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Home My WebLink About193-091'. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 14::~,.~'-. 0~ [ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs-of various kinds [] Other COMMENTS: viScanned by: Beverl ncent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMIISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well fl Rug Perforations r Perforate Other Set Patch Alter Casing r Pull Tubing fl Stimulate-Frac fl Waiver r Time Extension fl Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r _ 193-091 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22382-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 1Y-34 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool• 11.Present Well Condition Summary: Total Depth measured 9354 feet Plugs(measured) 8294 true vertical 6406 feet Junk(measured) none Effective Depth measured 9263 feet Packer(measured) 8275 true vertical 6344 feet (true vertical) 5557 Casing Length Size MD TVD Burst Collapse CONDUCTOR 38 16 80 80 SURFACE 6248 9.625 6289 4349 PRODUCTION 8605 7 8644 5824 LINER 1011 5 9354 6406 RECEIVED OCT 2 4 2013 AOGC 1 Perforation depth: Measured depth: 9010'-9018', 9030'-9056' } 1 'i` ^' True Vertical Depth: 6113'-6119',6129'-6150' SHE Tubing(size,grade,MD,and TVD) 4"x 3.5",J-55, 8642 MD, 5823 TVD Packers&SSSV(type,MD,and TVD) PACKER-CAMCO HRP-1-SP RETRIEVABLE PACKER @ 8275 MD and 5557 ND SSSV-OTIS SSSV @ 1778 MD and 1652 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze for this operation 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 fl Development 17- Service r Stratigraphic 16.Well Status after work: Oil . Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WIND 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: none Contact John Peirce @ 265-6471 Email John.W.PeirceCa�conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date - , N. 1/7-g 1°17-14 l3 l00 RBDMS OCT 2 J), �G� Form 10-404 Revised 10/2012 Submit Original Only 1 t KUP PROD • 1Y-34 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB( crnr6c' 1vtlrp 500292238200 KUPARUK RIVER UNIT PROD 55.15 2,415.58 9,354.0 ..° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date I 15-34,10/22/2013 1 2:46:33 PM SSSV:TRDP 1 100 8/14/2012 Last WO: 7/13/1993 Verbal schematic(actual Annotation Depth(ftKB) End Date Annotation (Lest Mod By End Date ,,,,,., Last Tag:SLM 9,117.0 6/5/2013 Rev Reason:SET PATCH Ihipshkf 10/21/2013 HANGER;37.6- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.0621 42.0 80.0 80.0 62.50 H-40 WELDED l ki :.. r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 41.6 6,289.4 4,349.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • PRODUCTION 7 6.276 38.9 8,643.6 5,824.4 26.00 L-80 BTC-MOD .AAA.CONDUCTOR;420-80.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 5 4.276 8,342.9 9,354.0 6.4007 18.00 1.-80 LTC Liner Details SAFETY VLV;1,778.3 fit N Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn tin) 8,342.9 5,603.9 45.86 HANGER BAKER HYFLO II HANGER w/C-2 SETTING 4.276 SLEEVE Tubing Strings Tubing Description String Ma... Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 433.5 1 ID(in)41 3.4761 37.6 8,642.6 5.823.61 11.001 J-55 DSS-HTC GAS LIFT;3,297.2 Il j Completion Details Nominal ID Top(ftKB( Top(TVD)(ftKB) Top Inc!C) Item Des Com (in) 37.6 37.6 0.02 HANGER FMC GEN IV 5M TUBING HANGER 4.000 IT 1,778.3 1,652.1 44.31 SAFETY VLV OTIS 4"SERIES 10 SELF EQUALIZING SAFETY VALVE 3.313 GAS LIFT;5,193.7 5,183.3 3,674.3 53.08 XO Reducing CROSSOVER 4 x 3.5 3.500 8,253.6 5,542.2 46.64 NIPPLE CAMCO W-1 LANDING NIPPLE 2.812 8,262.0 5,547.9 46.57 PBR CAMCO PBR 2.937 8,275.4 5,557.1 46.45 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 • 8,294.0 5,5700 46.29 NIPPLE CAMCO D NIPPLE w/NIPPLE REDUCER,PLUG SET IN 2.750 NIPPLE REDUCER GAS LIFT;5,973.9 8,641.6 5,8220 4027 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 8636'during 3.000 SBHP on 1/14/2003 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND( Top Intl Top(ftKB) (ftKB) (°) Des Com Run Data ID(in) 8,214.3 5,515.2 47.03 PATCH OWENS PERMANENT PATCH,OAL=20'(8214- 10/16/2013 2.230 • 8234) SURFACE;41.641,289.4-.• : l 8,294.0 5,570.0 46.29 PLUG 1.81"CA-2 PLUG 9/17/2013 0.000 a 8,294.0 5,570.0 4629 NIPPLE NIPPLE REDUCER SET IN D NIPPLE 9/17/2013 1.810 GAS LIFT;8,745.0 it REDUCER Perforations&Slots Shot Den Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT:7.552.3 9,010.0 9,018.0 6,112.7 6,119.2 A-5,1Y-34 7/27/2010 6.0 APERF 2.5"Mil(enium HMX,60 deg phase - 9,030.0 9,036.0 6,129.0 6,133.9 A-4,1Y-34 9/7/1993 4.0 IPERF 33/8"SWS HSD _ Guns;180 deg.phasing; Oriented 150 deg.CCW F/High Side GAS LIFT;8,2091 9,036.0 9,056.0 6,133.9 6,150.3 A-4,1Y-34 9/7/1993 4.0 IPERF 33/8"SWS HSD Guns; 180 deg.phasing; s s Oriented 155 deg.F/ PATCH;8,214.3 High Side L x. Mandrel Inserts St c NIPPLE;8,253.6 ary No Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (11K8) Make Model OD(in) Sery Type Type (in) (psi) Run Date in PBR 8,262.0 l 1 3,297.2 2,550.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/18/2013 PACKER;8,275.4 '-''' 2 5,193.7 3,680.5 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/27/1994 3 5,973.9 4,155.5 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/17/2013 NIPPLE REDUCER;8,2940 4 6,745.0 4,623.4 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/3/1993 PLUG;8,294.0.1 r IJ NIPPLE;8,294.0 Y'r', 5 7,552.3 5,102.3 MACCO SPM-2 11/2 GAS LIFT DMY RK 0.000 0.0 9/7/1993 6 8,204.1 5,508.3 MACCO SPM-2 1 1/2 GAS LIFT DMY RK, 0.250 0.0 8/1/2013 WIP Notes:General&Safety '1 f End Date Annotation 10/29/2010 NOTE:View Schematic w/Alaska Schematic9.0 SOS;8,641.6 PRODUCTION;38.9-8,643.6 APERF;9,010.0-9,018.0 J IPERF;9,030.0-9,036.0 IPERF;9,036.0-9,056.0 LINER;8,342.9-9,354.0 • 1Y-34 Well Work Summary Ask DATE SUMMARY 9/16/2013 GAUGED TBG TO 2.78". B & F TBG& D NIPPLE @ 8294' RKB. IN PROGRESS. 9/17/2013 SET 2.75"X 1.81" NIPPLE REDUCER @ 8294' RKB; SET 1.81"CA-2 PLUG @ 8294' RKB; SET 2.85"CATCHER @ 8253' RKB; PULL GLV&SET DV @ 5975' RKB; ATTEMPT COMBO MIT-IA (FAIL). JOB IN PROGRESS 9/18/2013 PULL GLV& REPLACE WITH DV @ 3297' RKB; COMBO MIT-IA(PASS). IN PROGRESS 9/19/2013 PULL CATCHER @ 8253' RKB; (1.81"CA-2 PLUG IN NIPPLE REDUCER) READY FOR PATCH. 10/16/2013 SET PATCH FROM 8214.3'TO 8234.3'. CCL TO TOP OF PATCH : 10.3'. CCL STOP DEPTH : 8204'. LOG CORRELATED TO LEAK DETECT LOG DATED 4-AUG-2013. LRS UNABLE TO PERFORM MITT OR MITIA DUE TO T X IA COMMUNICATION. DID GET PASSING CMIT. SEE ATTACHED REPORT. JOB COMPLETE. STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~ Repair w ell ~ Plug Perforations ~ Stimulate Other Alter Casing ~,' Pull Tubing ~ Perforate New Pool Waiver ~' Time Extension Change Approved Rogram ~ Operat. Shutdow n ~ Perforate Re-enter Suspended Well . 2. Operator Name: 4. Current Well Status: \5. Permit to Drill Number: \ ConocoPhillips Alaska, Inc. Development Exploratory ~' 193-091 3. Address: Stratigraphic Service ~ 6. API Number: ~ P. O. Box 100360, Anchora e, Alaska 99510 • 50-029-22382-00 7. Property Designation: 8. Well Name and Nurryber: ADL 25647 \ 1 Y-34 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9354 feet Plugs (measured) None true vertical 6406 feet Junk (measured) None Effective Depth measured 9263' feet Packer (measured) 8275 true vertical 6344 feet (true verucal) 5557 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 6243 9.625 6289 4347 PRODUCTION 8604 7 8633 5849 LINER 1011 5 9354 6406 ~~'' ~` ~ / ~~ Zf a ° I i. ~ i~~ t 1. .' Perforation depth: Measured depth: 9010'-9018', 9030'-9056' 1 True Vertical Depth: 610 4'-6111', 6122'-6144' ~,~~~~(8 t~ ~ ~',5~ ~. ~*~~~$~0i~ ~,~r6iJfaQE? Tubing (size, grade, MD, and TVD) 4, 3.5, J-55, L-80, 5183', 8642' MD, 5823 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO'HRP-1-SP' PACKER @ 8275 MD and 5557 TVD Otis Series 10 - OTIS SERIES 10 @ 1778 MD and 1652 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: ~' ` '~ ' ~=I l.a ~ :~ ~ i i ~ E 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 70 625 61 -- 163 Subsequent to operation 132 1251 53 -- 165 13. Attachments 14. Well Class after ro osed work: P Co ies of Lo sand Surve s run P~ 9 Y ~° De to men ~ Service ! E lorato ~ rY P 15. Well Status after work: Oil ~ Gas [ WDSPL Daily Report of Well Operations XXX GSTOR WAG ~ GASINJ r WINJ SPLUG 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. 6cempt: none Contact John Peirce ar7.263-6471 Printed Name John Peirce Title Wells Engineer J Phone: 263-6471 Date S / I ! ~ Signature ~Q ~ *~ t .- Il RBDAAS AUG 122010 `~ 9 f~ ~'-/z ~~ Form 10-404 Revised 7/2009 // / ~_ yrbmit Original Only 1Y-34 Well Events Summary DATE SUMMARY 7/20,10 DRIFTED TBG WITH 7' 5" x 2.70" MY; TAGGED @ 9148' SLM. READY F E/L. 7/27/10 PERFORATED AT A DEPTH OF 9010'-9018' USING A 2.5" X 8' GUN, WITH 6 SPF, 60 DEG PHASING, DEEP PENETRATING MILLENIUM CHARGES. LOG WAS CORRELATED TO SCHLUMBERGER CBL DATED 9/6/1993. - Conc~+~oPhiliip~s A~:iskt. fnr.;. CONDUCTOR, 80 SAFETY VLV, 1.178 GAS LIFT, 3.297 GAS LIFT, 5.194 GAS LIFT, 5.5]4 SURFACE, 6.285 GAS LIFT. 6.745 GAS LIFT, 7.552 GAS LIFT, 8.204 NIPPLE, 8.254 PBR. 8.262 ?ACKER, 8.275 NIPPLE. 6,294 PRODUCTION. 8.633 SOS, 8.642 TTL. 8.643 APERF, 9,0109,018 IPERF. 9.030-9.03fi IPERF, 9.036-9.056 LINER. 9,354 TD, 9,354 KUP ,S __ Field Name 1KUPARUK RIVER UN H2S (ppm( l 100 _ -- I. lepth (ftK6( Entl Date 9,148.0 7/20/2010 I 4 4,155.9 53.00 GAS LIFT 4,623.41 54.30 GAS LIFT 5,102.0', 52.65 GAS LIFT 5,508.3 ~~, 47.21 GAS LIFT 1 Y-34 Mod ey ;End Date 41.0 46.0 6,. 29.0 8, 43.0 9, Set Di <g) (ftK 0.0 5, 788/1280/ Comment STA 1 Y/RK/U Comment: STA 2 J/RKL25I1261/ CommentSTA 8,262 5,549.9 4283 PBR Camco PBR 9!7/1993 2937 _ 8,275 - 5,558.41 47.54 PACKER __._ _ __._. Camco'HRP-I-SP' PACKER _. - -1 9!7/1993 I _ ___ . 2.937 8,294 5,570.8 47 12 NIPPLE Camco'D' Nipple NO GO 9/7/1993 ~ 2.750 8,642 5,854.5 45.57 SOS Baker SHEAROUT SUB 9!7/1993 2.992 ~i 8,643 5,855.1 45.54 TTL ELMD TTL @ 8636' during SBHP on 1/142003 9/7/1993 2.992 ' ___-_ i Perforat ions 8 Slots -- ~ ' snot ' rep ~rvD( Btm (rvDl Dens Top (ftK6) Blm (ftK8) (ftK6) (ftK6) Zone Data (sh,,. Type Comment 9,010 9,018 6,104.1 6,111.1 A-5, 1Y-34 7/27/2010 6.0 APERF 2S" Millenium HMX, 60 deg phase 9,030 9,036 6,121.7 6,126.9 A-0, 1Y-34 9(7/1993 4.0 IPERF 3 318"SWS HSD Guns;180 deg. phasing; Oriented 150 deg. CCW F! High Sitle 9,036 9,056 6,726.9 6,144.4 A-0, 1Y-34 9/7/1993 4.0 IPERF 3 3/8"SWS HSD Guns; 180 deg. phasing; Oriented 155 deg. F/ High _... Side _ __.__.. -. _ _-_. I • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~y~ggy~ pFn~, :~ ..~ Dear Mr. Maunder: • ~' 19~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20~' -Sept 1 lth, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 C-178 203-041 8' 1.50 8" 9/11 /2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24!2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 ~. ^~ n ` MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: FROM: John Crisp, SUBJECT: Petroleum Inspector May 17-18, 2001 Safety Valve Tests Kuparuk River Unit 1Y Pad May 17 & 18. 2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test. The AOGCC test report is attached for reference. I conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape w/no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems w/VSM's shifting up & I wanted to make sure KRU Rep's were aware of this problem. SUMMA,R.Y,: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. ,.Attac._hmen~: SVS KRU 1Y 5-17 & 18-01jc CC; NON-CON .F!DENTIA. L SVS KRU 1Y 5-17 & 18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kupan~ River Unit 1Y Pad Separator psi: LPS 85 HPS Well Pemit Separ Set L~ Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCL~ 1Y-01 1830500 1Y-02 1830590 1Y-03 1830610 3750 2~6 1800 P P WAG' , 1Y-04 1830660 1Y-05 1830870 , 1Y-06A 1971340 85 70 55 P P OIL , , , 1Y-07 1830680~ 1Y-08 1830620 ~ , 1Y-09 1830520 1Y-10 1830510 37~0 ' 2000 '1750 P P WAG 1Y-11 1830410 1Y-12 1830260 , , 1Y-13 1830150 1Y-14 1830230 1Y-15A 1981860 85 70 50 P P OIL 1Y-16 1830420 1 Y- 17 1930680 85 60 60 P P OIL , 1 Y- 18 1931060 1 Y- 19 1931070 85 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL 1Y-22 19307~ 85 60 55 P P OIL , 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL 1y-24 1930720 85 70 78 P P OIL 1 Y-25 1880890 , 1Y-26A 1881160 85 70 50 P P OIL 1Y-27 1930880 85 70 ~ P e OIL 1 Y-28 1930890 , 1 Y-29 1880910 85 70 60 P P OIL . 1Y-30 1880900 85 70 701 P P OIL 1Y-31 1930900 1 Y-32 1880930 85 70 70' P P OIL t~3~://~ ~:)' '~: q 930910 85 70 65 P P OIL Wells: 16 Components: 32 Failures: 1 Failure Rate: 3. ~ 3% [3 90 my · i i i i ii Well Pemit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ., RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18-01jc THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL E M_~A T E IA L U N D TH IS M ARK ER C:LORJ~MFILM. DOC W E R ',"}iS .... 09 I 5853 :2) .., ... . :.~ .... 091 DAiL. Y WELL OF' 93 -~ 09 i S URVE V 93 .w 091 C:BT 93 ---O 9 i 93--09 i 93 ..... 09 'i 9~-~._, '-~ 09 i 93 .... 09 I 93 -- 09 i 93 ..... 09 i 9x) .... 001 q '~ -- 091 ~?, 356 -921}8 (; E'. N '"' !... W .tS; / D C '~'"I ...... 6 o 50 .... o,.; 6 4 0 CDR ....E/LWD/'DC p--'E 7200,--8600 CDR ....LWD/D,:2 I/'% 625C) ......88a. C) · ','?El' L 7300-'~,5313 C E '-F C...L-~- 7 ~ C A S I N G ,:-; E 'T' ~ 8356 -,' 92612 CYB DZL/SFL./GR ~... 8635--,9340 D Z L / S F !....:/(.~ R L~. 8635,,-93 ~,~ 0 !.,.DT NEi...I'T'RON-,,PORO/~_.. 8635---g3 i6 !...DT NE!JTRON'-RAW ~ 8635'-93 i 6 A We 'l i d r"y t he we 'i 'i C C:, H H E N T S ARCO Alaska. !nc. Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 5, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~?:- .~;/1B-12 Other (SSSV) .~L 1 B-1 2 Perforate \1B~12 Stimulate ?>.-:~ 1F-02 Stimulate ~l..-bt,, 1 L-24 Perforate cFs_~ 1Y-23 Stimulate q~-~l 1 Y-34 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAbr, A OIL AND GAS CONSERVATION COMMISL,,..,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing 2. Name of Operator ARCO Alaska. In~;. 3. Address Stimulate X Plugging~ Perforate Repair well Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service __ 4. Location of well at surface 570' FNL, 1822' FWL, Sec 1, T11N, R9E, UM At top of productive interval 124' FNL, 102' FWL, Sec 7, T11N, R10E, UM At effective depth 388' FNL, 372' FWL, Sec 7, T11N, R10E, UM At total depth 428' FNL, 292' FWL, Sec 7, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 9354 feet true vertical 6405 feet 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-84 9. Permit number/approval number 93-91 10. APl number 50-029-22382 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 9 2 6 3 feet true vertical 6344 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 121' 16" 6243' 9.625" 8591 ' 7" 9308' 5" measured 9030'-9056' true vertical 6150'-6196' 225 Sx PFC 1 21 ' 1 21 ' 985SxPFECmt& 6289' 4350' 890 Sx Class G Cmt 200 Sx G Cmt & 8633' 5860' 175 Sx Class G Cmt 9354' 6405' RECEIV j p,,F -- 5 19' Tubing (size, grade, and measured depth) 4", 11#, J-55 @ 5183' & 3.5", 9.3#, J-55 @ 8306' & 3.5", 9.2#, L-80 @ 8642 Packers and SSSV (type and measured depth) Anchorage PKR: Camco HRP-4-SP Retr PKR @ 8275'; SSSV: Otis 4" Series 10 Self Equalizing @ 1778' 13. Stimulation or cement squeeze summary Fractured "A4/A5" Sand on 11/10/93. Intervals treated (measured) 9030'-9056' Treatment description including volumes used and final pressure 14. Pumped 193 Mlbs of 16/20 & 12/18 ceramic proppant into formation, fp was 4490 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 3 71 1 2571 200 1300 180 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereb~certify that the foregoing is true and correct to the best of my knowledge. Signed "'~~((~,' (/~~" Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE D ommis,, KUPARUK WELL: I SERVICE CO: HOLE ANGLE @ PERFS: PERFORATED INTERVAL: STIMULATION SUMMARY DATE: ARCO REPS: AFL ~: DENSITY ORIENTATION COMMENT'S/OTHER FRICTION CORRELATIONS: (PSI/FT vs. BPM) RATE. XLGW GW SLK WTR SLK DSL TVDTOP PERF: C / $ ~' MD TOP PERF: 7 o: O MDTBGTAJL: ~',s MD TBG ~ER: c// FORMATION FRAC GRADIENT: FRAC FLUID GRADIENT: PRE-TREATMENT (~ALQI, ILATIONS -},~:/ -:/3 d,70 ~3~ O,: 2-5 ? ~ ~,' ;-;.- j .... EXPECTED TREATING PRESSURE = (FORM F~AC GRAD X ~D TOP PERF) + (TBG FRIC X MD TBG TAIL) - (~UID G~D X ~D TOP PER~ = FLUSH VOLUME = (MD TBG TAIL - MD TBG HGR) X (~G BBLS/F~ + (MD TOP PERF- MD TBG TAIL) PRESSURE ANALYSIS ACTUAL FRAC GRADIENT = ISIP / 'I-VD TOP PERF + FRAC FLUID GRADIENT ~155 EXCESS FRICTION = FVVHTP-ISIP- (TBGFRIC X MD -I-BG TAIL) , STEP .VOLUME RATE FWHTP ISIP FG X$ FRI(;; dAN ---5 i97}/+ ~, x,s :~ utt& Oas Cons. Commission Ancl]orag~ (;:;LOSURE PRESS EFF. -7., :- d.-'.,:'~ / /(cz.f:, /,7 EFFECTIVE PAD: 12_0 ./?z7 ,7~$ 2- zZ TREATMENT ~I, IMMARY ~FFECTIVE SLURRY: ? ~-i PAD/SLURRY RATIO: PROP PUMPED: 16/20 /2]'zYJ012/18 2.1~'~ .¢ 10/14 PPA @ PERFS: 1 ¢, ~ PROP IN WELLBORE: I ' SEA WATER USED: / ~ 5~', ~ DIESEL USED: TOT~. 224. / PROP IN FORMATION: ADDITIVES USED: NOTES' ARCO Alaska, Inc. Date: November 19, 1993 RETURN TO:~ Transmittal #' 8932 Transmitted here with are the following items, Please acknowledge receipt and return one signed copy of this transmittal. · 1 R-18 LIS Tape and Listing: 11-09-93 93491 Field Tape Copy of CDR Data 2M-12 LIS Tape and Listing: 11-09-93 93507 HLDT Depth Shift-3 passes and Lat Avg. 2M-32 LIS Tape and Listing: 11-11-93 93505 HLDT Depth Shift-5 passes and Lat Avg. 2M-04 LIS Tape and Listing: 11-12-93 93508 HLDT Depth Shift-3 passes and Lat Avg. 2M-08 LIS Tape and Listing: 11-12-93 93506 · i..,..~.. ' · HLDT Depth Shift-3 passes and Lat Avg. ~ ,---r f' 2M-08 ,) -.~-LIS Tape and Listing: 8-12-93' ' 93301 / t.~'.:~,,.-~.~'~.,.____._.~'.,, ~_ , DITE/LDT/CNTG/LDWG Format' ._ Receipt Acknowledged: //--~.,~L.~~ /Oo.~-~ Date: DISTRIBUTION: .,¢?~o' ,..,..:,/,~,.,:~_¢~,.~_, ,,.,,,.. ,, .o, nas Stat, o, '"~"o b .'br- ARCO Alaska, Inc. Date: November 19, 1993 Transmittal #: 8932 RETURN TO: .. ARCO Alaska, lnC, Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 ,;.-' P.O. Box 10036(:}::' Anchorage, AK 99510-0360 Transmitted here' with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '8 : - - 09:- 9 ~--~3-491---~ .~ui '~r'~ V --F~e-GoPY-°£~R-Dat~- 2M-12 c~ LIS Tape and Li~ing: 11-09-93 93507 · 5~ HLDT Depth Shift-3 passes and Lat Avg. 2M-32 cH LIS Tape and Listing: !1-11-93 93505 ~ ~ ~HLDT Depth Shift-5 passes and ~t Avg. c~ LIS Tape and Listing: 11-12-93 93508 ~~ HLDT Depth Shift-3 passes and Lat Avg. c~ LIS Tape and Listing: 11-12-93 93506 ~SHLDT Depth Shiff-3. passes and Lat Avg. ~ LIS Tape and Listing: 8-12-93 93301 DIT~DT/CNT~ LDWG Format 2M-04 2M-08 2M-08 Receipt Acknowledged: DISTRIBUTION' Bob Ocanas / Date' INDIVIDUA] ELL GEOLOGICAL INVENTORY ~PORT PERMIT DATA DETAIL 93-091 CBT 93-091 CBT 93-091 93-091 93-091 93-091 CDN-LWD/DC CDR-E/LWD/DC CDR-LWD/DC CET 93-091 CET 93-091 CET 93-091 CET 93-091 CYB 93-091 93-091 93-091 DIL/SFL/GR DIL/SFL/GR LDT NEUTRON-PORO 93-091 LDT NEUTRON-RAW 93-091 407 93-091 DAILY WELL OP 93-091 SURVEY 93-091 5853 5",8356-9238 7300-8290 2&5",6250-8640 5",7200-8600 2&5",6250-8640 5",8356-9262 7" CASING SECTION 7300-8290 7300-8313 8635-9316 8635-9340, 2" 8635-9340, 5" 8635-9316 8635-9316 COMP DATE: 9/09/93 6/29/93 TO 9/09/93 121.00-9354.00 OH-CDR/CDN,6289-8640 11/18/1993 PAGE: 1 INDIVIDUAl 'ELL GEOLOGICAL INVENTORY ~PORT PERMIT DATA DETAIL 11/18/1993 PAGE: 1 SUMMARY Are well tests required? Was well cored? Yes No Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No WELL IS IN COMPLIANCE. INITIAL Yes No COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well .:: OIL E~] GAS ~] SUSPENDED [] ABANDONED [~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-91/93-245 SA 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22382 4 Location of well at surface .... - ..... ,. 9 Unit or Lease Name 570' FNL, 1822' FWL, SEC 1, T 11 N, R 9E, UM -'. .,' ~11014S KUPARUK RIVER At Top P reducing Interval --~/~~ i ' i~~.~ 10 Well Number 124' FNL, 102' FWL, SEC 7, T 11N, R 10E, UM i ~."i¢~;:~iT] .~ 1Y-34 428' FNL, 292' FWL, SEC 7, T 11N, R 10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER UNIT RKB 106', PAD 65' GL ADL 25647 ALK 465 .12 Date Spu0ded .13 Date T.D. Reached .14 Date Comp., Susp. or Aband. ~ ,~ t 5 Water Depth, if offshore 116 No. of Completions 28-0 -93 09- 1-93 . 3(couP> feetMSL,I 1 t7 Total Depth (MD+TVD) '18 Plu~ Back Depth (MD+'I-VD) tO Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 9354' MD, 6405' -I'VD 9263' MD, 6344' TVD YES IXI MWD NO ~ I 1778' feet MDI 1500' APPROX 22 Type Electdc or Other Logs Run CDN, DIFI_/SFI_/GFI, LDN, CYBER[_OOK, CE'I-, CBT 23 CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE W-I- GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 225 PFC 9.625" 36# J-55 SURF 6289' 12.25" 985 SX PF E CMT, 890 SX CLASS G CMT 7" 26# J-55 SURF 8633' 8.5" 200 SX G CMT 5" 18# L-80 8343' 9354' 6.125" 1175 SX CLASS G CMT 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) 4"/3.5" 9.3# J-55/L-80 8643' 8275' SWS 3-3/8" HSD MOD GUN @ 4 SPF 9030'-9056' MD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. OCT 2 7 AJaska 0ii & Gas Cons. L;o.m_~'tsSi¢ Form 10-407 Submit in duplicate Rev. 7-1 ~80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 8725' 5887' ~ ~'.~.¥~:, '. . 31. LIST OF A-FrACHMENTS REPORT OF OPERATIONS, 2 COPIES OF MWD SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~ ,~,_~/~ ~/_~~-~. Title ~. ~,,~ 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-34 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25647 ALK 465 50-029-22382 93-91 ACCEPT: 06/28/93 01:00 SPUD: 06/28/93 04:00 RELEASE: 09/08/93 13:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 06/29/93 (1) PARKER 245 TD: 2942' (2942) 06/30/93 (2) PARKER 245 TD: 4165' (1223) 07/01/93 (3) PARKER 245 TD: 5880' (1715) 07/02/93 (4) PARKER 245 TD: 6310'( 430) DRILLING 16"@ 121' MW:10.0 VIS: 50 MOVE RIG F/1Y-24 TO 1Y-34. NU 20" DIVERTER. 41.44' STARTING HEAD TO ROTARY. FUNCTION TEST DIVERTER & VOLUME TEST KOOMEY. TEST WITNESSED BY DOUG AMOS W/AOGCC. FILL STACK & CHECK FOR LEAKS. PU BHA. TAG @ 58'. CO CONDUCTOR F/58'-121'. SPUD @ 1600 HRS 06/28/93. DRLG 12.25" HOLE F/121'-156'. POH, PU MWD, STAB, & ORIENT TOOLS-RIH. DRLG 12.25" HOLE F/156'-2942'. (KOP 282'). ADT 10 HRS. STAGING IN HOLE 16"@ 121' MW:10.1 VIS: 44 DRILL F/2972'-4163'. MOTOR LOCKING UP. CBU. POOH. TIGHT F/2380'-1664'. SWABBING F/2380'-1400'. LD NAVI-DRILL & BIT. CUT & SLIP 110' DRILL LINE. RESET & TEST DUO-MATIC. MU NEW BIT, NAVI-DRILL, ORIENT, & TIH. HIT BRIDGE @ 1670' REAM TIGHT SPOTS 1670', 1805'. RIH. WORK THRU TIGHT SPOTS F/1805'-2351'. WASH 60' TO BTM. DRILL 4163'-4165'. LOST RETURNS AFTER 2400 STROKES. MONITOR WELL. POOH ATTEMPTING TO REGAIN CIE @ 3250', 2318', 1660'. HAD PARTIAL RETURNS @ 1196' POOH TO 561'. FULL RETURNS 10.0 PPG. FIN POOH. LD MOTOR & SET BACK MWD. MU NEW BHA WITH H/O & RIH TO 1000'. CIRC & COND MUD-10.0 PPG. RIH. REAM TIGHT SPOT F/1672'-1766'. CIRC & COND MUD TO 10 PPG. RIH TI 2983' REAM TIGHT SPOTS F/1860'-1890' F/1952'-2046' CIRC & C~ND MUD TO 10 PPG. POOH FOR BIT 16"@ 121' MW: 9.7 VIS: 49 CBU @ 2983'. 8 BPM NO LOSS. FIN TIH TO 4165' NO FILL. CIRC & COND MUD TO 10 PPG. 15 BPM @ 1200 PSI-NO LOSS. POOH. LD STABS & HOLE OPENER. PU BIT, NAVI-DRILL, OREINT & TIH. WORK THRU TIGHT SPOT @ 2330'. WASH 60' TO BTM. CBU. DRILL FROM 4165'-5880'. CBU. RUNNING 9-5/8" CSG 16"@ 121' MW: 9.7 VIS: 45 POOH F/NEW BIT. CONE WAS LOCKED UP. MU BIT, ORIENT MWD, & TIH. DRILL F/5880'-6310' SHORT TRIP TO 5840'-RIH, NO FILL. CIRC & COND MUD. ~ROP SURVEY & PUMP PILL. POOH. LD BHA FOR INSPECTION. NO TIGHT SPOTS. SERVICE RIG. RU CSG TOOLS & HOLD SAFETY MEETING. RUNNING 9-5/8" CSG. TOTAL OF 152 JTS(72 JTS L-80 & 80 JTS J-55) TO BE RUN. OOT 7 !99;¢ " r-, ~AIaska Oil & Gas Con°. Anchorage WELL: 1Y-34 API: 50-029-22382 PERMIT: 93-91 PAGE: 2 07/03/93 (5) PARKER 245 TD: 6310'( o) 07/04/93 (6) PARKER 245 TD: 7628' (1318) 07/05/93 (7) PARKER 245 TD: 8490' ( 862) 07/06/93 (8) PARKER 245 TD: 8640'( 150) CIRC & COND MUD 9-5/8"@ 6289' MW:ll.8 VIS: 48 FIN RUNNING 9v5/8" CSG. SHOE @ 6289'. CIRC & COND MUD. TOTAL OF 800 BBLS. TEST LINES TO 3000 PSI. USED THREE PLUG SYSTEM. MIX & PMP 985 SX LEAD CMT FOLLOWED BY 890 SX TAIL. DISPLACE W/RIG PMP, LOST ALL RETURNS AFTER PUMPING 260 BBLS OF CAL 467 BBLS DISPLACEMENT. PUMPED 470 BBLS-3 BBLS OVER DISPLACEMENT. DID NOT BMP PLUG. MAX PSI=1800#. CIP @ 1235 HOR 0702/93. FLOATS HELD. CLEAN OUT DIVERTER & LINES. LD LANDING JT & CGG TOOLS. ND DIVERTER. PMP 213 SX TOP JOB-15 PPG RETURNS. INSTALL PACKOFF. INSTALL SPEED HEAD & TORQUE TO 18,000 FT/LBS. RKB=38.90. NU 13-3/8 FM BOPE. TEST BOPE. TEST WITNESSED BY BOBBY FOSTER W/AOGCC. PULL TEST PLUG & SET WEAR RING. MU BHA, ORIENT, LOAD LWD-MWD & TIH TO 6211' CIRC OUT THICK MUD. TEST CSG TO 2000 PSI-OK. DRILL FL6AT COLLAR, & 58' CMT TO 6269'. CIRC & COND MUD TO 11.7 PPG BEFORE DRILLING OUT SHOE. POOH F/MOTOR 9-5/8"@ 6289' MW: 10.5 VIS: 44 DRILL 20' CMT, SHOE, & 10' NEW FORMATION. CBU. RUN PIT W/ll.7 PPG. DID NOT BREAK DOWN W/250 PSI. EMW=12.8 PPG. DRILL 6320'-6780'. LOST RETURNS. MONITOR WELL. FILL BACKSIDE WTIH WATER. POOH TO CSG SHOE. TOOK 32 BBLS OF WATER TO STABILIZE HOLE. CIRC & CUT MUD WT TO 11.O PPG. TIH TO 6780'. ATTEMPT TO CIRC W/ll.0 PPG-HOLE STILL TAKING FLUID. CIRC & CUT MUD WT TO 10.6 PPG. DRILL F/6780'-7628'. MOTOR STALLING OUT. CIRC & MONITOR HOLE. HOLE TAKING FLUID WITH PUMPS ON AND FLOWING WITH PUMPS OFF. POOH FOR NEW MOTOR. HOLE DID NOT TAKE ANY FLUID FOR THE FIRST 40 STDS. DRILLING 9-5/8"@ 6289' MW:10.5 VIS: 42 FIN POOH. DOWNLOAD MWD/LWD & LD MOTOR. NU NAVI-DRILL, ORIENT & TIH TO CSG SHOE. SLIP & CUT 109' DRILL LINE. MONITOR WELL-SLIGHT FLOW. TIH TO 7600' REAM F/7600'-7628' FOR ANADRILL. DRILL F/76~8'-8490'. CIRC & COND MUD 9-5/8"@ 6289' MW: 10.4 VIS: 44 DRILL F/8490'-8640'. CBU. DROP SURVEY. PMP PILL & POOH. DOWNLOAD MWD/LWD SOURCE & LD BHA. FILL UP 16 BBLS SHORT. MU BIT & SCRAPER & TIH TO 6200'. CBU THREE TIMES. PMP PILL & POOH. LD BIT & CSG SCRAPER. RU SCHLUMBERGER & RUN USIT LOG F/3500'-500'. CASING SHOWED NO WEAR. RD. MU WIPER BHA & TIH. NO FILL. CIRC & COND MUD TO RUN CSG. OCT 2.. 1993 A!aska 0il & Gas 0ohs. C;omm Anchorage WELL: 1Y-34 API: 50-029-22382 PERMIT: 93-91 PAGE: 3 07/07/93 (9) PARKER 245 TD: 8640'( 07/08/93 (10) PARKER 245 TD: 8640' ( o) o) 07/09/93 (11) PARKER 245 TD: 9079' ( 439) 07/10/93 (12) PARKER 245 TD: 9354' ( 275) o) 07/11/93 (13) PARKER 245 TD: 9354'( PU 3-1/2" DP 7"8 8633' MW:10.4 VIS: 43 PUMPED DRY JOB. POH. LD BHA. PULL WEAR RING. RU CASERS FOR 7". HOLD SAFETY MEETING. RUN 7" CSG. CIRC 8 9-5/8" SHOE. TIGHT 8 7337' MD. CIRC & COND FOR CMT. PARTIAL RETURNS. LOST 150 BBLS. PUMP CMT. CIP 8 2330 HRS 07/07/93. PLUG BUMPED TO 3500 PSI. TEST CSG FOR 30 MINUTES. FLOATS HELD. WELL FLOWING SLIGHTLY UP BACKSIDE. SHUT IN & MONITOR PRESS IN 7" X 9-5/8". PU & STANDING BACK 3-1/2" DP UNTIL PRESS DROPS. RIH W/3-1/2" DP 7"8 8633' MW:ll.2 VIS: 46 CONT PU & STANDING BACK 3-1/2" DP. WAITING ON FLOW OUT ANN TO STOP. ND BOPE. PU STACK. SET SLIPS W/210K LBS. ROUGH CUT 7". LD LANDING JT. SET STACK BACK ON RISER. MAKE FINAL CUT. INSTALL PACK OFF. TEST FAILED. PULLED TBG SPOOL. RETIGHTEN PACK OFF. TEST PASSED. NU BOPE. CHANGE 5" RAMS TO 3-1/2". TEST BOPE. WITNESS WAIVED BY STATE (JIM SPALDING). FREEZE PROTECT ANN W/100 BBLS WATER FLUSH & 70 BBLS DIESEL. FINAL PRESS=900 PSI. RIH W/BHA & 3-1/2" DP. POH FOR BIT 5"8 9354' MW:ll.7 VIS: 48 CONT RIH W/BHA & 3-1/2" DP. TAG CMT STRINGERS 8 8524' CIRC & TEST CSG TO 3500 PSI F/5 MIN. DRILL CMT STRINGERS. TAG PLUGS 8 8550'. DRILL PLUGS, FIT COLLAR, & FLOAT SHOE. DRILL 10' NEW FORMAITON TO 8650'. CBU. TREAT CMT CONTAMINATED MUD & EVEN OUT MW. PERFORM LEAK OFF TEST-12.8 PPG EMW W/300 PSI. DRILL F/8650'-9079'. SHORT TRIP TO SHOE. MONITOR WELL 8 SHOE FOR 5 MIN-0K. CBU. DROP SINGLE SHOT. POH FOR BIT. 72 STDS OUT 8 0600 HRS. RUNNING E-LINE OH LOGS 5"8 9354' MW:ll.7 VIS: 48 CONT POH F/BIT. CHANGE BIT, TEST PDM, RIH. REAM F/8935'-9079'. NO FILL. DRILL F/9079'-9354'. SHORT TRIP TO SHOE. HOLE IN GOOD SHAPE. MONITOR HOLE 8 SHOE WHILE SERVICING RIG. CBU. NO TRIP GAS. DROP SURVEY. PMP SLUG. POH (SLM). HOLE IN GOOD SHAPE. LD MONEL'S, STAB'S, PDM. RU SCHLUMBERGER. RUN OPEN HOLE E-LINE LOGS (DIL-SFL-GR/LDT/CNTG). CIRC & COND F/CMT JOB 5"8 9354' MW:ll.7 VIS: 48 CONT TO RUN E-LINE LING. RD SWS. MU BHA. RIH TO 7" SHOE. SLIP & CUT 120' FO DRLG LINE. RIH. WASH F/9259'-9354' HOLE IN GOOD SHAPE. NO FILL. NO TRIP GAS. CBU. PMP SLUG. POH. PULL WEAR RING. RU WEATHERFORD CASER. RIH W/5" LINER & LINER HGR. CIRC LINER VOLUME WHEN RUNNING TOOL, PU. CONT TO RIH W/5" LINER ASSY ON 3-1/2" DP. CIRC 8 7" SHOE. WASH 30' TO BTM. NO FILL. CIRC & COND MUD. HOLE TRYING TO PACK OFF. 1500 BBLS CIRC 8 0600 HRS. WELL: 1Y-34 API: 50-029-22382 PERMIT: 93-91 PAGE: 4 07/12/93 (14) PARKER 245 TD: 9354'( 07/13/93 (15) PARKER 245 TD: 9354'( 09/05/93 (16) TD: 9354 PB: 263 09/06/93 (17) TD: 9354 PB: 9263 o) 0)- TEST LINER LAP 5"@ 9354' MW:ll.7 VIS: 53 CONT TO CIRC. ESTAB GOOD RATE. HOLE NOT PACKING OFF & RECIP GOOD. 500 BBLS PUMPED. PMP 5 BBLS WATER. TEST LINES TO 3500 PSI. PMP 20 BBLS SPACER FOLLOWED BY 37 BBLS CMT. DROP DP WIPER DART. PMP 5 BBLS WATER. DISPLACE 67.5 BBLS MUD USING RIG PMPS. PLUG DID NOT BMP. SET LINER ON BTM. LINER TOP @ 8343'. ROTATE 18 TURNS TO RELEASE. OFF LINER HGR. PU 2-1/3 STDS. REVERSE CIRC @ 8126'. 14 BBLS CMT BACK. CIRC DOWN DP @ 6 BPM. POH. LD 5" LINER RUNNING TOOL. SET WEAR RING. MU ROCK BIT, 7" CSG SCRAPER. RIH. WASH F/8028'-8136' TAG CMT @ 8136' DRILL CMT F/8136'-8343'. SO~T CMT LAST 40'. ~BU. PMP SLUG. PON. LD HWDP & DC'S. RU TO RUN 2-7/8" PAC DP. PU 4-1/8" GOPHER MILL & 5" CSG SCRAPER. RIH ON 2-7/8" DP (31 JTS TOTAL). RIH W/3-1/2" DP. TAG PBTD @ 9268'. CBU @ 57 SPM (5.75 BPM). TEST LINER LAP TO 1500 PSI FOR 30 MIN. LOST 50 PSI. RIG RELEASED 5"@ 9354' MW: 0.0 VIS: 0 PMP 43 BBLS HI VISC SWEEP. FLUSH STACK & SURF EQUIP W/WATER. PMP 100 BBLS WATER FOLLOWED W/ll.7 PPG BRINE W/DOWELL HOLDING BACK PRESS W/CHOKE. POH. LD 3-1/2" & 2-7/8" TBG. CLEAR RIG FLOOR OF 2-7/8" TOOLS. RU TOP DRIVE FOR 5". CHANGE RAMS IN BOP. ND BOPE & NU LOWER TREE ASSY. LD 5" DP FOR RIG MOVE. 25 STDS LEFT IN DERRICK. RELEASED RIG @ 0400 HRS 07/13/93. BEGIN THE RIG MOVE TO 1Y-27. LOAD PIPE SHED 5"@ 9354' MW:ll.7 NaC1/Br MOVE RIG FROM 3A-12 TO 1Y -34. RIG MOVE SLOW DUE TO BREAKING THROUGH THE ROAD FROM 3A TO THE MAIN ROAD @ CPF-3. ACCEPT RIG @ 2200 HRS ON 09/04/93. ND DRY HOLE TREE, NU BOP. INSTALL TEST PLUG. RU CHOKE & KILL LINES. RU ACCUMULATOR LINES. FUNCTION TEST. CHANGE PIPE RAMS TO 3-1/2". LOAD 170 BBLS 11.5 PPG BRINE IN PITS. WT UP TO 11.7 PPG. RU FLOW RISER. FUNCTION TEST BOP. FOUND SEAL LEAK IN HCR. CHANGE OUT HCR VALVE & REPLACE CHOKE CONNECTION. LOAD 3-1/2" DP IN PIPE SHED & STRAP. POH 5"@ 9354' MW:ll.7 NaCl/Br LOAD 3-1/2" DP IN PIPE SHED & STRAP. WAIT ON PMP STUFFING BOX FROM MACHINE SHOP. INSTALL STUFFING BOX ON MUD PMP & TEST TO 4000 PSI. TEST ANNULAR, PIPE & BLIND RAMS, HCR VALVES, CHOKE & KILL LINE TO 300/3000 PSI. TEST FLLOR VALVE & CHOKE MANIFOLD TO 300/3000 PSI. TEST WITNESSED BY BOBBY FOSTER W/AOGCC. MU BIT & SCRAPER. PU 3-1/2" & RIH. TAGGED FILL @ 8312'. PU KELLY & TEST TO 3000 PSI CLEAN OUT FILL TO TOL @ 8331' (NORDIC RKB). CBU. HAD ~USHY CMT IN RETURNS. BREAK KELLY & STD BACK. RU TO CIRC W/HEADPIN & HOSE. WELL OUT OF BALANCE DUE TO HEAVY SPOT IN ANN. CIRC TO BALANCE BRINE. POH. WELL: 1Y-34 API: 50-029-22382 PERMIT: 93-91 PAGE: 5 09/07/93 (18) TD: 9354 PB: 9263 09/08/93 (19) TD: 9354 PB: 9263 RUNNING CET/CBT 5"@ 9354' MW:ll.7 NaCl/Br POH W/3-1/2" DP. LOAD 2-7/8" DP IN PIPE SHED & STRAP. RU FLOOR TO RUN 2-7/8" DP. MU BIT & SCRAPER. RIH. TAGGED FILL @ 9243'. PU KELLY & WASH TO 9250' (NORDIC RKB). ROTATE & WORK PIPE WHILE FILTERING BRINE. STAND BACK KELLY. REVERSE CIRC & FILTER BRINE. POOH & LD 61 JTS OF 3-1/2" DP. POH & STAND BACK 100 STDS OF 3-1/2" DP. LD 32 JTS OF 2-7/8" DP. RD FLOOR & FLOW RISER. PULL WEAR RING. RU SWS. MU CET/CBT LOGGING TOOLS @ 0515 HRS. RIH. LAND TBG IN TBG SPOOL 5"@ 9354' MW:ll.7 NaCl/Br CONT TO RUN LOGS W/SWS-CBT, CRT,GR, CCL. SERVICE RIG & LOAD PIPE SHED W/4" DSSHTC TBG WHILE RUNNING LOGS. LD LOGGING TOOLS. PU PERF GUNS & TEST SWS LUB TO 900 PSI. RIH FOR GUN RUN #1. PERF F/9036'-9056' W/4 SPF, 180 DEG PHASING, GUNS ORIENTED 160 DEG CCW F/HS. POOH & PU GUN #2. RIH & PERF F/9030'-9036', 4 SPF, 180 DEG PHASING, GUNS ORIENTED 160 DEG CCW F/HS. NU FLOW LINE. LOAD PIPE SHED W/3-1/2" EUE TBG & RU FLOOR TO RUN TBG. RIH W/3-1/2" J-55 TBG & JEWELRY AS PER TBG DETAIL. RUN TOTAL OF 11 JTS 3-1/2" BTCS & 94 JTS 3-1/2" EUE 8RD TBG. MU 3-1/2" X 4" XO, TBG HGR, & LANDING JT. LAND TBG, BACK OUT LANDING JT, & CLOSE BLIND RAMS. CHANGE PIPE RAMS TO 4" & TEST SAME TO 3000 PSI. BACK OUT TBG HGR & LD SAME. RIH W/4" 11# J-55 DSSHTC TBG & JEWELRY. PU OTIS SSSV. ATTACH CONTROL LINE & TEST SAME TO 5000 PSI F/10 MIN. CONT TO RIH W/4" TBG. RUN TOTAL OF 170 JTS 4", 11# J-55 TBG. MU TBG HGR & LANDING JT. ATTACH CONTROL LINE TO HGR & PRESS TO 5000 PSI F/10 MIN. DRAIN BOP STACK & LAND TBG IN SPOOL. AJask~, (iii & Gas Cons, Anchorag~ WELL: 1Y-34 API: 50-029-22382 PERMIT: 93-91 PAGE: 6 09/09/93 (20) TD: 9354 PB: 9263 RIG RELEASED 5"@ 9354' MW:ll.7 NaCl/Br LAND HGR IN WH. DROP BALL. RILDS. WAIT FOR BALL TO DROP. PRESS TBG TO 2500 PSI & HOLD FOR 30 MIN TO SET PKR. BLEED OFF PRESS, BOLDS. PRESS TBG TO 1000 PSI & PULL UP TO SHEAR PBR. SHEARED @ 100K# UP WT. RE-LAND & RILDS. PRESS ANN & TBG TO 1000 PSI, CLOSE SSSV. BLEED TBG TO 500 PSI & MONITOR FOR 15 MIN SSSV TEST. RE-PRESS SSSV CONTROL LINE & EQUALIZE ANN & TBG PRESS-NO INDICATION OF SSSV OPENING. BLEED OFF TBG PRESS & ANN PRESS FOLLOWED, INDICATING SSSV OPEN. PRESS UP ANN & TBG TO 2500 PSI & HOLD FOR 15 MIN. PRESS TBG TO 3000 PSI, SHEAR-OUT SUB SHEARED. BLEED OFF PRESS & CLOSE SSSV. PULL LANDING JT. LEFT LANDING JT XO ON TBG HGR. ND BOP STACK, BREAK OUT XO, SET BPV, NU TREE. TEST P/O & FLANGES TO 5000 PSI. PULL BPV, SET TEST PLUG. TEST TREE TO 250 PSI & 5000 PSI. PULL TEST PLUG, OPEN SSSV. RU TO FREEZE PROTECT. CIRC 10 BBLS DIESEL DOWN ANN @ 2 BPM, 500 PSI. BULLHEAD 6 BBLS DIESEL DN TBG. REQUIRED 3500 PSI @ 1/5 BPM FOR FORMATION TO BEGIN TO TAKE FLUID. SLOWLY RAISED PMP RATE AS PRESS DECREASED. FINAL RATE 3/4 BPM @ 2800 PSI. MONITOR WELL, RD CIRC LINES. SET BPV, SECURE WELL. RIG RELEASED @ 1330 HRS, 09/08/93. SIGNATURE: (dr~erinten~t) :::AG~. NO: ~,w***** ANADRILL ~**~ S~L~BERGER *~***~* ~**** ***~ ********************************************** ~'~r~r~i ARCO ~LASt(~.~ iNL: WELL NAM£ I¥-34 LC~CATION I XUP~UE W~ ~JMB~R 0 WELL HEAD Lu~ATiUN; ,.~,Ni-o) u,Ou ^"'~ ? I wz~Mb~H FROM ROThRY. TABLE TR. _ ..,,.,.~ac'r~ IS ~'~l~. IN FGiNT(TIP) : M~SUR]SD DEPTH 121,00 TRUE VERT D~F'TH 121,00 ~MLITH 0.00 ~T~TUD~N/-~ O~C~ DEPARTURE(E/-W) 0 .Oil .& Gas Cons. uommisston ~Anchorage 2 1"f-34 TARGET =,:~: ,ur~ AZIMUTH L~TI]'JDE ft de9 de9 0.00 0.00 0~00 O.OO -0,05 o,os 183,44 0,00 0,72 o,'.¢y t45,i2 ' '"' 4,18 3,i4 i40,72 -3.55 ,,.,,.., DIoPLACEMEh~ at DEF'ART~:E r 0,00 -0,06 0.14 0,80 2,23 4.1'.;' .A.68 AZIMUTH dee 0,00 271,72 169,71 147,86 DLS deG/ lOOft O,OO 0,0~ 2,71 922,41 91,7 A~9 ~ %,4 737~04 91,8 907,57 '"~ ¢= -" :"; i45,30 -*.~",13 12,72 21,45 142,97 2,30 -",t , ' ~9 4.~g C-<- .-,,", AL 94 .... . &~O,YO ~o,08 ii,.,.-, ,~,...'- -z.~ ...... ,.,,58 .qA,A8 ...... " 57:?6 15,79 IX)J0 _,r,. ',.=. 32,91 ~-, :,o ., .,~ o,' .7, 145:42 4,89 8.>,08 146,91 1,50 8-2,94 :~ ......... ,,,- .o~.,,,.,~" -A9,60 .. 45,36 110,81 IA.46 149,67 .-,--, 0 _. -7o,w 59,42 ,ll,i0 147,67 1012,9.9 1198,73 ~ ~,',~ -,~: 1386 .90,6 994,97 71,4 i08~18 94.3 1167,42 94,4 ....... I<~,,'~ 20.41 150.76 ~=~ ~o ..... : .... 147,25 246,66 29.77 ,:~ ~r, 74,39 ,4,,21 .-~,,--~'~ o~2,18 0 o=. 174,2A 148,$'2 2,04 / .~1_, 106,35 210,05 147,56 0,6? 124,07 248,23 l_,o,vi a, .... 144,58 -,1,28 1.50,24 3.00 i482,27 1574,3i 176i ~ t0~ LC, 96,0 !419,40 9P,O 1495,90 93,8 ,=,, .... ~' 147,84 -294,2~ ~o/,16 3i,k~ 388,24 ~: ~' ¢0,88 144,5~ -336.73 ~r =n "40 14A,79 i,,.~' -436,10 507,30 43.63 '9' :: 390,40 1.49,60 £./ ,JJ . ..... A7 447 ='" 149,1(; 4,1i ,'r7._. ,P7 .. ..... 4~ 50?,49 148,87 4.49 ~Y~,Sv 576,64 148.A7 4.05 i750,77 2415,57 5LO~ OO ?_~ 1768,44 92,0 1824,73 ' ~' "' t 870 279,? 2040,54 645,96 50,42 146,28 %52,43 339,30 648,31 718,65 54,12 "= ~? ,,J,o/ -612,62 2~0,17 720,%' /=,,~ o~,oo i44.55 -674,36 423,47 ..-, ~ 148,44 148,Ib 147,87 146,78 3,20 4,0,.-.<, 0.7/'7 0,60 2?75',54 4075+64 280.6 ~oi+3 ~oao,IX o~= = 30i 8~ .... 16 14~.,v 145.21 992,00 ~vne ~i ,~ ~o I~A? wr, ~,QLw 1,17 0 U,o4 ().11 O,3i 4379 ~7~+,.,~ 52~,74 559g 276,7 ~ .... 35~Y,24 373.9 3926,70 3062+45 =~ o^ ~- ~.,u 142.~/ = ...... o~.i ~c. =~ 4.~ i44,02 o,~ ~ ':'^ =~ 2612,04 143.31 oO,.,~,ao 1.43,10 1838,80 ~,i~ =' " · _ o=SO,ov 143,1i !972,&4 .... r. 2i46,94 3581,96 i43,17 0,57 0,63 o, 20 0,4.':3 0,46 5879,66 6220,17 LA'7£ 0O ,j.?/ ,.,, .'-,=i ,43 ,j! _ti., 7037,18 283,2 40%',12 340+3 4306.06 4o£,,Yv 282,7 a~o~ ~o ac,,>:. 145,02 -3049,94 '- A _557 4076,50 51,2,0 i45..6 -~ ./~., = os +0c, 146,66 2777,63 38.06,54 143.25 5~ m,-, tM5 57 ~,o= 4076,52 £o4i.44 4278,41 £,..ri,~o 4503,67 2803,% 4732,73 143,87 0,84 0,$I 0,50 0,56 ~ ,4,' 8356,'7'I 136.8 %412,93 9005, O0 447,2ozuo" n,,, o.'~'~ THZ NST SURVZY !S PROJECTD ~aq,uv 74,0 ,:~u~,o~ A~T . TARgeT STATION n~Mb~H LATITUDB ~BP~RTUR£ DISF'LACBMB~ 4"q~ ~ = .... 147,69 '~ ~ ~o~' ~ ~,-,=" ~ '.7_ue~ : .... -, :~ ~ ~- _~o~ ~ 3008.36 5106,48 ~v --" ='"~,2~ .... 143,48 -4749,48 3502.37 5901,20 o~,~o ao,Ou 146.97 -4V/~.o~ 3661.53 6180,14 .~i 28~ '=~ .... 5106,65 2TM ~ 6326.19 o361.~ 6361,13 ~o ~ ~:~ o? -s~qg.m 3749.64 .... ~ZIMU~H 143.8S 143,90 143,75 143.68 143,63 143,57 143,67 143,83 143,86 DLS d_PO," lOOft I Ic' 2,10 ;.04 0,00 ARCO Alaska, Inc. Date' October 22, 1993 Transmittal #: 8903 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items, please acknowledge receipt and return one signed copy of this transmittal. Y-27 Y-27 Y-27 l Y-18 Y-18 Y-18 IY-31 Y-31. Y-31 IY-28 Y-28 Y-28 IiTM Y-21 Y-21 .Y-19 Y-19 Y-19 ~1 ~-'7~ ----1 Y-24 Il Y-34 c~,-~ .. c1 \ Y-34 ,,/CDR Enhancement 5': 8-23-93 LWD/Depth Corrected ,/CDN LWD/Depth Corrected~-~-5"8-23-93 ,/CDR LWD/Depth Corrected a'~s"8-23-93 v~CDN LWD/Depth Corrected ~_ ~-5"9-08-93 ~:~DR Enhancement s~ 9-08-93 LWD/Depth Corrected ,/'CDR LWD/Depth Corrected ,/'CDR LWD/Depth Corrected ,,"CDR Enhancement LWD/Depth Corrected v~HLDT Corrected Casedhole 5" Density c/CDR Enhancement .¢ 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected ;z~ 9-08-93 ¢CDN LWD/Depth Corrected ~-~ 9-08-93 ¢CDR Enhancement : 5 9-08-93 LWD/Depth Corrected ~'CDR LWD/Depth Corrected-~-~ 9-08-93 ¢'CDN LWD/Depth Corrected ~'~s 9-08-93 ¢'CDN LWD/Depth Corrected ,~t-5 9-09-93 ~"CDR LWD/Depth Corrected ='~ 9-09-93 ,/'CDR Enhancement 5' 9-09-93 LWD/Depth Corrected ¢TDTP Depth Corrected ¢/CDN LWD/Depth Corrected 2¥5 ..~CDR LWD/Depth Corrected z~-~ 9-08-93 8-26-28-93 8-26-28-93 10-08-93 8-24-93 7-2-5-93 7-2-5-93 8858-10012 8850-10018 8870-9990 8280-9180 8500-9150 8290-9160 6910-7830 7100-7700 7000-7700 7650-8250 728O-825O 7260-8250 690O-745O 6670-7640 6650-7590 6900-7610 6900-7660 7050-7500 7450-8220 6250-8640 6250-8640 c~-~.q.\ 1Y-34 ,-//CDR Enhanced LWD/Depth' Corrected 5" 7-2-5-93 7200-8600 · Receipt Acknowledged' DI,~TRIBUTION: D&M Drilling NSK State.of Alaska (+Sepia) Bob Ocanas ARCO Alaska, Inc. Date: October 22, 1993 'Transmittal #: 8904 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-27~ 5~~3 LIS Tape and Listing: 9-13-93 93327 o~-z-'~/CDR/CDN/RAB Data 1Y-18.~5~q, LIS Tape and Listing: 9-13-93. 93362 c~-~CDR/CDN, 1 Bit Run with QRO Processing 1Y-28~-~5o LIS Tape and Listing: 9-14-93 93391 ow-CDR/CDN, 1 Bit Run with QRO Processing 1Y-2~sa~5( LIS Tape and Listing: 9-08-93 93347 ~--CDR/CDN/RAB in 1 Bit Run and QRO Processing 5--~5--7u~/ 1Y-19~s~-~z LIS Tape and Listing: 9-13-93 93380 o~ CDR/CDN, 1 Bit Run with QRO Processing 1Y-34~%~3 LIS Tape and Listing: 9-24-93 93296 ~!~- CDR/CDN, 2 Bit Runs, QR0 Processed u ~ ~, ~ u~o 1Y-24~$~s~( LIS Tape and Listing: 8-24-93 93319 C.P~- 3 Passes TDTP, LDWG Format 75~5 ---~zzTz..., 1Y-31-~535~ LIS Tape and Listing: 9-13-93 93362 -~[-t-CDR in 1 Bit Run, QRO Processed u~5o- 1Y-31-~--~5~ LIS Tape and Listing: 10-08-93-93 93430 0_.~ 3 Passes, Averaged and Reprocessed HLDT Receipt Acknowledged: Bob Ocanas DISTRIBUTION: ARCO Alaska, Inc. Date: September 17, 1993 Transmittal #: 8868 RETURN TO: ARCO Alaska, Inc. A'I'TN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased receipt and return one signed copy of this transmittal. Hole items. Please acknowledge 1Y-34 Cement EvaluatiOn Log CET 9-06-93 1Y-34 Cement Bond Log CBT ~' 9-06-93 . / Acknowledge: ~_//~_.~- _ _ ~ Date' State of Alaska(+sepia) Drilling 8356-9262 5" 8356-9238 5" NSK Ab. A OILAND GAS CONSERVATION COMM~._ .ON APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well__ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing Variance X Perforate Other - 5. Type of Well:- ~. Datum eleva~on (DF or KB7 Development . X , Exploratory _ 106 RKB-MSL Pad 65' 1. Type of Request: 2. Name of Operator ARCO Alaska, I.nc. :3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 570' FNL, 1822' FWL, Sec. 1, TllN, RDE, UM At top of productive interval 124' FNL, 102' FWL, Sec. 7, TllN, R10E, UM (approx) At effective depth 392' FNL, 272' FWL, Sec. 7, TllN, R10E, UM (approx) At total depth 431' FNL, 292' FWL, Sec. 7, T11N, R10E, UM (approx) 12. Present well condition summary Total Depth: Effective depth: measured 9,354 feet (measured) (approx) true vertical 6,406 feet measured 9,263 feet Plugs (measured) (approx) true vertical 6,344 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-34 9. Permit number 93-91 10. APl number 50-029-22382 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 8 0' 1 6" 225 Sx AS I 6,2 8 9 9 - 5 / 8" 985 Sx Class E 890 Sx Class G 8,361 ' 7" 200 Sx Class G 1,0 2 0 5" 175 Sx Class G measured None true vertical Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Measured depth True vertical depth 119' 119' 6,289' 4,349' 8,361' 5,616' 9,354' 6,406' (approx) (approx) (approx) Alaska Oil & Gas Cons. Cornrnissio~ Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch 14. Estimated date for commencing operation 9/4/93 Name of approver '~R ~OI~P'Z'~' [ ~- Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service -- 17. I hereby,.~certify that the foregoing is true and correct to i~he best~f.., my knowledge. FOR COMMISSION ~OSE ONLY/ Conditions of approval: Notify Commission so representative may witness IApproval ~o..;~_~.-..-- Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10-,,v'/'~ ",pp;oved CoCy Re-~-urned Original S!gned By ~'-,,¢--/~ Approved by the order of the Commission David W_ jc:hr, stnq comm~i-d~b7 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 Request for Varience KRU Well 1Y-$4 ARCO Alaska Inc. requests approval to accept the the MWD and single shot surveys for KRU Well 1Y-34 pursuant to AOGCC 25.050 (e). KRU Well 1Y-34 was drilled in July, 1993 as part of Drill Site 1Y infill development program. As such, the well is not subject to any lease or property implications. The MWD and single shot surveys provide adequate wellbore path description in the event of future drilling in the area. Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Jo~n_ ~ Chairma~ Blair Wondzell, P. I. Supervisor Bobby Foster, Petroleum Inspector DATE: September 5, 1993 FILE NO: AAUIIEAC.doc SUBJECT: BOP Test- Nordic # 1 ARCO-KRU- 1Y-34 PTD # 93 - 91 KR Field Sunday September 5, 1993: I traveled to this date to Nordic rig # 1at ARCO's 1Y - 34 and witnessed the initial BOPE test. As the attached AOGCC BOP Test Report shows there were two failures. Two valves in the choke manifold leaked. These valves are to be repaired with in 24 hours and an inspector notified. . ,~~ary: I witnessed the BOP test on Nordic rig #1- test time 2 hours - 2 ffailures. Attachment · AAUIIEAC.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 5" Test: Initial Workover: COMP. NORDIC Rig No. 1 PTD# 93- 91 ARCO Rep.: 1Y- 34 Rig Rep.: Set @ 9,354 Location: Sec. '1 T. Weekly Other X DATE: 8/5/93 Rig Ph.# 659- 71 '15 CARLA LENZ LANCE JOHNSON 11N R. 9E Meridian U Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit NtA Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Pressure P/F 300 ~ 3000 P '1 300 ~ 3000 P 'I 300 t 3000 P I 300 ~ 3000 P '1 300 ~ 3000 P 2 300 ~ 3000 P N~A MUD SYSTEM: Visual Alarm Tdp Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Gas Detectors YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP P/F CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Quan. Pressure SEE NO TE ~3~ 2 300\30000 '1 300\3000 Test Pressure P/F 300 ~ 3000 P 12 28 300 ~ 3000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3, '100 I P Pressure After Closure 2,400 I P 200 psi Attained After Closure 0 minutes '14 System Pressure Attained 1 minutes 4 Blind Switch Covers: Master: YES Remote: Nitgn. Btl's: 2 @ 2300 Psig. sec. sec. YES Numberof Failures: 2 ,TestTime: 2.0 Hours. Number of valves tested '18 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I REMARKS: 2 VALVES FAILED IN THE CHOKE MANIFOLD - TO BE REPAIRED AND AN INSPECTORNO TIFIED NOTE; THE UPPER AND LOWER KELLY VALVES ARE TO BE TESTED BEFORE USING Distribution: odg-Well File c - OperJRig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES. X NO Waived By: Wrtnessed By: F1-021L (Rev. 7/93) AAUIIEAC.XLS ,. ARCO Alaska, Inc. Date: July 30, 1993 Transmittal #: 8816 RETURN TO: ARCO Alaska, Inc. A'I'TN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and 'return one signed copy of this transmittal. 1Y-24 ~ ~,"7"'~ Cement Bond Log CBT 1Y-24 Cement Evaluation Log CET 1Y-34 I Cement Evaluation Log ~'~· CET 7" CaSing Section 1Y-34 Cement Bond Log CET 7" Casing Section Receipt ~~:~~//~ ~ Acknowledg~/'~.~/~'/....,/,~ 'Drilling 7-16-93 7-16-93 7-15-93 7-15-93 Date' Please acknowledge 615O-823O 6150-8254 7300-831 ~ 7300-8290 NSK ARCO Alaska, Inc. Date: July 16, 1993 Transmittal #: 8802 RETURN TO: ARCO Alaska, inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1Y-34 -~ Dual Induction-SFL-GR 7-10-93 (5" Phasor Processed) 1 Y-34 .., Litho Density Neutron 7-10-93 (Porosity & Epithermai) (2"& 5") 1Y-34 ~ Litho Density Neutron-Raw 7-10-93 Data (2" & 5" Data) 1Y-34 - Dual Induction-SFL-GR 7-10-93 (2" Phasor Processed) 1 Y-34 -- Cyberlook 7-10-93' Please acknowledge 8635-9340 8635-9316 8635-9316 8635-9340 8635-9316 Receipt Acknowledged: DISTRIBUTION: D&M Drilling NSK State of Alaska (+Sepia) ARCO Alaska, Inc. Date: July 16, 1993 Transmittal #' 8800 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. ~~ Ultrasonic Imager Corrosion 7-05-93 ~ y ~.~,~,~ Presentation Receipt ~ t~~~-q ~ate Acknowledge: _ . ' - I Drilling State of Alaska(+sepia) Please acknowledge 500-3500 NSK MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzell, a~l~ P. I. Supervisor ~/[~ FROM: Bobby Foste~,~~ SUBJECT: Petroleum Inspector DATE: July 4, 1993 FILE NO: AAXIGBAA.doc B.O.P. TEST--PARKER 245 AAI --KRU -- 1Y-34 KUPARUK RIVER FIELD PTD. 93-91 Friday, July 2, 1993' I traveled to rig 245 on AAI's 1Y-34 on this date and witnessed the initial B.O.P.E. test. As the attached B.O.P.E. test report shows there were no failures. Summary: Tested BOPE's on Parker 245--- Test time-- 2 hours--- 0 failures. Attachment' AAXIGBAA. XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initial X Workover: PARKER Rig No. 245 PTD # AAI Rep.: 1Y-34 Rig Rep.: Set @ ### Location: Sec. Weekly Other DATE: 7/2/93 93-91 Rig Ph.# 659-7697 JIMMY PYRON GRANVILLE RIZEK 1 T. 11N R. 9E Meridian U MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: X Well Sign X Upper Kelly/IBOP Housekeeping: X (Gen) Drl. Rig X Lower Kelly/IBOP Reserve Pit N/A Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 300/3000 1 300/3000 1 300/3000 1 300/3000 1 300/3000 1 300/3000 2 300/3000 N/A- Test Pressure P/F P P P P P P P N/A N/A Test Quart. Pressure P/F I 300~3000 P 300~3000 P 300/3000 P 300/300O P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F /3 3OO/3OOO P 38 300/3000 P P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,725 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 24 Trip Tank X X System Pressure Attained 2 minutes 18 Pit Level Indicators X X Blind Switch Covers: Master: YES Remote: Flow Indicator X X Nitgn. Btl's: 3 @2350, 1@2200 Gas Detectors X X 2@2400 Psig. sec. sec. YES Number of Failures: O ,Test Time: 2- Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within NONE days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 2/93) AAXIGBAA.XLS IARCO Alaska, Inc. p;~ ONE HUNDRED DOLLARS To the order ALASKA DEPT ANCHORAGE 73-426 ,ARCO Al~im,, Inc. ...~. Th~.F!~ National Bank of Chicago-O?lO .:!ii'>.::i!!i::>. ...Chi~gO~::!~[lZinoi$, Account 09-9?5?9 00216001 ,"0000 ~ ~ 600 ;," ~:O~SqOq~&8',' oq q?S?q," M'EMO~ND UM TO: David Johnsto.~ Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Doug Amos ~ Petroleum Inspector S TA TE Or ALASKA ~s~ o~,~vo aas co~vs~avar~o~v co~ss~o~ DATE: June28,1993 FILE NO: EAXHF2AB.DOC PHONE NO.: 279-1433 SUBJECT: Diverter Insp. Parker 245 AAI KRU 1Y-34 Kuparuk Rv. Field PTD No. 93-91 Monday June 28,1993: I traveled this date to AAI's KRU 1Y-34 well to witnessed the Diverter Function test on Parker Rig No. 245. As the attached AOGCC Diverter Inspection Form indicates, the diverter system consisted of a 20" Annular Preventer, 2- 10 3/4" Full Opening Ball Valves, 140' of 10 3/4" Schedule 80 Vent Line running West and 170' of 10 3/4 Schedule 80 Vent Line running East. The prevailing wind direction in Kuparuk is North East to South West. All components of the diverter system were in good repair and functioned properly, I found the location in good condition with clear access to the pad and around the rig. IN SUMMARY, witnessed the diverter function test at AAI KRU 1Y-34, no failures. Attachment EAXHF2AB.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development X Exploratory: Drlg Contractor: Parker Rig No. 245 PTD # 98-91 Rig Ph. # Operator: Arco Alaska Inc. Oper. Rep.: Mike Whitely Well Name: KRU 1Y-34 Rig Rep.: Dearl Gladden Location: Sec. 1 T. 11 N. R. 9 E. Merdian Umiat 659-7670 MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: YES Systems Pressure: 2,900 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1,500 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: 0 min. 32 sec. Systems Pressure Attained: 2 min. 51 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 2 @ 2300 3 @ 2400 Diverter Size: 20 in. 1 @ 2500 psig Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 10 3/4" in. Trip Tank: OK OK Vent Line(s) Length: 140 & 170 ft. Mud Pits: OK OK Line(s) Bifurcated: Yes Flow Monitor: OK OK Line(s) Down Wind: Yes Line(s) Anchored: Yes GAS DETECTORS: Light Alarm Turns Targeted / Long Radius: Yes Methane OK OK Hydrogen Sulfide: N/A N/A The following information is considered to be the Minimum requirements for the drawing on the Diverter Schematic "North Arrow, Prevailing Wind Direction, Distances from Annular to Tee, From Tee to Terminus of Vent Lines, Camp Location, Access Road Location and Any Other Vital Information." Camp on Other ~ Old Reserve Pit ~.... ~1~ Side of The~ ~- 140'~2' 170' ~ ~ 10 3/4" 103/4" ~~J~'(~)(~) ~1 I ~'[,1~--~ ~-~ [~-~ Access Road to Drill Site We,, House _ ~1~ I Main Rig Mod.~ ~ ~Well Houses i ~ Sub Base N Cuttings Processing Module 20" Annular With 2 - 10 3/4" Full Opening Ball Valves Prevailing Wind Direction NE & SW Distribution orig. - Well File c - Oper/Rep AOGCC REP.: c - Database c- Trip Rpt File OPERATOR REP.: c - Inspector F1-022 EAXHF2AB.XLS S/gned: Doug Amos ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 25,1993 A W McBride, Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 1Y-34 ARCO Alaska Inc 93-91 570'FNL, 1822'FWL, Sec 1, T11N, RgE, UM 468'FNL, 578'FWL, Sec 7, T11N, R10E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the Nodh Slope pager at 659-3607. David W Johr~ton \ - Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl . "--' STATE OF ALASKA ALAS. . OIL AND GAS CONSERVATION COMMISSI(... PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Test Re-Entry [--] Deepen [--] Service [--] Development Gas ~] Single Zone ]-~ Multiple Zone X 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 106', Pad 65' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25647, ALK 465 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 570' FNL,1822' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 146' FNL, 327' FWL, Sec. 7, T11N, R10E, UM 1Y-34 #U-630610 At total depth 9. Approximate spud date Amount 468' FNL, 578' FWL, Sec. 7, T11N, R10E, UM 6/£?/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line 1Y-07 9,469' MD 578' @ TD feet 24' @ 550' MD feet 2469 6,382' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 53.92° Maximum surface 2,561 psig At total depth (TVD) 3,395 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~ Weight Grade Coupling Len!~th MD TVD MD TVD /include sta~le data/ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 6,272' 41' 41' 6,313' 4,326' 590 Sx Permafrost E & HF-ERW 890 Sx Class 8.5" 7" 26.0# J-55 BTCMOC 5,117' 41' 41' 5,158' 3,646' HF-ERW 8.5" 7" 26.0# J-55 BTC 4,311' 5,158' 3,646' 9,469' 6,382' 200SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measure~d._depth True Vertical depth Structural RE( E I VED Conductor Surface Intermediate Production Linerd U IV, 2:4 t99;5 Perforation depth: measured true vertical Alaska 0il & Gas Cons. commission Annhnrane 20. Attachments Filing fee X Property plat I-I BOP Sketch X Diverter Sketch- X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~¢,,f..4.~ ~ FO, /).'JX/t~ Title Area Drillin~l Engineer Date ,~ ~'//~ ;~._ Commission Use Only Perm~, Number I APl number I Approval date I See cover letter for ~.-~r! 50- C):~-- ~.~- ~:;)~,,~ other requirements Conditions of approval Samples required [] Yes ~[ No Mud Icg required [] Yes [] No measuresHydr°gen sulfide [--] Yes ~. No Directional survey required ~ Yes ~ No Approved Copy Required working pressure for BOPE D 2M ~. 3M E] 5M [--] 10M r'"] 15M/ _Returned Other: Z'//,~-J,'"'//,~.-~r __ Original Signed By , David W. Johnston by order of Approved b~/ Commissioner the commission Date Form 10-401 Rev. 7-24-89 n triplicate ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR ... 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 25, 1993 ADMINISTRATIVE APPROVAL 190.15 Re: The application of Arco Alaska, Inc.' to deepen the maximum surface casing setting depth to 4440' true vertical depth from rig kelly bushing (TVDRKB) for all future wells to be drilled on the Kuparuk River Unit 1Y pad. R. F. Morgan Regional Drilling Engineer ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Morgan, The Commission has received your applica~tion dated June 23, 1993 requesting permission to set surface casing as deep as 4440' TVDRKB for all future wells to be drilled on the Kupamk River Unit 1Y pad: The Commission has reviewed the data presented and data already available, and finds that the request is based on sound engineering principles and will not cause waste. Therefore, by this letter, the Alaska Oil and Gas Conservation Commission permits the setting of surface casing as deep as 4440' TVD for all wells to be drilled on the Kupamk River Unit 1Y pad. This action is taken pursuant to Rule 3, Conservation Order No. 190. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 23, 1993 Mr. D. W. Johnston Chairman of Commission State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: SUBJECT: Revised Surface Casing Setting Depths Kuparuk River Field Pad 1Y This is a request for approval to vary from the existing Kuparuk River Field Rules, Conservation Order No. 173, to permit surface casing to be set as deep as 4,440' TVD RKB in infill wells on pad 1Y, which is an existing Kuparuk pad. This request references Conservation Order No. 190, Rule 3 which states a variance may be granted by Administrative action for the maximum surface casing setting depth. This depth will be below the West Sak and K-10 sands. In previous discussions with you and your staff, which resulted in the establishment of Conservation Orders No. 203 and No. 209, ARCO Alaska Inc. established a standard operating procedure of setting surface casing at least 200' TVD below the base of the West Sak sands. This request is for variance to set the surface casing 150' TVD below the K-10 sands on 1Y pad. Attached is a diagram depicting a generalized well profile on 1Y pad. Also attached is a data sheet summarizing the thicknesses and contents of the shallow sands in previously wells drilled on 1Y pad. In reviewing our geological structure maps, it is estimated that for the 1Y Pad, the base of the K-10 sands will occur at a maximum depth of 4,290' TVD. A surface casing depth of 4,440' TVD would ensure that the West Sak and K-10 sands would be isolated by the surface casing cement. A copy of ARCO's present Unit Development Status Map showing the location of the 1Y pad with respect to the existing development of the CPF-1, CPF-2, and CPF-3 areas is attached. Specific reasons for requesting a deeper surface casing setting depth are: o It is preferential to set the surface casing at least to a depth of 4,440' TVD RKB which will be below the K-10 sands a minimum of 150' TVD. It is believed that the K-10 sands are a lost circulation zone while drilling with the mud weights of greater than 11.7 ppg required to control the Kuparuk reservoir pressure. This lost circulation zone has been the cause of top setting the Kuparuk sands and completing the well with a costly 5" liner. By isolating the K-10 sands with surface casing, the lost circulation zone will not be exposed to high equivalent mud weights. RECEIVED J UN 2 4 199 Alaska 011 & Gas Cons. CommiSSiO" Anchorage Mr. R.A. L,u'f .... :ss December 2, 1992 Page 2 . . A higher or equal formation integrity test at the surface casing shoe will be obtained by setting surface casing deeper prior to drilling into the Kuparuk sands. Although past formation integrity test data has been acceptable, drilling into the Kuparuk interval will be safer with a higher surface casing shoe integrity. Information and experience gathered from previous Kuparuk development wells on 1Y pad indicate the West Sak and K-10 zones can be safely drilled using a diverter system on the conductor casing with a mud weight of 9.0 ppg. Although it is planned to drill the surface hole with a 10.0 ppg mud weight, there is no risk of lost circulation expected using mud weights as high as 11.0 ppg. In previous wells on 1Y pad, the West Sak and K-10 sands were drilled with a maximum 9.1 ppg mud weight. Thank you for your consideration of this request. ARCO can furnish any further information you may need. Contact Dan Stoltz at 263-4208 if anything else is necessary. Sincerely, R. F. Morgan~'~ Regional Drilling Engineer RFM/DSS/mac Attachment cc: A. W. McBridei 1Y Pad General Wellfile RECEIVED JUN 2 4 199, Alaska 0il & Gas Cons, G0mrn~ss~o~' Anchorage Well Yr 1Y-1 '83 1Y-2 '83 1Y-3 '83 1Y-4 '83 1Y-5 '83 1Y-6 '83 1Y-7 '83 1Y-8 '83 1Y-9 '83 1Y-10 '83 1Y-11 '83 1Y-12 '83 1Y-13 '83 1Y-14 '83 1 Y- 15 '83 1Y-16 '83 1Y-25 '88 1Y-26A '88 1Y-29 '88 1Y-32 '88 1Y-30 '88 DS-IY SHALLOW DATA SUMMARY Surface Casing Shoe above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu base West Sak base West Sak base West Sak base West Sak base West Sak West K-lO U(~nu Sak Sands Mudloq wet oil no no wet oil 4250-4280 TVD wet 30' no wet oil no no wet oil 4034-4038 TVD wet 4' no wet oil no no wet oil 3866-3893 TVD wet 27' no wet oil 3815-3832 TVD wet 17' no wet oil no no wet oil no no wet oil no no wet oil 3868-3870 TVD wet 2' no wet oil 3828-3831 TVD wet 3' no wet oil 3904-3914 wet 10' no 3990-4000 wet 10' wet oil no yes* wet oil no no wet oil no no no logs no logs no no no logs no logs no no no logs no logs no .. no no logs no logs no no no logs no logs 5577-5579 MD 2', wet no * 1Y-14 mudlog results: JTE-jiz/504 Ugnu sands W. Sak sands K-10 sands K-5 & below - C1 methane in net sand zones - probably from coals, up to 200 units - tr. brn oil stain - Oil-bearing 400-500 units, C1-C4 - no gas, no oil, no K-10 sands in this well -trace sand, local C1-C4 in shales above Kup beginnin~ C~-~3~)~/T~ir~?.00 units backc~round to top Kup KEL. E/V Eu J UN 2 4 199;5 Alaska 0il & Gas Cons. Commission Anchorage 1Y Generalized Well, Expected Drilling Results , ~ 1300' ~2500' ~2900' ~3300' ~3800' ~4950' ~5800' ~6200' JTE/JIZ-505 Sudace Base Permafrost T. Ugnu Sands T. West Sak Sands Wet. Trace oil. Methane (C1) up to 200 units of background gases from sands and/or coal beds Oil-bearing, Cl-C4, 400-500 units of background gas Base West Sak Sands K-10 Expect 0'-30' TVD of sands below K-10 marker. 1Y-14: mudlog, no K-10 sands, no oil, no gas K-5 Expect little to no gas K-5 to K-2 K-2 Expect up to 200 units of C1-C4 from shales between K-2 to Top Kuparuk. c3T. Kup Cl A B. Kup TD Expect oil & C1-C5 gas in mud I ECEIVED JUN ~ 4 1993 Alaska Oil & Gas Cons, Ijommissio, Anchorage KUPARUK RIVER UNIT HARRISON BAY STP OUKTOK PT SIMPSON LAGOON MILNE PT 3H 3A 3F 3C iR 2M 2A 2K 2G 2F lC Z *~' 1M 2D 1E JUN 2 4 199~ Alaska 0ii & Gas Cons. ijommisS~°" Anchorage , . . 10. 11. 12. 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-34 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,313')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. ; Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9,469') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED ,.I U N 2 4 t99 Alaska. 0il & Gas Cons. Cornrnissi0O Anchorage ARCO ALASKA, II C. Structure : Pad 1Y Well: 54 Field : Kuparuk River Unit Location : North Slope, Alaska .Created by : jones For: D STOLT'Z Dote plotted : 11-May-93 Plot Reference is 34 Version #2. :Coordinates are in feet reference slot #34. ~True Ve~ical Depths ore reference wellhead. INTEQ , 1050 2100_ 2~.~0. C~ - ~,~ 2800_ '-I--' . - - I V Sca,e ' ,50.00 E a S t - - > ~ 0 300 60,0gOO 1200 1500 lB(X)2100 2400 2700 3000 I I I I I I i I I I [ I I I I I I I i I I I I S 37.94 DEG E 6157' (TO TARGET) SURFACE LOCATION: 570' F'NL, 1822' FWL SEC. 1, Tl lN, RgE RKB ELEVATION: 10~' KOP WD--300 TMD--300 DEP=O 3.00 9.00 15.00 27.00 33.00 B/ PERMAFROST TVD-1406TMD-1480 OEP-353 39.OO 45.00 51'OOEoc TVD=1844 TMD=2098 DEP=785 T/ UGNU SNDS TVD-2616 TMD=,3409 OEP=lB45 r/ W .?~AK SND5 TVD-5006 TMD,=4071 OF_.P,-2381 MAXIMUM ANGLE 53.92 DEG B/ W SAK SND$ 1~=,54-46 'IlaD,,4-819 DEP=2985 9 5/8" CSG PT WD=3646 TMD=5158 DEP=3259 K-lO TVD--3876 TMD=5549 DEP=5575 TARGET ANGLE 40 DEG TA,~GET LOCATION: 146' FNL, 327' F'WL SEC. 7, TIIN, RIOE TARGET WD=5896 TMD=8~34 DEP-,6157 SOUTH 4856 EAST 3785 K-5 q%1:)=5006 TMD=,7468 0EP=5126 BEGIN ANGLE DROP 1'VD-5264 TMD=7906 DEP=5480 DROe 1.5 DEO / TARGET - T/ K'dP SNDS (EOD) TI/D--5896 TMD=8834 DEP=6157~ T/ ZONE A TVD=6113 TMD=9118 DEP=6339 B/ KUP SND$ TVD=6229 TMD=9269 DEP-,643 TD - 7" CSG PT '['V1)=638~- 1~=9469 DEP=6585 5250 ~ 5~3o~ 63~3 ~ 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 1 i i i i i i i i i i 350 0 350 700 1050 1400 1750 2100 2450 2800 31543 350~ 5850 4200 4550 490~ 5250 5600 5950 Scale 1: 175.00 Vertical Section on 142.06 azimuth with reference 0.00 N, 0.00 E from slot ~34 39o0 J i .I 4200 1200 4200 450O 5100 TO LOCATION: 468' F'N!_, 578' F'WL SEC. 7, T11N, RIOE 52.50 RECEIVED 43.50 40.50 --ka Oil & Gas Cons. .... ^nchorafla ARCO ALASKA, ] nc Structure · Pad 1Y Well · 31 / 34 Field · Kuporuk River Unit Location · North Slope, Alaska Scale 1 : 20,00 0 .. 0 120 320 52O 56O East --> 200 1 6O 120 8~ 40 0 4~ SO 120 1 ~:) 200 2~0 280 ,120~ 400 44~ 480 S20 $~0 6~0 320 280 120 \ ~,oo.,d -..,,,,,:, ,',':'~' REC[E]VED Alaska 0 520 2~ ~ ' I I i I i t I i i i -1 i i I i I I i i I' i i I i i i i i I I I I I i 2~ 1 ~ 120 ~ ~ 0 ~ ~ I ~ 1 ~ 2~ 2~ 2~ 320 ~ ~ ~ 4~ 520 5~ 0 I I V DRILLING FLUID PROGRAM Well 1Y-34 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~ 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to wei~lht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' 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 and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,158 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-34 is 1Y-07. As designed, the minimum distance between the two wells would be 24' @ 550' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. RECEIVED J UN ~ 4 199;5 Alaska 0il & Gas Cons. Anchorage Casing Design/Cement Calculations 24-Jun-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 1Y-34 6,313 ft 4,326 ft 5,158 ft 3,646 ft 9,469 ft 6,382 ft 4,071 ft 8,834 ft 5,896 ft 11.4 ppg ** See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,326 ft {(13.5*0.052)-0.11}*TVDshoe =1 2,561 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight Top of Target Zone, TVD 100 psi Overbalance 11.4 ppg 5,896 ft 3,495 psi 3395 psi] Surface lead: Surface tail: Top West Sak, TMD = 4,071 ft Design lead bottom 500 ft above the Top of West Sak = 3,571 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,118 cf Excess factor = 15% Cement volume required = 1,286 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 590 sx TMD shoe = 6,313 ft (surface TD - 500' above West Sak) * (Annulus area) = 859 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt - 894 cf Excess factor - 15% Cement volume required = 1,028 cf Yield for Class G cmt = 1.15 Cement volume~E~Eirequired Iv ._~.L)..,.. 890 sx JUN 2 4, 199. ..~iask~ 011 & Gas Cons. Anchorage Casing Design / Cement Calculations 24-Jun-93 Production tail: TMD = 9,469 fi Top of Target, TMD = 8,834 ft Want TOC 500' above top of target = 8,334 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 198 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 215 cf Excess factor = 15% Cement volume required = 248 cf Yield for Class G cmt = 1.23 Cement volume required =1 200 sxI TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=1.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =i Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength)= Desi n F~_cto[,--,,L Alask~ 0il & Gas Cons, Anchorage 564000 lb 6,313 ft 36.00 Ib/ft 227268.0 lb 33627.0 lb 193641.0 lb 639000 lb 6,313 ft 36.00 Ib/ft 227268.0 lb 33627.0 lb 193641.0 lb 3.3] 415000 lb 9,469 ft 26.00 Ib/ft 246194.0 lb 42329.6 lb 203864.4 lb 2.0] 490000 lb 9,469 ft 26.00 lb/ft 246194.0 lb 42329.6 lb 203864.4 lb 2.41 Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ BURST. Minimum Design Factor = 1.~'Et~EIVED Surface Casing: JU ,I 2 4 t995 Casing Rated For: Burst = Maximum surface pressure ~' ' Max Shut-in Pres = ~,la$~a Oil & Gas Cons. Oon~rnissio¢ Design Factor =l Anchorage Production Csg A: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 24-Jun-93 415000 lb 4,311 ft 26.00 Ib/ft 112086.0 lb 19271.6 lb 92814.4 lb 490000 lb 4,311 ft 26.00 Ib/ft 112086.0 lb 19271.6 lb 92814.4 lb 5,3J 3520 psi 2561.0 psi 1.4J 4980 psi 5661 psi 1687 psi 3974 psi 1.3J 4980 psi 7283 psi 2954 psi 4330 psi 1.21 2020 psi 0.593 Ib/ft 1628 psi 1.2J 4320 psi 0.593 Ib/ft 2161 psi 2.0J 4320 psi 0.593 Ib/ft 3783 psi 1.1J Casing Design / Cement Calculations 24-Jun-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength 1161000 lb 979000 lb 639000 lb 931000 lb Body Strength 1086000 lb 916000 lb 564000 lb 715OO0 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength 667OOO lb 490000 lb Body Strength 604000 lb 415000 lb Collapse 5410 psi 4320 psi Burst 7240 psi 4980 psi REEE]VED J U N 2 ~ t99;~ Naska 0il & gas Cons. 0ommissio' Anchorage RIVER UN~ ~ JPARUK 21-1/4" DIVERTER SCHEMATIC 6 ~ 4 5 3 I DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL Of THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER ~-~ECEIVED ,I U N ?_ 4 t995 · ~Jaska Oil & Gas Cons. uumrntsslu Anchorage EDF 3/10/92 13 5/8" 5000 , $1 BOP STACK 7 , 6 5 4 II ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ~ OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE, BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7, TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH, TEST AS IN STEP 4, DO NOT PRESSURE TEST ANY & CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO3-FOM PIPE RAMS, TEST BO~-FOM 9. RAMS TO 250 PSI AND 3000 PSI, OPEN PIPE RAMS, BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11, AND 12_ UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 11' - 30(X) PS~ X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 13-5/8' -5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES ~ 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13~J/8' - 5000 PSI ANNULAR RECEJVF D d UN 2' 4 199 0il & Ga9,0ons. Comm~ssio~ Anchorage SRE 8/22/89 General Purpose W__?rksheet L OI RECF~V?r~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-o36V Telephone 907-276-1215 ?iO, :j ~U." June 23,1998 Mr, D. W. Johnston Chairman o~. Commission State ef Alaska Alaska Oil & Gms Con~ation Commi~,.~ir~n 3001 Porcupine Drive Anchorag¢., Ala.~ka 99501 Dear Mr, Johnston: SUBJECT: Revised Surface Casing Setting Depths Kuparuk River Field Pad 1 Y This is a request for approval to vary from the exlstln~ Kuparuk River Field Rules, Conservation Order No. 173, to permit surface Casing to be set as deep as 4,440' TVD RrB in thrill wells on pad 1Y, which is an exi~l, in9 K,.'paruk pad. This request references Oonsgrvatior~ Order No. 190, Rule 3 which states a variance may be granted by Administrative ~ul. ion for the m~ximum surf~oe casing setting dc, pth, This depth will be below the West Sak and K-10 sands. In previous disc~dssions with you and your staff, which resulted in the establishment of Conservation Orders No. 203 and No. 209, ARCO Alask~ Ina, established a standard operating procedure of settfng surface casing at least 200' -I'VD below the b~$e of the West ,.C, ak sands. This rc. cllJ~,~t is for variance to set the surface casing 150' TVD below the K-!0 s~nds on 1Y pad. Attached is a diagrsm depicting ~ generalized w~lt profile on 1Y Cad. Aisc attached is a data sheet summarizing the thicknesses and contents of the shallow sands in previously wells drilled nn 1Y pad, In reviewing our geological structure maps, it is estimated that for the 1Y Pad, the base of the K-10 sands will occur at a maximum depth of 4,290' TVD, A surface casin.q del~th of 4.440' TVD would ensure that the West SAk and K.10 sands wouid be isolated by the surface casing cement, A c~py cf ARCO's present Unit Deveiopmen1 $~tus Map showing the location of the 1Y pad with respe¢ to the existing development of the CPF-1, CPF-2, and CPF-3 areas is attached. Specific reasons for requesting s de~por ~u.,'face casing setting depth are: It Is prefe[~[iai to set th~ sud, ace casing at least to a depth of 4,440' TVD RrB which will be below the K-10 sands a minimum of 150' TVD. !t is believed thst the K-t0 s~nd~ arc a Io~t circulation zone while drilling with the mud weights of greater th~n 11.7 ppg required to control the Kuparuk ,~,servoir pressure. This Io.~t nirculation zone has been the c~use of-[op setting the Kup~ruk sands and completing the welt with a costly ,~" liner. By isolatin~ the K-10 sands with surface casing, the lost cimulation zone will not be exposed to high ~quivaJent mud weiChta -.. Mr. R. A. L .,gl~so December 2, 1992 Page 2 ~', 0/0 . A higher or squsi formation integrity tc~t at tho surface casing shoe will be obtained by setting sudace casing deeper prior to drilling into the Kuparuk ~.~ nde. Although past formation integrity test data has been s¢ceptable, drilling into the Kuparuk interval will be safer with a higher surface casing sh~ integrity. lnfnrm~tir~n and experience gathered from previous KuParuk development wells on 1Y pad indicate the West Sak and K-'I 0 zones can be safely drilled using a cliverter system on the conductor casing with a mud weight of 9.0 ppg, Although it is planned to drill the surface hole with 10.0 pP.q mud weight, there is no risk of lost circulation expected using mud weights as high as 11.0 ppg. In previous wells on 1Y pa, d, the West Sak and K-10 sands were drilled with a maximum 9.1 ppg mud weight. Tha, nk you tot your consideration of this request. ARGO can furnish any furtl~ur information you may need. Contact Dan Stoltz at 263-4208 if anything else is necessary. Sincerely, R. F. Morgan Regional Driiling EngineEr RFM/DSS/mac Affachment co: A, W. McBri(Jei 1Y Pad General Wellfile JUN 4 ]9.93 1Y-1 '83 1Y-2 '83 1Y-3 '63 1Y-4 '83 1Y-5 '83 1Y-6 '83 1Y-7 '83 ~¥-8 '83 tY-g '83 IY-IO '83 1Y. 11 '83 1¥-12 '83 t¥-13 '83 1Y-14 '83 1¥-15 '83 1Y-16 '83 1Y-25 '88 1¥-26A '88 1¥-~.9 '88 1¥-32 '88 1¥-30 '88 D ~' 1Y-14 mLidlOg results: ECEIVE ? U~_~i.'z ~ g93 DS-1Y SHALLOW D_~TA SUM~ Surface Casing West K-10 ~ ~ ~ ~ Mudlog above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu above Ugnu base West Sag' base West Sak base West Sak base West Sak base West Sak wet oil rio no wet oil 4250-4280 TYD wet 3D' no wet oit no no wet oil 4034-4038 TVD wet 4' no wet oil no no wet oil 3866-3893 TVD wet 27' no wet oil 3815-3832 'I'VD wet 17' no wet oil no no wet oil no no wet oil no no wet oil 3865-3870 TVD wet 2' no wet oil 3828-3831 TVD wet 3' no wet oil 39043914 wet 10' no 3960-4000 we1 1 O' wet oil no yes* wet oil no no wet oil no no no logs no logs no no no logs no logs no no no logs no logs no no no togs no logs no no no logs no togs 5577-5579 MD 2', wet no UOnu sands W. Sak sands K-10 sands K-5 & below - C1 methane in net sand'zones- probably from coals, up to 200 ur~'~s~ - tr. brn oil stain - Oil-bearing 400-500 units, Cl -C4 - no gas, no oil, no !(-10 sands in this well - trace sand, local Cl -C4 in shales above Kup beginning 600'-700', max 200 units backgmu_nd to top Kup .... _ ~':, ~- ii<LO _ . 1Y Generalized Well I! Ex_ _peered DrBlinqResplts o' , ,, Surface --2500' ~2900' -3800' *,4950' ",5800' -6200' JTE~J~Z-505 Base Permafrost T, Ugnu Sands T. West Sak Sands Base West Sak Sands K-lO K-5 K-2 c~T. Kup II I II Wet. Trace oli, Methane (C1) up to 200 units of ta~kgrouncl gases from san(ts ancot coal Oil.bearing, C1-C4, 400-500 units of backgrouncl gas Expect 0'-30' TVD of sands below K-10 marker. 1Y-14: mudlog, ,no K-tO sands, no oil, no gas Expe~'t lit'tie to no gas K.5 to K-2 Expeot up m 200 units of C1-C4 from shales between K-2 to Top KupanJk. Expect oil & C1-C,5 gas in muO RECE!VFh JUN 2 4 ]993 Alaska 0il & G,~..~ Cons_ ~.;o~;,ms~:,{::, I I-- I[- i 'O~P!~ /'i o, ,j/¥ i i", 0.. 0 KUPARUK RIVER UNIT STP OLIK'rO~C Irt SIMPSON I..4GOON MILNE PT ~/ARRfSON BAY SH 3A 2U 2M 2K 2G :iN 3K aC 2D iR 1I: 1J tC kl_ Alaska ITEM (1) Fee (2) Loc , , , ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru 8] (3) Admin [8~1. thru 13] [10 & 13] [14 thru 22]" [23 thru 28] Company 4'/'~-' ~o Lease & Well ~ YES NO (5) BOPE (6) Other [29 thru 31] (7) Contact [32] 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line .................. : 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. (8) Addl geology' engineer lng:- D~ MTM RADS) ~,-'2..-~ RPC~ BEW~,~ dDH...~ /::>/~.. ~ TAB rev 6/93 jo/6.011 16. 17. 18. 19. 20. 21. 22 23. 24. 25. 26. 27. 28. ,? Does operator have a bond in force .................................. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & n~rnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. ,~---~,- Is adequate well bore separation proposed ............................. 29. 30. 31. 32. 33. Is a diverter system required ........................................ _~ Is drilling fluid program schematic & list of equipment adequate ..... .~' Are necessary diagrams & descriptions of diverter & BOPE attached .... ,~- Does BOPE have sufficient pressure rating -- test to ~Z~ psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE REMARKS 0 ~-~0 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 14, 1993 A W McBride, Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 1Y-34 ARCO Alaska Inc 93-91 570'FNL, 1822'FWL, Sec 1, T11N, R9E, UM 468'FNL, 578'FWL, Sec 7, T11N, R10E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W Johnston ~ ~ Chairman '~~ · BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ?--- STATE OF ALASKA Al_AL , OILAND GAS CONSERVATION COMMIS~ ,~1 PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll [~ lb Type of Well Exploratory r-~ Stratigraphic Test n Development Oil X Re-Entry E~] Deepen r~ Service [~] OevelopmentGas [~] Single Zone r"] Multiple Zone X 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 106', Pad 65' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25647, ALK 465 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 570' FNL,1822' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 146' FNL, 327' FWL, Sec. 7, T11N, R10E, UM 1Y-34 #U-630610 At total depth '- 9. Approximate spud date Amount 468' FNL, 578' FWL, Sec. 7, T11N, R10E, UM 6/1 2/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 1WD) property line 1Y-07 9,469' MD 578' @ TD feet 24' @ 550' MD feet 2469 6,382' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O ,sAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 53.92° Maxirnurnsurface 2,158 psig At total depth (TVD) 3,395 psig 18. Casing program Settin~l Depth size Specifications To~ Bottom Quantit~ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD /include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 5,117' 41' 41' 5~158' 3r646' 590 Sx Permafrost E & HF-ERW 530 Sx Class G 8.5" 7" 26.0# J-55 BTCMOC 5,117' 41' 41' 5,158' 3,646' HF-ERW 8.5" 7" 26.0# J-55 BTC 4,311' 5,158' 3,646' 9,469' 6,382' 200SxClassG HF. ERW Top 500' above Kuparuk 1 9. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth StructuraIconductor ~;.il '~'~ i;~;~ ? i "'~ ~; i~~,~; ~.~;: ~/,-! i: Intermediate Production Liner ~._!i i 'i' Perforation depth: measured.:~ i~ ~I¥.-'~..~,~. :~_, r~.,., ~ ,;.~. ...,~-' ~.~i.; ~;0?~S~ f;~ ~iTt true vertical ?~ 20. Attachments Filing fee X Property plat ~] BOPSketch X Diverter Sketch X Ddlling program X Ddlling fluid program X Time vs depth plot [~ Refraction analysis ~] Seabed report [~ 20 AAC 25,050 requirements X 21, I hereby certih/that the foregoing is true ancl correct to the best of my knowledge Signed ~~"~ ~-.~ ,/~ Title Area Drilling] En~lineer Date / ~ Commission Use Only/ Permit...N, umberI AP, number I Approve' date I ~°~*°v°~'°"~'or ~.,~" ~/ 50- O2.~- Z_2_. 3 ~'2_- other requirements Conditions of approval Samples required ~] Yes ~ No Mud log required ~] Yes J~ No Hydrogen sulfide measures [~] Yes .~ No Directional survey required ,[~ Yes [~ No , Required working pressure forBOPE ~ 2M ~ 3M I--~ 5M I-1 10M E~] 15M.~,_ ~,.: Other: '~)r~.~ina! c;oned By , -' i;.~avid W. johnston by order of Approved b:~ Commissioner the commission Date Fnrm 113-41'11 Rnv 7-D4-R.(:i iCreated by : jones For: D STOLTZ iDote plotted : 11-May-95 iPIot Reference is 54- Version #2. iCoordino(es are in feet reference slot #34. iTrue Yer~ical Depths are reference wellhead. INTEQ ALPC0 ALASKA, Structure : Pad 1Y Well : 34 Field : Kuparuk River Unit Location : North Slope, Alaska Scale, :150.00 E a st -- > 5000 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 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 S 37.94 DEG E 6157' (TO TARGET) 3500 I I 3900 SURFACE LOCATION: 570' FNL, 1822' FWL SEC. 1, T11N, R9E I I V 0 350 700 1050 _ 1400_ _ 1750_ _ 2100_ 2450 2800 _ 3150_ _ 3500_ _ 3850_ _ 4200 _ _ 4550_ _ 4900_ _ 5250_ _ 5600_ _ 5950_ _ 6300_ 6650 I I I I I I I I 350 0 350 700 1050 Scole1 : 175.00 RKB ELEVATION: 106' KOP TVD=300 TMD=300 DEP=0 3.00 9.00 15.00 BUILD 3 OEO / 100' 21,00 27.00 55.00 B/ PERMAFROST 'fVD=1406 TMD=1480 DEP=353 59,00 45.00 51.00 EOC TVD=1844 TMD=2098 DEP=785 T/ UGNU SNDS TVD=2616 TMD=5409 DEP=1845 T/ W SAK SNDS 'FVD=3006 TMD=4071 DEP=2381 MAXIMUM ANGLE 53.92 DEG B/ W SAK SNDS TVD=3446TMD=4819 DEP=2985 9 5/8" CSG PT WD=3646 TMD=5158 DEP=3259 K--lO TVD=3876 TMD=5549 DEP=3575 TARGET ANGLE 40 DEG ITARGET LOCATION: 146' FNL, 327' FWL SEC. 7, Tl lN, R10E 17150 I TARGET TVD=5896 TMD=8834 DEP=6157 SOUTH 4856 EAST 5785 K-5 TVD=5006 TMD=7468 DEP=5126 BEGIN ANGLE DROP TVD=5264 TMD:7906 DEP:5480 DROP 1.5 DEG / 100' TARGET - T/ KUP SNDS (EOD) TVD=5896 TMD=8834 DEP=615? T/ ZONE A TVD=6113 TMD=9118 DEP=6339 B/ KUP SNDS TVD=6229 TMD=9269 DEP=6431 TD - 7" CSG PT TVI)=838~ TMD=9469 DEP=6585 4200 _ 300 ~-~ o _ oo _ 600 _ 900 _ _1200 1500 1800 _ _2100 O - _2400 - D-- _2700 - I I - _3300V . .3600 · .3900 4200 4500 _ _4800 _ _5100 5400 ITD LOCATION: I 468' FNL, 578' FWL SEC. 7, T11N. RIOE 52.50 49.50 46.50 43.50 40.50 I I I I I I I I I I I I I Vedical Section on 142.06 azimuth with reference 0.00 N, 0.00 E from slot #34 j t.i N '-- Y 19uJ~ Uii & Gas O0ns, O0fflrfCs~,u gnchm'ago ARCO A ASKA Structure · Pad 1Y Well · 51/ 54 Field · Kuparuk River Unit Location · North Slope, Alaska Scale 1 : 20.00 8 320 _ - .. 280 _ 240 120 120 160 200 Easf --> 200 160 120 80 40 0 40 80 120 160 200 240 280 320 .360 400 440 480 520 560 600 IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII 1100 pROPOSED 1700 270C 310 gO0 1300 190C _ 320 _ _ 280 " ' 240 100 300 -- 200 1300 :~,. - - 1900 _ ~0_ - - ~700 5~0 _ 200 J I 240 V I I0I 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 200 160 120 80 40 0 4 80 120 160 200 240 280 320 360 400 44-0 480 520 560 600 Scale 1 : 20.00 Eo sf - - > 80 120 160 ~-- 280 320 36O 4O0 440 480 _ - 520 - _ 56D 600 _ 640 680 , , , 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-34 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,158')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9,469') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1Y-34 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Dril ling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,158 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-34 is 1Y-07. As designed, the minimum distance between the two wells would be 24' @ 550' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. Casing Design ! Cement Calculations 26-May-93 Well Number:' ' 1Y-34 .......... Surface Csg MD: 5,158 ft Surface Csg TVD: 3,646 ff Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: -. Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice- Production Csg A Choice · Production Csg B Choice' Production Casing Frac. Pressure 5,158 ft 3,646 ft 9,469 ft 6,382 ft. 4,071 ft 8,834 ft 5,896 ft 11.4 ppg ~ ........ ~ ......................... For Cas~n Choices 3,500 ps~ Maximum anticipated surface pressure TVD surface shoe = 3,646 ft {(13.5'0.052)-0.11 }*TVDshoe =1 2,158 psiI Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =[ 11.4 ppg 5,896 ft 3,495 psi 3395 psi! Surface lead: Top West Sak, TMD = 4,071 ft Design lead bottom 500 ft above the Top of West Sak = 3,571 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,118 cf Excess factor = 15% Cement volume required = 1,286 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 590 sxJ Surface tail: TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required = 5,158 ft = 497 cf = 80 ft = 0.4340 cf/If = 35 cf = 532 cf = 15% = 612 cf = 1.15 =1 530 sxl Casing Design/Cement Calculations 26-May-93 Production tail: TMD = Top of Target, TMD = Want TOC 500' above top of target = Annulus area (9" Hole) = (TD-TOC)*Annulus area = Length of cmt wanted in csg = Internal csg volume = Cmt required in casing = Total cmt = Excess factor = Cement volume required = Yield for Class G cmt = Cement volume required =[ 9,469 fi 8,834 ft 8,334 ft 0.1745 198 cf 80 fi 0.2148 17 cf 215 cf 15% 248 cf 1.23 200 sxJ TENSION - Minimum Design Factors are: T(=b)=l.5 and T(j$)=I.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 564000 lb 5,158 ft 36.00 Ib/ft 185688.0 lb 27474.7 lb 158213.3 lb 3.61 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 5,158 ft 36.00 Ib/ft 185688.0 lb 27474.7 lb 158213.3 lb 4.01 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 415000 lb 9,469 ft 26.00 Ib/ft 246194.0 lb 42329.6 lb 203864.4 lb Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 49OO0O lb 9,469 ft 26.00 Ib/ft 246194.0 lb 42329.6 lb 203864.4 lb Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ff)- Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ BURST- Minimum Desi_en Factor =1.1. Surface Casing: -- i!~- ii-"? !"'~ i ¥ ~-' !i"'i~ Casing Rated For: Burst = Maximum surface pressure Max Shut-in Pres = ~,,~, Design Factor =[ Production Csg A: ~\.i~;sk~ 0il ~ ~i~ ~:;o::s. ~::0~:~i~si;~Casing Rated For: 1. Design Case - Tubing leak while well iS~Slhor~.!,!,~ Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.gppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Inside pressure Outside Pressure Net Pressure Design Factor Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Deslan Factor = 1.0 -- Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000q'VD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =l Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 26-May-93 415000 lb 4,311 fi 26.00 lb/fi 112086.0 lb 19271.6 lb 92814.4 lb 4.5] 490000 lb 4,311 fi 26.00 Ib/ft 112086.0 lb 19271.6 lb 92814.4 lb 3520 psi 2158.4 psi 1 .Si 4980 psi 5661 psi 1687 psi 3974 psi 1.3J 4980 psi 7283 psi 2954 psi 4330 psi 1.21 2020 psi 0.593 Ib/ft 1225 psi 1.6J 4320 psi 0.593 Ib/ft 2161 psi 2.01 4320 psi 0.593 Ib/ft 3783 psi 1.11 Casing Design / Cement Calculations 26-May-93 Surface Casing Choices OD ID I blft Grade I 9,625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10.750 9.950 45.5 J-55 Metal X-Section 13.5724 sq. in. 11.4538 sq. in. 10.2545 sq~ in. 13.0062 sq.'in. Jt Strength 1161O00 lb 979OOO lb 639000 lb 931OOO lb Body Stmngth 1086000 lb 916000 lb 564000 lb 715000 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Bumt 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID I blft Grade I 7.000 6.276 26 L-80 2 7.000 6.276 26 J-55 Metal X-Section Jt Strength 7.5491 sq. in. 667000 lb 7.5491 sq. in. 490000 lb Body Strsngth 604000 lb 415000 lb Collapse 5410 psi 4320 psi Bumt 7240 psi 4980 psi KdPARUK RIVER UNI3' 21-1/4" DIVERTER SCHEMATIC 5 6 4 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. . 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 , 6 5 13 5/8" 5000 PS1 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR Al~sk~ Oi[& Gas Coi-ts. Corltto~o · SRE 8/22/89 State: Alaska Borough: 'Well: 1Y-34 Field: Kuparuk River st. Perm # 93-91 1Y-34.XL$ Date 6/10193 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 9.625 3646 41 5117 2.A. 7 6382 41 9428 8A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Descriptior, Description Tension Lbs Grade Thread Lbs $6 J-55 BTC 0 26 J-55 TC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/it psi/ft 9.6 0.499 0.399 11.4 0.593 0.493 0.0 0.000 -0.100 0.0 0.000 -0.100 0,0 0.000 -0.1 O0 0.0 0.000 -0.100 0.0 0.000 -0.1 O0 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2158 3520 1.6 2158 4980 2.3 0 0 #DIV/0! 0 0 #DIV/OI o o #DIV/O! 0 0 #DIV/0! 0 0 # DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! Tension Strength K/Lbs lC 184.212 2C 245.128 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 564 3.OB 415 1.69 0 #DIV/O! 0 #DR//O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 1455 3145 0 0 0 0 0 0 0 0 Resist. CDF 2020 1.388 432O 1.374 0 #DR/10i 0 #DIV/O! 0 #DR//O! 0 #DIV/O! o #DR/lO! 0 #DIV/O! 0 #DR/10! 0 #DIV/O! 1Y-34CMT.XLS State: Well: Field: State Permit 1Y-$4 Kuparuk River 93-91 Work Sheet: Date: £~men! ~ /ol~,,me £81culation.¢ Casing Type Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks 111 Cement- Yield 111 Cement- Cubic ft 111 Cement- Cubic it 111 Cement- Sacks 112 Cement-Yield112 Cement- Cubic ft 1:12 Cement-Cubic tt 112 Cement- Sacks 113 Cement-Yield113 Cement- CUbic tt 113 Cement- Cubic It 113 Cement- Cubic ft / Vol Cement- Fill Factor Conductor 16.000 80.000 24.008 0.000 0.008 0.000 208.000 0.080 0.000 0.000 0.000 200.000 1.432 Surface 9.625 5,117.000 12.250 590.000 2.170 1,280.300 1 280.300 530.000 1.150 609.500 609.500 0.000 0.000 0.000 0.000 1,889.800 1.179 Line[ 0.000 0.000 0.000 0.000 0.000 O. OOO 0.008 0.000 0.000 0.000 0.000 0.000 ~DIV/0! Casing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks 111 Cement- Yield 111 Cement- Cubic It ~1 Cement- Cubic fl 111 Cement- Sacks 112 Cement-Yield112 Cement- Cubic ft 112 Cement- Cubic ft :ii2 Cement- Sacks 113 Cement-Yield113 Cement- Cubic It 113 Cemrent- Cubic ft :113 Cement- Cubic ft / Vol Cement-Interval ft Top of Cement- Feet Intermediate :I:M 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.08 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0!. I~DIV/O! Intermediate 112 0.000 0.000 0.000 0.08 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! I~DIV/O! Production 7.000 9,469.000 8.500 200.00 1.23 246.00 246.00 0.00 0.00 0.00 0.00 0.00 0.00 0.08 0.00 246.00 1,939.96 7,529.0 Measured Depl'h ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [ 2 thru (3) Admin ~ C_j-'~,,/~t 13] '~ [10 $ 13] [14 thru 22] [23 thru 28] . 2. 3. 4. 5. 6. 7. 8. e ' 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES Is permit fee attached ............................................... ~__ Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... ~ Is well located proper distance from other wells ..................... /~ Lease & Well NO Is sufficient undedicated acreage available in this pool ............. L Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. /~ Can permit be approved before 15-day wait ............................ ~. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease number appropriate .......................................... Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ............... . ......................... Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ,%~OO~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Ot he r ~/_~ ~//~//~ '1~'29 thru 3:~] (7) Contact (8) Addl geology' encjineer ing: RP~ BEW JDI-LF: ~,,,~,-~ ~ TA~ -- rev 6/93 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM MERIDIAN' SM WELL TYPE' Exp/Dev Inj Redrill Rev 0 ,-4 -rz ~-.., 0 f,.,n -,..-I rtl g 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 simp!ify 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. ~-- ss57 ALASKA COMPUTING CENTER CQ~PANY NAMe; : ARCO ALASKA INC. WELL h~A~E : lY-34 FIELD NA~E ~ KUPARUh. BUROUGN STATE APl NUMBER : 50-029-22382-00 I ICi OFILMED Tare Ver~..ficatiom Llsttnq ;cblumberoer AlasKa Computino ceDter 12-aUG-1993 14:10 **** REEL NEADMR **** [>ATE OPICIM : FLIC PFEVIOU$ REEL C~M~E~T : ARCO AbASK~ I~!C.,~UPARUK,1Y'34,50-029-2~382-00 DATF : 93108/12 OPlCIN : FLIC TAP~ N~E : 93301 CO~T'INI;ATI[]N ~ : 1. PR~VIOUS T~PE CO~ES!T : ~RCO AbA$~.A INC.,KUPARUF.,!Y-34,50-0~9-22382-00 PPUDHOE BAY UNIT AP! NUMBER: bOGGING COMPANY: TaPE CREATION DAT~: JO8 DATA SURFACE LOCATION SECTION: T~W~JSHIP: FSL: FEL: EI_,EV~TIQN(F~ FRO~ ESL O) ~ELLY BUMMING: DE~RICK GROineD W~'L[.. C~SING RECORO IST ST¢ING !Y-34 500292238200 ~ 2-~.UG-93 RU~ t STQLTZ/CHIVV 1 570 !822 107 1~7i00 65 O0 9P~U NO[,E CgSING D~ILLFPS BIT SIZE (I~) SIZE (I5) DEPT~ (FT) 6.!25 7,000 8633,0 PAGE~ ~I$ Tare Verification !.,istlng ~chlum~erger .Alaska ComputlnO Center .~RD &TR!NG PRODUCTION STRING LIS ~OR~aT D~TA FIL~: NA~E : EDIT ,001 SKRVICE : FL!C VFR~IO~ : O01CO! D ~.TF. : 9]108112 k~tX REC $IZM : 4096 FIL~: TYPE : bO I~8T KIbE : i2-~0G-I99~ I4:10 PAGE: 2 ~],1 tOOl strings; Cl~.pped curves~ no cased hole data, [)KPTH ! hJCRE~.~gNT: 0.5000 FIbE V'E~:DOR TOOL, CODF 8TART D~PTH STOP DEPTH OTK ~636,0 SDN 9B~7.0 ~636,0 C~TG g~97,0 8636,0 GR 9285,0 8504.0 BASFLI:iE CURV~ FOR SHIFTS: C~IRVE SHIFT DATA (~gASURED DEPTH) B ASE!.~I ~g DEPTH ~O0.O 100,0 I,~ERGED O~TA SOURCE P~3i] TOOL C~DE RiJN Nt~. PaSS b:O, MERGE F, EF,~RKSt Nfl OE~'rH ADJUST~Et,:'PS ~:~[7: RKOUIRFD AS ONLY ONE TOOL STRING wt~8 LOGGFD, bJS FOR~.~AT DATA .......... Ei_~!jIVALE~..:T U~!SHIFTED DEPTH .......... ~ERGE ~ASE ~IS TaDe Yerification b. istinq ;cblu~berc]er AlasKa ComDu. tinq Center' I2-AUG-!.993 14:10 PAGE{ ** DATh ~'OR~AT SPMCIFICATION RLC_~D ** ** SET TYPE TYPE ~ .... [) E ALUE . 2 66 0 ] 73 104 4. 66 5 66 6 73 7 65 8 68 0,5 9 65 MT !l 66 13 66 0 1.4 65 FT 15 66 6~ 16 66 0 66 0 ** SET "Y - N~MFf SE~V UNIT SERVICE API ~PI ~PI ~PI wILE MUM~ MUMB SiZE REP~ P. OCE$8 !D ORDER # LOG TYPE Chi. SS ~<~D NUMB SA~P EbEM CODE (HEX) .... FT 5994 O0 0 I 1 ~ 0000000000 IDPP DTF OH~q~' 599472 00 000 00 0 1 1 1 4 68 I~?'pU DTE O~..M~ 599472 O0 000 O0 0 i 1 1 4 68 ILO DTE f3~~ 599472 O0 000 O0 0 1 i 1 4 68 !5~ UTE O~t~ ~, 599472 O0 000 O0 0 1 ! t 4 68 S~L, DTE 599,472 00 000 00 0 1 1 ! 4 68 8~ UT~? ~a!t 599472 O0 000 O0 0 1 1 I 4 68 ~ DTF G~Pl 599472 00 000 O0 <) 1 t 1 4 68 ~ .... ,~,S b~ 0477 0~ 000 O0 1. 1 I 4 68 T~' ~,~9 UTE bB 590472 O0 00o O0 o 1 1 !. 4 68 ~!T57~z 9T~ DEGF 599472 O0 000 O0 O 1 1 1. 4 68 ~b?$ DTE CH~q~ 599472 O0 090 OV ;.; 1 1 I 4 68 r~t)~ Sr)~~ G/C3 599472 00 000 ~:<'.) e 1 1 ! 4 6~ [)~'~qO S[;~ G/C3 ~90472 O0 0O0 (:9 9 1 ! 1 4 68 PF? SD~J BH/E 59947~ 0O 0O0 f~(' i.~ i l 1 4 68 CtL1 S 12 t,~ I~: 599i7~ O0 000 c)~ 0 1 1 ~ 4 68 E~,'R ~ C'~G 599472 O0 OOC ')~ ~ ! 1 1 4 68 CFwC C~qTG CPS 59947~ O0 mO0 ')0 0 ! ~ ~ 4 69 CUEC CNTG CPS 59947~ O0 OO0 00 c; 1 1 1 4 68 NPNT C;,;TG P!.)-S 599472 O0 OOO O0 O 1 I I 4 68 ~A? CNTG 599472 O0 000 O0 9 I 1 1 4 68 CPar CNT(; ~9q472 O0 000 O0 0 1 1. ! 4 68 :~CN* . OO n ~ ?' . , CCTG CPS 599472 O0 .0 O,~ I., ! ~ ~ 4 68 FC~T C?.., CG CPS 59947~ nO OOO O0 0 i ! 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O090000000 0000000000 0000000000 0000000000 0000000000 Verification Lj. stlng ;chlumber~er Alaska Com,)uti. n6 Center 12-AUG-~993 14:10 PAGE: 1,~a~,~ SgRV UNIT SERV!,~E AP') API API .aPT FILE NUM~5 NUmB SIZE REPR P OCESS ID DRDER ~ bOG TYPE CLASS 'MOD NUMB Ca~TC CNTG CPS 599~720040000 O0 O0 0 ~ ! ,, g ...... () 0 0 .. CFTC C~:'TG (P~ 599472 O0 000 I 1 1 4 68 0000000000 * * D A T A * * DEPT. 9,340.000 IDPM.DTE 2.569 I ~,~,PH , DTE 21.603 ILD.DTE IL~,DTE ~,582 SFb,DTE 2,956 SP,DTE -2~'500 GR,DTE TF~S, DT~ 5240,000 TS~'. N'[) , [>TE 964.3ql MTE~,DTE 150,620 MRES,DTE RNOB.SDN -999.250 DR~{').SDN -999,250 PEF,SDN -999,:250 CALl ENRA,CNTG -999,250 C~"EC,CNTG -999,250 CNEC'CNTG -999,250 NPHI.CNTG N~AT,CNTG -999,250 CRAT, ~3NTG -999,250 NCNT, C~TG -999,250 FCNT,CNTG . . ~. ....... m ,. · '~ ~ ~ ' .~ ~ ~ C~"C,CNTG 99~ 250 C~TC CN~..G -~99250 D~P'F 9000,000 IDPH.D~r~ 2,~55 IMPM,DTE 2,457 ILD'DTF. Ibrd': DTF 2,542 $~"b. DTS] 2,384 SP,DTE -25,313 GR,DTE T~NS..DT~]. 50~0.00(') T~N''~E:.O.DTF 1028.76~ MTE~.DTE 146.319 MRES.DTE RWOR,SDN 2,344 DRHO S~N 0,090 PEF,SDN 15,396 CAL~..SDN E~R~ ,CNTG ~,51! .~.~ EC 747. 95 CNF.' ,CN?~ ! EC CNTG 3370631 NPHI CNTG ~ N ~1'~ NmAT,CNTG 3.~29 CRAT,.~ ~.:~= 3,~03 NC.~'.~, C~TG 2~47:~.84 FCNT,CNTG C~TC, C~TG 2308,950 CFTC,CNTG 7L)6,902 D~PT, '~ 8504.000 IDPH,[)Tg -99g.250 I~pN,DTg -g99,250 iLD DTE ~[.~.P~.. -999'250 ~FL,DTE -999,250 SP,DTE -999,250 GR~DTE TF~.)$.D~E -999.250 TEND.DTE -999.~50 MTE,,DTE -999250 MRES,DTE R~,SDU. .. _ .~ -99~. o250. DRFO,SDI~!. . -~99... . .250 PEF,$DN -999:250 CALI.SDN ~AT,CNTG -999.250 CRA~.CN.TG -~9,250 NCNT.CNTG -999~250 FCNT,CNTG CNTC.CNTG -999,250 CFTC,CNTG -99.250 ** ~ND OF DATA , 2,558 99g,250 0.70! :999,2~0 999~:250 -999,~50 93 ! 042 6190 4059 659 -999,250 81,243 -999'250999,250999"250 999'~50 **** FILE TRAILER FILE NA~E : RDIT ,001 V~R$!ON : O01COI DATF : ~× R~C SIZ~ : 4096 FIL~ TYPE : bO L~ST F!~,E ~,IS Tape Ver!f~catJon Listing ;chlumberoer AlasKa Comr~utID0 Center **** FILE HEADER **** FIL~ ~A~E : EDIT S~R¥ICE : FbIC VFRSION : OOICOi [.~A T~ : 93108112 F,~AX R:~C SIZE : 4096 F!bF TYPE : LO I., ~ ST FILE i2-~UG-I993 14:t0 PAGE: 5 Curves and 1oo hea~er data for each run and too!, str],n~ in separate f~]es; Tool itrin~ #! ~o Sadleroch!t ru~ presented ~irst (primary ~eptn control string' used to depth shi~t ~the Sadler interval) (aligned DF ~iles ~or other main pass tool strings per run. RUS NUMBER: ! DMPTH IWCRE~ENT: -.5000 VENDOR TOOL CODE START DEPTH LOT 9368.5 CNL 936~.5 LOG H~A. DER DAT~ DATE LOGGED: $OFT~ARE VERSIQ~: TI~M CIRCULATION MMDED: T!~E LOGGEP O~ SOTTO~: mD DRILLER CRT): TD LOGGE~(FT): TOP LUG !NTEPVAL BOTTO~ [.,~G INTERVAL LOGGI~G SPEED STOP DEPTH 8493,0 8493,0 ~493o0 TOC}L ST~ISG (Tt)P TO gOTT[I~) VEt~DUR TOO[, CODE TOOL TYPE mmmmmm~m~mmm~mmm C~TG ~U T DITE S mm~mmmmmm ~UXIbIAP¥ ~EAS, TELE~iET~Y CARTRIDGE RAY CO~PENSATED NEURON L!T~O-DM~iSITY !~IDUCTION 5C0-423 ~73o 9-JUL-93 708 lO-JUL-92 9354.0 9349.0 8365.0 9340.0 TC)OL NUMBER TCC-B-281 SGT-L-50 C{~T-G-65 LOT-D-51 D!T-M-~79 6,!25 ~IS Ta~e Verification !~isting ;chlumberuer Alaska Computing Center 12 '{.G 1993 1.4:10 PAGE{ DRI'LbERS CASING DEPTH LOGGERS CASING DEPTf{ F~f3g~]~!{][.~E Cf)ND]T! O~JS ~,UD TYPE: DENSITY ([,B/G): VISCOSITY (S): P~: FLUID LOSS (C3) ~AXI~.~[.i~! RECORDED TE~PE~AT{~RE (DF. GF) RESI= ....... oTIVITY (0~,~) Al T~MPERATURE ([)~GF)' ~UD AT ~;EASURED TE~"PERI, TURE (?iT): F~I,]D AT ~'![~TTO~ ~UD FILTRATE AT ~UD FILTRATE AT ~UD CAKE ~,~I}D CAKE AT CBHT): TOOL TYPE (EPITHERNAb OR NATRIX: ~ATRIX DENSITY; hOLE CORRECTION 8633.0 ~635.0 WT,/DISP !1,70 48.OO 10'00 1,670 1,370 2,000 65.0 72.0 72.0 REMARKS: TOOL STANDOFF BOTH SANDSTOb~E ~.65 A total of ~ !oqgl~o passes were.maOe, The,first was field ~11e 006 an.'inctu~ed a high resolutlon pass at 900'FPH amd !,2" sample rate..' The hiQh resoZutlom bDT da~a i~ tn ~le 3 on t. hlS ~ape, ~he ht~h Tesolut&om · .1 ~ .... ~ CNI~ data is in file 4 on this ta~e, and t e 6" sampled data for file .006 is iD this fil® .002. The second logging pass was the main ~ass of DITE/LDT/CNTG and its'data,is also i. ncluded n this file, The third pass (field file .00R) is a repeat pass..of the DITE/LDT/CNTG sulte and can be found ,in file 5 of this tape, Dual IDductlon used 1.5" finned standoffs, and a 2' hole finder. The ~eutro~ was logged o~ sand matrix using density caliber for hole correction. The Dens{tv was lo~ned on matrix of 2.65 g/cc, filtrate density was l.O g/cc. LIS FORMAT DATA 0000000000 89 ~ I ~ Z 0 O0 JO0 O0 ~L9o6S mQ"l 0000000009 89 ~ ~ [ ~ 0 O0 gO0 O0 ~L~66~ £3/D £(]q uOn~ O000000OO0 89 ~ l ~ ~ 0 O0 000 O0 [L~66§ fid zQq iHd(] 0000000000 89 ~ I [ ~ 0 O0 ~00 OO ~L~66~ ~q ~ci 0000000000 89 ~ ~ I E 0 oo oO0 oo ~k~o6~ ~;~ttO a£d 0000000000 89 ~ I i ~ 0 O0 000 O0 ~L~66~ ~93q ~£Q 0000000000 89 ~ I '[ ~ 0 60 O00 O0 ~L~66§ ~q ~ZQ 0000000000 89 ~ ~ I [ 0 O0 000 Ob ~LV66~ Id~D ~,£G 0000000000 89 ~ g ~ ~ 0 O0 000 O0 ~L~66~ A~ ~d 0000000000 89 ~ I ~ [ 0 O0 000 O0 ~L~O6~ ~hHO ~d 0000000000 89 ~ I I E 0 O0 000 O0 ~L~b6~ OH~ 3Z~ ~XiI 0000000000 89 ~ t ; ~ 0 O0 000 O0 EL~66~ OH~ ~£~ 0000000000 89 P [ t ~ 0 O0 000 O0 gL~66~ ~Wh ~(l ~XlI 0000000000 89 ~ I '[ ~ 0 O0 000 Oo ~Lf66~ OH~ 3£Q 0000000000 89 ~ I ~ ~ 0 O0 GO0 O0 gL~66S :~Z(] ~0~I 0000000000 89 ~ I t g 0 oo 000 O0 ~LP66g ~£G ~Oqi 0000000000 89 P t g I 0 O0 000 O0 aL~66S NNHO 3~d ~"1I 0000000000 89 9 ~ I ~ 0 O0 000 O0 EL~66~ []Mn~ ~£Q ~qlO 0000000000 89 ~ I [ ~ 0 O0 000 O0 ~LP66~ ~HD M£Q Q'Ii 0000000000 89 P I ~ g 0 O0 000 O0 gi~66S OH~N ii,LQ dqiD 0000000000 89 ~ ~ ~ g 0 O0 000 O0 gAP66~ N~HO 3£Q Hd~! 0000000000 89 9 I [ ~ 0 O0 000 O0 ~/~66g OH~ ~iO u~ID 0000000000 89 ~ I I ~ 0 O0 000 O0 gLP66~ ~HO ~£d HdQI 0000000000 89 ~ I I g 0 O0 000 O0 gL~66S ~HN~ M~Q a(]lO O00000OO00 ~9 ~ t ~ ~ 0 O0 000 O0 ~L~bbg i~ 0 I 99 89 99 SI 0 99 ~"0 89 8 ~9 L 99 I 99 gLE EL 0 99 0 99 :MDYd Oi:gt bulbs'Iq uo'I~Otli~OA a~e& ~i 0000000000 89 ~ I ~ ~ 0 0000000000 89 ~ I [ ~ 0000000000 89 ~ I ~ ~ 0 0000000000 89 ~ I ~ ~ 0 0000000000 89 ~ i I ~ 0 0000000000 89 ~ '[ I ~ 0 0000000000 89 ~ I I ~ 0000000000 89 ~ ~ I ~ 0 0000000000 89 ~ i ~ ~ 0 0000000000 89 ~ I ~ ~ 0 0000000000 89 ~ i ~ ~ 0 0000000000 89 ~ [ t ~ 0 0000000000 89 ~ I '[ ~ 0 0000000000 89 ~ I '[ ~ 0 0000000000 89 ~ [ I ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ ~ I ~ 0 0000000000 89 ~ ~ '[ ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ i ~ ~ 0 0000000000 89 ~ I ~ ~ 0 0.000000000 89 ~ ~ 'I ~ 0 0000000000 89 ~ t i ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I '[ ~ 0 0000000000 89 ~ I ~ ~ 0 0000000000 89 ~ t [ ~ 0 0000000000 89 ~ t ~ ~ 0 0000000000 89 ~ I I g 0 0000000000 89 ~ ~ I g 0 0000000000 89 ~ i I g 0 0000000000 89 ~ I t g 0 0000000000 89 ~ ~ t g 0 0000000000 89 ~ I I g 0 0000000000 89 ~ ! I g 0 0000000000 89 ~ ~ '[ ~ 0 0000000000 89 ~ I ~ g 0 0000000000 89 ~ ~ I g 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ 't I g 0 0000000000 89 ~ I I g 0 0000000000 89 ~ t t g 0 0000000000 89 ~ I i ~ 0 0000000000 89 ~ ! I ~ 0 0000000000 89 ~ ~ ~ ~ 0 0000000000 89 ~ I [ g 0 0000000000 89 ~ I t ~ 0 0000000000 89 ~ i I g 0 0000000000 89 ~ ~ t g 0 (X~H) 3Q03 ~2q3 d~¥~ ~[tN Ov 0[)0 O0 ~a~b6S 00 0 t) 0 00 a L t~ 68 ~ ~ q O0 000 O0 OO 000 O0 000 O0 gL~06~ O0 OOO 00 gL~66~ O0 000 O0 gL~66~ O0 000 O0 EL~66~ A O0 000 O0 gL~665 A O0 OOU O0 O0 000 O0 gL'~66~ O0 000 OU O0 000 O0 O0 000 O0 ZL~66~ O0 000 O0 ~L~66~ O0 000 O0 O0 000 O0 gL~665 O0 000 O0 ZL~665 O0 000 O0 ZL~66~ O0 000 O0 EL$~66~ O0 000 O0 ~L~66~ i'Id O0 000 O0 ZL~665 Sd3 O0 O00 O0 000 O0 O0 OOO O0 gL~66S SdD O0 000 O0 ~L%z66~ fid O0 000 O0 O0 000 O0 O0 000 O0 gL~66~ Fid O0 000 O0 gL~665 O0 000 O0 gLi~66S WdD O0 000 O0 O0 000 O0 ~&~66~ fid O0 GO0 O0 ~/966~ A O0 000 O0 ~L~66~ A O0 000 O0 gL'~66~ O0 000 O0 [L~66~ O0 000 O0 gLP66~ O0 000 00 gL~66~ O0 000 oo gL~66~ SaD O0 000 O0 O0 000 O0 EL~66~ SS~qD 2dX£ Doq ~ ~O Id~ Id~ IdV 3DiAH~9 &INi'i Aa H(]q HQ"i HG~I HQ'i Hziq H 0 q <i q H ('l "I [1 'l HQq sq h Q 'l S "i 0 HG'I Hdq H (i '"I H~'I iliad "IND rIND '"1 h 3 daN& qND qND DSND '"IND ~qq aHSq ~ O q q i (l q ~l q I Tame Verification List!no ;cblt]mberqer AlasKa Computlno Center l~-AUG-1993 14:10 PAGEI 9 N~E SERV UNI? ID CF~C C~'~ CPS C~.~ EC C~I~' CPS RCE~ C~.{H CPS ~ CEt'~ CN~ CPS TNPN CNH PU ~TN~ CNg ~Ct~T Cc~ RCFT CNH CUTC CFTC CNN SE~VICM API APl ~Pl !PI FILE NUMB NUMB SIZE REPR P~OCESS ORDER ~ LOG TYPE CLASS ~OD NU~B SA~P ELEM CODE (HEX) 599472 O0 000 O0 0 ~ 1 1 4 68 0000000000 599,472 O0 000 O0 0 2 1 ! 4 68 0000000000 599472 O0 000 O0 O 2 i i 4 68 0000000000 59947~ O0 OOO O0 0 ~ l 1 4 68 0000000000 599472 O0 00O 00 0 2 I I 4 68 0000000000 599472 00 000 00 0 2 I, 1 4 68 0000000000 599472 O0 O0(? O0 0 2 I ! 4 68 0000000000 599472 00 000 00 O 2 1 I 4 68 0000000000 599472 O0 000 O0 0 2 1 I 4 68 0000000000 599472 O0 000 O0 0 2 ~ I 4 68 0000000000 599472 O0 000 OO 0 2 ! 1 4 68 0000000000 PU 599472 O0 000 O0 0 2 1 I 4 68 0000000000 CPS 599472 O0 000 O0 0 2 1 1 4 68 0000000000 CPS 599472 O0 000 O0 0 2 I 1 4 68 0000000000 CP~ 599472 O0 OOO O0 0 2 1 ! 4 68 0000000000 CPS 59947~ O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. I~P[{.DT~ TLa.DTE IIXD.DTE SP.DTE PPHO. LDT 1,$ , bDT sSI.LDT SJ. RH.LDT ENPP.Ci~I, RCEF.C~L T~a.CNL ~CFT,C~L ~SS.I, DH LITM.LD~ SSHV.LD~ CALT.LDN M~ES.LD~ CFEC.CN!{ NDHT.C~H NoOR.CNq I~PW.DT~ IL~.DTE II×D.DTF 9368,500 2.592 2.585 55.BB1 0.701 0.005 339.241 242.744 2.36! 32.624 734.107 2.351 1106.358 -999.250 -999.250 -999.250 -999.250 -Oqo.250 -999,250 -999.250 -999.250 -999.250 -999.250 9o00.000 2.457 2.542 35.!44 -25.313 CiDP.DTE CILD..DTE %DOF'DTE IIRm.DTE GR.DTE HTEN.DTE PEF.LDT LU.LDT SS2,LDT LSRH.LDT EN~A.CN5 RCEN.CNL RTNR.C~I, CNTC.C~L DRHO.LDH L$.LDH SSI.LD~ S1~H.LDH GR.LDH NTEN LDH c~c:c~ TNPH.CNH RCNT,CNH CIDP.PTE CII.,D.DTE IDQF.DTE 389.008 IDPi~.DTE 2.571 CI~P.DTE 390.762 ILO.DTE 2.559 CILm.DTE 0.000 IMOF'DTE 0.000 IIRD.DTE 359.279 !I×~.DTE 28.17] SFLU.DTE 138.857 TENS.DTE 1540.000 ~TE~.DTE -260.917 DPHI.LDT 15.900 RHOB.LDT 37.554 OLS.LDT -0.057 QSS.LDT 329.847 LL.LDT 174.318 LITH.LDT 342 4~2 bSHV.LDT 1439.045 SS~V.LDT 2~3~ 2 LIJ~H.LDT 2.380 CALI.LDT 4.707 CFEC.CNL 735.536 CNEC.CNL 3273.240 NPHI,CNL 29.475 TNPH.CNL 2.444 MPOR.CNL 26.]94 RCNT.CNL 2742.068 CFTC,CNL 1175.297 DPMI.LDH -999.250 PFF.LDH -999.250 OLS.LD~ -999.250 LU.LDH -999.250 LL.LDH -999.250 SS2.LDH -999.250 LSHV"LDH -999.250 hSRg.bDg -999.~50 LURH.LDH -999.250 TEN$.LDH ~99 ~50 MTEM.LDH -999.250 FNPH.CMH -=99;250 ENRA.CNM -999.250 RCEF.CN~ -999.250 RCEM.CNM -999.250 T~:R~.CNH -999.250 RTNR.CN~ -999.250 RCFT.CNH -999.250 CNTC.CMH 376.6(35 IDPH.DTE 2.655 CI~P.DTE 388.288 !LD.DTE 2.575 CIL~.DTE 0.000 INOF.DT~ 0.000 IIRD.DTE ]65.207 IIX~.DTE lt.182 SFLU.DTE 93.241 TENS.DTE 5090.000 MTE~.DTE 85'839 86~824 32t,557 62O 2.388 0,004 77,243 2,883 3461,903 26,394 2753.304 -999,250 :999,250 999.250 '999.250 '999,250 '999,250 '999,250 '999.250 '999,250 '999,250 406.974 393,375 313.113 2.384 146.319 89S'LgEi £6I'Eg 660'0- I)8'9£I O00'OOL6 EBg'E~- 09~'o~- OSg'666- OSg'666- 0~g'666- 0S~'666- 0Sg'666- 0~:666- OS~ 666- 0~°666- O~go666- 8tt.EOLI 189~LgL~ 660 O- l~6"'l 6~O~Ei ooo:oo 6 ~£6 6)gg 8g~ 066 6L6[ 088 8~0 £,gL SOl' ~00- ~0) 9I ~8L O~ ~'0 tE9,gLEE LI£:'L~EI ~Oq'IqV3 ~Oq'H[Iq 3~O'~qlD HND'D&ND HND'N3DH HND*U~N3 HOg'H~9 HOg°^H~9 HOq'~qO ND'~ND~ qND'D3ND &O HND'¥~N3 HOq"HS£iQ HOq"qq HO'I'S90 HOq'iHdO qND'~NDH qN~..HdNi D' ~Oq'H£Iq ~Gq'SSO 869'~ 68E'~0I ~EO'O- O00'SI9) 5go'ggE- 000'0 9£)'~3 0S~'6662 05E'666 0~g'666- 0S~'666- 0~'666' 0S~'666- 0~°66~- 0~'666- 0~'666- 80~'9~b ~6~9~ 869!' 68[ ~£0'0- O' ~gO..9~g' O0 0 OlO.'6gL 88£.Lg ~9~'ogE LIL'~LE [0690L $aq'Haaq 199'~ iOq'AH~q OOE'9E~ ~O9'~'lO £O9'lHdO LEg 9~6 haD'iJJ~ 0~g'666' HND'~aNA O~g'66b' HND'MMD~ 0qg'666' HND~HdNM 0~'660' HOq SNJL 0~'666' HGq'H~q O~g'b66' Hoq°~S OS~'666- HOg'~q qND'D&~O 08E'609I qND°~OdN qND'IHdN qND'DJJD 68~'9 iO9'gqO ~ig 61 £Gq"IHdO L~ 9)6 3iO'~XiI ggS'[ ' · ~ .0I 2iOJ~I 000 3£(]'<lqI HND'HdN3 9~0'6g01 HGq'Hs~q LSO'~ HGq'~q gS~'f6E HOq'~i~d 560'0 q~'D£JD O~6'80EZ qND'iHdN zOq'AH~q ~DE'EgE ioq'q'] 6g0[~6[ ioq'gqO £O'l'fiq [t9'§0~ ~dq'S'l ~'l'~3d O[L'O- 3£~'~3&h [08'0 3,LO'S3~ 3iQ'E9 CAS'gE ~£d'dOOl 000'0~6I J.G'O'IiD 000'0~6[ 3iO'dfllD 000'E6~8 '£dag HND'HdN£ 0~'666- ~iND'IHON HND'D3ND 0~'006- ~ifqD'O3~D HOq'Na£H O~'6b6- ~o"i'a~ 0~a'666- H(lq'lq~D HO'I'HalS 0~g'666- HOq'AHSS HQq'ISS 0S~'666- hdq'H~Iq !.tG'i'OH~IQ O~g 666 qND'DiND g6~'~aE q~D'&3ja rlNO'~i8 6~6'E qND'~'~N3 6~9'E~ iOq'~SS E§i'~8 ioq'Bq E'[O'~OZ aa~'i'~3d OiL'O' 3iO'a3aH 008'0 ~ZG ~OOI o00 0~6~ 3£G'dOlD 000'00§8 9~6'Eb O~'~EL 6~L'O H(lq'S3a~ 8gi'9 HOq'iQ~D ~98'LgE'[ HGq'AHSS £$E'g9 HOrl'H~iq 980'0 6LE'g 6S9'6S9 gte'6g qND'HdN3 ~90'~ ~LS'~Sg LtI"iI~ &Gq'sq 060'0 .. ,IS Ta~e V~rificat!on Llstinq ~cblumberoer AlasKa ComputinO Center ENp~4,Ciqb 53.619 RCEF.C~I[, 463' 604 T ~.~R A. C ~ l~ ]. 959 RCFT, Cb~b 3~4. 492 O~S.LDH -999,~50 LITN, LD;'4 -999,250 ~S[iV. L[)~ -999. 250 CALI. LD}{ -999. ~PES. LP~ -999,250 CFEC.CMH -999,250 t}PHI. CM~{ -999,'250 NPO~,C~.)H -999,250 CFTC.CNN -999,250 I2-AUG-1993 I4:!0 6.589 CFEC.CNL ~67~.039 NPDI..CNL 4.364 NPOR.CNL 1609,380 CFTC,CNL -999,250 PEF,LDH '999 250 LU.L[H '999,~50 882,LDH ~999.~50 [,SRH.LDH 999,250 TENS.LDH :999 250 ENP~I, C*.~N 999:250 RCEF,CNH -999,250 T~RA,CNM -999,750 RCFT,CNH 448.290 CNEC.CNL 56 294 TNPN CNb 54'825 RCNT:CNb 426..508 QPM. I,LDM -999.250 OLS,LDH -999'250 L[,.LDH -999,:250 bSHV, LDH -999~50 Li.~RH. LDH -999.~50 ~TEM.LDH -999.250 ENRA,CNH -999.250 R. CEN.CNM -999,~50 RTNR,CNH -999.250 CNTC.CMH PAGE{ 2767 681 53 5]4 1703 lis -999.250 -999,250 -999,~250 -999,:250 -999"250 -999,250 -999,=250 -999,250 -999,~50 -999.~50 ** END OF DATA ** **** FILE TRAILER **** FILM FAME : EDIT .002 SERVICE : FLtC V~R$ION DATE ~ 93/08/~,2 ~IX REC SIZE I 4096 FILE TYPE : hO LAST FILE **** FILE HEADER **** FILE NAhuM : EoIT 003 SERVICE ; FLIC VERSION : OO1COI paTE : 03/08/12 ~aX R~C SIZE : 4096 FILE TYPE I~AST FILE F!LF HEADEP R~W ODE~: HOI, E RE~P..F..AT PASS Curves and lo~ header data for each run a~d tool string in separate files. TOOL STRING NUt, BEN: ! pass ~}U'~BER: 1. DE~TH INCRE~EMT: -.08333 FT[,F Stlu~{ ~Ry VgND~R TOOL CGDg ~TART [;EPTH sqoF DEPTH .................... 7'i ............. I,[)T 936 9 7. ~50~,0 -,IS wade Verification List:.i~o ;chlumberqer AlasKa Computing Center 12-AUG-!993 14:~0 bOG HEADER DATA DATE LOGGED: SOFTWARE VER$IOI~: TI~E CIRCULATION ENDED: TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL BOTTO~ LOG !MTE~VAL (FT): LOGGING SPEED 10-JUL-93 5C0-42] 534 9354,0 9349.0 9340,0 900.0 9-JUL-93 lO-JUL-92 TOOL STRING (~rO'P TO BOTTOM) VL;MDDR TOOL CODE TOOL.TYPE I~IIImII!~!I! C~TG DITE $ G~M~& R~Y COmPENSaTED NEURON blTM~-DENS!TY TOOL FHASOR iNDUCTIO~ OPEN HOLE BIT SIZE DRILLERS CASI~!G DEPTH LOGGERS CASING DEDTM (PT): ~©REHOLE CONDITIONS ~UD TYP~]: ~t!O DENSITY (LB/G): ~UD VISCOSITY FLUID LOSS ~AX!~U~ RF]CORDED TE~P~RATIIRE (DEGF): RESISTIVITY (OH~M) ~T TEMPER~TUR~ (DEGF): AT ~EASUR~D TEuPERATURE AT ~TT[i~,~ HOLE T~PEPATURE FILTRA~'E AT FILTRATE AT CAKE AT (~T): CAKE AT (~T): ~EUTRON TOOL TOOl. TYPE (EPITHELIAL OR THERMAL): ~TRIX: ~TRIX D~JSITY~ UOLE CORRECTION TOoL NUt, DER A~S-S-7!2 TCC-B-281 SGT~L-50 CMT-G-65 LDT-D-51 DIT-~-379 6 125 8635.0 WT,/DISP 11,70 4R.O0 10,00 148.0 1,670 1.370 2.000 65.0 72.0 72.0 BOTH S~NDSTONE 2.65 TOOL STANDOFF A total of 3 lo~oinn.passes were.made, The first was flel0 file ,006 amO included a nigh resolution pass at 900 PPIS, and 1,2" sample rate. The high resolution ~IS Tame Verificatiom !.ist:lnq ~chlumberoer A!as~a Computing Center i2-AUG-1.993 14:10 LDT data is in file 3 on this taoe, the high resolution C~,:!TG data. is in file 4.on thl. s tape, and the 6" sampled data. for fil. e .006 is in file !, 'The second !ogling pass was the ma~D Pass of mil ~:./S!)T/CNTG a~d its data lB also included in file i... The third pass (field ~ile .008) is 8 repeat Pass_of the DITE/LDT/CNTG suite and can be fox, nd in tlle 5 of this tape Dual Induction used t.5" ~lnned stando~s, and a 2; hoIe ~i. nder' The Ne6tron' was lo~oe~ on sand matrix, using . The Density was density call. Der for hole correction. !o~ed on matriR o~ 2,65 g/cc, filtrate densit~ was I. 0 q/cc. L~S FOR~T DATf~ 1¸3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 52 4 66 5 66 6 7 65 8 68 0.083 9 65 FT 11 66 78 17 68 13 66 0 1.4 65 F~~ 15 66 68 16 66 1 0 66 1 ** SET TYPM - CNAN ** Na,~w SM~V {.!~!m F.~ S ~VICF APlaPI API API F!bE U B NM M U~B SIZE REPR PROCESS ID ORDE~ # O~ TYPE CbASS ~OD NUmB SAMP ELEM CODE (HEX) DFpT FT 59947~ O0 000 O0 0 ] I ~ 4 68 0000000000 ~PFF LDH 599472 O0 000 O0 0 3 1 I 4 68 0000000000 HNR~ L[?H G/C3 509472 O0 000 O0 0 ] 1 1 4 68 0000000000 HPN~,~ [,~ PU 599472 O0 OOO O0 0 3 ! 1 4 68 0000000000 H~HO [~D~ G/C3 599472 O0 OOe O0 0 3 1 ! 4 68 0000000000 NDpW LD~ G/C3 599472 ~0 000 O0 0 3 ! 1 4 68 0000000000 ~pw LL?~ ~t.! 599472 o0 OOo O0 0 ~ 1 1 4 68 0000000000 Tame Verifl. catton List:in.~ ;chl!lmberger AlasKa Comput~nm Center 12-~UG-~993 14:10 PAGE: 14 ID O~DER # LOG TYPE CLASS MOD ~UMB SAMP ELE~ CODE (HEX) NLL L[)M CPS 599.~72 O0 0 0 0 O0 0 ] ! I 4 68. 0000000000 ~[,U LD~ CPS 599472 O0 000 O0 0 3 ~. I 4 68 0000000000 HbS LD~ CPS 599472 O0 000 O0 0 ~ I 1 4 68 0000000000 HLI? LDH CPS 59947~ O0 ©00 O0 0 3 ~ I 4 68 0000000000 H$SI LD~ CPS 599472 O0 000 O0 o 3 ! 1 4 68 0000000000 FSS~ LD~ CPS 599~7~ O0 000 O0 0 ] ~ 1 4 68 0000000000 D~PT 9363 918 HPEF,LDH -999 250 HNR[.~i. LDH -999~250 HPH i.LDH · . - % I . ... ~HO LOH -999.250 HDR~.LD~ -999 250 HDP!~ bDH -999.:~50 HLL.LDH HL!~.LDH -999.250 HLS,~DH -999.~50 HbIT.LDH -999.250 H$S~..LDH HSS~.:R,D~{ -999.250 DEPT. 9000.000 HPEF.bDH 10.275 HNR~i.bD),t ~.401 HPHN~LD~ ~Q~O.I, DH '2.413 H[)~H'LDH 0.114 HDP~.bi)~t 14'383 HLL.bD~ ,LU.LD}.! 364..476 ~LS.LD~ 383.196 ~t, IT.bD~ 60,!04 HSSI.LD~ ~SS~,LD~.{ ~66.048 EPT._899 . ~,i.~qo.t..r.~ 9 250 ..D~ [,D~t -qgg.250 HDP~[LDH 99.~ 0 HLL..LDH "~LU.[,D'~ -999"250 HLS.L[~H -999.250 HI,,,,IT.LDH 99.250 HSSI.LDH [~S8~. LD~ -999. 250 END OF DATA ~99g,250 9gg' 250 -ggg, 250 '999, -99 ~:50 **** FILE T~AIbER FILE ~AME : ·EDIT .003 SErViCE : FLIC V~RSION ! O01CO1 DATE : q3/08/1~ ~aX REC SIZ~ : 4096 FIL? TYPE LAST FILE **** FILE MEADM~ **** FILE lq~E : EDIT .004 SERVICE : FL!C VMPSIO~ : OOICOI DaT~ : ~3/08/12 ~× ~EC SIZE : 4096 FTLE TYPE] : L,O LAST FILE ~ ,iIS Tape verificat~,on Listing ;chlumberger Alaska Compt.!ting Center 12-AUG-1993 !~:10 Curves and Io(~ header data for each run and tool string in separate files. RUN NUMBER: I TOOt, ST~IgG Nt~ER: P~SS NUMBER: ! D~PT~ I~rRE~E~T: -.!.6667 FT[,~ Sit,MARY VENDOR TOOL CODE START DEPTH N ~ 9363,833 ~OG H~DER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TIM~ LOGGE~ ON BOTTOM: TD DRILLER TD TOP LOG ~NTERV~L ~OTTO~ bOG INTERVAL (ET): LOGGING SPEED (FPHR): STOP DEPTH TOOL STRING (TOP TO BOTTOM) V~NDOR TOOL CODE TOOL TYPE ~$ TCC GP CNTG LOT DITE $ T~LE~ETRY C[RT~IDGE' COMPENSATED NEURON t, IT~O-DENSITY TOQb PHA$OR IND!JCTIO~ BORE~{OLE A~D CASING DATA DRILLERS CASING DEPTH b~G~ERS CASI~G DEPTH (FT): nOREHOLE CONDITIONS MUD TYPE: ~UD DENSITY ~[TD V~SCOSITY (S)~ FLUID LOSS (C3): ~A×I~U~ RECORD50 TE~mERAT[!RE CDEGF): PF$~STIV!TY (O~) ~T TEMPERATURE {DEGF): ~UO AT ~MASU~ED TEMPERATURE ~UD AT 6OTTOM HOLE TEMPERATURE ~UD FILTWATE ~T ~!}D FILTRATE AT ~UD CAKE AT !O-jUL-g3 5C0-42] 1730 534 9354 0 9340!0 8365 ~0 93~0 0 900.0 g-JUL-g3 lO-jUL-92 .... OOh NUMBER TCC-B-281 SGT-L-50 CNT-G-65 LOT-D-51 DiT-E-379 6.125 8633.0 WT.tDISP !1,70 48.00 10,00 148.0 1.670 ~,370 2,000 65.0 72.0 72.0 PAGE{ :15 ~I$ Tape Yerlftcation 5istlnq ,chlumberQer Alaska Computino Center 12-AUG-!993 14:10 ~EUTRON TOOL TOO[, TYPE (EP!T~ER~A[, OR THERgAL): MhTRI×: ~ATRi'X DE~SITY: HOLE CORRECTIO~ (INJ: TO[}L STA~DOFF (IM): SANDSTONE ~.65 A total of 3 loq~in~ passes were made. The.~Irst was ~ield ~11e.006 and'incl%lded a ~l~h resolution pass at 900 FPH an~ I 2" sample rate. The bi~h r'esol~ltion LDT data l~ iD ~.~e 3 on this tape, the hl~n resolution CMTG data.is in ~]..le 4. on this tape, a~d t~e 6" sampled data ~or ~lle .006 is in file 1,. The second ioq~in~ pass was the main pass of DITE/bDT/C~TG and ts da~a.ls also included i~ file 1. .... The third pass (~leld file .oOB) lsa repeat Pass,.of the DITE/SDT/CNTG suite and can be ~ou~d ln' ~lle 5 of this tape} Dual Induction used 1.5" flnmed standoffs, a~.d a 2 hole ~1nder, The Neutron was lOqged on saD~ matrix uslnq density caliper for hole correction. The Density was ].oozed on matrix of 2,65 g/cc, filtrate density was $ bis FORMAT DATA 1¸6 ** DATA FORMAT SPECIFICATI(~N RECORD ** ** SET TYPE - 64EB ** TYPE RFPR COD ~E VAL~}E I 66. 0 2 66 0 3 73 4 66 5 66 6 73 7 65 § 69 0.166 11 66 146 1~ 68 1~ 66 0 14 65 FT 15 66 16 66 0 66 ,IS WaDe Verlf!cation L:isttn~ ;Chl%~mberqer Alaska Computlnq Cer~ter 12-AUG-!993 ~,~:10 PAGEI 17 ** SET TYP~ - C~AM ** ,, ,.,~,, ,:. · PHFT C~ CPS ~99472 O0 000 O0 0 4 ! 1 4 68 0000000000 ~WNT CN~ CPS 599472 O0 000 O0 0 4 ~, i 4 68 0000000000 HT~P CN~ PU 599472 O0 000 O0 0 4 I I 4 68 0000000000 MNpn CN'~ PU 599472 O0 000 O0 0 4 ! ! 4 68 0000000000 ~CFT C~ CP~ 599472 O0 000 O0 0 4 I ! 4 68 0000000000 HC~T CN~ CPS 599472 O0 000 O0 0 4 1 1 4 68 0000000000 ** D~,TA ** D~PT. 9363.834 RH[T.CNH ~PO.CNH -999,250 HC~T~CN'H DEPT. '90~0.000 MNPO.CNH 39,904 HCF~.CNH DEPT, ~50J,000 RHFT.,CMH HNP~,CNH -9q9.250 ** END OF DATA ** -999.~50 PHNT.,CNH -999,250 HCNT,CNH 675.674 RNNT,CNH CNN 687.085 MCNT,, -999 250 RHNT,C.~H -999,250 HCNT,CNH ~999 250 HTNP.CNM 9992250 '' 2264, '999,250 MTNP,CNH -999,250 '"999,250 290 **** FILE Tgi!hER **** FILE NAIVE : EDIT ,004 SERVICE : FLIC VFR$ION ~ O0!COI ~X REC SIZE : 4096 FILE TYPE : bO LASv FILE **** FILE HEADER **** SERVICE : FLIC VWRgION : O01CO1 !)~TF ~ 93/08/!2 ~aX R~C SIZE : 4096 F?LF TYPE : L~ LASW VItaE : FILE HEAi')MR FIb~ NL!~!~ER 5 -,IS ~a~-e veriflcation 5istinq ~chlumberqer Alaska Com~Utinq Center 12-AUG-!993 14:t0 ~A W C,,)rves and loq header data for each run and tool strlncl. In separate files° P!~a aUa~ER: I TOOL STRING NUaBE~: D~PTH INCREMENT: ~.5000 FILE Stl~Y VENDOR TOOL CODE START DEPTH E 9371,5 bDT 9371,~ ¢N5 9371.~ DATE LOGGED: SOFTWARE VERSION: ?IaE C!RCULATIO~ ENDED: TI~E LOGGE~ ON BOTTO~: TD DRiLlER TI) LOGGER(FT): , TOP LOG INTERUA5 ~OTTOM LOG INTERVAL LOGGING SPEED (FPHR): STOP OEPTN 8498.,5 849~,5 TOOL STRING (TOP TO BOTT9N) VENDOR TOOL CODE TOOL TYPE *~S TCC G~ CWTC LOT D!T~ $ GA~ RAY CO~PE~SATED N~URON LITHO-DENSITY TOOL PHASOR I~IDUCTION ~ORMHOLE AND CA$I~G DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH fFT): LOGGERS CASING DEPTN aOREHOLM CONDITIONS HUD TYPE: ~lIP DENSITY (La/G): MUD VISCOSITY MI~D FLUID LOSS (C3): ~XI~i~4 RECORPED TE~PFR~TURE (D~GF): ~SIST!VITY (OH~a) AT TE~PERAT[JOF (DEGF): ~UD AT ~EASU~ED TEMPERATURE (~): uU~ AT S!.)TTO~ HOLE T~!PE~ArTIJRE ~UD FI!~TRATE AT (~T): uUD F!LTmATE IT ~!lD CAKE AT (~T): 10-JU5-93 5CO-423 · 173o 9-dUb-93 704 10-JUL-92 9354.:0 9349,0 8365 ~DCb ~<UMBER ~mmmmmmmmmm TCC-0-281 SGT-L-50 CNT-G-65 bDT-O-5I DIT-~-379 6.125 8633.0 P635.0 WT./DIS? 1!,70 48.00 148.0 1.670 1 · 370 2.000 65.0 72.0 72.0 PAGE: 18 ,IS Ta.~e verlitcatlon !,lsti, no ;chlumberoer Alaska ComPutlnq Center l~-AUG-1993 14:10 PAGE: !9 MUD CA~E AT [BHT): ~TRIX: ~ATRI× DENSITY: HObE CORRECTIO~i (IN): SANDSTONE 2.65 TOOL STA~DOFW (IN): A..total of 3 logoin~.passes were made, The ilrst was field ~lle .006 and included a. hl~h resolution Pass at. gO0 FPH. a~d 1.2" sample rate~' The high resolutioD bDT data is im file 3 on th~.s tape, the high resolution CNT~; data.is ln~ flle 4 on this tape, and the 6" sampled ~ata for field file .006 is in file 1. T~e second lo~Qing pass was the main pass of DITE/SD?/CNTG and its data15 also ~.r~ci~qed In file ~' The:third pass (field file 008) is a repeat Pass of the DiTE/bDT/CNTG s%lite and ca~ be-f~]nd in" file 5 of this tame Dual Induction used 1 5. ~Imned standoffs, and a ~1mder. The Ne,ltron was logged on sand matrix using density caliper for hole correction. The Dens'tV was logged on matri~ of 2.65 q/cc, ~il. trate densit~ was 1.Oa/ce, S LIS FORMAT DATA ** OATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REP~ 2 66 0 3 73 ~20 4 66 1 5 66 6 7~ 7 65 ~ 6~ 0,5 9 65 ~T 11 66 13 66 0 ~ 65 FT !5 66 68 16 66 O 66 1 ~!S Ta~>e Verification Listing ;chlumberger AlasKa ComPutlno Center i2-AUG-~,gg3 I4:10 ** SET TYPE - CHAN ** N~!~ V ..I- SE ] I NtJM6 NUMB P~OCE$~ ID ~IRDER # LOG TYPE CL!$$ MOD NUMB 8AMP ELEM CODE (HEX) '''''''''D~PT ..... FT''''';;;;~'''~'''~'~'''~'''''''';''''~''''''''''''''''';;''''~;~''''''''5. 0 1 ~ '' 000000 C!DP DTR M~HO 59~472 00 000 00 0 5 1 1 4 68 0000000000 IDP~; DTR OHMM 599472 00 000 00 0 5 I 1 4 68 CIMP DTR MMHO 599472 00 000 00 0 5 i 1 4 68 IVPI~ DT~ O!4~s 599472 00 000 00 0 5 I i 4 68 CILD DT~ MM~O 599472 O0 000 0O 0 5 1 I 4 68 II, D DTR OH~ 599472 00 000 00 0 5 I 1 4 68 C!L~ DTR MMHO 599472 OO OOO O0 0 5 ! ! 4 68 I[.,~ UTE O}~MM 599472 00 000 00 0 5 1 I 4 68 IDQF DTP 59947~ 00 000 O0 O 5 ~ I 4 68 I~O~ DTR 599472 00 00O 00 0 5 1 ~ 4 68 IIRD DTR M~HU 599472 00 000 00 0 5 ! I 4 68 I!XD DTR M~HO 599472 O0 000 00 0 5 1 1 4 68 i!~ DTR MMMO 599472 00 000 00 0 5 1 1 4 68 IJX~ DTR M~HD 599472 00 000 00 0 5 1 ~ 4 68 SFbU DTP DHMD 599472 00 000 00 O 5 I I 4 68 SP DTR ~V 599472 00 000 00 0 5 1 I 4 68 GR DTR GAPI 599472 00 000 00 0 5 1 1 4 68 TFN8 DT~ LB 599472 00 000 00 0 5 ! 1 4 68 ~TE~ DT? DEGF 599472 O0 000 00 0 5 1 1 4 68 MRE8 DT~ OH~ 599472 00 000 00 0 5 I 1 4 68 HTEM UTE LB 599472 O0 000 00 0 5 ~ ! 4 68 DPH? I,DR PU 599472 00 000 00 0 5 I t 4 68 ~EUB LDR G/C] 59947~ O0 000 00 0 5 1 ~ 4 68 D~n LDP G/C3 599472 00 O00 00 0 5 1 i 4 68 PEP I~P~ 599472 00 000 00 0 5 ! I 4 68 OL$ LDR 59947~ O0 000 O0 0 5 1 1 4 68 DSS LD~ 599472 00 000 O0 0 5 ~ ~ 4 68 t,S LD~ CPS 59047~ 00 000 00 0 5 1 ! 4 68 LU LD~ CPS 5q9472 00 000 O0 0 5 1 1 4 68 LL LD~ CPS 599472 00 000 O0 0 5 I 1 4 68 LIT~ LDR CPS 599472 00 000 O0 0 5 1 1 4 68 851 LD~ CPS 599472 00 000 00 0 5 1 I 4 68 SS2 LDR C~S 599472 00 000 00 0 5 ! ! 4 68 LSHV LDR V 599472 00 000 O0 0 5 1 1 4 68 SS~V LD~ V 599472 O0 000 O0 0 5 I 1 4 68 S1~ LDR G/C3 599472 00 000 00 O 5 1 1 4 68 LS~ LD~ G/C3 599472 00 000 00 0 5 !. ! 4 68 LUR~ bPP G/C3 59947~ 00 000 O0 0 5 1 1 4 68 CaLl LDR IN 590472 OO 000 O0 0 5 1 ! 4 68 ~PH CNR PU 599472 O0 0o0 O0 0 5 ! I ~ 68 E~a CNR 599472 00 000 00 0 5 1 ! 4 68 CFEC C~R CPS 599472 oo 0o0 O0 0 5 I I 4 68 CNFC CNR CPS ~99~72 00 000 O0 0 5 1 1 4 68 ~CEF CN~ CPS 59947~ O0 000 00 0 5 1 I 4 68 RCEN CNR CPS 599472 O0 o00 oo 0 5 ! 1 4 68 NP~il CN~ pu 59g472 O0 oO0 Oo 0 5 ! I 4 68 TNpH CNR mU 59~472 O0 OOO O0 0 5 1 1 4 68 TNRa CN~ 590472 O0 000 O0 0 5 1 1 4 68 ~TNP C!~!P 599472 O0 OOO 00 0 5 ! 1 4 68 0000000000 000000o000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00o0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o00 PAGE: 2O ~IS Ta~e Verification Listinq ;c~lumberc~:er A!.as~a Computi qn_ Center PAGE: 21 ID ORDER # LOG TYPE CLASS MOD NUMB SA~P ELE~ CODE (HEX) ............................ .... .... ...[.......-.... ..... NPOP C~R Pti 599.472 O0 00 .~. 0 t I 4 000 000000 RCNT C~ CPS 599~7~ 00 000 00 0 5 1 1 4 68 0000000000 RCF~ C~JR CPS 59947~ O0 000 00 0 5 !, 1 4 68 0000000000 CFTC CNR CPS 599472 00 000 00 0 5 I 1 4 68 0000000000 CFTC C~R CPS 599472 00 000 00 0 5 I 1 4 68 0000000000 ** DATA ** I ~P~. D :. R ? L~ . DTR IIXD.DTR SP.DT~ ~ES.DTR bS LDR SS~,LDR SJR~.bDR ENP~.CNR RCEF,CMR TMR~.C~R RCFT,CNR DFPT. IMPH.DTR )L~.DTR IIXD.DTR SP,DT~ DRNO,LDR LS,bDR SS~.LD~ $1RH.LD~ TMRA.CNR NCFT.CN~ DEPT. IBPN.DTR IL~.DTR II~D.DTR SP,DT~ b~RES.DTR SS1.LD~ S~{.LDP 9371,500 CIDP.DTR 38g.~.49 IDPH.DTR ~.570 CI.~{P'DTR 2,590 CILD.DTR 390,612 ILD,DTR 2'560 CtLM.DTR 2,583 IDQF,DTR 0,000 I~QF.DTR 0.000 'IIRD'.DTR 56.304 II~g,DTR 359.506 IIX~.DTR 29,233 SF!,~U.,DTR - , .... , , ~'N' DTR 1435.000 MTEM,DTR 20 OhO GR :D~R lO1 472 TE.,S. 0,69~ ~{TE~ DTR -277'758 DP~I,tDR 14,q9i RHOB,bDR 0.10] ~E~~ ~9.235 OLS.bD~ 0~:021 ~SS.~DR 3~1.5242 LU.LDR ]48.527 b[.,.LDR 207.260 LITM.LDR 283, 35 SS2,LDR 356.864 LSH~,LOR 1439.160 $SHV,bDR 2,088 5SRH,LDR ~.300 LURH,LDR 2,346 CALI,LDR 32,62~ ENRA.CMR 4.707 CFEC,CNR 735,536 CNEC,CNR 734.107 RCEM.CNR 3273.240 NPHI,CNR 38 ~5 TNPH'CNR 2,896 RTNR.,CNR 3,000 NPOR.CNR 34:~,7 RCM ~ToCNR 857,~01 CNTC.C~R 2613.569 CFTC.CFR g~.253 9000.000 CIDP,DTR 369.974 IDP+I,DTR 2.50! CILD.DTR 38~,683 iLD,DTR 2,5~9 IDOF.DTR 0.000 IMQ~..DTR 37,653 !I~,DTR 367.09~ IIX~.DTR -28.875 GR~DTR 97,28~ TEN$"DTR 0,736 HTE~,DTR J047,827 DP~I,LDR 0.097 PKF.LD~ 14,9i0 OLS,LDR 430.649 LU,LDR 414.561 LL,LDR 286.855 SS~,LD~ 309,333 LSHV.LDR 2.02~ LSRH.I..DR 2.228 LURH,LDR 3!.976 ENRA.CNR 4.731 CFEC.CNR 7~3,28! RCE~.CNR 3063,796 NPHI,CNR 3,348 ~TNR.CNR 3.476 NPOR,CMR 647,724 C~TC.CNR 2333.672 CFTC,CMR :703 :620 o'ooo 11.077 4955,000 19.646 -0 064 223:369 144~.613 2 245 678584 43266 44 333 697 734 CIMP.DTR CILM.DTR IIRD.DTR SFLU.DTR MTEM'DTR RHOB.LDR QSS.LDR LIT~.LDR SSHVLDR CALIiLDR CNEC CNR TMPM.CNR RCNT.CNR 8500.000 CIDP.DTR 47.595 IDPH.DTR 21.011 CIMP.DTR 1950.000 CILD.DTR 38.765 ILD.DTR 25.796 CIL~.DTR 1950,000 IDOF.DTR 0,000 I~QF.DTR 0.000 IIRD.DT~ 7!,609 IIR~i. DTR -23.993 II×~,OTR -249.383 SFLU.DTR 34,500 GR.DTR 76,500 TENS.gTR 4435.000 MTE~.DTR 0.790 HTL~,DTR 869.204 DPHI,LDR -2,]08 RHOBoLD~ 0.21g PEF.LDR 28.671 Qb$.LDR -0.039 O$S.LDR 280.972 LU.LDR ~77.280 LL.Lg~ !42.332 LITH.LDR 303.36o SS2.LDR ~68.784 LSH¥.LOR 1442.754 SSHV.LDR 2.0~6 LSRH.LD9 2.470 L[iRM,LDR 2.495 CALI.LDR 48.362 E~:RA.CNR 6.J00 CFEC.C~R 418.568 CMEC.CNR 38~,075 ,446 32~:,914 151,620 2-403 OO95 56 1325 418 2,883 3.461'903 34:,617 2624,278 308,608 2,550 146,983 2,326 0,089 58.475 ~327.223 '189 42,016 2234.089 -63.993 -16,903 32.603 2 496 138:271 2.688 0.386 29928 1327:337 2,886 2738.707 .IS T.aDe verification Li ;cblumberoer Alaska Comp RCEP.CNR 406,404! TNR~.C~R 3,988 RCFT.CNR 336,931 DMPT. 8498.500 I~P~.OTR 1950.000 II,U.DTR 1050,000 IIXD.DTR 71.609 SP.DTR 34'500 MRES.DTR 0.79! DRHO.LDN 0,2~8 LS.LDR 280,972 $$!.LDR 303.360 S1RH.LD~ 2.086 ENPH.CNR 48,362 RCE~.CN~ 406,404 TNRA.C~!R 3,9~ RCF~.CNR 336,931 END UF DATA Center ~CEN.CNR RTNR.CNR CNTC.CNR CIDP.DTR CILD.DTR IDQF.DTR !IRM,DTR GR.0TR HTEN,DTR PEF.LDR !~U.LDR ~$RH,LDR ENeA.CNR ~CE~.CNR RTNR.CNR CNTC.CNR 12-AUG-!993 I4:10 2524.648 MPEI.CNR 4.538 NPOR.CNR I503.714 CFTC,CNR 47.595 38.765 0 000 76,500 869'204 28.671 ~77 ~80 268 784 2 470 6.100 2524,648 4,538 1503,714 IDPH.DTR ILD,DTR IMOF.DTR IIXM,DTR TENS,DTR DPHI,LDR OLS,SDR LL.LDR 5URH,LDR CFEC,CNR NPMI,CNR NPOR,CMR CFTC,CMR 58.928 5~.38~ 383.81 2:5 96 0.0o0 -249,383 44~5..000 2.308 -0.039 142.332 1442'754 2.495 418,560 58,928 52'386 383.818 T:' CNR '.NPH. RCNT.CNR CIMP.DTR CILM.DTR IIRD.DTR SFLU.DTR ~T~.~Te RHOB.bDR QSS.L~ 5ITH'5... SSHV..LDR CAb~.'FDR CNE,.CNR ?NPH.CNR RCN~.CNR PAGE: 22 5 ~ ,. 8 08 -16.903 32,603 2.496 !38,101 2.688 1327.,337 2'886 2738'707 51,808 1550,437 **~* FILE TRA!bER **** FILE NA~ : EDIT ,005 SMRVICE: : FblC VF~SIO~ : O01C0! DATF : 93/08/I~ MAX REC S~ZE : 4006 FILE TYPE : LO **** TAPE TRAILER **** SFRVICM gAHM : EDIT ORIGIN : FLIC T~PF NAME : 03301 CO~TINI.JATION ~ : 1 PREVIOUS TAPE : COu~EMT : ARC() ALASKa INC.,KUPARUK,1Y-34,50-O~9-~2382-00 **** REFL TRAILE~ **** SrRv!C~ N.~-~E : EDIT ODIGIN : ~L!C RFE!~ r,~A~E : 93301 cn~,TI NUATIOK! ~ PR~.;VIOUS REEl_. CO',c~E~T : ARCO AI.ASK~ IDlC.,KUPARUK,l¥-34,50-029-22382-00 , ****************************** ****************************** FIELD ~:At~I~.: ~ KLIPAR~'K RIVER BOROUG~ : N[!~TH SLOPE STATE : ALASKA lis T'ar:e ',.~'eri~!catir'~r~ ~ i ~t:ino cb].urr;ber,~er Ale...sK~ Co~:~>uti~,rj Cent:ar 24-SE;P,., ! 903 ;t! PAGE: TS'r STnI~:G 500292238200 ARCO ALASKa, INC, V F' $CHLLJNBERGER ~ZLL SER.,IC._,S 23-GEE-93 ~IT Rt.'N 2 ST 57 0 I 97.00 1.07. O0 -~ 5.0 O ~chlumberoer ~,las<a Con~;~utin~ (:enter 993 ~.i ::)9 9 TO 762 i i7' BIT TO GR 5 ~ , B!T r3 DEN 108 ~' i15 7~' D b ED, ]: AL '8640 . 8~ ..... ~t..,K O%::~S:ITY P~OCESS!:.,~G~ USED. ~AR~TE ....... ADDED SYSTE.::,:, DATA FRD~ DCJWNHOLE ~EMORY, DOWN~OLE lt~[)ICA%'OR SHOW::~ I~ D~:PTH TRACK, ~ , . , S~::CT:[c:~?.~ W~S FIRST bOGGED 15-JUL-93 ~ITHOUT C~',:TIRe LWD SECTIO~q ~AS .NOT !~OGGED ~'ITH cB'r, C F, RF, C SIZE TYPE: FI l.jE . ,, , ~ ~ .,, Fi,~SF, i[,T:'..;~ 0!.:~7~: FOR .... . . , ~ .~ . . < , .... ~,iS 'raoe Verif!.cat.i..on L, ist~.~m 8~$5o.0 ~547,n ~4:24,0 g420.5 84, i, 4., 5 ~:~410.5 9392.r~ 8.389.5 83'7q, 0 ~373,0 8359.5 ~345.0 ~340,5 1('~,~. 0 95.5 ............ . ........ ............ WP ! 6289'0. ~,~ w U, 2 7628,0 864:0.0 W!PELI~,~E CbT/GR ~'.~F 06-SEP-93. ALI, QTHER CLIRVE~ ~ERE CA~.:,,:iE[) '¢~ITH ~;~(:.,;R SHIFt[. Tfi~S F:I.~,E A ,S,) CO~TAI~q:S vERY E~¢}'~.~'~CE.D QF'O PRt. uESSEO R~S1STZVITY DAT~ ~tTH A ~' AVERAGE, :L¢~}"~ '?OOLS ?:,l~;R[!l :'qOT RON' BEL[)W ~540' DUE T(] HOLE CONDITIONS, THE CASEDHObK (;~:~ CQV~';RS THE ,3~,.~TE~VAL 8EbOv~ L~4D. S .,:IS Tar.~e Veriflcati¢:~ I,i'stJ..r'~q ~c~].umherg~er ~las~a C~mt.~ltJn~ Center 24-Sk;P-i993 ~1 ..'09 PAGE PI PI AP . DE ~)UYi~ ~URB RE PRO,.ES TYPE C.uASS ~f:)D NUmB $~ ~P EI.,EN " ,~.!.i: COU~ (HEX) 440853 O0 O0 4 4. 0 B 53 0 0 0 0 4 ,~ 0 ~ 53 t) 0 00 :4 4 O 8 5 3 0 0 0 0 ,14 C) 853 0 0 0 0 140853 O0 O0 440853 00 0 u 44c853 O0 ~ 4 n 853 00 O 0 -:l. ,~ (,:'85 3 00 0 0 4 4085 3 0 o c 0 44.~853 Of') OO 4 4 (;'853 fi 0 00 440853 ()0 O0 .. 0 . ,.. 1 I 4 68 0 0 0000 0 O0 0 1 I I 4 68 0000000000 0 O0 0 I I 1 4 68 0000000000 0 O0 <) I 1 1, 4 68 0000000000 0 O0 0 1 I I 4 68 0000000000 0 O0 0 1 ! ! 4 68 0000000000 0 O0 0 1 1. ! 4 6a 0000000000 0 O0 0 1 1 1 4 68 0000000000 0 O0 0 1 1 i 4 68 0000000000 0 O0 0 1 I 1 4 68 0000000000 0 O0 0 I 1 1 4 6~ 0000000000 0 O0 0 I 1, 1 4 68 0000000000 0 O0 0 1 1 ! 4 68 0000000000 0 O0 0 ! 1, I 4 68 0000000000 0 O0 0 I ! I 4 68 0000000000 0 O0 0 1 1 1, 4 68 0000000000 0 O0 0 I I 1 4 68 0000000000 -992 250 DS,:l.!O.¢4!nO -99g 250 PEF.MWD ,-999:250 e.,%. ~qwD -999:'250 RP.MWD -99q.250 VR~ ~I,;D -999.250 ROP.N D -999,250 FC~'~~,.. ,~'~'C). -99~..250 FET.~WD -999.250 DRHO.qV:D -999.250 PEF.~WD -~9q.250 RA.,q~D -999.250 RP.M~D -999.250 VRA.~,~D -999.250 ROP.MWD -999.250 FCNT.~;:~D -999.250 VET.~WD 2.388 DF:' h O. ,q ~'D 0.012 PEF.MWD 37.400 RA. ~WD 2.015 RP.MWD 1.811 VFA..,I~D 1.873 ROP.MWD ~5t~3.50o FCNT. :¢.wO 5.830 FET.MWD -999.250 -999.250 999.250 :999. so -999,250 -999.250 :999.25o 999.250 3.596 1.810 120.806 0.629 ,IS q'eoe verifJ, cation Listir,,O ;cblu.mt'~erq,,er ,,!asKa (lor~Puti. n~ Cent. er GR. ~:,;~D 73.643 GPC~. OPl~,J -999. 250 ** E?,iD OW r, ATA **** FILE TRa}.[,.F.i;? **** SERVICE : ?LIC VKR8 ID/'? : : 93109124 aEC SIZE FI[~E lt:99 2.372 D~HO,MWD 2.500 ¥~A.~{WD 7505.000 FC~T.~4WO 2.3~5 DRHO.~WD :~4.250 RA.NWD 7005.000 FCNT.i~4WD 2.302 DRH(!.?!~D -999.250 VRg.~O 65U5.000 FC~T.~4~D -0.006 2.279 2,609 6.687 -0.019 1.739 .974 5'987 -0 008 2 754 -999 250 6.675 -0.004 2 651 7.098 -099.250 D~HO.Mi(D 999.250 -999. 250 RA. a{;,~O -'999' 250 -999.25,.') VR~.~i:~D 2999.250 ':' u~vO 999.250 -999 250 PEF.MWD RP.MwD ROP.MWD FET.MND PEF.MWD RP,MWD ROP.MWD FET.MWD PEF.MWD RP.MWD ROP.MWD FET,MWD PEF,~D RP,~WD ROP.~WD FET.MWD RP.~WD ROP.MWD FET.~WD PAGE: 3.432 3.028 I!5.024 0.389 3.334 2'460 a. 699 0.431 3.122 2,768 2:03.354 0.339 3.336 2.799 164,199 0.324 :999,,2§0 999,250 -999. 250 -999'250 ~chlumberger ~lasKa Co,~pt]tinc [:enter 24-Sa:P-1993 I!:. PAGE: CL~rves and loq ~'~eader data for each hit r'~)~ l, rl se~arate files. Ti) 9RILLKR Ti]p LOG HOLE INCLINATIO:':~ ( ,,E .~(J;l/ I)ROSITY CDR RESISTIVITY STOP DEPTH 0 2,,d tJb-9'~ Fa:ST 2, BE V4. OC 9263 0 6289: 0 5O0 62~9.0 2.730 67.0 2.65 ich],umberger ~,laska Com~>utin<~ Cent, e~' PAGE~ $ P F, C I ii C A { I I'3 t:! F,'. E, C. _1 R P * * 1 3 7 9 1 I 1 ! 1 66 0 66 0 73 64 66 73 65 6~ 0.5 65 66 16 6~ 66 0 65 FT 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ;chlumber~,~?~r~ ..... Alaska ('ic~,~;utin~ Center 11:o9 PAGE~ ............... ,g t,~'~ ~ ~g slg~ RgPR pRoCESS D~::R L~';1 0 H i~ ~-' ,~:40 ~: 53 09 000 O0 0 2 ~ I 4 68 0000000000 ROPE !,'~,zl F/H~:~ ~;40853 0(:~ 000 O0 0 2 1 ! 4 68 ~000000000 GP L~.,' ! GAPI ~.4. o 853 00 000 O0 0 2 1 ! 4 68 0000000000 ~i Ft,~ ~ L~I CPS 440 ~353 0O 00C 00 O 2 ! t 4 68 0000000000 t4EFA L~'~I CPS 6.40853 oO 0O0 O0 0 2 1 i 4 68 0000000000 T ~ ~:~ Lwl HR ~40~753 0() 000 GO () 2 1 1 4 68 0000000000 T ~ Fi[:, b'w! t4P ,~ 40~ 53 gO oO0 09 0 2 1 I 4 68 0000000000 PE:V'. Lv~ 1 '999,25':: DC,a L. [,~' :[ -999.250 TNPH.LWl ~999.250 A~.LW1 ''~F' [:,~:~1, -999 255 ........ t~ , PS , ..... ue.,.~.,~,,,,,~l -999.P~0. ~ ROPE.LWl 31.359 G...LWl HEN ~. I,~ ! 7627.50C, ~.~EF ~%. l,~ i -99~.250 TA~,. L~ .! -999.250 TABD.LW! D F P T. 7500. (~ C, () R H O ~"~ b ~ 1 2.372 I) P H t. 1,, w I 16.800 D ' PEF'.[~!~I ' 3.353 [)CAL'L~!. 0.149 TNPH.LWl, 36.300 ATR:LW! n8~. [,~,~ 1 2.047 bE:R. L~ 1 t .96] ROPE.LWl 139.544 },.~Er~,a. bx ~ 7500,500 HEFA.i,~: ! 6.426 TA6. L,,wl 0.~39 TABD.LW! D F p 3 70 ~ ~,.. ~'~ ('~ 0 R ~i 0 ~,. L ~,,~ ! 2.355 D P H i, b W ! 17 9 O 0 D R H 0. L W ! PEF l,zI 3 2q5 ~.CAI,.L 1 O,O(}O TF~PH.LW1 33:200 ATR.BWl PSP I~l 2 6~a I)[;:P.:!:,~41 2 699 ROPE,L~41 2~0 250 GR.L~I I ,] ~ ~ ~ ., ,~ ~ , I , I..~F r4 ~. L'v,~ ! 70()e, 50(; F;'E: P.&. [,~; 1 6,990 'I"A B, bw 1. 0.332 TABD.LWi D~PT. 65()b, ~3r; {,) R~!UB. [,~ 1 2.302 DPHI.L~I 21.100 DRHO.LW1 PEP.b~,~I 3.!6h DC~,L.L,w! 0.000 ~i~iPH,LWl 35 500 n,.p [,,~l 2'6n2 F~FiP LwI 2 487 ROPE,LWl 1651411 GR,[,~I. r ~) "L ~ . · ,..,..~ ~ e I · . DBiPT. 6104, L,C,O F: HOF, [.,w 1 -999.250 OPgI.b~! -999.250 DRHO.LWl PEV. [,,V 1 -999.250 DCA 1-~. LX~ 1 -999.250 T~,~PP. LW! -999.250 ATR.LWI PS~:. l_, u< 1 -999.250 DER. L~,~t -9~9.250 ROPE.LWI -999.~50 GR.LWl HV i,,~ ~. I~?.~ 1 6194.50(, }4~;:F A. l.,', 1 4.980 T!~B, I,;~ 1 -999.250 TABD.L~I %999,.250 .999,250 999,250 -999.250 I 9',49680 1.~9 0.001 2,722 108,014 0,724 -0..012 2,331 74,842 0.867 -999,250 -999.250 -999,250 -999.250 .,IS Tar)e verification [,!sti.qo ;ch!um~erger A!as~a Co~,~uting tearer 24--SEP-1993 i1:09 PAGE: data for' o o 762~.0 'l.' D ~ !T Ct,~.rves and lo,~ head, er LOG ~{E~[)ER. DATA RO~ATI~G 8~.~EF:O (RPq): ! X ! :..'i I } :','~ ANG!~F<: each bit run l.u $ CODE TOn!, TYPE ............ R~:STS'~IV 9PEi,~ t-!Cl.,( ~3IT SIZE (!~'): ~'~l.}D DEr4SITY (I.,?,/G): t.'l;O VTSCt)S['~Y (8): STOP DEPTH o 864~,0 se~ar8t, e files. 02-JUL-93 FAST 2,3E v4.0C ~E~ORY 926].0 7628.0 a640.0 · OC)b ~!U~BER N [, S 05 2 RG8043 ~.500 62~9.0 10.50 ~i$ Tane ver~,ficatios 'List. inQ ichlumberger ~lesk:s ComoutinS Center 2~,~8EP.,,! 993 11:n9 PAGE: 1¸0 ~,4~TP IX: ;'-;~ t~ T R I X DELi:SI TY: HOLE C[}~'~F;CTI¢i~i (I~): 2,730 8().0 67.0 2.65 8.500 ********** 2 ********** ....... ' ' 6.. ' ' 8' BIT 7'0-,E[',P 11~.76 D~ILL D I~(~TERV,~L 762 13 8640 . TD ~aOR:39 [)t~; 05-jUL-9], ~ 5 (Gi~/CC) FbUiD DE,~'~SITY 1 0 (G~/CC) ;:"':f T!ONAL ~:~UI,,K DE~SITY~ PRO~JESSING [JSEt2 BA~TE ADDED '~')T~'jt.~ SYST~7~,~. DgT~ FRO~ DOWr~H[3LE ~E~'IOR~. DOwNHOLE SOTT,.,,APE VERSIO~ ~4.0C. SLIOI?,~(; I~,~DICAT(2~ SHOWN IN D~',PTH TRAC~. Lv~[) TOOLS ~/ERF ~OT ~[,JN SF':b[J)~ 8640' DUE TO HOLE PROBLEMS ~IS Tape veri..fIcation ~chlumberger i~!asKs Comp~tlng C" e ~ t e r 993 PAGE: I1 :3:: ,'"'"'"'""'"'""'" ::::--:.-- .... ..... ......... ...... ..... ... S!~.a.V K AIC P.I: APl APl API FILE NU IZE REPR PRO ESS LOC TYF~E C,b Ao8~ ~- t,,D'": ~:~ i,..~ ~: B 5 A ~-~ P EbEM CO DE,' (HEX) 440:53 oO oo0 O0 0 3 ! 1 4 68 0000000000 440~53 oo 000 oo 0 3 J. I 4 68 0000000000 44(;>~53 O0 noo O0 o 3 ! l 4 68 0000000000 440g53 O0 000 O0 (~ 3 1 I 4 68 0000000000 4~0~53 O0 C:O0 O0 0 3 1 t 4 68 0000000000 a40~53 Oe o0() ~)0 0 3 1 1 4 68 0000000000 440~53 O0 OOO O0 0 3 1 i 4 68 0000000000 440~53 O0 000 O0 0 3 1. I 4 68 0000000000 440853 O0 000 O0 0 3 I 1 4 68 0000000000 440~53 O0 000 O0 0 3 1 1 4 68 0000000000 ~40~53 0<) 000 O0 0 3 i I 4 68 0000000000 440653 ©0 o00 O0 0 3 I 1 4 68 0000000000 4.~0~53 O0 OOO O0 0 3 I. ! 4 68 0000000000 ** [)ATA ** i)FPT. UEF.I~W2 DF: p '.,'!". PEK, Li~!2 PS~. I,v,' 2 1) ~, p 'r' ~,% [:t. l, ,:2 H_ F: :: ;--,'. L .~ 2 ~500.OOG RHCi~i.L:,~2 2.4(38 DPHI.b82 1~.650 DRHO.LW2 3.~;a3 nmlb. I,~:,2 o.lg4 Tb~PH.LW2 38.400 ATR.LW2 2,145 "f:iKR.b:,!2 2,137 ROPE.L~2 119.603 GR.L~2 269.(~25 HF:FA.LV, 2 5.799 TAB.bW2 0,634 TABD.LW~ 383 r)PH I. I_,,? 2 16.150 DRHO b~2 O. 1.97 TiiPH. I,,V2 39.900 ATR,LW2 682 R r) P .LW2 125. 103 ~R.BW2 ~.781, )'A :3. ht:~2 0.394 TABD.L~{2 75(.ii,. {~,~(; ~ ;~06. i'.,:.'/2 ?.4U7 DPHI.LW2 14.750 DRHO.L~2 z ~;61 r)(TAl, i.,~',2 0 235 T~tP:i.L~2 36.250 ATR.Lm2 .., . ,,, --~ ..,-' t, . ~ · ,., -aaq.z.~C <.,K~:..Lv2 '999 250 R[:JPt;~.LW2 -999 250 GR,L~2 2gO.MP~: ~F:F;'~.i ~:2 ~.257 '.?A~,L~.2 -999.250 TABD.LW2 -999 250 -999.250 -999.250 0,005 2 127 116:793 1.,968 '0,009 2.296 105.91.4 1.953 0,000 -999,250 -999,250 -999,250 icb!umber~Ter Al. asKs Co,~Dutincf Center PAGE: -99~.250 DPPI,L~2 -999.250 T~PH.L~2 -999,250 ROPg. BW2 6°280 TAa. L~2 ,,999.250 999 ' ~50 FI[~F ~<~A~Y : EDIT .003 VERSIOH : [).~ T~ : 93109/24 F!LK TYPE bAST FISE : **** TAP[<: TRA i!jE;R SFRVIC~] NA?4E t EDIT DATP : 9~/0Q/24 OPIG I~ : FLIC TAPF N'AME : 93296 PR Ev IOl...I8 TAPE : Co;~ME~T : A~-~CO A~!.,ASKA, I~C.,KUPARi}K RIVER Ut:.!IT~ 1Y-34,50-029-22382-00 D~TF RF'EL ~.',AhE : 93296 PREVIOUS RE~b C~4t~'l~:'!" ~ n~.iCO AbASKA, INC.,KUPAROK RIVER U!'JIT, 1Y-34,50-029-22382-00