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185-046
WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϱϬϰϲϬ Ͳ^Ğƚ͗ϯϲϭϴϬJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ;,; RE: Gas Lift Survey: 1Q-15 Run Date: 8/25/2010 August 27, 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 1Q-15 Digital Data in LAS format, Digital Log Image file 50-029-21308-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ~: ~ ;.~ , klinton.wood 4, ~ ,~ ~~~ ~~ Date: G~,~ ..;a Signed: Cono+coPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~~~ . .. -APR 2 '7. 2010 ~~ . ,tasks ~1~9l~ ~ Cons. Gommissiar. ~t1C~aQR `~U Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi.J).. 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 March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru Apri117, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since Perry 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 4/23/10 1A. 7 F. 1Q 3i 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF ri/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6/2010 1A-05 50029206270000 1811040 SF n/a 6" Na 4.25 4/7/2010 1A-08 50029203130000 1780400 SF n/a 10" Na 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" Na 2.55 4/2/2010 1A-15 50029207110000 1820170 SF n/a 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" Na 4.25 4/1/2010 1 Q-02 50029212480200 2051420 22" n/a 22" Na 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" n/a 27" n/a 3.4 4/6/2010 1 Q-05 .50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" n/a 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" n/a 32" n/a 3.82 4/1/2010 1 Q-15 50029213080000 1850460 22" n/a 22" Na 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" Na 25" n/a 3.82 4/1/2010 1 Y-21 50029223870000 1931020 23" Na 23" Na 3.82 4/1 /2010 1 Y 24A 50029223717100 2041250 26" n/a 26" Na 3.82 4/1/2010 1Y28 50029223800000 1930890 28" n/a 28" Na 5.52 4/1/2010 1Y-31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1/2010 i +~ ~ t. ~~ ~. F = ~ :~~,y ~~~~ ~~~~ ~~xm~saiv~ ~iay~c>saic ~~R~7c~s~ l~c, i o: AOGCC Christine ~Ulahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hale/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the following : BP Exptoration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and - ZCI~~~ ,,:=,,(y ~~~~} ' ~~` ~~ ~ ~ .. ~ t~J ~r 4 4J ProAc~ive Diagnostic Services, tnc. Attn: Robert A. Richey 130 West tnternational Airport Road Suite C Anchorage, AK 99518 Fax (907~ 245-8952 r ~3~ ~ 1 J Caliper Report 02 Aug-09 1 ~-15 1 Repor~ / EDE 50-029-2'I 308-00 2) r ; ~ (~ Signed : ~ ~ ~!/ Print Name: t'~~ !~`~ -,~f~o Date - _ _ .. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. BNTERNATIONAL AIRPORT Rp SUITE C, ANCHORAt3E, AK 99518 PHONE: ~907j245-8951 FAx: (90T~245-88952 E-MAIL : ;'_ VUEBSlTE : ; j~~ :s'`_ C:~Documents and SettingslOwner~DesktoplTransmit_BP.docx . • ~ Mernor~y IUlul~i-Fin~er Calip~er Log Resutts Summary Company: _. ConocoFhi!lips Alaska, lnc. _ Well: 1 Q-15 Log Date: August 2, 2Q09 Field: Kuparuk Log No. : 7354 State: Aiaska Run No.: 2 API No.: 50-029-21308-00 Pipe1 Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD Top Log Intvl1.: 8,378 Ft. (MD) Pipe1 Use: Tubing Bot. Log Intv11.: 8,468 Ft. (MD) Pipe2 Desc.: 2.8" Top Log Intvi2.: 8,468 Ft. (MD) Pipe2 Use: Pilot Hole Bot. Log Intvl2.: 8,533 Ft (MD) Inspection Type : Whipstock PlacementAssasment COMMENTS : This log es tieal into the top of the Injecdon Mandre/ 11 ~ 8,418' (ELMD). This !og was run to determine the orientation ofi the whipstack at 8,520' and the condition of the 2.8" miiled hole above far placement of a 2"~ whipstock. The caliper recordings indicate the milt out window appears to be oriented at ~315 degrees. The caliper recardings also indicate miN wear (8,468'-8,482', 8,484'-8,497') in the 2.8" piiot hole logged. A 3-D log plot of the centered and off-centered caliper recordings of the 3.5" tubing and 2.8" pilot hole logged is included in this report. Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: Ed. Hylsky ProActive Diagnastic Services, Inc. j P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-i369 E-mail: PDS~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 v Z C,r' t$ S' Cx~~o l`b ~~'~ . • PDS Multifinger Caliper 3D Log Plot ~,_.~ ~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1Q-15 Date : August 2, 2009 Description : Detail of caliper Recordings of the 3.5" Tubing and 2.80" Pilot Hole Logged Comments Depth Nominal I.D. (1N000 in.) (Off-Center) Image Map } .. ................................................................»................. 1ft:75ft 1500 4500 0° 90° 180° . 270° 0° Min I.D. (1/1000 in.) 1500 4500 Max I.D. (1/1000 in.) 1500 4500 8380 3.5" Tubing Jt. 267 8390 3.5" Tubing - ~ Jt. 268 ' 8400 8410 , Pup Jt ;i __ I- ~ ~ i I i i i 8420 ~ ~._...~.~.,...~ 3 -~• Injection - - - - ~ - ~ .. d,. ::~;}_~.~ Mandrel 11 I 4 ' -- ' ~~ • . PDS Multifinger Caliper 3D Log Plot ~.-.~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1Q-15 Date : August 2, 2009 Description : Detail of caliper Recordings of the 3.5" Tubing and 2.80" Pilot Hole Logged Comments Depth Max I.D. (1/1000 in.) (Centered) Image Map 1ft:75ft ~~ _ 45~0 0° 90° , 180° 270' U" Min I.D. (1/1000 in.) 1500 4500 Nominal I.D. (1/1000 in.) :. ......................................................................................~ 1500 45pp 8380 3.5" Tubing Jt. 267 8390 3.5" Tubing j ~ ~ Jt. 268 -.-~_-~ 8400 8410 ~ ~ Pup Jt j -'~w.~'G ~., _,,.. ~ ' E ~ . "'___- I /~ "., r~~f.+~% '~" . ,.. ~ iHi~ ~ ,.... .~~4r~..:.a ~ ...~"_.._. .....:....... ... ....._~_~ .~ ... . 8420 ~ ° ~ ; 3 I ~° ' ~ Injection ~ ~ rt -~ ~, Mandrel 11 ~ ~F ~ ~ ~~-~ ~ KUP 1 Q-15 ~OIIOCO~l1~~IP 5 W~ ~ ributes An e 8 ND TD :,i: w ae 50029 tldMSne d 2130800 KUPARUKRIVERUNIT PRODUCING a~ry ~ 50.15 8700.00 aaeen ~ 8,866.0 Commert SSSV: LOCKED OUT H28~pqn) 86 e fi/20/2004 AmotatlonFiMD3e Last WO: KB1itl(Ip 44 50 RlpReleaseDale 5/1M7995 aa ia ~~ ~ - . u i DepM 1 ste Amotatlon Last N1o0 ae Lasl Tag: RKB 8J05.0 5/22/2009 Rev Reason: TAG top of Cement 8427 SLM krasbor 6l10/2009 Css1 Stri s acmg atnng sec oeqn qn 1 ) ~e vrt ~ 9 ceyng o esa~ptlon Iln) IMI ToP 1~g1 1~81 I~sl lro~l Q'aG e Top 7trtl coNOUCroe, CONDUC TO 7 8 7.062 44.5 102.0 1 02.0 62.50 H-60 ~o~ SURFAC E 95 l8 8J65 0.0 4420.0 3,5 244 36.00 Jb5 soreTVVw. ~ ' --- PRODUC TION 7 fi.151 0.0 8.8G0.0 6,5 55.6 2fi.00 J-55 1,916 d Tubi Strin 7udrp Descnpnon ere o P~) o amrg (ln) ToP QIItB~ oe MNd) se~ ne ~ (~~) rn p~~q so-~ ~'~ ~M iop 71rtl ersuFr, io~ f z TU ING 3 V 2 2.992 0.0 8.48 -0 6,3 104 9.30 J-66 EUEBRD , OtlNr I n Hole A ll Jewe : Tubf Run 3 RatrlevablQ Fish etc . GASLIFT. a,is~ T~ ~g) Top Deptl~ ~N~ (roc8) lbpllld (~ De on Cammat R ~n Date ID g 1,91fi 1,790.3 46.40 S AFETV VLV Baker'FVL' (locl~etl Ou16120l89) 6/1 6/1985 2.873 suRF^c~. 4 620 Y 2.107 1.922.3 46.1 G AS LI CAMCQ/KBUGIi/DMYiBK/tl Cmment: STA 1 1/1 4/2007 2. 75 4,181 3.341.6 45.28 LIFf CAMCO/KBUGIi/DMY/BKIIlConment :STA2 1/1 4Y2007 2.875 ~~s~iFT. spse 5,468 4.238.1 47.29G ASL~ CAMCO/KBUGf1/DMYBK//lComment :STA V7 4l2007 2.875 6,221 4,748.4 4746 G AS UFT CAMCCYKBUG~1 /BKd/Contmmt : STA4 7/1 9/1996 2.875 eas u~ 6,6 5 5,045.0 46.61 G ASUFT CAAqCdKBUG/1/DMY/BKI/lCanrnent 5TA5 V1 4/2007 2.875 . s.1z+ 7,093 6.347.6 46.44(3 ASLIFT CAMCOIKBUGIt/DMYlBK!llConvrient A6 7/1 H/1996 2.875 ,527 5,646.7 46.10 G AS LI CAMCOIKBUGIt/DMYBKI!/ Cortrnent : STA 7 7/1 4f2007 2.875 ~ S,t 4 6,065.0 46. G ASLI M X/1.5 MY/RA4/ ommen l:S A8 !2 1/1996 2.8 5 ~~~~ . 6.655 8.1&9 6,0.96.8 45.53 P 8R Baler 6Y1 6l1985 2.813 8,176 6,101.7 45.58 P ACKER Baker'FHl' 611 6/1985 3. 0 GASLIFT. B,ZSS 6,158.7 46.041N JEC ION MERLHlTPDXl1.SrDMV/RNW/Carwix nC5TA9 CV7 6/1985 2.875 ~ 09' 8,329 6,2WJ 46.77 1N JECTION MERIA(fPDXl1.5/DMY/RNtll/ Cortme nC STA 10 9l1 7/2008 2.875 8,438 .281.4 47. IN JECTiON ME X/1.5JDMY/RNV// Canne M S A 11 7/1 8/1996 2.%75 ~~~i~. ? 5Z~ 8.452 6.290.9 4.97 P AqCER Baker'FB4' 611 6/19 4.000 8,469 6,302.3 48.15 N iPPLE Camco'D' Nipple NO GO a< MILI ON 5l302009 > > FROM 2J5 TO 2.80 5I3 0I2009 2.800 ~asuFr tI4 B 8,480 6,309.7 4827 S OS Camoo 1 6/1985 2.992 . e,eai 6.31 .4 +a.sa rn s~i s~isas z.ssz 8.538 6,348-0 48.89 FI SH 2. Svedge Lost in RaMde 6/6 //990 Pea. e,,ss PaAOfe tlons 3 Sbts Top (TWj Bhn (TVDry m~ Dens lan PACKER.8.V6 T g,2G0 eon 8285 I~BI 6,160.1 1~1 6 177.5C mne ~.G3 7O-15 orie 6/16/1965 ... 72.0 IPER F ~~K 5'ScalopedGunsHD;120deg ph , , . 8,394 8,40~ 6252.0 6258.1 U NI 8, 10-1 6/16/1 72.0 IPER F S' Scabped G~n s H D: 120 tleg. ph IN.ECTION, H,AB~ 8,482 ,297.0 8,29Z6 U NR B. 10-75 5l312009 6.0 APE RF 2" HYPERJET HS D, 60 DEG H 6 Z~ 8.552 8,626 6, .1 6,406J A -4, A-3, 1Q-15 6/7 f1995 4A tPER P 4" Cartier JJ II; 12 0 d eg. Dh 8,GFi4 8.660 6.423.6 6,427A A -2, 1¢t5 6/16/1985 4.0 IPER F 4" '.IJ II: 12 0 deg. ph 81W~8,285 Notrs: General 3 Sflfe OM D ~e Anqtatlon 5l30/20Q9 NOTE MILIE D D NIPPLE ~ 8469 FROM 275 TO 2.80 ID iri ~~oN. 8.329 IPERF, 8,394b.406 M.ECTION, 8,438 PACKER, 8,052 APERF. 8 461A dfi7 NIPP E 6 L , 84 9 $O5, B 680 rIL . 8 481 ~ FISH. 8.538 IPERF, 8,552~ 626 IPERF. 8,654-8.660 CemeK SWe~e, 6,070 PROIXICTION, B,BBO Tn, tl 866 ~ ~~~~iv~n ~ STATE OF ALASKA )~N ~ ~ zI~O~ ALASKA OIL AND GAS CONSERVATION COMMISSION '' REPORT OF SUNDRY WELL OPERATI~9~~~ ~+ ~~s Cons, eomm;~e;~R 1. Operations Performed: Ab8-ldon ^ Repair Well ^ Plug Pertorations ^/ , Stimulate ~ ~t~~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, IttC. Development ~ Exploratory ^ 185-046 /• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21308-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' - 1 Q-15 - 8. Property Designation: 10. Field/Pool(s): ADL 25634 • Kuparuk River Field / Kuparuk River Oii Pool 11. Present Well Condition Summary: Total Depth measured 8866' ` feet true vertical 6559' feet Plugs (measured) ~~S'~~,~ ~~ Effective Depth measured 8770' feet Junk (measured) 8538' ~~~ true vertical 6497' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 102' 16" 102' 102' SURFACE 4327' 9-5/8" 4420' 3524' PRODUCTION 8767' 7" 8860' 6556' Perforation depth: Measured depth: 8260'-8285', 8394'-8404', sqz'd off intervals = 8461'-8462', 8552'-8626', 8654'-8660' true vertical depth: 6160'-6178', 6252'-6258', 6197'-6298', 6357'-6406', 6424'-6427' ' Tubing (size, grade, and measured depth) 3.5", J-55 @ 8481' jr if~ ~,s(~ 4r~s ~j a.~i`a+'~"~t~A~itrO/' ~~~~~ V k~ ~~U~~ Packers & SSSV (type & measured depth) Baker'FHL' pkr, Baker ~FB-1~ pkr @ a176', 8452~ Baker'FVL' SSSV= 1916' 12. Stimulation or cement squeeze summary: lntervals treated (measured) below 8450' . 24 bbls 17 ppg cement Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG~ GINJ^ WINJ ^ WDSPL^ 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: 309-147 Contact Gary Eller @ 263-4172 Printed Name J. ry Eller Title Wells Engineer Signature Phone: 263-4172 Date ~~~~ ~q P ar b Sh r n Allsu - rak 263-4612 ~ 1 ~` a Form 10-404 Revi 0 ~1~ ;~i~i. ~~ ~ 2~~~ ~ ~ ~ ~ t t ~7 / ` ~ ~ ~ "Gl °~ I Submit Original Only ~f~~~~i 1 Q-15 Well Events Summary DATE SUMMARY 5/22/09 TAGGED @ 8705' RKB. MEA~E BHP @ 8552' RKB: 3585 PSI. SET C V@ 8469' RKB & PT TBG 2500 PSI, GOOD. PULLED SV. READY FOR E/L PERFS. 5/29/09 ATTEMPT TO MILLOUT D-NIPPLE @ 8469 RKB, HAD SEVERAL STALLS & LOST ALL ROP. RTN IN A.M. WITH NEW MILL. 5/30/09 MILLED OUT D-NIPPLE @ 8469 RKB TO 2,80. WELL IS FREEZE PROTECTED, READY FOR E-LINE. 5/31/09 PERFORATED THE 3.5" TUBING IN THE MIDDLE OF THE SHORT JOINT BELOW THE D- A ' ELMD. CORRELATED TO SLB PERFORATION RECORD DATED 21-MARCH-2005. PERFORATED THE INTERVAL 8461'-8462' USING 2" HYPERJET HSD. API DATA: 0.33" ENTRANCE HOLE, 9.6" PENETRATION. 6/1/09 DRIFT THROUGH MILLED D NIPPLE @ 8469' RKB W/ 2.79 SWAGE. WELL READY FOR COI L. 6/4/09 PERFORM CEMENT SQUEEZE: PUMPED 24 BBLS OF 17 PPG CEMENT, SQUEEZED 5 BBLS BEHIND PIPE, TOC ~ 8450 CTMD, LEFT 1500 PSI TRAPPED ON WELL. 6/8/09 TAGGED TOC Cc~ 8421' SLM( ESTIMATED 8441' RKB) PT CEMENT TO 1500 PSI, GOOD.RETAGGED TOC 1' DEEPER. COMPLETE. ConocoF'hillips ... PIAsk~ In.r,. saFEn GAS LIFf, O,tfit GAS LIFT, 6,221 GAS LIFT, 6,fi55 GAS LIFT, 7,093 GAS LIFT, 7.527 GAS LIFT, 8.126 PBR. 8,189 Ap(ER, 8,1]6 INJECTION, 8.258 IPERF, B.P60-8285 INJECTION. 8.349 IPERF, 8,396-B.d01 INJECTION, 8.638 ~ACKER, 8,452 APERF, 8,~61-8.a62 NIPRE. 8.169 SOS.8.980- - TTL,8,~81 FISH,8.538--- - IPERF, __ 8,656-8,660 Cement SqueB2e,8,6I0 PRODUCTION. 8.860 \ TD, 8.866 ~~ KUP ~~ Well Attributes __ I ;wau s~a~ PRODU I IM t tion'~En LaSf WO: ~.. . ~ ~~~~ ~~~~IA oGtion Depth(HKB) EndDate Annotation ILast Tag: RKB I 8,705.0 I S22/2009 IRev Reason: TAG top of Ce ~Casin Strin s i String OD String ID Set Depth Se 1s- Casing Description (~^) (~~) Top (ftKB) (HK6) 15.062 44.5 102.0 . CONDUCTOR 16 I~SURFACE ~~- .. . . .9~5/SI 8.765 0.0 4420.0 -._. PRODUCTION ~ 7I 6.151 0.0 8,860.0 ITubing Strings String OD I Shing ID Set Depth Se TubingDescription (~~) ' (in) 7op(ftKB~ (hK8) TUBING 3 7;2~ 2.992 0.0 8.481.0 Other In Hole (All Jewelry: Tubing Run & Retrievable, F Top Depih (TVD~ Toplncl Top (flKB) (hKg~ (°) Description Cor ~ 1,916 1,790.3~~ 46.40iSAFETYVW ~Baker'FVL' (LcekedOut62~ 2,707 1 922.3I 46.15~GAS LIFT CAMCO/KBUG/7/DMYlBK//! I~ 4,161 3,341.6~I 4528 GAS LIFT i,CAMCOIKBUG/1/DMY/BK/// 5,468 4,238.t I q72g GAS LIFT CAMCO/KBUG/1/DMY/BK/U 6,221 4,749.4 4746 GAS LIFT CAMCO/KBUG/1/DMY/BKIf/ 6,655 5,045.0 46.61 GAS LIFT CAMCO/KBUG/1/DMY/BK//! 7,093 5,347.6 46.44 GAS LIFT CAMCO/KBUG///DMY/BK/// ~,527 5,646.1 46.70 GAS LIFT CAMCO/KBUG/1/DMYBK/U 8,124 6,065.0 4520 GAS LIFT MERLA/TPDX/t5/DMY/RM/ 8,169 6,096.8 45.53 PBR Baker 8,176 6,101J 45.SSiPACKER Baker'FHL' ~ 8,258 6,158J 46.04IINJECTION MER~A/TPOX/1.5/DMY/RM// 8,329 6,207.7 46J71NJECTION MERLA/TPDX/t51DMY/RM/i 8,438 6,281.4 47.821NJECTION MERLA/TPDX/i.S/DMY/RM// I 8,452 6,290.9 47.97 PACKER ~Baker'FB-1' 8,469 6,302.3 48.15 NIPPLE !Camco'D' Nipple NO GO << I,ON 5/30/2009 » WeIIGoreAPVUWI FieltlName 500292130800 KUPARUK RIVER UNIT C«nment HYS(ppm) Data . ... SSSV: LOCKED OUT 86 6/20/2004 • 1 Q-15 Max A Incl(°) ngle 8 MD MD (NKB) TD Ac[ Btm (ftKe) CING 5015 I 8,700.00 8,866.0 d Date KB-Grd(k) Rig Raleasa Dat I 44.50 I 5/14/1985 ILast Mod By ~End Data ent (cil 8422' SLM Imosbor I 6/70/2009 m Comment: STA 2 Comment: STA 3 Comment: STA 4 Comment STA 5 Comment: STA 6 Comment: STA 7 // Comment: STA 8 1 . , , ... . _ . .... .. _ _.--° '.IOf1S $ SIOtS .. .. ._. _. . . .____ ..- I Shot I Top(fVD) B~m(TVD~ ' Dens ' Btrn (kK6) (NKB) (HKBI , Zone i Date (sh... T,/pe '.~ 8,285i 6,160.1 6,177.5 C-0,C-3, 10-15 6/16/1985 12.OIIPERF 'S"Scallopf ~ 8.404I 6,252.0 6,258.1IUNIT B, 1Q-15 ~I6/16/1985 , 72.OiIPERF ~IS"Scallopf iQ-15 Run oate ID linl HD; 120 tleg. ph HD; 120 deg. ph I~/ELL, LCJfa TR~lNSlt~l/TTAL ,,. PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C -, .~, - ~, - - =.~,, Anchorage, AK 99518 ~=a~~~ ~~~~`~ ~~ a' ~dQ~ Fa~c (907) 245-8952 1 ] Caliper Report 2) 14May{l9 1 ~-15 50-029-21308-00 MAY 2 ~ X009 Signed Print Name: ~~ ~~b ~ ~taa~ka i `~ AnchAra~~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsarechoraQeCcUmemorvlo .corn WEBSITE : www.memorvlog.com 1 Report / E~ C:\Documents and Settings\Owner\Desktop\Transmit_Cwioco.docx • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: __ 1Q-15 Log Date: May 14, 2009 Field: Kuparuk Log No.: 10549 State: Alaska Run No.: 1 API No.: 50-029-21308-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD Top Log Intuit.: Surface Pipet Use: Tubing Bot. Log Intuit.: 8,481 Ft. (MD) Pipet Desc.: 7" 26 Ib. J-55 Top Log Intuit.: 8,481 Ft. (MD) Pipet Use: Production Casing Bot. Log Intuit.: 8,652 Ft. (MD) Inspection Type : pre CTD Corrosive & Mechanical Damage Inspection COMMENTS This log is tied into the 3.5" Tubing Tail @ 8,481' (Driller's Depth). This log was run to assess the condition of the tubing and production casing with respect to internal corrosive and mechanical damage for CTD planning. The caliper recordings indicate the 3.5" tubing is in good condition, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Although not presenting a significant I.D. restriction, the caliper recordings indicate light deposits throughout the 3.5" tubing. The caliper recordings indicate the 7" production casing logged is in good to poor condition with respect to internal corrosive and mechanical damage, with a maximum recorded wall penetration of 43% recorded in an area of line corrosion in joint 3 (8,526'). No significant areas of cross-sectional wall loss are recorded. Ovality restricts the I.D. to 5.85" in joint 5 (8,595'). A 3-D log plot of the caliper recordings of the 7" production casing logged is included in this report. Graphs itlustrating minimum recorded diameters on a joint-by joint basis of the 3.5" tubing and 7" production casing logged are included in this report. 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 19%) are recorded. 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%} are recorded. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 7" PRODUCTION CASING -MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion Line Corrosion ( 43%) Jt. 3 @ 8,526 Ft. (MD) ( 40%) Jt. 4 ~ 8,537 Ft. (MD} No other significant wall penetrations (> 14%) are recorded. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Strafford, TX '7497 Phone: (281} or (888) 565-9085 Ear.: (281j 565-1369 E-moil: FADS a~memorylog.com Prudhoe Bay Eield Office Phone: (907) 659-2307 Fa;c 0:307) 659-2314 U~~ 1~s5--c~~ 6 ~se~~ ~ • • 7" PRODUCTION CASING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded outside of the perforation interval. '' 7" PRODUCTION CASING -MAXIMUM RECORDED ID RESTRICTIONS Ovality Minimum t.D. = 5.85" Jt. 5 ~ 8,5951=t. (MD) No other s~ nificant 1.D. restrictions are recorded. ~9 Field Engineer G. Etherton Analyst: HY. Yang Witness: F. Ferguson ProActive Qiagnostic Services, Inc. / P.O. Box 1369, Stafford; TX 77497 Phone: (281) or (888) 565-9085 Fax: (281 j 565-1359 E-mail: PDS@memarylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ''. '. • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc Field : Kuparuk Well : 1Q-15 Date : May 14, 2009 Description : Detail of Caliper Recordings Across the 7" Production casing Logged Comments Depth Max. Pen. (%) Max I.D. (1/1000 in.) 3-0 Log Image Map 1ft:130R 0 100 5800 -~~ 6800 0° 0° 90° 180° 270° 0° Min I.D. (1/1000 in.) 5800 6800 Nominal I.D. (1/1000 in.) 5800 6800 3.5" Tubing 8480 I I ~ ~ -- ~ -? L Joint 1 i ~ - ~ - - - j 8490 ~ 1 i ~ ' ~ , i i I , , Marker Joint 8500 ~ , ,__ ,_ ~~ ~ - -_ 8510 ~ ~ , Marker Joint ' ~ I -.;. Line corrosion 8520 ' ~ a3% wa11 Penetration ' i _ .' ~ I i 8530 ~ I ~' ~ ~ i I ~ - - i. 8540 I I Joint 4 Line corrosion 40% Wall 550 ~ ~ ~ i i ,i, - Penetration Perforations ' ~ i ' . u ; _ r - i_ • Correlation of Recorded Damage to Borehole Profile ' Pipe 1 3.5 in (34.2' -8481.5') Well: 1 Q-15 Pipe 2 7. in (8481.5' - 8611.2') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 14, 2009 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 34 25 786 50 °~ 1553 75 2355 100 3128 125 3905 150 4689 ~ 175 5469 E _ ~ c Z 200 6254 c ~ n. °/ o O 225 7027 250 7807 1 8481 6 8611 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 6 • ~~ Minimum Diameter Profile Well: 1 Q-15 Survey Date: May 14, 2009 Field: Kuparuk Tool: UW MFC 24 Company: ConocoPhillips Alaska, Inc. Tool Size: Fxt.No.214040 Country: USA Tubing I.D.: 1.69 inches 2.992 inches 1.69 1 7 14 21 28 35 42 49 56 62 68 75 82 89 96 103 110 117 124 ~ 131 E 137 ° 144 Z C 151 .a ... 158 165 172 178 185 192 19B 205 212 218 225 231 238 244 251 258 260 265 268 269 2.89 i ~; s s II 3 Iii !~ 1= ~L= L I -~ a ]-s ~j ~~ _~ ~_{ II ~+ ~I' ~~ 1=_' ~_ I- I - _•_ J= Minimum Measured Diameters (In.) 1,89 2.09 2.29 2.49 2.69 PDS Report Overview ~ s. Body Region Analysis Well: 1 Q-15 Survey Date: May 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Eingers: 24 Anal st: HY, Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°,6 wall) ~ penetration body ~,,~ metal loss body 2 50 200 150 100 50 0 0 to 1 to 10 to 1% 10°/~ 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 276 pene. 0 234 42 loss 72 204 0 0 0 0 0 0 0 10 Damage Configuration (body ) Damage Profile (°~ wall) ~ penetration body .:,, metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 0~ ~ ~ I i isolated general line ring hole /you pitting corrosion corrosion conosion ible hole Number of joints dama>;ed (total = 6 6 0 0 0 0 GLM 4 GLM 5 GLM 6 GLM 7 rl AA Q ia~M a~ Bottom of Survey = 269.2 Analysis Overview page 2 • PDS REPORT JOINT TABC. Pipe: 3.5 in 9.3 ppf )-55 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 1 Q-15 Kuparuk ConocoPhillips Alaska, Inc USA May 14, 2009 Joint No. Jt. Depth (Ft.) I'c•n. Ul~se~i (Irn. i Pen. Body (Ins.) F'c•n. % ~tc•tal I os1 „~ Min. LD• (Ins.) Comments Damage Profile (%watl) 0 50 100 1 34 c ~ 0.0 7 2.94 1.1 66 U 0.02 7 I .96 PUP 68 ~ I 0.02 9 u 2.9 3 100 tl 0.01 6 2 2.93 4 131 U 0.01 4 -t 2.93 5 162 a 0. 2 ~~ ~:~ .93 6 193 U 0.02 ~> 2.93 7 2 5 t 1 0.0 '~ a 2.94 Lt. De o f ts. 256 U 0. 3 11 i 2.9 9 288 U 0.02 9 2.88 10 3 0 (~ 0. 1 4 3 95 11 51 t~ 0.03 1 1 1 .9 12 3 O 0.03 l U n 2.89 13 41 a 0.0 ~> .90 14 44 t~ 0.03 I , 3 Shallow ittin . 15 472 t ~ 0.02 ' ~ 4 16 501 a 0.02 ~ ~ .93 17 533 U 0.03 1 U I 2.90 1 565 (~ 0. 7 .93 19 596 t ~ 0.02 ~) 2.92 0 6 8 t ~ 0.01 t~ .92 2 659 U 0.01 4 i ~ 2.92 22 691 U 0.01 ~ 2.93 23 723 i1 0.01 5 2.89 4 755 (I 0.0 7 ' 9 25 786 U 0.01 4 2.92 26 818 0 0.01 4 I .93 2 7 850 ~~ 0.02 9 ~ 2.90 28 882 U .0 7 ~ .9 9 911 a 0.01 v d 2.92 30 941 a 0.02 ~~ ~' .91 31 973 a 0.03 1(~ -t 2.92 32 1004 a 0.02 '~ 2.92 33 1036 U 0.02 7 ~ 2.93 34 1065 U .01 (~ _' 2.93 35 1097 l1 0.02 ~? 2.94 36 11 6 U 0.02 ~ 2.9 37 1156 ~ ~ 0.01 -t 2.94 38 1187 t~ 0.0 '~ I 2.91 39 1216 t~ 0.01 t~ 2.94 124 U 0. 2 2.9 41 1277 U 0.01 ~ 2.93 4 1307 l) 0.0 7 I 2.94 43 1336 U 0.02 ~) I 2.92 44 1368 a 0. ~~ 2.92 45 1399 a 0.01 ~ 2.89 46 143 i ~ 0.01 4 .95 47 1462 t> 0.01 r, 2.95 1493 .01 -~ .90 49 1521 ~ ~ 0.02 '? 2.94 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd Well: 1 Q-15 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 14, 2009 Joint No. Jt. Depth (Ft.) I'cn. Ulx~~t (Im_) Pen. Body (Ins.) P~~n. °4, Me•t,il I cuss ",~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1553 ~) 0.02 ~) 1 2.93 51 1585 ~ t 0.02 7 I 2.93 52 1616 ~ t 0.01 (, 2.94 53 1648 ~) 0.01 ~ ~ 2.93 54 1680 ~ t 0. i .93 55 1712 a 0.02 ') I 2.95 56 1743 ~) 0.01 4 ~ .93 Lt. De osits. 57 1775 tt 0.02 ') ? 2.94 58 1806 ~) 0.01 (~ ~' .92 59 1838 a 0.03 1.? a 2.91 Lt. De osits. 60 1870 U 0.02 2.91 Lt. De osits. 60.1 1901 U 0 1t ~ ~ 2.81 aker'f-l/L' SSSV Locked out 6 0 89 61 1915 ~ t 0.01 -1 2.91 62 1947 ~ t 0.01 ~ I 2.93 63 1978 ~t 0.03 1 I 2.92 Lt. De osits. 64 2008 t t 0.02 ~) _' 2.93 65 2040 ~> 0.0 9 1 2.88 66 2072 ~) 0.03 1 1 ~ .9 Lt. De osits. 66.1 2100 ~t 0 It u N A LM 1 Latch ~ 7:00 67 107 ~t 0.02 ~) 2. 2 68 2139 ~ t 0.02 7 2.92 69 2168 i. t 0.01 4 I 2.93 70 2 00 a 0.01 4 2.93 71 2232 a 0.02 2.96 72 2262 ) 0.02 7 .9 73 2293 O 0.02 ~) 1 2.88 Lt. D osits. 74 2325 tt 0.02 ~ ~ 2.91 75 2355 U 0.02 <1 .' 2.93 76 2385 U 0.01 (~ 2.92 77 2416 ~ t 0.03 I u 2.95 78 2447 t t 0.01 ~ 1 2.92 79 2479 ~ t 0.02 7 l 2.88 80 2511 tt 0.01 4 ~' 2.92 81 2541 tt 0.03 1tl 2.95 82 2572 U 0.02 7 .91 83 2602 ~ t 0.02 ~ t I 2.93 84 2634 tt 0. 2 s3 I 2.91 85 2663 ~! 0.02 ~ I 2.92 86 2693 ~) 0.00 ' .95 87 2723 a 0.02 7 2.92 8 753 U 0.01 ~ ~ 2.95 89 2785 U 0.02 ~~ 1 2.90 90 2816 U 0.02 7 ' 2.94 91 2846 U 0.01 5 ? 2.93 92 2878 i) 0.03 I 1 ? 2.88 Lt. De osits. 93 2908 ~) 0.01 3 3 2.94 94 2939 rt 0.02 ~) )1 2.92 95 2971 ! t 0.01 -1 2.92 96 3002 i` 0.01 1 90 LL Dce osits. 97 3033 t i 0.02 ' ~ ~ 2.86 Lt. lie x~sits. ''t' __ Penetration Body Metal Loss Body Page Z • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 ¢15 Kuparuk ConocoPhillips Alaska, Inc USA May 14, 2009 Joint No. Jt. Depth (Ft.) I'~~n. U)x~~l (Inc.) Pen. Body (Ins.) I'e~n. °io V1c~l.~l I ~~~ .~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3065 I t 0.01 6 _' 2.93 99 3097 U 0.02 ~~ 2.91 100 3128 ~) 0.0 10 2.92 101 3160 i ~ 0.02 9 ? 7 t. De osi 102 3192 U 0.02 7 2.92 103 3223 a 0.03 l0 ~ 2.9 104 3255 t) 0.01 ~ ? 2.93 105 3 85 O 0.03 1O _' 2.92 106 3 17 t) 0.01 (, _' 2. 9 1 7 3348 t) 0.02 9 2.92 108 3378 U 0.02 7 5 2.93 1 9 3409 U 0.01 6 2. 11 344 U 0.01 (~ _' 2.91 111 3471 ~) 0.02 .92 11 350 t) 0.01 (, ~~ 2.89 t. De osits. 113 3534 a 0.01 v 2.93 114 3565 tJ 0.03 12 I 2.92 Lt De osits. 115 3597 t~ 0.02 ~ ~ .91 116 62 7 c l 0.03 1 1 U 2.84 Lt. a osi ts. 117 3659 ~ I 0.0 9 2 .92 118 3689 ~ ~ 0.01 -1 I 2.92 119 3720 i I 0.01 (~ 2. 9 1 0 3751 ~) 0.03 11 ~ 2.9 121 3782 ~? 0.02 ~) I 2.89 Lt. De osits. 3 13 a 0. 123 3842 O 0.03 11 _' 2.90 1 4 3873 l) 0.03 12 2.91 125 3905 O 0.01 6 I 2.90 Lt. De sits. 126 3937 ~~ 0.02 9 2.87 127 3968 ~ ~ 0.03 i U I 2.89 Lt. De osits. 1 8 3998 ~) 0.02 7 2.90 LL De osits. 129 4028 U 0.03 12 t~ 2.91 Lt. De osits. 1 0 4060 U 0. 11 ? .88 Lk e osits. 131 4091 U 0.03 12 ~ 2.91 Shallow 'ttin . 1 2 4123 l) 0.03 10 _' 2 89 132.1 4155 U 0 U U N A GLM 2 Latch ®2:30 133 4161 0 0.03 I 1 ~) 2.87 Lt De osi . 134 4193 ~) 0.03 12 _' 2.86 Lt. De osits. 135 42 3 ~ ~ 0.02 ~) ~, ~ .8 136 4252 i ~ 0.02 ~l 2.90 137 4284 ~ ~ 0.03 1 1 r .92 138 4315 a 0.03 lt1 2.90 Lt. De sits. 139 4345 I ~ 0.01 4 ! 2.89 140 4374 ~I 0.03 11 2.89 Lt. De osits. 141 6 U 0.03 12 ~ 2.92 142 443 7 U 0.02 9 ~' 2.92 143 4469 t) 0.03 ltl 2.92 144 4501 ~) 0.01 4 -1 2.89 145 4532 ~ ~ 0.02 - I 2. 2 146 4563 i i 0.02 `~~ ~' 2.89 Lt De posits. _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd Well: Body Wall: 0.254 in Eield: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 1 Q-15 Kuparuk ConocoPhillips Alaska, Inc. USA May 14, 2009 Joint No. Jt. Depth (Ft.) I'c•n. 111 ~se~ I (I~...1 Pen. Body (Ins.) Pc~n. °i~ ~9c~i.il I uss °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 147 4594 It 0.0 ~) 2.92 148 4625 ~~ 0.02 ~~ 2.92 Lt. De osits. 149 4657 a 0.02 ~) _' .90 Lt. D osi 150 4689 ~ ~ 0.02 ~) ~ ~ .92 151 4721 i I 0.0 ~) 2.94 152 4752 ~ I 0.02 ~) 2.92 153 4784 a 0.03 11 -! 2.87 154 4816 l1 0.03 1 1 2.93 155 4847 t l 0.02 ~ I ~' 2.90 156 4879 II 0.03 I1 _' 2.9 157 491 1 I) 0.02 ti ~ I 2.89 t. De sits. 158 4940 ~) 0.02 2.91 159 4970 II 0.02 `~ 2.90 160 5002 II 0.03 ll) .92 161 5034 ~ ~ 0.02 ~~ _' 2.93 162 5066 U 0.03 I I i i 2.90 163 5096 a 0.02 ~~ 2.90 164 5128 a 0.03 I~ I .90 165 5159 U 0. 3 11 (I 2.91 166 5188 I I 0.03 I O ~ 2.9 1 7 5217 tl 0.0 <I ~ .89 Lt. De osits. 168 5249 t) 0.02 ~) ~' 2.89 169 5280 i ~ 0.03 I 1 ~' 2.92 170 5310 II 0.02 `~ 2.90 171 41 U v .91 172 5373 i I 0.02 ~) ~ 1 2.87 173 5405 tl 0.02 ~) ~ .92 174 5435 ~I 0.02 ~I ~ 2.92 174.1 5463 ~~ 0 I I t l N A G M 3 Latc ~ 4:3 175 5469 ~ ~ 0.03 1 1 `; 2.92 176 5499 t) 0.01 ~ i I .90 177 5529 11 0.03 1(1 2.89 178 559 (~ 0.03 1 1 2.90 Lt. De osits. 179 5591 U 0.02 7 ~ i 2.92 180 5622 O 0.01 ~ .91 181 5654 t) 0.02 ~~ ~ 2.91 182 5686 U 0.03 11 II 2.90 183 5718 (t 0.02 ~ 2.93 184 5749 ~ I 0.02 9 .90 185 5781 a 0.02 ~) ~ 2.92 186 5812 ~ ~ 0.02 7 I 2.90 187 5843 t I 0.01 4 _' 2.92 188 5875 a 0.02 ~ 2.89 189 5907 U 0.02 `~ 2.90 190 5938 U .02 ~) .! 2.92 Lt. De osits. 191 5967 II 0.02 7 ~ 2.91 19 5999 a 0.0 rt 1 2.87 193 6030 II 0.01 4 2 2.89 Lt. De osits. 194 6060 i? 0.01 ~~ ~' 2.91 195 6091 ~ 0.02 _' 2.89 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • ~ LATI O N SHEET 1¢15 Kuparuk ConocoPhillips Alaska, Inc. USA May 14, 2009 Joint No. Jt. Depth (Ft.) I'~•n. i ll,:~~t Um.) Pen. Body (Ins.) I'~•n. °i~> ~t~•)•~I I ~~s `i.. Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 96 61 1 ~) 0.02 i U 2.91 197 6153 tt 0.02 7 ~ 2.90 198 6184 n 0.03 1 t t r, 2.92 198.1 6216 ~! 0 tt ~.' N A GLM 4 Latch ~ 6:00 199 6222 ~) 0.03 I 1 t 2.92 200 6254 t t 0.02 i 2.90 Lt De osits. 201 6281 ~ t 0.02 ~) c ~ 2.89 202 6313 tt 0.02 7 I 2.91 t De osits. 203 6343 ~ t 0.02 9 _' 2.92 204 6374 tt 0.01 2 ,' .91 205 6406 t t 0.02 8 a 2.92 Ton Mash. 206 6438 i) 0.02 ~) ~ 2.91 207 6467 tt 0. 1 5 2.92 208 6499 ~ ~ 0.02 ~ ~ ~ ~ 2.89 209 6527 a 0.02 ~~ 2.88 210 6559 tt 0.02 ~) ~~ 2.87 Lt. a osits. 211 6590 a 0.02 ~) t ~ 2.87 212 6621 t) 0.02 9 tt 2. 5 L . e osits. 12.1 6650 l) 0 t) tt N A GLM 5 Latch 3:00 213 6657 t) 0.02 9 2.88 214 6687 U 0.02 i ~) 2.89 215 717 n 0.02 7 ~ t 2.88 216 6748 t t 0.03 11 2.88 Lt. De osi ts. 217 6780 a 0.00 2 U 2.87 6810 ~) 0 11 s 2.9 219 6843 t t 0.02 ~) ~ 2.87 220 6874 c) 0.02 7 ~) .86 221 6903 t) 0.02 ~) ~ 2.86 222 6934 t) 0.03 1 U 2.87 223 6965 ~) 0.01 t~ i t 2.86 224 6997 U 0.02 ~ 2.85 225 7027 a 0.02 ~ -a 2.86 226 7058 t1 0.02 7 ~ 2.88 226.1 7087 t) 0 O ~t N A GLM 6 Latch @ 3:00 2 7 7095 t1 0.02 9 (~ 2.84 Lt. De osits. 228 7126 U 0.02 ~) -J 2.85 229 7157 tt 0.02 7 u 2.88 230 7187 U 0.03 12 I 2.89 Lt. De osits. 231 7219 i t 0.02 7 2.90 232 7250 a 0.02 ~~ _' 2.89 233 7282 tt 0.02 ~ I 2.89 234 7313 a 0.02 ~) a 2.88 3 7343 U 0.02 ~) -1 2.88 236 7373 t~ 0.02 2.89 37 7402 tt 0.01 (~ s 2.89 238 7432 ~t 0.02 2.89 2 9 7464 ~ i 0.02 ~) 2.88 240 7492 a 0.02 ~) ~ ~ 2.86 240.1 75 0 U 0 U ~~ N A GLM 7 Latc ~ 6:00 241 7529 U 0.02 c, 2.85 Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEEP 1 Q-15 Kuparuk ConocoPhillips Alaska, Inc. USA May 14, 2009 Joint No. Jt. Depth (Ft.) I'rn. lJl~s~~i (In..) Pen. Body (Ins.) Nc~n. `%, !v1~~i,~l IoSS ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 242 7560 t~ 0.02 - t! 2.86 243 7589 U 0.01 6 s .91 244 7620 t~ 0.04 1(i 2.90 Shallo ~ttin . 245 7651 t i 0.03 1 tl d 2.88 246 7683 t ~ 0.03 1 Z 1 .89 Lt. De osits. 247 7715 t ~ 0.02 U 2.88 48 7744 ~ t 0.02 9 2.93 249 7776 i ~ 0.02 s 2.92 250 7807 ' ! 0.02 ~> 2.91 251 7839 tt 0.03 12 -1 2.88 252 7869 t 1 0.02 9 t ~ 2.90 2 3 7900 U 0.03 1(~ U .88 254 79 3 n 0.02 7 s 2.88 255 7964 (1 0.02 i I 2.90 256 7993 a 0.03 10 ! ~ 2.89 257 802 U 0.02 9 -l 2.89 258 805 (1 0.00 Z > 2.89 Lt. De osits. 259 8084 tl 0.02 t3 ~~ 2.89 259.1 8115 t~ 0 U t~ N A GLM 8 Latch @ 9:00 260 8126 (1 0.01 5 1 2.89 260.1 8156 11 0.05 1 ~) -1 2.92 PUP Shallow ittin . 260.2 8168 l) 0 l) t~ N A Baker PBR 260.3 8170 l~ 0 t) U 3.00 Baker'FHL' Packer 260.4 8179 U 0.01 ~ ~' 2.88 PUP 261 8188 t~ 0.01 5 t! .88 262 8217 t ~ 0.02 I 2.90 262.1 8 50 t l 0 U t i N A I M 9 Latch ~ :00 263 8259 t~ 0.03 1> 2.87 Shallow ittin . 264 89 (1 0.03 11 t~ 2.89 264.1 8320 (t 0 0 tl N A I M 10 Latch ~ 9:00 265 8332 (~ 0.01 U t) 2.87 t De o i 266 8360 a 0.02 9 s 2.94 Blast oint. 267 8379 U 0.02 9 i 2.92 Blast oint. 268 8400 t~ 0.01 4 ~ 2.93 Blast oint. 268.1 8420 t~ 0.03 12 ~ 2.87 PUP Lt. De sits. 268.2 8426 t t 0 U t~ N A I M 11 Latch ~ 1:00 268.3 8440 t ~ 0.03 I ~' s 2.83 PUP Lt. De sits. 268.4 8449 u 0 t) a N A Baker Locator Sub 268.5 8451 U 0.01 ~ 2.85 PUP Lt. De sits. 268.6 8456 O 0 U tt 4.00 Baker'FB-1' Packer 268.7 8460 U 0.02 7 2.88 PUP 268.8 8469 U 0 (~ ti 2.75 Camco'D' Ni le No Go 268.9 8471 tt 0.02 2.91 PUP 269.1 8479 ~~ ~ 0 ~ ~ 2.99 Carnco SC~S 269.2 84x1 ~ ~~ 0 2.99 ~ruhj~; l-all ___.-- _ Penetration Body Metal Loss Body Page 6 • • i~~ Minimum Diameter Profile Well: 1Q-15 Survey Date: May 14, 2009 Field: Kuparuk Tool: UW MFC 24 Company: ConocoPhillips Alaska, Inc. Tool Size: Ext.No.214040 Country: USA tubing I.D.: 1.69 inches 6.276 inches 1 2 3 E 0 z •a 4 5 6 Minimum Measured Diameters (In.) 1.69 2.19 2.69 3.7 9 3.69 4.19 4.69 5.19 5.69 6.19 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ~ LATI O N SHEET 1 Q-15 Kuparuk ConocoPhillips Alaska, Inc USA May 14, 2009 Joint No. Jt. Depth (FL) I'c~n. lll,~c~t Ili~~.) Pen. Body (Ins.) N~~n. °~ ~1~~lal Kris ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 8481 i~ 0.05 14 _' 6. 4 Line corrosion. 2 8488 t~ 0.04 1l) -1 6.26 Marker oint. Lin corrosion. 3 8508 U 0.15 ~ ~ t, 6. 7 Marker oint. Line corrosion. 4 8528 U.Uti 0.23 b"'. I_' 6.12 Line corrosion. Perforations. 5 8568 U. I ~ 0.51 1 t )U I'_~ 5.85 ali .Perforations. 6 8611 t~ 0.30 ~i-l ~ 6.03 Perforations. _ Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections Well: 1Q-15 Survey Date: May 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 ins 26 ppf J-55 Analyst: HY. Yang Cross Section for Joint 3 at depth 8525.9 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 94 Tool deviation = 52 ° Finger 5 Penetration = 0.154 ins Line Corrosion 0.15 ins. = 43% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 r ~ i ~ ~s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ PDS Report Cross Sections Well: 1Q-15 Survey Date: May 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 lubing:____ _ 7 ins 26 ppf J-55 Analyst: HY. Yang Cross Section for Joint 4 at depth 8536.84 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 94 Tool deviation = 54 ° Finger 5 Penetration = 0.144 ins Line Corrosion 0.14 ins. = 40% Walt Penetration HIGH SIDE = UP • Cross Sections page 3 ~~ `~ PDS Report Cross Sections Well; 1Q-15 Survey Date: May 14, 2009 Field; Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 7 ins 26 f -55 Anal st: HY. Yan Cross Section for Joint 5 at depth 8595.09 ft Tool speed = 43 Nominal 1D = 6.276 Nominal OD = 7.000 Remaining wall area = 83 Tool deviation = 53 ° Finger 7 Projection = -0.344 ins Ovaliry Minimum ID = 5.85 ins. HIGH SIDE = UP • Cross Sections page 3 KUF' ConocoPhillips w~a ~c li,3sa,1, In, wepDgeA .. ~ 50029. sssv. 1 ete GAS LIFT, 2.107 GAS L1FT, 4.181 ^uURFACE, a ago GAS LIFT. 5168 GAS LIFT. 8,221 GAS LIFT, 6 655 GAS L IFT 7.093 GAS LIFT, 7.527 GAS LIFT, 8.124 PBR, 8,188 PACIfFR.8.176 PACKEA,8,152 NIPPLE. 8,469 SOS,8480 TTL, 6,481 FISH, 8,538 IPERF, 8,552,628 IPERF, B,BS/A,B80 PRODUC110N, 8,860 TD. 6.668 9 (.j-7 b • ~, ..~.NG i TUBING I LINER DE'"` ~ .. _ ~ .~ is DRIL SITE L _ ARCO A#aska Inc. DATE _ ~,,,L ~~ ~~ r P / Subsidiary of ANanlicRkhRrldCompanY a9a of _ ~~ pages • . #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTM ~_ ~ - ~ i' N r.. ~.© ~ ~a ¢ h h M ~M q N N - ~~ l0 9 SAFE ,~ 8~3 '- 2 ~ ~t'' ~~ G '' J3 -- / /6 ~~ An?.~' ~ / 5 oP df ~ fin"' v ~ ~r i''' 6~° 67 ?~ ~ ~~ 55~ ~° rr! T,8G ~ ~ '~ /' !~ ~ ~' mr-a ~ cq 55 b~ s~ ~~ sL~ w v 6~ ~~~© 'lf . 7 s~ <`~ ~` `" ~- Y -&~Z G~ ~ ~ 5 BOSS `~? s.~is~ 0 3 ¢_ o8c~ ~ ,~ ~ w ~. _ ~ ~r X093 ~s ti;....,,_ ;; l ~ ~ ~ ti r< -~'K2 cA 6 ~ 3° ` 8& ~~ ~ ~ Dx y w d8 3..~' S? -- r ~ ~ ~ - ~ ~ G~ c~ J '~.. 3 .P .SrY 3~3 ~ p ,C'' ~- SSA, 03 ~ Z2 S G ~ a ~= !~ b '~~ 2J3'S ,may -' G. i4 3b aR ~ ~,- ~. ~~ ~ S8 '~,~ ~ STS ci/ 3F 3 3a G~~ ~ ,. D ,, w y ., ,37 g~.~ 67 BOTTOM OF TUBING TAIL Remarks - ~~ -_. . ;;_ ~' i~F '"' ARCO PM 11 t3 `~ 4tfAi,17'Y Lil'HQ PRtNTtNG - ANCHQRAOE R. Supervisor ~~.:; - ~~~~~ ' - ' ~ , __VG /TUBING /LINER DE' ~~ DRI LL SITE ~ ~ / 5! . ARCO AI DATE ~ i~ ~s~ aska, Inc. ~ pags2 of ,~ pages ' Subsidiary of Atlant~AichtialdCoitipsny #ITEMS COMPLETE DISCRIPTtON OF EQUIPMENTRUN LENGTH D PT1-I .iT 5.~1~,c' T,6G 2ri ~ 3a~~"~. r/~ ,S~~.E O i ~ v ~ ?73G o ~~ ~' •~ - ~ 32 4 2 4 ip ,~atp i 3Z ~ o -- 5F _ 57 ~.. ._.---== / is- 846?-~- ~i~lt '' ~cJ _ '¢s 84 9 / 5! 847 d Sd S - 6 s' 84? id t is 60 -- 90 - ~ N '~ ° /3¢ . ~ "' Z53 •tf ~~ ~sS ~ .. /26Z w~ ' ' 80TTOM OF TUBING TAIL G a~ r S ~~ i~. . itJ %3~ ' ~,~iNG~^S ~^T~~'G ri_,,rrr~e~~, ~.~f C~~3r1-~S ~.~. ARCO f'M 118 '~ QUALITY LfTHO PRINTINQ - ANCHORAQE Fj, uparvisor • ~-.-,, ALASSA OIL AID S CO1~T5ERQA'TIO1~T COMl~IIS51O1~T Gary Eller Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 U SARAH PAt/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~Y ~ \`~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 Q-15 Sundry Number: 309 147 ry~ qt }{y!{y~ Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in .the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, f7 'y ~~ .,r"'r~! Daniel T. Seamount, Jr. Chair DATED this~day of April, 2009 Encl. • STATE OF ALASKA • ~, ~_ ~, ~ s~ A, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~~~~ iii ~ Gas Cor~s• Cammission 20 AAC 25.280 Al;l;hlrag~t, 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^~ ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 185-046 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21308-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ~ 10-15 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25634 RKB 93' Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8866' 6559' 8770' 6497 8538' Casing Length Size MD TVD Burst Collapse CONDUCTOR 102' 16" 102' 102' SURFACE 4327' 9-5/8" 4420' 3524' PRODUCTION 8767' 7" 8860' 6556' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8260'-8285', 8394'-8404', 8552'-8626', 8654'-8660' 6160'-6178', 6252'-6258', 6357'-6406', 6424'-6427' 3-1/2" J-55 8481' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'FHL' pkr, Baker'FB-1' pkr @ 8176', 8452' Baker'FVL' SSSV= 1916' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat April 30, 2009 Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby rtify t the foregoing is a and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Printed Name . Ga Elle Title: Wells Engineer Signature Phone 263-4172 Date Commission Use Onl Sundry Number: Conditions of approval: otify Commission so that a representative may witness r / Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ,7~ ~ ~>'~~~ Other: ?>._~`~ pS~ ~~ r\~h®3~L,\ ~~ ~~ Subsequent Form Required: ~~ APPROVED BY (~'` ~~ Approved by COMMISSIONER THE COMMISSION L Date: Form 10-403 evised 06/200 ~y, S bmit ~ Duplicate • • onoct~P'~ ~ ~ I ~ ps Alaska, Inc. 1Q-15 Pre-CTD Sidetrack Prep Wells network: 10250074 The anticipated spud date for Nabors CDR-2AC to drill dual CTD A-sand horizontal laterals from ~ we11.1Q-15 is June 2009. Objectives: Prep well for a CTD sidetrack out the 7" casing ~' o Slickline: Drift, tag fill, and caliper the 7" casing & 3 %2" tubing. Get updated SBHP survey. Confirm tubing integrity. o E-line: Shoot holes in tubing tail to be able to put cement across the tail o Coil: Mill out the 2.75" D-nipple to 2.80" with alert-hand motor o Coil: Lay in cement plug from existing top of fill to the 3'/s" tubing tail o Coil: Clean out cement & cement sheath to the tubing tail Procedure: Prep Wellbore for Squeeze 1. MIRU Slickline. Tag fill. Need top of fill at 8600' or deeper prior to cementing or running caliper. If fill is tagged high, contact CTD Engineer before continuing. 2. RIH with PDS memory caliper dressed for 7" casing. Caliper 7" casing from 8600' into the 3- 1/2" tubing tail at 8480' MD. Continue to caliper the 3%2" completion all the way to surface. POOH. 3. Get updated static BHP survey down to 8552' KB, plus a gradient stop at 8402' KB. 4. Set plug in D-nipple at 8467' MD. MIT tubing to 2500 psi to confirm integrity prior to pumping cement. All GLMs and production mandrels should be dummied off. Pull plug, RDMO Slickline. 5. MIRU e-line unit. RIH with 1' of jet perfs for the 3'/2", 9.3 ppf tailpipe. Suggest using a 2" HSD gun loaded 6 spf, 60° phase with HyperJet charges with 0.33" entrance hole and 9.6' API penetration. Correlate with CCL to tubing and completion jewelry. Shoot holes at X8473' MD. Punches should be placed near the middle of the 10.15' pup joint immediately below the 2.75" D-nipple at 8467' RKB. See the attached tubing detail for jewelry tie-in -the original tubing detail of 6/16/85 is completely screwed up. (Note: Shots will likely penetrate the 7" casing in addition to the 3'/2" tubing. Shots are opposite the B-shale.) POOH, RDMO e-line. 6. MIRU 13/4" CT unit. PU Baker 2'/8" left-hand motor and 2.80" left-hand D331 mill. The left- hand motor will eliminate the potential for backing off the tubing tail. Mill out the 2.75" March 16, 2009 Page 1 of 3 1 Q-15 Pre-CTD Sidetrack • D-nipple at 8467' to 2.80" ID. Circulate hole clean with seawater. (Note: Any viscosifier used for sweeps will contaminate the cement. Fully circulate the well clean prior to placing cement.) Cement Squeeze/Plugback Note: Ensure that the 10-403 has been approved for plugging 1 Q-15 prior to performing the following steps. 7. MU BHA. Use standard balldrop nozzle w/jet swirl profile and 5' stinger to CT. Pump a dart through the coil tubing to calibrate coil reel volume. 8. RIH to top of fill (8680' as of 7/23/08). Fill the hole with heated seawater or KCl water (120° to 140° F, circulating 1 %2 to 2 wellbores volumes) while waiting on cement to mix. Hole volume at 8680' MD is ~82 bbl. 9. RU cementers. Batch mix a pumpable 25 bbl of 17.0 ppg cement (i.e. 7.9 bbl capacity in the 7" casing from 8473' - 8680' MD, plus 17.1 bbl excess). Cement specs: 17.0 ppg density, .thickening time of 3-4 hours, gas-block agents, and fluid loss of 75-90 ml/30mins. Assume BHT (circulating) = 140° F and BHT (static) = 152° F. • Ultimate target TOC 8473' at the perfs in the 31/2" tubing tail. If the top of fill is at 8680' MD as per the last tag, the 25 bbl of cement can conceivably go as high as 6507' MD in the 31/2" tubing if none gets squeezed behind the perfs. Historically though, in most A-sand wells we have put 5 to 10 bbl of cement behind pipe. • Bring pod up to weight and shear thoroughly. QC test cement. Send sample to lab for UCA testing. • Cement is cheap compared to the cost of a bad cement job. In 2007 it cost ~$350k to under-ream and re-cement well 1 C-03 from the Nordic #2 rig when that pre-rig cement plug got contaminated. Pump plenty of cement to get the job done, and make sure that the well never gets underbalanced to contaminate the cement. • Expected A-sand reservoir pressure = 3644 psi = 11.0 ppg EMW (July 2008). Measured reservoir temperature 152° F (7/23/08). Adjust procedure and cement properties as needed from the updated SBHP survey obtained just prior to the cement squeeze. Maintain minimum 1500 psi pressure on cement after it is put in place to prevent underbalance and contamination. • Expected fracture pressure = 4770 psi (assume 0.75 psi/ft = 14.4 ppg EMW). Equates to .1970 psi at the surface with fresh water in the hole. Do not exceed fracture pressure at any time during squeeze. • Monitor annulus pressures while pumping and bleed off as necessary. Max IA & OA pressure should be 2000 psi & 1000 psi respectively. 10. Pump the following down the coil: a) water spacer for PT (do not use friction reducer, J313 will clabber cement) b) 25 bbl neat 17.0 ppg cement c) 5-10 bbl of spacer water d) 1.5# Biozan gel for cement clean out 11. Position nozzle as deep as possible as cement reaches nozzle. Take returns and allow cement top in casing to rise 50' above nozzle before beginning pulling up hole. Verify getting 1:1 March 16, 2009 Page 2 of 3 1 Q-15 Pre-CTD Sidetrack ~p returns in 40 bbl open top tank before moving nozzle. POOH laying in cement 1:1, applying backpressure as needed to maintain max of 1:1 returns (no excess returns). 12. When the CT nozzle reaches the tubing tail at 8480' MD, close the choke and begin applying squeeze pressure while slowly moving the pipe. Stage up hesitation squeeze pressure to a target squeeze pressure of 1800 psi in 500 psi increments, holding each increment 10-15 minutes. • If we're unable to achieve at least 1500 psi squeeze pressure will have to pump another batch of cement, so pump away remaining cement into perfs. 13. If squeeze was successful, POOH laying in remaining cement while continuing to hold squeeze pressure at the choke. Pull up 100' out of the top of cement. Maintain target pressure of 1800 psi and hold for 30 minutes while circulating at minimum rate. 14. Hold minimum 1500 psi surface pressure to overbalance the formation throughout all remaining operations. Circulate 1.5# Biozan and launch ball. Chase ball to nozzle then RIH at 1:1 jetting at max rate to the tubing tail perfs at 8473' (target TOC). 15. Swap to 0.5# Biozan water. Jet uphole at 80% running speed and max rate, continuing to hold minimum 1500 psi overbalance on the cement. Wash all GLMs and C-sand production mandrels, particularly those that contacted uncontaminated cement. Freeze protect top 2000' of well bore. Thoroughly wash the tree and BOP stack. 16. Trap minimum 1500 psi at surface to maintain overbalance on partially set cement after coil leaves. RDMO coil tubing. 17. Allow cement to fully cure (72 hours or more recommended). MIRU slickline. Drift tubing, tag top of cement. RDMO slickline. March 16, 2009 Page 3 of 3 ConocoPhillips ... AL:>i;et, Inc. ._ __WNI Canfl9., 1. 13.8/.. , -. ..-_.--- StllerPa/k ACA CONDIK:TOR, 102 SSSV, 1,916 - - GAS LIFT, _ x,107 GAS LIFT, _ 6.161 SURFACE. a.exo GAS LIFT, 5,666 GAS LIFT. 6.655 GAS LIF i, 7093 GAS LIFT, __ ].52] GAS LIFT. _ _ _ 8.126 PBR, 8.169 - PACKER, 8;178 - INJECTION, _ _ _ _ _ 8,266 IPERF, 8.2fi0-6,285 INJECTKN. 6,329 IPERF. 8,3%-8.0% INJECTION, __ 8,636 PACKER. 8.652 NIPPLE. 8,689 -- SOS, 8,660 --- TTL, 8,681 - FISH, 8.538 - -- IPERF, 8,5528.626 IPERF. - 8,650-8.660 PRODUCTION, 8.Bfi0 TD. 6.866 KUP We11 Attributes Wellbore API/UWI Field Name Well slams A / 500292130800 KUPARUK RIVER UNIT PROD Comment ' H25 (ppm) 'Date A notation (End Date - I .LOCKED OUT ... I 86 1/1/2008Last w0: Annotation 'Depth (flK6) ' ErM Date Annotalion last TaD: I 8.683.0 '~ 7/23/2008 ,Rev Reason: PULL PLUG. TAG RATHOLE 2, 107.OGAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STATION#1 4,161.0 GAS LIFT ~ ~ CAMCOlKBUG/1IDMY/BK/I/ Comment: STATION #2 5,468.0 GAS LIFT CAMCO/KBUG/1/DMYlBK/// Comment STATION #3 6,221.OGAS LIFT ~ CAMCO/KBUG/i/DMYlBK//I Comment STATION #4 6,655.OGAS LIFT CAMCO/KBUG/1lDMYlBK/l! Comment: STATION #5 7,093.O~GAS LIFT CAMCO/KBUG/i/DMY/BK/// Comment: STATION #6 7,527.OGAS LIFT I I GAMGG/KBUGl1/DMY/BK/l/ Comment STATION #7 8,124 OiGAS LIFT I MERLA/TPDX/1.5/DMY/RM/!/ Comment: STATION # 8,169.0!PBR ( Baker 8,176.OPACKER ~ Baker'FHL' #10, OPEN 8,469.Oi NIPPLE Camco'D' Nipple NO GO 84800~,SOS ~CamcD R 4A t0 TTL 8,538 0 FISH 2.7' Swedge Lost In Rathole ~rforations - - snw Top (TVD) 'i Btrn (ND) II Dens P (flH6) '~. Btrn (flK6) ~ lHKel ~ (kKB) Typa Zone (shot... 3,260.0 8,285.0 6,160.1 6,177.51PERF C-0,C-3,14-15 12.0 3,394.0 8,404.0 6,252.0 6,258.1 IPERF (UNIT B, 10-15 12.0 3,552.0 8,626.0 6,357.1 6,405.7 IPERF ~A-0, A-3. 10-15 i 4.0 3,654.0 8,660.0 6,423.6 6,427.4IIPERF A-2, 10-15 4.0 1 Q-15 Inclination (°) Total Depth (k K8) '0.15 8,866.0 GN (ft) .Rig Release Date 44.50 5/14/1985_ iEntl Date slarzoos wl -, _ - ~ os#tl Grad I Top Thread e 62.50 H-00 36.00 J-55 26.OOJ-55 1!14/2007 JJ II; 120 deg- ph ~' x ! • Review of Sundry Application 309-147 ConocoPhillips Alaska, Inc. Well 1Q-15 AOGCC Permit 185-046 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to plug the perforations on this oil producer to prepare the well for a coiled tubing sidetrack. Recommendation: I recommend approval of Sundry Application 309-147 to allow CPAI to perform this operation. Discussion: CPAI proposes to plug the perforations in the subject well to prepare the well for a coiled tubing sidetrack to target the A sands in the Kuparuk River Oil Pool. The well was originally drilled and completed in 1985 and began sustained production in July of that year. Production continued until July 1996 at which time the well was converted to WAG service. Oil production peaked ay over 750 bopd in February 1987, but was typically in the 300 to 400 bopd range during the early life of the well. When the well was converted to WAG service cumulative production was just under 1.3 combo and the rate had dropped to approximately 200 bopd. The well injected water from July 1996 until January 2000 at which time the well was shut in. Peak water injection was a little more than 1,450 bwpd in September 1997, but this occurred over just a single day of injection that month and otherwise peaked at nearly 1,100 BWPD in August 1996 when it had a full month's worth of injection. From August 1998 on the well's average injection rate was much less than 100 bwpd. Cumulative water injection was a little less than 250 mbw. In January 2004 the well was converted back into an oil producer. CPAI stated in their justification that "[t]arget injection rates for Well 1Q-15 have not been realized. It has been determined that the bottom hole location of Well 1Q-15 is in an isolated fault block and is competing with Injection Well 3C-14 (offtake at Production Well 1Q-20A). Converting this well to an Oil Producer will create a more efficient Injector to Producer pattern in this fault block." After being converted back to a producer the well was never able to obtain a significant oil production rate. From January 2004 to June 2005, at which time the well was again shut in production never exceeded 37 bopd and totaled about 4 MBO. Not surprisingly, water production was much higher than oil production during this period and totaled over 100 mbw. In a year and a half of attempted production the well produced less than half of the .water that was injected into the well. At these rates it is reasonable to assume the well would need to produce for at least a year ~~ _ R or two more, at a 90 plus percent water cut, before it would be likely to see the possibility of any increased oil production. Conclusion: At the current production rates the well has no value to CPAI and will not be produced. The best opportunity for returning this well to meaningful production is to abandon the current wellbore and sidetrack the well to a more favorable location. This should result in increased resource recovery from this portion of the Kuparuk River Oil Pool. Therefore, I recommend at CPAI's proposed activities for the subject well be approved. °, D.S. Roby ` . Sr. Reservoir E weer Apri127, 2009 R E C E IVE r:\ ALASKA OIL AND ~-r:;~g~S~~~~ON COMMISSION FEB 172004 REPORT OF SUNDRY WELL OPERATIONS ~~.{{){J('~~ 1. Operations .~~rfS~: C ~ba~:~i..~Gù ' .:^t.è:;¡k~ iJH ..~: lj~S °11~""'~. '."~':' '~'''' ' :: , '-..'. " .',": ',' ;: A~CbÐ:ði~:.().~iri~. .:'..0 ' . :C:h;~~g"e-'Ai?proyed Program' .0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 93' Suspend .0 'R~p~ir~elr 0 : .p.~il Tubing D. . . .perto~~t~ g . Vari~nce '.P Annular Di~?:. 0 ':, :.,~iimu'~te .0 :'. . .::.Ti~?:~È~~:~$i9n: ,'0.' ,o~her'. 0 : . H~~eo.t~~:.sus'pe~d~d We,ll, .D." '. "" . .' ..' 5. Permit to Drill Number: , ~I~'rato¡y' 0 . 185-046 I . . Se~ice D. 6. API Number: 50-029-21308-00 Operaü~n.~~utd~wn, :"p.: . '~f'.~9..p~~qr~~(?~~...:..I:'J :':~. Perfo~te. New:p~~:;:: .:.JJ. '., . ': '4.'CuriêlitWell" Sti3,tus::.: : . .. . b~~16Pnie~t.: :<El : . .St~t,igra'ph¡c ': 0 9. Well Name and Number: 10-15 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOH SUR CASING PROD. CASING Perforation depth: measured 8866' feet true vertical 6559' feet measured 8770 feet true vertical 6498 feet Length Size MD 102' 16" 102' 4327' 9-5/8" 4420' 8767' 7" 8860' Plugs (measured) Junk (measured) TVD Burst Collapse 102' 3459' 6496' Measured depth: 8260-8660 true vertical depth: 6160 - 6427 Tubing (size, grade, and measured depth) 3-1/2" ,J-55, 8481' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FB-1'; BAKER 'FHL' pkr= 8452'; 8176' SSSV= SSSV SSSV= 1916' . .1.2. Stfmulatión or cenïèr:1t squeeze summary: . " . Interval$ treated (measured) . Treatment ~escriptil?ns including volumes used and finai pressure: . .' . . .,.' . 13. .. ~epresèntative -D~ily Averagè:f'ro.d~ction or, InJection Data. .: ." '. Oil-Bbl: .. . 'Gas-Met . ' .. ." WaJer-Bbl' . . . Pric;>r to. well.operation . '. SuÞs.eqÙent to operation ..' 14~ A~aChmØnts '. . .. . . Copies of.Logs and Surveys run-"- . ' .. . . : 6 ".'. . .' '1 Q2()' . 15. W~II Class after prqpdsed :wofk: .. . . ExpI6'r~t~.ry '.D ..' 'Development. 0 Se~i~e D . .. . .. . '.Daily Report.of Well Operations ~X . 16. Well Status after proposed work:' . .". .' . . ,. .'. .' 'oii0.. :.'~asD' .wAGD" GINJD WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sund¡y Number or N/A if C.O. Exempt: ., Contact Signature N/A ..Casin Pressure Tubin Pressure 10' 211" '1309 . WDSPLD. ¡ ..... Title Phone Form 1~~~tqeE!2p"<E~11 82004 '~" 8ft ~ ~\I! I,':. !, ld \¡¡ ¡r ~ FEB 1 ..,,) 1004 SUBMIT IN DUPLICATE 1 Q-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/16/04 Converted Sllnjector to Oil Producer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Abandon, 0 Suspend 0 operatiOn,ShUtdown " 0 Alter casing ", 'p , , ': Rep~ir~e\í "0 ' Plug pe'rloratiå~s :' 0 , , " '"Cha~g~,apþroved program ",'0' : Pu~lTübing ': 0, 'Perfo~~~'N~V'PoOl:: ',';0' 2. Operator Name: '4."CuiT~nty.¡~I', CI~ss: ConocoPhillips Alaska, Inc. ,Dèv"elo~ment~D' 'ExpIO~~ory:'O' . .. . . . 3. Address: Stratigraþhi:c " '0 ' 'Service' 0 10. FieldlPool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Dep.th TV[) (ft): , Plugs (mea~ured): " ',6498' , ,',', ,: ',", ' MD TVD JJ:' , ,', ~ ' " 1. Type of Request: P. O. Box 100360 7. KB Elevation (ft): RKB 93' 8. Property Designation: , , Kupar:uk River' Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8866' 6559' "," , ': 8l70, , ' " Casing Length Size CONDUCTOR SUR. CASING 102' 4327' 16" 102' 4420' 9-5/8" PROD. CASING 8767' 7" 8860' Perforation Depth MD (ft): .. ..... .. . .... a2~Q~&.óëö ',: ,':' ,:, ,",' ',:, Packers and SSSV Type: pkr= BAKER 'FB-1'; BAKER 'FHL' SSSV= SSSV 12~::mt;~ti~~::;::;SUinbW~-~~ketÇ~6 -. , "14~ Estiniatep:, [)äte:for ' , : 'CommenCing "Qpe.:rations': ' 01/1'6/04: , 1,6. Verbal Approval: :' 'Date: Perforation Depth TVD (ft): . .. "" . . . 6)6Ò'~~42j",<:,," " ' , 'v-J.6Æ If '3 D I 2,00 i.f /) vJ (ISO 11--, : Perlo~te' 0 ' Va~ance 0 Annulé~'r: Disp. 0 :Sti~ul,aJe: ,q, " ' Time,Extension ,0 'R~nte~'SuspendedWell ,,0 5. Permit to Drill Number: 185-046 r' 6. API Number: /' , 50-029-21308-00 9. Well Name and Number: 10-15 /' Oth~r 0 ': Junk (measured): Burst Collapse :';::H~2::':": , , , , . ... , , Tubing Size: , 3-1/2" Tubing Grade: J-55 Tubing MD (ft): 8481' Packers and SSSV MD (ft) pkr= 8452'; 8176' SSSV= 1916' '13., ,Well,'Classafter proposed work:: " "" ,'" " ,':: : EX'plo"r~tory': tJ' :, ': " ' 'D~velop'n1:Emt,: ~l '15~: ,Well' Status åfter'þrdpósed,woi"k:' ,,' , oii, ,0:' ',' , 'Gas 0' , PI~ggéd 0 wAG ,0 ,GINJ' 0' WINJ '0 Signatur Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Other: ¡;¡æJ ~ ()~~ IO-4éJ~ COMMISSIONER ,Service 0, ,Ab~nd6r1ed 0 WDSPL, 0 Contact: , Title: , Jéff Spencer ,@ 659-7226, , , Production Engine~ring Technician , Phone: 659-7535 ,pate Sundry Number: Location Clearance R:E eEl VE D JAN 3 0 2004 Alaska Oil & Gas Cons. Commission Anchorage BY ORDER OF THE COMMISSION ORIGINAL SUBMIT IN ~ICÅ Tj 1ß8Ua RØDMS BFl tota u ,.. {un 1Q-15 DESCRIPTION SUMMARY OF PROPSAL ConocoPhillips Alaska requests approval to convert We1l1Q-15 from a WAG Injector to an Oil Producer. This well was originally completed as a Kuparuk Oil Producer in July 1985. The well was subsequently converted to a Class II UIC well in July 1996 as part of an ¡nfill drilling program. Target injection rates for Well 1 Q..15 have not been realized. It has been determined that the bottom hole location of We1l1Q-15 is in an isolated fault block and is competing with Injection We1l3C-14 (offtake at Production WeIl1Q-20A). Converting this well to an Oil Producer will create a more efficient Injector to Producer pattern in this fault block. # ConocoPhillips Alaska, Inc. KRU 1Q-15 500292130800 LOCKED OUT INJ 5/14/1985 1Q.15 Size To Bottom TVD Wt Grade Thread 16.000 0 102 102 62.50 H-40 9.625 0 4420 3525 36.00 J-55 7.000 0 8860 6556 26.00 J-55 Thread EUE 8RD Zone Status Ft SPF Date Comment C-4,C-3 25 12 6/16/1985 5" Scalloped Guns HD; 120 de. h 8394 - 8404 6252 - 6259 UNITB 10 12 6/16/1985 IPERF 5" Scalloped Guns HD; 120 de. h A-4 A-3 74 4 6/16/1985 IPERF 4" Carrier JJ II- 120 de. h A-2 6 4 6/16/1985 IPERF 4" Carrier JJ II; 120 de. h Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt KBUG GLV 1.0 BK 0.125 1329 12/31/2003 KBUG GLV 1.0 BK 0.156 1352 12/31/2003 KBUG GLV 1.0 BK 0.188 1374 12/31/2003 KBUG DMY 1.0 BK 0.000 0 7/19/1996 KBUG GLV 1.0 BK 0.250 1469 12/31/2003 KBUG DMY 1.0 BK 0.000 0 7/18/1996 KBUG OV 1.0 BK 0.250 0 12/31/2003 TPDX m.w 1.5 Rt\1 0.00:1 0 7í21,'1996 Man Type V Mfr V Type VOD Latch Port TRO Vlv Cmnt Perf (8552-8626) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator I 5. Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1087' FNL, 1834' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1430' FNL, 748' FEL, Sec. 23, T12N, R9E, UM At effective depth 1103' FNL, 698' FEL, Sec. 23, T12N, R9E, UM At total depth 957' FNL, 636' FEL, Sec. 23, T12N, R9E, UM Stimulate __ Plugging Repair well __ 12. Present well condition summary Total Depth: measured true vertical 9175 6386 Perforate Other X 6. Datum elevation (DF or KB) RKB 92.5 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-15 9. Permit number/Approval number 85-46/96-152 10. APl number 50-029-21308 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Effective depth: measured 8957 true vertical 6217 feet Junk (measured) 8905' (undrillable fill) feet Casing Le n g t h Structural Conductor 1 02' Surface 4 42 0' Intermediate Production 8 85 6' Liner Perforation depth: measured 8666'-8654', true vertical 6431 '-6423', Size Cemented Measured depth True vertical depth 1 6" 240 Sx CS II 102' 102' 9-5/8" 1200 Sx AS III & 4420' 3525' 400 SX CS1 7" 350 Sx Class G & 8 8 5 6' 6 5 5 3' 250 Sx CS I 8626'-8552', 8404'-8394', 6405'-6357', 6259'-6252', Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 8479' Packers and SSSV (type and measured depth) Pkr: Baker FB-1 @ 8440', Baker FHL @ 8160'; SSSV: Removed 8285'-8260' 6178'-6160' RECEIVED 13. Stimulation or cement squeeze summary Converted oil producer to WAG injector. / Intervals treated (measured) / N/A Treatment description including volumes used and final pressure N/A OCT 1 5 1996 011 aonm. Oomml ion Al lorage 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 200 150 235 750 215 Subsequent to operation 0 0 500 750 24OO 15. Attachments Wellbore schematic 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations __ Oil Gas __ Suspended __ 17. I her~ c~rtify that the foregoing is true and correct to the best of my knowledge. / / Signed Title Wells Superintendent Form ~0-~0~ he~ 6(r/~ '"'- / Service WAG Injector D at e/~,~',~----/( SUBMIT IN DUPLICATE STATE OF ALASKA gJ_ASKA OIL AND C~S C_~, NSERV~TION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program X 2. Name of Operator ARCO Alaska, Inc. 3. Address Suspend __ Operation Shutdown__ Re-enter suspended well ~ Repair well ~ Plugging ~ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) Pull tubing 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1087' FNL, 1834' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1430' FNL, 748' FEL, Sec. 23, T12N, R9E, UM At effective depth 1103' FNL, 698' FEL, Sec. 23, T12N, R9E, UM At total depth 957' FNL, 636' FEL, Sec. 23, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical RKB 92.5 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-15 9. Permit number 35-46 feet 10. APl number 5o-029-21308 11. Field/Pool Kuparuk River Field/Oil Pool 91 75 feet Plugs (measured) None 6386 feet Effective depth: measured 8957 true vertical 6217 feet Junk (measured) 8905' (undrillable fill) feet Casing Length Structural Conductor 1 0 2' Surface 4 42 0' Intermediate Production 8 8 5 6' Liner Perforation depth: measured 8666'-8654', true vertical 6431 '-6423', Size 16" 9-5/8" 7" Cemented 240 Sx CS II 1200 Sx AS III & 40O SX CS1 350 Sx Class G & 250 Sx CS I 8626'-8552', 6405'-6357', 8404'-8394', 6259'-6252', Tubing (size, grade, and meaSured depth) 3.5", 9.2#, J-55 @ 8479' Packers and SSSV (type and measured depth) Pkr: Baker FB-1 @ 8440', Baker FHL @ 8160'; SSSV: Removed Measured depth True vertical depth 102' 102' 4420' 3525' 8856' 6553' 8285'-8260' 6178'-6160' JUL 13. Attachments Description summary of proposal X Convert oil producer to WAG injector. 14. Estimated date for commencing operation July 28, 1996 16. If proposal was verbally approved Name of approver Blair Wondzell 7/26/96 Date approved Detailed operation program __ 15. Status of well classification as: Oil Gas Service WAG Injector BOP sketch Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,,,..~4,/,4~..~.~-~, ~/~r//~a/'AI'' ~'~,/C.. Title Wells Superintendent Signed FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Sub,.,se. qt~ent, f,~rm require 10- /-leo ~- ur~g~na~ ,~gnea u~ David W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 IApproval No.C~.~o,,_/~ I SUBMIT IN TRIPLICATE on , ;,~?oved Copy R e~ r._n..~'d_c.~ Attachment 1 Conversion to WAG Injection Kuparuk Well 1Q-15 ARCO Alaska requests approval to convert Well 1Q-15 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection ..Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6160' and 6431' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, In(:. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1087' FNL, 1834' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1429' FNL, 748' FEL, Sec. 23, T12N, R9E, UM At effective depth 1119' FNL, 677' FEL, Sec. 23, T12N, R9E, UM At total depth 958' FNL, 637' FEL, Sec. 23, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8770' M D feet 6404' MD feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 92.5 7. Unit or Property name Kuparuk River Unit $. Well number 1Q-15 9. Permit number/approval number 8-404 10. APl number 5q-Q29-21:~QS-QQ 11. Field/Pool Kuparuk River Oil Pool feet Effective depth' measured 8652' M D feet true vertical 6328' MD feet Junk (measured) None Casing Structural Conductor Surface Length Size 80' 1 6" 4188' 9-5/8" Intermediate Production Liner Perforation depth' 8696' 7" measured 8260'-8285' MD, true vertical 6159'-6177' TVD, Cemented 200 SX CS II 1100SXCS III & 450 SX CS I 300 SX Class G Measured depth True vertical depth 116' MD 116' TVD 4224' MD 3392' TVD 8731' MD 6516' TVD 8394'-8404' MD, 8552'-8626' MD, 6253'-6259' TVD, 6357'-6404' TVD, Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55 IPC, 8469' MD Packers and SSSV (type and measured depth) SSSV: Baker "FVL" @ 1893'; Packer: Baker "FHL" @ 8160' 13. Stimulation or cement squeeze summary 8654'-8660' MD 6423'-6427' TVD 14. Refer to Well Service Report Intervals treated (measured) Refer to Well Service Report ~',,i;-',,-', Treatment description including volumes used and final pressure r-~.~ ..... ~e~,or, .: ::.,;;,.: .0il .& G~s Cons, r',., Refer to Well Service ' ¢ .l_ . . '~ Representative Daily Average Production or Injection Data .... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 261 1 90 0 1 000 160 Subsequent to operation 3 7 2 3 4 9 0 727 193 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby//~,~4.~certify that~ the.,,r.,~n/t v",~~¢ '~''/y'~''~f°reg°ing is true and correct to th~ best/"),~°f my knowledge. Signed Title Form 10-404 ~e¢ 06/~'5/8~ - SUBMIT IN DUPLICATE WELL *ARCO Alaska, Sul~idla~y of Atlantic Richfield Compan~ PBDT J F, ELD - ~S:,?: -(S/TtTE WELL SERVICE REPORT I iDATE , CONTRACTOR ~r)~.,_~--.z/ - _~_, ,~EMARKS IOPERATION AT REPO~I¥ TIME [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp- I Chill Fact°r I Visibility IWlnd Vel' ..,or, Z//. oF, .-----o~:l//,,,j/_. miles · REMARKS CONTINUED: D ESCRI PTION DAILY ACCU M. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON · ARCTIC COIL TUBING Roustabouts Diesel 'TZ, Methanol Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE STATE OF ALASKA '-" ALASK,-~ OIL AND GAS CONSERVATION COMN,..~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate 1~ Pull tubing [] Amend order [] Perforate [] Other [] . Name of Operator ARCO Alaska, ]]nc 3. Address PO Box 100360: Anchorage: AK 4. Location of well at surface 995]0 1087' .FNL, 1.834'.FEL., Sec 26, T12N, R9E, UM At top of pro(]uct~ve in[erva~ ' 1429' FNL, 748' FEL, Sec. 23, T12N, R9E, UM At effective depth 1119' FNL, 677' FEL, Sec.23, T12N, R9E, UM At total depth 958' FNL: 637' FEL: Sec. 23_. Tl2N. RgE. IIM 11. Present well condition summary Total depth: measured 8770' ND feet true vertical 6404' ND feet Effective depth: measured 8652' MD feet true vertical feet 6328' MD Casing Length Size Structural 80' 16" Conductor Surface 4188' 9-5/8" x x x krxt~t ~q~ i~te Production 8696' 7" xxxk- xxxx Perforation depth: 5. Datum elevation (DF or KB) RKB 92.5 6. Unit or Property name Kuparuk River Unit 7. Well number 10-15 8, Permit number Permit #85-46 9. APl number 50-- 029-21308-00 10. Pool K~Jpar~Jk RivPr (lil Pnnl Plugs (measured)None Junk (measured) None feet '.~ Cemented Measured depth 200 SX CS II 116' MD 1100 SX CS III 4224' MD & 450 SX CS I 300 SX Class G 8731' MD measured 8260'-8285' MD, 8394'-8404' MD, 8552'-8626' MD 8654' -8660' MD true vertica16159'-6177' TVD, 6253'-6259' TVD, 6357'-6404' TVD 6423' -6427' TVB Tubing (size, grade and measured depth) 3½", 9.3 lb/ft, J-55 IPC, 8469' MD Packers and SSSV (type and measured depth) SSSV- Raker "FYI" @ 7893'' Packer- Baker "FHL" @ 8!60' 12.Attachments Description summary of proposal ~ Detailed operations program ~ue Vertical depth 116' TVD 3392' TVD 6516' TVD BOP sketch [] H.ydraulicallv refracture the A Sands with i40M nf 16/?F) £m~'ho-I ire proppant. 13. Esl'f~.~dl~])~§ for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to.~l~ ~te~fa~¥oknn¢~~eer Title _ ' ' -Commission Use ~nly ~ Conditions of approval Approved by Notify commission so representative may witness Approval No. [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 ORIGINAL SIGNED BY LONNIE C. SMITH 5/17/88 Date Approved Copy Returned Commissioner by order of the commission Date Submit in triplicate /"y/ Kuparuk Well 1Q-15 A Sand Refracture Stimulation CC 230DS10QL May 13, 1988 1. RU Slickline. 2. RIH with gauge ring and tag bottom. 3. Pull 1-1/2" C Sand CV's and run DV's @ 8240', 8310', & 8419' RKB. 4. Pull 1-1/2' GLV and run DV @ 8105' RKB. . Pull 1" GLV's and run DV's @ 2092', 4145', 5452', 6205', 6639', 7077', & 7511' RKB. * 6. Run Standing Valve in 'D' nipple and pressure test tubing to 3000 psi. 7. RDMO Slickline ! . 11. 12. 14. Pump diesel/10% Musol and flush with diesel (soak overnight) as described on Pump Schedule. MIRU transports and pumps; Install 'Tree Saver'. Diesel should be checked for contamination before gelling. Check Carbolite for fines due to handling. Take samples of the Carbolite and the gelled diesel with breaker. Record the proppant weight before and after the fracture stimulation. Begin pumping job (Refer to Pump Schedule); Obtain representative fluid samoles of the pad. slurry and flush stages during the stimulation. Maintain pressure on the annulus as close as possible to 3500 psi during the fracture treatment. WHTPE = 4700 psi Fracture Gradient = 0.75 psi/ft (6380' TVD) Tubing Friction = 250 psi/1000ft (8469' MD) Recommended Maximum Treating Pressure = 6900 psig ** SI Well; RDMO fracturing equipment. Consult flowback schedule for post frac procedures. * All mandrels have live valves. * * If treating pressure during the pad exceeds 5500 psi, shut down job and consult Operations Engineering. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A KUPARUK WELL 1Q-15 'A' SAND FRACTURE PUMP SCHEDULE 5/13/88 STAGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT BBLS B P M PPG DESCRIPTION PROPPANT WT DIRTY VOLUME HIT PERFS LBS STG/CUM BBLS 1 DIESEL/10% MUSOL 2 DIESEL FLUSH 3 GD PRE-PAD 100.0 40.0 5 0 77.0 5 0 SHUT 25 0 SHUT 25 0 25 2 25 4 25 6 25 8 25 10 25 0 4 GDPAD 600.0 5 GD w/2 PPG 27.6 6 GD w/4 PPG 51.0 7 GD w/6 PPG 102.8 8 GD w/8 PPG 118.3 9 GD w/10 PPG 152.7 1 0 GD FLUSH 75.0 +SV DOWN OVERNIGHT DOWN FOR ISIP 16/20 M CARBO-LITE 16/20 M CARBO-LITE 16/20 M CARBO-LITE 16/20 M CARBO-LITE 16/20 M CARBO-LITE 0 40/ 40 77 0 77/ 117 117 0 100/ 1 O0 77 0 600/ 600 77 2316 30/ 630 677 8569 60/ 690 707 25909 130/ 820 767 39746 160/ 980 897 64134 220/ 1200 1057 0 75,0/ 1275.0 1277 NOTES: TOTAL DIESEL = 113.0 BBLS +SV TOTAL GELLED DIESEL = 1227.4 BBLS TOTAL MUSOL = 4.0 BBLS 16/20 M CARBO-I. ITE = 140675 LBS Stage 1 is Diesel with 10% Musol Stage 3 is Gelled Diesel with 8 hr breaker Stage 4 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 5 through 9 are Gelled Diesel with 6 hr breaker and without silica flour. ' ','~ Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker(6 hr. break). · This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. ~-~ All fluids should be maintained at 70 to 90 F on the surface. Kuparuk Well 1Q-15 A Sand Refracture Sundry Notice 5/17/88 No BOP will be used for this refracture stimulation of the A Sands. No workover fluid will be used for the refracture of the A Sands. A Sand reservoir pressure is estimated to be 2500 psia. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM,.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,,-1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other . Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 4. Location of well at surface 99510 A1087' .FNL, 1.834.'.FEL, Sec.26, T12N R9E UM t top oT proaucuve ~n~erva~ ' ' 1429' FNL, 748' FEL, Sec. 23, T12N, R9E, UM At effective depth 1119' FNL, 677' FEL, 5ec.23, T12N, R9E, UM At total depth 958' FNL: 637' FEL: Sec.23, T12N: RgE.. IIM 11. Present well condition summary Total depth: measured 8770' MD feet true vertical 6404' MD feet 5. Datum elevation (DF or KB) RKB 92.5 6. Unit or Property name Ku~aruk River Unit · 7. Well number 1Q-15 8. Permit number Permit #85-46 9. APl number 50-- 029-21308-00 10. Pool Kun~r~,l~ Rivmr 13il Pnnl ! feet Plugs (measured~one Effective depth: measured 8652' ND feet true vertical feet 6328' MD Casing Length Size Structural 80' 16" Conductor Surface 4188' 9-5/8" XX X J~r~R~[~lite Production 8696 ' 7" xxx Ja xxxx Per=foration depth: measured Junk (measured) None Cemented Measured depth 200 SX CS II 116' MD 1100 SX CS III 4224' MD & 450 SX CS I 300 SX Class G 8731' MD 8260'-8285' MD, 8394' -8404' MD, 8552'-8626' ~ID 8654' -8660' MD True Vertical depth 116' TVD 3392' TVD 6516' TVD true vertica16159'-6177' TVD, 6253'-6259' TVD, 6357''6404' TVD 6423' -6427' TVD Tubing (size, grade and measured depth) 3½", 9.3 lb/ft, J-55 IPC, 8469' MD Packers and SSSV (type and measured depth) SSSV- Raker "FVI" 0 ]Rq3'; Packer'. Baker "FHL" @ 8160' 12.Attachments Description summary'of proposal H.ydraulically refracture the A Sands with lZ[OM nf 1~/2~ £~rho-~ ~te p?Ornrnan, t. 13. EslYra~t,edl~ll~[t~ for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. Ihereby certify that the foregoing is true and correct to.~l~e~ b~te~fa~fo~r~~eer Signed ~...~.~_ ~ ~)~_.~.,;.~.~ Title J~_ ~,~nf?...g~..~.~_~C,; ~ ~ ' ' ' Commission Use ~nly ~ 5/17/88 Date Conditions of approval ORIGINAL SIGNED BY , '~,~,~ r, RMITH Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Returned Approved by '_ ~ .. Commissioner by order of ,,.~--- the commission Date Form 10-403 Rev 12-1-85 : ;;:~' Submit in triplicate Kuparuk Well 1Q-15 A Sand Refracture Stimulation CC 230DS10QL May 13, 1988 1. RU Slickline. 2. RIH with gauge ring and tag bottom. 3. Pull 1-1/2" C Sand CV's and run DV's @ 8240', 8310', & 8419' RKB. 4. Pull 1-1/2' GLV and run DV @ 8105' RKB. . Pull 1" GLv's and run DV's @ 2092', 4145', 5452', 6205', 6639', 7077', & 7511' RKB. * 6. Run Standing Valve in 'D' nipple and pressure test tubing to 3000 psi. 7. RDMO Slickline . Pump diesel/10% Musol and flush with diesel (soak overnight) as described on Pump Schedule. 9. MIRU transports and pumps; Install 'Tree Saver'. 10. Diesel should be checked for contamination before gelling. Check Carbolite for fines due to handling. Take samples of the Carbolite and the gelled diesel with breaker. Record the proppant weight before and after the fracture stimulation. 11. Begin pumping job (Refer to Pump Schedule); Obtain reoresentative fluid sem.oles of the Dad. slurry and flush stages during the stimulation. Maintain pressure on the annulus as close as possible to 3500 psi during the fracture treatment. WHTPE = 4700 psi Fracture Gradient = 0.75 psi/ft (6380' TVD) Tubing Friction = 250 psi/1000ft (8469' MD) Recommended Maximum Treating Pressure = 6900 psig ** 12. SI Well; ~RDMO fracturing equipment. 1 4. Consult flowback schedule for post frac procedui'~es. All mandrels have live valves. * * If treating pressure during the pad exceeds 5500 psi, shut down job and consult Operations Engineering. ARCO Alaska Inc.. Is a subsidla,'y of Atlantic Richfield Company AR3B-6001.A KUPARUK WELL 1Q-15 'A' SAND FRACTURE PUMP SCHEDULE 5113/88 Si,aGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME HIT PERFS STG/CUM BBLS 1 DIESEL/10% MUSOL 2 DIESEL FLUSH 3 GD PRE-PAD 100.0 40.0 5 0 - - 77.0 5 0 - - SHUT DOWN OVERNIGHT 25 0 - - 0 SHUT DOWN FOR ISIP 25 0 - - 0 25 2 16/20 M CARBO-LITE 2316 25 4 16/20 M CARBO-LITE 8569 25 6 16/20 M CARBO-LITE 25909 25 8 16/20 M CARBO-LITE 39746 25 1 0 16/20 M CARBO-LITE 64134 25 0 - - 0 4 GD PAD 600.0 5 GD wi2 PPG 27.6 6 GD w/4 PPG 51.0 7 GD wi6 PPG 102.8 8 GD w/8 PPG 118.3 9 GD w/10 PPG 152.7 1 0 GD FLUSH 75.0 +SV 0 40/ 40 77 0 77/ 117 117 100/100 77 600/ 600 77 30/ 630 677 60/ 690 707 1 30/ 820 767 1 6O/ 98O 897 220/ 1200 1057 75.0/ 1275.0 1277 TOTAL DIESEL = 113.0 BBLS +SV TOTAL GELLED DIESEL = 1227.4 BBLS TOTAL MUSOL = 4.0 BBLS 16/20 M CARBO-IITE = 140675 LBS Stage 1 is Diesel with 10% Musol Stage 3 is Gelled Diesel with 8 hr breaker Stage 4 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 5 through 9 are Gelled Diesel with 6 hr breaker and without silica flour. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker(6 hr. break). This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. I All fluids should be maintained at 70 to 90 F on the surface. Kuparuk Well 1Q-15 A Sand Refracture Sundry Notice 5/17/88 No BOP will be used for this refracture stimulation of the A Sands. No workover fluid will-be used for the refracture of the A Sands. A Sand reservoir pressure is estimated to be 2500 psia. ARCO Alaska, Inc.~-.~ Post Office~ 'x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. DAT~: 10-22-85 T1AANSMITTAL [40:5410 RETURN TO: TRANSMITTED CEIPT FINAL PRINTS/.-SCHL/ ONE * OF EACH CEMENT. BOND LOG/ VAKIABLE DENSITY "~3B- 8 06-06-85- RUN #1 5850-8369 ~ 42X- 15 "~2X-13 ~ 2X- 12 ~2X-11 -~2X-10 w2X-9 '~ 2W-6 '~2V-16 '~ 2V- 15 ~ 2V-13 '. A1{CO ALASKA, INC. KUPARUK OPERATIONS ENGINEEItING }d~CORDS CLEkK ATO-1115B '- ', P.O. BOX 100360 . ANCHORAGE, AK 99510 HER/-~4ITH AK~ Tn~ FOLLOWING ITE~IS. RETURN ONe: SIGNED COPY OF THIS TRANSMITTAL. 7-85 3-85 RUN RUN RUN RUN kUN RUN RUN kUN RUN RUN · 11-07-.84 11-17-84 12-08-84 12-08-84 12-21-84 12-20-84 11-25-85 06-06-85 06-0 O6-O 2- 85 RUN 1-~5 ~UN 1-85 t{UN 04-01-85 03-02-85/ ~ i{UN 12-19-84 kUN 12-18-84 RUN 11-03-84 RUN 06-17-85 kUN 06-08-~5 06-08-85 ~UN 11-05-84 RUN 05-27-85 RUN 04-17-85 · t~UN ~XJ2U'8 :~ 04-0 ',,",,2U- 7 :":.-' ' 04- 0 2U-6 ::-: ' 03-3 2D- 16 20-15 :: '~ 1R-8 ~'~lL-15 lQ-15 #1 #1 %1 #i #1 #1 LOGS/ #1~ _#2-: #1-:- #1. PLL.'ASE ACKN(~4LEDGE %CPF- lA. 12-21-84' ~UN . CEMENT EVALUATION TOOL tF~'16 03-12-85 RUN ' %~iR-5?<i~/. 06-26-85 RUN ~lR-5~'~!?/i-06-27-85 _ RUN ~2U-2~!~:i!-: 03-25-85 · RUN ' ~' 2U-15<:. 03-07-85 RUN 5900-8258 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-6938' 0070-~122 5600-8107 -. ' 5994-9161 6284-7850 520U-7469 3285-6454 - 5693-6652 5987-8324 4302-7028 6950-8628 4883-6600 6490-7566 897~-10744 2200-3856 _ Ck24ENT ~:VALUATION LOGS 8269-8712 6974-8644 8254-8532 5790-9450~ 6400-7002 W. PASHE~ EXXON PHILLIPS OIL J. RATHmELL" 6000-8246 6500-8726 540O-7457 V~3B-9 ::::?:::: 06-30-85 RUN #1 "~'3C-11':-: 06-29--85 _. RUN #1 ' ~3C~12: '- 06-29-85- RuN ~1 : t~EC~iPT ACKNOWL~DG~'.D: B. CUVIER L. JOHNSTON_ .. D'& M. ~ ' ~" NSK CAE~K*DL - · - . ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfielclCompany ' DA.~,r.,~Alasmz 0it '& Gas Cons. commiSSiOn os....: .- ,_, ............ SOHIO ...... UNION ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-15 Dear Mr. Chatterton- Enclosed is a copy of the 1Q-15 Well History (Completion Details) to include with the Well Completion Report, dated 7/10/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L125 Enclosures RECEIVED A/aska 0il & Gas Cons. C0mmissJo~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanticR .,fieldCompany ~' Dally Wall History-Initial Report Inlbugtl~fll: Prepare and submit the "l.ttJII Report" on the first Wednesday after s well Is spudded or workover operellonl are ituted. Dally work prior to spudding .~ould be summarized on the form giving inclusive dates only, Di~tdct :::: '~!~--~ I County or Parish Alaska .: North Slope Borough I Field ILease or Unit Kuparuk Rive= [ ADL 25634 Auth, or W.O. no. [Title AFE 504777 [ Completion WWS #1 API 50-029-21508 Alaska no. lQ-15 Operator I A.R.Co'e W.I. ARCO Alaska, Inc. Complete record for each day reported Date and depth as of 8:00 a.m. 6/lo/85 6/11/85 6/12185 6/13/85 6/14/85 56.24g 7" @ 8860' ~77~8-7~ PBTD, RIB w/DP 10.0 ppg Na¢l/NaBr Accept rig @ 0115 hrs, 6/10/85. ND tree, NU & tst BOPE to 250/3000 psi. RIH w/bit & scrprs. 7" @ 8860' ~770~8-7~-P' PBTD, Drlg cmt 10.0+ ppg NaC1/NaBr RIH, drl cmt f/7569'-7944'. 7" @ 8860' 8~'"~e~' PBTD, Drlg cmt 10.0+ ppg NaCl/NaBr Drl cmt f/7944'-8488'. 7" @ 8860' ~07~' PBTD, NU 7" riser 10.0+ ppg NaC1/NaBr Drl cmt f/8488'-8760', CBU, POOH. gyro f/TD to surf. NU 7" riser. Rn CBL f/TD to 8000'. Rn '.7" @ 8860' ~-/7~, PB~I), PU B~A ~O;O+-pP~NaC1/NaBr ~:!Scbl,:'RIH w/4" csg guns, 4 SPF, 90° phasing. Perf 8~'70'-8172', RD Schl. RIH w/Champ II sqz pkr, set @ 7920'.~kOLff]~ Tst ann; OK. Est IR @ 1BPM/1500 psi. Pmp 100 sx C1 "G" w/.3% D-31, .8% D-28 & .1% D-6. Stage in cmt. POH, LD pkr. PU BHA. RECEIVED OCT 2 .i i 85 The above is correct Signature For form preparation al~d distribution, see Procedures Manua~ Section 10, Drilling, Pages 86 and 87. AR3B-459-1-B / ~'/,.3'/,,F.,5"'AFI0J"J0}8_~0 Drilli., $uper,nten,ent Number all dally well history forms consecutively as they are prepared for each well. j Page].no. · , :/ ARCO Oi. _nd Gas Company Daily Well History-Final Report Inslruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of lime. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish Stale Alaska, Alaska North Slope Borough Field Lease or Unit ~Well no. Kuparuk River ADL 25634 I IQ-15 Auth. or W.O. no. T t e AFE 504777 Completion WWS #1 AP1 50-029-21308 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 6/10/85 Date and depth as of 8:00 a.m. 6/14/85 thru 6/17/85 Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our Prior status il a W.O. 0115 hrs. 7" @ 8860' 8~'7ch~o~ PBTD, Ba Crude RIH, tag cmt @ 7920', DO to 8172'. Chg over to cln brine. RU WL, RIH w/3½" compl string. Set pkr, shear PBR, set BPV. ND BOPE, NU & tst tree. Displ well to crude. Shear ball. RR @ 1530 hfs, 6/16/85. (Note: Rn 265 its, 3½", 9.3#, J-55 8RD IPC tbg.) Old TD New TD Released rig Date . 1530 hrs. Classifications (oil, gas, etc.) O±l PB Deplh 6/16/85 Kindofrig Type completion (single. dual, etc.) Single Producing method Ofliciai reservoir name(s) Flowing Kuparuk Sands Potential test data 8760' PBTD Rotary Well no. Date Reservoir Producing interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sig~ ~%~u~,~ Date ITitle ~'/.~.Z,,/~f.f Drilling Superintendent For form preparationl~and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3R-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage~no. Olvlllon ol AlllnticRIcMleldGompIny ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 TRANSMITTAL NO: 5341 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 - TRANSMITTED HERA%4ITH ARE THE FOLLOWING ITt/~IS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. CASED HOLE LOGS (FINALS): x'rlQ-15 / 'CBL 6/12/85 8000-8745 ~ lQ-1~-~ CCL & PERFORATING RECORD 4/16/85 ~ 2V-9--~ COMPLETION RECORD 4/25/85 7525-7800 ~2H-15''~ COMPLETION RECORD 4/13/85 6998-7438 ~2H-2--' CCL & PERFORATING RECORD 4/24/85 ~ 2H-14~- CCL & PERFORATING RECORD 4/23/85 ~2H-16~ CCL & PERFORATING RECORD 4/19/85 ~lR-9~ PERFORATING RECORD 8/3/85 7800-8000 ~lB-2 ~-~ PACKER SETTING RECORD 6/5/85 7290-7820 ~lA-9~ PACKER SETTING RECORD 8/15/85 6700-6950 ~ ~w2H-13-- COMPLETION RECORD 4/!7/85 7434-7650 i~IR-10 ~ PERFORATING RECORD 8/5/85 8300-8550 '~2Z-8~ COMPLETION RECORD 4/27/85 8920-9030 ~ 3B-11~-~ CET 7/5/85 6500-9100 RECEIPT ACKNOWLEDGED: · DISTRIBUTION: BPAE DRILLING* W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D &~M NSK CLERK* J. RATHMELL UNION K.TULIN/VAULT ARCO Alaska. Ir~ Post Office ~,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RJJTURN TO: DATE: 08-21-85 TRANSMITTAL NO: 5292 ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 lB-1. lB-2. '~lB-4. 1C-4 lC-6~ 1D_ 8_~ --1H-3 ~lQ-13/ IQ- 14-~' · -'lQ-16 1R_5? 1R-6 -1R-7/ "lR-8 "2A-2 ~2~-7-~ "-2V- 3 .~2W-15-~ 3B-t 3B-2 ? 3B-3.~ ~3B-3' ~3B-4-- -3B-5 3B,6~ -.3B- 7.- 3B-7 -~ 3B- 8~ -3B-9~ . -10-: ~-3B-11 -- 3B-12 -.~ 3B-13. ~3B-14 TRANSMITTED A~:CEIPT AND KUPARUK WELL PRESSURE REPORT--ENVELQPE FACE DATA 05-30-~5 CAMCO HEREWITH ARF; THE FOLLOWING ITEMS. RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ~3B-15 3B-16--' -'"'% 3C-11 05- 3 0- 85 CAMCO 05-16-85 CAMCO 07- 24- 8 5 CAMCO 07-25-85 CAMCO O 7- 30- 8 5 CAMCO 0 7- 30- 85 CAMCO 06- 24- 85 CAMCO 06-23-85 CAMCO 06- 21- 8 5 CAMCO 06-21-85 CAMCO 07- 05- 85 CAMCO 07-06-85 CAMCO 07- 06- 85 CAMCO 07- 08 - 85 CAMCO 07-04-85 OTIS 07-26-85 DRESSE~ 07-11-85 OTIS 08-04-85 OTIS 06-14-85 ???? 06-14-85 CAMCO 06-28-~5 OTIS 06-15- 85 CAMCO 06-15- 85 CAMCO 06-26-85 CAMCO 06- 2 6- 8 5 CA~]CO 06-28-85 CAMCO 06- 27- 85 C~JCO 06-28-85 OTIS 07-18 - 85 CAMCO 07-20-85 CAMCO 07- 20- 85 CAMCO 07-21-85 CAMCO 05-29-85 OTIS PLEASE ACKNOWLEDGE 05-29-85 OTIS RECEIPT ACKNOWLEDGED: DISTRIBUTION: %'~. PAShER EXXON PHILLIPS OIL* J. RATHMELL* BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* b~BIL* D & M* NSK CLERK 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, /nc. ~s a Subsid{ary of AtlanticRJch~lieldCompany ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-08-85 TRANSMITTAL N0:5242 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. ~ ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. lQ-5 lQ-6 2D-7 2D-8 2H-3 2H-3 2H-3 3B-3 3B-3 SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS FLUID AND ACID DATA 'C' SAND ACID 06-23-85 'C' SAND ACID 06-24-85 'C' SAND ACID STIMULATION 06-21-85 'C' SAND ACID STIMULATION 06-21-85 'A' SAND ACID STIMULATION 06-23-85 'A' SAND ACID STIMULATION 06-21-85 'A' SAND ACID STIMULATION 06-22-85 FLUID I. D. FLUID I. D. PRESSURE DATA 1E-25 BHP WORKOVER lQ-13 STATIC AND MISCELLANEOUS lQ-14 STATIC AND MISCELLANEOUS lQ-15 STATIC AND MISCELLANEOUS lQ-16 STATIC AND MISCELLANEOUS 2E-9 BHP STATIC SURVEY 2E-10 BHP STATIC SURVEY 2E-11 BHP STATIC SURVEY 2E-12 BHP STATIC SURVEY 2F-10 FLOSSING BHP AND MISC. 2U-14 'C' SAND PBU--START 2U-14 'C' SAND PBU--FINISH 2U-16 'A' SAND PBU--START 2U-16 'A' SAND PBU--FINISH 2V-5 'A' SAND PBU--START 2V-5 'A' SAND PBU--FINISH 2V-13 INITIAL BHP & MISC. 2V-13 INITIAL BHP & MISC. 2V-14 INITIAL BHP & MISC. 2V-15 STATIC BHP 2V-16 STATIC BHP !X-2 E-LINE BHP 2X-2 E-LINE BHP 2X-5 BHP FOR WORKOVER ~B-2 STATIC PRESSURE & MISC. ~B-3 STATIC PRESSURE & MISC. ~B-5 STATIC BHP PRIOR TO FRAC ,B-6 STATIC BHP PRIOR TO FRAC ~ECEIPT ACKNOWLEDGED: ~PAE* MOBIL* iHEVRON* ~ & M* 06-23-85 06-20-85 06-12-85 06-24-85 06-23-85 06-21-85 06-21-85 06-13-85 06-13-85 06-13-85 06-13-85 06-14-85 06-18-85 06-18-85 06-17-85 06-17-85 06-26-85 06-26-85 06-22-85 06-21-85 06-22-85 06-19-85 06-19-85 06-16-85 06-14-85 06-12-85 06-14-85 06-15-85 06-26-85 06-26-85 SOHIO* PHILLIPS OIL* J.RATHMELL* ~,,$TATE OF A~K* ^n,"-,-, A,_~,.- ,_- =- - ~ .... - ...... NOWS CO/HALL IBURTON NOWSCO/HALLIB URTON B. J.HUGHES B.J.HUGHES CAMCO/HOT OIL DOWELL NOWSCO OTIS OTIS OTIS CAMCO CAMCO CAMCO CAMCO OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CA/.~CO CAMCO/OTIS OTIS ,,~ OTiS OTIS CAMCO CA~-~CO DATE: K. TULIN/VAULT L. JOHNSTON WELL FILES ARCO Alaska, Inc.'~-''' Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE- 07-16-85 TRANSMITTAL NO: 5247 RETURN TO: TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1115B OPEN HOLE FINAL PRINTS/SCHL (ONE * OF EACH) lQ-15 5" DIL/SFL-GR 05-12-85 RUN $1 4416-8714 2" DIL/SFL-GR 05-12-85 RUN $1 4416-8714 5" DEN/NEU-GR PORO 05-12-85 RUN $1 4416-8689 2" DEN/NEU-GR PORO 05-12-85 RUN $1 4416-8689 5" DEN/NEU-GR RA%; 05-12-85 RUN $1 4416-8689 2" DEN/NEU-GR RAW 05-12-85 RUN $1 4416-8689 CYBERLOOK 05-12-85 RUN $1 8000-8689 2U-10w' 5'' DIL/SFL-GR 04-11-85 RUN $2 2994-7034 2" DIL/SFL-GR 04-11-85 RUN $2 2994-7034 5" DEN/NEU PORO 04-11-85 RUN $2 6350-7008 2" DEN/NEU PORO 04-11-85 RUN $2 6350-7008 5" DEN/NEU RAW 04-11-85 RUN $2 6350-7008 2" DEN/NEU RAW 04-11-85 RUN $2 6350-7008 CYBERLOOK 04-11-85 RUN $2 6350-6985 RFT LOG 04-11-85 RUN $2 6575-6869 2U-11 5" DIL/SFL-GR 04-17-85 RUN $1 3767-8472 2" DIL/SFL-GR 04-17-85 RUN $1 3767-8472 5" DEN/NEU PORO 04-17-85 RUN $1 6000-8449 2" DEN/NEU PORO 04-17-85 RUN $1 6000-8449 5" DEN/NEU RAW 04-17-85 RUN $1 6000-8449 2" DEN/NEU RAW 04-17-85 RUN $1 6000-8449 CYBERLOOK 04-18-85 RUN $1 8000-8390 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M*BL DISTRIBUTION~ DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL*BL Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA*BL SOHIO /SE UNION K.TULIN/VAULT*FILM ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~. 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in~ duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action 1B-2 Fractur 1B-4 Fractur 1E-lA Cancel I 1E-lA Cancel I 1E-27 Cancel ! 1E-30 Polymer 1F-6 Cancel lation 1F-13 Cancel lation 1G-1 Cancel lation 1Q-5 Acidize 1Q-6 Acidize 1Q-7 Fracture 1Q-11 Cancel lation 1Q-1 3 Fracture 1Q-14 Fracture 1Q-15 Fracture 1Q-16 Fracture 1Y-2 Convers i on 1Y-8 Convers i on 1Y-12 Convers i on 2A-2 Convers i on 2C-8 Cance I I a t i on 2C-1 4 Ac id i ze 2H-1 5 St imu I at ion 2V-2 Convers i on e e at ion (Reperf) at ion (Frac) ation (Frac) Proiect (Frac) (Frac) (Stressfrac) (Frac) (Perf) Date Performed 6/14/85 6/14/85 1/5/85 6/23/85 6/24/85 6/25/85 7/2/85 7/1/85 7/2/85 7/2/85 3/30/85 3/30/85 3/30/85 3/31/85 7/2/85 6/30/85 5/16/85 on the If you have any questions, please call T. M. 'Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. Is a Subsidiary of AllanlicRIchlieldCompany STATE OF ALASKA --' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 7. Permit No. 2. Nar~eF~l~)pe~tl~SKA, INC. 85 - 46 3. Address 8. APl Number P O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 308 FNL, 1845' FEL, SEC. 26, OTHER [] 4. Location of Well SURFACE LOCATION' 1087' T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 92.4' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25634, ALK 2567 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number lq-15 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 2, 1985, the "A" sands of Kuparuk well 1Q-15 were hydraul ical ly fractured and propped to improve production. The treatment consisted of 343 BBLS of gel led diesel as pad and carrying fluid and 1000 LBS of 100 mesh and 12,600 LBS of 20/40 sand as proppant. 60 BBLS of gel led diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~__,~,~z~,,.~..,--- KU PARU K Signed ~.~, ~-,-,,.-,~ Title ...... ur=r,t,I l ONS COORD i NATOR The space below for Commission use Date 7/17/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date FOrm 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~--" Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Q-15 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 1Q-15. I have not yet received a copy of the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU10/L55 Enclosures RECEIVED JUL 1 2.1 B5 Alaska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ' ALASKA _ AND GAS CONSERVATION CC ,VIISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-46 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21308 ,, 4. Location of well at surface 9. Unit or Lease Name 1087' FNL, 1834' FEL, 5ec.26, T12N, RgE, UM ~LOCATIONS Kuparuk River Unit I VERIFIED At Top Producing Interval 10. Well Number 1430' FNL, 748' FEL, Sec.23, T12N, R9E, UM tSurf.. /~- : 1Q-15 At Total Depth [B. H...~-~. !; _ __ 11. Field and Pool 957' FNL, 636' FEL, Sec.23, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 92.5' RKBI ADL 25634 ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 05/06/85 05/13/85 05/14/85*[ N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (ME~-TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8866'MD,6558'TVD 8770'MD,6497'TVD YES I~X NO [] 1902 feet MDI 1400' (Approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal, CBL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 102' 24" 240 sx CS II 9-5/8" 36.0# J-55 Surf 4420' 12-1/4" 1200 sx CS III & 400 s~ CS I 7" 26.0# J-55 Surf 8856' 8;'1/2" 350 sx Class G & 250 s~ CS I · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8660'-8654' 8404' -8394' 3-1/2" 8479' 8449' & 8169' 8626'-8616' 8265'-8260' w/12 spf, 8616'-8596' 8285'-8265' 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8596'-8576' w/4 spf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8576'-8556' 120° phasing 8170' - 8172' 100 sx Class G 8556' -8552' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-C~IL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE "~ 28. CORE DATA r~ r- ~-. _ Briefdescripti~n~f~ith~~~gy~p~r~sity~fractures~apparentdips~ndpresence~f~i~~gas~rWater.Submitc~rechips~ ~ ~L ~1 VEa None Ju L 1 1985 Alaska Oil & Gas Cons. Cornrnission Anchorage Form 10-407 * NOTE: The well was perforated and tubing run on 06/16/85. GRU10/WC15 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . 30.. .: ,. GEOLOGIC MARKERS ' FORMATION TESTS · · NAME Include'interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8218' 6130' N/A Base Upper Sand 8333' 6210' Top Lower Sand 8537' 6346' Base Lower Sand 8675' 6436' '1 · ... :. ~ . 31. LIST OF ATTACHMENTS ~ . , ': , Gyroscopic Survey (2 copies) ! ' 32. I hereby certify .tha. t the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title Associa~;e Eng~rleer Date INSTRUCTIONS- · General: This form is designed' for submitting a complete and correct well completion report and log on- all types of lands and leases in Alaska. ' Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Al, ~, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ?~ZTURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANC;IORAGE, AK 99510 DATE: 06-27-85 TRANSMITTAL NO: 5235 ENGINEERING PLEASE ACKNOWLEDGE T?~ANSMITTED }IE.R~.'tITI[ ARE THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE LIS TAPES PLUS LISTING (ONE COPY OF EACH) SCIlLUMBERGER 2C-12,~.. 06-16-85 RUN ~1 3756.0-7598.0 REF !t70547 3J-8~ 06-02-85 RUN ,~1 3925.5-8516.0 REF !t70495 3B-7~ 05-24-85 RUN #1 3268.0-7310.5 REF #70468 2D-9~ 06-10-85 RUN ~1 3988.0-8415.0 REF ~70526 3D-5~ 05-12-85 RUN ~1 3447 5-8148 0 REF ~70417 22-16.~ 06-08-85 RUN ~1 4062.5-8163.5~ REF ~70525 2V-16~ 06-03-85 RUN ~! 2973.0-7168.0 REF ~70496 2V-15~ 05-24-85 RUN ~2 2U73.0-6544.5 REF ~70470 2V-14 ~ 05-16-85 RUN ~1 3047.0-7086.5 REF ~70426 2V-13 ~ 05-07-85 RUN ~1 3536.5-8710.5 REF ~70409 lR-8~ 06-14-85 RUN 91 4040.5-8576.5 REF ~70546 !~-6~ 05-14-85 RUN ~! 4623.5-9332.5 REF ~70422 ~Q--15~ 05-12-85 RUN ~1 4390.5-8730.0 REF ~70415 iQ-14~ 05-21-85 RUN ~1 4371.0-9027.5 REF ~70447 1~13~ 05-30-85 RUN ~1 3679.0-7772.5 REF ~70482 lQ-4 ~ 03-18-85 RUN ~1 4570.0-9471.0 REF ~70506 ~ AC ~-:r ~ *REVISED * DATE: ~ ~*S TATE "'OF' 'ALASKA £OI!IO UH!ON K.TULIN/VAULT Alaska C~i & ~as Dens. Commission Anchcra~ ARCO Alaska, Inc. ~' Post Office Bo,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1Q-15 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 1Q-15. I have not yet received a copy of the Well~ History (completion details). When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L41 Enclosure J u L o 1 85 Alaska Oil & Gas Cons. bu,,~rnission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /-. STATE OF ALASKA .~-._ ALASKA~ _ AND GAS CONSERVATION CC .~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-46 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21308 4. Location of well at surface 9. Unit or Lease Name 1087' FNL, 1834' FEL, Sec.26, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1Q-15 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indiCate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 92.4' RKBI ADL 25634 ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/06/85 05/13/85 05/14/85*J N/A feet MS L 17. Total Depth (MD+TVD) ilS.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8866'MD 8770'MD _. . YES [] NO E~XI 1902 feet MD 1400' (Approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Ca 1 , CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 102' 24" 240 sx CS II 9-5/8" 36.0# J-55 Surf 4420' 12-1/4" 1200 sx CS III & 400 s~ CS I 7" 26.0# J-55 Surf 8856' 8-1/2" 350 sx Class G & 250 s) CS I 24. Perforations open to Production (MD+TVD of Top and 'Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8660'-8654' 8404'-8394' 3-1/2" 8479' 8449' & 8169' 8626'-8616' 8265'-8260' w/12 spf, 8616'-8596' 8285' -8265' 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8596' -85767 w/4 spf, DEPTH INTERVAL. (MD) AMOUNT& KIND OF MATERIAL USED 8576'-8556' 120° phasing 8170' - 8172' 100 sx Class C 8556' -8552' 27. N/A PRODUCTION TEST Date First Production ] Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL_ CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None J L 0 3' 1985 Alaska 0, & G~s Cons. 50rarnissi0n Anchorage Form 10-407 * NOTE: The well was perforated and tubing run on 06/16/85, GRU10/WC02 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .. GEOLOGIC MARKERS ' ' '~ FORMATION'TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8218' N/A N/A Base Upper Sand 8333' N/A · Top Lower Sand 8537' N/A : Base Lower Sand 8675' N/A . . . · : · .. 31, LIST OF ATTACHMENTS .,. Well Historv '.' , 32. I hereby cer:tify that the foregoing is true and correct to the best of my knowledge , , Signed ~.2~ ~ Title Associate Engineer Date //' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and. leases in Alaska. ,- Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for. in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". · ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County, parish or borough [State Alaska North Slope Borough Alaska Field I Loase or Unit IWell no. Kuparuk River ADL 25634 lQ-15 Auth. or W.O. no. ~Title AFE 504777 I Drill Nabors 26-E API 50-029-21308 Operator 1ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 5/6/85 I'°ur 1430 hrs. IPri°rstatusifaW'O' Date and depth as of 8:00 a,m. 5/07/85 5/08/85 5/09/85 5/lO/85 Complete record for each day reported 16" @ 102' 1618', (1516'), Navi-Drl Wt. 9.1, PV 16, YP 18, PH 10, WL 11.4, Sol 6 Accept ri~ @ 0830 hrs, 5/6/85. NU diverter sys. Spud well @ 1430 hrs, 5/6/85. Drl to 496', Navi drl to 1618'. 422', .8°, S47.8E, 422 TVD, 1.7 VS, 2.0S, 2.2E 787', 7.8°, N 0.8W, 786 TVD, 17.6 VS, 16.9N, 8.4E 1150', 17.7°, N10.2E, 1139.6 TVD, 97.4 VS, 96.1N, 18.1E 1329', 23.7°, N8.2E, 1307 TVD, 160.5 VS, 158.5N, 28.3E 16" @ '102' 4440', (2822'), Surv'g Wt. 9.4+, PV 16, YP 12, PH 10, WL,12.2, Sol 8 Drl & surv 12¼" hole to 4440'. 1520', 30.8°, N 7.2E, 1476.7 TVD, 247.9 VS, 1897', 42.5°, N 0.2E, 1776.8 TVD, 474.5 VS, 2581', 46.4°, N 5.2E, 2248.0 TVD, 969.9 VS, 3082', 47.1° 3586', 46.5° 4216', 45.4° 245.1N, 40.0E 471.8N, 51.2E 966.0N, 86.9E , N 7.2E, 2591.2 TVD, 1334.7 VS, 1328.8N, 126.4E , N10.2E, 2936.3 TVD, 1701.6 VS, 1691.9N, 181.9E , N10.2E, 3374.3 TVD, 2153.1VS, 2137.5N, 262.1E 9-5/8" @ 4420' 4440', (0'), NU BOPE Wt. 9 5, PV 16, YP 8 PH 10, WL 10.4, Sol 10 Short trip, C&C hole~ POOH. RnA~-5/8 , 36#, J-55 BTC csg to 4420'. M&P 1200 sx CS III @ 12.2 ppg & 400 sx CS I @ 15.3 ppg. Bump plug. CIP @ 2245 hrs, 5/8/85. ND diverter. NU BOPE. 9-5/8" @ 4420' 6054', (1614'), Drlg Wt. 9.2, PV 10, YP 7, PH 9, WL 10.2, Sol 8 NU & tst BOPE. Drl flts + 10' new hole. Conduct formation tst . 8~" hole to 6054' to 11 5 ppg EMW. Drl & surv a · 4370' 45° NllE, 3482 TVD, 154 VS, 2244N, 282 ' ~ ' 5126' 47. o N7E, 3997'TVD, 428 .VS, 2794N, 350 . ' 5699-', 47.7°', N6E, '4382 TVD, 5~3 'VS, 3216N, 399 .... RECEIVED 56.24% J U L 0 1985 Alaska 0il & Gas Cons. Cu~m~issi0n Anchorage The above is correct Signature ~ see Procedures Manual, Se(~ion 10, Drilling, Pages 86 and 87. Date 6/10/85 ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title I AFE 504777 Nabors 26-E Operator I A.R.Co. W.I. I ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 5/11/85 thru 5/13/85 5/14/85 Accounting cost center code State North Slope Borough Alaska 5/15/s5 ADL 25634 Drill API 50-029-21308 ~olal number of wells (active or inactive) on this [cost center prior to plugging and I 56.24% labandonment of this well I IHour IPrior status If a W.O, 5/6/85 | 143o hrs. I 9-5/8" @ 4420' 8866', (2812'), POOH, LD DP Wt. 9.9, PV 16, YP 7, PH 8.5, WL 5.2, Sol 12 Drl & surv to 8082', CBU, POOH. Chg BHA, TIH, drl to 8731' short trip, wrk tight spots, POOH. Rn DIL/FDC/CNL/GR/CAL f/8721'-4420'. RIH, drl to 8866', C&C. 6198', 47.4°, N4E, 4718 TVD, 3608 VS, 3582, 433 6702', 46.8°, N5E, 5061-TVD, 3977 VS, 3950, 463 7208', 46.8°, N6E, 5408 TVD, 4346 VS, 4317, 500 7709', 45.8°, NSE, 5754 TVD, 4708 VS, 4678, 536 8002', 45.4°, N5E, 5959 TVD, 4917 VS, 4886, 555 IWell no. lQ-15 7" @ 8860' 8866', (0'), Set 7" pack-off Wt. 10.0, PV 14, YP 6, PH 8.5 POH, LD DP. RU & rn 7", 26#, J-55 BTC to 8860'. Cmt w/350 sx C1 "G" w/3% KC1, .7% D-19 & .3% D-31. Displ w/brine. Press inc'd to 3000 psi. Displ 16 bbls short. Flts OK. CIP @ 0145 hrs, 5/14/85. -Set slips, ND BOPE, set pack-off. 7" 6.8860' 8866', (0'), RR Wt. 10.0, PV 14, YP 6, PH 8.5 NU tree. RR @ 0930 hrs, 5/14/85. Old TD Released rig 0930 hrs. Classifications (oil, gas, etc.) Oil Producing method -' ' - . New TD i I P8 Depth ~ Date ' ' ~Kind of rig 5/14/85 J Rotary " Flowing PotentiAl test data I Type completion (single, dual, etc.) "-'t ' . Single. . .~ OIficial reservoir name{s! ~ Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time K I~°{uctil~l ~ V ~ ~) ~1 o~te'~ ' ' - G~s per day .IUL 0 19 5 Pump size, SPM X length Choke size !T.P. C.P. Water % GOR Gravify Allowable Effective date corrected Alask~ Oil & Gas Cons. L;u~l~nission Anchorage The above is correct I iTiUe Signature ,~_ _~lf _ _ _~l~.~l~ Date 6/10/85 Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. ('. Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Q ~~ r;lv ~~'f~ A 1f4I /L- ~ June 13, 1985 Mr. C. V. Chatterton Commissiöner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the following wells: 3B-4 3B-5 3B-6 3B-7 3B-8 1Q-13 1Q-14 1Q-15 1Q-16 1R-5 1R-6 1R-7 2V-13 2V-14 2V-15 2V-16 4-9 (workover) Ll-l 4-13 (workover) LI-10 4-30 L2-24 4-31 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Si ncerely, ta::~~ Associate Engineer JG/tw GRU9/L56 Enclosures RECEIVED JUN 1 41985 Alaska Oil & Gas Cons. CommissIon Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllanllcRlchfleldCompany STATE OF ALASKA '-'-. ALASKA ~..~ AND GAS CONSERVATION CO,.,MlSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well)~[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-46 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21308 4. Location of Well at surface 1087' FNL, 1834' FEL, Sec.26, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 92.4' RKB 6. Lease Designation and Serial No. ADL 25634 ALK 2567 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Q-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. May ,19. 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 1430 hfs, 05/6/85. Drld 12-1/4" hole to 4440'. Ran, cmtd, and tstd 9-5/8" csg. Drld 8-1/2" hole to 8731'. Ran logs. Continued drlg 8-1/2" hole to 8866'TD (5/13/85). PBTD = 8770'. Secured well & RR ~ 0930 hrs, 5/14/85. Arctic packed on 5/22/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set @ 102' Cmtd w/240 sx CS II 9-5/8", 36.0#/ft, J-SS, BTC csg w/shoe ~ 4420'. Cmtd w/1200 sx CS I II & 400 sx CS I. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8856'. Cmtd w/350 sx Class "G" & 250 sx CS I. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/FDC/CNL/GR/Cal f/8721'WLM - 4420' (9-5/8" shoe') 6. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska, 0il & Gas Oons, 60mm~ssior, Anchorage 17. I hereby certify, that the foregoing is true and correct to the best of my knowledge. SIGNED & ~ )~.L/~ j TITLE DATE /! NOTE--Reporl~/on this form is required for each calendar month, reg~'r~e~s~o~ ~h~e~sta~'~Jo~ '~e~tions, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. p¢,r~ ~n..~n4 Submit in duplicate ARCO Alaska, Inc. Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 31, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-15 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1Q-15. I have not yet received a copy of the well history. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU9/L26 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JUN l ;2 1 85 Alaska Oil & Gas Cons. Commission Anchorage - ~-.- STATE OF ALASKA ALASKA, ..AND GAS CONSERVATION CC IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAs [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-46 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21308 4. Location of well at surface 9. Unit or Lease Name 1087' FNL, 1834' FEL, Sec.26, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1Q-15 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i I Pool 92.4' RKBJ ADL 25634 ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I16. No. of Completions 05/06/85 05/13/85 05/14/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8866'MD 8770'MD YES [] NO I~XI N/A feet MD 1400' (Approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Ca 1 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 102' 24" 240 sx CS II 9-5/8" 36.0# J-55 Surf 4420' 12-1/4" 1200 sx CS Ill & 400 s: CS I 7" 26.0# J-55 Surf 8,856' 8-1/2" 350 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED JUN 2 ]98.,5 Alaska 0il & Gas Cons. Co~:imission Allchorm~¢ Form 10-407 GRUg/WCl0 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ' . ,: , ,. ' . ._-- ,~ ,..'- · ., . - · ' ,' , ' : GEOEOGICM RK--A~:ERS' ' " "' ''" FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and' time of each phase. N/^ N/^ · .: · : 31. LIST OF ATTACHMENTS :: : Non~. : , ; - ' 32. I hereby certify that the foregoing is true and.correct to the best of my knowledge ~.. Signed ~ ~ .~..LL~L/~L~' Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. .. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and 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". SUB-SURFACE DIRECTIONAL SURVEY ['~ UIDANCE [~]ONTINUOUS ['~"~OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY , . lQ-15' ¢1087' FNL,_ 1834' FEL. S26. T12N. RqE. K, UPARUK, NORTH SLOPE. AT,~RWA Job Reference No: 70580 Lo~ed By; T. URAM RECEIVED J d L :[ 2 ~.~B5 Anchorage Oate 28-JUNE-1985 Computed CUDNEY GCT DIRECTTONAt SURVEY CUSTOMER bI$1ING FOR ARCO ALASKA, INC, KUPARUK 10o15 KUPARUK NORTH S60PE,AbASKA SURVEY DATE: 13-JUN-B5 ENGINEERI T. URAM METHODS OF COMPUTATION TOO6 60C&TIONl TANGENTIAb- averaged deviation and azimuth ~NTERPOLATION: LINEAR VRHTICAt SECTION~ HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH 0? NORTH 5 DEG 49 MIN EAST ARCO AI,~SKA.(sTN¢o K,,JP R,,K tO KUPARUK NORTH SLODE,AI,ASK~ COMPU?ATION DA?El 28-jUN-85 PAGE ~ DATE.OF SURVEYg 13-dUN-85 BUSHING £DEVATIONI.:' 92.50 ENGINEERI T, URAM INTERPOLATED VALU~ FOR EVEN lO0 FEET OF MEASURED DEPTH TRUE SUB-SEA ~OURS~ MEA$I)R~D VERTICAL VERTICAL DEVIAT ON AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 000 100 O0 200 O0 300 O0 400 oO 500 O0 600 O0 700 O0 800 O0 900 O0 1000 O0 0 O0 100 O0 200 O0 oo 99 4~9 99 599 93 699 66 798 94 897 65 -9~ 50 ? 5O 107 50 ¢07 607 8O5 1.4 29 F: N 15 37 E N 13 58 E 1 1] 57 52, E N 12 31E N 12 12 E 8 43 E 6 53 F. 6 ! g VERTICAL DOGbEG RECTANGUbAR COORDINATES HORZZ, DEPARTURE SECTION $~V~RIT¥ NORTH/SOUTH EAST/WEST DIST,: AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 1100 1200 1300 1400 500 600 1700 1800 1900 0 O0 0 2,4 -0 05 -0 ~3 -0 9 -0 79 2,1.5 9.26 21,24 37,19 O0 1092 O0 1.187 O0 1280 O0 i37.1 O0 1459 O0 1543 O0 1.624 O0 1702 O0 t777 57 74 ~4~ 69 ~90 ~0 2,9O 995 47 90~,97 13 19 30 999,80 16 38 1094,88 '!9 37 62, 1188,12 ~2 55 40 I~8,90 ~6 49 2 1366,72 ]0 11. 9 1451.19 34 7 10 08 27 168477 42 2000.00 1848,34 1755 84 46 18 2100,00 1916.~5 ~ ]5 46 11 2200 O0 1986. 3 13 45 43 2300'00 ~056.34 1963 84 45 58 2400 O0 2125 7~ 2033 ~6 46 , 2500 O0 2195:13 2i02 63 46 2 2600 O0 22R4;49 2,71 09 4b 7 2700 O0 2333.75 2241.25 46 18 2800 O0 9402.69 2310.19 46 31 2900 O0 2471.46 2378,96 46 30 3000 O0 2540,10 2447.69 46 36 3100 O0 2608,80 2516.30 46 4R 3200 O0 ~677,23 2584,73 46 50 3300 O0 2745,36 265~,86 47 9 3400 O0 2813,48 2720.98 46 54 3~00 O0 28~1.~ 2789.41 46 3R 3600'00 2950.,, 2~58.27 46 q 3700:00 3020,~ 2927.~1 46 14 3800 O0 3089, 2996. 8 46 7 3900:00 3158,66 3066.16 45 58 348 81 411 75 478 23 N 8 11 ~ 548 55 N 10 19 E 621 22 N 10 39 F 69~ 61 N tO 45 ~ 764 05 N 10 47 ~ 835 76 N 10 50 E 90750 N il 3 F 979 26 N 1~ 10 E 1051 08 N 11 18 ~ 1123.2,0 N 11 54 E 119~.44 N 12 19 E 1267 64 ~ 13 11 ~ 1339 84 N 14 33 ~ 141~ 09 N 15 27 ~ 148431 N i§ 48 ~ 1556 42 N 15 47 g 2628 24 N 16 25 ~ 1699 63 N 16 40 E 1841 {l N 16 23 g 1912,08 O0 51 O8 8o 46' 1 93 4 71 2 79 2 85 4 31 3 22 3 9'/ 2 72 3 4O 4 47 2 35 0 33 0 33 0 52 o 0 0 29 0 48 0 5~ 0 45 0 38 0 0 61 0 ~? 0 43 0 00. N 0 23 N O 095 0 O985 83 N 83 N 20 75 N 36 58 N $6 79 N 80 84 N 110 72 N 145 89 N 62 N 342 67 N 4O5 12 N 471 '17 ~ 000 F, 0 07 E 0 40 E 8 0t4E 4 0 E ! E 12 26 £ 824 895 965 1036 11 44 77 86 93 N 41 N 153 14 N 169 65 N 71 M 2O9 84 ~ 223 82 N 1 1249 86 N 238 1532 60 167t 1 174 181~ 1879 79 N 67 N ~5472 N 91 67 N 350 77 N 90 N 412 0 00 N 0 F N 17 20 g i,.! 10 1½ 4'¸ 41 S .77 42 K 93 S 56 SO E N~ 6 2 E 41 S i2 2 E 58,09 N 12 11 E ~5 E I N 13 37 E 02 E I 04 N ) 46 E 293;20 N 1~: 18 E O0 E 414,15 N ! 59 E 58 E 480,38 N 11 14 ~ 75 E 550 98 E 623 09 £ 694 37 E 766 87 £ O~ E 982 O0 £ 1054 05 E 1127 60 £ 1199 N 1 9666 N I032 E 34 65 N I E 66 N 1035 E N ~0 4~ ~ N lO 44 E 81 ~ 1272 4'/ N 10 49 E N 10 55 97 1345 14 E 1418 39 ~ 1491. 20 E 1564 02 E 1636 93 E 1709 '69 E 1780 37 g 1852 87 E 1924 05 N 11 04 N 1128 E 76 N 1t ~0 E 08 N I 0 E 86 N 1 71 N 1 COMPUTATION DATr,= 28-JUN-85 ," 4 PAGE 9_ ARCO AbASKA TNC, DATE OF SURVEYI 13-JUN-85 KUPARUK 1~-15 KELbY BUSHING EbEVATXONI KUPARUK NORTH SLOPE,ALASKA ENGiNEERI ~,' URAM INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COU~$r VERTICAb DOGLEG RE~ANGUbAR COORDINATES HOR'XZ..~ DEPARTURE MZASURFD VERTICAL VERTTCAb DEVIATION AZIMUTH SECTION SEVERITY NO.~H/3OUTH ER&T/WEST DIST.': AZIMUTH DEPTH DEPTH DEPTH DEG MIN [)EG MIN FEET FEET F~ET FEET.' DEG MXN 4000 O0 32~8 17 3135 67 45 52 4'00'00 3719 33 ]~ 83 47 23 4800'00 379& 97 47 47 18 4900:00 3854 52 3762 02 47 39 5000 O0 3921 8~ 3829,38 47 39 5100 O0 3989 22 3896,72 47 41. 5200 O0 4056 49 3963,99 47 41 5300 O0 4123 90 403!.40 47 33 5400 O0 4191 31 4098.81 47 35 5500 O0 4258 83 4166.33 47 19 5600 O0 4326 55 4~34.05 47 25 5,00 00 4394 ~? 430i 69 47 25 5800 O0 44'61.. 4369:41 47 4 5g00 O0 4530 07 4437.57 47 6 6000 O0 4598 11 4505 61 47 7 6100 O0 4666 13 4573 63 47 12 04 4641 81 4709 54 4777 57 4~45 O0 4013 83 4982 81 5051 96 5120 54 47 1~ 31 47 22 04 07 15 07 46 56 50 46 40 33 46 30 31 46 15 46 46 9 6200 O0 4734 630O 00 4801 6400 O0 4869 6500 O0 4937 660O O0 5006 6700 O0 5074 6800.00 5143 69OO.OO 52i2 7000.00 5282 21 9189 71 46 14 7100 O0 5351 24 5258 74 46 27 7200~00 06 5327 56 46 38 77 5396 ~7 46 34 52 5465 02 46 40 38 5533 88 46 17 61 5603 11 45 59 20 5672 70 45 49 44 5742 94 45 6 14 5813.64 44 5~ H 16 30 E 1982.72 ~ 16 31E 2053.06 ~ 16 40 E 2122 9! ~ 16 37 F 2192 34 ~ 16 46 E 2261 44 ~ ,6 26 ~ 2330 48 , 16 11 E 2400 78 ~ '.3 11 r 24 73 03 ~ 12 44 E 2546 15 N 12 52 £ 2619 34 ~ 12 47 E 2692 70 ~ 12 46 E 2766 ~ 12 48 E 2839 ~ 12 46 E 2912 N 12 35 E ~ 12 31 E 3132 ~ 12 3 ~ 3205 ~ li 4 ~ 3278 ~ 10 35 ~ 3351 08 52 94 17 67 '/6 N 10 2~ E 3424 80 ~ 10 21 E 3497 ~ 10 14 E 3571 ~ 10 21 E 3644 ~ lO 25 E 3717 ~ 10 39 E 379n ~ 10 54 E 3863 Nll lg E 3935 ~ 11 35 E 4007 N 11 41E 40 79 86 04 35 67 54 N 11 39 E '4151 29 N 11 27 E 4223 N 11 24 E 4295 N 11 29 E 4367 N 11 34 E 4440 V 11 26 E 4512 ~ 11 12 g 4584 ~ 10 52 ~ 4655 ~ 10 41 ~ 4726 ~ 10 31 ~ 4,96 28 47 78 04 19 O1 53 44 92 92,50 FT 5420 7300 O0 5488 7400 O0 5557 7500 O0 5626 7600 O0 5605 7700 O0 5765 7800 O0 5'835 7900 O0 590b DEC/100 0 81 1948 84 N 43~ ~2 E 1996 ~ N 1~ 31 E 0 15 2017 46 N 45 2 E 2067 t N I40 E 1 8i 2356 70 N 554 55 E 2421 06 N 13 1 641 56 3 N 622 18 E 2715 47 N 13 14 E 0 33 2643 ']2 ~ 2 89 '39 N 13 14 2 ~ N 638 55 63 1 E 29 1 12 E 53 2859 50 N' 67 E I N ' ~ 86 N13 11E 0 28 3003 ~6 N 0 9 3075 ~35 68 E 5 3 0 ~5 ~ '33 . 34 E 3 32 09 N 3 E 1,71 35 N 7S0 40 g 3305 6~ N 13 ~ E 0,63 3291 25 N 763 97 E 3378 75 N 13 4 E o 09 . 6o s25 o . soo oa 4150 44 ~ 914.71 41 , , , 12 48 . 987.09 45 . 12 ~.~ 4505.70 ~ 1001.33 ~ 46~,63 12 , 4576,19 1015,07 42 ~,~ 4646,.11 47 56 12 , 4715 6] ~ 1028,37 , 48 , 12 7 KUPARI.IK 10-{5 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE8 28-JUN-85 PAGE DATE OF SURVEY1 13-JUN-85 KELLY RUSHING EbEVATZONI , ENGINEERI T, ?,URAM INTERPOLATED VA[,UE~ FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUR-SEA COURSE MEA$11RED V£RTICAT., V£RTICAb DEVIATION AZIMUTH DEPTH DEPTil DEPTH DEG 8000 DO 597b 71 5884,~9~ 458 8100:00 6047 39 5954, 45 6 S~CTION sre:vgR:]:T¥ FEET DEG/IO0 N 10 50 E 4867.52 ~ 11 29 E 4937 98 N 13 9 E 5008 fl2 N 13 7 E 5080 27 N 12 59 E 5152 76 N 12 59 E 5226 52 091 I 69 013 04 0 84 0 O0 O0 oo 8300 O0 6196 8400 O0 6255 8500 O0 63~1 8600 O0 6387 8700 O0 6451 8800,00 6515 8866,00 6558 N 42 . 503, RECTANGUbAR COORDINAT£$ HOR! NORTH/SOUTH EAST/WEST FEET FEET 4785 4854 4924 4994 5065 5410 72 N t0 37 N 108 49 N 109; 68 N 1116 :~2 N 1132 0 N 1150 .20 N ! 67 8O N t~65 04 N 1197 45 E 49o8: 86 E 497 E 5114, E 5261 09'E 5316 72 E 5413 9~ E 5490 91 E'5541, 82 08 6162 97 6229 71 6295 80 6359 86 6423 14 6465 46 58 47 30 47 48 29 21 49 33 3O 50 9 36 50 q 64 50 q 92,50 ,r~ DEPARTURE AZIMUTH DEG N 12 : 109 a 14 N t-22 N . N 12 ~5 E ~4 E !4 E ARCO AbA~KA INC, KUPARIIK 1(3-{5 KUPARUK NORTH SLOPE,A[JASKA COMPUTATION DAT~ 28-dUN-85 PAGE, DATE OF SURVEY~ 13-dUN-85 KELb¥ BUSHTNG EbEVATION~ ENGINEERI T,, DRAM iNTERPOLATED VALUE6 FOR EVEN 1000 FEET OF MEASURED DEPT TRU~ SUB-SEA C~URSE MBASUR~O VERTICAL VEST,CAb D~VIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 84 46 8 69 46 ~6 45 5~ 61 47 7 71 46 14 21 45 ~ 64 50 ~ -92 47 902 34 1755 3135 88 3829 11 4505 21 5189 71 5884 14 6465 .92,50 FT 45 12 81 1948 3~ ~64 55 40 9 91 4785 O0 5410 N 0,2 86 ~ 23 N 43 81 ~ 62 56 N 914 26 N 1054 04 N 1197 0 O0 ~ 0 26 E 58 75 E 55O 22 E 1 ,£ 2715 71E 4180 4~ E 4900 91E 5541 0 N 0 0 E 9 N 1~2 11 E ',~½ N 10 49 E N .~.0 39 E 41 N 31 E 5 N 12 3[. 6 N 12 25 E 08 N 12 29 g 0 O0 0 O0 1000100 995 2000,00 1848 3000,00 2540 4000 O0 3228 5000 O0 3921 6000 O0 4598 ?000 O0 5282 8000 O0 5976 8066 O0 6558 ~ 0 0 E 0.00 ~ 14 29 ~ 57 74 N 8 11E 548 55 ~ 12 19 E 1267 64 ~ 16 30 ~ 1982 72 ~ 12 47 E 269? ~0 N 10 28 E 3424 80 N 11 39 E 4151 29 N 10 50 E 4867.52 ~l 13 42 g 5503.63 VERTICAb DOGbEG RECTANGUbAR COORDINATES HORIZ,' DEPARTURE SECTION SEVERITY NORTH/$OUTIt EAST/WEST DIST,. AZIMUTH F~ET DEG/IO0 FEET rEtT ,FEET DEG ~IN ARCO ~{.,~ SKA K[IPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTIC~b DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M~N o oo g~'~O 9 192'50 192 ~9~:so 292 392,51 392 492,5! 4~2 592,56 592 692,81 ~92 793,50 92 894,77 892 O0 5O 5O 5O 5O 5O 5O 5O 5O 5O PAGE 5 COMPUTATION DATE: 28-dUN-85 DATE OF SURVEY1 13-dUN-85 KELbY BUSHING EbEVR?IONI ENG'INEERI T,' URRM INTERPDLA?ED VALUES FOR EVEN 100 FEET DF SUB~SER DEPTH VERT~CRb DO,bEG RECTANGUbRR COORDINR~ES HORZ~,~DEPARTURE SECTION SEVERITY NORTH/SOUTH ,ERST/WE~T' DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET' DE~ -92 50 O O0 lO0 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 0,00 0,24 -0,02 -0.40 -0 77 -0 83 8 59 20 2 36 ]7 996.04 992 50 900 O0 13 15 1100.~0 1092 50 1000 O0 164 1205.43 1192 50 1100 00 19 46 1]1~.92. 1292 50 1200 00 23 lm 1423,75 1392 50 1300 00 2747 1 538.~8 1402 50 1400.00 31 56 659,56 1592 50 1500.00 35 58 1786.68 169~ ~g 180~,00 40 24 920,00 179 70 ,00 43 43 2064,57 1892,50 1800.00 46 48 57 04 82 39 114 68 153 73 200 98 324 4O3 03 2208 40 19~'50 lO00 00 45 41 2496 2640 40 229250 2~00,00 46 7 2785 19 2392 50 2]00,00 46 29 2930 60 2492 50 2400,00 46 35 3076 ~9 2592 50 2500,00 46 44 3222 33 2692 50 2600,00 46 56 3369 24 2792 50 2700,00 47 4 3515:41 2892 50 2800.00 46 37 3660.26 2992.50 2900 00 46 17 3804 64 309250 3000 00 46 6 3948 72 3192 50 3100 O0 46 0 15 3292 50 ~4 33O2 50 3300 320 O0 45 33 0 O0 44 57 28 3492 50 3400 O0 44 38 98 3592 50 3500,00 45 21 42 3692 50 3600,00 47 12 15 3702 50 3700.00 47 21 40 3892,50 3800,00 47 39 492 55 595,57 N l0 40 E 698,61 N 10 48 E 801,40 N 10 50 E 904,78 ~ II 11 E 1008,24 ~ 11 14 g 1117,51 N 11 59 E 1217,52 ~ 13 7 E 1322,64 N 15 5 E 1428,18 ~ 15 47 E 1534,27 N 15 47 E 1639,27 4092 4234 437~ 451 4660 4808 4956 0 00 0 50 0 08 0 12 0 2 ,55 1,79 2,72 1,98 4,72 2 77 3 4 .1~ 4 53 4 58 4 86 1,24 0 59 0 O9 0 27 0 33 0 48 0 17 0 42 1 36 0 33 0 O7 0 74 0 85 0 62 0 20 0 69 0 93 I 22 2 77 0 78 0 40 0 0 0 0 0 ! 19 35 00 N 23 !~ O5 8 48 $ 89 $ 16 ~ 8,~ 0,00 E 0,06 E 0,37 g 0,75 E I 20 E. ! 78 'E 4 92,50 56 10 N . 12 08 E 8O 11 4~5 58? 57, 39 N 12 9 £ 90 N 50 N 27 84 N 36 19 N 47 76 N 60 83.N 74 9 N 84 ~l N 95 50 N 109 85 E 83 29 E 115 17 E 155 44 ~ 202 08 E 4 41 E 59 06 N. 1,~ 6 E 76 N 13 38 E N 1 I E N I 5 E N 11 4 E 60 N 10 32 E 689 790 892 994 t097 2O0 1303 1407 1511 1613 16 28 46 66 18 N 206 57 ~ 2~8 72 N i°5 34 2O 87 E 21 E 12 02 E 1327 32 E 1434 07 E 154 07 E 164{ 52 N 10 40 E 07 N 10 45 E 85 N 10 ~3 - 29 N li 6 ) 61 N ll 24 ~' 1714 30 N 1913 2012 2108 220 229~ 2399 2505 2611 52 N 422 09 N 45 82 N 48g 12 N 509 98 N 537 5 N 566 '~1N 590 81N 615 42 E 1752 40 N 11 58 E 34 E 1856 76 E 1959 02 E 2062 87 E 2162 34 E 2262 6O E 2361 28 E 2465 72 E 2573 04 E 2683 22 N 12 14 E 67 N 12 27 24 N 12 39 E 96 N 12 50 E 20 N 13 0 E O0 N 13 9 E 08 N 13 16 E 82 N 13 16 E 25 N 13 15 E N 16 48 E 1742,32 N 16 40 E 1844,60 ~ 16 26 E 1946,53 N 16 32 E 2047,55 N 16 45 E 2146,72 ~ t6 40 E 2244.41 ~ 16 25 ~ 2341,64 N 14 26 E 2444,21 ~ 12 46 E 2552,10 ~ 12 49 E 2660,72 ARCO AbASKA INC, KUPARUK KUPARUK NORTII SLOPE,ALASKA TRUE SUB-SEA COURSE VER?ICAb VBRTICAb DEVIATION AZIMUTH s o4 50 ). oo oo 525 .4o :5o ooo oo 47 5401 5549 5697 5844 5991. 6138 6286 6433 ?7 4192,50 4100 ?0 4292,50 4200 50 4392 50 4300 87 4492 50 440 0 ,oo 92 50 4600 26 4792 50 4700 83 4892 50 4800 6580,3! 6725,66 6870,44 7014,~7 7159,93 7305.42 7450,90 7595.52 7739,03 7880,72 8022 37 5992.50 5900,00 8]64 23 6092,50 6000,00 830~ 24 6192,50 6100,00 845.5 63 6292,50 6200,00 8607 ]9 6392,50 6~00,00 876] 53 6492,50 6400,00 8866 O0 6558,14 6465,64 00 47 35 00 47 22 00 47 25 00 46 59 00 47 00 47 12 00 47 20 00 47 16 4992 50 4900,00 46 5092 50 5000,00 46 25 5192 50 5100,00 46 17 5292 50 5200,00 46 16 5392 50 5300,00 4629 5492 50 5400,00 46 5592 50 5500,00 46 29 5692 50 5600,00 46 5792 50 5700,00 45 5892 50 5800,00 44 55 45 4 45 30 46 31 48 5 49 39 50 50 N 12 46 E 2760 65 N 12 50 E 2078 N 12 35 ~ 298? N 12 36 g 3095 N 12 3 E 3203 N 10 40 E 3311 N lO 28 E 3418 N lO 18 E 3526 N lO 19 E 3634 N'lO 29 E ~742 75 47 73 84 56 26 46 N 10 49 E 3849 N 11 23 E 3954 N 11 44 E 4058 31 N 11 37 E 416! 97 N 11 26 E 4266 53 ~ 11 29 E 4371 69 ~ 11 33 E 4476 83 N il 13 E 4580,80 N 10 47 £ 4683,31 N 10 28 £ 4783,35 N lO ~8 E 4883 30 N 12 39 E 4983 43 ~ 13 8 E 5086 20 N 12 51 E 5193 61 n 13 4 E 5306 84 N ~3 42 E 5425 68 N !3 42 E 5503 63 0 24 0 21 0 64 0 21 0 32 0 6O 013 0 61 0 32 0 I3 0 46 0 44 0 54 0 79 0 47 013 0 62 0 60 0 81 0 23 0 38 ! 8O 0 59 I 6O I 27 0 O0 0 O0 303~ 314! 3 346 357~ 3676 378 388~ 3988 4090 4193 4296 4400 4502 4603 4702 83 N 639,35 E 2792,99 N 13 13 E 02 N 663,69 E' 2902,91 N 13 12 E 84 N 687,84 E 3012,42 N 13 11E 23 N 711,63 E 3121..43: N 1310 E N 734,95 E 3230, N 13 9 E 3338, t3 36 N 77 . 344S~94 N t3 43 N 79 , 35~3e6~' ~ 97 N 854 40 E 3877 28 N 12 43 E 47 N 874 03 N 895 08 N 916 04 N 93 54 N 1000 25 N 10 72 E 3982 75 E 4087 88 E 4191 88 g 4296 87 E 4402 Ol E 4507 70 E 4612 32 E 4715 84 E 4815 39 N i E 59 N 1~ 38 E 65 N 12 ,36 E 30 N 4O N 1~ 31 E 29 N 12 29 K 63 N 12 27 E 4800 82 N 1057 44 E 4915,89 N 12 25 E 4899 43 N 1077 44 E 5016,50 N 12 24 E 5000 32 N 1101 09 E 5120.11 N12 25 E 510579 N 11~5 53 E 5228,38 N 12. 25 E 52i6 98 N 11~1 37 E 5342,52 N 12 26 E 79 27 E 546 41 N12 28 E 5333 59 ~ 11 2, 5410 04 N 1197 9t E 5541e08 ~ 12 27 ~ / COMPUTATION DATE{ 28-JUN-85 DATE'OF SURVEY{ 13-JUN-S5 KEbbY BUSHING EbEVATIONI 92,50 FT ENGINEER{ T, URAM INTERPOLATED VA[.,UF$ FOR EVEN ~00 FEE~ OF SUB-SEA DEPTH VERTICAL DOGbEG RFCTANGUbAR COORDINATES HOR[Z,:. DEPARTURE . SECTION SEVERITY NORTH/8OUTH EA$T/WE$~ DI8T, DEG MIN FEET DEG/tO0 FEET FEET FEET DEG MARKER TOP UPPER SAND BA$~ UPPER RAND TOP bOWFR SAND BASE bOWER SAND PRTD COMPUTATION DA~ 28-JUN-B5 INT£RPOI, ATBD VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 8075 00 8770 00 9866 00 ', PAGE DATE OF SURVEYi 13'JUN-85 KELLY BUSH~NG,EIaEVATION~ 92,50 FT gNGINEERI T, URAM SURFACE LOCATION AT' ORIGIN= I087' FNb,18]4' FEb. SEC 26.TI2N. TVD RECTANGUbAR COORDiN~9E'UM,TES FROM KB SUB-SEA NORTH/8OUTH '&AST/WEST 6130 05 6209 51 6346 45 6435 77 6496 6037 55 6 ! O! 6343 27 6404 15 6465 64 4936,92 N 5017.84 N 5t65.i4 N 5267,57 N 5338,42 N 5410.04 N ~05.19 139,22 163,22 1197,91 ARCh Ab~$KA TNC, KUP~RI~K NORTH MARKER ~Op UPPER BAND BASE UPPER ~AND TOP bOWeR 6AND BASE LOWER SAND PRTD Tn COMPUTA?ION DA~i 2B'JUN-SS M~ASURBD DEPTH *333 , 877 0 886~ 0 DA?g Or SURV£¥: 13-dUN-85 ,/'" KBLb¥ BUAH~NG EDEVATIONI,- '92,5'0 .rT BNGIN~ER'I ~· URAM ~UMMAR¥ FROM KB SUB-SEA 6130 05 6346 45 6435 77 6496 65 6~58 14 6037 55 61i,70t 6 95 640~ 29 6465 64 NOR:tH/SOUTH igA&TYW£ST N 086 541 04 N 1180 ,t3 E 9! TRU~ SUB-SEA MFASURED V~RTICAL VERTICAb D£PTH DFPTH DEPTH 8866,00 6558,i4 6465,64 HORTZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MTN 5541,08 N 12 29 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL l[g-lS F t ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 13-JUN-SS REFERENCE 00017'/OS00 185. WELL NAME: lQ-15 SURFACE LOCATION/-'~.087' FNL, 1834' FEL, S26, T12~ ~9E, UM VERTICAL PROJECTION . . -1000 0 0 - !000 ~000 ' 31300 4000 ~000 S000 ?000 5, PROJECTION ON VERTICAL PLANE g. - 185. SClLEO IN VERTICAL OEPTHS HORIZ SCALE = 1/1000 IN/FT WELL NAME: lQ-15 SURFACE LOCATION:' 087' FNL, 1834' FEL, S26, T12~ 19E, UM HORIZONTAL PROJECTION ~I~?H ?000 R£F 000070S80 6OOO S000 4OOO 9000 ~000 1000 $0U?H - ! 000 SCALE = 1/I000 IN/FT : , : : : : : : : [ : , [ ! [ : : : : : ~ : : : : : , : , : : i ~ ~ : [ : ~ [ [ ~ : I ! : : : : : : : : : , , : : , +-~%~. -HH~H+%t-H .-~-b-~-~-H -++-H~+-~-.++- ~.+~--~-e~-- -Hi~4-.i-Hb-HH -~ ~..i- - b-~.-~~ ~-~"~ ..... 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LLL.LII.4._L.LL ~~'~-F~'~~'~ I ~ i :~ ~}~ ~ ~ i ~3--~-~YY~"-~'"T-~T"~-~?Y'~ ..... ~"~T"~"T"~-Y'?'r" d"~'?T-~'~?~'~~'-~'"~ ~ ~ ~ i~,~ ~ H ~ ~~=-~'?'?r'r'?"~?'?r'T-F~-'~'-?'i'"~-~TH'T':'"?' -??-~-?"~"?"~'"~" '~'"??-?"~"~"?-'?'~- ~-~'~'~ ~ ~ . , . :- ~'"?'?"*-'~"~-~-~'- '-~-?-?-'~-t"~'"?'"?-?"' '"?'"?"~'"?'"~'"?"'?'-?'~ ...... ~"~-?"~"~'"?"~""~'"~'" !'"11-: T"~I---!'"rI-T": 1?t ~'~I-~'"I'~i ~ ~ ~ ~ i i~ i i ~-!- : 71" -~ ~'~'I-I'~? T'-'~ I'~'-? , ? T'T"? ?"~'T'I' .-~'i"I"'~' -t'"i-i-fd-"f'-tt-!--f'ff-f~tff~-!?-ffr-t--i-t?tf--fff-i i i ?ff-ff~- ~ ~--t-i--~-f?~-t--f-%~-i-i--f--t-.?. r"f"f"f'-~"i'l ~"-t"!'-'! ...... i-i-+"f"f"i"+'+"~" -t't"~d'"tdl"t't't'-t't't'tlPt''~'?''f''t't'tff'Tff-t'~''' "~~ ~--ff?f''f'?'lt'?'''''t't't'i"t'f'l?'>t'r'<l'''>'t'''~'''1' ~"'~'''t't' "t"'t'~ <'''t'''~ ...... : ....... ''illlL'L~'I'i'I'LILL'L--LI'LILZLLLL'LL'Li--LL'LLLLL ''lM'''LLi--'i''i'4''ll ...... LLLLIL'L'LLL''''L'LLM'''IL'L'i--I'; ...... L'LILIL'LLL'L'; ....... LLL'L'LL'LL; -3000 -2000 - 1000 0 ! 000 2000 3000 4000 SO00 NEST EP, ST Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. 0P~,mC'TOR, ~L~NA~. ANb / Reports and Materials to be received by: ~--/~.~---~,_~c Date - Re'q'uired Date Received Remarks Completion.... ... .,Rep°rt V.~...~ ~ . _/~.. _- ~.~. ~/:. Well History ,~----~' Samples Core Chips Core Description ' ' ' Registered Survey Plat,, urve Directional Survey '" Production Test Reports tog aun~~ .... .MEMORANuUM State Alaska ALASKA OIL A~.rD GAS CONSERVATION COI~4ISSION ' ~ DATE: TO: C.V. (terton Chai ,. FILE NO: T~LRU; Lonrlie C. Smith ~i~ ~'''':'~'~ TELEPHONE NO: Commissioner May 13, 1985 D.EWS. 34 FROM: Petroleum Inspecto~.~.-'- SUBJECT: Witness BOPE Test on ARCO' s Kuparuk lQ-15, Sec. 26, T12N,R9E,UM, Permit No. 85-46, Nabors Rig 26E. Wednesday, May_ 8, 1985: I traveled this date from ARCO's Kuparuk IR-6,' (SubjeC~ of' another report) to ARCO's lQ-15, Nabors Rig 26E, to witness a BOPE test. The drilling contractor was in the process of running casing. Thursday, May 9. 1985: The BOPE test commenced at 8:15 am and was c-~.cl~ded At:9':~-0 am. There Were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk lQ-15, Nabors Rig 26E. Attachment 02-00IA(Rev. t0179) O&G 5184 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMblISSION B.O.P.E. Inspection Report Inspector 'Operator .~-_~ ~' We~ / ~--~ Location: Sec Drilling Contractor W~ R q6 ~M Ri w~ ! ~-i g Representative Permit t! . ~,5''~ ~/~ Casing Set @ ~~ .ft. ¢5/~. :entative ~, Z//~/d]d~ '" Location, General D~ Well Sign General Housekeeping O~ Rig O~-~ Reserve Pit O/<- ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure 3/09 psig 1700 psig / Mud. Sys.tems. Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio · , .OK BOPE S tack ~n~~revent er 0/~ Blind Rams 6 Choke Line Valves .~Valve O~ ill Line Valves ~ Check Valve Test Pressure 00 ~ . , Test Results: Failures Pump incr. clos. pres. 200 psig. O m~:in31 sec. Fu~ll C_barge Pres~.ure_ A%ai~d: ~"~in. ~$ sec. N2/JZJ~ ~o if'Ir) 1%~, if, o, ~1~o ~1~ psig Controls: Maste~ ~emo~e Z~ ~n~ s~i~c, cov'~'~ WiS _ Kelly and Floor Safety Valves Upper Kelly, O~t-/Test Pressure . Lower Kelly, {3~ T/est Pressure ~OOo Ball-Type ~ ~est Pressure Inside BOP 0 ~ '~est Pressure Choke Manifold_O~'~est Pressure ~o. Va~.ws ~ ~o. ~"an~s3':1 Adjustable Chokes ~ ~ ~ ~ ~-- Hvdrauicall7 operated choke I ~f~ Test Time _~_ hrs. ~ ~ ~, Repair or Replacement 'of failed equipment to be made within ~/~ days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor March 18, 1985. Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit lQ-15 ARCO Alaska, Inc. Permit No. 85-46 Sur. Loc. 1087'FNL, 1834'FEL, Sec. 26, T12N~, R9E, UM. Btmhole Loc.- 983'FNL, 1286'FEL, Sec. 23, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter sur~eys. Many rivers in Alaska and their .drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing opera-tions you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewzn Kuparuk River Unit lQ-15 -2- March 18, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipmemt so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipmemt installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very. truly yours, / /.r t// /? / _' C. V. Chattertbn Chairman of Alaska Oil and Gas Conservation Co~mission BY ORDER OF ~E COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. L~ery ARCO Alaska, Inc. ' Post Office B(., 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 25, 1'985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kupaurk 1Q-15 Dear Mr. Chatterton- Enclosed are' I o An application for Permit to Drill KuparukfQ-15, along a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore with o A proximity plat o A diagram and description system ° A diagram and description of the surface hole diverter of the BOP equipment We estimate spudding this well on April 17, 1985. If you have any questions, please call me at 263-4970. Sincerely, A~~B.~~_~.~ea.Driqling Engineer' JBK/LWK/tw PD/L46 Enclosures RECEIVED -- Anchor~o ARCO Alaska, !nc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (./iL AND GAS CONSERVATION CO~,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] ST. R A T I C_zR A~PI~I I,C ~ RECEIVED MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. ¢',,,-,,, !i 1905' 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 Alaska 011 & GaS COILS, C0ml]l[ Anchorage ...... 4. Location of well at surface 1087' FNL, 1834' FEL, Sec.26, T12N, R9E, UM At top of proposed producing interval 1450' FNL, 1333' FEL, Sec.23, T12N, RgE, UM At total depth 983' FNL, 1286' FEL, Sec.23, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 92.4', PAD 55.4' 6. Lease designation and serial no. ADL 25634 ALK 2567 9. Unit or lease name Kuparuk River Unit 10. Well number 1Q-15 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8731' MD, 6516' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 1087 feet 17. Number of acres in lease feet 2560+ 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 1Q-16well 60' @ surface feet 18. Approximate spud date 04/17/85 2859 3283 psig@ 80°F Surface psig@ F,_%77 ft. TD (TVD) i SI~E j Hole Casing i24" 116" 12-1/4" I 9-5/8" 8-1/2" I 7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH MD TOP TVD 80' 36' 4188' 36' I I 36' I 36' 8696' I 35' I 35' MD BOTTOM TVD 1161 116' 42241 3392' 1 8731{ 6516' I QUANTITY OF CEMENT (include stage data) ± 200 cf 1100 sx CS III & 450 sx CS I 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8731' MD (6516' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2859 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 1Q-15 will be 60' away from 1Q-16 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be (see attached sheet) 23. I hereby cert, j.~ that the foregoing is true and correct to the best of my knowledge SIGNED .~'~/~'~'.f~"'".- - - TITLE Area Drilling Engineer The space'~w'o~~sion us~' CONDITIONS OF APPROVAL Samples required I-lYES ~O Permit number APPROVED BY Mud Iogrequired I Directional Survey required I APl number E]YES ~[~O [ ~-YES •NO I 50- ~ t. ~ Approval date ~ , o3/ 8/ 5 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March ] R, ] 9R5 by order of the Commission Form 10401 (LWK) PD/PD46 Submit in triplicate PERMIT TO DRILL 1Q-15 completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ~~-- .,~ __:-~ ~ , ~ ~ ~ ~ . . ~ . , :-~-~-'~-:-':~ .... ~ ~ ...... PAD-1 Q;~'-WELL- N0'~'-15 :'i PROPOSEDY:~ - --::::~:Z:~:' 5~-:'~:-::::::~: ::~::~C~i::X- KUP ARUK'/FI ELD.-NORTH'} SLOPE,-.-ALASKA ~ . _ ~ . . = _ . . . - _: · ' · ' ' : ' : ' - : ..... ~ i ' ; ~ ~ - ~ .... _ . - ~ . · ~ ~ ~--:--! ' .~:-, ~':-~'-'~--_-:-T:?~..-_.-?-:'7TT- i ~ '~:~~; .~ ~ ?~T'~-~7[~F~r ~--~:-~.~~ .... ~F:'" ~" '..L~ ....... ~: ...... .ARCO~ALASKA,--~NC, ,~--~ ~-~,-%-~:-~-:~'--:"~I ': ........ ~ ....... ;': ....... ;: ...... ~:'-':T ....... : .......... ': - - ~:~-Z- - ~UPARUK-; FI ELD-~-~NOE~H- S~OPE~-~-AL-A~KA---7-~-~~--======================= ...... ' ..... T : '-T ........ ~:: ~ : ~ : ' ~T';-'?'~ ........ ~ ..... : .... ~V- - ..................... '. - _ ~: : - _ A , . _,,~ ............................'~ ~ ~ - ~. ~ . · __~. ~ : .~.~ · · ~_:.~:.,~ ' ~ ' ...... : :~ ~-: .......... ~L--:-:'--%: .... : .__' .......;_.~.._:. ............. ~ ......... ..... - ~ : . 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' . - .... -'--:~-~ ...... : ........ :- T::--' ~- --45-~ EOC'--~ TVD=!877-'?"~D=2038-'DEP=S86 ............ : .... ~ ..... :'" :"., '- ~ .......... :""7-- · · .... t . , : , ' : j · ' ; . ~ , ' :"-:--~:::--: ........... 7':---'~: .:?.::::~:___~_~..__._._ ~::-~:~::-:: TOP: U~NULSNDS_L::_ TVB~22.92-..T~D~2637 DEP= 1:01 8. '_:: '. :.:.____~:~ -~::- '-_ ~ ....... ~~ ~~~.- _::: :: _: - : :L::..: :: _:Ti:..:::': .. _~ : ~_ : :-:: .::L: : ~:::::. :~-::~:--:-~::' ? : .:. ;_T_..: T:'.: ..:.: - -. '_ ~ :~ -:. '-._ .-'.'": _..: :; '" _: _: :': -." '~- - . --~u~~~~p-~u: S.K-;-~D~;-~T~~.2.-~TMD-~7 t9--DEP-t--798 ::::_:-%-~ :::~ :, :::_::~::_: :'--:_:. ::: :::~: ::~~:~::_. :::7: ~:::: :: :-: _. · ::~ ....................... ~ ............... : .~___~ ..... - ........ : ....... :_.__~ ................ :.~.~_~ ................. ~ ................... ~ .......... . ...... . ......... '._ . ~ .......... ...... : ; _ · : ~ ' : -. :-:% ~ -: ...... ~ ......... ~-. :--... ....... ,, ........ , · ..... ~ .......... :-:-;.TARGET CNT.-' 'TVD~6190 .T,D=B261 DEP=SOZ~ ........... ~ .... ~ ....... : ..... ~ .......... TOP LO~R SNDS ....TVD=6255 T~D=~355 DEP=51~l - ~"~ ~ ...... ~ .................. TD (LO~G[NG PT) T:VD=~16'T~D=BT~i D~P=5~12 ' " ' ........ ~ ........ ~ ........ ~ t ......... · - ~ ...... ~ . ~ - . ~ -~ - · ~ ; · '--:;::--{-::,-:---':- --::0:--- : :; '--- ..... ~ooo' ~ .....:-~ ~ooo"!, _.;'-.-~ooo ' 4ooo sooo sooo ....... ~ ........ . _~ -~.~ ........ ~ ....... ~ ....... ~ .' . ~ ....... . . _ ..... .......... ~ ....... ~ ....... ~- ,- .... .... . ..... ~ ~- ~ . A 5. u. rface Diver-.er S,vstee, 15"-2000 psi Tank¢o starting hea¢. Tankco quick connect assy. 16" X 20" ZOO0 psi 20" 2000 ps50~5]~ng 10" ~all valve~, hyOraulically actuate~, w/lO" lines tm reserve' ~i~. Valves ~m o~en au~o~icaily u~on closure of annular ~reventer. 20" 2000 psi annular preventer. 20" bell nipDle. Haintenance & Ooeracion 1. Upon initial installation close annular preventer are verify ~hat ball valves have oDeneO properly. 2. Close annular preventer ere blow air t~,rougn civerter lines every 12 hours. Close annular preventer in t~e event t,~at .oas or fluid ~verri~e end ¢lgse bell valve to u~wind Oiverter line. ~o not shut in ~ll unOer any c( re.stances. , = 16" Conc~uctor -7 mil m= 5 ) 4 m i 2 1:5-5/8' 5CK~ PSI ~A ~__ STAC~ ,A~ATC~, CA~AC;[TY TEST 54 ARCO Alaska, Inc. Post Office Bu^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 26, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - lQ Pad Wells 1-8 Dear Elaine, Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU2/L44 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~. i i i ! i - '~ ':~ ':-? .. --.-~ ~. -:~:--~?-~.-.~:-:~-~'-.~-~--?-i'-& :~-"--.:_~i~-_-~:.- ~ WELL 9 .~-~ff~-,984,4~ 8.62 Lat. 70°~'06.~05" ' ' - "'" ......... -:?-:':':;'~--: ..... :' ':-' ': ::-- ~ . X = 527,725.89 ~ng. 149°46'28.916''- .... ~ .... ~ O.G. Elev. PQd Elev. 56.6 50.~ ~6 25 ~ ' ' ' ' 1~899' FEL 1~441' FNL ' WELL I I Y :5~984~439,44 Lot. ~22'06.8895" , ~ PHASE ~ AS-BUILT x=527,666.85Long. 149°46'30.645'' ~ Pod Elev. 56.7 O.G. Elev. 50.6 -"' WELLS I Thru 8 ~,958' FEL 1,451' EEL . ~ "~' (,SK 9.05.117d,)_ '-." -- WELL 12 Y=5,984,449.95 Let. . X = 527~607.83 Long. 149e46'5~568" ~d Elev. 56.6 O.& Elev. 50.8 2~017' FEL 1~4ZO' FNL WELL 13 Y=5,984~804.50' ' Lot. ~°22'10.4801" X = 5A7~670.35 ~ng. 149°46'30.500''~ Pod Elev. 55.5 0.~ Ele~, 48.6 1~952' FEL 1~066 FNL WELL 14 Y=5,984,794.20 Let. 70°22' 1~5766" X = 527,729.40 ~ng. 149°46'28.774'' Pod Elev. 55.3 O.G. Elev. 48.3 - 1~895' FEL 1~076' FNL WELL 15 Y=5,984,783.67 Lot. ~22'10.2708" WELLS 9 Thru 16 x=527,788.50 ~ng. 149°46'27.046'' .... Pod Eiev. 55.5 O.G. Elev. 48.0 . .- .' ..._/....~.. _ ._ _ .'-'-'- . . 1,854' FEL 1~087 FNL ~ /'- ~' WELL 16 Y = 5,984,773.22 Lot. 70°2Z'i0.1659" . . X= 527~847.58 Long. 149°46'25.319'' · Ped Elev. 55.3 O.G. Elev, 48.5 NO SCALE 1,775 FEL 1,098 FNL =, , , , . . LOCATED IN PROTRACTED SECTION 26 ~ ._k~., ~ .~.~.., ~.t.. TOWNSHIP NOTE' BASIS OF POSITION IS MONUMENTATION 19-1 ?~':'?~ ~'~' /~ '~'~3~ f~:~',, 5276-S, AND 19-3 PER LHD ~ ASSOCIATES ..... , ~_ ~ .... ,.. THIS SURVEY LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 27 2 5 ~0 ' ' ARE CORRECT AS Of OCTOBER 15, 1984. . ". .. . . ~ ARCO Alesk0, Inc. .. 3~ ' ',. DRILL SITE IQ CONDUCTOR AS-BUILT . LOCATIONS - , s.ow SCAL[: ~--'~ , Z~) ~ ,~ ,:~ Drawn By' ~ Owg. NO. NS"9~S, IITd2 Company ~1J'J Lease & Well No. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee 1~ !-)i.-ð)- / (2) Loc ./7 '-... 3-17, -itJ- ~8) JiúJf :? /111.5 (8) .f (3) Admin ~'". )~/î,-I.[ (~ thru 12) IIJJI :Jj liZ'S' (10 and 12) (4) Casg l)JJ! 3//;;/35'" 13. (13 thru 21)1 14. l~L 16. 11. 18. 19. 20. 21. (5) BO~E. J/¡TJ/ j/tifif (22 thr 2) ( 6) Add: IliTII.' ~/¡7~':::- Does: operator have a bond in force.................................. Q.. Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... --- 1"1.- Is the lease number appropriate ..................................... ~--- Is conductor string provided ........................................ ~ Is enough cement used to circulate on cond~ctor and surface.. ~ . . . . .. Ællt --- Will cement tie in surface and intermediate or production strings ... --- ~ Will cement cover al! known productive horizons ..............~...... ~ Will surface casing protect fresh water zones ....................~.. /Ii!J1 Will all casing give adequate. safety in collapse, tension and burst.. !I1l:L Is this well to be.)cickedoff from an existing wellbore ............. ii/I'll Is old wellbore abandonment procedt1re included on 10-403 ............ --- N./J. Is adequate wellbore s~paration proposed. . . . .. . . . . . . . . . . . . . . . . . . . . .. JlJ7/ $ E.£ eE'/.. t).t{) ;/JII !filif JiJJd --- --- A/I)/ SVBMJÎít:D J:IØf. Ji!!lf YES NO oL. Is the 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.................... y~ = ¡s su£ficient undedicated acreage available in this pool ............ ~ Is well to be deviated and is wellbore plat included ................ ~ Is operator the only affected party................................. ï1C: Can permit be approved before ten-day wait .......................... ~ --- 2. 3. 4. 5. I). "7 . B. J. 1 ). 11. 12. 22. 23. 24. 25. 25. Is a diverter system require,d ............................,........... Arenecessarydiagramsöf diverterand BOPequipmentattached........ Does BOPE have sufficient pressu;re rating - Test to J/ tf?5D psig. . Does the choke manifold comply w/API RP-53 (Feb.78).................. Is the presence of H2S gas probable ................................. 27. Addit.ional requirements..." ... ,.. .. .. . . . .... .. 0 .. . .. ... .0 . .. .. . . . .. . . . . . ¡L-fL-.U I Q ~/5 REMARKS AdditionalR~J11arks: 1!J.E:ILI.CX-LtJWtLL Be 6Ól FÞôM /O-)b rÆl>¡V( $UÆ/-:/f..(:E Tl> 5ðt)r TvDÞ rJl£I<E w/)..1.. B £ Nt; /;1.)" os E WE 11J5deES Df) tuNf/'tJL~ .. INITIAL GEO. UNIT ON/OFF POOL CLAS S STATUS AREA' NO. SHORE If ~ /loL:> ^(Iç¡,4 J"""Ut) ð$,ù / /1 b ~ ù¡J (~ t:1 0 ~ ::t:z HO cn~ ~~ ~~ I?=:! I?=:! H Z ("'~ Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically organize this category of information. .o ,VP 010oHOZ YERIFZSATION L~STING PAS~ :'~ TAPE HEADER ,ERVICE NA~E :'EDIT ,ATE :85/06.! 1 JRIGiN :0000 'APE NAME :0415 .DNTINUAT~;3N ~ :01 'REVIOUS T~P~: ',OMM ENTS : :~ FI.LE HEADER :I.LE NAME ::EDIT .OOl ;ERViCE NAME : ?ERSION ~ : ~ATE : ~AXIMUM LENGTH : :ILE TYPE : ~REVIOUS FIL~ : ~ INFORMATION RECORDS 4NEM CONT:ENTS ;N :' ARCO ALASKA INC ~N : 1Q-15 :N : KUPARUK ]ANG: 9E ~ECT: 26 ;OUN: N. SLOPE ~TAT: AK ;TRY: USA "INEM CONTENTS ,~RES: E ~ COMMENTS ~ JNiT TYPE CATE SIZE CODE 000 000 015 06:5 000 000 005 0~5 000 000 007 055 000 000 002 0~5 000 000 003 065 000 000 002 0~5 000 000 008 0~5 000 000 00~ 0o5 000 000 003 065 TYPE CATE SIZE CODE 000 000 001 0~5 ,VP 010.M0.2. VERIFISATI.,3N LISTING PA.,~E 2. SCMLUMBER ALASKA CDMPUTING CENTER i~'MPAN'Y = ATLANTIC RICHFZiELD CDM,P~NY I'ELL = :IELD = KUPARU~ ~D.DNTY = NDRTM SLOPE ,6DR~UGH ;TATE = ALASKA lOB NUMBER AT ACC: 70415 :IJN ~1~ DATE LOGSED: .'DP: L.B.C~DNEY ;ASING 'YPE FLUID )ENSIT¥ fISCOSiT¥' 'H :LUID LGSS 9.625" ~ 46£0~' - BIT SIZE : 8.5" TO 8'T31' LSN,D ~O-O S RMF : 1.T00 ~ 68.0 ~F 9.5 RMC '= 1=5'80 ~ 68.0 OF 5.6 C3 RM AT B'HT = .932 a 141. DF *ATR.IX SANDSTONE .VP O.IO.HOZ VSRIFICA'T,IDN LIS'TING PA55 THIS DATA HAS NOT SEEN D6PT,H SHIFTED - OYE:R,LAYS FIELD PRINTS S.CHLUMSERG'ER LOGS ,INCLUDED WITH DUAL INDUCT~2N SPHER~.CA,LL~ FDC. USED LOG DATA AV AI::LA~,L E: ~ORMAT~ON gENSiTY COMPENSATED LO~ (FDN) COMPENSATED N~EUTRON LOG DATA AVAILABL'E: ~. DATA FORMAT RECg.RO ** ENTRY B, LO,C~S TYPE S~,ZE REPR CODE ENTRY Z 1 6~ 0 4 1 ,6& 8 4 73 60 9 4 65 16 1 6b 1 0 1 66 0 .VP OIO.HO~ YERigICATION 'LI$?ING PASE ~ ),ATUM SPECIFICATION ~LgCKS ~,NEM SERVICE SER¥ICE UNIT I~ aRDER # LOG )E P T FT 00 ~FLU 9IL DHMM 00 :LO OIL gHMM OO IL4 OIL gHMM O0 ~P OiL MY O0 ;R OIL GAPI O0 ;R FON ~API O0 ~ALI FDN IN O0 ~HgB FDN ~/C3 O0 )RH~ FDN ~/C3 O0 ~R~T FDN OO ~NRA FDN ~P~I FON PU O0 JCNL FDN CPS O0 =CNL ~DN CPS O0 )EPT 8730.0'000 SFLU ~ P - 20 . 1 '7,19 G R JHOB Z. 25]39 ORHO ~PHI ~8. ~B16 NCNL ) E P T 8 '? 00 . 0:000 S F L U ~P -15.2.500 GR ~HOB 2.2656 ORHO ~PHi 46.6309 NCNL )EPT 8500.0000 SFLU · ~P -3~. ~375 GR 2HgB 2. Z715 ORHO ~P ~I 28- 857~ NCNL 2EPT B~O0.O000 SFLU SP -25.0938 SR ~Hi3B 2.6121 DRHO ~PHI 30.322~ NCNL )EPT 8~00.0000 SFLU SP -27.1250 GR ~HOB Z. 39~5 DRHO qPHi 29. 1504 NCNL 2EPT 8300.0000 SFLU SP -20.9375 GR RHOB 2.5176 DRHO NPHI 25.8056 NCNL 3EPT 8200.0000 SFLU SP -21.2656 GR API TYPE 000 120 010 310 310 280 350 355 ,~20 000 330 330 Z. 105. O. 1891. 3~ 105. O. 1891. 6.1. O. 3500. 92. O. 2262. 73. O. 2685. 107. O. 2386. CLASS 0-0 O1 OI O1 O1 O1 02 O1 O1 O0 O0 31 30 0277 8125 1958 000'0 5566 198.2 O000 4063 000~0 0439 0000 9336 0474 0000 7188 1875 0454 0000 8750 0493 DO00 9453 7 $ O0 ~'Pi FILE SIZE SPL 400 NO. 0 0 ~ 0 0 ~+ 1 0 O ~, l 0 O .~ 0 0 ~ l 0 0 ~, 1 0 0 ~ 1 0 0 ~, 0 0 % 0 0 .~+ 0 0 ~ 0 0 ~ 1 0 -0 q, 1 0 0 ~, I iLg G,R NRAT FCNL ~R NR AT FC ..,;iL ~R NR~T FC ~L iLO 2R NR~T FC,~L NRAT FCNL ILD ,MR AT FCNL SR 3. 3906 105,.,8125 3.8008 '512. 000,0 3.3281 3.8008 512.0000 37.9687 6t.0000 138.4.0000 5.4531 9Z.~375 Z.BIZ5 855.5000 10.8125 73.1875 2.7129 104~,.0000 3.8652 107.8750 1.6035 992.0000 3.7168 125.7500 REPR PRDCES S O000OO00000000 00000000000000 68 0000000.000000:0 68 00000000000000 68 00000000000000 00000000000000 O'O000O~O0'O'O000~ $8 00000000000000 6.B 00:00-00.0000000~ 68 000,0000000.0000 0000,00000000'0~ 68 00000000000008 68 0000,00.0000'000~ 68 O0.OOOO00000000 00000.00000000~ ILM 3.0000 CALl, 8.5000 RNRA 3.:5934 CALl 9.8906 RNRA 3.693~ iLM 49.1502 CALl RNRA :Z.52'73 ILM .~. 6797 CALl ~.I094 RNRA Z. b4 Z. 6 ILM 10.859~ CALi 8.~516 RNRA 2.5703 RNRA ILM 3.a836 CALl 9.9766 .VP OiO.HO~ VERIEI~ATI~N LISTING PAVE ~HOB ~PflI )E P'T ~P ~H3B ~PHI )E:PT ;P ~PHI )EPT ~P ~P HI )EPT ~P ~H08 ~PHI )EPT ~P 2H~ )EPT ~P 4PHI ]EPT 5P 4P HI 23E PT SP 2H08 qPHi 3EPT 5P :ZHOB ~PHI )EPT ~P 4PHI 3EPT g. 5762 DR ,~0 36. 3770 N,CNL BLO0.O000 SFLU -21,.9062 GR ,2.°3594 DRHO ~3.701Z NCNL 8000,. O00,O SFLU -1.~...~219 GR ). 2 B 52 g R H 0 ,':,. 8. ~375 NCNL 7900.0000 SFLU -2Z. Sg3B GR -~99,. ZSO0 gRHO -999.2500 NCNL 7800,.0000 SFLU -27.0156 ,$R -999.2500 ORHO -999.2500 NCNL 7700.0000 SFLU -13.7969 GR -999oZ500 DRH.O -999.2500 NCNL 7500.0000 SFLU -29.8281 GR -999.250,0 DRHO -~99. Z500 NCNL 7500.0000 SFLU -31.7031 GR -999,.Z500 DRHG -~99. Z$'00 NCNL 7~00.0000 SFLU -8.6953 GR -999.2500 DRHO -999.2500 NCNL 7300.0000 SFLU -13.1406 GR -999.Z500 ORHO -~99. 2500 NCNL 7200.0000 SFLU -17.078I GR -999.Z500 ORHO -999.2500 N£NL 7100.0000 SFLU 0.0952 NRAT .£67Z. 0000 FCNL 1.7148 ILO 136.6250 G!R 0.0278 NR~T 183'7.000'0 FC~L 1-5.332 '129,.~750 0.0322 NRAT 177'0,.0000 FCNL Z.~961 ILO 129,.~000 :GR -999.25~0 NRAT -999.Z500 F£NL 3.1973 ILO 153,.~250 GR -999.2500 NRAT -999.2500 FCNL 2.9453 ILO 231.750-0 GR -999.2500 NR~T -999.21500 .FCNiL 3.~0~3 ILO 169.~000 ~R -999.250'0 NRAT - 999. Z 500 F C N,L Z.L3t8 iLO L74. 500'0 GR -999oZ500 NRAT -999. ZSO0 FC ~L 1.9111 ILD i09.8750 ~R -999.2500 NRAT -999.2500 FC~L 2.1621 iLO 129.1250 GR -99'9.2500 NR~T -999.2500 FC4L Z.3653 ILO 115.1250 ~R -999.Z500 NR~T -999oZ500 FCNL z. gz97 iL2 8~0.0000 1..86~3 1.36.,~250 3.5879 5Z~.O000 1.76.95: 1~9.8750 3..B6,33 Z.~375 lzg.~ooo .-~99.Z500 -999. Z500 153. ~ZS.0 -999.Z$00 -999. ZSO0 Z.3Z23 Z31.7500 -~99,.Z500 -,999. Z500~ 3. Z109 169.5000 -999. Z$,00 -999.2500 2.3379 17~.$000 -999..Z500 -999. Z~00 Z..3231 109.8750 -999.2500 -999.Z500 Z.~O0~ -~99.Z~00 -999.Z500 2.5078 115.1250 -999.Z500 -999.2500 2.9785 RNRA CALI RNRA CALI RNR~ t,L M C,AL I RNRA ILM CALl RNRA IL M C ,AL t RNRA CAL.I RNRA I L M CALI RNRA ILM CALI RNRA ILM CAcI RNRA ILM CALl RNRA .ILM 3.i797 3.5039 1.,'7510 3. Z.$098 l 0.03 '9 i -999.2500 Z.98'05:: '9.6563 -~99.Z500 Z. 85 ,-999.Z500 3.3017 t0.4453 -99'9.2500 2.3711 10o5313 -999.2500 2.3691 9.3047 -'999.Z5~0 9.3i81 -999. ZSO0 2.5664 9.1562 -999.Z500 Z.99ZZ .VP OIO.HOZ VERIFICATION LISTING PASE 6 ~PHI )E P T ;P iP l'i I }E P T iP H I )EPT ~P ~:H 0 B 4PH I )E PT ;P ~PH I )EPT ~P ~HDB ~PHI )EPT ~P ~ H'3B ~PHI )EPT ~P ~HOB ~PHI )EPT ~P ~H38 4PHI )EPT ~P )EPT ~P ~HgB ~PHI ' Z 0. ! 719 G R - 9 '99. Z 500 O R fi 0 · -999. 2500 NCNL 7000. 0000 !~FLU '-22o 8,125 -999. Z 500 -999.2500 NCNL 6'300.0000 SFLU -2 6. :S z,,. ,59 ~ :R '-~99. ZSO'O ORHO 6800;,..0000 SF~U -15.3828 GR g99.2,500 :DRHO -999. ZSO0 NCNL 6'700,. 0000 SFLU -19'6250 GR -999.2500 ORHG -999, 250,0 N C NL 6 $ 00.0,000 S FLU ' -21.7188 GR -999. 250,0 ORH0 -999,,,, 2500 NCNL 6500. 0000 SFLU -2¢. 1,250 '2R -~9'9 Z500 ORHO '- '~ 9 '9 .. 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