2.1233 ILM 111.6523 GR !21.6523 DT 9.9316 GR 111.6523 NRAT 0.0200 NPHi 42.~316 DPHi 1942.6875 RNRA 4-0671 OEPT 4000.0000 SFLU SP -25.9795 CTL 111.5273 CALl RHJ~ 2.2424 DRHO PCNL 539. BI25NCNL 2.6538 ILD 2.6487 ILM 120.7148 GR 118.2148 DT 9.4+316 GR 120'7148 NRAT -0.0073 N~HI 39.5996 DPHI 2151,5000 RNRA 3 rj E P T 39 O0 '0'000 SFLU SP -27.9951 GR DTL : _~, :,1:10.77.73 C. ALI RmOB 2.2952 DRH~ ,,,.i: F C NL 56i9~. 2.3479 ILD: : 2"6077: ILM 105.4648 GR 100.1523 BT G R. '._ '1,~0 5~ ~:;:4 6.4'8.NRA T 0. 0293 NPH! 37. 5000 OPHI 195 5 ~ :.: SP -28.7451 GR 39.5898 GR 84.7773 DT .~ 0.0063 NPHI 36.8164 ~', qH,~ 2.2229 DRHO ~ ~ -31.9883 GR 89.5273 GR 89.1523 DT 11~.7773 3.4807 23.7305 2.0881 11,5.0273 3.5764 22.4509 2.5217 112.0273 3.3811 24.7070 2.5276 111.0273 3.:2756 21.4844 111.2773 25.8789 112.2'773 SP RHS~ 2. ,2288 ORHO ,~.,~r: ::~:,~:::::::.:::.~:~::~:~:~ :,.: ::::: :: $ :,~:: ~::~:i~:~:,~:::~:~ ~:::::::~:::' :)~ :~:No~i:~:i~,~::$:::~ ~::~$:~:~ ~:~!~:i~,:4 ~: :,~.,: i!i ' i:~ i!~:~ : ~,:; :~:::~:~:: :L ~, : SP -46.4883 G~ 116.7773 RHOB 2.2288 DRHO SP RHOB 2. 1935 DRHS : ::: ::: :::. 5 ~:: 7::::~::::~ :9::~:: ~:::: ::::::?:: ::: :~ :::~i~:: :: :: ::::: A::::',:::::: :;: ::: ::: :~:::: :::,:: :::::: ::: :::::::::: :~:: :::~::::'~ ::,~ ~: : ::.::: :::: ::::: :::: : : : : : ::: : :: : ::: : : ::::: : : :::::::::::::::::::::::::::::::::::::::: : :: :: ::::: : ::::::~:: .:: ::,~:B::~::::?:: :::: :::~:::::: ::: :::: ::::: :::: ::::::::::::: :::::, ~::::~:::::::::: ::: ::: .:::, ::~:::::~::: ::::::: :.: :::¢::::::::. :: :~ ~ ~ : : :: : : :::::::::::::::::::::::::::::: LVP OlO.H02 VERI~iCATIDN LISTING P&GE 5 S? -56.2i83 GR DTL 118.5273 C~LI RnO8 2.1115 DRMO FCNL 450.8906 NCNL 90.~023 GR 11.5488 GR -0.0058 NPd. 1653.6875 RNRA ~:~:~ FIL= T~AILER FILE NAME :EDIT .001 S~RViCE N~ME : VERSION ~ : D~TE : MAXZMU~ LENGTH : 1024 FILE TYPE NEXT FILE N~ME : '~0.2773 ~0.4023 ~5.6543 3.6663 DT NR~T DP~I 119.0273 3.8381 32.6172 ~;~ TAPE TRAILER SERVICE:~ DATE :86/07/17 DR.iG!N ,:~ ~ REEL TRAILER ~: D~TE :86/07/17 REEL NAME :149318 DATE 186/06/25 ORIGIN I CONTINUATION ~ 101 COMMENTS :::LIS LIBRARY TAPE; ** TAPE HEADER Sf;R V ICD] NAME ;EDIT DATE ORIGIN': TAPE NAME ~1550 CONTINUATION ~ 10,1 PREVIOUS TAPE COMMENTS :LIS LIBRARY TAPE ********** EOF ********** ** FILE ~EADER ** FILE Nt~E IEOIT ,001 S~RVICE NAME VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECO~D6 ** MNE~ CONTENTS CN : ARCO ALASka Wl~ ! 2T-9 ~N : KUPARUK RANG: BE TOWN: l. lr~ SECT: 1 COUN: N. SLOPE STIT: AblSKA CTRY: USA ~NEM CONT~T$ ** COM~EMTS ** UNIT TYPE CATE SIZE CODE; 000 000 018 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 [,V'.P OIO,HO~ VE~IFICATI[tN [.,ISTING PAG~ 2 , SCHLUMBERGER , &bASKA COM. PUTING CENTER **************************************************************************************** COMPANY = ARCO .ALASKA IMC WELL = 2T-9 FIE[~D m ~UPA~UK COUNTY : NORTH SI,,OPE 80ROUGH' STAI E, = ALASKA ,JOB NU~[%R AT ,~CC: 71550 RUN #1 ~)ATE I,~OGC, h[; 22-JUN-86 [,,DP: ~,CK KRUW[~bL CASING TYPfJ FI,UID V I $ C [.] S I TY Fbl)ID bOSS MATRIX ShNDSTUNE 16.O" @ 1~.0' ' BIT SIZE = 13,5"' TO 20.10' &PO [,~ MUD 9,2 LBiG R~ ~ 4,81 g 58 DF' 10 S RMF :, 4,11 ~ 58 DF 9,5 R~C ],82 ~ 58 ~F 9,0 C3 RM AT SBT = 4,06 La 70 DF DVP 01.0,I-.~02 Vf~;~IFICATION bISTiNG PAGE ,$ * $CHb!:I~BERGER bOGS INCbUDFiD WITH T~I$ ~AGNETIC TAPgl * , * [)UAb INDUCTION ,SPHERIC~bb~ FOCUSED ~OG (OIls) * * D~TA ,~VAI:LABbE~ 2008' TO * L[)~iG 8PACED SONIC bOG (b$$) * [)ATA AVAILABLE: 1996' TO 11:0' * * FL]RNA'ZION D.EN$IiTY~CU~PENSATED LOG (FDN) * * OATA AVAiLABbE; 19,82' 110~ * , ******************************** ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ,ENTRY 2 1i 66 0 B 4 73 60 9 4 6~ ,liN' 16 1 66 0 1 ~6 0 LVP OIO.HO?. 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U '60,3633 Gk 2.1077 DRHO 55.3711 NCNL 145,3125 DT[, 1100 0000 SFLO 54:58~o GR 1,9532 DRHO 177.3125 DTL 32 3! 0 1783 144 15 44 1273 152 42 30 0 1,551 156 3 · .0 0,9 0,0 1.6 9,2 2 9 o g API API FI:bE $IZ~ CLASS MOD NO, O0 0 0 4 01 0 0 4 46 0 0 4 44 0 0 4 O! 0 0 4 O1 0 0 4 01 0 0 0 ° 0 4 Ol 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 31 0 0 4 30 0 0 4 O1 0 0 4 80 0 0 4 80 0 0 4 098 ILD 45.0117 02~, GR 100,9023 75 NRAT 4,6414 875 FCNL 328,3906 5OO 6680 ILO 38,2930 4580 ~R 31,4580 0303 NRAI 3.8752 6875 VCNL 424,1.~06 8125 1.660 !bO 19,2549 6367 GR 44,6367 0742 NRAI 4.4929 6875 FCNL 279,1406 5625 5117 IbD 55.6055 0674 GR 30.0074 0137 NRAT 4 0867 6875 FCNL 348:6406 0625 5PL REPR PROCESS CODE (OCTAL) 68 00000000000:O00 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 0000000o000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000~00000 68 O0000000 00000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 ! L, i~ 14,5879 C.Ab! 13,5020 RNRA 5,'0281 GR '999,2500 IbM 25,8018 CALI 5,!531 RNRA 5,028t GR 51,1367 Ih~ 36,605'5 CAI, I 11,3301 RNRA ,2039 OR 31,0049 Ib~. 17,7393 CAL, I 16,2705 RNRA 4,5632 GR 46,0117 IbM 54,6367 CALl 13,4395 RNRA 4,4500 GR 27,3018 bVP OlO,H02 VERIFICATIOI:~ GISTI, NG PAGE D~]PT .1600.0000 SP -52~6.133 G RHt)B ~ OOB1 DR }-iG 9492 N Nb DT 149,0625 DEPT SP R H o B NPHI SP R H 06 NPHI DEPi RHO~ OEPT SP RHOS NPHI OEPT SP NpHI SP NpHI DEPT NPHI DT DEP~ SP NPHI 15o0 0000 -51 3,320 5:8 3 I :107 7773 S F L U GR D F~ H U NCNb 1400 0000 SFbU -49 3945 1 7715 DRHC~ 59 1797 NCNb 8~ 7773 1300,0000 SFLU '51,6445 GR 1,9991 DRHO 56,6406 NCNb 76~527~ DTb 1200 0000 -49 7070 1 7960 57 5684 99 7'773 1100,0000 '95,3477 1,8135 60.0586 77.5273 !000 OuO0 . -03,8J20 1,7715 55.8594 120.5273 ~00.0000 51.6133 2 0159 47:]145 !01.o273 ~OO 0000 60:8320 1.7930 53.7598 76.5273 SFLU DRHO NCNb LTL SFLU ORHO NCNb OTb GR DRHO NCNb GR DRHU NCNb DTL S F b d DRHO NCN[, PT!., 39,418.0. 38 '3861 0,0303 2 6875 150,0625 23 6924 45 3555 0 0239 1 6875 105 '5273 NRAT FCNL I I,,O NRAT FCNG 430 3906 ILl) 25: 09:86 0,.02~59 NRAT 1315' 6875 FCNb 88,5273 4 0 1 .6406 IbD 3t , ;$643 GR 0,0498 NRAT 1451 '6875 FCNb 76,0273 142 875 40 ~930 0 0405 1457 6875 97 5273 873 8125 36 1680 0 0254 t272 6875 '17 0273 33 9805 51 2930 0 0449 1281 6875 129 5625 lbo NRAT FCNL 4~,~992 IbM 3 .: 867 CAbI 4,0085 RNRA 395,6406 GR 24,9580 lb~ 45,3555 CAbI 4 ' 6296 RNRb 45;56 88,4~ 25' 09 · CA5I 4,.7898 RNRA 252,,6875 296,3906 IGM 3t:.364,3 CAbi 4,5984 RNRA 28:8'6406 GR 53,9492 IbM 40'7930 CAbI 4,6453 RNRA 289'8906 GR '~1 .,9492 13,291.0' 3~: 0867 :8555 ,2080 5,7507 41.4180 72,0273 19,6455 5,2039 34' 29 ,~ 0 12~, 4648 15, 7080 ,028l 34,76,17 4~,8867 , ,4 ~ 93 15,0281 39 ;, 386"7 I[,,,D 2000,6875 IbM 133,8125 GR 36,1680 CALl 20,6455 NRAT 4,8640 R. NRA 5,2468 FCNL 24~,4575 GR 35,5117 35,9805 IbM 51.2930 CALl 4,4695 RNRA 268.890b GR GR NR~T FCNb 62,7305 47.6055 GR 0.0391 NRAI 1491.6875 FCNL 99,7773 213,6875 ILO 32,4805 GR 0.0596 NRAT 1252 6875 FCNL 75:7773 59 9~05 IbM 47' ,6055 CAhI 4,0046 RNRA 330,3906 GR 102,7148 32.4805 CALl 4 4382 RNRA 279:3906 GR 30,1768 14,3770 4,7664 44,2617 49.2b17 14,4160 4.5125 44,4i80 78,9648 17,5986 4,4~1.2 35,6680 [,'VP OIO,HO~ VERIFICATION LI~,~TI~tG PAGE 6 700 ',54 57 11:2 9551 2 '7 7 3 , DO00 SFI,,,U ,1,992 N .lC. N b ,27'73 P L 9EPT 40 SP -ll :gPHI 6 OT 7 0000 8477 801~ 9863 7773 DEPT SP ~00,0000 79,472'I RHOB 2 0~03 ~PHI 5413945 D'.r 10~,02'73 DEPT !00,0000 SP 48.2617 RHDb 1,4630 ~IPHi 64,2090 OT 17,004.9 DEPT 67 SP '999~ RH06 :~99 NPHI 99: DT 20, ~500 250~3 2500 6299 ** FILE TRAILER FILE N~E :EDIT SERVICE NA~E : VERSIU~ ~ SFLU qC~5 SFLU NCNb DTL S F L U NCNb OTb SFLU G~ DR[iD NCNb DTL S~-LLJ GR DRHO NCNb DT5 45 1.055 ILD 1426' 75 FCN:h 110,0273 '10~34,6875 I[.,D 617 ~a 0,0635 N'RAT 124'7,68'75 F(,. h 82,2773 102,7773 54',7617 Ga . 0,0137 NRAT 1458,6875 FCNh 98,777~ 873 8125 24 3955 0 0264 330 6875 77 0273 NRAT rCN L 73 5273 ILO 57:5430 GR 0,0146 NR,AT 1397.6875 FCNL 100,5273 4,1960 25,036.1 GR -0,5322 N~T 1~19,6875 FCNb 9,8770 -999 2500 -999 2500 -999 2500 -999 2500 8 1270 GR NRAT F C N h 413,:~00 Ih~ 3 · ~,17 CALl 4,2546 RNRA 258, ~906 GR 90,~7673 IbM 5~, 17 CAhI. 4,3'992 RNRA 331,1406 GR 298.6406 I'h~ 24,3:955 CALl 4,9773 RNRA 251.,6875 GR 45,2617 ILM 60,2930 'CA:bi 4,6765 RNRA 269,'3906 GR 30,4268 Ib~ 57,5430 CALl 4,3953 RNRA 302,6406 GR 2000,6~75 IbM 25,0361 CALl 4,9460 RNRA 251,0625 GR -099,2500 ibM -~99,2500 CAbI -999,2500 RNRA -999,2500 GR 39,9180 13,7'754 4,4187 56,6992 138,687~ 8:,8643 4,8289 :! 3 67 57 6:60 4 0 3 5,2 g 22,0205 43'661! ,8223 5,1648 57,1367 13,9941 14,5566 4,6179 56,0898 I , 9600 1660 15'8562 -999 2500 -999, 500 21,0361 bVP OlO,H02 VERIFICATION blSTIN(; PAGE DATE : ~AXIMUN LF. 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NATIV~ CbA¥ DE"N&:~'T¥ .=', ~2:':0 bB'/G' VISCOSITY PH = 8,5 FbUID bOSS = 5,8 C3 BIT SXZg, =, 8**5" TO 5370' RM AT OHT 2,69 P, 62 Dr 2,14 P 5~ Dr 3,04 % 6'2 DF !,246 ~ :~42 O:lr ~IATRI, X SANDSTONE. bVP OlO,H02 VERIFICATION blSTI~G PAGE THIS .DATA HAS NOT BE, E,N DgPTH $ IF~'ED - OVER6A~S FIf, bD PRINTS SCH6UMBERGER bOGS INCbUDED NITH THIS * DUAb 'INDUCT/ON SPHER.ICA65¥.FOCUSED 60G * D'ATAA. VAZ,6ABhEI 3400' TO 2666,5' * ~ONG ~PA,CED SONIC 6O'G (bBS) * DA~A AYA'{~ABhEI ' 3400 TO * FORMA~:ION DEN~iTY',COMP.EN6,A~ED bOG (FDN') * C'O~'PENSA~DNEU~RON bOG. (FDN,] * DATA AVA~,6AB~E~ ~400' ~0 2666~'5' **'.D,A~A I?OR'NA~ RECORD ** ENT. RY BbOCK$ 66 bVP, 010,H02 VERI'FI~ATION bI.$~ING PAGE 9 4 65 lb 6~ rl O0 ~:00020 O0 O}t. MM O0 2 01 OHMM: O0 i O~ 46 OH, MM i 44 GAPI~ O0 Ol US/F 00 80 ~$/r oD 52'0 o iN '0:1 OD PU O0 8~0 PU 00. ,8~0 O0 OOoooO ooo M N~, 0 0 Q 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o § o 0 0 0 DATA ** O~P'r rcNb 3400 112 507 ,.0000 GR 104. 5,2 CAb'I 10.~105 DRHO 0. 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R'NRA OTb RFIOB 3300 ,.,56 118 2 450 0000 2383 5273 90b SFbO 3,0432 GR 90.4023 CALl 11,5488 DRHO -0,'0088 NCNb 1653,6875 lbo NPHI RNRA SP RHOB FCNb 3200 -68 89 2 881 0000 4727 2773 2405 3125 SFLU 11 GR 66 CAbI 8 DRHO 0 NCNb 2795 8145 ILO 0898 GR 8145 GR 0,0:29 NPH! 5000 RNRA DEPI 3100 0000 SFbU ] SP -59:7383 GR 7 DIb 129,3125 CAb! 10 RHOB 2,0745 DRHO 0 rCNb 375.8906 NCNb 1628 ,'tin DEPT 3000.0000 SFbU $IZS 4 4 44 4 4 4 4 4 4 4 4. 4 4 REPR ,RO:CESS CODE 6SO00000:O0000000 68 00000000000000 6800:000000:::0:000:00 68 00000000000000 6800000~0000'0:0000 68 0000000~0~0000 68 O0:O0000 ~0 .:0'00'0 68 000000,0,0000000 00:0'00~'~: 0~00 ~ ~0~0:0 0 O0 18~ O~::OOiO0:O:O00, O:O 6800000000000000 68000:"00'000000'000 68,0000,0000000000 6~'00000000000000 68 00000000000000 ' 00,~ O00:0: 0" O0 o oooo, oooooooooo NRAT DP:H1 27,636 10.5176 59,3555 66.0898 30,,8105 3,.1702 IbM 11,2520 DT 88,7 DPHI 0 7 24,..8 4 GR 75,3398 DF 129.'5b'25 97 78,4023 NRAT 4,0828 NPHI 50,5171 DPHI 34,8633 ,6 5 RNRA 4,3328 5,5750 5.5125 Ib.D 4,9617 -63,2,383 GR 122;5273 CA:bi 2,t.877 D~HO DF, PT 2700..~0000 S,F[,U ,5:2? CALl RHO. B 2,1643 DRHO 533,8129 NUNh 85.4648 OR · 19:73 OR 1~.0308 NPHI 1.???,6875 R~R:A 89,,4648 OR 14,6.191 OR. 0,0391 ~PHI 159,3:,6875 RNRA, 8,.2207 I'hD ,2129 ,~0063 NP,H! 1.858,6575 RNRA 2135.5000 R~RA. 4.0164 ~D 70,2148 11,5645 GR, 0,0029 NPHI, 1767,.~875 RNRR: SERVICE NAME VERSION # DA?E.I MAXIMUM LENGTH : 1024 riLE TYPE 1. NEXT FIbE NAME : ** TAPE TRAILER ** SERVICE NAME :EDIT DATE :86/07/17 ORIGIN :FSIA TAPENAME CONTINUATION ~ :01 NEXT TAPE NAME COMRENTS :LIBRARY TAPE ** REEL TR. AIL~R SERVICE NAME :EDIT 91,6523 DPHZ 4,39:14 8!9,4648 N:RA:Z :.i:, 58 8 ~;.84~7 NR~T DPH.i ~0.,4 23, 7:.5, e:'~98: N:::R.'A:~ 42,5781 DPHZ 4,:000? 70,2.148 NRA 4,4.7754 DPHI 13, ,~ 9'91 123,0273 2 '8 ,..0273 · t2 29,:199'2 7,~9070 :121,'777'3 t2[,652~ -999;2500 3i'7871