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193-071
STATE OF ALASKA AL/IL OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon EPlug Perforations I-••••. Fracture Stimulate Pull Tubing 1- Operations Shutdown r' Performed: Suspend E Perforate I Other Stimulate I Alter Casing E Change Approved Program 1', Plug for Redrill Perforate New Pool I- Repair Well VRe-enter Susp Well I® Other: Tubing Patch Ii 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F. Exploratory fl 193-071 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic L Service 50-029-22370-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25646 KRU 1Y-23 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 7500 feet Plugs(measured) None true vertical 6371 feet Junk(measured) None Effective Depth measured 7388 feet Packer(measured) 6836,7093 true vertical 6281 feet (true vertical) 5849,6048 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 3852 9 5/8 3893 3590 PRODUCTION 7439 7 7477 6353 RECEIVED DEC 0 6 2016 Perforation depth: Measured depth: 6927-7024,7166-7170,7180-7206,7226-7242 True Vertical Depth: 5919-5994,6105-6108,6116-6136,6152-6165 OC Tubing(size,grade,MD,and ND) 4 x 3.5 x 2.875,J-55/L-80,7121 MD,6070 TVD Packers&SSSV(type,MD,and ND) PACKER-CAMCO HRP-4-SP RETRIEVABLE PACKER @ 6836 MD and 5849 TVD PACKER-BAKER D PERMANENT PACKER W/5'SEAL BORE EXTENSION @ 7093 MD and 6048 TVD SAFETY VLV-OTIS 4"SERIES 10 FEX SELF EQUALIZING SAFETY VALVE @ 1799 MD and 1798 TVD 12.Stimulation or cement squeeze summary: {�y rk r Intervals treated(measured): IED ilii Are, 8 LO};' 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 14 7 1892 - 221 Subsequent to operation 16 253 1174 - 202 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1✓ Exploratory Development F Service I- Stratigraphic 1- Copies Copies of Logs and Surveys Run fl 16.Well Status after work: Oil I✓. Gas WDSPL L Printed and Electronic Fracture Stimulation Data E GSTOR I- WINJ 1 WAG -. GINJ r SUSP �. SPLUG 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: N/A -C. _ _......? Contact John Peirce Cir)265-6471 Email John.W. Peirce( conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date j.2151.G 104._ Form 10-404 Revised 5/2015 (/TL Z I l !// Submit Original Only � �� RBDMS 1,u DEC - 82016 • • 1Y-23 DTTMSTP JOBTYP SUMMARYOPS 11/10/16 TUBING/ PULLED 3 1/2"TTS TEST TOOL @ 6870' RKB; BRUSH n' FLUSH CASING PATCH INTERVAL FROM 6800'-6870' RKB. READY FOR E-LINE. PATCH 11/15/16 TUBING/ RIH WITH PACKER. CCL STOP DEPTH =6835.5' KB. CCL TO ME= CASING 11.5'. ME SET AT 6847' KB. PACKER SN: CPP 35082. SIT DOWN TO PATCH CONFIRM SET. PULL OUT OF THE HOLE. RDMO. JOB COMPLETE. 11/18/16 TUBING/ SET 29.5' SOS PATCH (2.72" PII PKR#CPP35044, SPACER PIPE, CASING ANCHOR LATCH#CPAL35054/ 1.62" ID) @ 6818' RKB USING HES DPU. PATCH MITT TO 2000 (PASS). COMPLETE. KUP P D 1Y-23 ConocoPhillips 4 Well Attribut Max Angle I TD Alaska in,. Wellbore APW WI Field Name Wellbore Status Inc'(°) MD(ftKB) Act Btm(ftKB) CtifleA hitIi)$ 500292237000 KUPARUK RIVER UNIT PROD 40.94 4,692.26 7,500.0 ... �• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 11-23,12/5/20162.32.41 PM SSSV:TRDP 75 8/11/2015 Last WO: 4/150994 6/10/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag-SLM 7,304.0 6/6/2016 Rev Reason:SET PATCH pproven 12/5/2016 114 Jr HANGER;37.6 III, Casing Strings Casing Description CONDUCTOR OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 41.5 3,893.0 3,590.3 36.00 J-55 BTC 11111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(ND)... Wt/Len It...Grade Top Thread PRODUCTION 7 6.276 38.0 7,477.1 6,352.8 26.00 L-80 BTC-MOD CONDUCTOR,42.0-121.0 III- Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/It) Grade Top Connection TUBING 4x3 5x2 875 4 3.476 37.6 7,121.0 6,069.6 10.90 J-55 BTC-MOD SAFETYVLV;1,798.7 f. Completion Details ■■■■ • Nominal ID ill i Top(ftKB) Top(TVD)(ftKB) Top Mel(°) Item Des Corn (in) Ilt 37.6 37.6 0.17 HANGER FMC GEN IV TUBING HANGER 4.000 GAS LIFT,2,391 9 Ir 1,798.7 1,798.3 6.94 SAFETY VLV OTIS 4"SERIES 10 FEX SELF EQUALIZING SAFETY 3.313 I . VALVE III 3,640.7 3,393.8 37.66 XO Reducing CROSSOVER 4 x 3.5 3.500 r 6,813.9 5,831.9 39.92 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 4 6,822.3 5,838.3 39.87 PBR CAMCO PBR w/10'SEAL BORE 2.937 4 6,835.6 5,848.6 39.79 PACKER CAMCO HRP-4-SP RETRIEVABLE PACKER 2.937 GAS LIFT;3,848.46,926.9 5,919.2 38.99 BLAST CARBIDE BLAST RINGS(4) 2.992 RINGS 7,082.0 6,039.2 39.09 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE-CLOSED 10/9/03 2.750 i 7,090.4 6,045.8 39.01 XO Reducing CROSSOVER 3.5 x 2.875 2.875 1 7,091.2 6,046.4 39.01 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.440 SURFACE;41 5-3,893.0-----. L 7,093.3 6,048.0 38.99 PACKER BAKER D PERMANENT PACKER w/5'SEAL BORE 3.250 EXTENSION 1:iii GAS LIFT;4,824.0 7,110.0 6,061.0 38.86 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,120.4 6,069.1 38.79 SOS CAMCO PE 500 SHEAR OUT SUB(CLOSED)ELME) 2.441 TTL @ 7107'during PPROF on 11/23/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5,5256 Top(ND) Top Incl in Top(ftKB) (MB) (°) Des Corn Run Date ID(in) 6,818.0 5,835.0 39.90 PATCH 29.5'SOS PATCH(2.72"PII PKR#CPP35044, 11/18/2016 1.620 SPACER PIPE,ANCHOR LATCH#CPAL35054/ 1.62"ID) GAS LIFT;6,190.1 6,847.0 5,857.3 39.72 PATCH .PIIP-PACKER. MAX OD=2.72" 11/15/2016 1.620 6,870.1 5,875.1 39.45 PATCH 2.72"SOS UPPER PIIP(ser#cpp35091),25.48' 9/24/2016 1.620 SPACER PIPE 8 SNAP LATCH(oat=30.84') 6,901.0 5,899.1 39.11 PATCH '2.72"SOS LOWER PIIP 9/24/2016 1.620 GAS LIFT;6,769.8 (ser#cpp35078/oat=4.02',1.62"id) 111 11 Perforations&Slots NIPPLE;6,8139 �� I Shot Dens a� Top(ND) Btm(ND) (shots/ FOR;6,822.3 ',■E, E Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,927.0 7,024.0 5,919.3 5,994.4 C-4,C-3,C-2, 9/12/1993 12.0 IPERF 4.5"SWS HyperJet II; PATCH;6,818.0- r.r'..7 C-1,1Y-23 Spiral Phasing PACKER;6,835.8 - -- 7,166.0 7,170.0 6,104.8 6,107.9 A-5,1Y-23 7/27/2010 6.0 APERF 2"Millenium HMX,60 I, deg phase PATCH;8,6470 i 7,180.0 7,206.0 6,115.8 6,136.3 A-4,1Y-23 9/12/1993 4.0 IPERF 4.5"SWS BH Ultra Pa; `I 180 deg.Ph 7,226.0 7,242.0 6,152.0 6,164.7 A-3,1Y-23 8/6/2004 6.0 APERF 2"HSD,2005 PJ HMX Charges PATCH;6,870.1 ,1 Mandrel Inserts PRODUCTION;6,882.2 It I St atii ( ° Top(ND) Valve Latch Port Size TRO Run PATCH;6,901.0 II Ii N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i 2,391.9 I. CAMCO KBUG 1 GAS LIFT GLV BK 0.15611 11 IPERF;6,927.0-7,024.0- I;'.- •11 • OV RK 0.188 0.0 11 1 4,302.1 • DMY RK 0.000 0.01/8/2007 CAMCO DMY RK 1 111 0.0 4/15/1994 91 • DMY RK 0.000 0.0 11 SLEEVE-C;7,082.0- CAMCO DMY RK 0.000 0.0 11 ((!! CAMCO 0.000 0.0 1 16 � i Notes:General&SafetyEnd Date Annotation SEAL ASSY;7,091.2 -ih' 2/20/2010 NOTE.Possible Leak @ 6917'from PPROF1/31/2010 PACKER;7,083.3 10/27/2010 • ••' •BOTTOM CIRCULATION al 10/27/2010 • •1 NIPPLE;7,110.0 X I SOS;7,120.4 APERF;7,186.0-7,170.0 IPERF;7,180.0-7,208.0- a APERF;7,228.0-7,242.0 I PRODUCTION;38.0-7,477.1 • . O �9 a, I o m o v al LE 3 r o 0 z - - '• ' @ >" ra h Z w � oco v Lo v 1—�Y O cO +, 0 0 aJ u `L/ U a` a c c +-+ 0 ...4 iU Qm 0 0 m CD CD CD m cD 0 0 CD CD oCr m Q �i > > > > > > > > 0 0 0 0 0 + ) n 1!° . . . . . . . . . . . . . 0 0 0 0 0 0 0 O O i +� rp '^ '' w Z Z Z Z Z Z Z Z Z Z Z Z Z c c u v 2 N N C+) M 8 CD I` 0) 0 0 . 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LL a a a a a a a a a > > > > > > > > > 0 Y Y Y Y Y Y Y Y Y C3 cc a W CD M M CO N M N X N O O O O o N 0 0 0 ra cc N 0 0 0 0 O O O O O 0 O O O 0 - O o 0 o O O O o O CV f6 �.� u 0 ❑ ❑ ❑ -) U U U 6 E U U U U Y co co oo N CD I� > >- >- Y >- 2 0 0 0 2 W G�7 `/ w 000000000 a � ° VI Q as c 1 i 1 -> 0 0 o 0 0 0 0 0 0 o u IiY �D o 0 0 0 0 0 0 0 o 0 N O O O NN U)N O CC Tr )n r•• N v N•cr CA VI el •or co M M O el OO E N 0 N N N 0 M M M h 0 n N N N N N N N N N i u N n O) O O 666, 666 O 0 0 NNNNNN NNN L r,,01 o 0 0 0 0 0 0 0 0 G) s O o 0 o O O O O O in iin in in O s- c.) L c « CL o C E CD 4=1 4," ^i Q OO N M M o 1;-1' �f) In 8 e ygp Z N O N N N O O o E CU 1- n 2 a Q L" N alal - r - C) ,- m m E Z co 9 _ a a, t= a a Q 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. /(:::::[ ~ '-0'7 ( 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: Scanned by: Beved~ncent Nathan Lowell Date: D TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1Y-23 Run Date: 7/27/2010 August 5, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-23 Digital Data in LAS format, Digital Log Image file 50-029-22370-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fax: 90 klinton. AUG 1 1 2010 Dat ~` ~~ `°` o~~. Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1Y-34 Run Date: 7/27/2010 August 5, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-34 Digital Data in LAS format, Digital Log Image file 50-029-22382-00 A r. _ ..... 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Dom' ~~ ~~ ~ ~o~ Date: A l1 G 1 1 ~ (11(1 Signed: lam. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS t operations Performed: Abandon ~' Repair w ell ~ i Rug Ft?rforations ~ Stimulate Other ~I Alter Casing ~"° Pull Tubing ~"" FZ?rforate New Pbol Waiver Time Extension ~ Change Approved Program Operat. Shutdow n Perforate Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: ~. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~~ Exploratory ~ 193-071 3. Address: Stratigraphic Service ~` API Number: ~ P. O. Box 100360, Anchorage, Alaska 99510 50-029-22370-00 7. Property Designation: 8. Well Name and Number: ADL 25646 ~ 1 Y-23 9. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7500 feet Plugs (measured) None true vertical 6371 feet Junk (measured) NOne Effective Depth measured 7388 feet Packer (measured) 6836, 7093 true vertical 6281 feet (true vertucaq 5849, 6048 Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16 121 121 SURFACE 3893 9.625 3893 3590 PRODUCTION 7477 7 7477 6353 ~,~ 5~~~ _ ~. ~ "~ 201G' Perforation depth: Measured depth: 6927'-7024', 7166'-7170', 7180'-7206', 7226'-7242' ' ~j~3;~8 ~"~+ ~~~ ~'''~t~SI4f1 ' ' 8 ' ' ' -6165 True vertical Depth: 5919 -6136 , 6152 -5994 , 610 0165 , 6116 €._1~1l~1;~~p Tubing (size, grade, MD, and TVD) 4, 3.5, 2.875, J-55, L-80, 3641', 7090', 7121' MD, 6070 TVD _ _ _.. Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP-4-SP PAKER @ 6836 MD and 5849 TVD PACKER - BAKER'D' PERMANENT PACKER W/ 5' SEAL BORE EXT. @ 7093 MD and 6048 TVD TRDP - OTIS 4" SERIES 10 FEX SELF-EQUALIZING @ 1799 MD and 1799 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured : 110h a livable ' ` ~~~ ~~~~' ,?~.. ~~ Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 340 1263 3163 -- 176 Subsequent to operation 355 1387 3349 -- 174 13. Attachments 14. Well Class after ro osed work: P P Copies of Logs and Surveys run Exploratory Development Service 15. Well Status after work: Oi Gas ~ WDSPL Daily Report of Well Operations _XXX GSTOR ~ WAG ~" GASINJ ~ 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. Exempt: none contact John Peirce aC~. 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ ~ Phone: 265-6471 Date ~/~~~~~ AUG Form 10-404 Revised 7/2009 ~ ~-/Z -!!) Submit Original Only • 1Y-23 Well Events Summary DATE SUMMARY 7/20/10 DRIFTED TBG WITH 10' x 2.125" STEM; TAGGED @ 7324' SLM. READY FOR. 7/27/10 PEFORATED AT A DEPTH OF 7166'-7170' USING A 2" X 4' GUN, WITH 6 SPF, 60 DEG PHASING, MILLENIUM DEEP PENETRATING CHARGES. LOG WAS CORRELATED TO SCHLUMBERGER CBL LOG DATED 6/17/1993. TUBING TAIL FOUND AT 7107', 14' SHALLOW OF TUBING TALLY. ~~c~eoPhlli~-s ... ..r;R<7 fnri. _ .Y?el1 CP flg t Y 22.8/5720' __. ___ _ S h matte-ACy CONDUCTOR,- _.__~ 121 SAFN VLV, _..... 1,]99 GAS LIFE, _.._.. 2392 GAS LIFT, 3,fi49 SURFACE, 3,853 GAS LIFT, 4,624 II GAS LIFT. _ 5,526 GAS LIFT. _._. 6,190 GAS LIFT, ___. 6.7]0 NIPPLE. 6,814 PBR,s.ez2 PACKER, 6,636- i PRODUCTION, 6,882 ..... SLEEVE-c, ],062 PBR, 7,091 PACKER, ],G93 -' -' NIPPLE, ],110 SOS, T,120 TTL, ],121 APERF,_ ° ],166-7,1]0 IPERF,__ ],180-],206 T APERF, __ _ 7.226-],2d2 PRODUCTION, 7,4]] TD, 7,500 KUP # 1Y-23 1 Well Attribut es Max _ Angle 8 MD iTD Wellbore API/UWI Field Name 500292237000 KUPARUK RIVER UNIT _ _ Well Status Inc! (°) MD (ftKB) (PROD 40.94 I 469226 Ad Bim (HKB) 7,500.0 Comment H25 (ppm) Date Annotation End Dale KB-Grd (HJ Rig Release Date SSSV: TRDP ( ~ 7S 816/2009 / Last WO: 4/15/1994 _ 6/10/1993 _ Annotation - Last Tag: SLM 'Depth (ftKB) IEnd Date Annotation 7,324.0 7/20/2010 Rev Reason: PERFORATIONS Last Mod By Imosbor IEnd Date 8/6/2010 Casco Strin gs _ __ Casin Descr t CONDUCTORp String OD Skiing ID on (in) (in) 'i i6 15.062 To HKB P.( 0.0 Set Depth (ftKB) 121.0 SetDepth (ND) (HKB) 121.0 String Wt (Ibs/ft) 62.50 Strmg Gmde H-40 String Top T_hrd 6.151 0.0~ 7,477.0 6,352.7 26.001E-80 ~ ng ID Set Depth Set Depth (ND) String 4V1 String Inl Top (ftKB) (HKB) (ftKB) (Ibslft) Grade Slring To 3.344 0.0 3,641.0 3,394.1 11.00 J-55 BTC-MOC 2.992 3,641 0 6,844 0 5,855.01.. 9.20 J-55 EUE SRD 2.992 6,844.0 7,0900 6,045.4 6.001'L-80 •EUE SRD 2441 7,090.0 7,121.0 6,069.6 6.50{L-80 EUE SRD (TVD) Top Inc! (ftKB) (HKB) (°) Description Comment Run Date _ ID (in)_ 1,799 1,798.6 6 95 SAFTY VLV Otis 4" Series 10 FEX self-equalizing 4/14/1994 3.313 ____- 2,392 2,370.7 23.03 GAS LIFT CAMCO/KBUG/1lGLV/BK/_156/1290/ Comment STA 1 1/8/2007 3.395 3,649 3,400.4 37.64 GAS LIFT CAMCOIMMG-2/tSIOV/RK/.188//Comment: STA2 1/8/2007 2.922 4,824 4,302.1 40.75 GAS LIFT CAMCO/MMG-211.5/DMYIRKI!/Comment: STA 3 118/2007 2.922 5,526 4,836 8 39.86~ GAS LIFT CAMCO/MMG-2;15/DMY/RK/!/ Comment: STA 4 4/15/1994 2 922 6,190 5,351.7 39.05 GAS LIFT I CAMCO/MMG-2/LSIDMY/R W// Comment: STA S 7/8/2007 2.922 6,770 5,798.3 40.19 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK/I/ Comment STA 6 1!8/2007 1 2.922 6,814 5,832.0 39.92 NIPPLE Camco'W-1' Selective Landing NIPPLE 4/14/1994 2.813 6,822 5,838.1 39.87 PBR Camco w! 10'seal bore PBR 4/14!1994 2.938 6836 5,848.9 I 39.79 I ~PACKER '. Camco HRP-4-SP PAKER 4174/1994 2.938 -- 6,882 5,884.3 39.25 PRODUCTION CAMCO/MMG;1.5/HFCV/RKP///Comment TOPAND 9!2812008 1 2.922 BOTTOM CIRCULATION STA 7 7082 6,039.2 39.08 SLEEVE-C Camco C6-1 Sliding Sleeve-CLOSED IO/92003 9/10/1997 --. _ 2.750 7,091 6,0462 39.01 PBR Baker'GBH-22' LSA PBR 4/14/1994 3.000 7,093 6 047 8 38.99 PACKER Baker'D' PERMANENT PACKER w/ S' Seat Bore Ext. 4/1411994 3.250 7,110 6,061 NIPPLE Camco'D' Nipple NO GO 4/14/1994 2.250 - /,120 _ 6,068 8 ~ 38 7 SOS Camco PE 500; CLOSED 4/14/1994 2.438 7.121 6,069 C 38, 78 ~. TTL __. ELMD 1TL @ 7107 during PPROF on 11/23/2006 __ 4/14/1994 2.438 rfora tions 8 Slots _. __.. _. ..---snot) Top (TV D) Btm (ND) ~ Dens (HKBJ Bim (ftKB ).. (HKB) (HKB) Zone Date (ski... Type Comment 6,927 7,024 5 919 .2 5,994.4 C -0, C-3, C-2, 9/12/1993 12 0 IPERF 45"SWS HyperJet II; Spiral Phasing C- 1, 1Y-23 7,166 1 7,170 6,104 .8 fi,107 9 A- APERF 2' Millenium 5, tY-23 7/27/2010 6 0 HMX, 60 tleg phase 7,180 7,206 6,115 .9 6,136 3 A -0, tY-23 9712/1993 4.0 •,IPERF 4 5" SWS BH Ultra Pa; 780 tleg. Ph ! 7226 - 1,242 6,152 0 6,164.7 A- 6,O ~APERF 2" HSD, 2005 PJ HMX Charges 3, 1Y-23 8/6/2004 des: Genera l 8 Safety End Date Annotation _ __ )12010 NOTE Possihle Leak a~ 691T from PPROF on 1!31/2010 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1Y-23 Run Date: 1/31/2010 February 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 Y-23 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-22370-00 Production Profile Log t ~, P, ~~, 50-029-223 70-00 ~ ~ ~ `~~ ~ ~~' p rt ~ ~~ ~: ~~ .; 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com l~3 "~~l ~~'/~ ~! Date: ~~ ~1 ~ /~ '~ Signed: ;~,~ L.- ,;' ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~3.07~ l/ 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 pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 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. Sincerely, ~~~ ~ ~, M.J. Loveland ~~' AU G ~ ~~ 208 ConocoPhillips Well Integrity Projects Supervisor .] ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/30!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 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1 Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4,90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 11/28/06 Sc~lumb8Pg8P NO. 4054 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV ~", ~) zoun Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 103-0-1-( Kuparuk Field: Well Date BL Color CD Job# Log Description 3B-13 11415652 PROD PROFILE WIDEFT 11/16/06 1 38-07 11502019 SBHP SURVEY 11/19/06 1 3S-10 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1Y -23 11502022 PROD PROFILE W/DEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24106 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-Ð9 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê-ll ~ . . Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~ i iii ps P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-263-4574 September 3, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1Y-23 (APD # 193-071) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 Y -23. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J1,J1~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED SEP -7 2004 AI.skl all & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Perfonned: Abandon D RepairWell D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 193-0711 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchoraç e, Alaska, 99510 50-029-22370-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 107' 1Y-23 8. Property Designation: 10. FieldlPool(s): ADL 25646, ALK 2577 Kuparuk River Oil Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7500' feet true vertical 6371' feet Plugs (measured) Effective Depth measured 7351' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3852' 9-5/8" 3893' 3591' PROD. CASING 7436' 7" 7477' 6353' RECEIVED Perforation depth: Measured depth: 6927'-7024',7180'-7206',7226'-7242' SEP - 7 2004 true vertical depth: 5919'-5994',6116'-6136',6152'-6165' AI88ka Oil &'Gas Cuns. Commission Anchorage Tubing (size, grade, and measured depth) 4'x3.5'/2-7/8', J-55 1 L-80, 7121' MD. Packers & SSSV (type & measured depth) pkr= CAMCO HRP-4-SP; BAKER 'D' PERM. W/5' SEAL BORE EXT. pkr= 6836'; 7093' SSSV= 1799' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RIIJMS 8F l SEP 0 7 'JfHIÌI Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 108 315 187 -- 191 Subsequent to operation 83 254 434 -- 156 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A i! C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature )J,d, I j Phone Date ~ 3~1- Pr"n~r"rl ~t.c,h~~ n AI/."n-nrak" M.~-.d"I? l ( J Form 10-404 Revised 04/2004 OqfGfNAf Submit Original Only 1Y-23 Well Events Summary Dme Summary 08/06/04 PERFORATE THE INTERVAL 7226' - 7242' USING 2.0" HSD GUN lOAD 6 SPF, 60 DEG PHASING WI 2006 POWERJET HMX CHARGES. API CHARGE DATA: 17.9" PENETRATION, 0.2" ENTRANCE HOLE. [Perf] 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. .SUMM .A..,.Ry: 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. Attachments: svs KRU 1Y 5-17 & 18-01jc cc; NON-CONFIDEN,T. IAL SVS KRU 1Y 5-17 & lS-0ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kupamk River Unit 1Y Pad Separator psi: LPS 85 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 1Y-01 1830500 1y'02 1830590 1Y-03 1830610 3750 2000 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 3750 2000 '1750 P P WAG 1 Y- 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 8~ 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL 1Y-22 1930700 85 60 55 P P OIL i~23 :~::'~i ~:~:~'~'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 19~0880 85 70 64 P e OIL !1Y-28 1930890 ' 1Y-29 1880910 85 70 60 P e OIL . 1Y-30 1880900 85 70~ 70 P P OIL 1Y-31 1930900 1 Y-32 1880930 85 701 70 P P OIL 1Y-34 1930910 85 70 65 P P OIL Wells: 16 Components: 32 Failures: 1 Failure Rate: 3.13% [2] 90 r>ay i i ~ .'Retest }Veil Type ~ :-~::~--~-~:':~-5;.~---~:~,:~:~,~:~::;~ &~:~:~;~:~7:~:~7~:;~`:c~.~.~:~:~:~&~' ~.~ ~ ::;,- ~ ,! .'~ _ ~ '~ . . : ~ Weil Permit Separ Set L/P Test Test Test Date Oil, WAg, ¢INJ, Number Number PSI PSI Trip Code Code Code Passed (;AS 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 W MATE IA~L UNDER --~ H IS M ARK ER C :LORIXMFILM.DOC G :-; o i o g... i c a 'i M a 't: .:,:'.~ r" i' :~, 1 s :l: n v ,3 n i: o~' y .j 93-'~071 ~9r'~6 93'.~071 L. 07 93--07 i DAILY 'c/ELL, OP 93 07 I ,',3E.l' 9 3 '*' 0 7 i C D N !.... 'd D/' D C 93 .... 07 i 9 ~ - 0 71 9~-*07 ~ 93 0'? 1 93--- 07 'i 9 3 0 7 'i r. D R L ~,,,? D/; D r' CDR:/VER C ET' CNTG-~ DC DCN/CI'.I/CNTG TDTF' TDT?-'-DC ()8,//2:)// 'J 993 t) 8 / ::'." '.) / i .9 9 3 06 ,." 2 !~ / 19 .,9 :: '1 'J/' ~)!:',/' 'J 99 3 0 9/:?'i / 'J 9 93 (') 9/'" 2 :;//' 1993 'l I ./(.:~ .9 ,/ i 99 ?, Ar'e dr'y i,,,¢,:.:~ s t. h e /::,i"e We] 'J We'i 1 i s (': O M M i: iq 1- S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface /'~ 568 FNL, 1342' FWL, Sec. 1, TllN, R9E, UM(j(~',X~), At top of productive interval 2313' FSL, 2197' FEL, Sec. 1, TllN, R9E, UM At ,effective depl, h '~4 2076 FNL, 2037 FEL, Sec 1, T11N, R9E, UM At total depth 2019' FSL, 2003' FEL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 107', PAD 66' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Y-23 9. Permit number/approval number 93-71 10. APl number 50-029-22370 11. Field/Pool Kuparuk River Oil Pool 7500' feet Plugs (measured) None 6371 ' feet feet Effective depth: measured 7388' feet Junk (measured) true vertical 6281 ' feet Casing Length Size Cemented Measured depth Structural 80' 16" 234 Sx PFC 121' MD Conductor Surface 3852' 9-5/8" 650 sx Perm E 3893' MD Intermediate 450 sx Class G Production 7436' 7" 250 sx Class G 7477' MD Liner Perforation depth: measured 6927'-7024', 7180'-7206' MD True vertical depth 121 'TVD 3591' TVD 6353' TVD true vertical 5919'-5994', 6115'-6136' TVD' ;.!."~'¢ - -~ ': ...... Tubing (size, grade, and measured depth) ;' 4"X 3-1/2" , 10.9~/9.3¢, J-55/L-80 TBG W/ TAIL ~ 7121' MD Anchorage Packers and SSSV (type and measured depth) CAMCO HRP4SP Rt~ Pkr ~ 6836', BAKER Model D Perm Pkr ~ 7093', OTIS 4" SERIES 10 FEX SSSV ~ 1799' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 05/17/89 Title Area Drillin~l Engineer D a t es U~ ?/¢",1. i Nc'//D U p LiCATE ARCO ALASKA INC. DAILY OPERATION5 PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-23 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25646 ALK 2577 50-029-22370 93-71 ACCEPT: 06/04/93 03:00 SPUD: 06/04/93 05:00 RELEASE: 04/15/94 06:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 06/04/93 ( 1) PARKER 245 TD: 190' ( 190) 06/05/93 ( 2) PARKER 245 TD: 3410' (3220) 06/06/93 ( 3) PARKER 245 TD: 3920' ( 510) DRILL 12.25" HOLE 16"@ 121' MW: 9.2 VIS: 76 MOVE RIG F/1Y-22 TO 1Y-23. NU DIVERTER SYSTEM. FUNCTION TEST DIVERTER & KOOMEY SYSTEM. TEST WAIVED BY STATE MAN LOU GRIMALDI. FILL STACK & CHECK FOR LEAKS. PU BHA & ORIENT TOOLS. SPUD WELL @ 0500 HRS & DRILL 12.25" HOLE F/121' TO 190' DRILLING AHEAD 12.25" HOLE 16"@ 121' MW:10.1 VIS: 66 DRILL 12.25" HOLE F/190'-1658' SERVICE RIG & TOP DRIVE. DRILL & SURV F/1658'-3157' CBU & PMP DRY JOB. SHORT TRIP 20 STDS TO 1289'-HOLE SWABBING-RIH & HIT BRIDGE @ 1600' MU TOP DRIVE & REAM THROUGH BRIDGE @ 1600' & 1670' CONT RIH & WASH LAST 95' DRILL & SURV F/3157'-3327'. AT 3327' MOTOR REPEATEDLY STALLED OUT & LOST 1300 PSI PUMP PRESS. PMP DRY JOB & POOH. ONE CONE & EXTENDED NOZZEL LEFT IN HOLE. MU NEW BIT, ORIENT MWD TOOLS, & RIH TO 3327'. NO FILL. ATTEMPT TO DRILL PAST JUNK IN HOLE W/SUCCESS DRILL & SURVEY F/3327'-3410' . TEST BOP EQUIP 9-5/8"@ 3892' MW: 0.0 VIS: 0 DRILL 12.25" HOLE F/3410'-3920' CBU & PMP DRY JOB. POOH-SET BACK 2 STDS DC'S-LD BHA. RU TO RUN 9-5/8" CSG. HOLD PRE-JOB SAFETY MEETING. RUN 96 JTS 9-5/8", 36# J-55 CSG. SHOE @ 3893' MU LJT & HGR. MU CMT HEAD & CIRC. RECIP CSG W/NO RETURNS. PUMPED 340 BBLS, LOST 292 BBLS. PUMP 5 BBLS H20 W/HOWCO, DROP 1ST BTM PLUG. TEST LINES TO 3000 PSI, PMP 15 BBLS H20, DROP 2ND BTM PLUG. PUMP 234 BBLS 12.1 PPG LEAD CMT & 92 BBLS 15.6 PPG TAIL CMT. DROP TOP PLUG. DISPLACE CMT W/20 BBLS H20 & 274 BBLS MUD. BUMP PLUG TO 2000 PSI. FLOATS HELD. NO RETURNS THROUGHOUT JOB. RD CMT & CSG EQUIP & ND DIVERTER SYSTEM. RU FOR TOP JOB & PUMP 15 BBLS H20 & 23 BBLS 15.6 PPG CMT. INSTALL PACK OFF AROUND HGR & NU SPEED HEAD W/17K FT/LBS. NU BOP'S. TEST BOP'S-CHOKE MANIFOLD, TOP DRIVE & FLOOR VALVES, & PERFORM KOOMEY TEST. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE' 2 06/07/93 ( 4) PARKER 245 TD' 6150' ( 2230) 06/08/93 ( 5) PARKER 245 TD: 6850' ( 700) 06/09/93 (6) PARKER 245 TD' 7500' ( 650) DRILL & SURVEY 8.5" HOLE 9-5/8"@ 3892' MW:ll.0 VIS' 40 FIN TESTING BOP'S. REPLACED SEALS ON RAMS & REPLACED TIW. SET WEAR BUSHING & BLOW DOWN CHOKE MANIFOLD & TOP DRIVE. MU BHA #2. ORIENT & TEST MWD/LWD. TIH TO 3500' CUT & SLIP 70' DRLG LINE. FIN TIH. TAG CMT STRINGER @ 3879' WASH & REAM TO 3817' TEST CSG TO 2000 PSI-OK. DRILL PLUGS, FLOAT COLLAR, CMT, SHOE, & 10' NEW FORMATION TO 3930' CIRC. PERFORM FIT TO 775 PSI-12.7 PPG EMW @ 3622' TVD. HOLD PRESS 10 MIN, NO LOSS. DRILL & SURVEY F/3930'-6150' WHILE DRILLING @ 5650' W/10.9 PPG MUD, HOLE STARTED TAKING FLUID @ 25 BBL/HR. DURING CONNECTIONS WELL WOULD GIVE BACK MOST OF WHAT IT TOOK. PUMP RATE WAS REDUCED F/500 GPM TO 450 GPM & WELL STABILIZED W/10.8 PPG MUD WT. HOLE REMAINED STABLE UNTIL REACHING 11 PPG @ 6000' WHERE FLUID LOSS WAS 25 BBL/HR. WELL CONT TO GIVE BACK FLUID ON CONNECTIONS. PUMP RATE WAS REDUCED TO 425 GPM, 2600 PSI UNTIL WELL BEGAN TO STABILIZE. DRILL & SURVEY 8.5" HOLE 9-5/8"@ 3892' MW:ll.7 VIS' 42 DRILL F/6150'-6850'. CBU. POOH. HOLE GAINED 36 BBLS PULLING TO SHOE, THEN STARTED TAKING PROPER FILL UP. REMOVE SOURCE & LAY DOWN TURBINE. MU NEW BIT, NEW BHA, INSTALL RA SOURCE, & TIH. FILL PIPE @ 3000', 5000', 6700' REAM F/6740'-6850' FOR LWD LOG. CIRC & COND MUD W/15 PPB LCM. WT UP F/il-Il.7 PPG. MONITOR WELL. PUMP DRY JOB & SHORT TRIP TO SHOE. MONITOR WELL @ SHOE-STATIC. RIH SLOW. POH TO RUN 7" CSG 9-5/8"@ 3892' MW:ll.7 VIS: 49 RIH F/3892'-6850' NO FILL. DRLG 8.5" HOLE F/6850'-6934' CBU @ 6934' DRLG 8.5" HOLE F/6934'-7040' SERVICE RIG. DRLG 8.5" HOLE F/7040'-7500' NO MUD LOSS & NO GAS. CBU @ 7500' MADE 9 STD SHORT TRIP TO 6768' HOLE TIGHT & SWABBING F/7250'-7150' TIH-NO FILL. CBU @ 7500'-N0 LOSS OR GAIN IN PITS-NO GAS TO SURF. SLUG DP. START POH TO RUN 7" CSG. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 3 06/10/93 ( 7) PARKER 245 TD: 7500'( 06/11/93 ( 8) PARKER 245 TD: 7500'( 08/14/93 (12) DOWELL TD' 7500 0) 0) NU TBG HEAD 7"@ 7477' MW:ll.7 VIS: 43 FPOH-LD 6" DC'S. DOWN LOAD RA SOURCE. LD ANADRILL TOOLS. RU CASERS. HOLD SAFETY MEETING-PULL WEAR BUSHING. RAN 176 JTS 26# L-80 BTC/MOD CSG-VERY SLOW. CBU @ 9-5/8" SHOE. MU CMT HEAD-CIRC W/CSG ON BTM @ 7477' NO MUD LOSS. PUMP 6 BPM @ 800 PSI. SHAKE OUT LCM MATERIAL. LOST 400 PSI PUMP PRESS & RETURNS W/LCM OUT OF MUD. LOST 200 BBLS MUD. SET & CMT'D 7" W/SHOE @ 7477' & FC @ 7388'. HALLIBURTON CMT'D PUMPING 20 BBLS PRE-FLUSH, 50 BBLS 11.7 PPG SPACER, 250 SX PREM "G" W/ADDITIVES. DISPLACED W/283.5 BBLS 11.7 PPG BRINE. RECIP W/5% RETURNS THROUGH OUT JOB. PLUG DOWN & JC @ 1245 AM. PLUG BUMPED. TEST CSG TO 3500 PSI FOR 30 MIN. HELD. FLOATS HELD. PU STACK. LANDED 7" W/125,000# ON SLIPS. BLOW DOWN 7" & CUT OFF. ND & SET OUT BOP. NU 11"-3000 X 7-1/16"-5000 TBG HEAD. TEST TO 3000 PSI FOR 15 MIN. TBG HEAD LD SCREWS TO RT=37.4' RIG RELEASED 7"@ 7477' MW: 0.0 VIS: 0 FIN TESTING 7-1/16" TBG HEAD. FREEZE PROTECT 9-5/8" X 7" ANN. PUMPED 100 BBLS WATER & 70 BBLS DIESEL. FINAL PRESS 900 PSI @ 2 BPM. RELEASED RIG @ 0800 HRS 06/10/93. MOVE RIG F/1Y-23 TO 1Y-24. 7"@ 7477' DO ARCTIC PACK 09/11/93 ( 9) NORDIC 1 TD' 7500 PB' 7388 RIH W/GUN RUN #3 7"@ 7477' MW.11.5 NaCl/Br MOVE RIG F/1Y-22 TO 1Y-23. ACCEPT RIG @ 2330 HRS 09/10/93. ND DRY HOLE TREE, NU BOPS. CHANGE PIPE RAMS TO 3-1/2". SET TEST PLUG, TEST PIPE RAMS, CHOKE LINE & BTM FLANGE TO 3000 PSI. FUNCTION TEST BOPS. PULL TEST PLUG. RU SWS, TEST LUB TO 1500 PSI. RIH W/GUN RUN #1. PERF F/7186'-7206' W/4 SPF, 180 DEG PHASING, ORIENTED 160 DEG CCW F/HS. POH. MU GUN %2, RIH. PERF F/7180'-7186' AS ABOVE. POH. MU GUN #3 W/12 SPF, SPIRAL PHASING. RIH. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 4 09/12/93 (10) NORDIC 1 TD: 7500 PB: 7388 09/13/93 (11) NORDIC 1 TD: 7500 PB: 7388 11/05/93 (14) DOWELL TD: 7500 PB: 0 11/06/93 (13) DOWELL TD: 7500 PB: 0 STING INTO PERM PKR 7"@ 7477' MW:ll.5 NaC1/Br RIH W/GUN %3. PERF F/7014'-7024' & 6994'-7014' W/12 SPF, SPIRAL PHASING. POH. PERF W/GUN #4 F/6987'-6994' & 6967'-6987' W/12 SPF, SPIRAL PHASING. POH. PERF W/GUN #5 F/6947'-6967' W/12 SPF, SPIRAL PHASING. PERF F/GUN 96 F6927'-6947' W/12 SPF, SPIRAL PHASING. RIH W/SWS 5.95" GAUGE RING & JB TO 7160' POOH W/JB FULL OF GUN DEBRIS. LD JB. PU BAKER PERM PKR & TAILPIPE ASSY. RIH ON E-LINE & SET PKR @ 7082'. POOH & RD SWS. RIH W/3-1/2" TBG RUN TOTAL OF 99 JTS 3-1/2" 9.3#, J-55 TBG & 7 JTS 3-1/~" 9.3# L-80 TBG. MU TBG HGR & LAND TBG IN TBG SPOOL. CHANGE OUT PIPE RAMS TO 4", TEST SAME TO 3000 PSI. PULL TBG HGR. LD HGR & LANDING JT. MU 3-1/2" X 4" XO & RIH W/4" TBG & TBG JEWELRY. MU OTIS SSSV. ATTACH CONTROL LINE & TEST TO 5000 PSI FOR 15 MIN. CONT TO RIH W/4" TBG & CONTROL LINE. STING INTO PERM PKR & SPACE OUT. RIG RELEASED 7"@ 7477' MW:ll.5 NaCl/Br STAB INTO PERM PKR & VERIFY W/400 PSI. PU & SPACE OUT. MU & TEST TBG HGR, C-LINE & SSSV TO 5000 PSI. LAND TBG. RILDS. PRESS TBG TO 2500 PSI & HOLD FOR 30 MIN TO SET PKR. BLEED OFF, BOLDS. PRESS TBG TO 1000 PSI & PU TO SHEAR PBR. SHEARED W/80K LBS UP WT. RE-LAND TBG & RILDS. PRESS ANN & TBG TO 1000 PSI & CLOSE SSSV. BLEED TBG TO 500 PSI & HOLD FOR 15 MIN SSSV TEST. OPEN SSSV. PRESS ANN & TBG TO 2500 PSI & MONITOR FOR 15 MIN. PRESS TBG TO 3000 PSI & MONITOR FOR 15 MIN. BLEED OFF PRESS ON TBG & ANN. RU OTIS SL. TEST LUB TO 1000 PSI. RIH, PULL CIRC VALVE F/GLM #2 @ 6769', POH. PMP 17 BBLS DIESEL DN ANN. CONNECT ANN TO TBG @ RIG FLOOR & ALLOW WELL TO U-TUBE DIESEL INTO TBG UNTIL WELL STABLE. RIH W/SL, SET DUMMY VALVE IN GLM #2 & POH. RD OTIS. PULL LANDING JT, SET BPV. ND BOPS, NU TREE. TEST PACKOFF & FLANGE TO 5000 PSI. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG, SET BPV. OPEN SSSV, SECURE WELL. RIG RELEASED 1530 HRS 09/12/93. SECURE WELL 7"@ 7477' MW:ll.5 NaC1/Br MIRU TREE SAVER & N2 PUMPER. TEST LINES TO 9100 PSI-OK. TEST TBG & TREESAVER TO 3000 PSI-OK. PRESS ANN TO 3500 PSI. PRESS TBG W/N2 @ 5000 SCF/MIN TO 7356 PSI TO SHEAR OUT. PMP TOTAL OF 121,647 SCF N2. SECURE WELL & RD PUMPER. FRAC/STIM 7"@ 7477' MW:ll.5 NaC1/Br DO FRAC/STIM PROCEDURE. JOB COMPLETE 1330 HRS 11/06/93 WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 5 11/07/93 (15) DOWELL TD: 7500 PB: 0 04/12/94 (16) NORDIC 1 TD: 7500 PB: 7388 04/13/94 (17) DOWELL TD' 7500 PB- 7388 SECURE WELL 7"@ 7477' MW:ll.5 NaCl/Br MIRU CTU & N2 PUMPER. TEST BOP COIL & HARDLINE TO 4000 PSI-OK. RIH W/1.75" SWIVEL NOZZLE ON 1-1/2" CT WHILE PUMPING GELLED DIESEL @ 1-1/2" BPM. START N2 @ 325 SCF/MIN @ 3500'_ INCREASE GEL RATE TO 1-1/4 BPM @ 7100'. CLEAN OUT W/50'-75' BITES RECIP BACK INTO TBG TAIL TO 7362' CTM. INCREASE N2 TO 600 SCF/MIN; MAKE 3 ADDITIONAL PASSES F/PBTD INTO TBG TAIL; SWAP TO CLEAN DIESEL & POOH. CUT N2 @ 3700' FLUSH POOH. GRAD INCREASE BACK PRESS F/0 TO 400 PSI WHILE POOH. RETRIEVE BPV 7"@ 7477' MW:ll.5 NaCl/Br MOVED RIG F/lQ-06 TO 1Y-23. ACCEPTED RIG @ 0130 HRS 04/12/94. LEVELED RIG & RU HARDLINE. RETRIEVED VR PLUG F/TBG HEAD. RU KILL LINE. RU BPV LUB. MONITOR WELL 7"@ 7477' MW:ll.7 NaCl/Br PULL BPVM - RIG DOWN LUBRICATOR - RIG UP LINES TO KILL WELL SITP 1075 SICP 650 PSI. ATTEMPT TO CIRCULATE DOWN TUBING WITH SEA WATER - PRESSURE UP TO 2500 PSI - WOULD NOT BLEED OFF - ATTEMPT TO BULLHEAD SEA WATER INTO PERFORATION @ 7180'-PRESSURE UPP TO 3000 PSI - BLED OFF SLOW CAN NOT EST. INJECTION RATE - ATTEMPT TO REVERSE CIRCULATE WITH DIESEL THROUGH ORIFICE VALVE @ 3650' - CAN NOT KEEP PRESSURE BELOW 1200 PSI - 1200 PSI OPENS GAS LIFT VALVE @ 2391' RIG DOWN CIRC LINES - RIG UP OTIS WIRELINE - RIH WITH SSSV LOCK OUT SLEEVE AND WIRELINE GRAPPLE - COULD NOT GET THROUGH SSSV TO SET SLEEVE - POOH - WIRELINE STUCK @ 300' IN ICE PLUG - RIG UP HOT OIL TRUCK - PUMP 180 DEGREE DIESEL DOWN ANNULUS - INJECT INTO FORMATION @ 3/4 BBL/MIN - MELT ICE PLUG - RIG DOWN OTIS WIRELINE. CIRCULATE HOT DIESEL TO CLEAR TUBING OF ICE - RIG DOWN HOT OIL TRUCK. BULLHEAD 11.7 PPG BRINE DOWN ANNULUS INTO TUBING STRING @ 3650' PUMP 12 BBL @ 3/4 BBL/MIN 3000 PSI - RIG PUMP BROKE DOWN. RIG REPAIR - WORK ON FLUID END OF RIG PUMP - CALL OUT HOT OIL TRUCK TO PUMP DOWN HOLE WHILE REPAIR RIG PUMP - SITP 1300 SICP 1300 PSI. ATTEMPT TO BULLHEAD 11.7 BRINE INTO FORMATION - PUMP 27 BBL @ 3/4 BBL/MIN 3000 PSI - LOCKED UP @ 3000 SPI WITH NO BLEED OFF - OPEN CHOKE & CIRCULATE 11.7 BRINE TO SURFACE - PUMP 118 BBL OF BRINE. MONITOR WELL - SITP 750 PSI SICP 750 - LET BRINE FALL AND DIESEL RISE. CIRCULATE 11.7 BRINE @ 1.6 BBL/MIN - TOTAL 120 BBL. MONITOR WELL - SITP 150 PSI SICP 150 PSI. CIRCULATE WELL WITH HOT OIL TRUCK @ 1.6 BBL/MIN 3000 PSI - TOTAL 50 BBL - 11.7 BRINE RETURNS. MONITOR WELL - SITP 0 PSI - SICP 50 PSI. CIRCULATE WELL WITH HOT OIL TRUCK @ 1.6 BBL/MIN 3000 PSI - TOTAL 60 BBL 11.7 BRINE RETURNS LESS DIESEL IN RETURNS EACH TIME CIRCULATED - MONITOR WELL - SITP 0 PSI - SICP 50 PSI. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 6 04/14/94 (18) DOWELL TD: 7500 PB: 7388 POOH WITH 3 1/2" TUBING 7"@ 7477' MW:ll.7 NaCl/Br MONITOR WELL WHILE WORK ON RIG PUMP - TEST RIG PUMP TO 4500 PSI - OK. CIRCULATE W/ll.7 BRINE @ 1 3/4 BBL/MIN 2500 PSI. MONITOR WELL - SITP 0 PSI - ATTEMPT TO INJECT INTO FORMATION - COULD NOT EST. INJECTION RATE - SET BPV. NIPPLE DOWN TREE - NIPPLE UP 7 1/16" BOP STACK WITH 10' SPACER SPOOL BETWEEN RAMS & HYDRILL. TEST BOP: TEST ALL RAMS, LINES, VALVES AND HYDRILL TO 3000 PSI - OK WITNESS OF BOP TEST WAIVED BY JERRY HEARING OF AOGCC. PULL TUBING HANGER TO RIG FLOOR - 50K OVER STRING WT. TO PULL SEALS OUT OF PBR. REVERSE CIRCULATE WITH 11.7 BRINE. MONITOR WELL - WELL DEAD - FLUID LOSS 10 BBL/HR. LAY DOWN TUBING HANGER - ATTEMPT TO POOH - TUBING PULLING WET. REVERSE CIRCULATE ATTEMPT TO DRY TUBING. POOH WITH WET 4" BTC TUBING - DRIFT TO 3.360" - CHANGE SEAL RINGS AND STRAP - RECOVERED WIRELINE FISH AT 4" X 3 1/2" XO CLEAN RIG FLOOR AFTER WET TRIP. POOH WITH 3 1/2" 9.3# J-55 TUBING - DRIFT TO 2.860" & STRAP. 04/15/94 (19) DOWELL TD: 7500 PB: 7388 FINAL REPORT-RIG RELEASED 7"@ 7477' MW:ll.7 NaC1/Br SERV RIG. CONT POOH W/3-1/2" TBG. CHANGE SEAL RINGS, DRIFT & STRAP. LOAD PIPE SHED W/COMP EQUIP, DRIFT & STRAP. RIH W/3-1/2" X 4" COMP. RIG REPAIR. REPLACE HYDRAULIC HOSE ON FOSTER TONGS. CONT RIH W/3-1/2" X 4" COMPLETION. MU OTIS 4" SSSV-TEST CONTROL LINE TO 5000 PSI-0K. CONT RIH W/COMPLETION. TBG WET. CIRC TBG VOL TO DRY PIPE. CONT RIH W/COMP. LAND TBG. RU OTIS WL-RIH & SET POSITIVE PLUG IN 2-7/8" D-NIPPLE @ 7109'. TEST ANN & TBG TO 3500 PSI-OK. TEST PBR SEALS TO 1600 PSI. TEST SSSV TO 1000 PSI-OK. RU OTIS WL-RIH & PULL PLUG F/D-NIPPLE. SET BPV. ND BOP & 10' OF SPACER SPOOL RISER. NU FMC 4-1/16" 5000 PSI TREE. TEST PACKOFF OF 5000 PSI-OK. CHANGE SWAB & WING VALVE TO ARCO CONFIGURATION. TEST TREE TO 5000 PSI-OK. DISPLACE ANN W/10 BBL DIESEL & BULLHEAD 6 BBLS DIESEL DOWN TBG FOR FREEZE PROTECTION. SECURE ~ELL. RIG RELEASED @ 0600 MRS 04/15/94. SIGNATURE: (dril-ling su~ri~ DATE: ARCO Alaska, Inc. Date' January 14, 1994 Transmittal #: 8980 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. and return one signed copy of this transmittal. 1 Y-27 ~.: ..,_.-~ Please acknowledge receipt Ll~S_T_ape__.and Listing' u;-.; ,c; 10-28-93 93426 C_ased Hgle-TEhT-P='3 passes and average LIS Tape and Listing: 10-28-93 93423 ,. ~.q~, 1Y-23 5o~;5~ LIS Tape and Listing: 10-28-93 93425 C~t-CNTG Main and repeat passes. ~tcok-~,-'~% P,\ 10-04-93 93429 12-07-93 with QRO Processing 12-07-93 with QRO Processing 12-07-93 with QRO Processing 12-19-93 with QRO Processing c[~Cl0 1Y-31 ~o~5~ LIS Tape and Listing: c:~_a,s.ecLJ=~C NTG ~'~-i'5'~ 2A-21 5ct5~ LIS Tape and Listing: Ck-'CDR/CDN, 2 Bit Runs 2A-17 ¢_~~ LiS Tape and Listing: o~r-CDR/CDN, 2 Bit Runs 2A-23 5q5'~ LIS Tape and Listing: O~--CDR/CDN, 2 Bit Runs 2A-24 5~ 5~ LIS Tape and Listing: o~-CDR/CDN, 1 Bit Runs 2A-20 5~8;t~ LIS Tape and Listing'. 12-20-93 o~--CDR/CDN, 2 BitR, uns with QRO /~' Proces,iing Receipt Acknowledged: State of Alaska DI~;TRIBUTION' 93452 H tcc-~-i t¢~ 93474 9347O 93480 93497 Date: Bob Ocanas ARCO Alaska, Inc. Post Office Box' i~0360 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 -7~.- '--- ;., 1B-12 Other (SSSV) ~ 1B-1 2 Perforate '~1B-12 Stimulate ~>-~ 1F-02 Stimulate ~l.-.bb 1 L-24 Perforate c/,~_-71 1Y-23 Stimulate q~-~/I 1Y-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 AtlanticRichlieldCompany STATE OF ALASKA ALAbr~ OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing Stimulate X Repair wel Plugging Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 568' FNL, 1342' FWL, Sec 1, T11N, R9E, UM At top of productive interval 2313' FSL, 2197 FEL, Sec 1, TllN, R9E, UM At effective depth 2076' FSL, 2037' FEL, Sec 1, TllN, R9E, UM At total depth 2019' FSL, 2003' FEL, Sec 1, TllN, R9E, UM Present well condition summary Total Depth: measured true vertical 7500 6371 12. 6. Datum elevation (DF or KB) RKB 107 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-2;~ 9. Permit number/approval number 93-71 10. APl number so-029-22370 11. Field/Pool Kuparuk River Oil Field/Pool feet feet Plugs (measured) None Effective depth: measured 7 3 8 8 true vertical 61 74 feet feet Junk (measured) None Casing Length Size Structural Conductor 1 2 1 ' 1 6" Surface 3 8 5 1 ' 9.6 2 5" Intermediate Production 7 4 4 3' 7" Liner Perforation depth: measured 6927'-7024', true vertical 5919'-5994', Cemented 200 Sx PF 430 Sx P F E & 450 Sx Class G 200 Sx Class G 7180'-7206' 6116'-6136' Measured depth 121' 3893' 7477' True vertical depth 121' 3590' 63 'ECEIVED Tubing (size, grade, and measured depth) 4", 11#/ft, J-55 @ 3628', 3.5", 9.2#/ft, J-55/L-80 @ 3628'-7079, & 2.875", Packers and SSSV (type and measured depth) PKR: Camco HRP-4-SP @ 6824; SSSV: Otis 4" Series 10 Self Equalizing @ 1786' i'3. Stimulation or cement squeeze summary Fractured "A4" Sand on 11/6/93. Intervals treated (measured) 7180'-7206' Treatment description including volumes used and final pressure Pumped 12.3 Mlbs of 16/20 & 143 M lbs 12/18 ceramic proppant into form., fp was 6480 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 6.5#/it, J-55 C-~"c~~llo' Prior to well operation 0 0 0 0 0 ,,, Subsequent to operation 1313 994 4206 1250 220 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed::~J ~' ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 ;ion Date /-5"¢¢ SUBMIT IN DUPLICATE .~.._) KCS-WHSE/DRILLING 907-659-77:39 NOV ~,o'9:3 16:07 No.010 P.O1/O" WELL NO: , .( .~- 2.~ ,_ Procedure D~t,e: Service co: Annul us Press: AFE: Begin Frac: /~c~. ! [//&~. _ . Zone: , ~'~-4:)_ '4~-4' __ Test Ltnes To: · r~,..,* ~. ........ .~ ~,, ~.~.~ . . mm i m _ _ ! ' STAGE VOL FLUID "tO PROP RATE ' PRESSLIRE · ISIP: ~ 15 Mtn: F]u~d to Recover': ~.-oZ.. Sand In Csg: Job Complete: _ ADC.. ----'- Avg Pres Sand In Zone: ~_ · · -- i Iii , ....... O{i & Gas Cons. Commission /). ~ Anchorage s: q:'G"lO ___ _ ps I INDIVIDUAL WELL GEOLOGICAL INVENTORY a~PORT 11/18/1993 PAGE: 1 PERMIT DATA DETAIL 93-071 CBT 93=071 CDN LWD/DC 93-071 CDR LWD/DC 93-071 CDR/VER 93-071 CET 7350-7386 OH,3739-7499 OH,3739-7499 3746-7497 MWD 5650-7380 93-071 CNTG-DC 6610-7364 93-071 DCN/CH/CNTG 93-071 TDTP 6600-7378 6700-7300 93-071 TDTP-DC 6700-7304 93-071 407 93-071 DAILY WELL OP 93-071 SURVEY COMP DATE: 09/13/93 6/04/93 TO 9/13/93 0.00-750O 93-071 5718 3750-7499,CDN/CDR/GR SUMMARY Are well tests required? Yes No Was well cored? Y~s No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No Yes No WELL IS IN COMPLIANCE. INITIAL COMMENTS: ARCO Alaska, Inc. Date: N~3vember 5, 1993 Transmittal #: 8919 - 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-23 1Y-18 %.~1o~ ~1Y-18 c~~ Y-27 Receipt Acknowledged: DISTRIBUTION: D&M NSK TDTP Depth Corrected CNTG Depth Corrected TDTP Depth Corrected CNTG Depth Corrected TDTP Depth Corrected CNTG Depth Corrected 10-22-93 6700-7304 10-22-93 6610-7364 10-22-93 8550-9062 10-22-93 8540-9080 10-22-93 9250-9790 10-22-93 9250-9810 Drilling State of Alaska (+Sepia) Date: !.. Catherine Wodey(Geology) ¢~.~ Bob O~nas STATE OF ALASKA ALASh,~ OIL AND GAS CONSERVATION COMMI~blON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r~ GAS E~] SUSPENDED E~ ABANDONED [~] SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 0/~ / ¢/~/~' ~ 93-71 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22370 4 Location of well at surface ~ ................ ~ ~~ 9 Unit or Lease Name 568' FNL, 1342' FWL, SEC 1,T11N, R9E, UM~ h¢:'¢';. ~FE~ ;[ KUPARUK RIVER At Top Producing Inte~al , ~~ i:,.~ ~ 10 Well Number ~;~. ~~ 1Y-23 2313' FSL, 2197' FEL, SEC 1, T11N, R9E, U~ '¢~;~¢~0 At Total Dep~ 11 Field and Pool 2019' FSL, 2003' FEL, SEC 1, T11N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 107', PAD 66' GL ADL 25646 ALK 2577 ~(COMp)Date Comp., Susp. or Aban¢.~~]115 WaterNADepth, if offshorefeet MSL 16 No. of Completions 12 Date Spudded 13 Date T.D. Reached 14 ¢--¢---- , 04-Jun-93 09-Jun-93 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ' ' ' ~20 Dep~ where SSSV set ~ 21 Thickness of permafrost 7500'MD, 6371'TVD 7388'MD, 6281'TVD YES ~ NO ~ I 1799' feetMDI 1500' APPROX ~ Type Electric or ODer Logs Run CDR, CDN, TDTP, CNTG, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~ 16" 62.5¢ H-40 SURF 121' 24" 234 PFC CMT 9.625" 36¢ J-55 SURF 3893' 12.25" 650 PF E CMT, 450 SX CLASS G 7" 26~ J-55 SURF 7477' 8.5" 250 SX CLASS G CMT 24 Pedorations open to Production (MD+TVD of Top and BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4"/3.5" 11~/9.3~ L-80/J-55 7123' 6837', 7095' SWS 4.5" BH UP 6927'-7024' ~12 SPF MD 5919'- 5994' TVD SWS 4.5" HJII 7180'-7206' ~ 4 SPF MD 6115'-6136' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Me~od of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD E Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE E 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Anch0rago 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 TRUEVERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 6 9 2 6' 5 91 8' , .... 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEYS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~-~/~~ Title //~/""~ ]'~ ~ 0 DATE / -' _ j - / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and 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-23 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25646 ALK 2577 50-029-22370 93-71 ACCEPT: 06/04/93 03:00 SPUD: 06/04/93 05:00 RELEASE: 09/12/93 03:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 06/04/93 (1) PARKER 245 TD: 190'( o) 06/05/93 (2) PARKER 245 TD: 3410' (3220) 06/06/93 (3) PARKER 245 TD: 3920' ( 510) DRILL 12.25" HOLE 16"@ 121' MW: 9.2 VIS: 76 MOVE RIG F/1Y-22 TO 1Y-23. NU DIVERTER SYSTEM. FUNCTION TEST DIVERTER & KOOMEY SYSTEM. TEST WAIVED BY STATE MAN LOU GRIMALDI. FILL STACK & CHECK FOR LEAKS. PU BHA & ORIENT TOOLS. SPUD WELL @ 0500 HRS & DRILL 12.25" HOLE F/121' TO 190'. DRILLING AHEAD 12.25" HOLE 16"@ 121' MW:10.1 VIS: 66 DRILL 12.25" HOLE F/190'-1658' SERVICE RIG & TOP DRIVE. DRILL & SURV F/1658'-3157'. CBU & PMP DRY JOB. SHORT TRIP 20 STDS TO 1289'-HOLE SWABBING-RIH & HIT BRIDGE @ 1600' MU TOP DRIVE & REAM THROUGH BRIDGE @ 1600' & 1670' CONT RIH & WASH LAST 95'. DRILL & SURV F/3157'-3327'. AT 3327' MOTOR REPEATEDLY STALLED OUT & LOST 1300 PSI PUMP PRESS. PMP DRY JOB & POOH. ONE CONE & EXTENDED NOZZEL LEFT IN HOLE. MU NEW BIT, ORIENT MWD TOOLS, & RIH TO 3327' NO FILL. ATTEMPT TO DRILL PAST JTJNK IN HOLE W/SUCCESS. DRILL & SURVEY F/3327'-3410'. TEST BOP EQUIP 9-5/8"@ 3892' MW: 0.0 VIS: 0 DRILL 12.25" HOLE F/3410'-3920' CBU & PMP DRY JOB. POOH-SET BACK 2 STDS DC'S-LD BH~. RU TO RUN 9-5/8" CSG. HOLD PRE-JOB SAFETY MEETING. RUN 96 JTS 9-5/8", 36# J-55 CSG. SHOE @ 3893'. MU LJT & HGR. MU CMT HEAD & CIRC. RECIP CSG W/NO RETURNS. PUMPED 340 BBLS, LOST 292 BBLS. PUMP 5 BBLS H20 W/HOWCO, DROP 1ST BTM PLUG. TEST LINES TO 3000 PSI, PMP 15 BBLS H20, DROP 2ND BTM PLUG. PUMP 234 BBLS 12.1 PPG LEAD CMT & 92 BBLS 15.6 PPG TAIL CMT. DROP TOP PLUG. DISPLACE CMT W/20 BBLS H20 & 274 BBLS MUD. BUMP PLUG TO 2000 PSI. FLOATS HELD. NO RETURNS THROUGHOUT JOB. RD CMT & CSG EQUIP & ND DIVERTER SYSTEM. RU FOR TOP JOB & PUMP 15 BBLS H20 & 23 BBLS 15.6 PPG CMT. INSTALL PACK OFF AROUND HGR & NU SPEED HEAD W/17K FT/LBS. NU BOP'S. TEST BOP'S-CHOKE MANIFOLD, TOP DRIVE & FLOOR VALVES, & PERFORM KOOMEY TEST. .qir¢.$.~ ~J~: & ,:~S ~O['~S~ ~'l)~'~¢'t~'~ ' WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 2 06/07/93 (4) PARKER 245 TD: 6150'(2230) 06/08/93 (5) PARKER 245 TD: 6850' ( 700) 06/09/93 (6) PARKER 245 TD: 7500' ( 650) DRILL & SURVEY 8.5" HOLE 9-5/8"@ 3892' MW:ll.0 VIS: 40 FIN TESTING BOP'S. REPLACED SEALS ON RAMS & REPLACED TIW. SET WEAR BUSHING & BLOW DOWN CHOKE MANIFOLD & TOP DRIVE. MU BHA #2. ORIENT & TEST MWD/LWD. TIH TO 3500'. CUT & SLIP 70' DRLG LINE. FIN TIH. TAG CMT STRINGER @ 3879' WASH & REAM TO 3817'. TEST CSG TO 2000 PSI-OK. DRILL PLUGS, FLOAT COLLAR, CMT, SHOE, & 10' NEW FORMATION TO 3930' CIRC. PERFORM FIT TO 775 PSI-12.7 PPG EMW @ 3622' TVD. HOLD PRESS 10 MIN, NO LOSS. DRILL & SURVEY F/3930'-6150'. WHILE DRILLING @ 5650' W/10.9 PPG MUD, HOLE STARTED TAKING FLUID @ 25 BBL/HR. DURING CONNECTIONS WELL WOULD GIVE BACK MOST OF WHAT IT TOOK. PUMP RATE WAS REDUCED F/500 GPM TO 450 GPM & WELL STABILIZED W/10.8 PPG MUD WT. HOLE REMAINED STABLE UNTIL REACHING 11 PPG @ 6000' WHERE FLUID LOSS WAS 25 BBL/HR. WELL CONT TO GIVE BACK FLUID ON CONNECTIONS. PUMP RATE WAS REDUCED TO 425 GPM, 2600 PSI UNTIL WELL BEGAN TO STABILIZE. DRILL & SURVEY 8.5" HOLE 9-5/8"@ 3892' MW:ll.7 VIS: 42 DRILL F/6150'-6850'. CBU. POOH. HOLE GAINED 36 BBLS PULLING TO SHOE, THEN STARTED TAKING PROPER FILL UP. REMOVE SOURCE & LAY DOWN TURBINE. MU NEW BIT, NEW BHA, INSTALL RA SOURCE, & TIH. FILL PIPE @ 3000', 5000', 6700' REAM F/6740'-6850' FOR LWD LOG. CIRC & COND MUD W/15 PPB LCM. WT UP F/Il-Il.7 PPG. MONITOR WELL. PUMP DRY JOB & SHORT TRIP TO SHOE. MONITOR WELL @ SHOE-STATIC. RIH SLOW. POH TO RUN 7" CSG 9-5/8"@ 3892' MW:ll.7 VIS: 49 RIH F/3892'-6850' NO FILL. DRLG 8.5" HOLE F/6850'-6934' CBU @ 6934'. DRLG 8.5" HOLE F/6934'-7040'. SERVICE RIG. DRLG 8.5" HOLE F/7040'-7500'. NO MUD LOSS & NO GAS. CBU @ 7500' MADE 9 STD SHORT TRIP TO 6768'. HOLE TIGHT & SWABBING F/7250'-7150'. TIH-NO FILL. CBU @ 7500'-N0 LOSS OR GAIN IN PITS-NO GAS TO SURF. SLUG DP. START POH TO RUN 7" CSG. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 3 06/10/93 (7) PARKER 245 TD: 7500'( 06/11/93 (8) PARKER 245 TD: 7500'( 09/11/93 ( 9) TD: 7500 PB: 7388 09/12/93 (10) TD: 7500 PB: 7388 o) o) NU TBG HEAD 7"@ 7477' MW:ll.7 VIS: 43 FPOH-LD 6" DC'S. DOWN LOAD RA SOURCE. LD ANADRILL TOOLS. RU CASERS. HOLD SAFETY MEETING-PULL WEAR BUSHING. RAN 176 JTS 26# L-80 BTC/MOD CSG-VERY SLOW. CBU @ 9-5/8" SHOE. MU CMT HEAD-CIRC W/CSG ON BTM @ 7477'. NO MUD LOSS. PUMP 6 BPM @ 800 PSI. SHAKE OUT LCM MATERIAL. LOST 400 PSI PUMP PRESS & RETURNS W/LCM OUT OF MUD. LOST 200 BBLS MUD. SET & CMT'D 7" W/SHOE @ 7477' & FC @ 7388'_ HALLIBURTON CMT'D PUMPING 20 BBLS PRE-FLUSH, 50 BBLS 11.7 PPG SPACER, 250 SX PREM "G" W/ADDITIVES. DISPLACED W/283.5 BBLS 11.7 PPG BRINE. RECIP W/5% RETURNS THROUGH OUT JOB. PLUG DOWN & JC @ 1245 AM. PLUG BUMPED. TEST CSG TO 3500 PSI FOR 30 MIN. HELD. FLOATS HELD. PU STACK. LANDED 7" W/125,000# ON SLIPS. BLOW DOWN 7" & CUT OFF. ND & SET OUT BOP. NU 11"-3000 X 7-1/16"-5000 TBG HEAD. TEST TO 3000 PSI FOR 15 MIN. TBG HEAD LD SCREWS TO RT=37.4'. RIG RELEASED 7"@ 7477' MW: 0.0 VIS: 0 FIN TESTING 7-1/16" TBG HEAD. FREEZE PROTECT 9-5/8" X 7" ANN. PUMPED 100 BBLS WATER & 70 BBLS DIESEL. FINAL PRESS 900 PSI @ 2 BPM. RELEASED RIG @ 0800 HRS 06/10/93. MOVE RIG F/1Y-23 TO 1Y-24. RIH W/GUN RUN #3 7"@ 7477' MW:ll.5 NaCl/Br MOVE RIG F/1Y-22 TO 1Y-23. ACCEPT RIG @ 2330 HRS 09/10/93. ND DRY HOLE TREE, NU BOPS. CHANGE PIPE RAMS TO 3-1/2". SET TEST PLUG, TEST PIPE RAMS, CHOKE LINE & BTM FLANGE TO 3000 PSI. FUNCTION TEST BOPS. PULL TEST PLUG. RU SWS, TEST LUB TO 1500 PSI. RIH W/GUN RUN #1. PERF F/7186'-7206' W/4 SPF, 180 DEG PHASING, ORIENTED 160 DEG CCW F/HS. POH. MU GUN #2, RIH. PERF F/7180'-7186' AS ABOVE. POH. MU GUN #3 W/12 SPF, SPIRAL PHASING. RIH. STING INTO PERM PKR 7"@ 7477' MW:ll.5 NaC1/Br RIH W/GUN #3. PERF F/7014'-7024' & 6994'-7014' W/12 SPF, SPIRAL PHASING. POH. PERF W/GUN #4 F/6987'-6994' & 6967'-6987' W/12 SPF, SPIRAL PHASING. POH. PERF W/GUN #5 F/6947'-6967' W/12 SPF, SPIRAL PHASING. PERF F/GUN #6 F6927'-6947' W/12 SPF, SPIRAL PHASING. RIH W/SWS 5.95" GAUGE RING & JB TO 7160' POOH W/JB FULL OF GUN DEBRIS. LD JB. PU BAKER PERM PK~ & TAILPIPE ASSY. RIH ON E-LINE & SET PKR @ 7082'. POOH & RD SWS. RIH W/3-1/2" TBG. RUN TOTAL OF 99 JTS 3-1/2" 9.3#, J-55 TBG & 7 JTS 3-1/2" 9.3# L-80 TBG. MU TBG HGR & LAND TBG IN TBG SPOOL. CHANGE OUT PIPE RAMS TO 4", TEST SAME TO 3000 PSI. PULL TBG HGR. LD HGR & LANDING JT. MU 3-1/2" X 4" XO & RIH W/4" TBG & TBG JEWELRY. MU OTIS SSSV. ATTACH CONTROL LINE & TEST TO 5000 PSI FOR 15 MIN. CONT TO RIH W/4" TBG & CONTROL LINE. STING INTO PERM PKR & SPACE OUT. WELL: 1Y-23 API: 50-029-22370 PERMIT: 93-71 PAGE: 4 09/13/93 (11) TD: 7500 PB: 7388 RIG RELEASED 7"@ 7477' MW:ll.5 NaC1/Br STAB INTO PERM PKR & VERIFY W/400 PSI. PU & SPACE OUT. MU & TEST.TBG HGR, C-LINE & SSSV TO 5000 PSI. LAND TBG. RILDS. PRESS TBG TO 2500 PSI & HOLD FOR 30 MIN TO SET PKR. BLEED OFF, BOLDS. PRESS TBG TO 1000 PSI & PU TO SHEAR PBR. SHEARED W/80K LBS UP WT. RE-LAND TBG & RILDS. PRESS ANN & TBG TO 1000 PSI & CLOSE SSSV. BLEED TBG TO 500 PSI & HOLD FOR 15 MIN SSSV TEST. OPEN SSSV. PRESS ANN & TBG TO 2500 PSI & MONITOR FOR 15 MIN. PRESS TBG TO 3000 PSI & MONITOR FOR 15 MIN. BLEED OFF PRESS ON TBG & ANN. RU OTIS SL. TEST LUB TO 1000 PSI. RIH, PULL CIRC VALVE F/GLM #2 @ 6769', POH. PMP 17 BBLS DIESEL DN ANN. CONNECT ANN TO TBG @ RIG FLOOR & ALLOW WELL TO U-TUBE DIESEL INTO TBG UNTIL WELL STABLE. RIH W/SL, SET DUMMY VALVE IN GLM #2 & POH. RD OTIS. PULL LANDING JT, SET BPV. ND BOPS, NU TREE. TEST PACKOFF & FLANGE TO 5000 PSI. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG, SET BPV. OPEN SSSV, SECURE WELL. RIG RELEASED 1530 HRS 09/12/93. SIGNATURE: (dr~l 1 i~~uper~endent DATE: Oil & Gas GOBS, Gom~n~ss~O~%' SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS !'~ OOL MICL OFILi E ) Date . Jl ~ / ~ ! Company ARCO ALASKA, INC. Well Name 1Y-23 (568' FNL, 1342' FWL, SEC 1, T11N, RgE, m Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. Date 93281 Loqqed By: SARBER 17-JUN-93 Computed By' DEES * SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE' 17-JUN-93 ENGINEER- SARBER METHODS Of COMPUTATION TOOl LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 35 DEG 38 MIN EAST COMPUTATION DATE' 15-JUL-93 PAGE ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 17-JUN-93 KELLY BUSHING ELEVATION' 107.00 FI ENG I NEER ' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -107 O0 99 199 299 399 499 599 699 799 899 93 -7 07 93 92 93 93 192 93 93 292 93 93 392 93 93 492 93 93 592 93 93 692 93 92 792 92 0 0 N 0 0 E 0 3 S 87 47 E 0 20 N 39 22 E 0 21 N 2 48 W 0 11 N 3 23 W 0 17 N 74 49 E 0 23 N 21 44 E 0 11 N 36 51E 0 20 N 82 59 E 0 25 N 39 54 E 0 O0 -0 06 -0 08 -0 47 -0 90 -0 92 -0 98 '-1 31 -1 16 -1 12 0 O0 0 48 0 47 0 28 0 21 0 26 0 35 0 33 0 32 0 75 0 O0 N 0 O0 S 0 25 N 0 84 N I 32 N 1 50 N 1 88 N 2 37 N 2 46 N 2 84 N 0 O0 E 0 11W 0 22 E 0 36 E 0 30 E 0 50 E 0 94 E 1 06 E 1 44 E 2 03 E 0 O0 N 0 0 E 11 S 89 38 W 34 N 41 8 E 91 N 23 28 E 36 N 12 55 E 58 N 18 29 E 11 N 26 30 E 60 N 24 1E 85 N 30 16 E 49 N 35 36 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 92 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1898 892 92 92 992 92 91 1092 91 91 1192 91 90 1292 90 89 1392 88 1492 85 1592 49 1692 42 1791 0 15 0 29 0 38 0 37 0 47 89 0 53 88 0 43 85 2 44 49 7 0 42 9 23 N 57 35 E N 79 33 E N 56 20 E N 59 2 E N 75 0 E N 57 44 E N 58 26 E S 48 56 E S 35 1E S 34 50 E -1 30 -1 07 -0 88 -0 91 -0 60 -0 28 -0 24 1 20 9.40 23.93 0 34 0 31 0 3O 0 22 0 25 0 31 0 3O 1 5O 2 47 3 44 3 30 N 3 43 N 3 83 N 4 51 N 4 93 N 5 50 N 6 29 N 5 83 N 0 55 S 12 48 S 2 37 E 2 95 E 3 83 E 4 73 E 5 85 E 7 20 E 8 35 E 10 20 E 15 37 E 23 65 E 4 06 N 35 39 E 4 6 7 9 10 11 15 26 52 N 40 40 E 42 N 44 59 E 54 N 46 22 E 65 N 49 52 E 06 N 52 38 E 46 N 53 2 E 75 N 6O 15 E 38 S 87 57 E 75 S 62 11E 2000 O0 1996 73 1889 73 11 31 2100 2200 2300 24OO 2500 2600 2700 2800 2900 O0 2094 O0 2190 O0 2284 O0 2377 O0 2469 O0 2558 O0 2644 O0 2729 O0 2811 13 1987 25 2083 89 2177 94 2270 02 2362 06 2451 89 2537 38 2622 24 2704 13 14 29 25 17 21 89 20 7 94 22 56 02 25 48 06 28 26 89 31 1 38 33 46 24 36 19 S 33 37 E S 31 51 E S 31 16 E S 3O 52 E S 29 37 E S 29 58 E S 30 40 E S 3O 58 E S 30 13 E S 31 59 E 42.17 64 73 92 21 124 38 160 80 201 83 247 12 296 54 349 80 407 02 2 27 2 58 2 71 2 96 2 84 2 79 2 75 2 75 2 69 2 75 27 58 S 46 7O 97 129 165 204 247 293 342 57 S 46.13 E 65 12 S 60.46 E 92 68 S 77.22 E 124 36 S 95 55 E 160 21S 115 96 E 201 47 S 138 92 E 247 02 S 164 38 E 296 08 S 191 54 E 350 34 S 221 05 E 407 33.90 E 43 70 S 50 53 E 55 S 44 44 E 58 S 40 46 E 52 S 38 20 E 82 S 36 27 E 84 S 35 4 E 20 S 34 11E 72 S 33 39 E 12 S 33 10 E 50 S 32 51E 3000 O0 2890 99 2783 99 37 44 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2969 O0 3048 O0 3126 O0 3204 O0 3282 O0 3361 O0 3440 O0 3518 O0 3595 83 2862 21 2941 33 3019 30 3097 76 3175 59 3254 70 3333 37 3411 83 38 14 21 38 26 33 39 0 30 38 31 76 38 10 59 37 45 70 37 54 37 39 41 74 3488.74 38 52 S 34 32 E S 34 37 E S 33 41 E S 34 45 E S 35 4 E S 35 6 E S 34 39 E S 34 26 E S 35 SE S 35 19 E 1026 467 29 528 79 590 87 653 27 715 88 777 88 839 40 900 55 963 53 88 2 65 2 16 1 33 0 87 0 68 0 64 0 55 0 43 0 88 0 98 392 84 S 254 04 E 467 82 S 32 53 E 443 494 546 597 648 699 749 801 853 42 S 289 79 S 323 58 S 358 90 S 394 65 S 430 12 S 465 53 S 500 24 S 536 09 S 572 05 E 529 93 E 591 80 E 653 66 E 716 29 E 778 47 E 839 11E 901 07 E 964 48 E 1027 31 S 33 6 E 40 S 33 13 E 82 S 33 17 E 40 S 33 26 E 39 S 33 34 E 90 S 33 39 E 06 S 33 43 E 03 S 33 47 E 37 S 33 52 E COMPUTATION DATE' 15-JUL-93 PAGE 2 ARCO ALASKA, INC. 17-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 17-JUN-93 KELLY BUSHING ELEVATION' 107.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3673 50 3566 50 39 4 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3750 O0 3828 O0 3905 O0 3981 O0 4056 O0 4132 O0 4208 O0 4283 O0 4359 99 3643 99 39 17 42 3721 42 39 16 31 3798 31 40 26 18 3874 18 40 41 96 3949 96 40 45 69 4025.69 40 49 30 4101.30 40 57 87 4176.87 40 51 63 4252.63 40 39 S 35 36 E 1089 76 S 35 47 E 1152 96 S 35 56 E 1216 24 S 36 9 E 1280 18 S 36 10 E 1345 32 S 36 9 E 1410 S 36 5 E 1475 S 35 58 E 1541 S 35 51E 1606 S 35 52 E 1672 56 87 31 81 08 0 98 0 57 0 32 0 41 0 49 0 46 0 29 0 10 0 09 0 13 904 30 S 608.96 E 1090 22 S 33 57 E 955 1006 1058 1111 1163 1216 1269 1322 1375 63 S 645 83 E 1153 9O S 682 62 S 720 20 S 758 89 S 797 66 S 835 59 S 874 64 S 912 54 S 951 93 E 1216 52 E 1280 97 E 1345 45 E 1410 94 E 1476 42 E 1541 84 E 1607 07 E 1672 40 S 34 3 E 65 S 34 9 E 55 S 34 14 E 66 S 34 20 E 88 S 34 25 E 16 S 34 30 E 58 S 34 33 E 06 S 34 37 E 31 S 34 40 E SO00 O0 4435 52 4328 52 40 34 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4511 O0 4587 O0 4663 O0 4740 O0 4816 O0 4893 O0 4970 O0 5047 O0 5125 53 4404 65 4480 80 4556 23 4633 79 4709 52 4786 27 4863 70 4940 79 5018 53 40 29 65 40 28 80 40 17 23 40 7 79 39 56 52 39 54 27 39 37 70 38 53 79 38 28 S 35 39 E 1737 20 S 34 25 E 1802 S 34 49 E 1867 S 35 5 E 1931 S 35 13 E 1996 S 35 21E 2060 S 35 30 E 2124 S 37 39 E 2188 S 38 55 E 2252 S 39 30 E 2314 17 O1 82 31 63 77 86 06 41 0 16 0 49 0 52 0 55 0 6O 0 42 0 25 0 43 0 83 0 95 1428 30 S 989.25 E 1737 43 S 34 42 E 1481 1535 1588 1640 1693 1745 1797 1847 1895 68 S 1026.29 E 1802 09 S 1063.09 E 1867 20 S 1100.23 E 1932 92 S 1137.38 E 1996 44 S 1174.51E 2060 68 S 1211.71E 2125 49 S 1249.45 E 2189 02 S 1288.83 E 2252 45 S 1328.29 E 2314 40 S 34 43 E 26 S 34 42 E 06 S 34 43 E 56 S 34 44 E 88 S 34 45 E 01 S 34 46 E 08 S 34 48 E 24 S 34 54 E 54 S 35 1E 6000 O0 5204 07 5097 07 38 30 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5282 O0 5359 O0 5436 O0 5514 O0 5590 O0 5667 O0 5744 O0 5821 O0 5898 02 5175 40 5252 79 5329 09 5407 98 5483 82 5560 76 5637 19 5714 23 5791 02 39 16 40 39 9 79 39 27 09 39 23 98 39 52 82 39 42 76 39 59 19 39 59 23 39 7 S 40 8 E 2376 46 S 40 50 E 2438 S 41 10 E 2501 S 39 3 E 2565 S 39 6 E 2628 S 38 51E 2692 S 39 20 E 2756 S 39 0 E 2819 S 39 11E 2884 S 35 57 E 2947 89 94 08 41 24 12 87 24 94 0 83 0 58 0 58 0 96 0 86 0 85 0 44 0 44 0 48 1 15 1943 25 S 1368.13 E 2376 55 S 35 9 E 1990 93 S 1408.76 E 2438 2038 68 S 1450.37 E 2501 2087 15 S 1491.13 E 2565 2136 41 S 1531.11 E 2628 2186 17 S 1571.25 E 2692 2235 83 S 1611.62 E 2756 2285 30 S 1652.03 E 2819 2335.43 S 1692.59 E 2884 2385.72 S 1731.77 E 2947 94 S 35 17 E 96 S 35 26 E 08 S 35 33 E 41 S 35 38 E 24 S 35 42 E 13 S 35 47 E 89 S 35 52 E 28 S 35 56 E 99 S 35 59 E 7000 O0 5975 79 5868.79 39 24 7100 O0 6053 16 5946.16 38 56 7200 O0 6131 47 6024.47 38 3 7300 O0 6210 82 6103.82 37 0 7400 O0 6290 96 6183.96 36 44 7500 O0 6371 11 6264.11 36 44 S 35 0 E 3011 06 S 34 51 E 3074 40 S 34 9 E 3136 57 S 32 50 E 3197 39 S 31 5 E 3257 08 S 31 5 E 3316 69 i 46 I 42 0 87 I O6 0 O0 0 O0 2437.37 S 1768.05 E 3011 11 S 35 57 E 2489.26 S 1804.38 E 3074 44 S 35 56 E 2540.53 S 1839.57 E 3136 61 S 35 54 E 2591.21 S 1873.26 E 3197 42 S 35 52 E 2642.27 S 1904.47 E 3257 09 S 35 47 E 2693.49 S 1935.35 E 3316 69 S 35 42 E COMPUTATION DATE: 15-JUL-93 PAGE 3 ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 17-JUN-93 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 $000 6000 7000 7S00 O0 999 O0 1996 O0 2890 O0 3673 O0 4435 O0 5204 O0 5975 O0 6371 92 892.92 0 15 N 57 35 E -1 73 1889.73 11 31 S 33 37 E 42 99 2783.99 37 44 S 34 32 E 467 50 3566.50 39 4 S 35 36 E 1089 52 4328.52 40 34 S 35 39 E 1737 07 5097.07 38 30 S 40 8 E 2376 79 5868.79 39 24 S 35 0 E 30il 11 6264.11 36 44 S 31 5 E 3316 0 O0 -107.00 0 0 N 0 0 E 0 O0 30 17 29 76 20 46 06 69 0 O0 0 34 3 2 27 27 2 65 392 0 98 904 0 16 1428 0 83 1943 1 46 2437 0 O0 2693 30 N 2 58 S 33 84 S 254 30 S 608 30 S 989 25 S 1368 37 S 1768 49 S 1935 37 E 4 90 E 43 04 E 467 96 E 1090 25 E 1737 13 E 2376 05 E 3011 35 E 3316 0 O0 N 0 O0 E 0 O0 N 0 0 E 06 N 3S 39 E 70 S $0 53 E 82 S 32 53 E 22 S 33 57 E 43 S 34 42 E 55 S 35 9 E 11 S 35 57 E 69 S 35 42 E COMPUTATION DATE' 1S-JUL-93 PAGE 4 ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 17-JUN-93 KELLY BUSHING ELEVATION' 107.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 107 07 207 07 307 07 407 07 507 07 607 07 707 07 8O7 08 907 08 0 O0 -107.00 107 207 307 407 507 607 707 807 907 O0 0.00 O0 100.00 oo 20O.O0 O0 300.00 O0 400.00 O0 500.00 O0 600 O0 O0 700 O0 O0 800 O0 0 0 N 0 0 E 0 5 N 53 15 E 0 20 N 35 23 E 0 21 N 4 24 W 0 11 N 0 47 E 0 18 N 71 46 E 0 23 N 18 17 E 0 10 N 46 20 E 0 21 N 79 25 E 0 25 N 37 53 E 0 O0 -0 06 -0 09 -0 51 -0 92 -0 91 -1 01 :1 32 -1 15 -1 14 0 O0 0 55 0 4.7 0 28 0 2O 0 27 0 35 0 34 0 32 0 72 0 O0 N 0 O0 N 0 29 N 0 88 N 135 N 151 N 193 N 2 39 N 2 47 N 288 N 0 O0 E 0 10 W 0 24 E 0 36 E 0 30 E 0 53 E 0 96 E 1 07 E 148 E 2 06 E 0 O0 N 0 0 E 10 N 88 41W 38 N 40 25 E 95 N 22 19 E 38 N 12 41E 60 N 19 31E 15 N 26 24 E 62 N 24 9 E 88 N 3O 55 E 54 N 35 37 E 1007 08 1007 O0 1107 1207 1307 1407 1507 1607 1707 1807 1908 900 O0 08 1107 09 1207 09 1307 10 1407 11 1507 12 1607 16 1707 57 1807 70 1907 O0 1000 O0 O0 1100 O0 O0 1200 O0 O0 1300 O0 O0 1400 O0 O0 1500 O0 OO 1600 O0 O0 1700 O0 O0 1800 O0 0 16 N 61 53 E 0 30 N 78 48 E 0 38 N 56 28 E 0 37 N 61 4 E 0 48 N 75 18 E 0 53 N 57 21E 0 43 N 60 56 E 3 4 S 46 41E 7 18 S 34 40 E 9 30 S 34 51E -1 30 -1 05 -0 88 -0 90 -0 57 -0 27 -0 24 1 53 10 32 25 35 0 33 0 31 0 29 0 21 0 26 0 30 0 30 1 70 2 63 3 46 3 32 N 3 44 N 3 87 N 4 55 N 4 95 N 5 56 N 6 33 N 5 61 N 1 30 S 13 65 S 2 39 E 3 O0 E 3 89 E 4 80 E 5 94 E 7 30 E 8 43 E 10 45 E 15 89 E 24 47 E 4 09 N 35 50 E 4 5 6 7 9 10 11 15 28 57 N 41 8 E 49 N 45 9 E 61 N 46 31E 74 N 50 10 E 17 N 52 41E 54 N 53 4 E 86 N 61 47 E 95 S 85 19 E O2 S 6O 5O E 2010 49 2007 O0 1900 O0 11 47 2113 2217 2323 2431 2542 2656 2773 2894 3020 31 2107 60 2207 61 2307 67 2407 40 2507 06 2607 20 2707 74 2807 26 29O7 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 26OO O0 2700 O0 2800 O0 14 55 O0 17 56 O0 20 44 O0 23 55 O0 26 54 O0 29 50 O0 32 58 O0 36 13 O0 37 50 S 33 30 E S 31 40 E S 31 26 E S 30 25 E S 29 33 E S 30 17 E S 30 58 E S 30 17 E S 31 53 E S 34 45 E 44 30 68 14 97 60 132 62 173 31 220 58 274 38 335 12 403 92 479 70 2 21 2 63 2 75 2 94 2 86 2 79 2 76 2 67 2 75 2 59 29.36 S 49.49 S 47 74.73 S 63 104'.80 S 81 140.30 S 101 181.49 S 125 227.96 S 152 280.35 S 184 339.70 S 219 403.06 S 261 35 08 E 93 E 68 28 E 97 43 E 132 76 E 173 42 E 220 94 E 274 11E 335 40 E 404 08 E 480 45 74 S 50 5 E 89 S 44 5 E 92 S 40 15 E 72 S 37 51E 31 S 35 57 E 61 S 34 39 E Sl S 33 51E 40 S 33 18 E 39 S 32 51E 23 S 32 56 E 3147 40 3007 O0 2900 O0 38 26 3275 3403 3530 3657 3785 3914 4043 4172 4302 19 3107 45 3207 81 3307 38 3407 24 3507 47 3607 19 3707 34 3807 22 3907 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 S 34 14 E O0 38 46 S 34 14 E 637 O0 38 30 S 35 4 E 718 O0 38 3 S 34 59 E 796 O0 37 38 S 34 27 E 874 O0 39 37 S 35 4 E 954 O0 38 47 S 35 26 E 1035 O0 39 12 S 35 41E 1117 O0 39 15 S 35 57 E 1198 O0 40 28 S 36 9 E 1281 558 19 72 03 89 47 12 97 02 74 61 1 68 0 94 0 69 0 61 0 49 0 80 1 O0 0 89 0 39 0 42 467 67 S 305 68 E 558 71 S 33 10 E 533 599 664 728 793 860 926 992 1059 73 S 350 66 S 395 22 S 441 01S 485 53 S 530 50 S 577 45 S 624 72 S 672 77 S 721 O1E 638 89 E 718 20 E 797 36 E 874 66 E 954 73 E 1036 84 E 1117 66 E 1199 36 E 1281 27 S 33 15 E 55 S 33 26 E 4O S 33 36 E 97 S 33 41E 62 S 33 46 E 46 S 33 53 E 47 S 34 0 E 15 S 34 7 E 99 S 34 15 E COMPUTATION DATE: 15-JUL-g3 PAGE 5 ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY KELLY BUSHING ELEVATION ENGINEER 17-JUN-93 107.00 FT SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4434 06 4007 O0 3900.00 40 43 4566 4698 4830 4962 5094 5225 5356 5487 5617 06 4107 28 4207 56 4307 43 4407 04 4507 44 4607 56 4707 23 4807 58 4907 O0 4000.00 40 47 O0 4100 O0 40 57 O0 4200 O0 40 45 O0 4300 O0 40 39 O0 4400 O0 40 30 O0 4500 O0 40 27 O0 4600 O0 40 7 O0 4700 O0 39 58 O0 4800 O0 39 57 S 36 8 E 1367.52 S 36 6 E 1453.69 S 35 58 E 1540.18 S 35 53 E 1626.78 S 36 0 E 1712:74 S 34 25 E 1798.30 S 34 56 E 1883.51 S 35 14 E 1968.32 S 35 19 E 2052.44 S 35 31E 2136.05 0.47 0 40 0 10 0 12 0 14 0 49 0 53 0 68 0 44 0 22 1129 14 S 772 07 E 1367 86 S 34 22 E 1198 1268 1338 1408 1478 1548 1618 1686 1754 74 S 822 68 S 873 83 S 924 47 S 974 49 S 1024 63 S 1072 05 S 1121 76 S 1169 87 S 1218 88 E 1453 76 E 1540 53 E 1627 93 E 1712 11E 1798 52 E 1883 24 E 1968 77 E 2O52 27 E 2136 99 S 34 28 E 45 S 34 33 E 03 S 34 38 E 97 S 34 41E 53 S 34 43 E 76 S 34 42 E 57 S 34 43 E 68 S 34 44 E 29 S 34 46 E 5747 55 5007 O0 4900 O0 39 17 5875 6003 6132 6261 6390 6520 6650 6781 6911 98 5107 74 5207 30 5307 44 5407 83 5507 86 5607 87 5707 46 5807 30 5907 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 38 34 O0 38 30 O0 39 24 O0 39 21 O0 39 19 O0 39 51 O0 39 32 O0 40 6 O0 39 2 S 38 36 E 2219 02 S 39 19 E 2299 S 40 10 E 2378 S 41 3 E 2459 S 39 43 E 2540 S 39 8 E 2622 S 38 58 E 2705 S 39 20 E 2788 S 39 10 E 2872 S 35 29 E 2955 48 79 28 66 61 59 50 34 07 0.71 0.92 0.82 O. 60 0.77 0.89 0.82 0.40 0.46 I .24 1821 21S 1268 13 E 2219 23 S 34 51E 1883 1945 2006 2068 2131 2196 2260 2326 2391 89 S 1318 03 S 1369 40 S 1422 23 S 1475 90 S 1527 58 S 1579 92 S 1632 18 S 1685 50 S 1735 80 E 2299 63 E 2378 18 E 2459 60 E 2540 44 E 2622 64 E 27O5 19 E 2788 O6 E 2872 93 E 2955 62 S 35 0 E 87 S 35 9 E 32 S 35 20 E 66 S 35 30 E 61 S 35 37 E 59 S 35 43 E 52 S 35 50 E 38 S 35 55 E 12 S 35 59 E 7040.43 6007.00 5900.00 39 27 7168.88 6107.00 6000.00 38 14 7295.22 6207.00 6100.00 37 2 7420.01 6307.00 6200.00 36 44 7500.00 6371.11 6264.11 36 44 S 35 5 E 3036.75 S 34 17 E 3117.36 S 32 59 E 3194.52 S 31 5 E 3269.00 S 31 5 E 3316.69 1 .40 1 .08 1 . 04 0. O0 O. O0 2458.40 S 1782.80 E 3036.79 S 35 57 E 2524.64 S 1828.77 E 3117.40 S 35 55 E 2588.80 S 1871.69 E 3194.54 S 35 52 E 2652.52 S 1910.65 E 3269.01 S 35 46 E 2693.49 S 1935.35 E 3316.69 S 35 42 E COMPUTATION DATE: 15-JUL-93 PAGE 6 ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER 9 5/8" CASING SHOE TOP KUPARUK C GCT LAST READING PBTD 7" CASING SHOE TD DATE OF SURVEY: 17-JUN-93 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 568~ FNL, ~ 1342' FWL, SEC1 TllN R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3893 O0 6926 O0 7350 23 7388 O0 7477 O0 7500 O0 3590 29 5918 41 6251 01 6281 35 6352 68 6371 11 3483 29 5811 41 6144 O1 6174 35 6245 68 6264 11 849 50 S 2399 04 S 2616 77 S 2636 13 S 2681 71S 2693 49 S 569 94 E 1741 31E 1889 21E 1900 77 E 1928 25 E 1935 35 E ARCO ALASKA, INC. 1Y-23 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE: 15-JUL-93 PAGE 7 DATE OF SURVEY: 17-JUN-93 KELLY BUSHING ELEVATION: 107.00 FT ENGINEER: SARBER ************ STRATIGRAPHIC SUMMARY ************ MARKER 9 5/8" CASING SHOE TOP KUPARUK C PBTD 7" CASING SHOE TD SURFACE LOCATION = 568' FNL, A 1342' FWL, SEC1 T11N R9E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3893.00 3590.29 3483.29 849.50 S 569.94 E 6926.00 5918.41 5811.41 2399.04 S 1741.31 E 7388.00 6281.35 6174.35 2636.13 S 1900.77 E 7477.00 6352.68 6245.68 2681.71 S 1928.25 E 7500.00 6371.11 6264.11 2693.49 S 1935.35 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7500.00 6371.11 6264.11 3316.69 S 35 42 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, !NC. FIELD KUPARUK RIVER UNIT WELL 1Y-23 COUNTRY USA RUN I DATE LOGGED 17 - JUN - 93 DEPTH UNIT FEET REFERENCE 93281 interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not. except in the case of gross or wilfull negligence on our par[. be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any Interpretation made by any of our officers, agents or employees. These interpretations are also subject to our Genered Terms and Conditions as set out in our current price Schedule WELL- 1¥-23 (568' FNL, 1342' FWL, SEC 1, T11N, RgE, UN) HORIZONTAL PROJECTION NORTH 1 000 FIEF 93281 5OO -500 -1000 -1500 -2000 -2500 SOUTH -3000 -1000 WE~T SCALE = I / 500 IN/FT -500 0 500 1000 1500 2000 2500 30OO ~ST WELL' 1'Y£23 ' (568' FNL, 1342' FWL, SEC 1, T11N, RSE, UM) VERTICAL PROJECTION 324.00 -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 -i !-~--~-i---i---i--.!---! ...... !---!---!--i ..... i---!---i--i- i..-~.-.~..i ........ i-.!..i ...! ..... i--!- -!-!-i.-~ ...... i-?-.i--i .i ~ .... i...i.i.~ ~. ~ ~ ::' :::- ::'. ::~ ~oo0 ~:::'i :!'i::: .... ' ~ ,:7~ "!" _ ................... : ' : - : : : - : i : . . ~ :,~ :, : : ~-,: , , · ,: , ., ,, , ,,,, '.2 :: ~ : . ! ; i : i ! ! ; i ~ ~ :1000( : ~ i:: · :: ::! ' .................... : , ....... . . :~ .2[!~i! :: --'' ~ : ''[ ..................... ........... · ':: :i!':. :'. ' ' :: ~ I : , : : · ~ i ! i i ! ! i ! : i ;1400( : : . ~ ~ ~ . . : : : .................... .: . :; ;::. . .. : : : .~ ~ ~ ~L..; ...... ~...~...~...~ .~.: .... ; ~ ;... : ~.~.:. : ............. ~ ..... :: -::: ~::~ : ~ : ::. ~ :~ ': : '. . ;;'- :~;.T .;.~..;~. ;.~ :;~? ; ~ , : : : ........... ~, ~ : ~ ~ ~ ~ ~ ; : : :--: :.. ~ , ~ ~ ~; ~ ; ; · , ~ ~ , : ....... :~ ~ .... ~...~ .~.-~-.~.-.~.~...~-: ..~..~..:..~.. ;.-~-: ~.~ .~.;;; ~ ~:: .:. :;..~ ......... ~ · ~ : :.~..; .... ;..~ ~.; , ~.~ ~ :..~-; ~..; : ; .~. : ~ .~,.~ ..... ~ ; ~ ........ ..... : .......... · . .:. ;~:~ ~, ~: ,. : ~ ~ : ~ : ' : 1600e ' : ' ~ ................ 144(:)0 PROJECTION ON VER'F1CAL PLANE324.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE -, I / 1000 IN/FT ARCO Alaska, Inc. Date' September 24, 1993 Transmittal #: 8870 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 ~ items. receipt and return one signed copy of this transmittal.. Please acknowledge ~)% ~o(~ 1 Y- 18 q%--qo 1Y-31 q~.,~c~ 1Y-18 c~ ~_~ 1Y-27 ~__~11Y'23 Y-23 1Y-27 ~,~/Dual Compensated Neutron Cased Hole CNTG Dual Compensated Neutron 9-09-93 CNTG 9-08-93 v"l'hermal Decay Time Dual Burst 9-09-93 TDTP Thermal Decay Time Dual Burst 9-10-93 TDTP ,/'Dual Compensated Neutron 9-08-93 Cased Hole CNTG ~Thermal Decay Time Dual Burst 9-08-93 TDTP · / Dual Compensated Neutron 9-10-93 Cased Hole CNTG Receipt Acknowledged' DISTRIBUTION: D&M 8550-9072 6450-7689 8550-9071 9250-9798 6600-7378 6700-7300 9250-9799 NSK State' of Alaska (-~Sepia) Bob Ocanas ARCO Alaska, Inc. Date: August 20, 1993 Transmittal #: 8838 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 ~ items. receipt and return one signed copy of this transmittal. ~'~_-~ !~,I Y-23 Y-23 ~1Y-23 0~...~.?_,~I H-14 H-14 ~t1H'13 ~..-t.~ H-13 H-13 i Y'17' c~.~ Y-17 Y-17 ~--OL, --' 1 H-O 1 c1'~.--O% -..-1 H- 02 ct~-, 2..~ ~"1 H-09 · ,/CDN LWD/Depth Corrected "~3D R Very-enhanced LWD/Depth Corrected 'vCDR LWD/Depth Corrected '.,~CDR LWD/Depth Corrected v.,-CDR Enhancement LWD/Depth Corrected u,-CDR Enhancement LWD/Depth Corrected v/CDN LWD/Depth Corrected ~-CDR LWD/Depth Corrected v'CDR Enhancement LWD/ Depth Corrected r./'CDR ~," CDN ,/'CDR Enhancement LWD/ Depth Corrected v--CDR Enhancement LWD/ Depth Corrected ~CDR Enhancement LWD/ Depth Corrected 7-06-93 7-06-93 7-06-93 5-18-93 5-18-93 6-01-93 6-01-93 6-01-93 6-18-93 6-18-93 6-18-93 3-05-93 3-05-93 4-26-93 Receipt Acknowledged: DISTRIBUTION: Please acknowledge 3739-7499 3746-7497 3739-7499 4695-1O524 4786-1O522 6368-10165 6360-10167 6360-10167 4338-8O25 4320-8045 7360-8045 7188-7942 7388-8037 10855-11750 Date: ARCO Alaska, Inc. Date: July 23, 1993 Transmittal #: 8812 RETURN TO: ARCO Alaska, inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items, and return one signed copy of this transmittal. '~"~..2-M~'29 ~'~ 3"~LIs Tape and Listing: - 10-18-92 92622 L..~..~¢ ,...,,~.n.,"7Bit Runs of CDR. Corrected HLDT ,~~-07 ~'["' LIS Tape and Listing: .9-18-93 92563 ~,~/,A? ..~,/,,,\ 3 Bit Runs of CDR. Corrected HLDT ¢J'~.~'~-21 S-i ,. LIS Tape and Listing: '3-27-93 93132 ~.L,~_, ~o~.%.. ./,,,~ .,~L~ CDR/CDN & QRO Enhanced Resistivity '¢i¢'~V1-32 b~. o~ LIS Tape and Listing: 11-17-92 - 92686 ~/"~\-\CDR Runs '1 & 2, Averaged Cased Hole HLDT ~ ~...1-Y-~ LIS Tape and Listing: 6-26-93 93292 ~/'~"~_ ~"1 \~ DTE/SDN & CNTH q'~'~1.¥'~3 ~ ' LIS Tape and Listing: '6-9-93 93263 '~,n0 J..,,,'~ CDR/CDN & GR CBT in LDWG Format 93."'~'~-22 '..l,'l' LIS Tape and Listing: 5-29-93 93244 ~~,~ __-- . ..,~ \~CDR/CDN in 1 Bit Run, GR from CBT ~'~..,.t-Y:-17 ¢ ~ /LIS::Tape and Listing: 5-23-93 93241 ["~_.1o\ .,./-.CDR Runs 1 & 2, CDN Run 2, QRO Processed 12 "~ LIS Tape and Listing: 5-18-93 93239 .. DISTRIBUTION: Please acknowledge receipt Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: June 25, 1993 Transmittal #: 8776 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. C['~.-~7.- 1 Y-24 /Ultrasonic Imager// Cement and Corrosion ~Y-2~ ~ Cement Bond Log (CBT) 1Y-2 ~t~? Cement Bond Log (CBT) Y-2 Cement Evaluation Log (CET) Y-23 Cement Evaluation Log (CET) 6-16-93 6-17-93 6-17-93 6-17-93 6-17-93 Acknowledge: -~ ' Date: Please acknowledge 200-4575 735O-7386 565O-6583 5650-6508 5650-7380 Drilling State of Alaska(+sepia) NSK ALASKA OIL AND GAS CONSERVATION COMMISSION TO' Dave Johnst~ Commissioner DATE: 6-6-93 THRU: Blair Wondzel P.I. Supervisor FROM: Lou Grimaldi Petr. Inspector SUBJECT: BOP Test Parker rig 245 Arco well # 1Y -23 Kuparuk river field PTD 93-71 '. SUNDAY 6-6-93 1 returned to Arcos 1-Y pad in the Kuparuk river field to witness the initial BOP test on Parkers rig//245 drilling well//23. The test went well with two failures observed, these being the lower pipe rams and the floor safety valve, both were repaired and retested before I left location. I find it a pleasure to test on this rig as the Toolpusher and crew seem committed to having the best rig on the slope and have developed a good procedure for testing the B.O.P.E. The area surrounding the rig was clean and orderly even though there was a unusually large amount of pipe on the pad (stacked neatly). SUMMARY; I witnessed the initial BOP test on Parker rig/t245 in the Kuparuk river field with two failures observed. attachments ALASK?"-~-',~L AND GAS CONSERVATION CO,~'~ ',SStON Corni X UIC Lc_,-', J .... Well Nan ! r~ ?. ................ DON ~,-~t[:.z¢z q i0E M. U t': ::':"::. :' ....... ~~.~,=`,`~:~.~.~.~:~;::~:~;::..;:~;`.~:i~,F~¢`~a~`::~t~¢;.~f~- ~ ............. ::'.~s::l~¢M~.'-'~ iL~: ~:::::::::;.;:::;:;::.:';~.~:~.~-~ :~::~.~..~: :~ ::::::::::::::::::::::::::::::::: .~.-:-~.~..~:~..;: ~ · :.~:..~ ~-::::: .: :': :.:.:.'.: ..... '~. '-: ~ ~:-:* · ~ 6..: ':::- ·: -~f. · -'... -'- .: ~: · · ' .'~:'.'..._~.z:'~;~ ~ ...... ~' ~ ............ ~~ ...... -¢ '%~ ..... T ............ , ........... i 4 Ip~n~ ....... ~ X ~ I i ~32~De, a~:ser ~Slind rams i X ~ i I p~iSepara~or ~yi:,ass ~ '- ~ .... :~Z.'.'L%~='~{~-~~ .... ..~]~ ~'" ~"~ ....... ~-~ ....~ ...... ~ ....... a ~~~=.~-_~:~-~=~-~;=~~,~w~w.::'e. 4 ":;:~ :-~'~'~ .... i- - .... i %/ i i ::::::::::::::::::::::::: ': '~- ~ . ~m ' :::.¢. ~I?~-T~;~T~~~T~arrG~ f ~ ~ F~'fEd~v r-oaks {up.,ar. lower IBOP) ~ ~~; ........ ~ - ~ ! ~ i .... - .............. . ....... ~ , i lr-:~F!-'~w Nir, n~- t ~ i i i ~ 8,¢l~-ellv ~ floor ,/,~1,/~ :::::::::::::::::::::: '..~ ~ ~'~ 'l::~:~::'::':u'-',::::':'~g~':~. ~,~ ~:.~ ..~:~e~ ~ ]i~j~-~ .... <- r-~.l ~ ~,~ , ~ u I l~~essure i X i i ~ 142iGas deieo'tlori { 181Op¢,ratin¢ pressure I X~ ] I 143JHydrau,a orlokc~ ~ ...... ~ ~/ C ~[ ~ ':':':':':':':':':':':~'-~D' '"~:~ ~ ..... ~ ~ ...... I ..~-:t ~P~ ~ ,~-'- - ," ~n~¢,,,-,[,-=n, ~.,,~,¢=~ ~ .. ~ , , ~ ..................... ,~..~_., ,.,~N..::~.~:,S...- ....... ~.~C.~... L...~?~..~.,~.= ~%: ~ _-- -..y '~,, ~Z_~_,~%'~ ...... -/ ..... ~ .... ~__. _ .~ .~_~ ~ .......................... ~.:-: mm~,i $ X I [ [ 4o~Persc, nne! protective eqMID. ~/iNliroe~R DO'~i' ~:oui'oe ii;aoKq X i i ~ /4~!Ali D, iJ~tt~ ot.,pe~/l~ gE~e Of Last Ri~ / REde' tr,~r~tir>r, Date nfi Non-Comp!ianoe not oorreoted ~ Reason' . o - Open/Rig o .- Database c - Trip F;pt Fiia o - P~speotor LG6793.XLS (Rev. ! 2/'92:) 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 May 17, 1993 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1Y-23 ARCO Alaska, Inc. Permit No. 93-71 ~Surf Loc 568'FNL, 1342'FWL, Sec 1, TllN, R9E, UM Btmhole Loc 1996'FSL, 1992'FEL, Sec 1, TllN, R9E, 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 ~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 en¢l ---" STATE OF ALASKA ALAS._, OIL AND GAS CONSERVATION COMMISS, PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~] lb Type of Well Exploratory E] Stratigraphic Test E] Development Oil X Re-Entry [~ Deepen r~ Service D Development Gas [--I Single Zone X Multiple Zone r"] 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska~ Inc. RKB 107'~ Pad 66' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage, AK 99510-0360 ADL 25646~ ALK 2577 4, Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.O25) 568' FNL, 1342' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2309' FSL, 2216' FEL, Sec. 1, T11N, R9E, UM 1Y-23 #U-630610 At total depth 9. Approximate spud date Amount 1996' FSL, 1992' FEL, Sec. 1, T11N, R9E, UM 5/25/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14, Number of acres in property 15. Proposed depth (MD and TVD) property line 1Y-22 7531' MD 1992 @ TD feet 30' (~ 1700' MD feet 2560 6370' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 1 700 feet Maximum hole angle 40.06o Maximums~rface 21 35 psig At total depth (TVD) 3466 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling] Length MD TVD MD TVD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 3880' 41' 41' 3921' 3607' 430 Sx Permafrost E & HF-ERW 450 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 7490' 41' 41' 7531' 6370' 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 Measured depth True Vertical depth Structural Conductor Surface ~.~. Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat r-~ BOPSke~:h X Diverter Sketch X Drilllhg program X Drilling fluid program X Time vs depth plot ~] Refraction analysis E] Seabed report D 20 AAC 25.050 requirements X 21. I hereby ce~fy that the foregoing is true and correct to the best of my knowledge Signed ~.//'}~~~'~ Title Area Drilling] En~lineer Date .~/O -~'..,~ Commission Use Only' 7a - 7f~ 50- O ~. ? - ~ ~. ~ 7 (:~ ,.~,~--/ ? - ~.~ ',~ other requirements Conditions of ~oprov., Samples r=uired D v~ E! No ~ud ~og requir.U D Yes E! No ,ydrogen su~,de measuree D v~ ID No Direc~ona~ survey required D Yes D No Recluired working pressure for BOPE D 2M ~-~ 3M [~ 5M r~ 1OM [~ 15M Other: ,_i©h, ~b ~Ot~ by order of ~.~/ Approved b)/ Commissioner the commission Date'~"l I~/~-~' Form 10-401 Rev. 7-24-89 Submit in triolicate I I Y 25O 1750_ _ 2000_ _ 2250_ _ 2500_ _ 275O_ _ _ _ _ 375O_ _ _ 4250_ _ _ 4750_ _ _ _ 5750_ _ _ 6250 _ 6500 ARCO Structure : Pod 1Y Field : Kuporuk River Unit ALASKA, ] ne. Well: 23 Location : North Slope, Created by : jones For: D STOLTZ D.ate plotted : 29-Apr-95 ,Plot Reference is 23 Version #3. iCoordin(]tes (]re in feet reference slot #23. iTrue Vedicol Depths (]re reference wellhead. BAKER HUGHES INTEQ RKO ELEVAtiON: 107' Scale I : 100.00 568' FNL, 1342' FWL I I I I I I SEC. 1, T11N, RgE B/ PERMAFROST TVD=1407 KOP TVD=1700TMD=1700 DEP=O 3.00 East --> 600 800 1000 1200 1400 ! 6001800 2000 II II II II II II II II S 35.63 DEG E 2956' (TO TARGET) 9.00 BUI~ 5 DEG / 100' 15.00 21.00 27.00 T/ UGNU SNDS TVD=2597 TMD=2634 OEP=224 33,00 59.00 EOC TVD=2929 TMD=3035 DEP=448 T/ W SAK SNDS 'PVD=2967 TMD=3085 DEP=480 B/ W SAK SNDS TVD=5407 TMD=3660 DEP=850 9 5/8" CSG PT TYD=3607 TMD=3921 DEP=1018 K--lO TVD=3857 TMD=4248 DEP=1228 AVERAGE ANGLE 40.06 DEG K-5 TVD=4977 TMD=5711 DEP=2170 TARGET LOCATION: 2509' FSL, 2216' FEL SEC. I. T11N, R9E TARGET 3VD=5912 TMD=6933 DEP=2956 SOUTH 2405 EAST 1722 TD LOCATION: 1996' I:~_, 1992' FEL SEC. 1, T11N, RgE TARGET - T/ ]CUP SNDS '["¢D=5912 TMD=6933 DE X T/ ZONE A TVO=6101 TMD=7179 OEP=5115'~X B/ KUP SNDS 'rVD=6217 TMD=7331 0EP=3215'. TD - ?" CSG PT TV'D=6370 TMD=7531DEP=3341 ...... I I I I 15ol 51ool ¢,5ol I I ;sol I ILI I I 15ol I o 250 500 750 10OO 12 1 1 2000 2 2~ 27 3000 .3,2 ~ Sc,de 1 : 125.00 Vertical Section on 144.37 azimuth with reference 0.00 N, 0.00 E from slot #25 ~o,~ ~: ~o.oo E a s t - - > 200 100 0 100 200 ~00 400 500 600 '/CO 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 200 I I I I J I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I °~o ~o °~° '°° 200 _ _ ~0_ 0 600 ~2800 _ ~0 - ~ ~0 _ 2~_ - ARCO ALASKA Inc. - 26~. ~000 Sfrudure : Pad 1Y Well: 2~ 27~_ Field : Kuparuk River Unif Locolion : North Slope. Alasko ~200 28~ ~ I I I I I I I I I I I I I I i I I I I I I I i I I i I I I i I I I I I i 200 1~ 0 100 2~ 3~ ~0 ~ 6~ 7~ ~0 9~ 1~ 11~ 12~ 1~ 14~ 15~ 1~0 17~ Scole 1 : 50.00 E a s t - - > 200 o 1 O0 200 3O0 ~00 500 _ 600 700 _ - 0 - ~7~ 2~ _ _2~ _ . _2~ . _2~ _ _2~ . 2~ . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1Y-23 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3921')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 (7531') 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-23 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~l 9.0-10.5 15-25 15-35 50-100' 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% Drillina 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 11.6 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 25.033. 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/ft. This shows that formation breakdown would occur before a surface pressure of 2135 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-23 is 1Y-22. As designed, the minimum distance between the two wells would be 30' @ 1700' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well ddlled. 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 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. Ca~/ln/g Design / Cement Calculations 7-May-93 ~'~ii""~'~i'~'~'i;'i"" ................................................................................................................................................. ~i'~:~ ................. '"'"'" ............... r'.-.-.-,-, ............. ,--..--,'-...,---,, ............... ,,,,. .......................... ,-, ................... , .............. ~ ................ Surface Csg MD: 3,921 ft Surface Csg 'FVD: Production Csg A MD: Production Csg A TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3,607 ft 7,531 ft 6,370 ft 3,085 ft 6,933 ft 5,912 ft 11.6 ppg 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe = {(13.5'0.052)-0.11}*TVDshoe =[ Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 3,607 ft 2,135 psil 11.6 ppg 5,912 ft 3,566 psi . 3466 psiI Surface lead: Top West Sak, TMD = 3,085 ft Design lead bottom 500 ft above the Top of West Sak = 2,585 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 810 cf Excess factor = 15% Cement volume required = 931 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 430 sxJ Surface tail: TMD shoe = 3,921 ft (surface TD - 500' above West Sak) * (Annulus area) = 418 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 453 cf Excess factor = 15% Cement volume required = 521 cf Yield for Class G cmt = 1.15 Cement volume required =[ 450 sx] Casing Design/Cement Calculations 7-May-93 Production tail: TMD = 7,531 ft Top of Target, TMD = 6,933 ft Want TOC 500' above top of target = 6,433 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area - 192 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 209 cf Excess factor = 15% Cement volume required - 240 cf Yield for Class G cmt = 1.23 Cement volume required =i 200 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and Tf_is)=l.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 (Ib/ft)-- Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ 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 =1 Production (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 (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 =l MAY 0 A!aska Oil & Gas Cons. 564000 lb 3,921 ft 36.00 Ib/ft 141156.0 lb 24227.4 lb 116928.6 lb 4.8] 639000 lb 3,921 ft 36.00 Ib/ft 141156.0 lb 24227.4 lb 116928.6 lb 604000 lb 7,531 ft 26.00 Ib/ft 195806.0 lb 34256.7 lb 161549.3 lb 3.71 667000 lb 7,531 ft 26.00 Ib/ft 195806.0 lb 34256.7 lb 161549.3 lb 4.11 Casing Design / C ..aent Calculations 7-May-93 BURST - Minimum Desiqn Factor = 1.1 Surface Casing Burst = Maximum surface pressure Production Csg 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 COLLAPSE- Minimum Desian Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Production Csg 1. Worst Case - Full evacUation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Max Shut-in Pres = Design Factor =1 Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 3520 psi 2135.3 psi 1.6J 7240 psi 7342 psi 2948 psi 4394 psi 1.61 2020 psi 0.6O3 Ib/ft 1240 psi 1.61 5410 psi 0.603 Ib/ft 3842 psi 1.4] Casing Design / C. nent Calculations 6-May-93 OD ID I b/f t 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 Surface Casing Choices Metal X-Section Jt Strength Body Strength Collapse Burst 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 11.4538 sq. in. 979000 lb 91 6000 lb 3090 psi 5750 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 13.0062 sq. in. 931000 lb 71 5000 lb 2090 psi 3580 psi OD ID Ib/ft I 7.000 6.276 26 2 7.000 6.276 26 Production Casing Choices Grade Metal X-Section Jt Strength L-80 7.5491 sq. in. 667000 lb J-55 7.5491 sq. in. 490000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi 415000 lb 4320 psi 4980 psi 7 ,6 , 5 I 13 5/8" 5000 P ,i 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. TESTALL 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 KILLAND CHOKE LINE VALVES. 6.CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. 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 UNIT I" ~PARUK RIVER 20" DIVERTER SCHEMATIC 5 HCR I 6 4 3 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. 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" o 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 EDF 3/10/92 1Y-23CMT.×LS Well: Field: State Permit 1Y-23 Kuparuk River 93-71 Engineer. Work Sheet: Date: £ement Volume Caleul~li~ns 5/11/95 Casing T j~e Casing Size Ca~ng LenCh Hole Diameter Cement- Sacks Cement-Yield Cement- Cubic tt Cement-Cubic tt Cement-Sacks Cement-Yietd Cement-Cubic tt CemerR - Cubic ~t Cement-Sacks Cement- Yield Cement- Cubic it Cement- Cubic It / Vol Cement- Fill Factor -Inches - Feet -Inches 111 111 111 1!1 112 112 112 112 113 113 113 113 Cor~ucto~ 16.000 80.000 24.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 200.000 1.432 Surface 9.625 3,880.000 12.250 430.000 2.170 933.100 889.700 450.000 1.150 517.500 471.500 0.000 0.000 0.000 0.000 1,361.200 1.120 Line[ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 IIDIV/O! Casing Type Casing Size -Inches Casing Depth - Feet Hole Diameter-Inche~ Cement- Sacks111 Cement-Yie~ 111 Cement- Cubic ~t 111 Cement- Cubic It 111 Cement- Sacks112 Cement- Yield112 Cement-Cubic tt 112 Cement- Sacks 113 Cemer¢. - Yield 113 Cement- Cubic tt 113 Cement-Cubic tt 113 Cement- Cul:~c f[ / Vol Cement-lnte~¥al ft. Top o[ Cement- Feet Inte~meo"~e 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIVtO! I~DIV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I~DIV/0! Production 7.000 7,531.000 8.500 200.00 1.23 246.00 246.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 246.00 1,939.96 5,591.0 · · t~, I .~T, .~,~.t ~: :_~ r,.r~:' Iv1 easured Depth State: Alaska Borough: Well: 1Y-23 Field: Kuparuk River St. Perm # 93-71 1Y-23KRU.XL$ Date 5/12/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 9.625 3607 41 3880 ZA 7 6370 41 749O 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 ?A 0 0 0 0 BA 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 36 J-55 BTC 0 26 L-80 ~ITC 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 4B 5B 6B 7B 8B 9t9 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/It 10,5 0.546 0,446 11,6 0.603 0,503 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0,000 -0,100 0.0 0.000 -0.100 0.0 0.000 -0.100 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 2135 3520 1.6 2135 7240 :3.4 0 0 #DIV/O! 0 0 #DIM/O! o o #DIV/O! 0 0 #DIM/O.I 0 0 #DIM/O! 0 0 # DIV/O.I 0 0 #DIM/O! 0 0 #DIM/O! 1C 2C SC 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 139.68 194.74 0 0 0 0 0 0 0 0 K/Lbs TDF 564 4.04 604 3.10 0 #DIM/O.I 0 #DIV/O! 0 #DN/O.i 0 #DIM/OI. 0 #DIV/Ol. o #DIM/O! 0 #DIM/O! 0 #DIM/O! Collapse Collapse Pr-BDt-Psi 1609 3205 0 0 0 0 0 o 0 o Resist. CDF 2020 1 5410 1.688 0 #DIM/O! 0 #DIM/O! 0 #DIMIO.I 0 #DiV/O! 0 #DIM/O! o #DIM/O! 0 #DIM/O.I o #DIVIO! ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee /~£~_ ~%/~//~_~ (2) LOc. ~p< ~//~/~ '['2 thru 8] - (3) Admin ~]C_ ~/~,/~. ~ '['9 thru 13] [10 & 13] [14 thru 22] · 2. 3. 4. 0 6. 7. 8. 9. 10. 11. 12. 13 14. 15. (5) BOPE ~-,,~.,~.:~. ~-/~- [23 thru 28] 16. 17. 18. !.9. 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 ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Lease & Well NO Does operator have a bond in force ................................... Is a conservation order needed ........................................ Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name & ncrnber ................................ I s conductor st r i ng prov i ded ..................................... :. · · 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 g 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 ~~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other ~/~, ~//~ ~ [29 thru 31]- (7) Contact /~/~C ~/~/?~ [32] (8) Add1 .-/~.~./~.~; ~-/~-~"~_ · ring~ geology en9 i nee ~ DWJ~ MT~/~~ LG rev 12/92 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 n~nber of contact to supply weekly progress data ...... / // Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ~/~ / ~o b~.~/ 7-~, / ~ ?~ ///~ ~ ~/J Additional remarks' UM MER ID~[AhJ' ~ ' SM Exp De~g~. ~ ,>~ Inj WELL TYPE' Redri 1 1 Rev © -rz m z Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, informati~)n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER · * SCHLUMBERGER · COMPANY NAME : ARCO ALASKA, ZNC. WELL NAME : 1Y-23 FZELD NAME : KUPARUK RZVER STATE : APZ NUMBER : 50-029-22370-00 REFERENCE NO : 93425 RECEIVE£? .Alaska Oi~ & Gas C.o,.s..", .... Bate LIS Tape Veri~icat, ion Lis~,ing Schlumberger Alaska Co-mput, ing Cent, er 28-0¢T-1993 13:04 **** REEL HEADER **** SERVZCE NAME : EDIT DATE : 93/10/27 ORIGIN : FLIC REEL NAME : 93425 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK RIVER, lY-23, 500292237000 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 93/10/27 ORIGIN : FLIC TAPE NAME : 93425 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK RIVER, 1Y-23, 500292237000 TAPE HEADER KUPARUK RIVER CASED HOLE WZRELINE LOGS WELL NAME: 1Y-23 APZ NUMBER: 500292237000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-0CT-93 JOB NUMBER: 93425 LOGGING ENGINEER: JEFF FORMICA OPERATOR WITNESS: JIMMY PYRON SURFACE LOCATION SECTION: 1 TOWNSHIP: RANGE: 9E FNL: 568 FSL: FEb: FWL: 1342 ELEVATZON(FT FROM MSL O) KELLY BUSHTNG: 107. O0 DERRICK FLOOR: 107. O0 GROUND LEVEL: 66. O0 WELL CASING RECORD SURFACE LOCATION OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 9.625 3891.0 36.00 2ND STRING 7.000 7477.0 26.00 3RD STRING PRODUCTION S-FRING PAGE: LIS Tape Veri¢ica%ion Listing 28-06T-1993 13:04 Schlumberger Alaska C~mpu¢ing Center CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CET LDWG CURVE CODE: GRCH RUN NUMBER: 1 PASS NUMBER: 2 DATE LOGGED: 17-JUN-93 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 88888 7287 7272 7231 72O4 7199 7188 7141 7111 7097 7044 7012 6928 6915 6911 6703 100 $ REMARKS: 88888 0 7287 5 7272 0 7231 0 7204 5 7198 S 7188 5 7141 5 7111 5 7098 0 7044 5 7012 5 6928 5 6916 5 6911 5 6704 5 101 0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT THE GRCH OF THE CNTG MAIN PASS FROM FIELD FILE .039 SHIFTED TO THE 17-JUN-93 CET/GRCH. ALL OTHER DATA CURVES ZN THE FIRST FILE WERE SHIFTED THE SAME AMOUNT. THE REPEAT CNTG PASS WAS LOGGED BEFORE THE MAIN PASS, THEREFORE, THE MAIN PASS ZS CALLED PASS#2 ON THIS TAPE. $ LIS FORMAT DATA LIS FORMAT DATA PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001601 DATE : 93/10/27 MAX REC SIZE : 1024 FiLE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: I LIS Tape Verifica%ion Listing Schlumberger Alaska Co,mputing Center 28-0CT-1993 13:04 EDITED CURVES Depth shiCted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CNTG 7375.0 6604.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: I EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH REMARKS: NO DEPTH CORRECTIONS WERE REQUIRED AS ONLY ONE MAIN AND ONE REPEAT CNTG PASS WAS LOGGED. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 76 4 66 1 S 66 6 73 7 65 8 68 9 65 FT 11 66 13 12 68 IS 66 0 14 65 PT IS 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** SET TYPE - CHAN ** 28-0CT-1993 13:04 PAGE: NAME SERV UNIT SERVICE API APZ APZ API FILE NUMB NUMB SIZE REPR PROCESS ZD ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440834 O0 000 O0 NPHZ CNTG PU-S 440834 O0 000 O0 ENPH CNTG PU-S 440834 O0 000 O0 CPHZ CNTG PU-S 440834 O0 000 O0 NCNT CNTG CPS 440834 O0 000 O0 FCNT CNTG CPS 440834 O0 000 O0 CRAT CNTG 440834 O0 000 O0 FUCT CNTG CPS 440834 O0 000 O0 NUCT CNTG CPS 440834 O0 000 O0 NRAT CNTG 440834 O0 000 O0 ENRA CNTG 440834 O0 000 O0 CNTC CNTG CPS 440834 O0 000 O0 CFTC CNTG CPS 440834 O0 000 O0 CFEC CNTG CPS 440834 O0 000 O0 CNEC CNTG CPS 440834 O0 000 O0 GRCH CNTG GAPI 440834 00 000 00 TENS CNTG LB 440834 O0 000 O0 CCL CNTG V 440834 O0 000 O0 GRCH CBT GAPZ 440834 O0 000 O0 0 I I I 4 68 0000000000 0 I I 1 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I 1 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 0 1 I I 4 68 0000000000 0 I I I 4 68 0000000000 0 I I I 4 68 0000000000 ** DATA ** DEPT. 7494.500 NPHI.CNTG NCNT.CNTG -9.99.250 FCNT.CNTG NUCT.CNTG -999.250 NRAT.CNTG CFTC.CNTG -999.250 CFEC.CNTG TENS.CNTG -999.250 CCL.CNTG DEPT. 3892.000 NPHI.CNTG NCNT.CNTG -999.250 FCNT.CNTG NUCT.CNTG -999.250 NRAT.CNTG CFTC.CNTG -999.250 CFEC.CNTG TENS.CNTG -999.250 CCL.CNTG -999.250 ENPH.CNTG -999.250 CRAT.CNTQ -999.250 ENRA.CNTG -999.250 CNEC.CNTG -999.250 GRCH.CBT -999.250 ENPH.CNTG -999.250 CRAT.CNTG -999.250 ENRA.CNTG -999.250 CNEC.CNTG -999.250 GRCH.CBT -999.250 CPHZ.CNTG -999.250 FUCT.CNTG -999.250 CNTC.CNTG -999.250 GRCH.CNTG -999.250 -999.250 CPHZ.CNTG -999.250 FUCT.CNTG -999.250 CNTC.CNTG -999.250 GRCH.CNTG -999.2S0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001601 DATE · 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Co'mput, ing Center **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE :93/10/27 MAX REC STZE : 1024 FILE TYPE : LO LAST FILE : 28-0CT-1993 13'04 PAGE' FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH fi les; raw background pass in last fi CNTG $ LOG HEADER DATA 7375.0 6604.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 08-SEP-93 CP 32.6 2130 08-SEP-93 7388.0 7381.0 6600.0 7378.0 600.0 NO TOOL NUMBER CNTG CNTG CNTG CNTG $ CASING COLLAR LOG TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): CAL-YA 1592 TCC-B 420 SGC-SA 26 CNTG 66 3891.0 BRINE 11.70 165.0 LIS Tape Veri¢ication Listing Schlumberger Alaska Computing Center 28-0CT-1993 13:04 PAGE: FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (OPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BOTH SANDSTONE 2.65 BLUELZNE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): # REMARKS: TIED INTO SWS CET DATED 17-JUNE-93. ~CUZRED DATA ZN HIGH RESOLUTION LOGGING MODE. PLOT IS UNNORMALIZED WITH W2FP = 1.0 A W3FP = 1.0 ~ELECTED VALUES' NORTH SLOPE PICKS: W2FP = 1.20 A W3FP = 0.95 # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 5 66 6 73 7 65 8 68 o.s 9 65 FT LZS Tape Verificat, ion List, ing Schlumberger Alaska Co, mpu%ing Cent, er 28-0CT-1993 13:04 PAGE: TYPE REPR CODE VALUE 11 66 10 12 68 13 66 0 14 65 F1 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNZT SERVZCE APZ APZ APZ APZ FZLE NUMB NUMB SZZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 440834 O0 000 O0 0 2 1 1 4 68 ENPH CNG PU 440834 O0 000 O0 0 2 I I 4 68 ENRA CNG 440834 O0 000 O0 0 2 1 1 4 68 CFEC CNG CPS 440834 O0 000 O0 0 2 1 I 4 68 CNEC CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 RCEF CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 RCEN CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 NPHI CNG PU 440834 O0 000 O0 0 2 1 1 4 68 TNPH CNG PU 440834 O0 000 O0 0 2 1 1 4 68 TNRA CNG 440834 O0 000 O0 0 2 I I 4 68 RTNR CNG 440834 O0 000 O0 0 2 I I 4 68 NPOR CNG PU 440834 O0 000 O0 0 2 1 1 4 68 RCNT CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 RCFT CNG CPS 440834 O0 000 O0 0 2 I I 4 68 CNTC CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 CFTC CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 GR CNG GAPI 440834 O0 000 O0 0 2 1 1 4 68 CALI CNG LB 440834 O0 000 O0 0 2 1 1 4 68 TENS CNG V 440834 O0 000 O0 0 2 I 1 4 68 CCL CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 RHFT CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 RHNT CNG PU 440834 O0 000 O0 0 2 I I 4 68 HTNP CNG PU 440834 O0 000 O0 0 2 1 I 4 68 HNPO CNG CPS 440834 O0 000 O0 0 2 I I 4 68 HCFT CNG CPS 440834 O0 000 O0 0 2 1 1 4 68 000000o0o0 0000000000 '0000000000 000000o000 0000o0o000 0000000000 0o00000000 0000000000 0000000000 00o000000o 0000000000 000o00o00o 000000o0oo 0000000000 .oo00000000 0000000000 0000000000 -0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. CNEC.CNG TNPH.CNG RCNT.CNG GR.CNG RHFT.CNG HCFT.CNG 7390 000 2591 831 43 930 1193 033 77 875 1162 798 1143 654 ENPH CNG RCEF CNG TNRA CNG RCFT CNG CALI CNG RHNT CNG 35 687 483 364 4 107 275 478 1500 000 37 800 ENRA CNG RCEN CNG RTNR CNG CNTC CNG TENS CNG HTNP CNG 5 223 CFEC CNG 2399 396 NPHI CNG 4 286 NPOR CNG 1173 401 CFTC CNG -0 OO9 CCL CNG 37 800 HNPO CNG 496.271 49.308 43.930 293.268 295.229 314.295 LTS Tape Verification Listing Sch I umberger AI aska Co'mput ing Center 28-0CT-1993 13:04 PAGE: DEPT CNEC TNPH RCNT GR RHFT HCFT CNG CNG CNG CNG CNG CNG 6594 000 2934 415 35 415 1350 599 131 750 1277 804 1308 314 ENPH CNG RCEF CNG TNRA CNG RCFT CNG CALI CNG RHNT CNG 36 155 560 860 3 508 350 449 1825 000 34 682 ENRA CNG RCEN CNG RTNR CNG CNTC CNG TENS CNG HTNP CNG 5 267 CFEC CNG 2812 448 NPHI CNG 3 478 NPOR CNG 1304 431 CFTC CNG 0 017 CCL CNG 33 323 HNPO CNG 557.155 38.376 34.653 373.445 330.807 379.491 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW CURVES Curves and og header data for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH files; raw background pass in last fi CNTG 7375.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOq-I-OM: -ID DRILLER (FT): TD LOGGER(F-T): 6604.0 08-SEP-93 CP 32.6 2130 08-SEP-93 7388.0 7381.0 LTS Tape Verifica~,ion Lis%ing Schlumberger Alaska Cc;mput, i ng Cen%er 28-0CT-1993 13:04 PAGE: TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 6600.0 7378.0 600.0 NO TOOL NUMBER CNTG CNTG CNTG CNTG $ CASING COLLAR LOG TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUTD LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): CAL-YA 1592 TCC-B 420 SGC-SA 26 CNTG 65 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 3891.0 BRINE 11.70 165.0 BOTH SANDSTONE 2.65 BLUELZNE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F--T): BLUELZNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CET DATED 17-JUNE-93. ~CUIRED DATA IN HIGH RESOLUTION LOGGING MODE. PLOT ZS UNNORMALIZED WITH W2FP = 1.0 A W3FP = 1.0 SELECTED VALUES' LIS Tape Verification Lis~,ing Schlumberger Alaska CcJmputing Center 28-0CT-1993 13:04 NORTH SLOPE PICKS: W2FP = 1.20 g~ W3FP = 0.9,5 LIS FORMAT DATA PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 100 4 66 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APZ APZ APZ APZ FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440834 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNR PU 440834 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNR 440834 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNR CPS 440834 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNR CPS 440834 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNR CPS 440834 O0 000 O0 0 3 1 1 4 68 0000000000 RCEN CNR CPS 440834 O0 000 O0 0 3 1 1 4 68 0000000000 NPHZ CNR PU 440834 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNR PU 440834 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNR 440834 O0 000 O0 0 3 1 I 4 68 0000000000 RTNR CNR 440834 O0 000 O0 0 3 I I 4 68 0000000000 NPOR CNR PU 440834 O0 000 O0 0 3 I I 4 68 0000000000 RCNT CNR CPS 440834 O0 000 O0 0 3 1 I 4 68 0000000000 RCFT CNR CPS 440834 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNR CPS 440834 O0 000 O0 0 3 I I 4 68 0000000000 CFTC CNR CPS 440834 O0 000 O0 0 3 I I 4 68 0000000000 GR CNR GAPZ 440834 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verifica~.ion ,Listing Schlumberger AlaSka Cc~mpu~.ing Cent. er 28-0CT-1993 13:04 PAGE: 11 NAME SERV UNIT SERVICE APZ APZ APZ APZ FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CALZ CNR LB 440834 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNR V 440834 O0 000 O0 0 3 I 1 4 68 0000000000 CeE CNR CPS 440834 O0 000 O0 0 3 I 1 4 68 0000000000 RHFT CNR CPS 440834 O0 000 O0 0 3 I I 4 68 0000000000 RHNT CNR PU 440834 O0 000 O0 0 3 1 I 4 68 0000000000 HTNP CNR PU 440834 O0 000 O0 0 3 1 1 4 68 0000000000 HNPO CNR CPS 440834 O0 000 O0 0 3 I I 4 68 0000000000 HCFT CNR CPS 440834 O0 000 O0 0 3 I I 4 68 0000000000 ** DATA DEPT CNEC CNR TNPH CNR. RCNT CNR GR CNR RHFT CNR HCFT CNR DEPT CNEC CNR TNPH CNR RCNT CNR GR CNR RHFT CNR HCFT CNR 7350.000 2611 976 38 461 1193 033 70 313 1180 936 1172 038 7094 000 3008 978 29 353 1520 933 55 969 1545 321 1518 334 ENPH.CNR RCEF.CNR TNRA.CNR RCFT.CNR CALI.CNR RHNT.CNR ENPH CNR RCEF CNR TNRA CNR RCFT CNR CALI CNR RHNT CNR 40 522 ENRA CNR 458 078 RCEN CNR 3 811 RTNR CNR 323 302 CNTC CNR 2105 000 TENS CNr 38 474 hTNP CNR 29 233 ENRA CNR 671 029 RCEN CNR 3 133 RTNR CNR 477 546 CNTC CNR 1960 000 TENS CNR 29 369 HTNP CNR 5 664 CFEC CNR 2416 121 NPHI CNR 4 039 NPOR CNR 1172 229 CFTC CNR 0 000 CCL CNR 38 421 HNPO CNR 4 582 CFEC CNR 2807 685 NPHI CNR 3 409 NPOR CNR 1518 921 CFTC CNR -0 OO4 CCL CNR 29 926 HNPO CNR 461.114 43.910 38.416 318.651 295.229 318.531 656 765 31 552 29 925 488 583 446 987 488 227 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE - 93/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LTS Tape Verificat,ion List,lng Schlumberger Ala_~ka CO~mput,ing Cent, er 28-OCT-IgC3 13:04 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 93/10/27 ORIGIN : FLIC TAPE NAME : 93425 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK RIVER, 1Y-23, 500292237000 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 93/10/27 ORIGIN : FLIC REEL NAME : 93425 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK RIVER, 1Y-23, 500292237000 PAGE: 12 Cas Cons. Date., }/~!~/ : Alaska PAGE i N C., IK I.]i p/':, R U K 1Y-23,50-029-22 :?70-00 "4 5 [, 0 ) ! bi C,, K [.l 'P A R U K R ']. v E: ~ U ,~'! 'I T, [~IT ~t..i~t{ 2 .... S T, l~ '4 0 U F! I 1 17'; 9 E 1 3 ,l 2 1 ()7.0 q f~!"l' FT,.Z..E ('I~'.') STZK ¢IN) DKI::-TH CF'T) H,5'3C). . · ~.. . ! ! .Y - 2 3 , 5 0 - 0 2 9 -?.. 2 37 O- 0 0 WET_,!,,,, $tE~V ICF;S. IlS Tar~e Veriftca..t.ion bi,,st,ino ~c~ lumber~:~r ~ 1 a~ Ka CoroDutl ! C ,an t e r Per, th shi,,,t~ted and F'] 1.,~? NPU TOgl, COD? $ 3R92.0 .......... ~.1L.} t.l I' V a I., !::' q ']" 7306.0 7 72 ,] 5. o 7'2nO. O 7105.5 7171 .5 71~.0 7!2~.0 7 O~, ~. 0 7060.0 7057.0 705 7 ('4~. 0 7 n,! 4.5 7013.5 7el! .O '7006. (? 7 ,'~9 J. 4.0 6ql 1 6959.0 6 ~ 834,0 6931.9 ~,796,5 6795.0 67 4 %. 0 all bit: runs merged. ~,chl,~]mh,:erqer ,~.las.k.:o.., Coml:;',ut:J.r',o Center AGE: 67 05.5 6704.5 66537.5 669&. 667 g. 0 6 6649,0 664~. 0 6642,5 664~ .0 656~, 0 6567. 6536. () 6535.0 6515.0 651. 4. 6474. o 6~.72.5 6417.0 6406.0 6405.0 6365,5 6363.0 '63a, 9.0 63,4,7.0 63~3.0 6322.0 6224.0 (;~ 92.5 6 ~ 91.. 5 6172. O 6 ! 80.5 60o3.0 6007.0 5966.0 5964:. 5 5855,0 5854.0 5827,0 5~25.5 5914,0 ! O0,0 o~, 0 ~ch]..umberc.~r A],a.,zK.a C/om..r),]t.i~n. Center 9 G '! ! 6 ! 6 G , , S, g T ]."i' P F,' N ~ ~,,~ ~ S F ~ ~ 1,1 ~,,,'~ 1 "t~ S E P V ~, . .,, [.) R [..~ r,~ u w r) d / E3 6 !, 91 f,;P~l" mu.;O P!)-8 6!.91 ~ ~ [~ M ~"' F; ['] ~] ~q H 6191 VPP ~4 a f,) 0 ~ ;',,~ P 61al P ~ Lf!(:; T¥'pF, C[..,ASS N~ 01 () 0 00 0 0 0 ......... .....mw ........... . .... .m.. .... .... o ,1 11 4 6 ~ 000000 0 (~ 1 1 1 4, 6 R O 00000000 0 0 ~. J ~ 4 68 0000000000 0 1 ! I a: 6~ 0000000000 0 t 1 1 4. 68 00000000~0 0 '1 1 1 4 68 0000000000 0 1 I I a 68 0000000000 o 1 ! ! 4 68 O000oo00oO (,' !, 1 1 4 69 0000000000 o !, i ! 4 68 00o0000000 0 1 !. ! 4 68 0000000000 (; ~ ~ ~ ~ 68 0009000000 f: ! 't I 4 68 O000oooono 0 1 1 1 4 69 0000000000 n !. ! !.. a 6~ 000000000() 0 1 !. ~ 4 6~ 0000000000 (i 1 ~ 1. ~ 6~ 0000000000 R H [', b. Y L,; I) ',!PN ! o G k'.. ;: 1,' n [./e., ,! t,: i3 2.497 Di< }s{.'. x~t4D 0,. ooq PEF.mWD 4. R (; 1 r,! C ~': T. !',; ;4 t) 7 4. () 5.00 0 F' C Fi T. m '.,4 D 2..549 v~ h. ki,,i 9 2.605 -999.250 -999,250 -999.~$0 -999.~50 4.466 2.483 7.458 ~chl. Umherc~er A.l, atka Cor:"i'~ut'lr)c~ center 9 -J i,t [,,,., :] 993 09:!.5 . .... ,., ,.... ~ ,, 3.158 VW t,, ~',~9 3.306 7:3.703 1:,,,tC ?,! ','l'. ~,,i W ~b 5.27 I. V R A. ~', w D 0 006 sl 4,897 2.28('1 D al.~ 0. ;,,l ~ [) -0 002 '.2., 4,057 ~ A., '~. ;,, t) 14: 605 4,8. 924 ' D {~l C ~ 'r, FI W 7 ~ ()3,644 12.902 VPA.>~WD 16.052 39.4t)O P h. Xt<[) I 3 !. 378 NCk'C..,~W~) 2.4.1. (', V~ A. 2.4:12 77.6i9 2.477 D F' ~4 ~'.~. ,',! i~ 0 36. '! 9 fi p ;'~. '.,! 2.75 4, tr 1:~, A. ~ k' l) o. 01. 4 1 6!8 6903:396 1.435 0. O54 1.996 6802. 209 1..868 0,0('1.4 2. 580 6701.500 2.349 -0.0O5 2.783 6601.724 9.71.1 O 2.966 6501..669 2.R64 PEF.~WD RP.~WD FcN'r.~WD VRP.~D PEF.~wD RP.~WD FC%~T.~WD VRP.~WD PBF.~!WD ~P.~WD F'CNT.~wD VRP,~WD RP.~WD FCNT.~WD VRP.MWD PEF. ~ RP.~WD FCNT.NWD PEF.MVD RP.~WD VRP.~D PFiF.MWD RP.~D FC~T.~WD V~P.MWD PAGE: 4.480 3.230 7.403 3.188 2.888 29,445 8,886 56,064 3.82'1 5,063 7,750 4,735 3.167 9,457 9.993 !,4,026 9.070 1.539 5.095 1.475 11.456 1.905 4.564 1.919 3.921 2.329 5.764 2.342 4.1.60 2.641 6.040 2.620 4.319 2,699 6.536 2,719 ~-Jt,~b-1993 09:15 2.51 5 33.334 3.4,00 2.421 35.5 ~; 0 117.~2~ 2.4 23 36.4,20 36.316 17. 390 39. 977 2.336 ,1. ~. 4 (') f) 2~. 1. 35.200 ! .71 !_ P. 356 0..011 3 1 5 i 641011679 3,169 -O.OOt~ 3,524 6301.610 3.476 ,.o.016 2.4B6 620! .638 2,.,.558 0,025 1,. 264 610~..774 1!,. 2o5 0.012 '2.90!. 6001.527 ~.931 o. 0 01 3.~67 5qO1,708 3.246 -n.oo3 1.319 5902.500 1.191 -0.0O2 1 .777 5702.5L)O I .q55 0.003 1.892 5602.5cO 1.922 4,016 2,988 6,773 3,039 4.223 3,341 6,984 3.201 4.192 21390 6,649 2,392 4,157 1,236 6,480 1.32e 4.452 2.744 6.386 2,778 4,8~6 2,991 5,694. .~.987 3.361 1.095 5,640 1,171 5.090 1.673 5.883 1.Re8 3.344 1,835 6,4.12 1,837 ,~chlumbercleF A18ska Comp~.,~,ti. mq Cer~te -999 G~'. CE~T -999,2'50 (.;P. CP'I -999. 8 - J'.'.'...~ L,-19 03 o 9; .'15 2.606 V P A. t';. ~:~1 b 0.005 2.655 5502.500 2.628 0.016 2.509 5407.5O0 2,~59 32,100 P. ~,,, ~g :4 g 3,10 '1 ~i.t 0. l 22 Fr C ~,7; '..1::. H ~, D 53 () 2.500 2.o~8 VRA. r'<w9 3.086 31 .8'J0 .I,,02.54 3 2.800 2.276 P F'.': t~ r). ;4 ~ P 3 '7.2 (i ('1 ? A. ~-' !,'; D ~': 5.2 f:) 5 % C ~: T. *," :,', 9 2.072 lip ~. i,,.',' ;,~ [) 2.. '.2,., b 5 .P., p t.i {t. t'4 ,,.i D 83.793 ~,~C~..'r. x~ ~ 0 2.260 p [:,, [4 (: · ;,': ¢: !) 37 f~ 0 3 ,t,, ;,,,. ;,,,, ~,,,-p 2. ~76 VPi'~, -O.008 2.925 5202.50O 2.865 0.002 2.35! 51,02.500 2. :t95 -0.011 2.041 5OO2.5O0 2.154 2.593 4902.500 2.605 0,008 2.290 4R02.5oO 2.261 -0.006 2.961 4707.500 2.843 PEF.Mt~D FC~T.~WB PEF,~WD FC~T,~WQ VRP.~WD PEF.~D FC~T,~WD VRP.~WD PEF.SND ~P.UWD FCNT.UWD VpP.UWb PEF.u~D RP,gwD FCNT.UWD VFP.~W9 PEF.~WD FC~JT.~D FCpT.~'WD VRP.U:~O 3,.1,85 , 7.5f¢0 2.515 3.556 2.670 6,620 2.760 3.153 2 901. 2,911 3,126 2.800 6.973 2.776 3.036 2.293 6.830 2.299 2,861 2,092 6.115 2,1~1 2.836 2.494 6,163 2.506 2.838 2.210 5.537 2,207 2.732 2.833 5.895 2.850 'I8 *ar.:~e Verifl, catior~ !.1, st,~.,~c~ ~chlumb~.r~:~er h,l, as~,:a Cor,~PUtin~ ('er~ter Gu. CRT -9q 9.25 ('! 4500. 000 R~,iO~. ¢.~wp 2..,.'2.. 0 !. 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I_,w I PSR.L.;~t DRHN.bWI PAGE: 14 3.951 0.000 0.367 0.000 2.175 0,013 0.371 0.000 4.279 -0.001 0.357 0,000 2.808 0.002 0.390 0.000 3.429 0.002 0.412 0.000 4.139 0.008 0.]88 0.000 2.729 0°002 0.44.6 0.000 2.654 -0.011 0.494 0.000 -999.250 -0.293 0.528 0.000 -999.250 -999.250 -999.250 0.000 ;ch.!,.umber!;~er ~,!as~a Computl, r~o C¢..r, ter PAGE: t5 Curves anti ,l,,od' head, er data for each bit run t,n sec, arate fi. les. ST~-', [,. !;,P'... II I i~I~ I 7.4. 9 9.0 '7 4: t¢ 0. o q dli,,'-q 3 PC.~C.,? 2 "..r..,C: ~q!~e Ver.ifi, cat~or 1.6 5O0 3B9:1,0 ,I !.. 70 3. 2,4:9 2.65 ~,500 8 0,0 .-'IS ~r:a,~e v'ertfltcation !:,istlna ;ch.!.u,~erc~er /~,!a. ska Comptlt!Bc.! Cen. r,.er P~GE: PrF' L¥.? Fl 91 01 O0 !:,~ t~ l., I,',.,: ? ,T'N ¢ 1, ~ ]. r./1 OO $~F'.,'~a 'l,w'2 CPS 51910! T r,. ~% r. [, :,',' 2 GI91.0! -9S;9.25n A'T' !;:. !_, w 2 -999.250 PSR.I,W2 -97a.25n P t-i [- :>. [, ,,; 2., -990,. 25o DPt40. l:.,w 2 -a9(,.259 r)..r. ~ :T. b t'; 2 -g99.250 T~-JDFI. 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