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183-023
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, August 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Y-14 KUPARUK RIV UNIT 1Y-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/20/2025 1Y-14 50-029-20910-00-00 183-023-0 W SPT 5796 1830230 1500 2340 2340 2345 2345 340 420 420 420 4YRTST P Austin McLeod 7/12/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Y-14 Inspection Date: Tubing OA Packer Depth 510 1800 1760 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250713141018 BBL Pumped:1 BBL Returned:0.9 Wednesday, August 20, 2025 Page 1 of 1 MEMORANDUM TO: P.I. Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1Y-14 KUPARUK RIV UNIT 1 Y-14 Src: Inspector Reviewed By P.I. Supry J Comm Well Name KUPARUK RIV UNIT 1Y-14 API Well Number 50-029-20910-00-00 Inspector Name: Matt Herrera Permit Number: 183-023-0 Inspection Date: 7/5/2021 ✓ IUsp Num: mitMFH210706141538 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-14 Type Inj w - TVD 5296 - Tubing 2280 2280 _' 2280 22280 — PTD 1830230 Type Test SPT" Test psi 1500 IA 1665 3000 2950 2940 . L Pum 1.1 BBL Ret Urnetl: 1 1 OA 440 520 p 520 - 520 - _ Interval 4YRTST !P/F P Notes' MIT -IA performed to 3000 PSI Per Operator Tuesday, July 13, 2021 Page 1 of 1 Originated: Schlumberger PTS-PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: 47 AOGCC ATTN: Natural Resources Technician II T Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 +gjg� Anchorage, AK 99501 TRANSMITTAL DATE TRANSMITTAL# 18 30 23 LJWELL NAME API # ORDERSERVICE # FIELD NAME DESCRIPTION DELIVERAEILE DESCRIPTION DATA TYPE DATELOGGED Prints CD's 1A-25 30-11 3K-23 2V-02 1Y-14 1H-109 1H-113 1H-117 3H-148 50.029.22116.00 50-029-21676-00 50.029-22771.00 50-029-21037-00 50-029-20910-00 50-029.23595.00 50-029.23588-00 50-029-23602-00 50-103-20092-02 EBNL-00028 EBNL-00029 EBNL-00030 EBNL-00034 EBNL-00035 EBNL-00036 EBNL-00037 EBNL-00038 EOSH-00062 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVERIPROF KUPARUK RIVEROWL KUPARUK RIVER KUPARUK RIVERIPROF KUPARUK RIVER KUPARUK RIVER(PROF KUPARUK RIVER WL WL WLJul-19 PPROF LDL LDL (PROF (PROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 21 -Jun -19 22 -Jun -19 23 -Jun -19 27 -Jun -19 28 -Jun -19 29 -Jun -19 30 -Jun -19 1- 3 -Jul -19 1 1 1 1 1 1 1 1 1 2G -14A 1B-06 18-09 3G-03 1R -22A 50-029-21161-01 50-029-20603-00 50-029-20655-00 50-103-20245-00 50.029-22206.01 EOSH-00064 EOSH-00065 EOSH-00066 EOSH-00067 EOSH-00048 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL LDL PPROF IPROF PPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 5-Jul -19 6 -Jul -19 7 -Jul -19 8 -Jul -19 N-19 1 1 1 1 OEGER1 14 A Transmittal Receipt signature confirms that a package (box, (/ envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy Schlumberger and CPAI. not have been verified for correctness or quality level at this Please retur..�r-.... courier sign/scan g point. Schlumberger -Private tnM • • t N N 0 X f0 al or w a > E p_03 no +, co >, m (� Q Y O I-MY O C U N j or 2 n f0 a� O a1 O u° a` a c c Ca CD « o 'c 4.-a 'O a C -6 a c M- Q U aJ > (0 Q p { W n N N N N N N + v 0 o CO e- r r E u t CU �u LO ko c w to r- a0 co O M C �0 Y 01 C N Q N N N U CO O 411 z U ZZ * C N > 'p Q1 Q L O C 0 + l . 1] F c Q) cu Q L W J• J J J J J J C C 0 } W W W W W W W 0 v C U `- H LL LL LL LL LL LL LL , N N N 17 C Q J J J J J J J a 4 > C ;9 h. : = c a z z z z z z z v CO N O _ v �� LL LL LL LL LL LL LL t _0 > 'nI m C 00 c0 +U.+ j Y a) k•+ s O O "' z Na aEo; u > cm �. V 10 0 c 0 m c.= co O1= ra a .. u -C C Z 1.1 V Cl. ~ c ccoo a 0 0 (0 Q a a V) c a ri fb < HLL LL LL h 'Z 0 0000 a33 O U G IX LL' CZ i0 J J F o � aaac� ooa3 0 W N• V' CO U co r7) w \ a W g V ; o p 13 �i IX Q A. h N g g►y t0 W O ? .7 p U d J J J J J J J 1 o z R N N 3 3 3 3 3 3 3 W W WWWWUJ13 41/1.1."1:1,11r, AL W w > > > > > > > 2_, W CY CG W W IX z Y Y Y Y Y Y Y 7 7 7 7 7 7 7 CIWLLJ a a a a a a a 1 LL a a a a a a a a `' U Y Y Y Y Y M7777Y Y c a '�'/rpt c::, ao O X (.1 MIMI Li'f LLI O CO a v 0 0 CO o CO la et o o O £ CV O o 0 0 0 0 0 o a I O O o o O O o V O Vw . 0 c, o r co co co co co co > 1444 5 cc0 0 0 0 0 Q c CC X U CO Y O E ' 0 0 0 0 0 0 0 a' O @ t.0 O O O O0 0 0 u Q Q N o r to ct) a O ;° • N I� N M M a M O N 01 Z13 T N O co O O O N OINOINNNN H _C N to 0 a) 0) 0o to c) R NNNNNO 0 0 0 0 0 0 co co a u O O O t8 O O t7 C7 0 C O MN 00 C O in N Ill N in a -co O C 0.1 r- Ln c , u m a to a Z a 0 k;W - '� @ E c (U 1� G m c° H- 119 a1 0.1 r1 Q h CO N { Q LD a1., aJ C , Y N e z ,_ m z O O O N v m = o N ti 3 Y T x E z v c —• d Q O N ..i N N M N N N O O p4-• u O C/3 4 rt: a s F°- t°- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 11,2017 P.I.Supervisor 1\eiC 7/17(i 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-14 FROM: Brian Bixby KUPARUK RIV UNIT IY-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry TG• NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-14 API Well Number 50-029-20910-00-00 Inspector Name: Brian Bixby Permit Number: 183-023-0 Inspection Date: 7/6/2017 Insp Num: mitBDBI70708095637 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-14 Type Inj W ' TVD 5796 Tubing 2430 2420 ' 2400 2400 ' PTD 1830230 Type Test SPT Test psi 1500 IA 1075 1900 1870 - 1865 - BBL Pumped: 0.8 [BBL Returned: 07 OA 25 25 • 25 25 - Interval 4YRTST P/F P Notes: • SCANNED AUG 1 52017, Tuesday,July 11,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,February 18,2015 Jim Regg fk J P.I.Supervisor 1��1`i Z`wl�� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC l Y-14 FROM: Chuck Scheve KUPARUK RIV UNIT IY-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J3e--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IY-14 API Well Number 50-029-20910-00-00 Inspector Name: Chuck Scheve Permit Number: 183-023-0 Inspection Date: 2/15/2015 Insp Num: mitCS150215150028 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-14 - Type Inj 'W�TVD 5796 ' Tubing T 2150 • I 2150 1 2150 . 2150 - PTD 1830230 - 'Type Testl SPT!Test psi j 1500 - IA 1240 2920 j 2870 - + 2860 rINITAL — f P 40 40 40 - t Interval P/F OA T 40 Notes: Initial test post rig workover SCANNED ;!,;y, j ; , Wednesday,February 18,2015 Page 1 of 1 UNSCANNED, OVERSI7ED MATERIALS AVAILABLE: / ~~ ~ PILE # ~ ~cu ~ Lo G~ To request any/all of the aUove information, please contact: Alaska Oil & Gas Conservation Commission X333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Tax (907) 276-7542 Ima~!~roject Well HiStory File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~"~__- ~-~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) D Color items: [3 Diskettes, No. D Maps: [] Grayscale items: [] Other, No/Type [3 Other items scannable by large scanner [3 Poor Quality Originals: [:]Other: '" ~~n-Scannable) '~varlous kinds .Y: BRE. V,.OE.* S.ERYL MAR,A 'OWEL,. 'S' Project Proofing .. BY: BEVERLY BREN VINCENT,~----~ MARIA ' (,._......-~ LOWELL DATE'~,:~ ISl ScanningPreparation '~//~/ x30= /~...~ + ,~" = TOTALPAGES /~ BY: BEVERLY BREN ~[~I~SHERYL MARIA LOWELL:,r D~TE.~~~'~ 181 ~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO DATE: //C~, ~._/S/ LOWELL Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCEN~ MARIA LOWELL DATE:/i/~/3~8/~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanne~Lwpd r r- STATE OF ALASKA AL A OIL AND GAS CONSERVATION COIVOSION REPORT OF SUNDRY WELL OPERATIONS F.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r . Other FY Install Patch r` Alter Casing r Pull Tubing j"°" Stimulate-Frac r- Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Development r Exploratory r 183-023 • 3.Address: 6.API Number: Stratigraphic r Service P. 0. Box 100360,Anchorage,Alaska 99510 50-029-20910-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25548 1Y-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 7386 ' feet Plugs(measured) none true vertical 6530 feet Junk(measured) none Effective Depth measured 7239 feet Packer(measured)6735,6928 true vertical 6384 feet (true vertical) 5885,6076 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114 114 SURFACE 2400 10.75 2436 2316 PRODUCTION 7287 7 7321 6465 SCANNED JUN 1 S RECEW-- JA ii 4, .013 Perforation depth: Measured depth: 6834-6888, 7020-7025,7032-7044, 7055-7076 ,r True Vertical Depth: 5983-6036,6167-6172,6179-6191,6202-6222 Tubing(size,grade,MD,and TVD) 3.5,J-55,6968 MD,6115 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6735 MD and 5885 TVD PACKER-BAKER FB-1 PACKER @ 6928 MD and 6076 TVD SSSV-CAMCO TRDP-1A @ 1865 MD and 1824 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic 16.Well Status after work: Oil r Gas f WDSPL Daily Report of Well Operations_XXX GSTOR r WINJ r WAG GINJ n SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-235 Contact John Peirce t')265-6471 Email John.W.Peirce(cr)conocoohillips.com Printed Name John Peirce Title Wells Engineer Signature Q _ Phone:265-6471 Date c^ /7/./ 2 7:Y4, jr` RBDMS JUN 11 201 I L f /, -A6. Form 10-404 Revised 12/2012 ,/J 4/0 Submit Original Only 1Y -14 Well Work Summary • DATE SUMMARY • 11/1/2012 BRUSHED / FLUSHED / GAUGED TBG TO 2.77" TO 6800' SLM. SET 2.81 MA -2 PLUG @ 6774' RKB. ATTEMPTED MIT x IA, TOO MUCH GAS. PUMPED 150 BBL DSL DOWN TBG, BLEEDING GAS OFF IA TO PRODUCTION. IN PROGRESS. 11/2/2012 BLED GAS OFF TBG & IA. COMBO MIT 2500 PSI, PASSED. PULLED MA -2 PLUG @ 6774' RKB. BRUSHED & FLUSHED PATCH AREA 6600' TO D NIPPLE @ 6956' RKB. DRIFTED TBG w/ DUMMY PATCH (2.78" OD x 206" OAL) TO 6956' RKB. COMPLETE. 12/6/2012 DRIFTED TBG TO D NIPPLE @ 6956' RKB WITH 2.78" x 30' DUMMY PATCH ASSEMBLY. READY FOR PATCH. 12/17/2012 TAGGED D- NIPPLE @ 6957' RKB W/ 2.80 CENT. AND BLB ASSEMBLY. SET 2.75" D X 2.25" D NIPPLE REDUCER @ 6957' RKB. READY FOR E -LINE TO SET PATCH 1/19/2013 SETTING 20' OAL PERMANENT TUBING P ATCH OVER LEAK IN C -SANDS AT 6860'. CCL TO TOP ELEMENT WAS 10.5'. CCL SETTING DEPTH FOR TOP ELEMENT WAS 6836.5'. SET PATCH @ 6847' - 6867' RKB. K U P • 1 Y -14 ConocoPhillip5 - - --- were Attributaa n Angle & MD TO Alaska, Inc. Wel lbore API /UWI Field Name Well Status Incl ( °) MD (ttKB) Act Btm (ftKB) (OnOc0,thps 500292091000 KUPARUK RIVER UNIT INJ 41.50 3,100.00 7,398.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well tonne'. -1v44, 1/24/2013 9:34:55 AM - SSSV: LOCKED OUT Last WO: 42.01 2/24/1983 Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,956.0 12/6/2012 Rev Reason: Drift/Tag, Set Nipple Reducer, Set Patch osborl 1/24/2013 HANGER. 30 - - Casino Stringa -i Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 37.0 114.0 114.0 92.00 H - 40 WELDED Casing Description String 0. Stri ID ... Top (t t Set Depth (f... Set Depth (TVD) ... String Wt... Str ... String Top Thrtl SURFACE 103/4 9 .950 3 6.1 2,436.5 2,316.3 45.50 K - BTC Casing Des String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6 3 9 7,320.8 6,465.3 26 00 K - BTC TUbinq �a Tubing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND)... String Wt... String ... String Top Thrd TUBING 31/2 2.992 29.8 6,968.7 6,116.0 9.20 I J -55 I BUTT 4 Complotion Details Top Dep ilk CONDUCTOR, (TVD) Topincl Nomi... 37-114 Top (ttKB) (ftKB) ( °) I tem Descriptlon Comment (in) 29.8 29.8 th 0.42 HANGER MCEVOYTUBINGHANGER ID 3.500 SAFETY VLV, NO 1,865 1,865.2 1,823.9 28.68 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE (LOCKED OUT 7/27/84) 2.813 .'. 6,709.1 5,859.5 9.76 SBR BAKER SBR w/ OTIS PROFILE 2.813 GAS LIFT, 6,735.3 5,885.4 9.57 PACKER BAKER FHL PACKER 3.000 2,064 6,773.7 5,923.2 9.30 NIPPLE CAMCO W -1 NIPPLE 2.813 6,927.5 6,075.2 8.19 NIPPLE BAKER SEAL NIPPLE w/ LOCATOR SUB 2.813 6,928.0 6,075.7 8.18 PACKER BAKER FB -1 PACKER 4.000 6,930.5 6,078.1 8.16 SBE BAKER SEAL BORE EXTENSION 4.000 6,939.9 6,087.4 8.08 MILLOUT BAKER MILLOUT EXTENSION 2.992 SURFACE. 36 6,946.1 6,093.6 8.03 MILLOUT XO BAKER MILLOUT EXTENSION CROSSOVER 2.992 LFT, 6,956.6 6,104.0 7.94 NIPPLE CAMCO D NIPPLE NO GO (2.25" w /NIPPLE REDUCER) 2.250 GAS 3.I957 6,968.0 6,115.3 7.85 SOS BAKER SHEAR OUT SUB, ELMD TTL © 6966' during IPROF on 3.000 it 10/2/2002 045 LIT. Otter In Mole '. - retrievable pIU • s, valves, 4 flab, etc.) (ND) Top Intl -- -� GAS LIFT. ( 1 p (ftKB) (ftKB) (1 acription Comment Run Date ID (In) 6,136 6,847,0 5,995.6 8.87 PATCH HES PERMANENT PATCH (OAL - 22.31') OVER C -SANDS 1/19/2013 2.360 II LEAK @ 6860' - See attached patch schematic GAS LIFT. 6, • • • • • 7.94 Nipple Reducer'D' NI D CER �� 12/17/2012 2.250 6.695 Perforations & Sluts � �/ Shot SBR, 6,709 I 1 Top (ND) Btm (TVD) Dens / rt e - �� Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh--- Type Comment PACKER, 6,735 Ot 6,834.0 6,888.0 5,982.7 6,036.1 UNIT D, C-4, C -3 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. C -2, 1Y -14 Phasing 7,020.0 7,025.0 6,166.8 6,171.7 A -5, 1Y -14 7/25/2010 6.0 APERF 2.5" Millenium II HMX, 60 deg phase NIPPLE, 6,774 It 7,032.0 7,044,0 6,178.7 6,190.6 A-4, 1Y -14 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. It Phasing INJECTION. 7,055.0 7,076.0 6,201.5 6,222.3 A -3, 1Y -14 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. 6,808 - Phasing Notes : : G. Safety End Date Annotation PATCH, 6,847 10/2/2002 NOTE: STRADDLE TUBING LEAK @ 6860' (IPROF) IPERF, 8,834.6,888 - 6/30/2005 NOTE: TUBING LEAK @ 6688' (E -LINE LDL) 10/26/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IF an- INJECTION, 6,911 1 NIPPLE, 6,928 11 PACKER, 6,928 58E,6,930 MILLOUT, r„ 6,940 II ili NIPPLE, 8,957 Nipple Reducer. N 6,957 IF SOS, 6,968 Ez Mandrel Details Top Depth Top Port APERF, s,.. (ND) Intl OD Valve Latch Size TRO Run 7,020 -7,025 N... Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (In) (poi) Run Date Com... 1 2,063.9 1,997.1 29.82 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/20/1993 IPERF, 2 3,957.2 3,484.7 39.01 CAMCO KBUG 1 GAS LIFT 'DMY BK 0.000 0.0 9/20/1993 7,032 ' 3 5,197.6 4,486.9 32.98 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/20/1993 4 6,136.1 5,305.8 20,75 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/19/1993 7,055 - IP 8 5 6,694.6 5,845.1 9.54 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/20/2005 6 6,807.6 5,956.7 9.20 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 5/12/1997 Closed 7 6,911.1 6,058.9 8.33 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 5/12/1997 Closed PRODUCTION, 34 -7,321 ■ TO, 7,398 • • 811:AnlIE SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. 3 , d P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1Y -14 Sundry Number: 312 -235 WiNtiED JUL o 202 Dear Mr. Peirce: 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. 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 reconsideration. A request for reconsideration 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. Sincerely, I46,,,54_, Cathy . Foerster Chair, Commissioner DATED this 3 d ay of July, 2012. Encl. STATE OF ALASKA K/ 7( r r ALQA OIL AND GAS CONSERVATION COMMIeN APPLICATION FOR SUNDRY APPROVALS - Z, 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well re ile Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension J° Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Install Patches , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183 -023 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20910 -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 Required? Yes r No J;� 1Y -14 , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25548. Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7386 - 6530 , 7239' 6384' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114' 114' SURFACE 2400 10.75 2436' 2316' PRODUCTION 7287 7 7321' 6465' RECEIVED t 1 JUN 25 2)12 A OGC g ing Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubin rade: MD (ft): 6834'- 6888', 7020'- 7025', 7032'- 7044', 7055' -7076' 5983'- 6036', 6167'- 6172', 6179'- 6191', 6202' -6222' 3.5 J - 55 6968 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 6735 TVD= 5885 PACKER - BAKER FB -1 PACKER MD= 6928 TVD= 6076 SSSV - CAMCO TRDP -1A SSSV MD =1865 TVD =1824 12. Attachments: Description Summary of Proposal J:: 13. Well Class after proposed work: Detailed Operations Program J`°' BOP Sketch j " Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/1/2012 Oil fl Gas J" WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG 17 " Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John s Peirce ^ Title: Wells Engineer Signature r"` L F , •_-� Phone: 265-6471 Date /2 �� Commission Use Only 6, 2,// Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 /2 • / 13 Plug Integrity r BOP Test r Mechanical Integrity Test V Location Clearance r , pT C'Cf in tv 26 p5 ci�v+� C��r ✓� ✓ .,70 �ih G S /v,cl/rc� ( Other: Subsequent Form Required: 3 'LUIZ i 4 0 4' s ,, 1NEL) JUL 6 /4/4,6 APPROVED BY Approved by: i . i COMMISSIONER THE COMMISSION Date: 7 ' 3 - / 4 \ I Form ..? i f L's/2 0 , . �L 12-- Submit in Du licate v • • Proposed 1Y -14 Tubing Patch Installations Note: An original 10 -403 approval of 2 -23 -10 (approval # 310 -052) to install tubing patches has expired. Re- approval is now being requested for the tubing patch installation. 1Y -14 is a selective injector with 3.5" tubing that has been shut -in since 2005 due to an Ann Comm tubing leak and a C sand leak that takes all PWI. 1Y -14 had tubing patches previously isolating these Teaks but the patches eventually p tually failed and were removed Procedure - Part 1 - Install Retrievable Tubing Patch across C Sand Leak in the Selective: A 10/08/02 IPROF shows a tubing leak at 6860' RKB taking all PWI to the C sand. A new patch at 6850 - 6870' RKB will isolate the leak to convert 1Y -14 to `A sand only' PWI. A Tbg x IA Ann Comm leak will also be isolated by another straddle patch after the C sand leak is patched. Slickline: 1. RIH & tag PBTD to determine the need for possible coil tubing fill cleanout. The last PBTD tag in 1Y-14 was on 4/28/03 at 7065' RKB (11' Fill). Coil Tubing (if needed): 2. If the tag in step #1 was made shallower than 7076' RKB, this indicates fill is covering perforations. If this is the case, perform a CT FCO as deep as possible to remove the fill from the well and to create some rat hole prior to installing a tubing patch. Slickline: 3. Brush & flush 3.5" tubing in the area where a new tubing patch will be set. 4. Run Caliper log from the tubing tail. at 6969' RKB to surface to verify the overall mechanical condition of the tubing before running a tubing patch assembly. The tubing is 28 year old 3.5" J -55. E -line: 5. RIH with a straddle Packer and set the packer in the 3.5" tubing at 6870' RKB. Slickline: 6. RIH with a straddle Packer, 20' spacer pipe, and Anchor Seal assembly. Latch into lower packer at 6870' RKB and set top ER packer at 6850' RKB to complete a new tubing patch at 6850 - 6870' RKB. Set a test plug. PT the top packer. Pull plug. RD. Procedure Part 2 - Install a Retrievable Tubing Patch across Tbg x IA (Ann Comm) Leak: 1Y -14 recently had a stuck selective patch fished that had been stuck since January 2006. The well previously had a patch installed across GLM #5 that was temporarily successful A patch to isolate TxIA communication will be completed before initiating A sand only injection. This procedure assumes that a new selective patch has already been set. JWP 6/22/2012 • • • Objective: Set tubing patch over Tbg x IA annular communication tubing leak above the top of GLM #5. Background: Well has been shut in since 11/23/05 Last SBHP was A & C Sand = 2657 psi on 8/26/09 after 1403 days SI time. Min ID above patch area is 2.812" in the locked out Camco TRDP -1A SSSV at 1865' . Caliper run 11/14/05 shows one isolated pit 2' above GLM #5 with no other penetrations > 17% LDL run on 6/30/05 indicates a lone leak at 6688' above GLM #5 Well currently has dummies installed in all 5 GLM's Previous patch packers were set at 6684' and 6705' RKB All patch depths reference LDL on 06/30/05 PWS Confirm that data obtained by running a Caliper survey as a part of selective patch does not require this procedure to be changed. Slickline: 1) RU & RIH and make gauge run < 2.812" through Camco W -1 nipple at 6774' RKB 2) RIH and set positive plug in Camco W -1 nipple at 6774' RKB 3) Perform TxIA CMIT to 2500 psi. 4) RIH and pull positive plug in Camco W -1 nipple at 6774' RKB E - Line: 1) RU, RIH with retrievable Packer and set with mid element in middle of pup joint below GLM #5 at 6700' LDL. Slickline: 1) RU & RIH with Packer plug and set in Packer at 6700' LDL. Perform TxIA CMIT to 2500 psi. 2) RIH with retrievable packer, ± 22' spacer pipe, and Anchor Seal Stinger. 3) Sting into lower packer and set upper packer with mid element at + 6675' LDL. 4) RIH with packer plug and set in packer at 6675' RKB. Perform MITT to 2500 psi. 5) RIH and pull packer plug 6) RU LRS to IA and perform MITIA to 2500 psi Cht�f--/ • ° 7) Turn well over to Production DHD: 1) MITIA once online and stabilized • 5/-11- It II 16. JWP 6/22/2012 N.-- KUP 0 1Y -14 ConocoPhillips Well Attributes Max Angle & MD TD Alaska, Inc Wellbore APUUWI Field Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) Conomrt I l es 500292091000 KUPARUK RIVER UNIT INJ 41.50 3,100.00 7,398.0 Comment H2S (ppm) Date Annotation End Date KB -Ord (ft) Rig Release Date Well Conlin -iv -1 a, 1111220116:16:21PM SSSV: LOCKED OUT Last WO: 42.01 2/24/1983 schematic- Actual Annotation Depth (ftKB) End Date Annotation - Last Mod ... End Date Last Tag: SLM 7,045.0 7/19/2010 Rev Reason: FORMAT UPDATE ninam 11/12/2011 HANGER, 30 ,iffi., Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1® CONDUCTOR 20 19.124 37.0 114.0 114.0 92.00 H-40 WELDED Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String Wt... String .,. String Top Thrd i r' ` f' SURFACE 103/4 9.794 36.1 2,436.5 2,316.3 45.50 K -55 BTC i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd ' Vi.„ J P RODUCTION 7 6.276 33.9 7,320.8 6,465.3 26.00 K -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ' TUBING 31/2 2.992 29.8 6,968.7 6,116.0 9.20 J -55 BUTT . �_- <� Completion Details Top Depth (TVD) Top Ind Nomi... CONDUCTOR, Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 37-114 29.8 29.8 0.42 HANGER MCEVOY TUBING HANGER 3.500 SAFETY VLV, 1,865.2 1,823.9 28.68 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE (LOCKED OUT 7/27/84) 2.813 1,865 _` ® , ' a 6,709.1 5,859.5 9.76 SBR BAKER SBR w /OTIS PROFILE 2.813 z 6,735.3 5,885.4 9.57 PACKER BAKER FHL PACKER 3.000 GAS Z 4 6,773.7 5,923.2 9.30 NIPPLE CAMCO W -1 NIPPLE 2.813 6,927.5 6,0752 8.19 NIPPLE BAKER SEAL NIPPLE w/ LOCATOR SUB 2.992 6,928.0 6,075.7 8.18 PACKER BAKER FB-1 PACKER 4.000 6,930.5 6,078.1 8.16 SBE BAKER SEAL BORE EXTENSION 2.992 6,939.9 6,087.4 8.08 MILL BAKER MILL OUT EXTENSION 2.992 SURFACE, . . 6,956.6 6,104.0 7.94 NIPPLE CAMCO D NIPPLE NO GO 2.750 38 -2,436 6,968.0 6,115.3 7.85 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 6966' during (PROF on 2.992 10/2/2002 GAS LIFT, 3,957 IF Perforations & Slots Shot GAS LIFT, Top (TVD) Btm (ND) Dens 5,198 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 6,834 6,888 5,982.7 6,036.1 UNIT D, C-4, C-3 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. , C-2, 1Y -14 Phasing GAS 61 6 7,020 7,025 6,166.8 6,171.7 A-5, 1Y -14 7/25/2010 6.0 APERF 2.5" Millenium II HMX, 60 deg phase IP ire 7,032 7,044 6,178.7 6,190.6 A-4, 1Y -14 2/24/1983 12.0 IPERF 5" Scallop; Dresser, 120 deg. GAS LIFT, Phasing 6,695 7,055 7,076 6,201.5 6,222.3 A -3, 1Y -14 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. Affil Phasing SBR, 8,709 Notes: General & Safety End Date Annotation PACKER, 8,735 10 /22002 NOTE: STRADDLE TUBING LEAK @ 6860' (IPROF) 6/30/2005 NOTE: TUBING LEAK @ 6688' (E -LINE LDL) NIPPLE, 6,774 ii;.. 10/262010 NOTE: View Schematic w/ Alaska Schematic9.0 INJECTION, 6,808 ( j IPERF, w ' ' "} V Y1 -ryti L1 ii"' /Y� h 6,834-6,888 ERR, "` �I III INJECTION, 6,911 «,g` NIPPLE, 6,928 - -- PACKER, 6,928 L'^ 98E, 6,930 I / MILL 6,940 1 NIPPLE, 6,957 p IF SOS, 6,988 Mandrel Details 7,020 -7 Top Depth Top Port APE, 025 RF, - - (TVD) Inc] OD Valve Latch Size TRO Run .-- Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (i^) (psi) Run Date Com... 1 2,063.9 1,997.1 29.82 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/20/1993 IPERF,. "f 2 3,957.2 3,484.7 39.01 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/20/1993 7,032 -7,044 3 5,197.6 4,486.9 32.98 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/20/1993 4 6,136.1 5,305.8 20.75 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/19/1993 7,055-7,076 = , - 5 6,694.6 5,845.1 9.54 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/20/2005 6 6,807.6 5,956.7 9.20 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 5/12/1997 Closed 7 6,911.1 6,058.9 8.33 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 5/12/1997 Closed PRODUCTION, 34 -7,321 N TO 7,398 • 4 • Conoco Phillips Alaska P.O. BOX 100360 • - ANCHORAGE, ALASKA 99510 -0360 December 30 2010 ` ( g.-3 CE Commissioner Dan Seamount , AN €1 4 2 U 1 `o Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 CjA 2t t O � ;' �� ` G8S Coos. Ccrrmtssion Anchorage, AK 99501 ncn9'age Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23 24 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. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • 1 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 404) Kuparuk Field Date 12/30/2010 1C, 1E, 1 F, 1G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1C-07A 50029205690100 2090290 3'2" n/a 3'2" n/a 4.3 12/23/2010 - 1E-09 50029207200000 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" n/a 3'9" n/a 11.6 12/22/2010 1E-16 50029207770000 1821100 4' n/a 4' n/a 13.7 12/22/2010 1E -17 50029207930000 1821160 3'11" n/a 3'11" n/a 8.5 12/24/2010 1F -13 50029210200000 1831440 6" n/a 6" n/a 3 12/23/2010 1F:47 50029226570000 1960470 SF n/a 18" n/a 7.65 12/23/2010 1F-20 50029226610000 1960530 6" n/a 20" n/a 6.1 12/23/2010 1G -13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y-01 50029209330000 1830500 SF n/a 6" n/a 1.9 12/21/2010 1Y -03 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF n/a 6" n/a 1.7 12/21/2010 1Y-11 50029209260000 1830410 9" n/a 9" n/a 2.6 12/21/2010 1Y-12 50029209130000 1830260 4' n/a 4' n/a 8 12/21 /2010 1Y-13 50029209030000 1830150 15" n/a 15" _ n/a 1.7 12/21/2010 ... ..,.41Y -14 50029209100000 1830230 24" n/a 24" n/a 1.7 12/21/2010 1Y 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21/2010 ~~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1Y-14 Run Date: 7/25/2010 July 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20910-00 A-,. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr Date: AUG 1 1 2010 mi~br~ oat 3' I ~ ~,~~ ~~ Signed: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t. Operations Pertormed: Abandon Repair w ell Plug Fbrforations ~'" Stimulate "` Other ~"" After Casing r Pull Tubing "" F~rforate New Pool ~ Waiver "` Time Extension ~" Change Approved Rogram ~"` Operat. Shutdow n ~ Perforate ~` Re-enter Suspended Well ~""; 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~" Exploratory "` 183-023 3. Address: Stratigraphic Service API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20910-00 7. Property Designatiory` 8. Well Name and Nurrl~er: ADL 25548 1Y-14 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7386 feet Plugs (measured) None true vertical 6530 feet .sunk (measured) None Effective Depth measured 7239 feet Packer (measured) 6735, 6928 true vertical 6384 feet (true vertucal) 5885, 6076 Casing Length Size MD ND Burst Collapse CONDUCTOR 114 20 114 114 SURFACE 2436 10.75 2436 2316 PRODUCTION 7320 7 7320 6464 ~a d (? v.~~_~ .a:, t ~~~ ~~~D ' ' ' ' ' ' ' -7044 , 7055 -7076 Perforation depth: Measured depth: 6834'-6888 , 7020 -7025 , 7032 True Vertical Depth: 5983'-6036', 6167-6172', 6179'-6191', 6202'-6222' ( ~;£ (~ q (~ , E °j ~ ~ U i l! ~ , ~I~~k3 ~ ~ ~8S ~'~~' I~gQ't)>>CnUS5~01i Tubing (size, grade, MD, and TVD) 3.5, J-55, 6969 MD, 6116 TVD ~~tc~~rr~ge Packers & SSSV (type, MD, and TVD) PKR -BAKER 'FHL' PACKER 6735 and 5885 TVD PACKER -BAKER'FB-1' PACKER @ 6928 MD and 6076 TVD LOCKED OUT - CAMCO TRDP-1A @ 1865 MD and 1824 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ]"""` Development ~` Service 15. Well Status after work: ~ Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG ~' GASINJ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce ~ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ ~ Phone: 265-6471 Date ~~ / ~ )~ Z RBDMS At1G 1~ 0 0-~0 -rd Form 10-404 Revised 7/2009 Submit Original Only 1Y-14 Well Events Summary DATE SUMMARY 7/19/10 DRIFTED TBG WITH 10' x 2.5" BAILER; TAGGED @ 7045' SLM. READY FOR E/L. 7/25/10 PERFORATED AT A DEPTH OF 7020'-7025' USING 2.5" X 5' GUN, WITH 6 SPF, 60 DEG PHASING, MILLENIUM DEEP PENETRATING CHARGES. CORRELATED TO BAKER ATLAS CBWDL LOG DATED 2/20/83 ~ KUP WeII Attnbutes _~~ ~C)1"1t)COI~'11~~1p5 ' ~. lNax Angle 8 MD 1Y-14 TD "~''"I~"~` Itl`" ~ Wellbore APUUWI Field Name _ 500292097000 KUPARUK RIVER UNIT - ~ Well Status INJ ~ Inc! (°) MD (ft KB) 41.50 I 3,10000 Act Btrn (ftKe) 7,3980 Comment H2S (ppm) Date _ An o[atlon Entl Date KB-Grd (H) Rig Release Date I ( __ _~SSSV LOCKED OUT I 1 ' I Last WO 42 01 - - - ( 2/24/1983 -_- Well COnYg 1V 14, 8/6f2010102 Scbemzte Actual J, _ - : 2A A notat'on Depth (ftK8) Entl Date Annotation - - -- 'i Last Mod By ---- /End Date _..__ ( ( i Last Tau SLM 7.045 0 7/19/2010 Rev Reason PERFORATIONS. TAG Imoshor 8!6/2010 SAFETY VLV, ._ rnvwi. iivi. ~... ..,,~..... vn..~.~ ~....,.. ~ .-.... 1.865 Tubing --__. __ Strings _ _.. _. _._ _ __ __ _ _ -.__ I~ St ng OD St ing ID Set Depth Set Depth (TVD) SVing WI Str ng ~ ' TubingD 'ption I lint (in) lop (ftK8) (ftK8) (flK6) (Ibslft) G de Str glop Thrd .-,. TUBING ~ 3 V2 2.992 (BUTT 0.0 6,969.0 6,116.3 9.20 J-55 1 GAS LIFT, - ° '' --- -_- _ _ 2.os4 Other I n Hole ( All Jewelry: Tubin g Run 8 Retrievable, Fish, etc.) __ - _._- _.. _ Top Depth (ND) Top Inc! ' SURFACE Top (ftK8) (RKB) (°) Description Comment Run Date ID (in) , 2,436 1,865 1,823.7 28.68 SAFETY VLV Camco TRDP-tA (LOCketl Out 7/27/84) 2!24/1983 2.81: 2 064 1,997.1 2982 GAS LIFT CAMCO/KBUG/1/DMY/BK//! Comment: STA 1 9!20/1993 2.87` GnsuFL -. Y= 399 3,484.6 39.01 GAS LIFT CAMCO/KBUGl1/DMYlBK//l Comment: STA2 9/20/1993 2.87` 3.95] '2: 5,198 4,487.3 32.97 GAS LIFT _-_. -_ CAMCO/KBUG/1/DMY/BKO/Comment: STA3 __ _ __ 9/20!1993 2.87`. 6,136 5,305.7 20.75 GAS LIFT CAMCO/KBUG/1/DMY/6W/1 Comment: STA4 9/19/1993 287`. ' 6 695 5 845b 9.541 GAS LIFT CAMCO/KBUG/1/DMY/BK/u Comment: STA 5 6120/2005 2 87; GAS LIFT, _ s.tse ' 6709 5,859.4 _ 9.76 ~i .SBR _. _ .__.. Baker wl Otis Profile _ 2!24/1983 -- 281: iDMYIBK/// GAS UFT. 6,695 BR. 6,]09--- - - - ~" i. .-'. . 6,957 6,968 6,969 Perfora _. Top (ftK8) 6,104.4 6,115.3 6116.3 tions 8 81m (flK6) 794 - 785 784 Slots '; Top (rV (ftK8) NIPPLE SOS TTL D) Btm (rVD) (flK6) Camco'D' Nipple NO GO 2lL4n 9US 1./D _ ___ Baker 2/24/1983 2.99 ELMD TTL aQ 6966'tluring (PROF on 10/2/2002 2/24/1983 2.99 i snot ~ _... ~ Dens I Zone Date (sh... ~ Type Comment 6,834 6,888 5,982.7 6,036.1 UNIT D, C-0, C-3 2124/1983 12.0 IPERF 6" Scallop; Dresser; 120 deg. C-2. 1Y 14 Phasing A-5, 1Y 14 7/25/2010 6 0 APERF 2 S" Millenium II HMX, 60 deg phase 7,020 7,025 6,166.8 6,771 7 PKR, 6,]35 _ - _ A-4, 1Y-14 2/24/1983 12 0 IPERF 5' Scallop; Dresser; 120 deg. 7,032 7,044 6,178.7 6,190.6 ' 1 I Phasing y ,_ ___ 7 076 6,201.5 6,22231 A-3, 1Y-14 12/24/1983 12.0 fPERF 5" Scallop; Dresser; 120 deg. 7.OSS j Phasing NIPPLE, 6,7]4 -- -- _ Notes: General & Safety _ ------ - End Date Annotation 10/2/2002NOTE: ST RADDLE TUBING LEAK a~ 6860' ((PROF) INdEC 6(00 _ +' 6/30/2005 ~ NOTE: TUBING LEAK a~ 6688' (E-LINE LDL) 8 I __ _. _ - _ IPERF,__ - 6,834-6.888 - j E ' INJECTION. f ~ ' 6.511 F i 3 ACKER, 6,528 f .~~ ~f.. ~. ~ - li NIPPLE, 6.557 SOS. 6.968- - TTL. 6,969- ----- - APERF,__ _ ___ ],020-],025 - - -- IPERF, ],032-7,044 -- IPERF,____- ~- 7.055-],0]6 'RODUCTION, _ 7.320 iD, ],398 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 16, 2010 11:04 AM To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); Peirce, John W Subject: RE: 1Y-14 (PTD 183-023) Regarding Sundry #310-052 Not a problem... will add this procedure to the 310-052 sundry. Just be sure and report~al(the wellwork for both patches on the 10-404. Regards, Guy Schwartz ~,~, ~r~r~ 1~ ~% ~~ Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Problem Well Supv [mailto:n1617@conocophillips.cam] Sent: Tuesday, March 16, 2010 10:49 AM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); NSK Problem Well Supv; Peirce, John W Subject: 1Y-14 (PTD 183-023) Regarding Sundry #310-052 Guy, As per our discussion on the phone, ConocoPhillips would like to add the tubing patch above the top packer to Sundry #310-052. Attached is a copy of the procedure for setting the patch. Following a successful set of the tubing patch, a witnessed MITIA will be performed once the well has thermally stabilized. Please let me know if this would be acceptable. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 3/16/2010 General Well Wor• equest Form ---- Well: 1Y -14 Type (inj/prod) Inj ~ Budget Category: ~e use Date: 3/6/10 Job Scope: Tubing/Casing Patel, ........ From: Martin waiters / Brent Rogers ~ WBS / Ntwrk: ....................................................................... Phone/Page 659-7224, pa er 909 Job /SAP Comment ...................................... ----- DSE: i Mark Kovar, 265-6097 ~ ~ ----- Estimated Cost: ................. .... NOB: Job Types: Slickline E Line Coil Tubing PT Casing _~L_1 ~ (set WRP) ~ ~ Run Dummy Gun/Patdi~ Otlier (TS ann com) ~ Set Patch Set Packer t ICI ~D l~3- az3 Distribution Paper E-mail Wells (2) CPF Supv. DS Lead DSE ATO-370 Other ~~ ICI ~~~ II SETCIM Shut-in Reason Code: vo Tubing /casing /Packer Leaks Justification: 1Y-14 recently had a stuck selective patch fished that had been stuck since January 2006. The well previously had a patch installed across GLM #5 that temporarily successful. A patch to isolate the TxIA communication needs to be completed prior to initiating A sand only injection . This procedure assumes that a new selective patch has already been set. Objective: Set patch over tubing leak above the top of GLM #5. Background: The well will be tagged prior to setting the selective patch and may need an FCO. Last tag on 4/28/03 indicates 11' of fill Last SBHP was A & C Sand = 2657 psi on 8/26/09 after 1403 days SI time. Minimum ID above patch area is 2.812" in the locked out Camco TRDP-1A SSSV at 1865' . ~ 1_ T~' PDS caliper log run on 11/14/05 shows one isolated pit 2' above GLM #5 with no other penetrations > 17% ~~ Q$Z SLB LDL run on 06/30/05 indicates a lone leak at 6688' above GLM #5 3 ~ 0 ~ Well currently has dummies installed in all 5 GLM's S Previous patch packers were set at 6684' and 6705' RKB ~o ~L All patch depths reference SLB LDL on 06/30/05 ~ 3' Well has been shut in since 11/23/05 PWS Confirm that data obtained by running a caliper survey as a part of selective patch does not require this procedure to be changed. Slickline: 1) RU i£ RIH and make gauge run <2.812" through Camco W-1 nipple at 6774' RKB ~~ / ~ S ~ .~~-S 2) RIH and set positive plug in Camco W-1 nipple at 6774' RKB ` 3) Perform TxIA CMIT to 2500 psi. ~~~ p „[~ ~.~ 4) RIH and pull positive plug in Camco W-1 nipple at 6774' RKB Y c-. E-Line: S~e~i~ir,t ea-'~G~ t•S 1) RU, RIH with Weatherford ER Packer and set with mid element in middle of pup joint below GLM#5 at 6700' LDL. ~• Slickline• 1) RU &RIH with ER packer plug and set in ER packer at 6700' LDL. Perform TxIA CMIT to 2500 psi. 2) RIH with HES ETD/DPU or WFT slick pump, ER packer, + 22' spacer pipe, and RS Anchor Seal Stinger. 3) Sting into lower ER packer and set upper ER packer with mid element at + 6675' LDL. 4) RIH with ER packer plug and set in ER packer at 8675' RKB. Perform MITT to 2500 psi. 5) RIH and pull ER packer plug 6) RU LRS to IA and perform MITIA to 2500 psi 7) Tum well over to Production DHD: 1) MITIA once online and stabilized 1Y-14 Patch 03-06-10.x1s • • Proposed 1Y-14 Tubing Patch Installation 1Y-14 is a selective in ector with 3.5° tubing. This well has been shut-in since late 2005 due to nn Comm tubin leaks nd a large leak in the C sand selective that accepts most of the PWI. ~ - 4 had tubing patches in it previously to isolate these leaks, but the patches eventually failed and were removed from the well -~ St~Cti,~~- An (PROF ran 10/08/02 verified a tubing leak is present at 6860'RKB allowing PWI to enter the C sand selective. A 20' tubing patch will be constructed with straddle packers for 3.5° tubing. E- line will set the lower straddle packer a# 6870' RKB. Arun #2 assembly consisting of a 20' spacer pipe and upper straddle packer will be run on Slicktine. Run #2 will anchor-latch into the lower straddle packer and the upper packer will be set at 6850' RKB to complete a new patch at 6850 - 6870' RKB. Per this procedure, a new tubing patch will be installed to isolate the C sand leak, and to convert the 1Y-14 to `A sand only' PWI. A separate 10-403 will be submitted later to address Annular Communication tubing-leak-repairs. Objective: Install a retrievable patch across a tubing leak at 6860' RKB to halt PWI entering the C sand. Procedure: Slicktine: 1. RIH 8~ tag PBTD to determine the need for possible coil tubing fill cleanout. The last / PBTD tag in 1Y-14 was on 4/28/03 at 7065' RKB (11' Fi11). Coil Tubing of needed): , 2. If the tag in step #1 was made shallower than 7076' RKB, this indicates fill is covering ~ perforations. If this is the case, perform a CT FCO as deep as possible to remove the fill from the well and to create some rat hole prior to installing a tubing patch. Slicktine: 3. Brush & flush 3.5" tubing in the area where a new tubing patch will be set. 4. Run a Caliper log from the tubing tail at 6969' RKB to surface to verify the overall mechanical condition of the tubing before running a tubing patch assembly. The tubing ' is 28 year old 3.5° J-55. ~`~~,~ t ,;. ~ ~~: E-line: 5. RIH with a straddle Packer and set the packer in the 3.5" tubing at 6870' RKB. Slicktine: 6. RIH with a straddle Packer, 20' spacer pipe, and Anchor Seal assembly. Latch into lower packer at 6870' RKB and set top ER packer at 6850' RKB to complete a new tubing patch at 6850 - 6870' RKB. Set a test plug. PT the top packer. Pull plug. RD. ~p 2/18/2010 STATE OF ALASKA ALAS IL ANp GAS CONSERVATION COMMI~N REPOOF SUNDRY WELL OPERATIONS. t. Operations Performed: Abandon Repair well Plug Perforations J" Stimulate " Other ~, Pull patch After Easing ~' PuI1 Tubing ~ Fl?rforate New Fbol (' Waiver Time 6ctension ""` Change Approved Program ~ Operat. Shutdow n Perforate ~""` Re-enter Suspended Well `" 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: Gonocophillips Alaska, Inc. Development ~""" 6cploratory 1$3-023 3. Address: Stratigraphic ~""" Service .API Number: P. O: Box 100360, Anchora e, Alaska 99510 50-029-20910-00 7. Property Designation: '`~- 8. Well Name and Nu~ber: ADL 25548 1Y-14 9. FiekilPool(s): ~, kuparuk River Field / Kuparuk River OiI Pool 10: Present Well Condition Summary: Total Depth measured ~ 73$6 feet Plugs (measured) None true vertical ~ 6530 feet Junk (measured) None Effective Depth measured 7239' feet Packer (measured) 6735`, 692$' true vertical 6384 feet (true vertucat) 5885', 6076' Casing. Length Size MD ND 'Burst Collapse CONDUCTOR 114 20 114 114' * SURFACE 2436 10.75 2436 2316' ~~~~~ ~~~ PRODUCTION 7320 7 7320 6464' MAR 0 9 2010 ~C8 01 & Gas CAns. Ga~'n Perforation depth: Measured depth: 6834'-68$8', 7032'-7044', 7055'-7076' A True Vertical Depth: 5983'-6036', 6179'-6191', 6202'-6222' ..~_'~~~~~~ ~~Art ~ ix ~01f Tubing (size, grade, MD, and TVD) 3.5, J-55, 6969 MD, 6116 TVD Packers & SSSV (type, MD, and TVD) PKR -BAKER 'FHL' PACKER 6735` D and 5885 TVD PAGKER - BAKER'FB-1' PACKER Q 6928 MD and 6076 TVD CAMCO TRDP-1A 1865 MD and 1824 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): nOt appllCable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Si Subsequent to operation si 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development ~ Service . Well Status after work: Oil ~ Gas ~ WDSPL Daily Report of Well Operations XXX GSTOR ~""" WAG ~ GASINJ WINJ ~ SPLUG j "` 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 310-012 contact .John Peirce Cad 265-6471 Printed Name John Peirce Title Wells Engineer Signature /~ ~ Phone: 265-6471 Date ~ .. ~ ^ ~~ Gtr ~' Form 10-404 Revised 7/2009 Submit Ori nal Only R6DMS MAR 0 9 ~0~~~ 3 . «, w . ~~ - ' v 1Y-14 Well Events Summary DATE SUMMARY 2/8/10 RAN 2.6" LIB TO 6791' SLM, PIC~FILL. RAN BAILER, RECOVERED FILL~OD MARKS f/ BAIT SUB. IN PROGRESS. 2/9/10 RAN PUMP BLR TO TOP OF FISH @ 6834' RKB, NO RETURNS. LATCH FISH W/ GR PULLING TOOL, HIT 61300# OJ LICKS BEFORE SHEAR. RAN HOLEFINDER, TESTED TBG @ 6683' RKB, GOOD. JOB COMPLETE 2/14/10 ATTEMPTED TO FISH STUCK PATCH ASSEMBLY AT 6833' CTMD. ENGAGED BAITED 3" JDC ON BAKER K3 PACKOFF ASSEMBLY. THE 3" JDC SHEARED PREMATURE. INPROGRESS 2/15/10 FISHED STUCK PATCH ASSEMBLY FROM 6820.5' CTMD. PATCH CAME FREE AFTER THREE 30K JAR LICKS. TRAPPED FISH IN MASTER VALVE. ORIGINAL PATCH ASSEMBLY OAL= 53', CONSISTS OF 2.31" EXTERNAL FISHNECK, BAKER K3 PACKOFF, SPACER PIPE, AND SNAP LATCH. READY FOR SLICKLINE. 2/16/10 PULLED 53' K-3 PACKOFF,SPACERPIPE SNAP LATCH ASSY.MISSING 1/3 OF K-3 ELEMENT.FLOW CUTTING JUST BELOW K-3 AND APPROX 27' BELOW ON SPACERPIPE.PULLED LOWER ECLIPSE PKR FROM 6886' RKB LOtt(3Ci7Pr11~~1~$5 ~ t I t ' .Well Attributes Max Angle 8 MD !TD ~ Y,I,. I l l 1 ., .. '. W Ilbore APl/U WI ', Field Name (Well til:~liis Inc)(') MD (ftKB) _~OU29 20 9 1 00 0 ',KUPARUK I.11V Eh IJNff INJ 4150 3,10000 ActBM (ftK8) 7,398.0 Entl Date 'KB-Grtl (ft) Annotation ~C H2S pl nl Data em Rig Release Date g ~,yq4 2rlvm.o :,zo wen cony ~.+ i Last WO. 42.01 SSSV LOCKED OUT 2/24/1983 - .. . __. Srliemauc A. it o A Depth (ftKB) End D 1 Ann fation Last Mod By oration End Date i - _ ~ Last Ta 7,065.0 4C'k _CU" Rev Reason: Pull Patrh Assy, Fish Imosbor 9 2121!2010 __. - Ca .Ind Stri gs ~ - .v fdnIQE55 FJl _ Y p ~ _ St Set Depth Set DePth;NO) Stiing WtWt r String g 0D ..b ,y ID -~ ~ ( 1 P ( ) ( nl To ftK8 (ftKB ftKB i (Ibslk) Grade String Top Thrd conlDUCroR. CONDUCTOR 20'~ 18936 00 114.0 114.0'', 9200 H-00 'ISURFACE 103/4 '~41 00 2,436.0 2,315.9'. 45-50', K-55 'PRODUCTION ~ 7 F. 161 00 7.320.6 6,4644 2GOOKSS SAFETV VLV, , ass ~ _ . LTubing Strings _- String OD ring ID Set Depth Set Depth (ND) String Wt String ' `~• lirii lop (ftKB) (ftK8) (ftKB) (Ibs/ft) Gratle String TOp Thrd Tubing Description (in) 1 USING 3 1/2 :992 0.0 6,969.0 6.116 "3 920IJ 55 BUTT Gns uFT, I', Other In Hole. {All Jewelry: Tubing Run & Retrievable, Fish, etc.) .. . 2.066 Top Depth ' ~ u TVD T p Inc) Top (ftKB) (ftKB) Des ~p[ion Co nent 1') Run Date ID (inl SURFACE. ~` _ 1.865 1,823. /'' 28.68 SAFCE I S ~. U~ Camco TRDP-1A (Locked Out 7!27/84) 224/1983 2.812 zpafi 2 064 1 997.1 29.82 GAS LIF1 CAMCO/KBUG/1/DMY/BK!!/ Comment: STA 1 9/20/1993 2.875 3,957 3,484.6 39.01 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment: STA2 9/20/1993 ~ 2.875 GAS LIFT, 5,198 4,487.3 32.97 GAS LIFI CAMCO/KBUG/1/DMY/BK///Comment: STA3 9/20/7993 2.875 3,957 6,136 5,305.7 20JSGAS LIFT CAMCG/KBUG/1/DMY/BK/ll Comment: STA4 9!19/1993 2.875 I 6,695 5,845.5 9.541GAS LIF I CAMCO/KBUG/7/DMYIB K/// Comment: STA 5 6/20/2005 2.875 '' 6709 5,859.4 9.76!SBR Baker wl Otis Profile 2/24/1983 2.813 GAS LIFT. 5.,sa 6,735 5,885-0 9.58PKR Baker'FHL'PACKER 2/24!1983 3.000 6,774 5,923.5 9.301 NIPPLE Camco'W-1'Nipple 224/1983 2.813 6,808 5,957.1' 9.19 INJECIIGN ICAMCO/KBUGl1/DMYlBK//1 Comment: CLOSED STA6 5112/1997 2.875 GAS LIFT, 6,911 6,058.8' 8.331NJH_~II(iN '~CAMCO/KBUG/1/DMY/BK!//Comment: CLOSEDSTA7 5112/1997 2.875 6.136 6,928 6,075.7 8.18 PACKER Baker'FB-1' PACKER 2/24/1983 4.000 6,957 6,104.4 7.94 NIPPLE Camco'D' Nipple NO GO 2/24/1983 2.750 6968 6,115.3 7.85 SOS Baker 2/24/1983 2.992 6,969 6 116.3 7.84 TTL ELMD TTL ~ 6966' during IPROF on 10/22002 224/1983 2 992 GAS uFT, 6.695 ' j ' , Perforations & Slo_ is Shot Top RVD) Btm {T'VD) i Dens ',I ~ 'i (sh~~~ I Type Comment Top (ftKB) Btrn (ftKB) (ftKB) (fIKBj Zone Date _ seR.s709- 6,834 6,888 5,982.7 f,.,(r3G-1 UNIT D, C-0, C-3 2/24/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. C-2, 1Y-14 Phasing I __ 7,032 7,044 6,178.7 6,.1905 A-0, 1Y-14 224/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. Phasing 1 ~. t 7,055 7,076 6,201.5 223 A-3, 1Y-14 2/24/1983 12.0 IPERF 5" Scallop; Dress er; 120 deg. PKR, s,73s-_ ~ Phasing _ ', _ _ Notes: General 8c Safety _,., ''~~ .. _- =- .,._ , _e End Date Annotation 10/2/2002 iNOTE STRADDLE- iVEING LEAK @ 6860' (IPROF) NIPPLE, s.na -- -' 6/30/2005 (NOTE: TUBING LEAK, F:16688' (E-LINE LDL) INFECTION, _ ~ ~ I 6,60E ~- _ ~ 'I IPERF, 6.839-6.888 INJECTION. 6,9, PACKER.6.928- NIPPLE, 6,557 SOS, 6 568 TTL, 6,969 IPERF. 7.0327,044 IPERF, 7,055-7.076 PRODUCTION, T^ ],320 • • Mr. John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ti`~3 ~a3 Re: Kuparuk River Field, Kuparuk Oil Pool, 1Y-14 Sundry Number: 310-052 a~Y~ Dear Mr. Peirce: 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. 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, Daniel T. Seamount, Jr. Chair . ~ ~~ DATED this -day of February, 2010. Encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISS~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Ail & bas Casa. Comrnssion 1. Type of Request: Abandon ~"'" Plug for Redrill ~', Perforate New Pool ~"-'"; Repair w ell `~ Change Ap~~m Suspend ~ Plug Pertorations Pertorate Pull Tubing ;"'" Time Extension Operational Shutdown ~"'" Re-enter Susp. Well Stimulate "` Alter casing °" Other: Install Patch ~" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development """ Exploratory 183-023 • 3. Address: Stratigraphic ~ Service , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20910-00 ' 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 Required? Yes ~ NO ;/ 1Y-14 9. Property Designation: 10. Field/Pool(s): ADL 25548. Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7386 6530 7239' 6384' 6834' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 20 114' 114' SURFACE 2436 10.75 2436' 2316' PRODUCTION 7320 7 7320' 6464' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6834'-6888', 7032'-7044', 7055'-7076' 5983'-6036', 6179'-6191', 6202'-6222' 3.5 J-55 6969 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PKR -BAKER 'FHL' PACKER MD= 6735 TVD= 5885 PACKER - 3" ECLIPSE PACKER MD= 6886 TVD= 6034 PACKER -BAKER 'FB-1' PACKER MD= 6928 TVD= 6076 CAMCO TRDP-1A MD= 1865 TVD= 1824 12. Attachments: Dascription Summary of PI'oposal ~' 13. Well Class after proposed work: Detailed Operations Program ~"'" BOP Sketch j""` E~loratory Development ~"'' Service ~` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2010 Oil Gas " WDSPL Plugged '` 16. Verbal Approval: Date: WIND GINJ WAG Abandoned Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John P21fCe Title: Wells Engineer Signature (/~ c -- Phone: 265-6471 Date 2 -1 Cj-1 Commission s nl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ - ~JS~ Plug Integrity " BOP Test ~ Mechanical Integrity Test ~"` Location Cl earance ~"" Other: Subsequent Form Required: ~ 0 ~ /d r Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: `~ ~ ~ RBQ~~' ~ ~2~W9 R 4 G 1 N A L ~ Z• /~. /D Submit in Duplicate Proposed 1Y-14 Tubing Patch Installation 1Y-14 is a selective injector with 3.5" tubing. This well has been shut-in since late 2005 due to Ann Comm tubing leaks and a large leak in the C sand selective that accepts most of the PWI. 1Y-14 had tubing patches in it previously to isolate these leaks, but the patches eventually failed and were removed from the well. An (PROF ran 10/08/02 verified a tubing leak is present at 6860' RKB allowing PWI to enter the C sand selective. A 20' tubing patch will be constructed with straddle packers for 3.5" tubing. E- line will set the lower straddle packer at 6870' RKB. Arun #2 assembly consisting of a 20' spacer pipe and upper straddle packer will be run on Slickline. Run #2 will anchor-latch into the lower straddle packer and the upper packer will be set at 6850' RKB to complete a new patch at 6850 - 6870' RKB. Per this procedure, a new tubing patch will be installed to isolate the C sand leak, and to convert the 1Y-14 to `A sand only' PWI. A separate 10-403 will be submitted later to address Annular Communication tubing leak repairs. Objective: Install a retrievable patch across a tubing leak at 6860' RKB to halt PWI entering the C sand. Procedure: Slickline: RIH & tag PBTD to determine the need for possible coil tubing fill cleanout. The last PBTD tag in 1Y-14 was on 4/28/03 at 7065' RKB (11' Fill). Coil Tubing (if needed): 2. If the tag in step #1 was made shallower than 7076' RKB, this indicates fill is covering ~ perforations. If this is the case, perform a CT FCO as deep as possible to remove the fill from the well and to create some rat hole prior to installing a tubing patch. Slickline: 3. Brush & flush 3.5" tubing in the area where a new tubing patch will be set 4. Run a Caliper log from the tubing tail at 6969' RKB to surface to verify the overall mechanical condition of the tubing before running a tubing patch assembly. The tubing ' is 28 year old 3.5" J-55. E-line: 5. RIH with a straddle Packer and set the packer in the 3.5" tubing at 6870' RKB. Slickline: 6. RIH with a straddle Packer, 20' spacer pipe, and Anchor Seal assembly. Latch into lower packer at 6870' RKB and set top ER packer at 6850' RKB to complete a new tubing patch at 6850 - 6870' RKB. Set a test plug. PT the top packer. Pull plug. RD. JWp 2/18/2010 A ~ ~ KUP ~ 1Y-14 __ ~C)(lt3~OP~'1i~~Ip~ ~ '' Well Attributes _ _ 'Max Angle & MO ,TD Wellhore API/UWI Fieltl Name WeI15tatus ''~, Inc! (°) MD (ftKB) iActBM (ftKB) '""`°`"~ ~ f 500292091 U00 KDPARDK F.VJL-F: UNIT INJ ~ 41.50 3,100.00 7,3980 Canment H25 {ppnl (Date 'Annotation /End Date ~KB-Grd (ft) (Rig Release Dat ••• ccc~r ~ n~wn nl IT ~ I a<t wr>~ 4201 2/24/1983 CONDUCTOR,- _J 114 SAFEN VLV, _ _ t.66s GAS LIFT, 2964 SURFACE, 2,436 GAS LIFT, 3 55] GAS LIFT, 5.15fl GAS LIFT. _. _ 6,136 GAS LIFT. ` 6.695 SBR. 6,705- PKR. 6.735 NIPPLE, 6.]74 INJECTION. 6 806 fISH. 6.834 IPERF. 6,836-6.888 PATCH, 6,838 PACKER. 6 B8fi INJECTION, 6.511 PACKER, 6,528 NIPPLE. 6.957 ~, String OD String 10 Set Depth Set Depth (NDj String WI String ~ Casing Description I (in) lini Top (ftKB) (ftKB) (ftKB) (Ibslft) Gentle String T_op Thrd_ CONDUCTOR 20 18536 0.0 114.0 114.0 92.OO,H-00 SURFACE 103/4 ;'bl 00 24360 2,315.9 45.50 K-55 I I PRODUCTION T~ I. 7fi1 0.0 7,320.0 6,464.4 26.001 K-55 ;Tubing Strings _ _. _ ~, St ing OD 'itriny I^ Set Depth Set Depth (ND) SVing WI String TubingD Iption ~ (in) lini Top (ftK6) (ftKB) (ftKB) (Ibslft) Grade ( String Top Thrd TUBING I 3112 2!:i92 0.0 6,9690 G,116.3 i 9.20IJ-55 BUTT Other In Hole jAll_Jewelry: Tubing Run 8 Retrievable, Fish, etc.) - -___ - -- 1 rop Deptn I (TVD) Top Inc! '~To (ftKB) (ftKB) I (°) Description ~I Comment Run Date IID (in) 1,865 1,823.7 28.68 SAFE I Y VL\/ Camco TRDP-tA (Locked Out 7/27/84) 2/ 24/1983 2.812 2,064 1 997.1 29.82 GAS l_IF I CAMCO/KBUG/1/DMY/BK/// Comment: STA 1 9/ 20!1993 2 875 3 957 3,484 6 39.01 GAS LII-1 CAMCO/KBUG/1/DMY/B W// Comment: STA 2 91 20/1993 2.875 5,198 4,487.3 32.97, GAS LIFI CAMCOlKBUG/i/DMYBK///Comment: STA3 9/ 20/1993 2.875 6,136 5,305.7 20.75 GAS LIF ~I 'CAMCOIKBUGl1/DMYIBK!//Comment: STA4 9/ 19/7993 . 2.875 ~ 6,695 5,845.5 454 GAS LIFT CAMCO/KBUG/1/DMY/BKII/Comment: STAS 6/ 20/2005 2.875 ''~ 6,709 5,859.4 9.76 SBR Baker w/ Otis Profile 2/ 24/1983 2.813 6 735 5,885.0 9.58 PKR Baker'FHL' PACKER 2 24/1983 3.000 6,774 5,923.5 9.30'i NIPPLE- Camco'W-1' Nipple 2/ 24/1983 2.813 6,808 5,957.1 9.19 INJEC I ION CAMCO/KBUG/1IDMYIBW//Comment: CLOSED STA 6 5/ 121997 2.875 6,834 5,982.7 897 FISFI 10 /23/2005 0.000 6,838 5,986.7 8.94 PATCfI BAKER K3 PACKOFF (525')1SNAP LATCH ASSY. 8/ 10/2005 1.430 PULLED SLIPSTOP & SLEEE OFF K-3 ON 1/1212006. PLANTED BAITED 3" JDC (OAL=25"), 2.31" INTERNAL FIN 6,886 6,034.1 8.54 PACKER 3" ECLIPSE PACKER 5/ 222003 1.812 I. - 6,911 6,058.8 8.33 1NJECIPDN ~CAMCOIKBUGl1/DMY/BK1!/Comment: CLOSED STA7 51 121997 -2.875 6,928 6075.7 8.18 PACKER Baker'FB-1'PACKER 2! 24/1983 4.000 6,957 6,1044 7.94 NIPPLE Camco'U'Nipple NO GO 2/ 24/1983 2750 I 6 968 6.115.3 7 85 ~'. SOS Baker 2/ 24/1983 2.992 C 4 TTL ELMD TTL @ 6966' during (PROF on 10/2/2002 2/ 24/1983 2.992 sr $(015 PerfOratlOflS ,- ' Shot Top (TVD) Btm (ND) Dens Top (ftKB) i 61m (ftKB) ~~ (ftKB) (ftK81 Zone I Date (sh-~ Type CommerA _ _ 6,834 6,888 5,982.7 G,03G.1 UNIT D, C-0, C-3 224/1983 12 0 IPERF 5" Scallop; Dresser; 120 deg. C-2, 1Y-14 Phasing 7,032 7,044 6,178.7 6.-190 r, A-0, tY-14 224!1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. Phasing 7,055 7,076 6 201.5 %.222.3 A-3, 1Y-14 224/1983 12.0 IPERF 5" Scallop; Dresser; 120 deg. Phasing Notes: General 8 SafetY - _ -- - End Date Annotation _ 102/2002 .NOTE: STRADDLE I UBING LEAK @ 6860' ((PROF) 6/3012005 NOTE TUBING I_EA.K (n 6688' (E-LINE LDL) sos. s.5s6 I z I TTL. 6.v65- IPERF, ],032-] 044 IPERF, 7,0.55-],9]6 PRODUCTION, ],329 TD, 7 398 '~ti ~s ~afic.~. ~ta5 r'e~no e- oh z1~5-zl~~l~o. • • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~~'~ ~ A "` ~ rty ~ ~ ~~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 1Y-14 Sundry Number: 310-012 Dear Mr. Christensen: 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, DATED this Z~ day of January, 2010 Daniel T. Seamount, Jr. Chair Encl. u ConocoPhillips January 14, 2010 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 REC~IVE® JAN ~. 9 2Q1U Dan Seamount AOGCC Comissioner Ala~B 0~ S E~6i Ceps COI~NYtI$$IQII AnchKape State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to attempt to pull a stuck retrievable tubing ~ patch in Kuparuk Well 1Y-14. ~Enclos~d you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1Y-14 (PTD 183-023). If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659-7535. Sincerely, ~~ ___ Robert D. Christensen Attachments ~~ U' " , ~0 STATE OF ALASKA ~~ l~ V' ALA OIL AND GAS CONSERVATION COMMIS `~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECE~VEC~ JAN 1 9 2010 1. Type of Request: Abandon r Plug for Redrill [` Perforate New Pool r Repair w en ~ • I~~a® Suspend ~ Plug Pertorations r Perforate r Pull Tubing r ~-~~on Operational Shutdow n r Re-enter Susp. Well r Stimulate r ARer casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-023 3. Address: ~ Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20910-00 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 Required? Yes r No r 1Y-14 9. Property Designation: 10. Field/Pool(s): ADL 25548 Kuparuk River Field / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7386 + 6530. 7386' 6276' Casing Length Size MD ND Burst Collapse CONDUCTOR 114 20" 114' 114' SURFACE 2436 10-3/4" 2436' 2316' PRODUCTION 7320 7" 7320' 6464' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6834-6888'; 7032-7044'; 7055-7076' 5983-6036'; 6179-6191'; 6202-6222' 3.5 J-55 6969 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PKR - BAKER'FHL' PACKER MD= 6735 ND= 5885 PACKER - 3" ECLIPSE PACKER MD= 6886 ND= 6034 PACKER -BAKER 'FB-1' PACKER MD= 6928 ND= 6076 LOCKED OUT - ~AMCO TRDP-1A (LOCKED OUT 7/27/84) MD= 1865 ND= 1824 12. Attachments: Description Summary of Proposal ~' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r' 14. Estimated Date for Commencng Operations: 15. Well Status after proposed work: Janua 15, 2010 pil r G r WDSPL r Plugged (` 16. Verbal Approval: Date: as WINJ r GINJ ~ WAG ~ Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Title: Production Engineering Specialist Signature ~ Phone: 659-7535 Date ®~ / -~® C m i i n 1 Sundry Number. Conditions of approval: Notify Commission so that a representative may witness ~ `~ <, Plug Integrity r BOP Test [` Mechanical Integrity Test r Location Clearance [' Other. Subsequent Form Required: ~~ ~ 7 ~ ~-,/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION ~f Date: r/ ~BDMS JAN.2 l 2010_ ~ ~ ~ ~ ~ ' ~~ ~ ~ i . ~ ., ,,. talon rorm i u-4vs rcevrsea-1~uu!y ~ • ~ L ~ ~ - G v-~ v .7UUfTlli Irl UUF711k:d16 E~ 1 Y-14 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. requests approval to attempt to pull a stuck retrievable tubing patch located at 6838' and / 5987' tvd in Kuparuk Well 1Y-14. The well has been shut in since 2005 with a patch stuck in the selective. The well also. has an ann com leak above the top packer located at 6735' and / 5885' tvd. The well previously had two patches installed, one of which leaked in the selective. The upper patch was pulled successfully while the patch in the selective could not be pulled after one day of fishing with CT. The well has some benefit as an 'A' only injector. If we can retrieve the stuck patch, a new dual patch design will be run in order to achieve A sand only injection. An injection rate of about 1200 bwpd is expected in the A sand. REPAIR PLAN 1. Rig up 2" coil tubing unit and comence jarring on stuck patch. If no progress after two days of fishing with coil, terminate the job. 2. If fishing is successful, leave well shut in until a new patch design can be run ~- • ~,, ~~~ KU P r 1 Y-14 COIlOCO~'li~~Ip S W ell Attributes Max An le 8 MD TD AI2ShA I11~ . Wellbore APl/UWI Field Name WeIISWNs Intl (°) MD IftK8) Act Btm l(t KBI . 500292091000 KUPARUK RIVER UNIT INJ 41.50 3,100.00 7,398.0 Comment H25 lppm) Date Annotation End Data KB~L'ird (R) Rig Release Date SSSV: LOCKED OUT Last WO: 42 01 2/24/1 983 Well COnfi '.-tY-1{1h 2070733 :~3PM . merit- I Annotation Depth (ftK8) End Data Annotation last Mod ey End Date Last Tag: 7,065.0 4/28/2003 Rev Reason: DELETE PACKER @6834' Imosbor 1/1/2010 Casin Strin s String OD String ID Set Depth bet DepN (TVD) 6tring Wt String CONDUCTOR Casing Descrlptlon lint Ilnl Top IftKBI IRKB) (RKBI IIDa/fl) Grade String Top ThrO , 1/e CONDUCTOR 2 0 18.936 0.0 114.0 114.0 92.00 H~0 SURFACE 103! 4 9.794 0.0 2,436.0 2,315.9 45.50 K-55 sAFEryvLV, PRODUCTION 7 6.151 0.0 7 320.0 6 464.4 26.00 K-55 1.865 , , Tubin Strin s String OD String 10 Sat Depth Set DepN ITV0) Slring Wt String ~ Tubing Descrlptlon lint Ilnl Top (RKB) IRKB) (RKB) (lbsttt) Grade Skiing Top Thrd GA6 LIFT, TUBING 31/ 2 2.992 0.0 6,969.0 6,116.3 9.20 J-55 BUTT z,osa Other In Hole A ll Jewel :Tubin Run & Retrievable Fish, etc. Top DepN SURFZa E~ / ~ Top (RKR) (TVD) (~B) Top Intl (°) DescNptlon Comment Run DatO ID (in) 1,865 1,823.7 28.68 S AFETY VLV Camco TRDP-1A (Locked Out 7/27/84) 2/24/1983 2.812 GA6 LIFT, 2,064 1,997.1 29.82 G AS LIFT CAMCO/KBUGl1/DMY/BK//I Comment: STA 1 9/20/1993 2.875 3,957 3,957 3,484.6 39.01 G AS LIFT CAMCO/KBUGl1/DMY/BW//Canment: STA2 9/20/1993 2.875 5,198 4,487.3 32.97 G AS LIFT CAMCO/KBUG/1/DMY/BW/I Comment: STA3 9/20/1993 2.875 G~ l 6,136 5,305.7 20.75 G AS LIFT CAMCO/KBUGl1/DMY/BK///CommentSTA4 9/19/1993 2.875 s i 9s 6,695 5,845.5 9.54 G AS LIFT CAMCO/KBUGl1/DMY/BK/I/Comment. STA5 6Y10I2005 2.875 6,709 5,859.4 9.76S BR Bakerw/OtisProfile 2124/1983 2.813 6,735 5,885.0 9.58 P KR Baker'FHL' PACKER 2I24I7983 3.000 Gns uFr. 6,774 5,923.5 9.30 N IPPLE Camco W-1' Nipple 2/24/1983 2.813 6 136 , 6,808 5,957.1 9.191N JECTION CAMCO/KBUG/1/DMY/BK!//Comment CLOSED STAG 5/1211997 2.875 6,834 5,982.7 8.97 F ISH 10/23Y2005 0.000 6,838 5,986.7 8.94 P ATCH BAKER K3 PACKOFF (52.5')/SNAP LATCH ASSY. 8/10/2005 1.430 Gns uFr, PULLED SLIPSTOP & SLEEE OFF K-3 ON 1/12/2006. 6s9s PLANTED BAITED 3" JDC (OAL=25"), 2.31" INTERNAL F/N 6,886 6,034.1 8.54 P ACKER 3" ECLIPSE PACKER 5!22/2003 1.812 6,911 6,058.8 8.33 IN JECTION CAMCOlKBUGIilDMY/BKII/ Comment: CLOSED STA 7 5/1211997 2.875 saR, 6709 6,928 6,075.7 8.18 P ACKER Baker'FB-1' PACKER 2/2411983 4.000 6,957 6,104.4 7.94 N IPPLE Camcn'D' Nipple NO GO 2/24/1983 2.750 6,968 6,115.3 7.85 S OS Baker 2/24/1983 2.992 '- ' 6 969 6,116.3 7.84 T TL ELMD TTL @ 6966' durirlg IPROF on 1OI2Y2002 2/24/1983 2.992 PKR, 6,735 , Pertorations 8r Slots Shot Top ITVD) Btm (TVD) Dens NIPPLE 6 770 Top IftX8) Btm (RK8) (RKB) (RKB) 2pne Date len... Type Comment , , 6,834 6,888 5,982.7 6,036.1 U NIT D, C-0, C-3 2Y24/1983 12.0 IPERF 5" Scallop; Dresser, 120 deg. C-2, 1Y-14 Phasing 7,032 7,044 6,178.7 6,190.6 A te, 1Y-14 2Y24/1983 12.0 IPERF 5' Scallop; Dresser; 120 deg. INJECTION, Pha6lflg 6.BD8 7,055 7,076 6,201.5 6,222.3 A -3, 1Y-14 2/24/1983 12.0 IPERF 5" Spllop; Dress Phasing er, 120 deg. _ Notes: General S Safe FISH, 6,830 -- End Dale Annotation - -_- 10/212002 NO TE: STRADDLE TUBING LEAK @6860' (IPRRF) 6/30Y2005 NO TE: TU81NG LEAK @6 688' (E-LINE LDL) IPERF, 6634-6,888 PATCH, 6,838 PACKER, 6886 INJECTION, 6.911 PACKER, 6.926 NIPPLE,6957 605, 6,968 ~ TTL, 6,969 IPERF, 7,032-7,M1 IPERF, 7,056-7,D78 PRODUCTION, 7,320 rD. 7,396 Re: lY-14 (P1'D 183-023) TxIA \/ Subject: Re: lY-14 (PTD 183-023) TxIA From: Thomas Mawider <tom _ maunder@admin.state.alcus> D~te: Mon," 03 Oct 2005 08:47:00 -0800 Tq:"NSK ProblemW ell Supv <p1617@c<?µocophiÚips.com>" ç¢: James Regg<jim_regg@àdmin.state.ak.us>· ) " ' " I ... ',. MJ, Your plan is acceptable. Please add this well to the monitoring list. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/3/2005 8 :26 AM: Tom, I wrote a procedure to pull the top of the patch and re run the spacer pipe and an eclipse packer (new top) as the DHD crew confirmed a failed MIT yesterday. My plan is for the repair to be completed this month. The well passed a combo MIT 6/25/05 prior to the first patch, therefore I'd like to leave the well online until Slickline can be scheduled. Post repair I'll ask the State Inspector to witness an MIT IA and complete a 10-404. The form for yesterday's MIT will be sent under a separate email. I also added the well back to the failed MIT report (submitted yesterday) Please advise whether it is acceptable to leave the well online. Thank you MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 5CANNED WOV ~ft ~ 2005 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, October 03, 2005 7: 13 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1Y-14 (PTD 183-023) TxIA MJ, Go ahead and continue the work under the original sundry. No need to add additional paperwork. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/1/2005 1 :37 PM: lof2 10/4/2005 7:58 AM Re: lY-14 (PTD 183-023) TxIA ) I Tom, More research on this well reveals that the top of the patch is a K3 packoff element. It is likely that that element is what failed (assuming the MITIA will fail). I'd like to pull the top of the patch and re run the same spacer pipe with an Eclipse packer top. Is this something I can do using the original 1 0-403 (#305-180) and re submit a 10-404 when complete. Or do I need another 10-403? The length and location of the patch will not change. Please advise. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Saturday, October 01, 2005 9:19 AM To: Thomas Maunder'; 'James Regg' Cc: NSK Problem Well Supv Subject: lY-14 (PTD 183-023) TxIA Tom, The DSO reported this morning that it appears the recently placed tubing patch as started to communicate on 1Y-14 ( PTD 183-023). TIIIO before bleeding 1600/2100/20. A MITIA will be conducted this week to confirm. Attached it a 4 week TIIIO - On this plot you can clearly see the original patch repair. Let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 « OLE Object: Picture (Device Independent Bitmap) » 2 of2 10/4/2005 7:58 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 11Y 1 0102/05 Arend 1 Greenwod - AES Packer Depth Well 1Y-14 Type Inj W T.V.D. 5885 P.T.D. 1830230 Type Test P Test psi 1500 Notes: Diagnostic MITIA - unable to pressure above 2250 psi Sundry # 305180 Well Type Inj. P.T.D. Type test Notes: TVD Test psi Well Type Inj. TVD P.T.D. Type test Test psi Notes: Well Type Inj. TVD P.T.D. Type test Test psi Notes: Well Type Inj. TVD P.T.D. Type test Test psi Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Pretest Initial 15 Min. 30 Min. Tubing 1750 1750 Interval 0 Casing 2100 2250 P/F F OA 0 0 0 Tubing Interval Casing P/F OA Tubing Interval Casing P/F OA Tubing Interval Casing P/F OA Tubing Interval Casing P/F OA INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1Y-1410-2-05.xls 10/4/2005 8:01 AM --- -' 1 of 1 oleO.bmp (BMP Image, 1262x780 pixels) }ICi~¡1~'~.-""'''i'';j1!r''''T:r'e "r~-'.I", ~ !Ø'II%.,t'W:J . 'HIIJ"'""',Wi~\\,:¡:!;t}[-·..'II" ",! '~'''''~'''¡;'''i!.' J'II/f'LJ¡~~':!~ \ \.'..~ 1~1'rr:,lj~ßII STATE OF ALASKA,.."", ALASKA OIL AND GAS CONSERVATION COMMISSION ,~BfJP JlID.1fi REPORT OF SUNDRY WELL OPERA TIO~~§'~lk;F,1 rm p.~ ìl::~:~'¡1 ,1'\,,,,,,,, Abandon D RepairWell 0 Plug Perforations D Stimulate D Otheri~:,[!:>,Q~·~::;.::" Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D . Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 183-023 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360 50-029-20910-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1Y-14 1. Operations Performed: ') ) 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casi ng Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7386' feet true vertical 6530' feet measured 7386 feet true vertical 6276' feet Length Size MD 114' 20" 114' 2335' 1 0-3/4" 2436' 7219' 7" 7320' Plugs (measured) Junk (measured) TVD Burst Collapse 114' 2316' 6464' Measured depth: 6834-6888',7032-7044'; 7055-7076' SCANNED NO" 0 9 Z005 true vertical depth: 5983-6036'; 6179-6191'; 6202-6222' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6969' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' pkr= 6735' sssv= SSSV TRDP-1A -locked out SSSV= 1865' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFL SEP 2 6 2005 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 3500 3500 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-180 Oil-Bbl Casing Pressure 2250 1800 Tubing Pressure 1900 1550 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations _X WDSPL 0 Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name Marie McConnell , ""-./'If /~itle Signature ø~ ~~ Phone ORIGINAL Problem Wells Supervisor 907 -659-7224 Date 9- / 3 .... os- Form 10-404 Revised 04/2004 Submit Original Only " ) 1 Y -14 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 9/5/2005 PULLED TTP @ 6774' RKB. DRIFTED TBG WI 2.79" G. RING TO TOP OF K-3 @ 6834' RKB. DRIFTED TBG WI 20' X 2.74" TO 6834' RKB. SET ECLIPSE PACKER WI ETD TOOL @ 6705' RKB. 9/6/2005 SET K-3 PACK OFF ASSEMBLY (21' LONG) IN ECLIPSE PKR @ 6705' RKB. SET SLIP STOP ON TOP OF K-3 @ 6667' SLM. MITIA TO 2500 PSI PASSED. OOH, STARTING PRESSURES BEFORE MITIA. T/IAlOA= 800/90010 PT IA.800/250010 AFTER 15 MINUTES 800/235010. BUMP BACK UP.800/255010 15 MINUTES 800/250010 30 MINUTES 800/250010. GOOD MIT 9/12/2005 State witnessed (John Spaulding) MITIA post tubing patch - Passed. Initial T/I/O= 1550/180010 Pressure up IA with 1.6 bbls diesel to 2500 psi, start MITIA T/I/O= 1550/250010, 15 minute reading T/I/O= 1550/246010, 30 minute reading T/I/O= 1550/246010 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~q q flb/ú; DATE: Friday, September 16, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-14 KUPARUKRIVUNIT lY-14 ,,3 \%'3/00- FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,:J~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 1 Y-14 Insp Num: mitJS050915202923 ReI Insp N urn API Well Number 50-029-20910-00-00 Permit Number: 183-023-0 Inspector Name: John Spaulding Inspection Date: 9/1212005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 Y-14 Type Inj. w ITVD 5885 IA I 1800 I 2510 2460 2460 I --I ---- P.T. 1830230 TypeTest SPT I Test psi 1471.25 OA 0 0 0 Interval OTHER P/F P Tubing I 1550 I 1550 1550 1550 - Notes Post patch MITIA Sundry # 305180 ~ÇANNl:t NOV f~ ~ 2005 Friday, September 16, 2005 Page I of I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J Mechanical Integrity Test 01'1 CI( î ! 0<;' Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU 11Y 09/06/05 Sid Fergason - HES (~3 ..--.- O')~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y-14 Type Inj N T.V.D. 5887 Tubing 800 800 800 Interval 0 P.T.D. 1830230 Type Test P T est psi 1500 Casing 900 2500 2350 P/F F Notes: Initial Pre State Witnessed Post patch MITIA OA 0 0 0 Sundry # 305180 Well 1Y-14 Type Inj N T.V.D. 5887 Tubing 800 800 800 800 Interval 0 P.T.D. 1830230 Type Test P T est psi 1500 Casing 2350 2550 2500 2500 P/F P Notes: Pumped back up for second test OA 0 0 0 0 0 Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: OA Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: OA Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: OA Test Details: 5(;ANlNElj INO\f Ð 3 2005 TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1Y-14 09-06-05.xls 9/7/2005 07/08/05 Schlumbel'ger NO. 3429 ¡ caOZ:Y'- 0 ~'3 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth - ~ . -, 0 -~ I ~ ,--'. ro ¡- r> p ç:; ()/.- rl n ¡:: -;..:r;;ÀN\~þ:.! :. "'-T w ,I l', __Ji).) -~ ¡¡¡i J'~ :;". ~ r.-..., ".=' ~ ~> u Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 2G-02 If¡ '1 -j). ( 11047334 BHP SURVEY 06/30/05 1 , 2G-13 (~ :¡ - i )....{ 11047336 BHP SURVEY 07/01105 1 ;, 2G-11 I~'-¡ -if'? 11047337 BHP SURVEY 07/01/05 1 ¥ 1Y-14)3~~ 01\ 11022907 LEAK DETECTION LOG 06/30/05 1 \'/3H-19 187 ·IJ J 11022907 PRODUCTION PROFILE 06/28105 1 \,I, 1 J-Ò3 JeA - C ^ 'f 11022893 PRODUCTION PROFILE 06/17/05 1 'J 1 L-09 I q ()." v j C{ 11022895 PROD PROFILE W/DEFT 06/19/05 1 ,;', 3S-10 ).0;" -1:\ 1. 11001235 PROD PROFILE W/DEFT 06/14/05 1 .i 3F-04 iJij'. )..).8 11022891 INJECTION PROFILE 06/15/05 1 1Y-26A ¡JJ'lt~ 11022892 PROD PROFILE W/DEFT 06/16105 1 v 1E-112J(¡i..f-({iI 11047339 INJECTION PROFILE U l (. 07/03/05 1 j 1E-102 ).."-...,..J.JI 11047340 INJECTION PROFILE LitC 07104/05 1 SIGNED: l~/ Ô jl...J~, " " DATE: I, ¡ ¿}IJ~p Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD ,~/ -- /\ \_ tJ_ . (J'''.. ~ -, :¿~ J - --., ) #' ~lCf?ßTrŒ ~ I I ! t, !: ~\~, U hi I U'! i rù [ i, '1 I I ' {~f?l I ( ¡II I I , ' 'U-.l \ ! i I \ [ ~, , ,II 'nl fÃ' \ ("ñì fl'~' :' ill 'i il~ l\'Uf!/:' ,'¡~ /~,\ Ii /.f:\ "~, :1,'\; lr~\ ,0\\, ,-i1~ ,I, ,!U " 1\ !iii U: n~ n~) 'U' ; ,,\ l,1!:! i" "l.::J j U ,\::::)) ! i 'u U"l \ l / / / FRANK H. MURKOWSKI, GOVERNOR A."tA.~IiA OIL AM) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. <10r,1-. P.O. Box 100360 SCANNED Jut 14 (- u::' Anchorage, Alaska ()",~ 'A""/ \COJ Re: Kuparuk 1Y-14 Sundry Number: 305-180 Dear Ms. Loveland: 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. Please provide at least twenty-four (24) hours 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 liday or weekend. A person may not appeal a Commission decision 0 perior Court unless rehearing has been requested. (fr/ S· C6I' ' , ~1 JoJr: .. orma i;b~i~ DATED this '~ay of July, 2005 Encl. ) ConocóP'hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JUL 1 2 2005 Alaska Oil & Gas Cons Co .. . mmlsslon Anchorage July 10, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 /v~ \0~ Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1 Y -14 (PTD 183-023). The approval request regards the repair of a Tubing leak. Please call me or Marie McConnell at 659-7224 if you have any questions. Attachments OQ! Cf ~'.'/J' 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 101' 8. Property Designation: Kuparuk River Unit 7,1¿,1hr RECEIVED I"). JUL 1 2 2005 o A'aska öifiSrG,as ICénsAð~.Oe:J o Time Exten~c1liõt8ge Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 183-023 6. API Number: 50-029-20910-00 9. Well Name and Number: 1Y-14 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6530 MD TVD Burst ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 o o o Suspend 0 o o Stimulate Perforate Repair well Pull Tubing 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7386' 6530' 7386 Casing Length Size CONDUCTOR 114' 20" SUR. CASING 2335' 10-3/4" PROD. CASING 7219' 7" Perforation Depth MD (ft): 6834-6888', 7032-7044'; 7055-7076' Packers and SSSV Type: pkr= BAKER 'FHL' SSSV= SSSV TRDP-1A -locked out 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 01AUG05 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Loveland / -./ Signature ~~þ~ - . 114' 2436' 7320' 114 2316 6464 Perforation Depth TVD (ft): 5983-6036'; 6179-6191'; 6202-6222' Packers and SSSV MD (ft) pkr= 6735' SSSV= 1865' Tubing Size: 3-1/2" Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed, work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness C<.L~__.\or o\>\O~.::\~ ~ \1'-)\ \-N::....S "" \.\ RBDMS 8FL JUL Plug Integrity 0 BOP Test 0 Other. Nc>\.~\. TN Mechanical Integrity Test ~ Location Clearance 0 ~ ORIGINAL BY ORDER OF THE COMMISSION COMMISSIONER INSTRUCTIONS ON REVERSE or! Collapse Tubing Grade: J-55 Tubing MD (ft): 6969' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 MJ Loveland/Marie McConnell Problem Well Supervisor Date /~:rt,)L~~ Sundry Number: 3ZJ5=-I8'lJ J 3 7D05 Date: 11 oS Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. Kuparuk WelllY-14 (PTD 183-023) SUNDRY NOTICE 10-403 TUBING REPAIR 07/10/05 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well1Y-14 with a tubing patch. On June 19, 2005, the AOGCC was notified of a failed :J\1IT. Subsequent diagnostics have identified a Tubing to IA leak near the top of GLM #5 at 6688']V[}). The plan is to patch the tubing with a retrievable patch with the center-center patch element length as 20' centered on the GLM. Following a successful MIT, the well will be returned to normal ~ater injection. REPAIR PLAN 1. Set 20' 3.5" retrievable patch from 6678' - 6698' with center of the lower element at 6698 ' 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post repair. NSK Problem Well Supervisor RE: 1 Y-14 (PTD 1830230) Failed MITIA ) ) S¿bject: RE: 1 Y -14 (PTD 1830230) Failed MITIA From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 21 lun 2005 14:44:51 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, Most of the older injectors had diesel to the packer. I'm not sure why they did that, maybe for corrosion protection or to avoid accidental tbg collapse. I haven't actually dug thru the drilling files for the IA fluid types, this is just an observation I've made as the older CPF3 water injection wells injecting at the water injection header pressure of 2850 psi will have a sustained IA pressure of about 3200 psi when the TxlA communication is first observed. When water injectors are waivered for TxlA comm, we limit the max IA pressure to 3000 psi. To keep these wells in compliance, the injection rate must be pinched back to lower the tbg pressure to -2500 psi to lower the IA pressure to just below 3000 psi. 3K-08 injecting under sundry approval #304-190 is an example of this problem. The well has corkscrewed tbg preventing removal of a lower DV to swap the diesel over to inhibited sea water. Injection has been pinched back, reducing water flood performance in this area to keep the IA below 3000 psi. 3A-11 injecting under sundry #301-344 also has the same T&IA trend. Fortunately, 3A-11 is a prolific injector so pinching the tbg pressure to 2500 psi doesn't restrict water injection rate by much. For newer wells (last +5 years), drilling has been leaving inhibited sea water in the IA with a 2000 or 2500 psi diesel cap. Marie -----Original Message----- SCl~~\ft.~\~EI·' ,JUI From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, June 21, 2005 2:22 PM To: NSK Problem Well Supv Subject: Re: 1Y-14 (PTD 1830230) Failed MITIA 4: 2,005 Thanks for the follow-up Marie. Do you all have full diesel columns in the IA?? I thought only the top 2000 vertical feet or so had diesel. Tom NSK Problem Well Supv wrote: Tom & Jim, 1Y-14 was SI on 6-20-05. A plug set in the tbg tail identified a tbg leak above the packer. Slickline was able to narrow down the leak point to between 6681 and 6657' WLM. This is around the bottom GLM. The SBR is at 6709', so there may not be much room to successfully set a tbg patch. The well was left SI with the plug for an upcoming Eline LDL to locate the exact leak location. Once the leak point is known a 10-403 application to repair the well or an administrative relief will be filed. Yes, the higher IA pressure is due to the diesel hydrostatic versus the water hydrostatic in the tbg. The typical rule of thumb for Kuparuk is a -400 psi dp between the tbg and IA with a packer leak and a diesel column in the IA. Please let me know if you have any questions. Marie McConnell 10f3 7/12/2005 12:13 PM RE: lY-14 (PTD 1830230) Failed MITIA ) ) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 20, 2005 6:57 AM To: NSK Problem Well Supv Cc: James Regg; bob fleckenstein@admin.state.ak.us Subject: Re: 1Y-14 (PTD 1830230) Failed MITIA Marie, It is acceptable to keep the well in service to perform your further diagnostics. With the fluid level at surface in the lA, I would presume that the delta pressure is due to the freeze protection at the top of the lA. Keep us informed of your testing. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Jim, & Bob, Attached is a failed MITIA form for 1Y-14. The MITIA failed on 6-18-05. Tbg packoff testing completed on 6-18-05 did not find a problem with the packoffs, there appears to be either a tbg or packer leak. A plug will be set in the tbg and diagnostic pressure tests will be conducted to identify the leak location. Approval to keep the well on injection until the tbg plug is set is requested. The tbg plug will be set within the next week, possibly as early as Monday 6-20-05. Once leak detection diagnostics have been completed, injection will remain SI until an AOGCC approved repair is completed or an administrative relief approved. The well has been added to the Monthly Failed MITIA report. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659- 7224 -----Original Message----- From: NSK Problem Well Supv Sent: Thursday, June 16, 2005 2: 10 PM To: 'Thomas Maunder' Cc: James Regg Subject: RE: 1Y-14 (PTD 1830230) Report of suspected TxIA comm Tom, Attached is a 90 day plot of WHPs for 1Y-14 from setcim. The tbg pressure is automated, IA & OA pressures are manual operator readings. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, June 16, 2005 12:50 PM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1Y-14 (PTD 1830230) Report of suspected TxIA comm 20f3 7/12/2005 12:13 PM RE: lY-14 (PTD 1830230) Failed MITIA ) ) Marie, Your report of communication is acknowledged and your plan forward is acceptable. Does the setsim data show any history of IA pressure?? If you can send in the last 90 days, that would be appreciated. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom & Jim, On the afternoon of 6/15/05, the DSO found the IA pressure on 1 Y -14 (Produced Water Inj) at 2200 psi. The DSO bleed the pressure down to 1600 psi, but the IA repressured to 2200 psi shortly after bleeding. TII/O as of 6/15/05: 1700/2200/60 at an injection rate of 5000 BWPD. The well has a history of one way TxlA communication that is repaired by re-energizing the McEvoy wellhead tbg packoffs. The tbg packoffs were last energized on 3/15/05. A state witnessed MITIA passed on 6/19/04 and a diagnostic MITIA passed on 3/15/05. Permission to keep this well on injection with a sustained IA pressure of 2200 psi is requested while performing TxlA communication diagnostics. Planned work includes re-energizing the tbg packoffs, MITIA, and bleeding the IA for a pressure build up rate monitor. Please let me know if you have any questions, Marie McConnell Problem Well Supervisor 659-7224 30f3 7/12/2005 12:13 PM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test l " ,jßP--- ,J I b oS' Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us ) I Ó:;'¡'Ó2 3 OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU/1 Y 03115/05 Brake/Rogers - AES Well 1Y-14 Type Inj P.T.D. 1830230 Type Test Notes: Diagnostic MITIA S P Packer T.V.D. Test psi Depth 5885 1500 Tubing Casing Pretest Initial 15 Min. 30 Min. 1300 1300 1300 1300 Interval 950 2690 2690 2960 P/F o P Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: SCANNED APR 2 0 2005 TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0= Other (describe in notes) M IT Report Form Revised: 05/19/02 MIT KRU 1Y-14 03-15-05.xls 3/16/2005 MEMORANDUM TO: . ~ Jim Regg k'" e:, (~/Z(-I04 P.I. Supen-'isor 1\ ~ I FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 1 '1'-14 Insp Num: mitCS040619211005 Rei Insp Num: State of Alaska Alaslia Oil and Gas Conservation Commission DATE: \Vednesday, June 23. ~OO4 SlIBJECT: t\lechamcallmegrny Tests CONOCOPHTLLlPS ALASKA INC I Y-14 KUPARUl\. RIV UNIT 1 '1'-14 Src: Inspector NON-CONFIDENTIAL Reviewed 8,,: P.I. Supn-' '.:3b~ Comm API Well Number: 50-029-20910-00-00 Permit Number: 183-023-0 Inspector Name: Chuck Scheve Inspection Date: 6/1912004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1'1'-14 T)'pe Inj. P TVD 6529 IA 1040 2110 2060 2060 P.T. 1830230 TypeTest SPI Test psi 1471.25 OA 0 0 0 0 I nten'a I 4YRTST PIF p Tubing 1600 1600 1600 1600 Notes: Pretest pressures observed for 30+ minutes and found sLable. Well demonslraled good mechanical integrity. Wednesday, June 2.l 2004 Page 1 of 1 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joe¥ Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FiLM BLUE LINE Open Hole 1 1 '1 , , , ,, Res. Eval. CH I I I '" , , .... Mech. CH ly-14 3-:)9-03 Caliper Survey 1 Rpt or P Color Signed' Print Name: Date · ProActive Diagnostic Services, Inc., 3 IO K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952. , E-mail: pdsanchorage~memorylog.com Website: www. memory_ log.com RECEIVED APR 0 7 2003 Alaska O[i& Gas Cons. Commieeion Rn~orage Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLIPS ALASKA INC Well: March 29, 2003 Field: 4957 State: 1 APl No.: 3.5" 9.2 lb. J-55 RUIT Top Log Intvll.: Tubing Bot. Log Intvll.: 1Y-14 Kuparuk Alaska 50-029-209100-00 6,670 Ft. (MD) 6,969 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Tubing Tail ~ 6,969' (Drillers Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that 3.5" tubing is in good to poor condition. The caliper recorded a 73% penetration in joint 227 @ 6,858'. This penetration was recorded on two fingers, and the recordings point to a significant probability that the two fingers caught the edges of a full wall penetration. The damage recorded appears in the form of Isolated pitting. No significant Cross-sectional wall loss or ID restrictions were recorded throughout the interval logged. A 3D Log,Plot of the interval 6,770' - 6,970' is included in this report. Cross-sectional drawings of the most significant events are also included. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The joint numbering used in this report is an estimate derived from the average length of joints relative to the starting depth of the log. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pit (73%) Jt. 227 No other significant wall penetrations(<13%) are recorded in the interval logged MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas (<7%) cross-sectional wall loss is recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 6,858 Ft. (MD) Field Engineer: L. Koenn Analyst: J. Thompson Witness: J. Fritzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, -IX 77497 Phone: (28]_) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSCc~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231.4. Well: 1Y-14 Field: KUPARUK Company: CONOCOPHILLIPS ALASKA INC Country: USA PDS Report Overview Body Region Analysis Survey Date: March 29, 2003 Tool Type: MFC 24 No. 00387 Tool Size: 1.69 No. of Fingers: 24 Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread 3.5 ins 9.2 ppf J-55 RUIT Nom.ID Nom. Upset Upper len. Lower len. 2.992 ins 3.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) penetration body ~ metal Joss body 20~ 10 0 Ill 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 12) pene. 1 8 2 0 1 0 loss 0 12 0 0 0 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 2) 2 0 0 0 0 Damage Profile (% wall) penetration body ~ metal loss body 0 50 GLM 1 228 GLM 2 Bottom of Survey = 228.8 100 Analysis Overview page 2 Well: tYI4 Field: KUPARUK Company: CONOCOPHILLIPS ALASKA [NC Country: USA PDS Report Overview Body Region Analysis Survey Date: March 29, 2003 Tool [ype: MFC 24 No. 00387 '[ool Size: 1.69 N~). o~ Fingers: 24 Penetration and Metal Loss (% wall) Number of joints analzsed/total = 12) Damage Configuration ( body 1(3 Damage Profile (% wall) 228 GLM 2 Bot/om of Survey = 228,8 ! i 100 Analysis Overview page 2 Joint 228 Injection Mandrel 7 Pup Joint 228.2 228.3 228.5 Pup Joint 228.7 PDS REPI JOINT TABULATION SHEET Pipe: 3.5 ins 9.2 ppi J-55 RUI[ We]h Wall h ckmss' [~ody = 0.254 ins Upsel = 0,254 ins Field: Nomir/a) ID: 2.992 his Company: Country: Su!¥ey Date: KUPARUK CONOCOPI IILI. IP$ ALASKA INC ~ penetralion body Ma~ch 29, 2003 223.4i 0 226 i 0 0 .821 0 i227 0 , 0 .t9 I 73 [ 7 0 2281 [ 0 228.2 0 .01 ] 3 i 2 0 228.3 0 228.6 ] 0 .08 INj~ MAN I arch @ 6:00 2.82 2.91 r~ 2 89 NZ~ INJ. M~N 7 (Latch @ 1:00 2.92 i PUP 100 PDS Report Cross Sections Well: 1Y.14 Survey D~ie: March 29, 2003 Field: KUPARUK ¥ool Type: MFC 24 No, 00387 Company: CONOCOPI JII.LIPS ALASKA INC Too] Size: 1.69 I Co(miry: USA Nc~. iai: Fingers; 24 i Tt,ibin}~i _ ~.:~ 9.2_ ~pf ~75~ R~I7 AnaiysL j,T~ompson Cross Section for Joint 227 at depth 6857.72 ft l-ool speed = 47 Nominal ID = 2.992 Nomina! OD - 3,500 Remaining waJI area '- 93 % Tool deviation - 9 ° Cross Sections page 1 . ~ , Z cZ~Z¼~ZmZm,~mZ~Z~Z~Z --.[Z~Z~Z Z~Z~Z~ 'Z~Z 'Z 1Y-14 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ^~?' DATE: July 6, 2001 Commissioner ~__, .~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunderj3~.~o,~-- ' Phillips Alaska Inc. P.I. Supervisor ~..3\.-[ \~' ,;;:~\ 1Y Pad 1Y-03, 1Y-04, 1Y-14 FROM: Jeff Jones KRU Petroleum Inspector Kupamk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. : 'we.I ~Y-~ .ITypel,nj.I ,, (~ '1T:YJD. ! ~ I Tubir'gi' 3750 i 37,50,' I' ~-~0'i. 3~ I~"~, ', !, ,4 ,P.T.D.I 1830~1b ITy~testl P. IT~.~I 1472 I.C~.'r~l..~.~ .I 23c,0 I 2360 I 23501 P/F ! _P Notes: .. W~,ll 1Y~ iType~nj-I.. S i T:V:D'. I. 5914 I'-rubin'g.'l...2~_1 2__.~x).. I 25001 25oo I~.~il .4' _.P-T'D-1.1830660'ITyp~,,testl, P IT~I 1479 I '.c~.',,I ~. I 2.375 I 2375 I ~01 P/F I --" Notes: w~,,I w-~4 IT.~,,j~'I" S.'I T.v.b. t 58~' I'rubi~.l 2.55o. i 2~)...I '755o.. ! 2~ li.r"-v~'l 4 ' .. p.'r.D.! 1.830230 ITypet~l.. P IT~.1..~471 IC~.gl ~r,o I ~7~01 ~7401 1740 I .P/F I E ' P.,T.D. Nolx~: Notes: .,',!.,'.f-v-D- i '1Tu~.i , I" '1" /' I'~'1 Type.test., I I Test ~i I ~"g 1 .... I I I . I. P/F. I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Te~t'$ Details Friday, July 6. 2001: I traveled to Phillips Alaska Inc.'s 1Y Pad and witnessed 4-year MIT's on wells 1Y-03, 1Y-04 and 1Y-14. The pretest robing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all three wells passing the MIT's. Summary.: I wimessed successful MIT's on PAl's wells 1Y-03, 1Y-04 and IY-14 in the Kuparuk River Field / KRU. M.I.T.'s performed: 3 AttachmentS: Number of Failures: Total Time during tests: 2 h.m; CC'. MIT report form 5/12/00 L.G. MIT 1Y Pad KRU 7-6-01 JJ.xls 7/16/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging __ Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service X 4. Location of well at surface 208' FNL, 1134' FWL, Sec 1, T11N, R9E, UM At top of productive interval 1153' FSL, 1361' FEL, Sec 35, T12N, R9E, UM At effective depth 1194' FSL, 1405' FEL, Sec 35, T12N, R9E, UM At total depth 1200' FSL, 1411' FEL, Sec 35, T12N, R9E, UM I 6. Datum elevation (DF or KB) RKB 101 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-14 9. Permit number/approval number 83-23/94-305 10. APl number 5O-029-20910 11. Field/Pool Kuparuk River Oil Field/Pool feet 12. Present well condition summary Total Depth: measured ·true vertical 7 3 8 6 feet 6529 feet Effective depth: measured 7 2 3 9 feet true vertical 6 3 8 4 feet Plugs (measured) None Junk (measured) None Casing Length Size Structural Conductor 7 3' 2 0" Surface 2400' 10 Intermediate Production 72 8 4' 7" Liner Perforation depth: 3/4" Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 w/ tail Packers and SSSV (type and measured depth) PKR: Cemented Measured depth True vertical depth 605 CF 114' 114' 1000 SX Fondu & 2436' 231 6' 250 SX Perm C 1200 SX Class G & 7320' 6464' 250 Sx AS I measured 6834'-6888', 7032'-7044', true vertical 5982'-6036', 6178'-6190', @ 6970' 7055'-7076' 6201'-6222' Baker 'FHL' @ 6735', Baker 'FB-I' @ 6928'; RECEIVED DEC 2 7 1996 Alaska 0ii & Gas Cons. Commission SSSV: Camco A-1 Inj Valve gncl/~br45'- 13._ Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure INSTALL INJECTION VALVE 14. Prior to well operation Subsequent to operation Representative Daily Average Prodv(;tion or Inje(;ti0n Data, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4564 900 4900 1540 Tubing Pressure 2450 2530 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas __ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE tO~Z - qq DAY DESCRIPTION OF WORK /205' CONTRACTOR/K~ PERSON ff ~LL/~O~TO~ ~E~V ~6~v~ 70175 ~VQ/)I~F OPE~TION AT REPORT TIM E FIE~ EST: ~ COMP~ ' ~ INCOMPL~E $ ~ ] AFC/CC ACCU M U ~'~-Eb-~-OST $ 1o 57 TIME LOG ENTRY //1//7-/~L~<- ~' PS'i~' 'T~': ~ ps'..r//L~L/~'~F'; ~- /o_~- ~'R PAGE 1 OF pLU6 ~U~I~C O~OPP~ ~ I~r) ps~. ~fi~c [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F °F miles AR3B-7031 IWind Vel. knots ISigned .~ ~ 29~ ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 November 9, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Applicaton for Sundry Approvals (Form 10-403) and in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. Well Form Action 1 Y- 14 10-403 Variance (Inj VIv) 2C-09 10-404 Stimulate 2C-09 10-404 Perforate 2Z- 14 10-404 Variance (Inj VIv) 3H-23 10-404 Frac 3J-06 10-404 Frac If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering AttaChments Well Files (attach only) File: FTR110196 (w/o attach) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension Stimulate Pull tubing _ Variance X Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 208' FNL, 1134' FWL, Sec. 1, T11N, RgE, UM At top of productive interval 1153' FSL, 1361' FEL, Sec. 35, T12N, R9E, UM At effective depth 1194' FSL, 1405' FEL, Sec. 35, T12N, R9E, UM At total depth 1200 FSL, 1411' FEL, Sec. 35, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-14 9. Permit number 83-23 10. APl number 5o-029-20910 11. Field/Pool Kuparuk River Oil Field/Pool 12. Present well condition summary Total Depth: measured true vertical 7386 6529 Effective depth: measured 7 2 3 9 true vertical 6 3 8 4 feet feet feet feet Plugs (measured) None Junk (measured) None ORIGINAL Casing Length Size Structural Conductor 7 3' Surface 2 4 00' Intermediate Production 72 8 4' Liner Perforation depth: measured Cemented 20" 605 Sx AS II 10-3/4" 1000SxFondu& 250 Sx Perm C 7" 1200 Sx Class G & 250 Sx AS I 6834'-6888',7032'-7044',7055'-7076' true vertical 5982'-6036',6178'-6190',6201'-6222' Tubing (size, grade, and measured depth) 3 1/2", 9.3#/ft., J-55 with tail @ 6970' Packers and SSSV (type and measured depth) Measured depth 114' 2436 True vertical depth 114' 2316' 7320' 6464' Gas Cons. Commission PKR: Baker 'FHL' @ 6735', Baker 'FB-I' @ 6928'; SSSV: Camco WRDP @ 1865' A~chorr..,,-"-' 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ Lockout SSSV and install sub-surface, spring controlled safety valve. 14. Estimated date for commencing operation 15. Status of well classification as.' October 1994 Oil _ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved 'Service MWAG Injector 17. I hereby certify that the fo_regping Si~ned ~~-~ is true and correct to the best of my knowledge. Title Wells Superintendent FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ ~pproved by order of the Commission Form 10-403 Rev 06/15/88 IApproval Subsequent form require lO-,/./.oq. t-~pproved Copy, Retu, rn(~j:l,/ Original Signed By ii- David W. ;Johnston CommL~si_.'o_ner 13~t~ , ~-?~-i t/- /'~)' ~ ~ SUBMIT IN TRIPLICATE Well'1 Y-1 4 AR~.,O ALASKA INC.- KUPARUK FIELD APl# 50-029-20910-00 Spud Date: 02/04/83 CSand: OPEN Completion Date: 02/24/83 ASand: ~ Maximum Hole Angle: 41.2 deg. @ 3364' MD Original Rig RKB: 29.8" All depth are RKB MD to top of equipment. ' Je.elr, Well Type: WATER · Tree Type: McEvoy Gen I 3-1/8" 5000# Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: None 1 SSSV: CAMCO A1 IV ON CS LOCK @ 1865' 2 SBR: BAKER @ 6709' 3 PKR: BAKER FHL @ 6735' 4 NOGO: CAMCO 'W-I' NIPPLE @ 6774' ( 2.813" ID) 5 'PKR: BAKER FB-1 @ 6928' 6 NOGO: CAMCO 'D' NIPPLE @ 6957' (2.750" ID) 7 SHEAR OUT: BAKER @ 6968' 8 TUBING TAIL: 3.5" TUBING @ 6969' Minimum ID: 2.750" NOGO Casing and Tubing Size Weight Grade Top Bgttom 20" 92# H-40 0 114' 10.75" 45.5# K-55 0 2436' 7" 26# K-55 0 7320' 3.5" 9.3# J-55 0 6969' CASING CASING CASING TUBING Gas Lift Information Deoth Stn# Vtalve Ty_~e Sz. Latch 2064' 1 DV I" BK 3957' 2 DV' 1" BK 5198' 3 DV I" BK 6136' 4 DV 1" BK 6695' 5 DV 1" BK 6808' I DPHF CV 1" BEK 6911' 2 DPHF CV I" BEK 7,8 Perforation Data Interval SPF Date Zone 6834-6888 12 C 7032-7044 12 A 7055-7076 12 A Comments: Tubing head flange is 11" 3000 psi. port Sz..~,ID# 09120/93 09/20/93 09/20/93 09/19/93 09/21/93 O4126/94 04~26/94 LAST TD: 7073' on 09/20/93 PBTD: 7239' PBTDSS: 6283' LAST REVISION: 1013194 SWCIHTE ARCO Alaska, Inc. ; -. Post Office E 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 27, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas ConserVation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 31--!'15 1A-13 Perforate q3-o~ 1 H-02 Perforate ~__~11 H-16 Stimulate 9;~-J51 H-16 Perforate 3-~--l:z.'~ 1 L-05 Perforate %~--3-~ 1 Y- 14 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECE V .D Alaska 0il & GaS Gens. Oo~'tss'ton Anchor;tge ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AR2~-'3093-C STATE OF ALASKA ALA~,,A OIL AND GA~ CONSERVATION COMMIS~,uN REPORT OF SUNDRY WELL OPERATIONS feet 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 208' FNL, 1134' FWL, Sec 1, T11N, R9E, UM At top of productive interval 1153' FSL, 1361' FEL, Sec 35, T12N, R9E, UM At effective depth 1194' FSL, 1405' FEL, Sec 35, T12N, R9E, UM At total depth 1200' FSL, 1411' FEL, Sec 35, T12N~ R9E, UM 6. Datum elevation (DF or KB) RKB 101 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-14 9. Permit number/approval number 83-23 10. APl number ( .... ~) 5o-029-20910 "~'T-3 11. Field/Pool ~ Kuparuk River Oil Field/Pool (_j-'~ 12. Present well condition summary Total Depth: measured true vertical 7386 6529 Effective depth: measured 7 2 3 9 true vertical 6 3 8 4 feet feet feet feet Plugs (measured) None Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 73' 2400' Size 20" 10 3/4" 7284' 7" measured 6834'-6888', true vertical 5982'-6036', Cemented Measured depth True vertical depth 605 CF 1 14' 1 14' 1000 SX Fondu & 2436' 231 6' 250 SX Perm C 1200 SX Class G & 7320' 6464' 250 Sx AS I 7032'-7044', 6178'-6190', 7055'-7076' 6201'-6222' SSSV: Camco WRDP @ 1865' RECt v u Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 w/ tail @ 6970' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 6735', Baker 'FB-I' @ 6928'; 13. Stimulation or cement squeeze summary Converted Oil Producer to MWAG Injector on 10/6/93. Intervals treated (measured) N/A 14. 0 el' t B 199;f Treatment description including volumes used and final pressure N/A Alaska 0ii & G~s Cons. Representative Daily Average Production or Injection Data Anct~0ragB OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1335 1218 13 717 212 Subsequent to operation 0 0 2900 1100 2350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service MWAG In!. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~'~' ~'~' Tit,e Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KDQS MORNINQ WELL REPORT FOR 10/06/93 DRILLSITE 1Y PAOE 1 PRODUCTION WELL STATUS OAS LIFT STATUS IOOR = 15000 SI DATA W Z S E 0 T CHOKE 7" L N A OR WC H2S CSQ L E T % FTP FTT % PPM PSI 3 B PR 176 170M 110 71 95 1400 4 B PR 176 180 !12 75 100 1230 6 B SI 0 OM OM 86 16 A PR 176 250M 92M 4 17 C PR 176 170M 36M 0 18 B SI 0 OM OM 0 19 B SI 0 OM OM 0 21B SI 0 OM OM 0 22 B SI 0 OM OM 0 23 B SI 0 OM OM 0 24 B SI 0 OM OM 0 10" CSg PSI 960 160 25 B PR 26 B PR 27 B PR 28 B PR 29 C PR 30 B PR 31B SI 32 B PR 34 B SI 65 1450 65 330 0 300 0 0 0 0 0 0 0 220 0 0 0 0 0 450 40 0 0 0 20 0 0 176 190M llOM 64 65 1000 620 176 200M l12M 64 40 1200 750 0 OM OM 0 0 0 0 0 OM OM 0 0 0 0 12 720M 134M 80 55 2270R 210 12 1040 102 80 80 950 0 0 OM OM 0 0 0 0 12 780M 124M 93 110 1600 1600R 0 0 OM 0 0 0 0 gAS gAS INJ OPT OPT METER VOL RATE gL READINg MSCF MSCFD ROOTS 0 600M 0 400M 0 OM 0 600M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 895 0 1113 0 113 0 91 0 0 0 0 0 0 0 0 0 0 632 O. 0 624 O. 0 647 2. 0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0,0 0 0 0 0 0 0 786 1 9 187 0 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 743 25. 6 0 0.0 C H M 0 R I D S N E 0000 0 0000 0 2400 62 0000 0 1545 0 2400 0 2400 0 2400 0 2400 O 2400 0 2400 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 2400 0 0000 0 2400 11 TOTALS: 3812 3619 INdECTION WELL STATUS INdECTION VOLUMES SI DATA 4 Z S -_- 0 T CHOKE _ N A OR _ E T % L B SI 2 B SI 5 B. SI 7 B MI 8 B PW 9 B PW 10 B.PW 11 B PW 12 B PW 13 B PW 15 B PW 7" 10" INJ CSg CSg PSI FTT PSI PSI 0 OM OM O* 0 0 OM OM O* 50 0 OM OM 1500 500W 0 OM OM O* 0 100 1200 140 100 0 100 2325 135 1460 560 100 2300 143 550 300 WATER RECMD gAS C INJ INJ INd H M 0 METER VOL RATE VOL R I D READINg BBLS BWPD MMSCF S N E 100 2264 147 2600R 920 100 2191 146 1540 1150- ....... 100 2300.~__Ll_OD___~~ 0 OM OM 1980 600 100 2300 150 1940R 840 0 0 O* 0.000 2400 62 0 0 O* 0.000 2400 62 0 0 O* 0.000 2400 70 0 0 0 2.705 0000 0 0 2000M 6008 O. O00M 0000 0 0 1500M 1142 0.000 0 1200M 1550 0.000 0 12906 O* 0.000 0 4972 O* 0.000 _~.__O___.t~OM 1728 0.000 0~00.8~ O* 0.000 0000 0 0000 0 0000 0 0000 0 0000 0 1545----0' TOTALS: SWI: 0 + PWI: 25078 = 0 1300M O* O. 000 0000 0 o;R EE E IV AN * AFTER THE RECOMMENDED WATER INdECTION RATE INDICATES THAT THE OCT 2 8 !995 WELL SHOULD BE WIDE OPEN REGARDLESS OF, THE LISTED RECOMMENDED RATE. .Alaska Oil & Gas Cons. (;ommissi~' Anchorage ARCO Alaska, Inc. Post Office '~,.,x 100360 An, chorage, Alaska 99510-0360 Telephone 907 276 1215 September 8, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston° Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well 1Y-14 Action Change Program Anticipated Start Date 9/93 if you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED $ E P 1 ~ 199~ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance __ Perforate __ Other 6. Datum elevation (DF or KB) 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ~ 2. Name of Operator ARCO Alaska. In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service _ RKB 101 feet _ 7. Unit or Property name x__ Kuparuk River Unit 8. Well number 1Y-14 9. Permit number 83-2;~ 10. APl number 5o-029-20~)1 0 11. Field/Pool Kuparuk River Oil Field/Pool 4. Location of well at surface 208' FNL, 1134' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1153' FSL, 1361' FEL, Sec. 35, T12N, R9E, UM At effective depth 1194' FSL, 1405' FEL, Sec. 35, T12N, R9E, UM At total depth 1200 FSL~ 1411' FEL, Sec. 35, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7386 6529 feet Plugs (measured) None feet Effective depth: measured 7 2 3 9 true vertical 6 3 8 4 feet Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 605 Sx AS II 114' 1000 Sx Fondu & 2436 250 Sx Perm C 1200 Sx Class G & 7320' 250 Sx AS I 73' 20" 2400' 1 0-3/4" 7284' 7" measured 6834'-6888',7032'-7044',7055'-7076' true vertical 5982'-6036',6178'-6190',6201'~6222' Tubing (size, grade, and measured depth) 3 1/2", 9.3#/ft., J-55 with tail @ 6970' Packers and SSSV (type and measured depth) True vertical depth 114' 2316' 6464' RECEIV[D S E P '1 199 Alaska 0il & Gas Co~s. bumrniss~:,' Anchorage PKR: Baker 'FHL'@ 6735', Baker 'FB-I'@ 6928'; SSSV: Camco WRDP @ 1865' 13. Attachments Description summary of proposal Connvert oil producer to MWAG injector. Detailed operation program _ BOP sketch 14. Estimated date for commencing operation September 1993 oil _ Cas 16. If proposal was verbally approved Name of approver Date approved Service MWAG 17. I her/~ cer~yt~hat ~ng is true and correct to the best of my knowledge. Signed'""~(/~'' "~'~-~ Title Senior Encjineeer FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended, Injector Date ~ ""~*"~.~ Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test .L.-/ Subsequent form require 10- ~O~/' Original Signed By Approved by order of the Commission Form 10-403 Rev 06/15/88 David W. Johnston IApproval No. ?'3 Commissioner Date ¢/?_o/.~ SUI~MIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 1Y-14 ARCO Alaska requests approval to convert Well 1Y-14 from an oil producer to an MWAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water alternating with miscible gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5982' and 6222' 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. $ E P 1 ~ 199:~ A~aska 0ii & Gas Cons. Anchorage ;,o. 0 la. I & I N A L APPLIL;ATION FOR SUNDRY APPI.tOVALS Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate _ Other ~X change 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ 2. Name of Operator 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 feet Plugs (measured) feet NOlle 6. Datum elevation (DF or KB) wellhead RKB 101 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-14 9. Permit number 83-23 10. APl number 5o-029-2091 0 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 208' FNL, 1134' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1153' FSL, 1361' FEL, Sec. 35, T12N, R9E, UM At effective depth 1194' FSL, 1405' FEL, Sec.35, T12N, R9E, UM At total depth 1200' FSL~ 1411' FEL, Sec. 35~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7 3 8 6' true vertical 6 52 9' Effective depth: measured 7239' feet Junk (measured) true vertical 6 3 8 4' feet NOne Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 3 7' 2 0" 605 Sx AS II 7 3 73' Surface 2400' 10 3/4" 1000 Sx Fondu & 2436' 231 6' Intermediate 250 Sx Permafrost C Production 7284' 7" 1200 Sx Class G 7320' 6464' Liner 250Sx AS I Perforation depth: measured 6834'-6888', 7032'-7044', 7055'-7076' @ 12 SPF, 120° Phasing ~ E ~'-,5 ~.,. ['~ IV E D true vertical ' 5982'-6036', 6178'-6190', 6201'-6222', @ 12 SPF, 120° Phasing Tubing (size, grade, and measured depth 3 1/2" J-55 Tubing with tail @ 6970' Packers and SSSV (type and measured depth) Baker "FB-I" pkr @ 6928', Baker "FHL" pkr @ 6735', Camco TRDP @ 1865' 13. Attachments Description summary of proposal ~ Convert oil producer to a water alternating gas injector. 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved Oil ,?,: i;as Cons. Commiss, Detailed operation program_ BOP sketch ~ (Wellbore schematic attached). 15. Status of well classification as: Oil m Gas m Suspended m Service W~t{~r Alternatina Gas (WAG~ Iniector Name of approver Date approved 17. I hereb~ certify that the foregoing is true and correct to the best of my knowledge. Si~ned//'~'~-& ~'- ~--.~"L~ Title Area Drillin~ Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test /% jtz/MAC IApproval No. ~...(~,.~ Location clearance ~ Subsequent form require 10- ORIGINAL SIGNED BY l_OPk!"-,,. C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 Commissioner ~,~,ov,~d Copy SUBMIT IN TRIPLICATE Returned 1Y-14 WORKOVER PROCEDURE SUMMARY: The Kuparuk 1Y-14 workover .will be done to convert the well from a producer to a water alternating gas injector (WAG). The workover will require changing out the couplings on the exsiting tubing string and upgrading the wellhead from 3,000 psi to 5,000 psi equipment. 1Y-14 WORKOVER PROCEDURE 1. Move in and rig up Nordic 1. , Set plug in Camco 'D' nipple at 6957'. Circulate 11.2 ppg kill weight brine through GLM. 3. Nipple down tree and nipple up BOP. Test same. 4. POOH changing couplings on tubing to AB MOD. 5. Run in hole with completion. . Prior to picking up the SCSSV make up a storm packer on tubing. Set packer and hang off tubing string below wellhead. 7. Change out wellhead to 5,000 psi. , Pull storm packer to floor 'and lay down same. Pick up SCSSV and run in hole with remaining completion string. 9. Nipple down BOP and install 5,000 psi tree. 10. Displace out annulus with diesel. 11. Secure well and release rig. 5OOO PSI BOP STACK I I I I 5 I KRU 1Y-14 1. 10 3/4" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 11" - 3000 PSI TUBING HEAD 3. 11" - 3000 PSI X 11" - 5000 PSI CROSS-OVER AND SPOOL. 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR 13. 14. 15. ACCUMULATOR CAPACITY TEST I . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED 'DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORD~ SRE 9/89 KUPARUK WELL 1Y-14 APl #: 500292091000 ADL LEASE: 25641 SPUD DATE: 02/04/83 COMPLETION DATE: 02/24/83 PERMIT #: WORKOVER DATE: 83-23 SURFACE LOCATION: 207-FNL,1134-FWL,SEC1 ,T11 N,R9E TOP OF KUPARUK: 1154-FSL,1361 -FEL,SEC35,T12N,R9E TD LOCATION: 1201 -FSL,1411 -FEL,SEC35,T12N,R9E All depths are MD-RKB to top of equiPment unless otherwise noted ORIGINAL RKB: /0!; TUBING SPOOL: 29.8 ~' PAD ELEVATION: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH ~ ~$~# H-40 114 ,f 10.75" 45.5~ K-55 2436 7" 26# K-55 7320 ~ 3.5' 9.3# J-55 BTC 6969 LINER DETAILS WEIGHT GRADE TOP SIZE TUBING JEWELRY I~TEs~M ~TY~PE ID SSSV CAMCO TRDP-1AE 2.812" SBR BAKER PKR BAKER FHL PKR BAKER FB-1 NOGO CAMCO 'D' NIPPLE 2.75" SHROUT BAKER BTM DEPTH 1865 6709 ~ 6735 6928 '"'" 6957 ,,"' 6968 v-~' WELLTYPE: GAS LIFT and FLOW INFORMATION VALVE STN DEPTH MANDREL SIZE 1 2064 "' q^mco ~c~,,J4,-- /. o ~ 2 3957 ,,,/ ., /. ,.3 3 5198 ,-' ,, .. 7. a"' 4 6136 ~' '. " [.~" 5 6695 ,." ,. " /. ,-~" 6 6808 ,~' .- " 1.0" 7 6911 '/ .... /.0" PERFORATION DATA INTERVAL ZONE FT SPF PHASE 6834-6888 ~" C ~5'-~ 54 12 /,~.o 7032-7044,--' A'~ 12 12 7055-7076 '-'" AZ, 21 12 /'~ PORT SIZE ~{~ ~/,~ COMMENTS MISC, DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: FISH/OBSTRUCTION: z/'( deg ~ deg ~H ft PBTD: PBTDSS: DEPTH 7239 6283 REVISION DATE: -05/t2/8-6 REASON: ARCO Alaska, Inc, Date: April 20, 1988 Transmittal #: 7146 RETURN TO: ARCO Alaska, Inc. ' Alln: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1 1 19 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this Iransmittal. '"'" 1 G- 16 Kuparuk Well Pressure Repod 2 - 8 - 8 8 Static 'C' Sand "----~1G-09 Kuparuk Well Pressure Report 2 - 3 - 8 8 'A' Sand -----~ G-09 Kuparuk Well Pressure Report 2-3 8 8 Static 'C' Sand 1 G- 09 Kuparuk Well Pressure Report 2 - 3 - 8 8 Static Bolh Sands ~.L~. 2 C- 04 Kuparuk Well Pressure Report 1 2 - 1 3- 8 7 'A' Sand ..~3H-05 Posl-Frac Report 4 - 6 - 8 8 AIIo Frac 10 3 H-02 Posl-Frac Report 4 - 6 - 8 8 AIIo Frac 10 '~~ H-03 Posl-Frac Report 4 - 6 - 8 8 AIIo Frac 10 H - 07 Trealmenl Reporl 4 - 1 3 - 8 8 ~ ~~~ Pulse Tesl 3 - 1 1 - 8 8 'A' & 'C' Sands E Receipl Acknowledged' DISTRIBUTION: D & M Dale' Chevron Mobil SAPC UnoCal ARCO Alaska, Inc. ~ Post Office B(. .0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 19, 1988 Transmittal #: 7099 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lq-5 lq-6 1Y-3 1Y-3 2E-11 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuapruk Well Pressure Report(Otis)~ Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) 8-24-87 8-24-87 1-31-88 1-31-88 2-6-88 2-6-88 2-15-88 Both Sands Both Sands 'A' Sand Static 'C' Sand Static 'A' Sand Static 'C' Sand Static PBU 'At Sand Alaska Oil & Gas Cons. Commission Anchorage Receipt Acknowledged: DISTRIBUTION: Date: Chevr on Mobil S~3 C Uno ca 1 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany ARCO Alaska, In; Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal ~:6054 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H' 8-26 thru30-87 ' 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thrug-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thru8-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(Otis) Static A Sand 9-1-87 IY-14 Kuparuk'Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static.C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static-C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-10 Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: /~ /l~'aska 0il & Gas Cons. Commission ~~ ..... Anchorage D&M .... ~<State-of-Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc. Is a Subsidiary o! AtlantlcRIchfleldCompany Unocal Date: ARCO Alaska, In,"-" ' Post Office _..-.,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 2, 1987 Transmittal # 6049 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-3 Pressure Report 'AT Sand 8-20-87 100596H IY-14 Static Gradient Survey 8-20-87 100556Y14 1Y-5 Static Survey 8-20-87 1005551Y5 1G-1 Kuparuk Well Pressure Report(Camco) 8-24-87 1G-7 Kuparuk Well Pressure Report 8-24-87 2D-3 Kuparuk Well Pressure Report(Otis)'C' Sand 8-2-87 Alaska 0il & Gas Coils. Commissi.,m ^n(;horage Receipt Acknowledged: DISTRIBUTION: Date: BPAE Chevron Mobil SAPC Unocal D&M ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfleldCompany ATTACHMENT I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Drill Site Well No. Log Date 1A-4 7/6/83 1A-5 10/29/83 1A-7 2/8/82 5/7/82 1A-9 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 1A-14 4/1/82 1A-15 6/5/82 1A-16A 5/11/82 6/8/82 lA Drill Site Well No. Log Date lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Well No. Log Date lC-1 5/9/81. lC-2 5/8/81 1C-3 ~'-7/13/81 lC-4 11/8/81 3/9/81 1C-5 2/26/81 · 1C-6 11/30/81 1C-7 5/19/81 1C-8 ' 5/21/81 ,. Drill Site 10 Well No. Log Date 1D-1 ~ 1/80 5/23183 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 ,~D-8 (WS-8) 5/10178 Attachment Page 2 Drill Site 1H Well No. 1H-3 1H-4 1H-6 1H-7 1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Lo9 Date lQ ~1Q'5~:12/1/85 Drill Site Well No. Log Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/12/83 1F-7 Alaska Oil & ~ ~ns. ~mm)::: ~ora~e Lo9 Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 11/19/82 5/7/83 Attachment . Page 3 Drill Site 1Y Wel 1 No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/2O/83 ~v.J~--~l~ 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 tY-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2~28/85 2C-7 10/15/84 %2C~_16~12111t85 Drill Site Well No. Log Date 2Z' ~Z~ 7/10/83 2Z-2 " 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF'pg:O052 Alaska Oil & Gas Cons. Anchorag~ [ Drill Site 1Y Wel 1 No. Log Date ,,~0/21/83/ 6/10/83':'~ %3/4/84/ ~6/18/83 '~ 7/2/83 "~6/29/83 ~6/27/83 '-'-(.a "6/22/83 '~6/20/83 ~- "'"5/10/83'"-~ '"11/21/83/ %5/25/83 ',~5/27/83 ',~5/13/83'~> '~5/18/83 / ' "~5/29/83 "~'5/30/83'-,x : '"10/23/83 ~ Drill Site Well No. ~o9 Date 2Z '-.2Z_l '~2Z-2 ,g~ ~"2Z-3 '~2Z-4 ~2Z-6 '~2Z-8 7/10/83 6/24/83x,, 7/19/83/ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/8.3 Drill Site 2C Wel 1 No. Log Date -- 2C-4 "~2/lg/85\ ~ 2/28/85,~ . '~4- 2C-7 ~10/15/84 .! VLF:pg:O029 RECEIVED FEB 2 1 1986 Alaska 011 & Oas Corm. ~m~ltssion A~chorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent nOtices on the following wells at the Kuparuk River Field: Well Action Date Performed 1F-4 Fracture 9/1 8/84 1F-7 Fracture 9/21/84 1L-1 Fracture 1 0/23 / 84 1L-8 Fracture 1 0/16/84 1Y-2 Fracture 1 0/9/84 1Y-2 Ac id ize 1 0/22/84 1Y-3 Fracture 1 0/7/84 1Y-5 Fracture 1 0/4/84 ~~ Fracture 1 0/6/84 2C-4 Perforate 1 0/1 6 / 84 If you have any questions, please call me at 263-4253. M.ike L. Laue .. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED OCT 2 9'1 1 Alaska Oil & Gas Cons. Commission Anchorage AR~¢3 ~1~_~1~_ Inc_ is a Subsidiary o! AllanlicRichfieldCompany STATE OF ALASKA ALASKA',J~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL EX 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-23 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20910 OTHER [] 4. Location of Well SURFACE LOCATION. 208' FNL, 1134' FWL, SEC. 1, T11N, RgE, UM BOTTOM HOLE LOCATION. 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' (RKB) I ADL 25548, ALK 2662 12. 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1Y-14 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) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 October 6, 1984, the "A" sands of Kuparuk well 1Y-14 were hydraulically fractured and propped to improve production. The treatment consisted of 281 BBLS of gelled water as pad and carrying fluid and 23,185 LBS of 12/20 sand as proppant. The flush consisted of 25 barrels of gelled water and 41 barrels of gelled diesel. Prior to pumping, equipment and lines were tested to 6220 psi. Alaska 0il & Gas Cons. Commission Anchora~2e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~~J/<::::~4~J:Z_~ KU PARUK Signed Title OPERATIONS COORDI NATOR The space below for Commission use 10/29/84 Date/c? ,,' Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 2, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached is a notice of intention to fracture well 1Y-14. If you have any questions, please call me Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) Kuparuk at 263-4253. Field RECEIVED OCT 0 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ." -' STATE OF ALASKA ALASKA ~iL.AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-23 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20910 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCAT I ON' 208 ' T11N, R9E, UM FNL, 1134' FWL, SEC. 1, BOTTOM HOLE LOCATION' 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' (RKB) I ADL 25548, ALK 2662 12. 10. Well Number 1Y-14 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 I~ 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). It is proposed that the "A" sand in Kuparuk well 1Y-14 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Gelled diesel will be used as a fluid. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid- Gel led Water 249 BBLS Gel led Diesel 72 BBLS Proppant' 12/20 Sand 23,200 LBS RECEIVED ANTICIPATED START DATE' October 8, 1984 Subsequent Work Reported OCT 0 4198 Alasl<a 0il & 6as Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERAT IONS COORD I NATOR The space below for Commission use Date 1012184 Conditions of Approval, if any: Approved by ORIG,h!AL SIGNED BY tlAIIRY ii. KIlGLEil COMMISSIONER ~laroYed Cc,';'.. Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 17, 1984 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Commission Attached in duplicate following wells at the are subsequent notices on the Kuparuk River Field' Wel 1 Act ion Date Performed 1F-9 Perforation 11/30/83 1Y-11 Stimulation 11/14/83 1Y-14 Production/Injectivity Test 5/24/83 SWPT 01 Mud acid wash 11/22/83 SWPT 01 Water Injection see attached 2X-1 Perforation 12/9/83 2X-2 Perforation 12/10/83 2X-3 Perforation 12/11/83 2X-5 Perforation 12/12/83 2X-6 Perforation 12/13/83 2X-7 Perforation 12/14/83 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator C KH / kmc Attachment (Duplicate) ~-.RCO Alaska, inc. is a subsia, iary ol AtlanlicRichfieldCompaqy STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO ALASKA~ INC, 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 208' T11N, RgE, UH 7. Permit No. 83-23 BOTTOM HOLE LOCATION' 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 101' (RKB) ADL 25548; ALK 12. 8. APl Number 50- 029-20910 9. Unit or Lease Name RIVER UNIT FNL, 1134' FWL, SEC. 1, KUPARUK 10. Well Number 1Y-14 11. Field and Pool KUPARUK KUPARUK 2662 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other E~ Pull Tubing [] Other [] Pulling Tubing [] I nj ect i v I ty Test (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). ARCO Alaska, Inc. performed a production/injectivity test on Kuparuk Well 1Y-14 from May 13 to May 24, 1983. The test consisted of a pressure buildup of the "A" sands followed by a separate injectivity test of the "A" and "C" sands. Attached is the summary of the sequence of events for this test. The test was planned and conducted as part of a study to determine the need for selective completions in Increment II Waterflood injection wells which have both "A" and "C~' sand open. BOPD at 512 GOR for both "A" and "C" sands and achieved a post acid rate of 881 "A" sand averaged 1.33 BPD/psi and Initial production rate of 610 was tested; the well was acidized BOPD. Injectivity indexes for the 0.683 BPD/psi for the "C" sand. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~ Title KUPARUK OPERATIONS COORDINATOR Date /'"'""'/9 '"' e~ The space below for Commission use By Order of COMMISSIONER the Commission Date Conditions of Approval, if any: Approved by Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reporls" in Duplicate i'ia Y 'i ?, day 'i ? 'i 7a6. ? -% , ('.)6i ';.'.) ( 2 .}; 7 ~:.':, /'.,'arid'_:..' ~-'a i. [off i~a y 24 ARCO Alaska, Inc. Post Office Box '100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation · 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached are subsequent reports of stimulations performed on the following Kuparuk River Unit Wells: 1E-20 1E-21 1E-22 1E-23 1E-24 1E-26 1F-7 1F-8 1G-4 1Y-14 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/Icmc Attachment (In Duplicate) cc: W. Crandall/T. Best R. Ruedrich R. May ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COrvlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 208' FNL, 1134' T11N, RgE, UH SEC. 1, BOTTOM HOLE LOCATION' 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' (RKB) I ADL 25548; ALK 12. 7. Permit No. 83-23 8. APl Number 50- 029-20910 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-14 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 2662 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation X [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 J HC1 test 32OO used and the cleanup period, une 3, 1983, Kuparuk River Unit Well 1Y-14 was stimulated with 12.4% through coiled tubing. All surface lines and BOP's were pressure ed to 4000 psig. The maximum coiled tubing pressure observed was psig and the maximum wellhead pressure was 730 psig. Diesel was to displace the acid. Nitrogen was injected via the coiled tubing circulated intermittently with diesel to aid in cleanup. Following the well was switched to the CPF. TOTAL AMOUNT USED' Acid 81 BBLS Nitrogen 2106 GALS Diesel 5 BBLS 14. I hereby certify, that theJoregoing is true and correct to the best of my knowledge. Signed .... Title KUPARUK The space below for Commission use 0 P E RAT ! 0 N S COORDINATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate _. _- · At-lantic Ritchfield Company Arco Alaska, Inc. To: Wm.-Van Al'en/Sate of AK Date:' 31 Angusg, 1983 TRAN S}~TTAL From: EXTENSION/EXPLORATION' -. Transmitted herewith are the following: Mud logs f'rom the folio.wing wells' 1^-5 ' lA-8 -~44e st lB-5 1C-4 1C- lC- ID- ID- 1F- 1G- · . Sak 12 ) ~West gak 7) 8~West Sak~ 8) 5j- 4j 1H_3.~ 1H-6/ 1Y-14 J 2C-6 'j 2C-7~ 2X-2 J 2Z-4.~~ g-ll-S1 7-22-78 "11-27-77 1-1-81 2-9-81 .3-1.-81. 12-31-79 4-7-78 8-20-82 10-12-82 ' 7-24-82 5-19-82 2-4'83 7-8-83 6-29-83 7-2-83 6-10-83 Also, included is an expanded-core~ log from well 2X-2,-'7-2-83. 'A blueline copy and a Sepia is-provided for each well.. . R./. eipt Acknowledge:. Return receipt to: Arco Alaska, Ina. ~/ ' At tn: XM~XXMOK6YuX E. P.O. Box 100360 Anchorage, AK Date: · . McAlister Prepared by: B.Byrne 99510 KLIPAf~K B',IG I NEERi FIG TRAN~ I TI'AL # TO: Will i am VanAlen F-RC~3: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following- PLEASE N~I-E: BL - BLUEL ! NE, S - SEPIA, F - F I I_M,' T - TAP~'-~ AROD ALASKA, I K~. [~.l;:.~k.?'. ()ii L', :'~:J~ (.::~i~'.:. ~;~Ji!~ir~is~[o~ AT]N: SHELBY J. MA'FITtEVCS - ATO/1115-B z;,~,J~o,'ag~.~ P. O. BOX 100360 AI',K]-E)P,,~E, AK. 99510 Date: August 4, 1983 Subject: Kuparuk Wel 1 1Y-14 Production/Injection Test - Sequence of Events From/Location: V.d. dee ATO 1134 To/Location: R.S. May ATO 1120 The attached is a sequence of events for the 1Y-14 Production/Injection test performed from May 13 - 24, 1983. This test was performed to determine if the injectivity differences between the "A" and "C" Sands seen in the Increment I Waterflood area continued in wells further west and up structure. An in depth analysis of the test has been performed and that report will be issued under separate cover. Ope rations ng~nee /~ FH Attachment cc: B. A. Adams L. D. Hinman L. B. Kelly E. A. Lowen S. G. Suellentrop T. Wel lman Well Files 1Y-14 PRC 1105 ATO 1106 AST 306 ATO 1115D ATO 1220 ATO 1130 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany KUPA~JI( D'LSINEERI biS 'I'P'A'NS~zl I TTAL D.. W. Bose/Shelby J. ~;~atthews Transmitted herewith are the followirg- PLEASE NOTE. BI_' - BLUELINE, S - SEPIA, F- FI LM, T- TAPE,~.'.~PY~ / , /I?~CE! PT ACt<I-.O,:/LEDSED: - PLEASE P~I-UI~ RE~IPT TO: A~qSO ALASKA, INC. ATTN: .DLIEI_BY J. MAT-I¥1D.".,G - ATOll 11 5-B P. O. Po:DX 100360 Ax~()~?,/Y3E, Al(, 99510 KLIP/~RUK 13NG ! NEERI NG TO: William VanAlen FR~¢I: D.W. Bose/Shelby J. Matthews Transmitted herewi th are -the fo l i owincj' NOTE:~~F-Fl LM, T- TAPE, PC- R3DTEE)DPY pLEASE PLEASE REHJF~ RECEIPT ~ ARO0 ALASKA, INC. ATTN: SHELBY J. M~TTHEWS - ATO/111 5-B P. O. BOX 100360 ANQ4ORAGE, AK. 99510 ARCO Alaska, inc. Post Office B< Anchorage,'Alo.,,a 99510 Telephone 907 277 56-37 May 5, 1983 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Attached are notices of our intent to fracture Kuparuk Unit Well 1F-8 and injectivity test for Well 1Y-14. If questions, please call me at 263-4527. hydraul ical ly to perform an you have any Charles K. House Kuparuk Operations Coordinator CKH/kjc Attachment (In Triplicate) xc' W. L. Crandal 1/M. D. Schal 1 R. A. Ruedrich - ANO 332 H. C. Vickers - AFA 326 Kuparuk, North Slope ARCO Alaska. Inc. ,s a StJbsid);~t¥ o(AllanticRichh~:l,:~:o.q~.,~): STATE OF ALASKA ~'x ALASKA ~,~L AND GAS CONSERVATION CO,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-23 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20910 4. Location of Well SURFACE LOCATION' 208' T11N, R9E, UH FNL, 1134' FWL, SEC. 1, KUPARUK 10. Well Number 1Y-14 11. Field and Pool KUPARUK KUPARUK 2662 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data BOTTOM HOLE LOCATION' 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) } 6. Lease Designation and Serial No. 101' (RKB) I ADL 25548, ALK 12. 9. Unit or Lease Name RfVER UNIT RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). ARCO Alaska, Inc. proposes an injectivity test for Kuparuk Well 1Y-14 to determine the relative injectivity indices and parting pressures of the "A" and "C" Sands in the western edge of the CPF-1 area. This test is a key part of an effort to determine the need for selective completions in injection wells with both sands present in the Increment II Waterflood area. Initial production testing of this well will be performed concurrently with the injectivity testing to save on wireline costs. Expected start Cons. Gommissio~ 14. I hereby certify, that the foregoing is true and correct to the best of my knbwledge. Si§ned __ · Title OPERAT IONS COORDINATOR The space below for Commission use Conditions of Approval, if any: Approved by. . .___~.¢ COMMISSIONER · i'-; ,z r,',ve :'J Copy r:, ";'urnod j ,,. ,,.~ ... By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK RIVER UNIT ACIDIZING REPORT WELL: SERVI~ ~OMPA~IES~ ACID DESCRIPTION; · . ." o. ACID QUALITY CHECK RUN? PUMPING SB~L~N~ FLUID TIME: PLII~ED Ig',~ ~.~. CTU DEPm 14) FT '~-~ ~o ?,c qp TESTED CONOENTRATIONI mil PUMP RATE WING VALVE TUBING 8PM/SCm OPEN/CLOSED PRESSURE 1 13o0 ~..-J,,,-. ~ qO0 'goo ~0o .1~.oo 10 0 0 -1~1o0 16o0-I ~.on "/¢o CUM. VOLUME PUNPED o~. o VOLUME PUHPED /L::,.,.S~ /$.3~ . KUPARUK RIVER UNIT SEQUENCE OF EVENTS OP£RATI~N: DATE TIM~ EVENT i i im I0.30 , ' ~ . , c.S- ~t'~- · I I I f~' I m m ' ' ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 9951" Telepho?e 907 2'77 5637 April 25, 1983 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Attached are notices of our intent to Wells 1F-7 and 1Y-14 with acid via have any questions, please call me at stimulate Kuparuk Unit coiled tubing. If you 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kjc Attachment (In Triplicate) xc' W. L. Crandall/M. D. Schall R. A. Ruedrich - ANO 332 H. C. Vickers - AFA 326 - Kuparuk, North Slope STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-23 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20910 OTHER [] 4. Location of Well SURFACE LOCATION' 208' T11N, R9E, UM FNL, 1134' FWL, SEC. 1, BOTTOM HOLE LOCATION' 1200' FSL, 1411' FEL, SEC. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' (RKB) I ADL 25548, ALK 2662 12. 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1Y-14 11. Field and Pool KUPARUK RIVER KUPARUK RIVER POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). ARCO Alaska, Inc. proposes to acidize Kuparuk River Unit Well 1Y-14 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. Following the acid treatment, nitrogen coiled tubing and aid the cleanup. The treatment will consist of 2,800 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to' 4000 psig and the tubing pressure will be limited to 1500 psig_ will be injected through t he During cleanup the well will be produced the cleanup the well will be produced to Expected start date' 4/27/83 to tanks on location. Fol lowing CPF1. 14. I hereby c,~tif,vcthat the~foregping is true and correct to the best of my knowledge. Signed Title OPERATZONS COORD[NA~10rag~ate ~- ~~ The space below for Commission use Conditions of Approval, if any: Approved by Subsequent ;Vo:i< ?,¢FoFce~ co~ss~ou~ Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL TO: William Van Allen FROM- D.W. Bose/Shelby J. Matthews 17-1 1 Transmitted herewith are the following: PLEASE NOTE:~ F - FILM, T - TAPE, PC - PHOTOCOPY RE~E I PT ACKNOWLEDGED: LEASE RETURN RECEIPT TO ARCO ALASKA, INC.' ATTN' SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 DATE: APR-O Alaska Oi! & Gas Oons~ Anchorage ARCO Alaska, Inc. Post Office B~.~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 6, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-14 Completion Report Dear Mr. Chatterton' The 1Y-14 Completion Report, dated 03/30/83, incorrectly lists the base of the lower sand as 7126' MD (6271' TVD). The correct depth should be 7116' MD (6261' TVD). Please make this correction to your records/file. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG2L51'llm cc' R. W. Crick, ANO 912 R. B. Gremley, ANO 351 E. A. Lowen, AFA 311 1Y-14 Well File t ECEIVED APR 0 7 i§83 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office b,.__ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 HAND CARRY SAMPLE TRANSMITTAL SHIPPED TO~tate of Alaska Ak. Oil & Gas Conservation commission 3001 Porcupine Dr. Anchorage,Alaska 99501 Attn: Mr. Bill Van Alen DATE' April 4~ 1983 OPERATOR: Arco SAMPLE TYPE: Core Chips SAMPLES SENT' 6787-6813 @ 1't fntervals 6817-6833 @ 1' intervals 6834-6872 @ 1' intervals 6874-6930 @ 1' intervals 7000-7114 @ 1' intervals 7118-7176 @ 1' intervals NAME- Kuparuk 1Y-14 -- UPON RECEIPT OF THeE SA~PLES,,PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED To. ARCO ALASKA, INC. P.O. BOX 360 ANCHORAGE, A.LASKA 99510 ATTN: R. L. BROOKS RECEIVED BY' DATE' ARCO Alaska. Inc. is a subsidiary of At!anticRichfieldCompany ARCO Alaska, Inc. ~ Post Office ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~rch~25, 1983 .Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Comp. letion Reports Dear Mr. Chatterton' Enclosed are comoletion reports and gyroscopic surveys for the following'wells- 1E-19 1Y-13 1Y-14 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, p. ^. VanlXmen District Drilling Engineer /bc enclbsures ARCO Alaska, Inc. is a subsidiary of AtlanlicRIchlieldCompany ,~laska Oil & Gas Cons. An~herage STATE OF ALASKA ALASK; .L AND GAS CONSERVATION C( MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILXIx-] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-23 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20910 4. Location of well at surface 208' FNL, 1134! FWL, Sec. 1, T11N, RgE, UH At Top Producing Interval 1153' FSL, 1361' FEL, Sec. 35, T12N, RgE, UM At Total Depth 1200' FSL, 1411' FEL, Sec. 35, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' RKB IADL' 25548 ALK 2662 12. Date Spudded 02/04183 17. Total Depth (MD+TVD) 7386' MD, 6529 ' TVD 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-14 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 13. Date T.D. Reached 02/17/83 18.Plug Back Depth (MD+TVD) 7239' MD, 6384 ' TVD 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completion. 02/24/83 N/A feet MSL 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES,I~ NO [] 1865 feet MD I 1350' (Approx) 22. Type Electric or Other Logs Run DIL/MSFL/CR, BHCS/FDC/CNL/GR, RFT, HDT Dipmeter, CBL, 6¥ro/CCL 23, CASING SIZE WT. PER FT. GRADE 20" 91.5# H-40 10-3/4" 45.5# K-55 7!1 26.0# K-55 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Surf 73' 36" 605 sx AS II Surf 2436' 13-1/2" 1000 sx Fondu & 250 sx Pe Surf 7320' 8-1/2" 200 sx Class G & 250 sx AMOUNT PULLED 'mafrost C 'ermafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, sizeand number) 7055'-7076' 7032'-7044' 6834'-6888' 12 spf, 120° phasing 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6969' 6735' & 6928' 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 GAS-MCF Flow Tubing Press. Casing Pressure PRODUCTION FORIOIL-BBL * I CA'CULATED ,1~10~L-BBL 24-HOUR RATE -rI GAS-MCF WATER-BBL I CHOKE SIZE IGAS'OILRATIO WATER-BBL IOILGRAVITY-API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core See attached core description. MAR ~ 11983 Alaska 0il & Anchorag,3 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 30. NAME GEOLOGIC MARKERS Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand TRUE VERT. DEPTH MEAS. DEPTH 6854' 6912' 7014' ~7~-26' --! , r '~ 6002' 6059' 6160' 6271' -, - FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History~ Core Description_, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ? Title Area Dril 1 ing Engr. 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". orrn 10-407 1Y-14 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1930 hrs, 02/04/83. Drld 13-1/2" hole to 2460'. Ran 61 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2436'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 6787'. Cut Core #1 f/6787'-6817'; recovered 27'. Cut Core #2 f/6817'-6831'; recovered 14'. Cut Core #3 f/6831'-6874'; recovered 40'. Cut Core #4 f/6874'-6930'; recovered 56'. Drld to 7000'. Cut Core #5 f/7000'-7058'; recovered 58'. Cut Core #6 f/7058'-7118'; recovered 56'. Cut Core #7 f/7118'-7177'; recovered 59'. Drld to 7386' TD (02/17/83). Ran DLL/MSFL/GR f/7378'-2400', BHCS/FDC/CNL/GR f/7200'-2400'; RFT; HDT dipmeter f/7370'-2700'. Ran 171 jts 7'", 26#/ft, K-55, BTC csg w/shoe @ 7320'. Cmtd 7" csg w/1200 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus. Ran _ Gyro/CCL. (PBTD = 7239'). Ran CBL f/PBTD - 2000'. Perforated well. Set packer on wireline @ 6928'. Ran 3-1/2" completion assy w/tail @ 6969', pkr @ 6735' & SSSV @ 1865'. ND BOPE. NU tree & tstd - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Secured well & released rig @ 0400 hrs, 02/24/83. JG2DH18'sm 03/11/83 Anc~orago ARCO Alaska, Inc. Date: Subject: Internal Correspon -'~. March 21, 1983 Kuparuk 1Y-14 Core Descriptions From/Location: To/Location: Marcia Matthieu - ANO 462 JoAnn Gruber - ANO 354 Core #1: 6867-6817' Cut 30' Recovered 26'4" Shale - dark gray to black. Core #2: 6817-6831' Cut 14' Recovered 16.5' Shale - dark gray to black. Core #3: 6831 -6874 Cut 43' Recovered 39' 19' of shale, a/a, gradually changing to siltstones, gray, argillaceous, glauconitic. 20' sandstone, gray-green, very fine to fine-grained, glauconitic, fair shows. Core #4: 6874-6930' Cut 56' Recovered 56' 47.5' sandstone, brown, very fine to fine-grained, glauconitic, good shows. 8.5' interbedded siltstone and minor sandstone, oil stai ned. Core #5: 7000-7060' Cut 60' Recovered 58.9' 31' interbedded $iltstone and sandstone, oil stained. 27.9' sand- stone, dark brown, fine-grained, heavy stain and odor, good shows. Core #6: 7058-7118' Cut 60' Recovered 57' Interbedded sandstone and shale, with sandstone decreasing downward, heavy stain and odor, good shows in sands. Core #7 7118-7177' Cut 59' Recovered 59' Shale, dark gray, mi nor siltstone. M. P. Matthieu MPM-dvh File- GO 12 KR KRU 4.4 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany KUPARUK WELL- 1Y.-14. PRODUCflON/IN3ECTION TEST SEQUENCE OF EVENTS Hay 3, 1983 Acidized 'well through open mandrels at 6808' and 6911' MD, both "A" and "C" Sands open to Flow. May 11 , 1983 SI well to r'un dummy valves in mandrels at 6808'- and 6911' MD. This isolates the "C" Sands and allows only the "A" Sands open to Flow. May 12, 1983 1200 SI well to run standing valve as a check to make certain the dummy valves at 6808' and 6911' MD are not leaking. Well was SI ten hours total. 2200 Return well to production, From the "A" Sands only. Hay 13, 1983 "A" SANDS PRODUCTION TEST 0130 Put well in test_- "A" Sands only open. 0830- RU Schlumberger. 1220 End well test - "A" Sands Flow at 606 STBD, 581 1243 SI well to RIH with CCL/GR/HP/RA Tracer/Temp/FBS. 1343 Return well to production. The HR is set at 7000' HD (6105' T'VD). Bottomhole pressure is being monitored pursuant to SI flor PBU. Make dynamic logging passes across the interval 7000'-7150' MD. Flow is mainly from the A4 Sand with a small amount From the top of the A5 Sand. 1740 Reset the HP at 7000' MD (6105' TVD). 1746 SI For PBU. FFBHP = 1535.6 psi, FFBHT = 163°F. '1710 Kuparuk Well 1Y-14 Production/Injection Sequence of Events Page 2 Test May 14, 1983 0745 End PBU. FSIBHP = 2911.3 psi, FSIWHP = 970 Make static logging passes (7000'-7150' additional baseline GR/HP/Temp log is run interval 6700'-7150' MD. psi. MD). aCrOSS An the "A" SANDS IN3ECTIVITY TEST Explanation of Measurements- Three mine injection rate. Rate was calcu meter in the pump truck and using volu the water storage tank. There was als the pump truck. During the test, i totalizer in the B3 truck was malfun determined by this method are conside most part, the rates calculated from from the rate meter were consistent. from the rate meter. Temperature measured by strapping a thermomete then insulating the thermometer to r conditions. Temperature was measu the wellhead. Temperatures reporte unless otherwise stated. Injection pump outlet and at will be specified specified as POP. methods were used to deter- lated using the totalizer mes determined by strapping o a digital rates meter in t was determined that the ctioning, therefore rates red to be invalid. For the tank straps and the rate The rates shown here are of the injection water was r to the injection line and educe effects from ambient red.at the pump inlet and at d here are at the wellhead pressure was measured at the the wellhead. Wellhead injection pressure as WHIP and pump outlet pressure will be 0930 'Start priming pump. 0948 Begin injecting methanol (5 bbls) at 1440 BPD. 0955 Begin injecting water. QW=864 BPD, POP=1300 psi, T=65°F at the pump inlet, BHP=3275.4 psi. 1025 14.4 bbls water pumped. BHP decreased from 1020-1030 hour, due perhaps from initial water at the perma- frost. 1032 17 bbls water away, should be out of the permafrost. BHP starts rising again. QW=792 BPD, BHP=3585.2 psi. Kuparuk Well 1Y-14 Production/Injection Test Sequence of Events Rage 3 1100 Dresser stopped by and informed us that they would be perforating 1Y-2 with WL guns, therefore we will not have radio contact with the pump truck until they are done. 1201 63 bbls away, should have water on the perfs at this time. QW=890 BPD, BHP=3838.5 psi, POP=1300 psi, T:80°F. 1300 Have monitored BHP for one hour after water on the perfs. BHP has not .been constant. Since we cannot keep close communication with the pump truck due to enforced radio silence, it was decided to keep surface pressure constant rather than BHP. One minute readings of BHP and 15 minute readings of rate will be taken. During the 12 hours of this injection the rate and pressure were very constant. Attachment 1 is a schedule of rate and pressure data for this part of the test. 2200 End perforating on 1Y-2, can resume radio usage. Hay i5, 1983 0100 End constant pressure injection period. Average readings over 12 hours were QW=720 BPD, BHP=3902.2 psi, POP=1300 psi, T=80°F. 0130 Start dy.namic logs. Temp/GR run over 6700'-7160' HD. Spinner passes over 7000'-7160' HD. Average rate during spinner passes was 680 BPD. 0215 Start RA Tracer Survey-cannot get tool to eject tracer. 0305 Decide to start Step Rate Test. Attachment 2 is a scheduie of steps and rates. Formation parting pressure is calculated to be 4227.0 psi which gives a fracture gradient of 0.692 psi/ft. 0~40 End step rate test, pump 25 bbls diesel. Kuparuk Well 1Y-14 Product ion/Inject ion Sequence of Events Page 4 Test 0949 May 0025 0045 0126 0130 0155 0211 0214 0222 0515 1213 1226 1230 16 , 198 SI well for falloff test. FBHP=4372.2 psi, final QW=4500 BPD, total volume pumped during both injection periods: water-1162 bbls,, diesel-25 bbls, methanol-5 bbls. End falloff test. FSIBHP=2980 psi, FSIWHP=640 psi. Make static temp pass from 6700'-7160'MD. Tried ejector of RA Tracer tool--previous tool failure was a possible software problem. Acheived tracer ejection. Set HP at 7000' MD for Step Rate Test #2. Priming pumps. Pumping methanol at 720 BPD and POP:1100 psi. Ambient temp is 11°F, BHP=2977 psi, BHP=141.7°F. Switch to water after pumping five barrels methanol. SI pumps--possible frozen feed line. Resume pumping water. 63 bbls water away, should have displaced diesel methanol, and have water on the perfs. Start Step Test #2. Attachment 3 is a summary of the rates pressures during this part of the test, and Rate and Slight coordination problem decrease QW fro,m 2000 BPD stretch water. and water truck is late, to 1440 BPD to try and Switch to diesel. Resume pumping water, a total of 2.5 bbl diesel was pumped. Formation parting pressure while stepping up is calculated to be 4047.7 psi, giving a frac gradient of 0.663 psi/ft. FPP while stepping down is cal- culated to be 4223.8 psi, giving a frae gradient of 0.692 psi/ft. Kuparuk-Well 1Y-14 Production/Injection Test Sequence of Events Page 5 2000 End Step. Rate Test. Start constant BHP injection period. POP=1300 psi, WHIP=1250 psi. Attachment 4 is a schedule of rate and pressures during the constant pressure injection period. May 17, 1983 0300 End constant BHP injection. Average readings over seven hours are BHP=3844.4 psi, QW=856.5 BPD, T=85°F, . POP=1300 psi, WHIP=1250 psi. 0310 Start dynamic logging passes. 0350 Start RA Tracer Survey, QW=792 BPD during this survey. 0635 Set HP at 7000' MD (6105' TVD) for falloff #2. 0703 Start pumping diese!. 0749 SI for falloff. FBHP=3732.8 psi, final QW=792-BPD, total volume pumped during both injection periods: water-1213 bbls, diesel-.25 bbls, methanol-5 bbls. 2030 End falloff test. FBHP=3002.6 psi, FWHP=690 psi. 2050 Make static logging passes. 2100 POOH, RD Schlumberger, RU Otis to set standing valve and repl.ace dummy valve at 6808' MD with a Camco CSK-1 circulating sleeve. May 18, 1983 "C" SANDS INOECTIVITY TEST 0530 0730 0830 0850 1240 RD Otis after setting SV and CSK-1 and RU Schlumberger. RIH with CCL/GR/HP/RA Tracer/Temp/oontinuous spinner. Tie-in and make static pass over 6700-6940' MD. Set HP at 6900'MD (6006'TVD) below water injection point. Action suspended for change out. Priming pump to start constant BHP injection test. Kuparuk Nell 1Y-14 Production/I'njection Test Sequence of Events Page 6 1246 Start water injection, initial WHP:625 psi. "C" Sands are not taking water as well as the "A" Sands. We will attempt to pump at minimum pump rate without exceeding 4000 psi BHP. 1730 1800 60 bbls water away according to tank straps, should have water to the perfs. (B3 rate meter not very accurate at these low rates.) ' BHP=3920 psi, WHIP=1450 psi . Start constant BHP injection. QW:320 (by tank strap), BHP=3934.8 psi, T=80°F, WHIP=1475 psi. Attachment 5 summarizes rate and pressure data for this portion o.f the test. Tank strap rates were used in this table due to inaccuracy of the rate meter at low rates. May 19, 1983. 0610 End injection period, make dynamic logging passes. 0655 Start RA Tracer Survey. 1000 End tracer survey and set HP at 6900'MD (6006'TVD). 1013 Start pumping diesel. 1156 2320 SI for falloff test. FBHP:3932.3 psi, total water pumping time of 21 .5 hours, ave @W:337 BPD, total volume pumped: water-302 bbls, diesel 25 bbls. End falloff test. FSIBHP:2999.1 psi, FBHT:147.7°F. 2340 Make static logging passes from 6700-6940' MD. May 20, 1983 0143 'Begin pumping water. BHP:2996 psi, BHT:148.B°F, will try to maintain 1350 psi POP. 0830 64.3 bbls water pumped, should have water on the perfs. BHP=3945.1 psi, POP=1520 psi, QW=230 BPD. Begin Step Rate Test. Attachment 6 summarizes the rate and pressure data during this part of the test. Kuparuk WelI 1Y-14 Production/Injection Test Sequence of Events Page 7 1812 BHP has fallen from 4400 psi to 3390 psi and has now increased to 3541 psi, HR tool failure suspected. Suspend Step Rate Test. Formation broke down at an instantaneous bottomhole pressure of 4625 psi at 1442 hours and QW=1440 BRD. 1830 Make dynamic temperature pass. 1905 POOH to check HR, start pumping 25 bbls diesel at 720 BPD, WHIP=1600 psi, POP=1700 psi. 2000 SI well, will make necessary repairs and resume in the morning. HR is ciogged with a thick tar-like fiuid. Totai voiume pumped: water-371.6 bbIs, dieseI-25 bbis. May 21, 1983 0600 RU Schlumberger 0800 RIH, set HP at 6900'MD (6006' TVD). 0920 Begin injecting water. BHP:3000 psi, WHP=600 psi, ROR=1350 psi. 1530 2147 65 bbls water pumped, should have water on the perfs. Start Step Rate Test. Attachment 7 summarizes the data for this section. HP acting up again. Suspend test. 2230 Make dynamic' temperature pass from 6700-6940' MD, QW=2160 BPD. 2300 POOH to change HR before falloff test. Decrease QW to 720 BRD. 2330 Running low on water, cut back to 288 BPD. May 22, 1983 0015 SI for 5 minutes to pull lubricator. 0027 Increase rate to 720 BPD. Kuparuk- Well 1Y-14 Production/Injection Test Sequence of Events Rage 8 0103 0110 0117 0122 0145 0155 0223 0243 0324 1530 1554 1625 1640 1658 1713 1830 1900 RIH with P/L string and new HR. Having trouble getting down, decrease rate to 288 BPD. Increase rate to 720 BPD. Increase rate to 1440 BPD. Tie in and set HP at 6696'MD (5804'TVD) to avoid tar-like substance at 6900'MD. Increase injection rate to 2160 BPD, BHP=4260 psi. Will pump water for 25 minutes to ensure that the formation is pressured up. Switch to diesel, QW=?20 8PD. Move HP to 6750'MD, (5858'TVD). SI for falloff test. FBHP=4090.6 psi. Totai voiume pumped during step rate test and before SI: water- 443.5 bbls, diesel-25 bb.ls. End falloff test. FSIBHP=2938.4 psi. Begin injecting water, QW=288 BPD, BHP=2950 'psi. Shut down pumps for 15 minutes to clear frozen line. Resume water injection. QW=144 BPD. Increase rate to 216 BPD, POP=1300 psi. Increase rate to 720 BPD, POP=1700 psi, BHP=3980 psi. 58.3 bbls water pumped, should have water on perfs soon, reduce rate to 216 BPD, BHP=4000 psi. 67.1 bbls water pumped, BHP=3975 psi, ~W=187 BPD, POP=1650 psi. Start constant BHP injection period. Attachment 8 summarizes rate and pressure data for this period. Kuparuk Well 1Y-14 Production/Injection Test Sequence of Events R age 9 May 23 , 1983 0300 Make Iapse GR done. 0419 HR reset at BHP=3959.3 psi. 0430 Increase injection 4190 psi. 0700 Increase injection 4320 psi. 0835 0858 May 24, 198 0200 dynamic passes from 6670-6940'MD. RA tracer time rate to 1800 BPD, BHP stabilized at rate to 1008 BPD, BHP stabilized at Begin pumping diesel. SI well for falloff test. volume pumped: water-359.9 3 End falloff test. BHP=4282.4 psi. Total bbls, diesel-25 bbls. test'. FSIBHP=2~31 .9 psi. POOH and end 6750'MD (5858'TVD) · QW=259 BPD, ATTACHMENT 1- "A" SANDS TEST CONSTANT SURFACE PRESSURE INOECTION PERIOD 5/14-5/15/83 TIME 1300 1330 1400 1430 1500 1530 1600 1630 1700 1730 1800 1830 1900 1930 2000 2030 2100 2130 2200 2230 2300 2330 24-00 0030 0100 QW,BPD 778 749 749 749 749 763 763 749 648 691 691 720 677 720 706 706 72O 72O 720 706 720 706 691 706 706 BHP, PSI 3896.3 3905.7 3924.2 3925.7 3933.8 3939.1 3969.0 3912.1 3852.5 3889.1 3858.7 3885.0 3900.6 3915 .2 3896 .8 3906.6 3908.9 3916.7 3881 .3 3884-.5 3893 .7 3884.5 3892.9 3892.9 3889.5 720 ave 3902.2 ave STEP ATTACHMENT 2- !1 A II RATE SANDS TEST TEST NUMBER 5/15/83 ONE STEP TIME SURFACE PUMP AVE QW PRESSURE PSI BPD AVERAGE BHP PSI I 0310-1400 2 0420-0520 3 0540-0640 0700-0800 5 0830-0900 6 0915-0940 1400 720 3980 1500 936 4082 1600 1238.4 4181 1700 1728 4254 1900 3254 4352 2000 4500 4440 *Breakdown occurred between StePs 3 and 4. STEP STEP · ' ATTACHMENT 3- "A" RATE SANDS TEST TEST NUMBER 5/16/83 TWO SURFACE PUMP AVE QW AVERAGE TIME PRESSURE PSI BPD BHP PSI 1 2 3 4(1) 6 7 8 9(2) 10 11 12 13 14 (1) (2) (3) 0530-0630 1200 0645-0730 1300 0745-0830 1400 0845-0930 1500 0945-1045 1600 1110-1200 1700 1330-1400 1750 1415-1430 1850 1445-1515 1800 1535-1610 1700 1630-1700 1600 1730-1800 1500 1830-1915 1400 2000-2100 1300 Breakdown occurred between Started stepping back down. Questionable. (3]) Steps 3 446 59O 792 1087 1540 2002 1949 3103 2405 1805 1459 1267 878 844 and 4. 3733 3842 3962 4076 4150 4227 4274 4351 4305 4226 4120 4020 3864 3845 ATTACHMENT 4- ' ~ "A" SANDS TEST CONSTANT BOTTOMHOLE PRESSURE INOECTION PERIOD 5/16-5/17/83 TIME 2200 2030 2100 2130 2200 2230 2300 2330 0000 0030 0100 0130 0200 0230 0300 QW,BPD 835 85O 850 850 85O 864 865 85O 864 864 864 864 85O 864 864 BHP, PSI 3848.4 3849.7 3839.7 3838.4 3839.8 3846.3 3845.4 3838.3 3844.4 3847.8 3844.8 3848.9 3841.5 3845.2 3847.8 856.5 average 3844.4 average ATTACHMENT "C" SANDS TEST CONSTANT BOTTOMHOLE PRESSURE IN3ECTION PERIOD NUMBER ONE 5118-5119183 TIME 1800 1830 1900 1930 2000 2030 2100 2201 2230 2300 2330 0000 0030 0100 0130 0200 0230 0300 0330 0400 0430 0500 0530 .0600 QW,BPD 320 320 320 345 316 320 360 322 360 322 360 440 360 360 34O 340 28O 40O 400 400 360 320 274 3~1 BHP, PSI 3934.8 3924.4 3912.0 3940.5 3904.6 3937.3 3940.0 3916.8 3928.3 3915.6 3931.7 3925.9 3926.1 3933.2 3926.9 3936.6 3935.8 3928.3 3924.8 3925.7 3914.6 3919.9 3915.5 3910.6 345 average 3925.4 average ATTACHMENT 6 "C" SANDS TEST STEP RATE TEST NUMBER ONE 5/20/83 SURFACE PUMP AVE QW STEP TIME PRESSURE PSI BPD AVERAGE BHP PSI I 0830-1000 1585 230 3950 2 1000-1135 1650 260 4020 3 1135-1335 1800 310 4125 4 1335-1435 1900 345 4225 5 1435-1531 2000 720 4300 6* 1631-1830 1875 1440 Unstable - Suspended test. *Insufficient data to determine breakdown point. ATTACHMENT . 7-- "C" SANDS TEST STEP RATE TEST NUMBER TWD 5/21/83 SURFACE PUMP AVE QW STEP TIME PRESSURE PSI BPD AVERAGE BHP PSI I 1530-1630 1550 216 2 1715-1800 1650 274 3 1830-1930 1750 424 4* 1945-2030 1825 706 5 2045-2130 1850 1440 6 2138-2146 2000 2160 At 2147 hours HR started acting up again. *Breakdown occurred between Steps 3 and 4. 3950 4050 4150 4260 4350 4480 ATTACHMENT 8 "C" SANDS TEST CONSTANT BOTTOMHOLE PRESSURE INOECTION PERIOD NUMBER TWO 5/22-5/23/83 TIME 1900 1930 2000 2030 2100 2130 2200 2230 2300 2330 0000 0030 0100 0200 0230 0300 QW.,BPD 240 180 240 240 250 230 240 280 260 260 280 260 280 240 280 280 BHP, PSI 3980 3975 3990 3985 3995 3985 3990 3995 3980 3975 3960 3930 3980 3990 3960 3965 238.1 average 3977.2 ave 1 Y-14 (SEC 01 T11N RO?.~) ~--' .......... COMF'LITATIF;N DAI'E BOS:--; GYFbqSF:OPIC F;LIRVEY PRUDHOE BAY <S ¢* :..c., ~ FEBRUARY 20, 1'.~:E::3 ._lOB NLIMBER Ah::-BO-:3FIC)14 AI_J'~SI<A__ c-: ':-~'~' S. 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'71 1:3. :22 602:3 5201.00 5100.00 1243.9'9 N 2323.50 W 822.93 10,22 - ":' ' ~::'":' ' ' ' ' ~"' ....... . ~ '" ~::"~ K '"'-, ~=,'', ,-, ,-' '-, ' ,-,-7 "~ ";2 ' :. :: ,:' . ~,~.~ ,~,,~: ............... ,.:,~'[) ~: ~ ~ ~D.:' ........................ ~"~f~'D'~';'D( ~ ........................................ ~'~',:,~'~' ~,=~'""!~1 ...................... ~'"~..,'E~'~"~D"'~ ........................... ~,:~ ,~,~..~ '~:' .......................................................... ~. :~',',,:,:,, ,t: ......... ....... ':::, ............ ;, :: :: i' ::. ::: :] :~:~:L:~. :: ~ ~::, ~:, ~::~::~:~':'~:~:~:~:~','. ~ :~;~ ~'~ ;::~::,: ':::.,:,,x .,.:, :~:,, :: :~::~'.,, :, '.~,~'~:h~; :~; '. :{:~:~:~',~',~'.~:~: ~ ~ :~,,' ,~::;,., :, ,,: '. 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C)C) 1:397. :32 N 25:33.4.9 W :355.59 O. 79 7:357 6501. O0 6400. O0 1405.95 N 2542. ~,2 W 856. :38 O. '79 ~.-,~-, c~.'-,,:~ '-"-' ""'" '-"3/ "'-' Z " "" ~' ~ '-~ ' '-' ~' ' " "" "" ::~.:~ ~.:~:~ :.~ ::~ :~ ~: ~ ~:~ '.~ ~::~ ~::~:~ ~ :~..~::CCt~::~E:: B.~d~:E~B~ ~:.~ ~ ~:.~:.::~:: :.~:: :::.:: ~ !~ BR~.::. :.~ ::~ ~ ::~ ~,:~ :~.~ ~:: ~::~'.::': ::::~:R:.~:B::::: ~:.:::::: ::~:. ~. :::::::::::::::::::::::: :::. ::::~:::~:: ~:::. :::::::::::::::::::::: ~.?:~ ::::::::::::::::::::: ::::~:::: :::::.:~:;~:.:: ::::::::::::::::::::::::::::::: ::~.:.~:::.:.~:::~:: :. ~ ~ ::~:.~:~,~::~:: ~:::: ~:: :.:.~:. :::::::::::::::::::::: :.~ :.~::::::.:.~:.:.:~ ~:. ~:::.~ .:~ ~ ~:~ ~: ~::~..~ ~:~ ~:::~ ~::~:~ ::~:.~ .:,::: ::~,.~ :~ ~:~:. ~':~:.~ :~:~::~ :~:i~::~ .......... (~? ~:,~:: "::~': L ~ ~~'~:':': ' ~' ~2:.', ~::":?:"~:' ~ '~,~ ~ ~', ~: ~ ~:~ ~: ~',, :: ~, ,':~: ~:.~':~' ~' :: ' :'.~:~? .~: -~" ~"~ ~:~ :'~ :~::~::~:"~: ~ ::::~'~: :,~:,~' ~':,~ "~4:1~!:,~',,~ ~f~ '~?'~'~: ~::~':~"h~'"~::~" :'~F~ ~:, "::~" ~'~'~ ~:~ ::'! :: ~ :: =: ~::"~ :~:~ '~ ~'::: :'" ~':: :~ :: :,~::~::':~ ':~ ~::~ f,~:: ~ ~ f:~:' ~ ~"~:=::'=~=:~: ~ ~i~=:~ ~ ~:: ~'/:~ ~ ~:: ~:,:: ~~ ~:: ~:'~::':~ ~:*=:~ ~:: !(~:::: ~ ~::(~ ~,~:,~ ~i~'.~=:~:,i ~ ~::~:,:.:,~"::.: ~:~'. :3~:, ~:~'~ ~: (::::: ~ :::: ~:: :~: ~: ~: ~:~ ::~: ~,~ :~ ~: ~:: : .' .... : - :, ,....'::,:: :z:.' '.,:.T,:.,:r'.i:::;..':;. .:~ .~ .. ~:. ,r:{.~. i'::.:.: -::.r:.- ~,~ '~,'-~::..:~- 'z:: '"; .?.': :::':'::" iff:.:::!:-. <:: : ::::: . :' ' . 1 Y-14 (SEC 01 TllN RO'~)E) COMPI_ITATION DATE Iz'RUDHOE BAY FEBRUARY 20, 1'~83 .JOB NLIMBER AK-BO-3()014 ..... ~)L~A~fi':~] ............................................................ KE~_.L Y. B~~G.._~2_.~ ~..l~]l.,. 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"!iii!i:'.: :~-~:%:Ci!::::~iZ.:~i: :~!:::':.: h' ::" ..... :.=.. .......... ;!~:~:~:.::::~:.:.:.!.::.~:'.: :J.b~: ~;.;:~.,: :~;:.~._:....~.:...:. :.:!.!;:::u:::_.....[.:~:.!:~!x;,~.,Jl:!..~..' :~'J.:::' .:'.~,~.~...,:~J~,l:u::~!::.~u~:::?..~:~:~:~.'l~::~Jl.~:~~~:~l :':~.:[1[~::~: :t:::~J::~t--::[~.:::. :::::::::::::::::::::::::: ..... : ..................... :.: ......... MARKER ................... hE:'A'.i-3LtRED ;OE:F:"FI .i : ............. ..= ..... :..TVK~--.-.;:--.-:: ...... ' '~ ::"."I"H :[ CI<NE:::is::': .:.!:-:::. ;:: WZ::'.:IxH:i:::.F,~E:[::,,::::. "l,C:i '"WF.'[,LjHE..AL] ~--:EC: 01 T '1. 1 N RO 9E t' · . . . . . d:, !..l ....! ~....::,0 ..! :.':.7~,::~,..,::,L) ;. ::': :: : ::::::::::::::::::::::: ":,..,:::~: .:,.i: :i.::l{i:,:~4:i:, z ~N': ::, ~-501. · : i: B~-]E: LIPpF'R SAiqD .6? :1. :2 ' "' ~ .... ' .... '" ' ':' "" "-' ":'~ "'" '::~" "' : ~''~:: :::: :~:'''::: ": :~ ''~': '~'~"' '-' ' ::..: : - ..- , ,: 7!:)14.' . ,.: .--., ...... '" ' :':' ":':. ,:. ,~ :.~:':"~ :~ ''''~: :: ':~: :' :':: ::::: .:::" .: ::::::::::::::::::::::::::::::::: ::::": ::"" ~:: '~, '"::: :':' '~" ~ :': :.,~. ~"', l ~"~{ ~ ~ .... z,.~ ~ .~ ..... :~:.: .~.::: ..... :. .... : ...... Z~., ..... : "'i ' ~'~.~ .... ...................................................................... ~ '~ l' .'~ -Z '~ ...: ....... ~.:~,_~,:_,.~: ...... ~:.,~__.:_.:_~..~.~:.~.,~, ~._-, .... '_1 Iq .... ~-.., ~ ,~- ~:, l_gi~ B A S E L 0 ~ E R '3 A N D 7 :~ ...... '2 6, d, :2'71 ,4:3 /", ......... :i. 7 () 4:3 1:3 8 ~-, 1 4 N '-~::....,"" ~::.'"" 1.6 6 W PB]"D "7'2'.;::~':i) 6:;;',:~3:3 5Zl, c.,' ~.- .... ,::,'"""'".~- .:::," .... 4 1 ":":'~ e] '::' 1 I',1 .,..:."".._,":..:,'"" 1 9 C~_ W Our Boss Gyroscopic Survey Job No:. -AT~-BO'30014 Well: 1 Y-14 (SEC 01 TllN R09E) Prudhoe. Bay Field North Slqpe, Alaska Survey Date: February 20, 1983 Operator: Sellers/S~lith Scale: 1" =500' I TI~UE NOFITH -lo00.0o ~o0.00 , ( 208SNL --500.00 HOBIZONTNL PROJECTION l134EWL) 0.00 1000. O0 2000. O0 3000. O0 4000..00 50OO. O0 6000. O0 7000. O0 Our Boss Gyroscopic Survey Job No. AK-BO- 30014 Well: 1 Y-14 (SEC 01 TllN R09E) Prudhoe Bay Field North Slope, Alaska Survey Date: February 20, 1983 Operator: Sellers/Smith Scale: l"m 1000' k 2908.90'@ N61° 02'W I 1000. O0 2000.00 5000.00 VERTTCRL PROJECTION Suggested form to be inserted in each "Active" 'well folder to check for timely compliance with our regulations. ' ~ ' . Operator, W~i 1 Nam~ a~d N6mber' Reports and Materials to be received by: ~ ?- ~ Date Required Date Received ' Remarks Completion Report' 'Yes , ~,' , Well History' Yes .-., .~.. _ --Pi ~ . · - ........... Core Descriptio .' ~:,S' . Registered. . Survey Plat ~ ~.~.. In¢l'i nati°n survey /,/' i~ ................. · Drill Stem Test Reports ,_/~./d.~ .... Pro:tuct2.on Te~t Reports STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX Atlantic Ritchfield Company Arco Alaska, Inc. TRANSmiTTAL From: :. Transmitted hereWith are the following: _7' '.: . _ Receipt Acknowledge: · Return receipt to: Arco Alaska, Inc. At tn: C. Mulliken P.O. Box 360 Anchorage, AK 99510 ARCO Alaska, Inc. Post Office I. ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 Ma~ch 15, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7~20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 '12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well Ravik State #1 #1 Also enclosed are well completion reports for' 1-24 1E--21 2-8 1E-22 7-18 1F-t '7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We al so are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA L .AND GAS CONSERVATION CO /IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellx[~] Workover operation [] !. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well atsurface 2087 FNL, 11347 FWL, Sec. 1 , T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 1017 RKB ADL 255/+8 ALK 2662 7. Permit No. 83 -23 8. APl Number 50-- 029-20910 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of February ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1930 hfs, 02/04/83. Drld 13-1/2" hole to 2460'; ran, cmtd & tstd 10-3/4" csg, Drld 8-1/2" hole to 6787'. Cut cores. Drld to 7386' TD; ran logs. Ran, cmtd tstd 7" csg. Ran CBL. Perforated well. Ran 3-1/2" completion assy. Secured well released rig (~ 0400 hrs, 02/24/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45 5#/ft, K-55, BTC csg w/shoe ~ 2436' Cmtd w/lO00 sx Fondu & 250 sx Permafrost C. 7" 26 O#/ft, K-55, BTC csg w/shoe @ 7320' Cmtd w/1200 sx Class G SEE DRILLING HISTORY 14. Coring resume and brief description Core #1 6787'-6817'; recovered 27'. Core #2 68177-6831'; recovered 14'. Core #3 6831'-6874'; recovered 40'. Core #4 6874'-6930'; recovered 56'. Core #5 7000'-7058'; recovered 58'. Core #6 f/7058'-7118'; recovered 56' Core #7 f/7118'-7177'; recovered 59' A detailed core description will be submitted with the completion report. 15. Logs run and depth where run DLL/MSFL/GR f/7378'-2400' BHCS/FDC/CNL/GR f/7200'-2400' RFT's HDT Dipmeter f/7370'-2700' CBL f/7239'-2000' 16. DST data, perforating data, shows of H2S, miscellaneous data 7055'-7076' 7032'-7044' 12 spf, 120° phasing 6834'-6888' Alaska Oil & Gas Cons.. C~m~,_ ~cl~urage ..... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· /~' /J' ~ ~ '' E Area Drilling Engineer ~/~3 ' SIGNED E /.-~,'~,'f~'*~,~-~ ~f~,/. Xr~L,4,-~,~/ TITL ................. DATE I J ~./ I ~ f~ . in Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 (] R U 2 / M R 20 Submit in duplicate 1Y-14 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1930 hrs, 02/04/83. Drld 13-1/2" hole to 2460'. Ran 61 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2436'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND-Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 6787'. Cut Core #1 f/6787'-6817'; recovered 27'. Cut Core #2 f/6817'-6831'; recovered 14'. Cut Core #3 f/6831'-6874'; recovered 40'. Cut Core #4 f/6874'-6930'; recovered 56'. Drld to 7000'. Cut Core #5 f/7000'-7058'; recovered 58'. Cut Core #6 f/7058'-7118'; recovered 56'. Cut Core #7 f/7118'-7177'; recovered 59'. Drld to 7386' TD (02/17/83). Ran DLL/MSFL/GR f/7378'-2400', BHCS/FDC/CNL/GR f/7200'-2400'; RFT; HDT dipmeter f/7370'-2700'. Ran 171 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 7320'. Cmtd 7" csg w/1200 sx Class G. Instld 7" 'packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus. Ran Gyro/CCL. (PBTD = 7239'). Ran CBL f/PBTD - 2000'. Perforated well. Set packer on wireline @ 6928'. Ran 3-1/2" completion assy w/tail @ 6969', pkr @ 6735' & SSSV @ 1865'. ND BOPE. NU tree & tstd - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Secured well & released rig @ 0400 hrs, 02/24/83. JG2DH18:sm 03/11/83 Atlantic Ritchfield Company Arco Alaska, Inc. TR~SMITT~ From: Transmitted herewith are the following: ipt Acknowledge: o ~eturn receipt to: Arco Alaska, Inc. Attn: C. Mulliken P.O. Box 360 Anchorage, AK 99510 Date: L RECFlV.~D Alaska Oil & r/r.,s Cons. An'chorng,v ARCO ~, INC' AT'N: - AFA/3I! P. O. BOX 360 ~~-//o Transmitted herewith are the following: PLFJ~E NOTE:~-~ F- FIIbl, T- TAPE, PC - PHOTOCOPY · ARO0 ALASKA, INC. Alaska Oil & Gas Cons. Commission ATI~: ~ - ~311 Anchorage · · P. o. ~x 3~o ~/, ~~ ~0~, ~. 99510- 35 LOC ATE D IN PROTRACTED SEC, IiTWR liN.! RGE,.9 E.! ?MI,AT .MERIDIAN. "' ,_ 180' " . .'o ' ' _ _, L60' TYP..STAKEOUT ... ' ! RESERVE PIT, 200" _ . m PHASE II . -[.. RESERVE' PIT t I PHASE I 380' .~. Y= 5 974755.35 X= '530921.60 LAT. 70° 20'31.5137". LONG. 149° 44' 56,599" 568'FNL , 1252' FWL I0. Y= 5974755,3,7 X-- 530861,81 LAT, 70°20' 31,5165" LONG. 149°44'58.$45" 568' FN~, 1192' FWL I I, ¥= 5974755, 40 X= 530801.57 LAT. 70°20'31.51'90" LONG. 149°45'00.,105" 568'FNL~ 1132'FWL 12. Y = 5974755.31 X-' 530741.58 LAT. 70° 20' 31. 5206." LONG. 149°45'01.858" 568' FNL , 1072' FWL 13. Y-- 5975115.63 X = 530741.64 LAT. 70 °2-0' 35.064~" LONG. 149° 45'01.813" 207'FNL, ~074~ FWL 14. Y=5975115. 61 X= 530801.96 LAT. 70 o 20' 35.0621" LO NG. 149° 45'00.050" 2:08' FNL, I 134' FW L NOTES' 51 SURVEY I 15. Y=5975115.51 X-' 530861.37 ' LAT. 70° 20'35.0587" LONG. 149°44 208' FNL~ 119:5' FWL 16. Y=5975115.:56 . X-' 530921.68 LAT. 70°2-0'35.0547" LONG. 149044 '56. 552" 208' FNL,1254'FWL D.S. A VICINITY MAP Scale': I"--Imi. I. ALL Y & X COORDINATES ARE ALASKA .STATE PLANE~ZONE 4, 2, DISTANCES TO SECTION LINES ARE GEODETIC, :5. SEE REE DWG, 22988~SHT, 7Y'I2'3OOI~REV. 7A, 4. DRILL SITE AND Y 8 X COORDINATES ARE BASED ON MONUMENTS I'Y WEST AND I'Y MIDDLE BY L HD A~SOClATES, drawn by'J.B./D.E dwg. no. NSK9.05 d.17 ,11 I ' I I D.S. IY CONDUCTORS AS-BUILT LOCATION PHASE I date' FEB. 1985 scale' 1"=300' i I]811 IISSI]G, IIIIIIIIII ,mt till I.HEREBY CERTIFY THAT I AM PRopERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA~ AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION~ ~NDTHAT ALL,DETAILS ARE · CORRECT AS 'OF JANUARY $0,1983. ARco Alaska, Inc. Kuparuk Project North Slope Drilling CERTIFICATE Thru: MEMORANDUM Stale ~ASKA OIL AND GAS CONSERVATION COMMISSIO~'~ l°:Co V. Chatterton chairm, an Commissioner of Alaska FROM: DATE: February 6, 19 83 FILE NO: 10 8/A TELEPHONE NO: Harold R. Hawkins Petroleum Inspector SUBJECT:~'~itness DOPE Test on ARCO Alaska, Inc. Kuparuk Well No. 1Y-14 Sec. 1, TllN, R9E, U~ Permit No. 83-23 ThursdaY, January 6, 1983 - I left ARCO's "E" pad at the ~_~pa~uk'River Field, Sub~'ect of another report, to ARCO's "Y" pad to witness a DOPE test. Friday-, January 7., 198--3- I witnessed, the DOPE test on ARCO's Well No. 1¥-14, there were no failures. In summa~3, i %;,itnessed the DOPE test on ARCO's %.~ell No. 1Y-14 at the Kuparuk Field. The BOPE tests were satisfactory. O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator .4 ~ ~-~- Well / Location:· Sec Drilling Contractor ~ ~ V~ ~ r,, ~cation, General Well Sign .. General Housekeeping Reserve pit Test Pressure · Rig BOPE Stack Annular Preventer Pipe ·Rams Blind 'Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Lower Kelly Ball Type Inside BOP Well Representative, Pe rmi t # . / /~ Casing~Set @ Re/resentat iva. Choke Manifold Valves, / NO. 'flanges 2 ~ " '- Adjustable Chokes Hydrauically operated choke ~~ .~ ~ . . .days'and'~'' ACCUMULATOR S'YSTEM ' Full Charge Pressure ~_~·67~ ps.ig Pressure After Closure /~'6~6~., psig · 200 psig Above Precharge Attained: .-- rain ~P sec Full Charge Pressure Attained: ~ .min.:~0 sec N2 22,00 ,~¢96; ,,:"71 ~-~ .-~2OO psig 2~ ~ ' / - / Controls: Master ,'~/~ Blinds switch cover KeIly. an._d Floor Safety Val.v. es - Upper Kelly. Test Pressure....' ~d~6F~,' Test· Pressure 3 ¢;6;(9' .... Test 'Pressure .~ ~.~ ,,. Test Pressure Test Pressure Test Results: Failures Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. / Distribution orig; - AO&GCC cc - 'Operator ¢c - Supervisor. Inspector I February 2, 1983 ~. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 _Anchorage, Alaska 99510 . Re: Kuparuk River Unit 1Y-14 ARCO Alaska, Inc. Permit }~o. 83-23 Sur. Loc. 207'FNL, i!34'F%~, Sec. 1, TllN, R9E, UM. Bt~hole ~c. !351'FSL, 1369'FEL, Sec. 35, T12N, R9E, U~.~I. Dear Enclosed ia the approved application for permit to drill the above referenced well. · If coring is conducted, a one cubic inch chip fro~ each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuou~ 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 surveys. Many rivers in Alaska and their drainage systems have been classified as important for thespawning 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 o~fice,~ Department of Fimh and Game. Pollution of any 'waters of the Sta~e 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 an~ended. Prior to co~mncing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing installstion of the blowout Mr. Jeffrey B. Kewin Kuparuk River Unit IY-14 -2- February 2, 1983 prevention equipment so that a representative of the Commission ~ay be present to witness testing of the equipment before the surface casing shoe is drilled.~ W%ere a diverter system is required, please also_ notify this office 24 hours prior to co~amencing equipment 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 you~rs, Chairman of Alaska Oil and Gas Conservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office B,.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-14 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Y-14, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we expect to spud this well on February 5, 1983, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A ~~~~~neer JBK/JG: sm At tachment s JG1/L38 ECEIVED Alaska 0il & Gas Corm. rjomrnissiorl ~chorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~'.- ALASKA O,L AND GAS CONSERVATION CO~,,,~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE J~(X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface -J'4 N2 207' FNL, 1134' FWL, Sec. 1, T11N, R9E, UM (appj',ox.) At top of proposed producing interval 1306' FSL, 1298' FEL, Sec. 35, T12N, R9E, UM ~i?a~s..COrl$ 'Chorage At total depth 1351' FSL, 1369' FEL, Sec; 35, T12N, R9E, UH 9. Unit or lease name Kuparuk River Unit 10. Well number 1Y-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. PAD 65', RKB 101' I ADL 25548 ALK 2662 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 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 1Y-13well 60' ~ surface feet 16. Proposed depth (MD & TVD) 7276' MD, 6403' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1000 feet. 21 14. Distance to nearest property or lease line miles 207' FNL ~ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 38 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 02/05/83 2707 psig@ ROOF Surface 305_5 psig@ 5_q~_5 ft. TD (TVD) SIZE Hole i24" 1t3-1/2" 8-1/2" Casing 16" 10-3/4" Weight 65# 45.5# 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling K-55 BTC Length SETTING DEPTH MD TOP TVD 80' 36' I 36' 2262' 35' I 35' I I 33' I I 33' 7242' M D BOTTOM TV D 116~ 116' 2297'1 2200' I 7276'1 6403' I QUANTITY OF CEMENT (include stage data) 300 c.f. 1400 sx ext. Perm & 250 sx Perm. C 525 sx Class "G"extended 375 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7276' MD, (6403' TVD). A 20"~ 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" 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 will be 2707 psig. Pressure calculations are based on current reservoir pressure. Surface ' pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. Estimated top of cement on 7" casing string is calculated to be 2529' MD which is 500' MD above top of West Sak Sands. if hydrocarbons are detected in the Ugnu Sands, cement will be brought up to 500' above top of the Ugou Sands or the shoe of the 10-3/-~"-casing (2297' MD)). 1Y-14 will be 60' away from 1Y-13 at ~ surface. Tb,eir~courses are divergen~ from there and there are no closer wellbores ~nywh~re ~~ e. //~_~.,.,~ ~,~, TITLE-Area Drill lng Engi neet DATE The space belo~,'~r'~iOn 6se ~ CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I~IYES ,~10 [~]YES I~NO t~-Y E S r-INO Permit number APPROVED BY Form 10-401 Approval date IAPl number 50-~ ~1- ~i O SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE .Fe~b~uat'y 2, 1983 by order of the Commission Submit in triplicate --,. ~-"~' ;. !:'. : [i; ,:ii ;~, .... I - ' I :s ~ i ; ' ~ i ~1 I i 1; i I I ~'.j ~ :::-~ ~ [ i i ~i i i Ii I I ; I Ill ,¢~¢1P i--II1 ~ ~: ~:-r:~:~ ~ . ,, _~'i;.-1-:.i ~ i ~ I : i ~ ~ ~ '. ~i : ; ' ~ : i '. : : ~ ~ ~ ~ : : ~ [ ', .... JAN 2 8 '~a-',: Alaska Oil & Gas Oons, Anchorage ' ' ~ · , ' : ' - .... . . · ~ ' ' : ' ~~~, I ~ ~ ~~ J J J J Jill : ~ : : : , .......... ~, · ~ . , , ~~ : , ' . . : ~ , . , ~ -~~ ~~~~ ~~ ~:: ~ ::__~ ..... ~_ l~__~~_--+ ~.~ : ' : I : ~ J ~ I ' , J ~ ; I~ ~ ~ I J ~ L~ ~'~ ~ ~ [~ [ J J : ~~ ~ ~~J~ JllJ Jl~ll~l~ lJljl~ J~jl~l~lJ~ ~Jl ,iii -:: ! t , s :~ : I ~ : : : ' I : : :. ~~~~~~~ ~- I : , : ~ ~ ~ ; ~ ~ ; , i~::},,~ ~ Lz_~ ~ ....... -®. ._ Surface Diver~er Ssstem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi dri.lling spool w/10" side outlets 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automatio cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6o · 20" bell ,nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours° 3~ Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. 16" Conductor t .1. %, PREVgENTORJ ) - - ~ : . BL I ND RR,'iS '-:T ' '-- 2 ' "-' °'' : P Z PE RR;'1S -7 !="s/8- sooo PSt , SRRA BOP STiC 2. 3. 4, e . _. 1o 3o SPOOL 6 PiPE RaHS 16" 8radenhead 16" 2000 PSI x lO' 3%3 PSI casing head · 10" 3000 PSI tubing head 10" 3000 PSI × 13-5/B~ 5gOO PSI adapter spool -" 13-5/8" 5000 PSI pipe ra:s 13-5/8" 5000 PSI drilling ~pool w/choke and kill lin~ 13-5/8" 5000 PSI pi~'ra~- -' .-.. ]. '"-:' '.-"' ' 13-5/8" 5000 PSI blind r~% -- '; .... --' 13-5/8" 5000 PSI an~lar .... .:f,..:.. . . . - - - _ . ACC~-~TOR ~I~ ~T _- ~- .- .. :-.. -. . -' . ~ ~ FILL A~t~TOR ~E~IR ~ P~P~ m l ~'~ ~I%4 HYD~IC ~IB'' -. ~ ~T AC~-~T~ P~E IS ~ ~I .- ~I~ 1500 PSI ~,~~ ~ ?r~ ~~R. ~S~YE TINE Th~ C~E ~ ~ITS S~~- ~LT ~qg RECOPJ r~ T~ ~ P~ ~I~ ' .m I)a ~J ~ ~(ITS ~ ~ W~a ~ OFF, - .. ~ ON IA~C R~RT. ~ A~~ t~ L~T ISq5 SE~,~ ~~ T~'~ 1~ PSI ~)tII~ P~SU~. - 13-5/8' BOP, Sl'A=< TEST ~ S~T mm S~T ~ ~~. ~. SC~S ~ ~. lO MII~TES~ B~ED ~ ~I. IP~E-PR~Sb~ TO ~ ~D 8~ ~R 10 ~E V~V~ DI~I ~~'( 0F ~.-- YALY~, IF ~g, WI~ TO ~ PSI. - ' _ ~1 TOP 5~ OF PIPE S~ ~ PIPE ~. IJ;~,~E PP, ESSUP~ TO 3~ ~ ~lg a~ ~E lO H!t~T~. B~ED TO Z~ PSI. ~' ~ig TEST TO 3~ ~I F~ iO ~~. B~O T0 EERO PSI. ' ~I~I. - T~ ~IDPIPE Y~Y~ TO T~~f ~ ~ I~I~ PZ~ TEST IIIF6~TI~ fica. - _ - - ', - ' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. t'?'"/: ITEM (1) Fee (2) Loc APPROVE DATE (:'2 thru" 8) " (3) Admin //~,,,. I- ~.'/'~] (9/' thru 11) (12 thru 20) · YES NO 1 Is the permit fee attached ' :'[~,. , 2. Is well to be located in a defined pool ........................... .. 3. Is well located proper distance from.property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included .............. 7 Is operator the only affected party 8. Can permit be approved before ten-day wait 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Does operator have a bond in force........................ . . · ,...... Is a conservation order needed .... ''''''-'''.'-'''''''''''''' ''''''" approval needed Is administrative ................................... Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or prodUction strings .... ~ Will cement cover all known productive horizons ..................... ~ L, Will surface casing protect fresh water zones ....................... ~ ..... Will all casing give adequate safety in collapse, tension and burst.. ~f Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ,~ REMARKS (5) BOPE ~4~.~ //-.~~.f (21 thru 24) (6) Add: 21. 22. 23. 24. 25. Is a diverter system required ....................................... ~ __ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirementS ............................................. Additional Remarks: WVA:~ JKT~ HJH ~ rev: 12/06/82 POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. I I I I I I I I I I I I I I I I I I I e e Memory Multi..Finger Caliper Log Results Summary hQ~'~5' We::. Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. Novernber14,2005 6041 2 3.5" 9.2 lb. J-55 Buttress Tubing Well: 1Y-14 Field: Kuparuk \ D. '2 _ 0:--, '"). State: Alaska 7;>/ CT .:::> API No.: 50-029-20910-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 6,814 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: <-::'..;)\'~'k'1 sO ç - \ ~O 4()~ 'b~-oÇ This caliper data is tied into the top of the Injection Mandrel @ 6,808' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The..3...5:' tuDinwappeørsin good-condition wüb respect to. corresive dalltøte, wåtAÖleexœption of a 78%wétlLpepetration in joint 214 (6,694'). The isolated pit in joint 214 is recorded by one of the caliper fif1Qers and located approximately 2' above the top of GLM 5. The damage recorded in the 3.5" tubing appears l11ainly in the form of isolated pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 3.5" tubing interval logged. This is the second time a PDS caliper has been run in this well. However, this is the first run of this interval ofthe 3.5" tubing. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting 214 @ 6,694 Ft. (MD) ( 78%) Jt. No other significant penetrations (> 17%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ~"[' c,· '~- F,-.I, <:;;i..... .....;(\,~.~~.. . ~\;¡,J!r\" ... '\ \?.f tÞ- ~ Field Engineer: D. Cain Analyst: M. Tahtouh ProÞ,ctive Diagnostic Services¡ Ine. / P.O. Box 1369¡ Stafford¡ TX 77497 Piìone: (281) or (888) 565-9085 Fax: (281) .565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fa>;: (907) 659-2314 Alaska Oil & Gas Cons. Cornmissinn Anchorage I I PDS Rep rt Overview Body Regi n Analysis I Well: Field: Company: Country: 11'-14 Kuparuk C:onocoPhillips Alaska, Inc. USA Survey Date: 1'001 Type: 1'001 Size: No. of Fingers: I I TUbing~-~~N-.om, .0, D 3,5 ins ~.^-------- Weight 9,2 ppf Grade & Thread J-5L___~_ Nom.lD 2.992 ins I Penetration and Metal loss (%, wall) I November 14,2005 MFC 24 No. 40665 169 24 Nom, Upset 3,5 ins Upper len, 1.2 ins lower len, 1,2 ins Damage Profile (''10 wall) penetration body metal loss body penetration body o o 100 I 250 200 150 100 I .50 o 40 to over 8.5(}¡~ 85~/o o to 1% 10 to 20% 1 to 10% 20 to 40% I ClM 1 o o I I Damage (body) 20 ClM 2 I I ClM 3 I general line nng hol~ / poss GlM 4 COITOSlon corrosion corrosion ¡ble holf' ClM 5 10 0 0 0 0 Bottom of Survey = 217 I I I Analysis Overview page 2 I I metal loss body 50 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I i-- I I Correlation of Recorded Damage to Borehole Profile 3.5 in 9.2 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 y- 14 Kuparuk ConocoPhillips Alaska, Inc. USA November 14¡ 2005 - - ___ __ - - __ - __________________n__________ I I I I I I I I I I I I Appro\.. Tool Deviation Appro\.. Borehole Profile 31 765 1542 ClM I 2340 0 3114 ~ ..; LL c ClM ') 3888 ClM 3 ClM 4 ClM 5 --.------ 50 Damage Profile (% wall) I Tool Deviation (degrees) I Bottom of Survey = 21 7 I 4662 54.52 6236 6814 100 I I I I I I I I I I I I I I I I I I I e PDS REPORT JOINT TABULATION SH Pipe: Body Wall; Upset Wall: NominaII.D.: 3.5 in 9.2 ppf J-55 0.254 in 0.254 in 2.992 in lY-14 Kuparuk ConocoPhillips Alaska, Inc. USA November 14, 2005 Well: Field: Company: Country: Survey Date: joint It Depth 1',>1 Pell. PPIL ,VieL11 Mill. Damage Profile No. (Ft) Ih"t Body ID. Comments (%wall) ¡i ! (IllS.) (Ills.) 0 50 100 ~J._ 12 0 0.02 0 2.8'L_ ~£'.lJP...... III ~.~- .2 15 0 0.00 ) 2.93 .PUL.. ------ .. 2" 0 0.01 0 2.95 PUP . ..) ,) 1 31 0 0.02 2.93 íi!I 2 6·' 0 0.01 I 2.93 -) .. :; 95 0 0.01 2 2.93 4 1 '17 0 0.01 2 2.95 ~/ 5 159 0 11.01 2 2.94 6 189 0 I 0.01 I ( 2.93 7 220 0 0.02 2.93 . 8 249 II 0.01 2.94 I 9 281 () 0.01 2.94 10 311 II OJ)] 2.95 . r-. I _._.~_.. I 11 341 1 0.01 2.95 12 3 1 2.94 _m~.______~_.. 13 4 1 I 14 4 ( I 15 4'; I 16 495 0 0.02 2.93 17 524 0 0.G1 2.94 18 553 0 0.1)1 5 ) 2.92 19 585 0 0.01 ---- 4 ) 2.91 20 617 0 0·01 --3· ., 2.95 ~.2L 647 ! 0.ü2 ') 2 2.94 0 ... I .~2.2 679 O·QJL_ , 2.93 0 5 --^~~---~- . . . 23 708 OJ1L I 2.94 24 736 0 ()'ol .5 I 2.91 ')" 76:5_. 0 0.01 4 I 2. (};2 ~.J ~---.._.~- 26 795 0 0.ü2 9 I 2.89 Slio Ma~h,IÇJwe.Lþodv. Lt Deposits. pi ~7~ .--- 827 0 0.01 4 3 2.94._ -_._~ II I 28 856 0 om 10 I 2.95 29 0 4 .2 ._.~- ---.. 888 0.01 . _2,522.. 30 917 13 .2 .. --- ..,...~ I 0.01 2.94 31 948 0 0.1)1 I 2.96 32 979 0 0.01 4 33 101 0 OJ)l ¡ 34 1042 0 0.01 35 1072 0 OJ)l 2 36 1104 0 0.01 2 2.91 , 37 1 (35 (J 2 -~.... 0.01 2.92 -.. 38 1167 0 0.01 3 2 2.,93 39 1198 . 0 0.00 2 2 2.93 40 -^-- 1229 0 O.OL 3 2,91 41 1261 0 0.G1 4 2.88 I 42 1292 0 0.01 ) 2.92 I 43 1323 0 0.G1 4 2.94 ...-. _44_ 1354 0 O.OL 3 2.92 45 1386 0 0.01 2 2.93 46 1418 0 0.G1 4 2.93 _47 1449 0 0.01 3 2.91 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.2 ppf J-55 0.254 in 0.254 in 2.992 in 1 Y-14 Kuparuk ConocoPhillips Alaska, Inc. USA November 14, 2005 Well; Field: Company: Country: Survey Date: loint It. Depth I Pel Pen. Pen. ,Vie 1;\1 Mill. Damage Profile No. (Ft.) ! Body I.D. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 48 1480 0 O.OL '-it-~ -~------ 2.90 49 1511 0 (1.0J j 2.92 50 1542 0 O.O:L --T ) 2.94 51 15ì3 U OJ)] ) 2.93 .. 52 .li;04 0 OJ)1 ;: ) 2.91 ~', 1635 1'1 (!.OO :2 ) 2.90 ::D 54 1666 .,_ 0 0.01 2.93 ---"".'~ -_..~. 55 1697 ---- 0 (!.OO 2.90 56 1728 0 0.01 2.94 I 57 . 11'>2 0 0.01 2.9:2. I I ... 58 1791 0 (!.O1 2.90 59 1822 0 CJ01 4 2.91 59.1 1853 0 0 0 0 2.81 SSSV_...~.. 60 1866 0 0.01 3 ) 2.93 ... 61 1897 0 0.ü2 9 ) 2.94 1 62 1928 0 0.01 3 ) 2.93 ----........- ---"._- ;3 1959 0 0.01 4 2. 2.94 I ,4 1990 0 0.ü1 3 I 2.94 ,5 2022 0 0.02 9 2. 2.87 6 ~) .1 2053 - 0 0 0 0 N/A CLM I II Mch @ 9:00\ '......Jlf>...... 2059 0 0.02 9 ) 2.87 It.J)ªposits. 67 -')(}tì1 0 (WI 3 2. 2.93 .....-- 68 -- 2121 0 0.03 13 ) 2.94 Sh'lllow ;,ittil1ll. 1 t. npnn<:;k 69 21 ~1.. 0 0.03 n 2.90 L1, Dªposits. 70 2IJHL 0 0.01 2 3 2.90 _..~....,....._-- .--.. .- .~,._..- 71 2214 0 .. 0.02 9 3 2.91 ~~~, 0 I) ) 72 2246 ..Q.02 1,91 ì3 ..2276 u 0.&2.. 13 2. ~Ji2 Shallow pittinK.... 74 23j)8 .. 0 0.01 3 2 2.92 .-......, 75 2340 0 0.01 '5 2.95 76 2372 0 4 ') .. 0.ü1 2.<)5 -. 2401 0 0.02 9 2. 2.CJ}.. - --.-.----.-. 2432 0 0:ð3 !2 ~---,- I -- 2.92 2, 0 2. ........- 0.01 1 . 2.94 RFf± 0 12 9 ! 2.93 -..,..- ..-..-..- 81 0 '5 I 2.95 82 0 10 I 2.94 IIì1I I 83 2 0 11 I 2.92 IIì1I 84 2616 ~o 12 2 2.94 Shaljow pitting. ~ 8S 2646 .01 6 ) 1,94 ~ I 8(, 2. 2. .... 2678 .00 2,91 87 2711 ,\ 0.03 13 I I 2.91 Shallow J)itting. I 88 2743 0 0.01 4 2. 2.91 89 2775 0 0.00 2. 1 2.92 90 2807 0 6 2. .. 0.01 2.91 91 2835 0 0.01 3 I .2.91 92 2868 0 0.ü2 9 I 2.90 _..,.~.- 93 2900 0 0.ü1 6 2. 2.90 94 2932 0 0.01 ') 2. 2.94 95 2960 0 0.01 5 2. 2.92 Body Metal loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.2 ppf J-55 0.254 in 0.254 in 2.992 in lY-14 Kuparuk ConocoPhillips Alaska, Inc. USA November 14, 2005 Well: Field: Company: Country: Survey Date: i Joint Jt. Depth ¡'¡'II Pen. PC'! .v1el;]1 Min. Damage Profile I No. (Ft) I Body !.D. Comments (% wall) I (Ins.) (Ins.) 0 50 100 I ! 96 2992 JH~ 9 2.90 7fIIÆ m ~ 97 3024 0.02 ß ) 2.93 III ;;: ) ----^'~ 98 3022_ 0.01 2.94 i 99 3085 0.01 " 1 ).91 100 1114 0.03 17 2 2.93 101 3146 0 0.03 10 / 2.97 0 P ) ~--- ---~ 102 3174 0.03 2.89 ffl" _.._._~._... , liB 3206 0') 9 2 i I -,_..,~-_.~ , ,..~..,~,--~-- 104 3238 0.01 4 ~,~._-- ~..~ . .--- 105 3267 Ö 0.02 1) ) 2.92 106 3299 0.01 5 1 2.93 --_.,._~.~_. ._m107m ~n2q O.G2 I 2.91 !JIll I 1()R 3360 0.02 2.91 fill 109 -nq, i ._----_.....~-- III 0.02 2.93 110 3424 í )4 111 1454 I III 112 141'\5 ( 1 Shallow Ditting. !III 111 1517 I ( ) !III 1]4 3549 ( 7 I ] ]5 3580 -~.. 0 0.01 I 7.92 --..-..-- 116 36]0 0 0.02 ) 2.91 !!Ii - 0 I ) .__....~_. !!Ii 117 3640 0.03 2.91 _ llR 0 II 3671 0.02 ¡ 2,94 I) , -.--- II ]]9 3702 (J.O 2 2.93 ..-- I) ) J]j) 37:rJ 0.01 2.9..L ]21 3764 I) 0.01 ) 2.93 I p'/ ~95 (j 0.02 ml! !!Ii f-~ (j .-.. .~.~. ]'P ~:2j) 0.01 I ./-.j '~ ]24 .- ~,-,------- ._,-,~ .,"~~~- 3858 I 0.01 I ") ¡ "'- 125 3888 I) 2 . 2m _M'_ 0.01 ]26 3919 I) o JJ3 0 I .87 !!Ii 126.1 1950 I) .. 0 A ClM 2 (latch @ 8:30) 127 '195h 0.02 2.78 It. II! 128 '{CJ RR ; 0.0] î )].9] 129 4020 ( C 2 II! no 40.S0 i C II) ) II! 131 4082 C 2 I 132 41n c ) 133 4141 C 134 4173 OJ)? II! I) .. .. _135 4204 0.01 2.90 136 4236 () Q,03 1': 2.92 Shallow Ditting. II! .....JlZ. 4267 (I 0.01 2.90 ----.- I) -..-.- .-l~8 4298 0.01 2.89 139 4328 I) 0.01 2.93 ]40 4360, I) 0.01 2.91 (j n ~"'I-- _'M"_ --.-.- m.,__ 141 4391 0.03 2.89 m_ 142 4420 I) 0.02 2.92 -~ It. DeDosits. (j -.-. _ ]43 4452 0.01 2.93 (j I .--.- -.- 144 448J OJ)] 2.9'1 ---. Body Metal loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.2 ppf J-55 0.254 in 0.254 in 2.992 in 1 Y-14 Kuparuk ConocoPhillips Alaska, Inc. USA November 14, 2005 Well: Field: Company: Country: Survey Date; loint Jt. Depth Pen Pen. Pen. :Vletal Min. Damage Prom No. (Fl.) I Body LD. Comments ("Iowa!!) (Ins.) (Ins.) 0 50 100 145 4510 0 0.01 4 ) 2.91 146 mn .4540 0.03 0 ) 2.87 Lt DeDosits. 147 4568 0.01 ) 2.86 n_, ) 'M^^^~~_____ 148 4600 OJ}1 2.94 ) --~_._...,-,~~._~.~ ~., 149 4632 0.02 2.86 --~ .- 4 ) _..~~ I 150 4662 ( 0.01 ~f91 151 4694 0 0.00 2 )88 Lt. DeDosits. ~_m_'_'__~_____ I 1 ~') 4725 ( 0.03 II) 2 2.92 'fI!Æ -)~ 153 4755 ( 0.02 ±=±~±±89' 154 47Rf,- ( 0.D2 .89 I ~~-- 155 4B17 ( 0.03 D 2.90 1--,156 4848 I (J.O 3 D 2.90 ..l.E 4879 ( 0.03 D 2.93 158 4910 : 0.01 2.92 Lt DeDosits, I 159 941 ( n.01 2.90 160 9Tt ( 0.01 2.91 161 ' ()()5 ( 0.02 ¡ 2.90 Lt 162 Oi7 ( OJ)I 2.91 Lt 161 5n69 0 n.n1 2.92 164 5099 0 0.01 2.90 I 165 51il : 0.01 2.90 166 5162 ( O.OL_ 2.92 166.1 5194 ( () 0 ; N/A GLM 3 (Latch @!2:(0) 167 .5200 ( OJJ2." 7 ! 2.91 !III _ 168 I 5231 ! 0,02 n ) 2.93 !III 0 - 4 ) -~,--.,------ .____.M 169 5265 (H)] 2.93 I n_ 170 5296 0 (J.DI 0 0 2.92 ---~-- 171 5327 0 0.01 i( 2.93 -- -...-...----- 172 0 ì ..~....'~M'____ 5358 0.01 ,. 2.91 .__mm._____ I 173 5389 (I 0.03 11 2.92 pi 174 5420 0 0.01 2.90 175 5452 0 0.01 2.90 _...m_ ......lZ.§._ 5483 0 0.01 2.90 -. 0 .-.,..- 177 5514 0.01 2.89 178" , ~45 0 OJB 10 --.- - ..... II 1 '9 , ,75 0 OJ)1 1 \0 , ,06 0 0.01 1 \ 1 , ,37 0 OJ)1 ( 1 \2 5669 0 n.01 2.93 183 5700 0 0.01 " 2.90 184 57:H 0 0.01 S 0 2.93 185 5763 0 0.01 i 2.92 ... 186 5795 () (}.01 ;> 2.89 187 5826 0 0.01 4 2.92 ---~,._- 188 5857 0 0.01 2.92 189 5888 0 0.01 2.90 ---, m_19O 5918 0 0.01 2.91 191 5948 () 0.D2 I 2.91 ,_. _192 5982 () OJ)1 'I 2.91 n_ 193 6014 0 0.01 2 ).91 , Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaILD.: 35 in 9.2 ppf J-55 0.254 in 0.254 in 2.992 in lY-14 Kuparuk ConocoPhillips Alaska, Ine. USA November 14, 2005 Well: Field: Company: Country: Survey Date: 1'''1 Peli. '\;\i'\:11 - ^^~.,~ ^ , -- Damage Profile Joint It Depth Pen. Min. No. (Ft.) \ pSi'! Body !.D. Comments (%wall) I (Ins.) (Ins. ) 0 50 100 r 194 6045 n 0.01 2 \ 2.91 195 6076 n 001 4 ) 2.89 ,- n q ) 2,91 196 6108 0.02 - Lt. Deposits. -. 196.1 6138 n 0 n n N/A "eLM 4 (Latch @ 1 :(0) ^~._~- 197 f>l45 . n 0.03 12 2 2,·95 Shallow Dittimt ìr 198 6176 n 0.01 ;> 2.88 .- -~-II I 199 6204 n 0.02 q 2.(!1_ Lt. Deposits. ---" n (I ._.~,--~ 200 6236 0.02 2.89 201 6267 n 0.D1 i 2.91 202 6297 n 0.02 (I 2.91 I , 203 6328 n 0.01 2 2.9Q - ~- 204 6359 n ,0.01_. 2 2.88 . -- I _205 6389 n 0.D1 S 2.94 -~...~..- 206 6421 n 0.03 12 2.92 . ., 20 6452 n 0.01 ;> 20 64112 n 0.01 2 )0 6513 n 0.00 2 )1' 6.542 n 0.00 2 ~1 1 6S72 n 0.02 8 12 6603 n 0.01 S 2.88 .~ 213 6633 n ,- 0.01 2 2.91 214 6665 n 0.20 78 /I 2.90 Isolated oitting, .J.14,.1 6695 n (j- 0 CI N/A - elM 5 II ;¡tch @ 9:001 214.2 6702 I n jW~. 13 ) 2.87 PUP Shallow J2Í.!!iJ:!1L !Mil - 2143 I 6711 n -º- n n N/Ä PACK OFF A C<T ,oy 214.4 6716 n 0.00 2 n 2.95 PUP ---.- I I ..JJ 4.5 6725 CI 0.00 I n 2.96 PUr _JJ4J~ 6735 n 0 n n 3.00 P A'(KER - 215 6745 n 0.01 \ ì 2.92 I 215.1 6775 n 0 n n 2.81 W·I Ninnlp 216 6778 n 0.01 2 ! 2.91 I 216.1 6808 n 0 () n N/A Iníection Mandrel (latçb.@ 9:(0) 217 6814 n 0.01 4 2 2.89 END OF LOe Body Metal Loss Body Page 5 - - - - - .. Well: Field: Company: Country: Tubin : - - - - - - - .. - - P S Repo Cross S ons 1Y-14 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 November 14, 2005 MFC 24 No. 40665 1.69 24 M. Tahtouh Survey Date: Tool Type: Tool Size: No. of Fingers: Cross Section Tool speed 55 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 17 0 214 at depth 6694.1 8 ft Finger 9 Penetration = 0.198 ins Isolated Pitting 0.20 ins = 78% Wall Penetration HIGH SIDE = UP Cross Sections page 1 - - - I KRU 1Y-14 I li1¥B14 ./ API: 500292091000 Well~ INJ AnQle @ TS: 9 deQ @ 6854 SSSV Type: LOCKED OUT Orig 2/24/1983 Angle @ TD: 7 deg @ 7386 sssv Completion: (1865-1868. ~n ~^~~---- OD:3.500) . AnnÙfarFluid~ LastW/O: Rev Reason: SetTBG Stop, Set Packoff Assy ! LOQ: Ref LOQ Date: Last Update: 8/31/2003 Last TaQ: 7065 TD: 7386 ftKB I ~:c:::12003 Max HOle_ 42 deQ @ 3100 Size Top Bottom TVD Wt Grade Threac:L.. 20.000 I 0 114 114 92.00 H-40 SUR. CASING 10.750 0 2436 2316 45.50 K-55 PROD.CASING£(B 7320 6464 26.00 K-55 ·ii:...",...'.'.<'.',·'.', <iii, ·.....·i..·.'..':·.· f~~u1-~% I TVD I Wt I Grade I Thread 6116 1 9.20 1 J-55 1 BUTT I Interval TVO lone Status Ft 1 SPF 1 Date Type Comment ---- '"6834--= 6888 ~598·3 - 6036 UNIT 54 12 2/24/1983 IPERF 5" Scallop: Dresser; 120 7032 - 7044~ ,C-4,C-3,C- deQ. Phasing 6179 - 6191 A-4 12 12 2/24/1983 IPERF 5" Scallop; Dresser; 120 1 7055 - 7076 6202 - 6222 - --- A-3 .-- 21- 12 2/24/1983 IP~ I St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Mfr I Cmnt 1 2064 1997 Cameo KBUG DMY 1.0 BK 0.000 0 9/20/19931 _1 DMY 1.0 BK 0.000 0 9/20/1993 I 1 DMY . .+--c~,.. BR-- 0J500" 9/20/19931 ....l.. amco.nK 1.0 0 -.4- amco K 1 DMY 1.0 BK 0.000 0 9/19/19931 5 am co KBU DMY 1.0 BK 0.000 0 6/20/20051 Packoff Assy St MD TVD Man ype V Mfr V Type VOD Latch ~ (6705-6726. OD:1.812) --;e- . Mfr Run 6 6808 5957 tii¡~rBUG ~BK 0.000 0 7 6911 6059 amco KBUG DM 1.0 BK PKR ~.1!tþ~ TVO T'IDG DescriDtion ID (6735-6736. 1865 1824 SSSV Cameo TRDP-1A (Locked Pulled "'" Vä,ve ur¡ 5/11/97 2.812 00:6.156) 6667 5818 SLlPSTOP SLlPSTOP set 9/6/2005 2.992 6705 5855 PACKER 3" ECLIPSE PACKER, SEIjJ/5/2005_ 1.812 NIP 6705 5855 Paekoff BAKER K3 PACKOFF (52.5')/SNAP LATCH ASSY SET 9/6/2005 0.000 (6774-B775. ---..- Assv 00:3.500) r 6709 5859 SBR Baker w/ Otis Profile 2.813 6735 5885 PKR Baker 'FHYu. ~---- 3.000 6774 5923 NIP Cameo 'W-1' Nip ole 2,813 6833 5982 TBG STOP TBG STOP SET 8/10/2003 2,992 6928 6076 PACKER Baker 'FB-1 ' 4.000 6957 6104 NIP Cam eo.'Q'l'JiJ:plef\jººO 2.750 6968 6115 SOS Baker 2.992 6969 6116 TTL..n.._.....u. 2.992 PACKER (6928-6929, 00:6.156) I 1 NIP (6957-6958. 00:3.500) 11JBING (0-6969. 00:3.500. 10:2.992) Pert u.. .... (7032·7044) u~ ...,..... .......... .~ -.. . .- Pert ---- ......... (7055-7076) .- ~... ...... ....... I I I I I I I I I I I I I I I I I ~iGH R~$OLUTIO 49©0 , '2736.0 ., 2738.0 ~ 2740.0 * 2742,0 . , ~744.0 35,1 317 * ~750,© ~ 275~.~ * 2758-, n , 2762.0 * 2764.0 , 2766,0 10.1 9,6 ~.9 5.8 293 29i 22--3 , 2770.0 277~.© ~ ~' . · ~ 2776.0 ~.9 · 2778,0 '-3;6 ~ ~786. ~ ~2 202 ~ 2788.0 ~!5.'5 245 ~ 2790.u , 2792.0 ~. 9 23 i · 2798,0 2~.:4 228 · :2~"~, ~ ~-~.~7 236 -~ 2806,0 ~.:a 215 96 35O 38~7 39,7 38.~ 38.8 38.9 39,0 39,0 39,1 39,1 39.1 39,3 39,3 39.~ 39,5 39,6 39.7 39.7 39.8 39.a 39.9 39.9 qO.O 40.0 40,! 40,I 40,! 40.I 40.1 40,0 40..0 304 303 304 304 305 305 304 305 305 306 306 306 306 306 306 306 306 306 306 06 306-- 3O6 306 306 306 306 306 -307 307 306 307 3O6 307 307 306 I .O~O 10;0 i0.I 10.3 10..4 9,9 9.6 9.6 9.6 9.8 9,7 9.6 9..7 9,6 _ ~.~ 9.6 9.8 9.7 9,6 9,6 9.5 9,5 9,6 !0.I !0.3 !0.4 10,~ 10.9 10,7 10,6 ! 0,7 10,6 ~ 2~i4,0 7,9 226- 40.0 305 ii.i 1 1 '~_ 1 1 1 1 1 1 1 11..5 1}..5 ll..O !0.9 12.9 12.9 15.9 1~.8 9,5 O. 5 C~,3 F P F F F E C E D F F D D F D D D D 28i6.0 !7, 6 2,36 ~".0 ~.;7 285 '8~ 0 2632.0 283a 0 2~36.n 2~. ~ ~37 ~ ~-9 9 23~ 2846,0 23.¢7 235 ~ 23j. 2850.0 25,9 212 ~52.0 28~ O ... -~ ~ 2856,0 2858.0 ~.~ ~856.0 2870.0. ~87~.0 -i~,3 122 28~a," 9 2RS6.0 ~i2.9 2890.0 2~92 O o 25i 285 199 i !? 254 _ - 2i2 40.0 305 qO.O 305 ~o.o 3~5 40.1 305 40.1 305 ~0.2 3O5 40.2 305 AO,2 305 40.2 305 40,2 306 40.3 306 gO,3 306 40.z 306 -40.2 305 40'3 305 40.3 305 40.~ 305 40.3 3(34 40.'3 304 40.A · ~. ~ _. 40.4 40,4 304 40.3 304 40.3 ~-'04 ~0.3 304 40,2 305 40.z 305 ao 2 305 40.2 306 40,2 306 40.3 306 40.4 306 40.4 305 40,5 304 40.4 304 40.5 305 40.5 3O5 40.6 305 40.7 305 ~-~ ~ 304 i0.8 9.6 9,6 9.7 9.7 9, ? 9:° 6 9,6 9,,4 9.2 9.2 9.3 9.3 9,~ 9,2 9.2 9.. 3 9.3 9,3 g,3 9.4 J. 1,1, 11,. 13.1 il,.5 tj..6 !1,,8 II,.9 12.4 11,.6 11',6 11-,,,6 11..6 1~.0 ~.3 ~.3 ~..7 2.6 D 2896.0 2898,0 2900 n 29~2,~ 2904.9 2910,0 2912,~3 ~0 !61 277 , 2930.0 ~i5.-6 333 , 2932.0 ~ 2934.0 25,6 -327 * 2936.0 23,3 272 293fi.0 !7.9 ~-~ ~ I9.8 2942,0 2944.0 20.7 2952.0 ~.~ 995~.0 .~o~.0 3.3 . _ - . - '~96e.0 lO. ~ 2970,0 291 275 328 'i77 ~75 2!6 257 40.8 40.~ _ 40,~ 40,7 40.7 40,6 40.6 40,6 40,5 40.6 40,5 40.5 40..5 -40.5 40.5 40.5 40,5 4u.5 40.5 40.4 40,4 40.5 40,5 45.5 40,6 40,6 40.6 40.6 40,6 DEV. Di~k DIAM 304 304 305 305 3O5 304 304 3O3 3O3 304 304 304 304 304 3O3 303. 302 302 302 3O2 '302 3O3 304 303 303 303 -303 3~3 304 3O4 9.4 9.3 9.3 9.3 9.2 9.2 9.2 9.2 9.2 9.3 9.3 9.3 9.3 9.3 9.2 9.3 9.4 9.4 9.4 9.~ 9.~ 9.4 9,3 9.4 9.5 9.5 9.5 9.5 9.5 9.6 9,7 9,6 237 40 7 302 ************************************************** 11,.. II. Ii,. 1t.. 'JO. 10. 10. 10. ~0. I O. 1 O, 9.5 1 a,.' --. I_~DEX ~ , ',E EST. , =g * AYbAa.~IC RIPB~IEbD CO~4PA {.~-1~ PAGF 4-FII, E DEV. :P!At.~ ',I 1AN ~ 'BEST ~ZI. ].-3 2-4 * =A 2976.0 ~.:7 248 -2978.0 2980.0 ~,2 309 2982,0 I0,'4 253 2984.0 9.8 257 29~6,0 2982,0 ~ ,~ ~'~. 2990.0 ~2 93 2994.0 ~-.~4 200 2998,0 ~!B.O 151 3000.0 ~ ,2 3006,0 3008°0 30!6.0 158 80 !33- !69 ~02 O,n -3022.0 9,4 3024. ..... 3026.0 ~.~ i80 ~u~u,v ~.~ i73 303~,0 D.5 303~,0 3o36.0 3035,0 -6,2 _ ~ -30~2,0 -5,:7. 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O. 3 ~13.6 302 10.0 302 lO.O 13.5 301 iO.O 13.5 301 9.8 !3,5 30t 9.8 304 9.9 1~.5 304 9.9 !3.6 303 9.9 13.5 303 9.5 13.2 303 9.4 13.2 303 9,8 13.3 303 9.8 1).4 303 9.8 13.5 304 9.9 13.5 304 9.9 1~.5 ~624.0 ~.~ 155 ....... o i0 2 3oo 4~0 ~ ~ ~ 277 _~ ~ ~ ~ ~ .~. ~ ~- . 4832.0 4S~O.O " -4846,0 9,:7 !24 484g'0 ~,2 161 ~850,0. 4852,0 ~,6 127 485a.o 5,6 181 4856.0 ._ ~60.~ ~64 0 4866,0 k~~ 4874,0 4878,0 4~86 -n {890.0 4~~* O fi 3 ,77 , 4894'.0 5.9 228 3~.I 302 34.5 304 9.9 13. 34.5 304 9.9 ~3. 34.5 306 9.8 34.4 305 9.8 34.4 303 9.9 13. 34.4 304 9.8 13. 34.4 305 9,g 34.4 307 lO.O 13, 34.4 308 I0.! ~4.4 306 !0.0 34.4 304 !O.l 13. 34.4 303 !0.1 34.3 303 10.0 34.3 303 10,0 13. 34.3 303 I0.1 ~.3. 34,3 303 10.2 34.4 30~ i0.1 13. 34.3 302 10.-0 13. 34.3 303 9.9 34.'3 303 9,9 34.3 304 10.0 34~3 304 9,9 ~4.~ 3(34 9..9 t3. 34.2 304 9.9 34.3 306 i0.! 13. 34.3 307 i0.2 34.2 307 I0.0 13. 34.2 309 9.9 34.3 31.0 10.0 34.3 309 !0,I 34,3 307 !l.0 34.3 304 t1..7 I~. 34.z 303 !0.9 12. 34,2 303 Io.2 34.~ 302 9,9 13. 34,2 30! 9.9 1~. 34.2 30! 9.9 13. 34.1 30! 9.9 34,I 30I 9.9 !3. 9.a 13. ~898,0 6.9 4912,0 9,7 4914.0 4918,0 -4920 0 4922,0 13.~4 4924,0 !5.9 49~6,0 *q30 0 i6,9 4934,0 4944.0 4946.0 4950,0 -9, - 4956.0 -~95~,0_ - 0 4966, 0 496S,U 167 i79 130 I47 99 i77 183 182 26O · ~25 218 239 160 i98 14i 34,! '34,! 34.1 34.0 34,0 34.0 34.0 34.,0 34.0 34,0 34,0 ~,0 34.0 34,0 34.0 34.0 33,9 33.9 33.8 33.8 '33,8 33.7 33,8 33.8 33,8 33.8 33.8 33.S 3~.S 33.8 33.8 30! 301 301 30i 302- 303 302 301 30i 302- 302 302 303 3O3 3O4 304 3O3 30! 30~ 3OO 3O0 3OO 3OO 300 299 300 3O0 301 30t 301 30I 301 301 30i 30! --, I!<D~;X * 4974,9 33,8 30au 9.9 9.8 1.3.5 9.8 13,5 9,9 i0,! 1~,5 !0,2 13,5 i0,0 i3,6 9.,9 13.6 i0,1 13.6 lO.O J.~.6 9.,9 13,6 9.9 1~.6 9.9 13.7 9,9 13.7 9,9 1~.8 9.9 1t3,8 9,9 iO,O 1~.7 I0.0 13,7 9..6 1~).6 9,6 13,5 9,9 !~.7 !0.2 10.2 13.7 !0.0 10,0 9,9 1~.7 i0.0 13.7 10,0 1).7 9.9 I:).7 9,9 !0,0 13.7 9.9 13.7 9,9 9.9 J.~,6 9,9 i~.5 9.B !3.5 9.~ J.~.5 ,,,, ****** ~., **~ ****,, ~ ****** ** *** ****** **~.,., .~ .***** **** ** **. ~ *** **.,. , 4976,0 6._I I_76 * ~978,0 5,9 187 , _-4982.0 t~.:2 i88 ._ 498~,0 ;~ ~9c~ ~ 2~,-2 23° :2 242 * 4998,0 * 5000.0 ~ -5u02.0 ~ ~006 0 .~- 5008.0 4.:5 143 .~ot~.o ~.9 276 50I%,0 .5016.n ~ ,, 5018,o 5020,0 502~_o0 5028'0 5032.0 5034,0 ~; :;7 5044.0 ~.9 5048,n 5.8 ~050.o %,2 5052,0 it.i 220 -185 245 -3 -304 248 _292 '~32 293 250 293 267 33.7 33.-7 33,7 33.6 33.6 33,6 33.6 33,6 33,6 33.6 33.6 33,6 33.6 33.6 33.6 33.6 33.5 33.-5 33.5 33,5 33~5 33.5 33.5 33,5 33.-5 33.6 33.-5 33.5 33,5 33.4 33.4 33.3 33,3 33.3 33.3 33.3 300 300 301 301 302 303 303 304 303 302 302 302 302 302 302 303 303 303 303 303 302 301 301 -302 302 302 303 302 299 298 297 298 298 299 299 299 298 I0.0 9.9 9.9 10,0 10.1 9.9 9,9 9.9 9.9 10,0 !0.2 !0.2 10.0 10.0 9.9 9.9 9.8 10.0 10,0 lO.t 10:0 10,0 i0.2 9.9 9.9 9.S 9.9 I0.0 iO.O 9.9 9..9 !0.0 t'3.7 13,8 13.8 13.7 1~,5 '1.3.5 13,6 1~.7 l~.P 1~.9 14.! 14, I 1%.0 1~.9 1~.9 13.9 !~.~ 13.9 1~.8 13.8 1~..8 13.8 13.9 13.9 1~.8 13.9 , -5054~0 33.3 299 10.0 14.0 5056,0 50.58.0 5060,0 5062,0 5066,0 * 5068.n * 5072,0 5074.0 * 5076,0 507S.0 5080.0 5086,0 * 5090.0 ~0~ 0 5096.0 , 509~,0 51OO.O * 5110,0 5112,0 5116.0 5~24 0 5126,0 , -5130.0 5~32,n _. 9.9 -i5-4 3,i 3,9 302 177 !75 I95 2O5 I95 !96 i80 i72 33,3 301 ~0.7 33,2 302. !1.! 13,9 33..2 302 !0,9 13,9 33.3 30:1 .10.5 13.9 33.3 302 9.9 13.8 33,3 303 9,8 13,9 33.3 303 9.9 13.8 33,3 303 i0,0 13,7 33,3 303 i0.0 13,7 33.3 303 9.9 13,8 33,3 303 9.8 13.8 33,2 302 9.8 13,8 33.1 30! 9,9 13,9 33.1 301 9.9 13.9 33.I -30! 9,9 1~.9 33,1 300 9.9 33.! 30i 9.8 13.7 33.2 301 9,8 13, 7 33,2 301 9.8 !3.7 33.2 301 9.6 33,2 300 9.8 13,8 33.1 300 9.8 13.7 33.! 299 9.8 I~'.8 33,1 300 9,8 13,8 33.1 301 9.8 13,9 33.i 301 9.9 33.i 301 9.9 33,0 301 9,9 14,1 33,0 30! 9,9 14.1 33, ~,--, 300 I0.0 14.0. 33.0 '30! 9,9 !3.9 33,0 301 9,8 13.9 33.0 301 9.8 13.8 33.0 30! 9.~ 13.8 33.0 301 9.S 33.0 301 9.~ 13.8 33,0 301 9.9 I3.9 33.0 301 9.9 13.9 33.0 302 ~,8 13.9 D F C A D 9.9 13.9 i34 33.n 0 ************************************************************************** D5¥, DIA~ ~[ I! aZ~, t'3 1.4.0 14.0 14.~ 14.2 1~.1 14.2 1~.2 14-3 i4.4 14.4 14.3 !4.3 14.2 14.2 14.1 14.! 14. t 14.0 1~.9 5i36 0 ~ 4 ~7 32~ 3o0 513@,0 ',~,-8 285 3~.9 5140,0 2~.~ 233 ~2.9 ~00 '-~ -~ 32. 5!42-'~ '3.1 ~ q 30t 51~4.0 2~,,i 26i 32.9 301 5~46.0 ~ !. 3.~.~ 2~9 32 9 300 5150,0 ~.-3 20t 32,9 300 5152.0 9,_I 246 32,9 300 5154.0 ),:3 ~5-.. 32,9 5156'0 32,a 300 5158.0 ~5..2 212 32,8 300 ~I~ . 301 5160,0 ~.4 -~u 32.a 5i62.0 4 .'> 1o6 32,~ ..... ~ ~ 3~..- =16~.b ~ 301 5!66,0 32,8 300 ~ - O~ . 300 5!68,0 j.8 2.~ 32 8 5~?0,.0 ~.~0 2~ 3~,9 300 5i72on 32.9 299 32.9 299 5174,0 517$,0 32.S 299 5180.0 3~,8 299 5182.0 32.8 299 5i_86,0 2~.:7 304 32,8 300 5~s8.~ ~§.3 305 3~.~ 300 5i~n.O 2~.q 300 32.a 300 ._ 5192.0 32.~ 300 ~4 ..... 32.8 5i96,0 l_),.9 i37 32.8 30! 5198.0 32.7 300 5200,0 ~ 7 5282.0 ~.~ _ 284 ~ 7 - 'r, 4 ~' - 32,7 299 52,,~.u ~,I 5206,0 ~/6 5208,0 ~..o 5~ _ ~.7 2 ~ ~ a 32.7 299 ~I~.0 32.7 300 5~ n 32.7 301 10.4 1_0.3 10,0 !0.0 9.9 9.9 9,9 9.9 9.9 9.9 t0.0 9,9 9.9 9.8 9.~ 9.~ 9.9 9,9 9.8 9. ~ 9.B 9.S 9.6 9.6 10.2 10,2 9.9 g,8 9,9 9.9 , 5216.0 ~ 5228,0 5230,0 ~.~5 ~232.0 0.2 '5234,0 5236,0 ~,'6 5238,0 -l~ 52~6,u 5256,0 5258,0 5280.0 .5~66,0 4.i7 -. 527~o0 5278,0 5.0 59~n 0 5288.0 g.3 5290,0 285 ~3 i07 314 152 163 139 '323 I89 229 184 176 133 ~76 249 _~_91 !52 !70 203 202 32.6 32.6 32.6 32.6 3~.5 3~.5 32,5 32.6 39.6 39~5 32.4 32.5 ~2.~ 32-~ 32.4 3~o3 32.3 3~.3 3OO 9'8 13,9 299 9.8 299 9.8 1~.9 299 9.8 13,9 299 9,8 300 9.8 300 9.9 300 9.B 298 9.8 1.3.8 298 9.8 298 9.8 298 9,8 298 9.8 13.9 299 9.8 299 9,8 299 9.8 14.0 299 9.8 300 9.8 14.0 299 9.8 ~4.0 299 9,8 299 9.8 1~.~. 300 9.8 14.1 300 9.8 299 9.8 298 9.8 14.! 297 9,8 14.1 297 9.8 297 9,8 14.2 298 9.8 298 9,8 298 9,8 1~.0 298 9.8 1~.0 298 9.8 14,! 29~ 9,8 298 9,8 998 9.8 14.3 299 9.8 14.3 3OO 9.8 14.3 300 9.8 14.2 ********************************* .5294,0 5296.0 530~.0 ~.0 530S.O 53!2.0 5316o0 53i8.0 5320.0 -171 7~ ~ 5324,0 ~.i laq . -5334,0 *5342,0 53~6,0 -, ~ ~ __ , _-5354~ O S,9 4 * 5362,0 9.:g ~- 5364,0 ),4 131 * 53~6,0 3,9 i27 * 5370,0 ~,.2 i36 240 32.3 32,3 32,3 32..2 3~.~ 32.2 3~.2 32.2 3~.~ 32.2 32.2 32.2 ~2.~ 32,! 32.0 32, t '32,! 32,! 32.0 32,! 32.i 3~.! 3~.0 32.0 -----, iNDEX 299 9,~ 300 9,8 300 9,8 14, 300 9,7 299 9,8 299 9,8 1~, 299 9,8 14, 29~ 9,~ 1~, 299 9,8 14, 300 g.8 14, 300 9.8 14, 300 9.8 1~. z99 q.~ 14. 300 9.7 1_4. 300 9.7 14, 299 9,8 !4. 299 9.8 3O0 9.8 i4, 300 9.8 14. 300 9.8 1~, 300 9.8 299 9.7 299 9.7 14. 298 9.8 1~. 29~ 9.8 299 9.B 14, 300 9.8 14. 300 9.7 1~. 300 9.7 1.4, 300 9,6 301 9,6 14, 300 9.7 14. 999 9,7 J-g. 299 9.7 14. 299 9,8 300 9.7 14. 300 9,5 14, 300 9.0 * 5372.0 ~.,i i48 32,0 299 9.6 !4, , 517~-0 },:7- 198 32 0 29~ 9 7 14 L"111~ .~J Il I l i 1 iT-I 'Il [ :.1 j _. DF¥. D % DS. PTlJ * DIP * 5~76.o 5380.0 5382.0 5384.0 5386 n 5388.0 5390-0 . 5392,0 5396.0 5400.0 8.I 5402.0 . '5406.0 5912,0 ~,~ 5414.0 7~ o 9.i 5418.0 5420.0 5424.o 5426,0 5428,0 ~.3 5430.0 ~,~2 5~32.0 · 5434,0 }.2 5436.0 5440.0 - ~ ~ ~aa4,0 ~ I 5446.0 5,3 5450.0 i35 '!23 268 136 125 I27 2t6 159 120 i91 147 !31 ! 256 1-32 3! .9 31,9 31.9 3!.9 31.8 31.9 3!.9 3!.9 31.9 3},9 3t-.8 31o9 31.8 3!.8 31.8 3i-.8 31.8 31.8 31-.8 3!.7 ~1.7 31.7 31.7 3i .7 31.7 31.7 31.6 31.6 299 298 298 299 299 299 299 299 299 299 300 300 300 30O 300 299 299 299 999 9~99 299 299 299 29~ 299 299 298 298 298 298 298 298 298 ~. ~a~a-n -~,I i33 31.6 298 9 i 9. 9. 9. 9.,, 9. 9,, 9. 9. 9. 9. 9. 9 .. 5 9.6 9.7 9.6 9,4 9.2 9.3 ~ 5 9.5 9.3 9.4 9.3 9.2 9°5 9.6 9.6 ~ 5 9.4 9.5 8.9 8.9 9.2 9.3 7 1 7 1 7 7 1 '; I 8 1 ? 7 1 6 1 5 1 3 1 5 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 *********************** , ~ 5506.0 55 iO, 0 55i2.0 5,,9 38 233 155 i2-0 2!.0 30i 2,i8 !50 i62 I83 ~ 55i¢;,0 a.~ 165 5fi20,0 5528.0 5530.0 5532.0 i73 3!.6 31.6 31.5 3i.5 31.5 ;¢1.5 3!~.6 31.6 31.5 31.5 31.5 3i.5 31.4 31,4 3!,4 3t.4 '3!,i 3i.4 3i.~ -r--. 3i;o4 31.4 3!,4 '3!,'. 4 31.3 3!-. 3 3!-.3 31.3 3~,,3 3t,3 3!.3 31.3 31.2 3!-.2 3!.i 29_9. 298 298 298 298 3OO 301 301 3OO 299 299 299 299 299 299 299 _2.98 298 298 2-'98 297 298 298 299 299 299 299 299 298 298 298 298 298 299 299 299 * 5534.0 9.2 i6i 31.I 299 9.2 9.4 9.4 14.'3 9,2 14.3 9,1 14.1 9,2 9,i 14.1 8.9 14.I 9., 0 1.4.0 9.2 1.3.9 9.2 13.9 ~.2 9,0 14,0 9,0 14.0 9.1 !4.1 c-.5 9..4 9.2 14.0 9.¢~ 14.0 9.! 14,0 9.3 l~.O 9.2 14.0 9.0 ! 4.0 C.l 14,0 -.' . 9.1 14,0 8,9 14.0 8.9 9.1 14,0 9..2 :t4.o 9.! !4.0 9.0 9,0 J. 3o9 9.(~ 13.9 9.0 13.8 8.9 .1~.6 8.8 13.5 9.3 13.6 9.3 9,2 13.7 ~ ,ti ,1~ F ~ B · C ~ E ~ E · E ~ ~ E ~ -:: : : . : 5552.0 5554' 0 5562.0 5568.0 5568,0 557~ ~ 557~ 5576.0 5578°0 ~58~.~ 5588o0 5,.~ !,9 9.9 1~..6 ~ - ~ 5586.0 _ 5590.0 5592.0 8.0 5594.~,~ 5596.0 -, 5800o0 * 580~.0 5~08-.0 9~ 0~- 225 31-.I . ~.0 3i,0 3~.0 30.9 3!.0 30,9 31.0 30.9 30.9 30.. 8 30.8 30.7 30..7 30.7 30.7 3o ,7 30,7 30.7 30.7 30.6 30 6 30.6 30.6 ~0.6 299 3O0 300 3~0 29'/ 96 ;296 296 ~97 298 297 29? 29~ ~96 29~ ~9~ 296 29~ 297- '97 3OO 3OO 56i4.0 30,6 299 9, P~GE 36'F1LE ,; 9.2 13.8 9.2 1,3.8 ~. - 9.3 1_~.9 9.2 13..8 9-1 13.7 8,9 13.6 8.9 13.6 9.0 ~3.6 9.! !~.5 9,2 13.4 9.0 13.4 9.{: ~3.3 9.2 13.2 9.0 .~3.. 0 9.0 13.1 9.1 i~. 2 9.0 1},2 9.2 13.3 9.3 !3.3 9.4 {3.3 9.5 ~.3 9.3 ~.2 9.3 ~.0 9.4 12.9 9.3 19.9 9.6 19.9 9.9 1~.9 9.8 I3.0 9.7 13.0 9.7 1~.0 9.8 13.0 9.9 ~3.1 i0.3 12.9 i0.6 13,9 5620,0 5~.3 ~62~.0 !9.6~ ~zv9 5626,0 5630.0 -5634,0 -5638,0 5644 56i6,0 5648,0 !9.4 23i 5650,0 i,-O 242 5652,0 6,:7 i99 565a.0 3.3 i97 5658,0 5662,0 5664.0 5670,0' . -i~,~ 8 !29 5a72.0~, 9.'4 157. 5674.0 :15,'~ i03 5676.0 9.8 144 _ 5678,0 ~, ~ i38 5680,0 15.0 5686.0 I3.0 ~z. 5688,0 . ' ..... n 2~.4 ]27 -569~,0. _~-7 i2! 219 ~z2 30.6 299 :30,6 300 30.6 301 30.6 301 30.5 30i 30,5 300 30.6 300 30,5 299 30.5 299 30.5 300 30,5 300 30.5 300 30.5 300 30.5 300 .30.5 299 30,5 299 30.4 299 30.3 299 30.3 299 30.2 298 30.2 299 ~0.2 299 ~0.2 299 '30.I 3OO 30.2 300 3^ 2 300 30.3 301 -30,2 301 30,2 301 30.2 30J. -30.2 302 -n 2 303 -30.2 304 .30.2 303 30,2 299 30,1 297 30,! 297 30.! 297 30.1 299 9.7 13.0 9.5 12.9 9.6 9-7 9.a 9,9 1~.8 9.9 12.7 9,9 1~.7 9.9 9,9 19.7 9.7 9.7 9.5 !~.4 9,6 9.6 9.3 i2.2 9.4 1~.2 9.6 9.7 1~,3 9.5 1~.4 9.6 1~,5 9.8 12,6 9.8 12.7 9,9 9.7 12,7 9,6 1~.7 9.5 9.6 9.7 9.7 ~9.7 9.7 12.7 9.7 12.7 9.8 9.6 12.4 9.6 9.~ !2.~ 9.7 9.7 13.0 , ,-,--.--------------,----------------------------------, I~DEX * · , -gZ~. ~ . ~ZI. 1-3 2-4 , =~ * ~ 5700.0 * 5702,0 I6.6 * 5704.0 26.5 , 5706,0 ~ 570~.0 ~ ..3 * 57~.0 * 5712.0 29.:7 * 57!4, O * 57!6,0 5720,0 * 5722,0 5724,0 5726'0 57~.© 5730,0 57~ 0 .~e.- 573~.0 57:6 0 * -57~8.0 .- *- * 57~.0 23,8 23.5 2~ '6 25 ..l 31..i ~7 5750,0 5752.0 5754.0 ~7~6,0 30,! ~7~,0 *'57~0,0 5768.0 5770.0 5772,0 12! 125 !40 !44 i4..5 !70 i44 i42 !3.0 i29 1.33 i32 128 30.1 30,! 30.0 30.0 30.0 ~.1 30,1 30.1 30,1 30.! 30,1 30.! 30.~ 30,1 30.0 30.1 30.! 30,I 30.1 30.! ~v,i 30.1 30.i 30,1 30.0 30,0 30,0 30,0 30.0 30.0 29,9 29.9 29.9 29,8 300 9.7 13.1 299 9,7 13.1 297 9.7 296 9.7 13.2 296 9,6 297 9.S 298 9.7 1~.0 299 9,6 300 9,5 13,9 300 9.4 300 9,4 1~.9 301 9.4 13.0 30! 9.4 !3,0 301 9.4 13.1 30! 9.3 300 9.3 13.1 300 9.2 299 9,2 299 9.2 297 9.3 13.1. 296 9,4 13.0 298 9.3 12.9 298 9,3 1~.9 298 9.4 12.9 298 9,4 1~.9 ~98 9,3 298 9.4 1~,9 298 9.4 13.0 297 9,4 1~,0 ~.8 9 4, 13 298 9,5 297 9,7 13,0 297 9,6 13.0 297 9.6 299 9,6 299 9.5 13.0 298 9.4 298 9.5 13.0 299 9.7 tU * 577fi.0 5780.0 5784.0 * 578~,0 29.3 578~.0 25,2 * 5790.0 * 5792.0 332 2O6 233 220 2O4 29.8 29.8 29.8 29.8 29,8 29,8 29.8 29.7 29.7 29.6 29.6 29;6 29,6 29.5 29.5 29,3 29.2 29.2 29.1 29.1 29,0 29.0 28.9 28,8 299 9,6 -300 9.6 300 9.7 300 9.9 3.~ 10.0 300 299 9.8 298 298 9.8 297 9.8 297 9.8 299 9.9 296 9.8 296 9.[~ 295 9.9 295 9.9 296 296 9.~ 295 9..9 295 9,9 295 9.~ 296 9.9 297 t0.1 299 i0.1 30! t0.3 300 1!.1 297 11,3 296 10.3 :u 9..9 295 I0,0 295 I0.0 z~5 9.~ 296 9.7 ~8 298 lO.l 298 1~ 4 297 !0,4 297 t0.3 0.1 5806.0 26.:5 58!0,0 2~.0 22i 5812'0 15,-6 249 5816,0 581 5820.'~. ~ -- ~ .~ 58~.0 5~.~ 277 -5826.0 5828,0 58~0.0 ~ 3 185 5S~2,0 25.6 -191 ~,u z~, ~ 191 5845.0 . . *************************************************** --- ..... =.-# INDEX DI~O , BEST 2-4 * =A 1 1 1 1 1 1 ! 1 ! 1 I ! 1 1 1 ! 1 1 ! t 1 1 1 1 3.2 ~.4 3.5 F ~.. 0 B ~.9 O .F F ~.0 2.2 ~.,5 2.5 2.2 D 2.1 B ~.t ~.9 ~.8 D ~.0 ~ I l1 mil il:~i[, [;I-r ~ . * . -bZI. * ~ZI, I-3 2- **_**************************************************************** 5~62,0 5o6~,v 5~7~.0 5~74,0 5882,0 ~8~0 5~88.~ 5896.0 590~. 0 5908,0 5910,0 5912'0 59-I. 5 o 5924.0 9~ 352 3O5 3.9 ~.6 I7~ 72 165 i02 187 ~05 126 28.7 299 I0.I 28,7 298 JO,O 28.7 298 9.8 I~.~ ~8 6 2q? 6.7 12.4 28.6 297 9.B 2~,5 299 !©.0 12.2 ~8.5 298 10.1 12.3 28.5 ~93 9.7 28,~ 28~ 9.6 ~ 3 280 9.8 ~.g ~28.3 291 9.6 1~.! ~¢8.3 29~_ ~.8_ 19.2 :28,~ 300 ~0.2 1~.4 28.~ 300 ~0.~ 1~.5 -28,~ 30! .~0..6 28.1 300 10.8 '1~.4 28.~ 300 10.5 I~.7 2~,0 299 10,2 1~.9 ~' 298 9.~ 1~.8 28.0 298 9,8 28,0 297 9.S 28.0 296 9.9 28.0 296 9,9 14.3 ~ ~.. ~7.~ 297 9.9 14.5 27,7 299 9.9 14.9 27.6 ~99 9.9 15. J. ~ z99 9,7 ~5.2 27.4 ~99 9.8 27,~ 3v~ lO,O 15.4 97,2 300 ~0..0 ~5,~ ~. 2 300 ~,¢ ~5,~ ~7 ~ 30~ 9.8 ~5.~ 27,& 300 9.6 15.7 ~7.! 300 10.0 15.g 27.1 299 ~0.0 ~5,9 ~ & 298 9.9 27.0 299 9,~ 16.& 27 0 ~01 ~.6 9.7 16o2 30! ---. INDEX D F F 0 '~. D F D 0 , 0 i77 z6.~ 300 g.8 16.2 26.7 300 9.8 16.2 26.7 299 9.7 16.3 26.6 ~99 9.7 16.4 26,5 299 9,6 16.5 '26.4 30! 9.6 16,6 26.4 300 9.8 16.7 26.4 299 !0.0 ~ a 300 9..~ 17,3 26.3 299 9.3 1~.0 26,3 300 9,1 I~.7 26.2 299 9.2 !6.6 6,2 29n ~ 3 26.2 298 9.3 1~.7 ~6 3 300 e.2 15.9 26.2 299 9..2 16.9 ~.! 297 ~.'d 16.8 ~& 0 2~6 ~ ~ 17.2 25.9 296 9.~ 17.6 25,8 296 9.0 ~.~.7 25.7 297 8,9 1~.7 25.6 297 9,~ 25.6 297 9.3 25,5 297 9.1 16.0 25.,~ 297 a.7 !5.4 25.3 297 8.8 i5,9 25.2 297 8.9 16.2 25.2 297 8,7 16.2 z5.2 297 S.6 ~6.3 ~,i 297 8.0 16.4 25.0 296 8,6 ~6.4 25.0 296 8,5 !~.5 25.0 296 ~.~ · 25.0 °95 ~,5 25.0 294 8.5 24,9 295 8.3 1~.1 24.9 295 ~.I ~.~ ~,.~ 295~ fl.3 1~.2 24.8 296 8.6 !~.4 2&o7 296 9.0 5q~ o 5954,0_ 59/6. ~a56 ~ 5958.0 5~bO.J 5966.0 -'5~. 6 59-70.0 5972,a 5976.0 -5978,0 5o~.0 20.I 5982,0 5990,0 5q~2'0 5994.0 ~ . . . 60!4,0 _ _ 6018-0 602.9.0 60~ 0 60jO,O 60~,0 605q,0 6058.0 60~0,0 6o7~,0 607~,0 6076.0 6078.0 162 5.! ),-6 i ; 5~ .96 ~7 133 *6082.0 6084.0 * 6096.0 ,6088,0 * 6090, O ~;- -" O ~gz. ~- * 609~,0 mm m#~ mmm mm #-'~' D1AN 2-4 ************************** 24.7 296 9..0 17.6 24,6 295 9.2 ].9,4 24.6 295 9.3 17,.5 24,4 296 9.2 16.9 24.2 297 9.0 16.2 24.2 ~97 9,0 16.2 24.2 298 9.0 16.3 24,1 297 9.0 !,6.4 ~4.1 297 9.2 !6.5 24,! 297 8.9 16.4 ~4.0 297 8,7 16,3 zS.q 296 9,0 16.5 a~ o 297 9.9 16.3 2S.9 298 8.5 16.1 23.9 299 8.4 .!6.6 23.9 299 9.0 93.9 999 9.5 23.~ 300 9.1 .1.~.6 ~3,7 302 8.~ 23,6 303 ~,7 /~3.~ 30t 9.1 17.6 23,4 300 9,4 17.4 23.3 299 9.5 23,3 298 9..6 16.8 2~ '~ 297 c~.7 2~ 2 296 9,8 !6.4 23.2 295 9.6 16.~ 23.2 295 9,5 16.0 22.9 295 9.8 1.5,6 22.9 298 9.7 ~5.7 22.8 301 11.3 18.3 22.8 309~ !3.9 22,7 301 13.4 16.7 22.-6 300 J_l,6 15,3 -22.5 300 10..8 14.7 22.4 300 I~).2 14.5 22.4 299 !0.~ 14,4 2~.4 298 10.0 14.2 2~.4 ~97 . 9.9 14.1 AZIo !'3 2' 9.2 -i93 ~.4 !46 ~.-2 ~.:7 !.60 5,0 -I55 251 !68 6098.0 aiO0oO * 6102,0 6i04,0 * 6106,0: 6108.0 61i%.0 . ~,~; i40 6118.0 ~...i 139 6120,0 ~-0 1~' 6124.0 6126-0 - . _ al2a.O 5.0 211 6130.,0 ~ . 0 ~,3 I.~ ~13~..0 _~.:7 i33 6136.0 5,2 i15 _ 6i40.0 6142.0 9.5 ~ - ~ ~ 0 ~.6 ~ .' . 73 95 i51 i47 141 -133 . _ 6!52.0 5.1 . ~I56.0 * 6i58.0 3.-3 * 6!60.9 22.3 22.3 22.3 · 2z-.2 22.! 22.o 22.0 21.9 -2i .7 21,5 21,3 21.3 2i..2 2!.o 2 21,0 2~ o 21-.. 0 20.8 20.7 ~0 7 _ -~ ~ · 20.7 20.6 * 6162.0 ~.9 i42 * 6166.0 ),6 162 * 6170.0 3%.0 221 ~ 617z,0 '3.q iii 297 297 297 297 297 297 299 299 298 299 299 299 3O0 3O2 3O2 3O2 301 297 297 299 3OO 3OO 3OO 301 30~ 3OO 297 295 296 297 297 297 298 299 299 298 . 9.9 9.9 9.6 9.4 9.~ 9.5 9.3 9.2 9.3 9.2 9.4 9°6 9.. 2 9.3 9.5 9.4 9.3 9,3 9,3 9.3 9.2 9.3 9.3 9.3 9.3 9.2 9..3 9.5 9.7 9.3 -,9.2 ---, IhOEX * 4 , =A * 3.5 9.7 2.6 2.6 ~.5 }.4 2.3 ~.2 ~.2 }.6 ~.5 ~.6 ~,.6 1,.6 1,.7 ~.7 1,.5 ~.5 }..6 ~.5 B D F A C A A A A g g F ~,'3 169 i55 :i68 129 i59 -1-42 !49 5212.0 6zi~.u 82!8-0 * 6220'0 * 6222.0 6226,0 . * 623~"0 , 6234,0 _ 6236,0 _ , ,- 6244.0 * 0246.0 . e~48.0 , 6250.0 62i0.0 4.6 -i54 . 126 169 163 161 159 .!59 214 147 i61 20 20.5 ~O.! 20-3 20:2 '20,0 20.0 i9.9 !9,9 ~9,~ 19.8 19.7 _t. 9.7 !9.7 I9,6 19.6 i9.6 t9~5 19-5 19.5 19.4 !9.4 19.3 !9.3 19,2 19.t t9.I i9.0 19.0 2 !9.0 2 18.9 2 18.9 2 * 625~,0 18.9 2 ***************************************** 298 9.3 297 9.2 297 9.1. 297 9.2 297 9.3 297 9.3 303 9.2 321 9.3 326 8.7 311 7.7 302 8.! 299 9.3 299- 9,5 299 9.3 300 9.2 300 9.2 300 9.2 300 9.3 298 9,3 296 9.4 296 9.8 297 9.5 298 9.1 298 9.3 297 9.~ 296 9,3 296 9.3 297 9.4 298 9.6 298 9.5 ~97 9.4 296 9..5 296 9,4 296 9.1 296 9.1 94 9.2 94 9.5 95 9.7 96 9.7 96 9.7 --, 15~DEX , BEST , =g. 11..6 11..7 11..8 I1,.7 11..6 11..6 I0.8 9.8 10.5 1~.5 11,.8 ~.9 11..9 19.g 1~.0 11..9 l~.l 12,4 12.2 1~.2 12.3 1~.4 19.4 12.5 I~.9 13.t 1~,3 ~.5 13.7 13.9 !?.9 297 18.9 297 I8.8 298 iS.8 298 18.7 297 18.7 297 18.7 297 18.7 297 i8.6 297 18.6 296 18,6 297 18-6 297 iS,6 298 18.5 298 !9.5 296 i8,5 294 18.5 298 i8.4 300 t8.4 296 ~ % 295 i~,3 295 ..~..2 296 !8.~ 297 I8.2 297 t8.1 18.1 298 I$.i 299 i7.9 299 i7~ ~97 ~7,7 297 17.7 ~7.6 ~97 17.6 ~9~ !7.5 296 I7.~ 289 9.7 9.7 9.7 9.8 9.8 9.7 9.7 10.2 i0.4 10.7 !0.9 10.~ 10.3 10.3 !0.0 ~0.~ I0.3 !1.3 10.6 9.8 9:7 ~.5 9.i 9,5 9.9 9.8 9,9 10.I I0.n 9.8 i0..6 !0.9 * 6262.0 * 6264.0 ~.-6 200 . 6268.0 O.t 19t -* 6274,0 li.O -164 ~ 6276.0 ~,.2 !46 ~ -6~7~.0 -~ 6280.0 ~ 6284.0 ~,2 188 ~8~ * 6~ o,0 ~ 6288.0 5.;7 97 * 6294,0 * ~6302,0 ~.-~ ._. . a30~.O - ~ 63!6,0 ~.'3 140 . -~3. ~ * 6322,0 * 6326.a -~.;7 123 -~ 6328.0 I}.0 i'i6 * 6330,0 9 ~ a'Q *. 6332,0. ~.' ~ 3~ 14.0 I~..2 I~.3 14.! 14.2 1~.5 !4,7 !5.0 14.8 1.4.8 15.0 1.5.0 14,.9 1~.8 · ~.5. ! 15.2 15.2 15.6 !5.6 J, 5.0 14,9 1~.9 I~,8 !4,7 !4.6 1~.7 1~,7 14,5 14.6 14.3 14,.3 1-~.5 15.1 1.5.5 15.6 * 6336.0 ,. 633S.0 4],4 , 6340,0 ~._I , 634~ o . 6344.0 ~ 6 346. o ~ 634a..o 35~.u .635~ 6356.~,, * 6358.0 6360.0 6362.0 6368,0 *6372.0 63~6.0 ~ 6380.0 ~,:2 * ~ 6384,0 ~ 6386 ~ 5390.0 .. ~ ~3~ ~.a ~.'6 * 6400,0 5.4 4.9 3,6 i95 313 76 3i9 153 AZI, 1-3 !7,3 ~73 ~7,3 287 I7.3 298 17.3 297 t7.2 296 i7.0 296 ~7.0 296 I7.0 296 16.9 296 16,9 296 $6,7 298 16.6 299 !6.6 299 16.5 298 16.4 299 i6.3 300 !6.3 3ol !6.2 300 ~6,2 298 16,2 298 I6,! 299 !5.9 300 15.9 302 15.8 z,~ !5,7 297 15,7 ~9~ ~5.6 ~97 ~ a 297 ~5.6 297 15.5 298 I5,4 292 15.4 299 i5.3 299 i5.3 298 i5.2 298 ~5..! 296 ~5.0 297 !o,1 15.4 10.7 15.7 !1.5 16.2 il.7 16.~ !!.3 !6.7 10,3 1~,.1 9.7 !5.4 9.7 15.3 9.6 15.0 9.5 1~.7 9.5 1~.6 9,5 1~.5 9.5 9.6 14.3 9.7 14.3 9.8 9.8 14,4 9,9 .!4.5 9.8 14,4 9.~-~ 14.5 i0.1 14.5 i0. i 1~,4 !0.0 14.4 1_0.2 1~.2 10.4 14.2 10,3 14.1 10.0 13.9 10.4 !4.0 !0.3 ~3.9 9.9 13.7 !0.0 13.5 9.9 13.1 9.~ 13.8 9.7 13.5 9.5 13.3 9.3 -I~.,0 9.4 ~.7 9.5 1~..6 9.5 11,.7 9.4 I1..7 A . . ~ ~ll!{I¢llIt!lllIllI~ ~ ' ~" ~l~ ~' 0~¥ DEV D~A~~ PI~~ ' * 6426, O ~o9 . a42s.o 5.3 . 8 430-. 0 : 3,:5 -~.. 0 ~ '¢ ~ 6436.0 · -6438,0 2,9 ~ 6440.0 _ . . ~ ~ · 6452.0 !51 i-55 ~57 !55 152 1.72 .tTO i46 !45 i~45 !56 ~0~ b~58 .O 6462,0 6970 o 0,76.0 6478. o 6~.. 2,0 6~8~.0 6486.0 -~.-O 6488.o 8490.0 .. ?,~.~ 332 =4 "~ 148 i59 ~i- ' -i59 * 64~,0 -~.I i34 I3,2 300 9.8 13 ************************************************************** 15.0 297 9.3 1~..7 i4.8 298 9.3 t1..7 i4.7 297 9.3 !!..8 !4,7 297 9.3 !4.6 297 9.3 1.9.9 14,5 297 9.. 3 I 1~, 9 14.5 298 9.4 14,4 298 9,5 14,3 297 9.5 1~.6 I4 ~' 2~ 9.5 1},~ 14.~ 299 9.5 l&,i 299 9.5 !4,! 299 9.6 11',2 i4.0 ~99 9.8 11'~ !3.9 300 1.0.0 !}.6 i3.9 299 9.9 i3.9 300 9,8 l~.2 13,8 300 li).O 1~.9 13.a 300 I0.I 1).3 13,7 299 9.a 13.3 i3.7 299 9.5 i3.2 13.7 300 9.6 l~.O i3-6 300 9.8 !3.7 300 9~9 I3.6 ~99 9.~ 1~.9 13.6 298 9.8 !3..6 298 9..7 !~.9 13,6 2~'~ 9.6 l~.q I3.5 -300 9.7 13.0 13,5 2q9. o.~.. _ 13.1 33.4 298 9,7 !3.0 i3.! 299 9,6 !3.3 299 9,6 I3,3 2-~ 9,8 13.~ 13,2 nO0 9.9 !3.2 t~ ~ 301 9 g 13.2 I3.2 300 9.8 13,3 13.2 300 9,8 !3,2 300 9,8 1~.5 6 _ ~TLA?:::TIC. i~I~CHFI~ILD C6~P~ ...,....= =......................................-.- - --* INDEX DiP ~9~.0 6500,0 6502,~ 6504.0 65_08.0 65tn-0 65~.0 85!6.0 . 65~0,0 ~52 65~0 65~0.0 6532,~ 6534.0 6536.0 6538.9 147 ~7! 123 25O i5~ ~.6 9 ~:7 336 !54 -i54 346 '8O 65~ 654~.0 ~.-~ 6552.0 6556'0 10 '0 79 ~ . !32 i51 !34 3,0 i33 !3.2 13,1 !3.1 !.3,0 12,8 ;I. 2,8 !2,7 12-,7 I~,8 ~2~.7 i2,6 12.6 ~2.5 i2.5 i2.5 !~.4 !2.4 !2.4 12.3 12.3 I~.3 1~_.3 t2,3 12.t t_2,1 , , 300 9.9 J.~.7 301 9.8 13.6 302 9.9 1).3 302 9,9 13,1 300 9,8 J. 3,~ 298 9.9 1.3.5 -300 9,9 ~.~.6 300 9,9 I}..7 300 9,9 ~}.7 30O 9.~ 1),6 301 9..9 1}.4 300 9,9 I~,1 300 9.9 IB.O 300 !0,1 1]..! 300 !0.4 1}.l. 298 !0.0 1).0 297 9.7 !9,~ 298 9.7 1~,6 299 9,8 12,6 300 9,8 12,5 299 9.8 1~.5 300 9.g 1~..3 301 9,8 12.4 300 9.8 !~.4 298 9.~ I~,3 297 ~ 7 1~,~ 297 9,5 ¢~,0 297 9,6 ~,9 297 9,,~ ~.,8 297 9,9 1.~,7 298 9,8 !~,5 ~9¢~ ~-. 7 ~.4 29~ 9,7 ~,4 298 9,7 ~,4 ~9S 9,8 1~'.,4 298 9.8 I~,4 298 9,7 15.4 ~98 9.7 1,9.4 298 9,9 11,.4 298 9.7 1%.4 ********************************* A~.LA;'~TiC RIC~F!~L>O CO~iP.~ 1'Y-!4 PAGE: ~9-FILE 2 - ~584.0 6598,0 6596.0 6598,0 _ 6600,0 66n~ 6604.0 i44. 13_o 134 i15 ~,~7 !57 3.! i55 !._.9 !32 ~76 · _~ ~- ~. '.:7 ~- &61~.0 ~..~ 20! ~ ~6i6.0 l~.g ._.0 --~ 6622.0 6626,0 6632.0 6636.0 6638.0 6640. o 66i2 O 6644.0 6646.0 -6648.n 6650.0 i64' !57 !81 336 154 197 -179 i30 154 ,. 11.9 Ii.9 11.'9 !!.9 i!.8 1i.8 !!.8 !1.7 !.1.7 il .7 1!.6 1t'.6 !!.4 i!.4 -ii.. ~ 1!-3 11.3 ~ 2 ! 11.2 II.2 !!,1 11.0 10,9 i0.9 i0.9 299 9.7 298 299 9.8 299 9,8 299 9.8 298 9,8 298 297 9.8 297 9,6 298 9,6 298 9.7 298 9.7 298 298 298 9.8 298 298 9.8 297 297 9.9 ~97 9.9 297 9.8 297 9..8 298 298 297 9,8 297 9,7 299 9.8 300 9,7 '302 3o2 9.8 301 9.~ 299 9,8 299 9.8 298 9.7 299 9,8 299 9.9 299 299 lO..O 298 9.9 11,.3 11..3 1~.2 !0.9 lO,,g 10..9 1~,0 11,.0 i~.~ I .i.. ~ 11'.1 ~ _i:, 0 ~;t,. 0 1~.7 11,.. 8 11,.a 11,,8 I~.0 12.0 19.1 12.2 INDEX A A A A D A .-. ;.. , - - * 6690,0 * 6694,0 5.2 ~ 6696.~ ~.2 ~ ~ -- ~- n -5.0 , 6702.o . 5708.0 I0.3 57 25~ '27 30O 3 107 97 , 6716,0 }.2 i15 !0,9 I0.8 i0.7 1~ 7 i0,7 ! 0.7 I0.7 !0,7 i0,7 !0.6 !0.6 i0-5 10.5 I0.5 10.5 10,5 !0,3 10,2 10.3 10.~ i0,4 !-0.~ !0, t !.O.i ~.0.1 10.2 10.I 10,! 10.0 9.9 9.9 298 297 '~97 297 297 296 ~97 297 ~97 297 999 29B ~96 299 276 256 247 265 289 294 295 ~95 ~72 ~5~ 253 ~7~ ~73 296 10. 10. 10, t0. !0. 10, 9. 9. 10. I0.. ~0. 10. I0.3 !0.8 11,6 12.0 ll.5 11.3 I~.~ !0.4 9,5 9.9 !0.8 .!0.5 10.2 10,1 10.2 .i0.9 !0.9 10.4 10.4 10.4 !2. 13. 113. 13, 12. 12. 13.. t3, 11,. 13. 1~. ~4. 14. 1~. 1~. --, INOEX , BEST , =A ************ 6738.,.0 6740,0 5.6 i42 6750, 0 6752,0 4.0 99 ~-4 0 ~.~2 -i26 6756.0 ~.~ 56 6764.0 6774,0 9.3 . 6'776.0 3.4 0778-0 3~ ~,-~ _ 6782.0 b/~e~, 6786,0' 5,6 6788,0 ~.2 6790'0 .6,:5 6792.0 ~79~,o 6.2 6796,0 6806.0 9,2 6766,0 . 6768,0 ~. I 249 6 770, t) ;:~;~ ~ a.3 -i5! ~77z.0 i17 i06 45 37 -17~q ~ 68t4,0 }.i !06 9.2 295 i!.3 9.7 998 10.4 13.7 9.7 297 10,6 t3.6 9.,6 299 10.9 13.3 9,6 299 t0,7 9,6 298 10,5 1~..~ 9.5 296 i0,4 '9,5 ~92 10.3 t~o9 9.5 285 10.6 9.,5 284 10.8 13.1 ~,5 276 10.7 1~ 7 9,5 256 10.2 9.4 248 9.9 !1.4 9,4 ~59 !0,6 9,'3 26.7 11.i 13.3 9.4 268 12.3 15.1 9,~ 268 i4,0 1~.5 9.3 ~65 13.8 9,3 247 14,3 i~.3 9.2 233 I4.6 18.5 9-1 256 !2.7 15.5 9,2 269 12,1 15.0 9,2 268 il,6 15.0 9,3 271 10,7 ~.4.5 9,2 269 11.~ 9.2 ~67 11.5 1~.2 9,i 269 !1.2 .12.,7 9, t 268 11.2 9..0 258 !1,4 13,6 9,0 249 11,4 1~.7 9.1 251 .11.4 13.0 9.2 279 11.3 9.3 296 !1,2 12,8 9,2 ~88 1.1,2 9,! 280 !1.,2 13.! 9.1 ~77 11,4 13.1 9,1 271 11.5 12.9 9.2 272 !!'.6 13,4 9.3 288 11.6 1}.9 ~.3 2m .... 13,3 **************************************** . * 6816.0 3 ~ ;~ 0 ~.7 200 * 6830.0 * 6838,0 ~.O !83 * 6840.0 I~.4 231 * 6842.0 , 6844,0 ).~5 5 ~ 6846,0 -6,6 9~ , 6850,0 - ~.~7 !78 - '- , 68-52. o -" 6856,0 ~.0 152 * 686o.o ~.4 !25 ~62,0 .. ~- ~ ., 686~,0 , 6870.0 --~,~7 i24 * 687~ ~' ~. 4 141 ,~ .~ . . 6874.0 ~.':J 63 -- ~.~ o ~.:7 . 6~7~, * ~0.0 , 6882.0 . ~a8a, 0 * 6886.0 9.6 'I00 , 6S8~.0 ~.~ * 6~9~,g _9.'3 73 . 6892.0 5.9 56 '95 9.4 9:4 9.4 9.4 9.4 9.4 9.4 9,4 9.4 9.2 9,2 9.2 9.2 9.I 9.0 8.8 8.7 8.6 296 295 296 297 296 296 297 297 297 299 298 298 297 297 298 298 299 ~00 299 299 299 298 298 299 ~00 299 298 300 ~05 306 309 307 306 tl.5 1t.4 -~I.0 i0.9 !0...9 !0.7 !0,7 t0,6 10.5 1.0,5 10...,5 10:4' ~0.4 !0.3 !0,t 9,6 9,? 9,? 9.5 10,1 10,~. t0.0 1~.2 10.7 10.6 10.7 10.5 10.0 9.9 10.0 10.0 10.0 10.0 9.7 9.5 9.5 9.6 9.4 9.5 9,5 9.5 9.5 9.5 9,5 9.4 9.4 9.4 9.4 9.. 4 9.6 9.9 9.9 9.9 ~ 68~6.0 6.9 253 * 6898-0 . . ~ 6900.0 ~ ~ iOl ~ 6904,0 ~.J !76 , ~L*~, 0 9.5 * 69!0.0 6.3 ~89 2~.~5 2~2 3.5 234 ), ! ~.5 96 79 . 6946.0 5.9 7'i' %4 . -- .~ I "~ ~ 6950.9 -~.-! 6954.0 * 6958.0 5,6 * 6966.0 6970,0 , 6972.0 94 i02 !20 2-05 74 97 131 147 8.7 306 9.a 9. 8,7 297 9,8 9. ~,7 297 9..9 9. 8,7 298 9,9 9. 8,7 999 9,8 9, 8.8 299 9.9 9. 8.8 2-98 9.9 8,9 _301 9.7 9. 8.8 304 9.5 9.. 8.8 307 9.4 9. 8.8 307 9,5 9. 8,8. 306 9,6 8,7 305 9.6 8.7 303 9.7 9. ~.,7 304 9,7 9. 8.-7 300 9.6 8.7 298 9.5 9. 8,7 299 9.6 9. 8.7 300 9.7 9. 8,6 ~99 9,6 9. 8.6 300 9.5 9. 8,5 304 9,4 9. ._ ~ 9. 8.5 30~ c~, ... 8,4 312 9.6 9, 8.3 31i 9.7 9.. 8.2 308 9.7 9. 8~,2 307 9,7 9. 8.i 306 9.7 8,1 305 9..7 9. ~.;1. 303 9.7 ~.2 30I 9.7 9. 8.2 300 9.9 9. 8.3 299 9_,9 8,2 298 9.9 9, 8,2 299 i0,1 9. 8,2 300 10.1 9. 8.2 299 lO.O 9, ~.2 299 ~.9 9. ~ ~97~,0 8.I 3n2 9.9 9. 9 9 9 7 7 7 C 5 5 6 6 5 6 6 6976~0 4.:7 6"" . ~ 7 '*-- ~.0 3.-i 126 · 6984,0 }.! !39 8986.0 2,9 i53 6988.0 ~.0 90 ~ 8 8992.0 ~,1 !36 ~ 7000,0 -~4 .. .0 -g 70!4,0 7020'0 702~.0 3,4 2,9 4 ,!:7 ~ ~7 e' 7026.0 . i,..3 ~- 7028.0 ' 4,_ .'8 96 98 99 84 1i3 99 !!7 5'3 zi 2 8.t 7,9 7.8 7.8 7.8 7e7 7.7 7.7 7~7 7-.7 ~.7 7.7 7.8 7~7 ?.7 ~.? ?.5 7_.5 7.5 7.5 7.5 7.5 7.6 7.6 7:5 7.4 7.4 7.4 304, 306 9. 309 9, 3i4 9. 316 3!5 lO, 313 lO.1 3!0 lO.! 307 304 lO.O 304 303 10.0 303 iO.O 300 ~_ 0.. 0 298 10.0 zg7 lO,n 297 9.~ 298 9:9 300 9,9 303 9.,9 306 310 9,9 3!3 9,9 3!1 9.7 309 9,5 308 9.6 306 9.7 306 9,~ 306 9.7 305 9.5 304 9.4 30! 9.4 299 9.4 299 9.4 302 9,4 -30~ ~ .5 307 9,6 306 9,6 306 9,,6 5 ~ 7v5~.~ 9,;7 113 7.4 306 9. 9.8 9.8 9.9 9.9 9.9 lO.O ~0.0 1.0,0 !0.0 10.0 10.0 lO.1 10..0 lO.1 I0.. 2 9.9 9.8 9.8 9.8 9.6 9.9 9.8 9.6 9.5 9.5 9.6 9.7 9,7 9.5 9.4 9.4 9.4 9.4 9.4 9.5 9.6 9.5 9.5 9.5 D D C C .~, C C ¢ C C L"'~ ~ll I11 i-rtl bT'-] d'~ f;1 ~ 7056.0 7058,0 7060.0 7062,0 · 706' ~' +~ -7066.0 7068.0 7070,0 7072.0 .7074,0 7076,0 i9.2 7078,0 ).'5 7080,0 8,8 140 i67 i68 104 !!4 i01 -96 -i2-7 4,9 3 .;7 7!26-0 7132.0 ~.5 85 .. 77 98 333 99 9! 3~ 40 90 AZI-. 1-3 7.4 7,5 7.5 7.5 7.6 7.5 7.5 7.5 7.4 7.6 7.4. 7.~ 7.4 ?,~ 7.5 7.5 7,5 7.5 7.~ 7.~ 7.3 7.3 7,3 7,3 7,3 7.3 7.3 7.3 7.3 7.3 7~5 7.~ .--.- .... --, INDEX DI~ a BEST 306 9.5 9.5 305 9.4 9.5 g 302 9.4 9.5 301 9,6 9,5 C 302 9.7 9.6 C .304 9,6 9,5 304 9.4. 9 .3 303 9.4 9.3 C 302 9.4 9.4 A 302 9.4 9.4 302 9,4 9.4 C 304 9,4 9,4 A 307 9,4. 9.~ 305 9.6 9.5 303 ~ ~ 9.5 C 303 9.7 q.7 301 9.7 9.8 A 298 9.7 9.,7 A. 298 9.. 8 9.8 299 9.8 9.8 A 301 9,9 9.8 C :303 9..9 9.8 304 9..9 9,8 B 306 9.o9 9,8 308 9..9 9.8 308 9,9 9.9 B 309 9.9 9.9 D 307 9.9 9,9 305 9.9 9.9 305 9,9 9..9 304 10.0 !0.0 P 304 10.0 lO.O O 302 9.9 9.9 299 9.8 9.8 297 9.9 9.@ C 296 9.8 9.8 296 9..~ 9.~ 3!5 9,8 9.7 3!9 9.8 9.7 ~ 7134,0 %.~ -i-a6 7.4 321 o 7 9 ~ ~ L~ Illiil iT:~i[i [:4 I .. , 7136.0 * 7-238, O , 7!40.0 * 7i42.0 , 7144~0 _ 7148,0 7150.0 * 7152,0 * 715~.0 7i. 56.0 -7!58,0 7i62,0 716~,0 7170,0 N,;7 , 7172.0 * 7i76.0 . .7178,0 ~.~5 * 7180,0 *_ 7182,0 7!84,0 718~.C 7!88.0 7190.0 , i~, -71 ~ 7*'nn 0 5;0 *_ ~7202,0_ . -~-~ * ;204.0 ~.-I ~ -7206,0 ~;7 ~ 7210,0 ~,~'* '~ ~ 72!2.0 7,~7 * 72!4,0 9.1 !52 95 57 ~7 ~5 97 82 . 69 7,3 '322 9.7 9.8 7,3 322 9,7 9.8 7-3 390 9,8 9.8 7.3 314 9.8 9.8 7.2 309 9,8 7,2 305 9,8 7.2 304 9,8 9.8 7.2 302 9.9 9.7 7-3 299 9.~ 9.7 7,3 297 9..~ 9,7 7.3 295 9.6 9.7 7,3 294 9.S 9.7 7.3 295 9..7 9,~ -7,3 296 9,7 9.~ 7.3 298 9.6 9.8 7.3 '300 9.8 9.~ 7.3 -301 9.8 9.~ 7,3 304 9.9 9.8 7,2 '307 9.9 9.8 7,2 312 9.9 9.8 7,~ 316 9.9 9.8 7.! 321 9,9 9.8 7.! 32i 9.9 9,8 7,0 3!7 9,8 9,9 7.C 3~2 9.~ 9.9 7,0 308 9.9 7.0 307 9,9 9.9 7.0 305 9,9 9,9 7.0 303 9.9 9.8 7-0 306 9,9 9.8 7.0 298 9.9 7,0 297 9.~ 9 7,0 296 9.9 9.9 7.0 297 9.9 9..9 7,0 298 9.9 9.9 7,0 299 9,9 9,9 7o~ 300 9.9 7,I 302 9.9 7.0 304 9.,9 9.8 7,i 307 9.9 9.~ ********************** DEPTH ~ DiP DiP , DEU. OEU. . _ ~ 72~6,0 ~,~ * 7218,0 7~ * 7228,0 * -7230' 0 * 7232,0 7~ - ~_ _ 7236,0 723~,0 72~0.,0 * 7~46,0 7248.0 * 7250,0 72~~ 0 i03 9 .:7 ~ 79 ~.9 !31 ~.~ 6.3 9 .;7 ~9 7294.0_ . . 6 ********************************** 7~0 -7, O 6.9 6.9 6.8 6.8 6-~ 6.7 6.7 6°7 6.7 6.8 6.8 6.8 6.8 6.8 6.7 6.7 6,5 6.4 6.4 6.4 6.4 .5 .5 310 3!5 318 32t 322 32'2 319 313 309 306 3O5 303 30! 298 297 296 295 296 3OO 302 3O3 308 3~ 3O9 3O6 3O5 304 3O3 301 299 297 9.9 9.9 9.9 9.9 9..9 9.9 9.9 9.9 I0..0 9.9 9.9 9.9 9.9 9.9 10.0 10.0 i0.0 ._~. 0.0 iO.O lO.O !0.0 9,9 9.9 iO.O 9.9 9,,9 9.9 10.0 10.0 9.9 9.~-~ D -----, I~9EX * , 9.8 C .* 9.8 C ~ 9.8 C ~ 9.8 ~ ~ 9.9 ~ ~ 9.9 a · 9,9 C '~ 9.9 C ~ 9.9 C ~ 9.9 * 9.9 C ~ 9.9 .~ ~ 9..9 g, " 9.9 C ~ 9.9 C a 9. g C , 9.9 C ~ O.O A ~ 9.9 * 9.9 C ~ 9.9 A '~ 9.9 A ~ 9.9 C ~ 9.9 A ~ 9.9 O ~ 9.9 8 ~ 9.9 D '~ boo O ~ 9.9 ~ 9.9 ~ 9.9 b ~ 9.9 ~ ~ 9.9 ~. 9..9 6 ~ 9.9 B ~ 7296.~ 7 oo o 7302.0 7304.0 7306,0 7~0~ 73!0,0 73,z,0 -7314,0 ~%~. 7330-0 7332,0 ~7334,0 733~,0 7338.0 7342,0 7344.0 ~346,0 7348'0 7350.0 73~ .0 -7362.0 736S,0 7372.0 85 ~7 '6 6_~6 6.6 6...6 6°6 6,6 6.6 6-,~ 6.5 6~ 5~5 5~6 ~ :7374'0 5.6 305 296 9.7 ~.9 296 9.9 9.7 296 !0.0 la.O 298 I0,0 10.0 299 lO,O 301 I0.0 9,9 303 !O.O 9.9 304 9.9 9.9 3n~ ~ 9 308 !0.o 9.9 3!~ I0.0 9.9 316 i0.0 3i9 I0,0 10.0 32! 10,0 !0,0 321 10,0 322 9,9 9..g 322 9.9 9.9 3!8 9,9 9.9 3i2 9.9 9.9 306 9,9 9.9 303 9.9 9.9 301 9..9 9.8 300 9,9 9.8 299 9,9 9.8 295 9.9 9.8 286 9,9 9.8 276 8,6 269 5,4 5.4 275 3,7 3.7 274 3,7 ~.7 263 3..7 3.7 25i 3.7 9.7 236 3,7 3,7 234 3.7 3.7 244 3,7 3.7 253 .3,7 3.7 279 3,7 3.7 303 3,7 3.7 305 3.7 3.7 3.7 3.7 7~7& a -5.6 305 37~.v 5.6 305 73~0.0 5.6 3{35 _ ~3~z. ~.~ 5.6 304 7384.0 5.6 304 7386,0 5,6 303 7390.0 5.7 ]04 7392.0 5.8 304 3. . · , 3:7 3.7 3,7 3.7 3,7 3.7 ~.7 ).7 3.7 3.7 ~.7 3.7 ).7 3,7 ).7 7 ~.7 7i30.0 -7i32,0 7!34,0 7139.- 71~a,O .7140,0 7i42,0 7~46.0 7152,0 7154,0 7!56.0 _~ . 7162, -~ 7!64,0 7166.0 ~170.~ 7i72.0 7178.0 7180.0 7i86,0 7190. o: 7192.0 7 ~:~ 84 97 ~3 !'o2 i_2-0 86 97 %,6 ~ .:7 % .:7 56 125 7,3 7,3 7,3 7,3 7,2 7.2 7.2 7.! 7,1 7,1 7,2 7.2 7.2 7, '_2 7.2 7.2 · 7,2 7.2 7.0 7.,0 7:O 7.0 7,0 7:0 7.0 7:O 7,0 6.9 298 '30! 304 307 312 3!3 311 309 306 304 301 296 296 296 299 301 3!2 313 312 309 306 304 302 ~97 296 296 296 3O0 304 3!~ 3~9 316 9.8 9'8 ~ 9.8 9.8 ~ 9..8 9.8 a 9.9 9.8 n 9,8 9,8 ~ 9_.8 9,8 A 9.$ 9.8 ~ 9.8 9,8 C 9.8 9.~ C 9.8 9.8 C 9,8 9.8 a 9.8 9.8 A 9.8 9.8 A 9,8 9.8 g,8 9.8 9,8 9.8 9,8 9..a. 9.8 9.8 9.9 9,8 9.9 9,8 9.9 9.8 9,9 9.9 9.9 9.9 9,9 9.9 A 9,9 9.9 A 9,9 9.9 A 9,9 9.9 A 9,9 9.9 C !O,O 9.9 ~ 10,0 9.9 ~. 9,9 9.9 A 9,9 9.9 A 9,9 g.9 C 9.9 9,9 C 10.o0 9.9 10,0 9.9 C !.o.n 9.9 C 10.0 9.9 C 9,9 9.9 C 9.9 9.9 C I T~;d" r-~ 72!2.0 3.9 -7216-0 7220,0 722~.0 ~ 2 7226.0 ~,3 _-722~.0 7280.0 7~'~ 0 728~,0 _ - ~ I~7 70 67 79 6.8 6.8 6.9 6,.9 6.7 6.7 6.6 6.5 6.5 6.6 ~7 6.7 6.5 6.5 3!0 ~.3 -- 3O4 -302 3OO 297 3~J5 3O7 3O5 2~5 30! ! t ! ! I 1 I 1 9.9 9,9 9,,9 'J. 0 ~, C !0.0 9.9 9,9 9..9 9.9 10,0 !0.0 !O..O iO.O 10.0 .!.0.0 O,, 0 0.0 0.0 0.0 0,0 0.0 9.9 0.0 i20 i94 6'4 298 6_.4 296 6.5 295 6,5 296 6.~ 297 ,1. 6,5 299 i 6.5 30t 6,,5 304 6,5 309 6.5 3i3 6.4 312 6.3 310 O,O 0,0 lO.O 0o0 I0.0 0.0 0.0 0.t 10,0 0o! J.O.O 0.1 IO.O 0.0 9.9 0,0 9.9 0,0 lO.O D ~ D ~ 7311,0 -7316,0 7318.0 7320.0 732~.0 7324-0 32o.0 ~2 ~5 'i 22 7~=.0 - _ 7330,0 -~332,0 7334,0 7336,0 -- . . 733~.0 734~,0 7342.0 7. 3~4- O 7346.0 7348*0 73~:3. (~ 7~52.0 ....... _ 7360.0 ~ 736~.0 9,6 79 * 7~68.0 3~,I i28 ~ 3 307 6,3 304 6.3 303 6,3 303 6,3 301 6,3 300 6,3 ~99 6.3 297 6.3 296 6,3 296 6.3 297 6,2 298 6.2 300 ~,! 30! 6,! 304 6.i -307 6.1 312 6,0 316 6.0 :318 5,9 3!~ 5.9 3~.4 5,<~ 309 5,9 305 5.8 303 5:7 301 5,7 299 ~ 7 2c~7 5.6 296 10..0 1o.o i0.0 10.0 10,1 9.9 I0.0 9.9 !0,o !0..0 ~.o.n 9.9 10,6 9,9 i0.0 I0..0 i.o.a !O.C 9.9 10,0 9.7 9,9 9.7 9,9 9,9 9.9 9.9 9.9 9.9 9,9 9.9 9.8 9.9 9.8 9.8 9.g 9.7 9.8 9.8 9,8 9.8 9,8 9.9 9.~ 9.8 9.9 9.8 9..9 9.9 9.5 9.3 8.0 ~.9 ~7372,~ 7374,0 7376,0 7378.0 7~80.0 7382,c3 : 5.7 296 6.6 6.6 5.7 297 6.5 6.5 5.7 ~-97 6.5 6,5 5.7 297 6.5 6.5 5.6 297 5.6 296 5.6 2-96 6,3 6.3 5.2 6.3 304. 3.7 3.7 * ~ -~ ~OTTOM * 7382.0 43.2 234, 5.6 296. 6.3 6.3 * 0.0© 0.00 0,00 0.00 BUFFERED I/O 2.00 0.00 0.00 0.00 0.00 0. O0 0. cji.-..,. 0. O0 0. O0 0. O0 . 0.,00 O.OC O.Or.: O. O0 0.00 o.O" .0 O0 ,,,,,,. 0 c, 0.00 0.00 ~ -kj _. ~ -- ~' ' ,~.00 0 . O0 0,,00 0.00 0,00 0.00 0.0~, 0.00 0.00 0. O0 [,,,IS TAPE VEJRIF'ICATIF]M LISTING VP OlO.H02 VERIFtCATIOi~ LI~TI~G PaGE * REEL HEADER ** ERVICE NAME :$ER¥IC ATE :83/02/28 RIGIN : EEL N A ~E : :ONTINUATION ~ 101 'REVIOUS RF, EL :OMMENTS :LIBRARY TAPE :* TAPE HEADER ** iERVICE NA~E :$ERVIC ~ATE :B3/02/2~ ~RIGI~.I :0000 'APE NA~E :8020 :ONTINUATION # :01 'R E',V I OIJ,S TAPE : ~Oi~Eb~TS :LIBRARY TAPE EOF :* FIt, E HEADER ** 'ILE NA[qE :SERVIC,001 ;ERVICE ~'~ A M F'. rERMION :# )ATE : AXl~'lJ~ DENGTi4 : 1024 iLE TYPE ~REVIOUS FILE ~* IiNFORMATION RECORDS aNEM CONTE~TS 2N : ARCO ALASKA 4N : 1Y-,t 4 ~N : KUPARUK ~ANG: 9E ~gCT: 1. CON: N, $1:,OPE ~TAT~ ALASKA 2TRY: USA 000 000 Ol .~ 065 0 O0 00 o 006 065 000 000 O 0 B 065 000 000 002 065 000 000 004: 06 5 000 000 002 065 000 000 008 065 000 000 (306 065 00 0 0:00 t} 0 ~ 0 6 b AbA,RA CO~',PIITING CEN'IER * ****************************************************************************** 'OMPA~,~ = ATbAt, TIC RICHFIELD ELL : 1Y-14 'IELD m KUPARUK ;TALE : NLI~!BER AT ACC: 68020 DATE LOGGED: ~A$ING ~YPE FLU I!.) ~T SIZE ~ISCO$IT¥ 'LUID ][,,[]SS = I0 3/4" SURFACE TO 2436' = 3% KCI., DL~!'~D = 8.5" = 10.4 I.,BtG R~ r., 40,0 5 R~IF = 7,8 R .i~, C : 5,5 C3 R~ AT 1.160 18 66.0 13F 0,846 ~ 66,0 DF 1.530 8 66.0 DF 0,557 ~ 145,0 DF DATA FORMAT RECORD ** ~NTRY BI.,OCKS TYPE SIZE ' REPR CODE ENTRY 4 I 66 1 VP OlO.H02 VE:R],FIC~TIOP4 I,IST[N(; PAGE 3 ~ATLI~i SPE¢IF]'CATI. ON BLOCKS iNE~ SERVICE SERV'ICE l.l) ORDEi~ # '73 05 66 API APl AP1 API F.tLE t, OG TYPE CLASS MUD NO, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 8 3 0 0 0 31 32 (.) 0 60 52 32 O 0 60 31 32 0 0 42 6.8 2 0 0 · 42 44 0 0 0 42 35 ! 0 0 42 34 92 0 0 42 34 93 0 0 42 28 3' 0 0 42 31 32 0 0 42 42 1 0 0 42 0 0 0 0 ,lin 6 0 ,$IZ[~. PROCE LFVE 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 , 4 0 4 0 L SA~iPLE 1 1 ! 1 1 ! 1 1 1 1 ! REPR CODE 68 68 68 68 68 68 68 68 68 68 68 b8 68 68 68 68 DATA )EPT 7195.0000 MSFL 2A[.I -999,2500 GR ~PHI 46,7285 DRMO ~CNL 122.6875 CALl {NRA 4.0039 ),EP% 710'0,0000 MSFL 2ALI 8.0625 GR qPHI 31,2500 DRHO ?CNL 566,0000 CALI ;~N~A 3 · 084:0 )EPT 70:00,0000 MSFL 2AI.,I 8,3594 GR ~PHI 31,6406 [DR}{{] F~,NL 547,000o C"'AL.i' RNR,A 3,0742 ,)EPT 6900. 0000 ~SF'L CALl 8,1953 I 1,7,6 58 RI=JO FpT AL1 N p fi I ~800,0000 MSFb 9.5859 GR 48,2910 DRHCi :~9,2500 LbS[ 9,250 0 D" - 235 R,HOB I~,6250 BLS 9 ,3750 DT 0,0361 ~H'O~ 8.7656 GR 5,7383 LbS H~'2500 DT ,0'566 RHOB ,7813 GR 19 72 453 81:43 5000 0542: LbS I.) T HO:~ ,bLS R H 0 B '999,2500 bbD 93 ,7 500 GR ?., 3945 NCNB 4 . 0000 RA[ B, 0 756 b L D S9; 3750 GR 2,4688 (,Nh 1.01,1875 ~,~RAT' 1, [,~LD 5 GR ! .7829 LbD 1 .1875 (';R 2,1719 NCNB '999,2500 45.0000 491,5000 3,6602 7,~157 101, 875 174~,0000 ',8437 5,82:8:7: 9'7,8750 168~, 0000 .8730 14,9779 71,8750 190~.0000 ,'9i41 11} ,8370 ,B125 1059.0000 ' ~.'- .... u.., ,, h/ ' . . :,., VP O10,H02 VE~IFI¢~Tltt~4 i~ISTI~G P~GE 4 'CNL 242,62~0 CAI,I ,NRA 4.3~33 ,EPT 6700.0000 IAL1 1.0,6172 GR ~PHI 43,1152 'CNL., 249.7500 CALl ~NRA 3.9668 )EPT 6600 :AL! 9 iPHI -999 'CNL -999 tNRA -999 )EPT ~500. :AL1 11 iPHI -999: ~CNL -999. INRA -999. )EPT 6400 ]ALI 10 CPHI -999 rCNL -999 ~NRA -999 )EPT b300 " I =Ab 1 2 ~l p H I - 999 ~'CN 1.. -999 ~NRA -999 )EPT 22()0, 2ALI 10, ~PNI 999. ~CNL -999, RNBA -999. 2ALI 10 NPHI 999 FCNL -999 RNRA -999 D E P T 600 (3 CAbI i2 NPHI -999 FCNL -999 RNRA -999 0000 ~$FL 3047 GR 2500 DRHfJ 2500 CALl 2500 0000 MSFL, 14,84 GR 2500 ~!~Ht') 2500 ALI 2500 0000 6328 GR 2500 2500 CALI 25o0 0000 82359 500 2500 250 u 0000 l~,i $ F I'.., 1953 G~ 25(!o CA[,Z 2500 000 {'~ 8 F ,b 172 GR 500 D R H 0 500 C A I,,, I 50O CAI, I 11 11.88 GR NPHI -999 ~500 .DRHO 1.1,4531 GR 0.6719 LbS 126.31.25 DT 0.0137 RHOD 13,6563 GR 4,5268 308.2500 PT '999.2500 9,7891 GR 1.5895 I.*LS 160,7500 DT -999.2500 1~.5469 2i9056 130 ()000 D -999 250() 11,~094. 3,7012 l,,hS 10 7500 3I' -99 ' 250{3 RHt]P, · 13,7188 GR 3,9720 LL, S ' 143,5000 DT -999.2500 RHOB 10,6250 GR 4.698 b I,, L, S 144,8750 [)T -999 · 2500 RH01% 11,4375 4,2246 I,~,bS 138,6250 DT -999.250C) RHOB 1e,8125 GR ' %t c 2 , 80,) 167,0000 -999,2500 119,81.25 .aRAT 1,821.9 DLD 119,1875 GR 2,1074 kCNt., 116.5000 NRAT 3.5099 I,L!) 105.3750 GR -999.250() NCNb 295.2500 NRAT 3,0554 l.,bD 125,0000 GR -999,2500 NCNL 163.6250 NRAT 3,3729 LLD 107,1875 GR -999,2500 NCNL 121,3125 NRAT 3.59 02 b L D 101 , 1.875 GR -999,2500 l~lCN L I 11,2500 NRAT 2,7682 10~,3750 GR -99 ,2500 NCNL I:40,6250 NRAT 3,37'18 LbD :110,~000 (;R '999. 500 130.6250 NRAT 2,8039 LLD 109.0000 GR '999.2500 ~CNI.~ 3,9668 1,8693 116 5000 991:0000 3.7383 3.3577 295.2500 -999.2500 '999,2400 2,8639 163.6250 -999,2500 -999,2400 3.2790 121,3125 -999.2500 -999.2400 4,1158 11 l 2500 999,2400 2 6575 -999 25 ' -999 2400 3,9539 148, 250 -999,2500 "999,2400 3,8603 130 ~, 6250 -999,2500 -999,2400 2,6254 99. 2500 -999,2500 (; P T 58 00 tI.,I I I :~FII -999 ]NL -99~ 5 700 11 -999 -999 - 999 i; P T ~ [, I ~N L! ~LI PHI 6 P T ~L,I 25 00 2500 25O0 0000 MSF'I.., 3281 GH 2 b 00 U FI H 2500 C. 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