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Home My WebLink About198-251MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-323 KUPARUK RIV U TARN 2L-323 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2L-323 50-103-20282-00-00 198-251-0 W SPT 5236 1982510 3000 1620 1620 1620 1620 200 250 250 250 REQVAR P Josh Hunt 8/6/2024 2-Year MIT-IA Required by AIO 16.005 Required test pressure to pass is the max anticipated injection pressure of 3000 psi. 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 U TARN 2L-323 Inspection Date: Tubing OA Packer Depth 380 3340 3265 3260IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806165531 BBL Pumped:2.3 BBL Returned:1.7 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 99 9 9 99 999 9 9 92-Year MIT-IA AIO 16.005 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:30:10 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.07.03 11:18:45-08'00' Foxit PDF Editor Version: 12.1.2 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)KRUWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in gal1A-24 5002922984-0000 200-181 N/APost Conductor Ext21.5" 3/7/2022 12.7 7/2/20232L-323 5010320282-0000 198-251 N/APost Conductor Ext11" 7/31/2022 3.4 7/2/20232N-310 5010320549-0000 207-090 12' 2.3 7" 5/31/2023 4.25 7/2/20232N-322 5010320678-0000 213-179 9' 10" 1.1 6" 5/31/2023 2.1 7/2/20233G-08 5010320128-0000 190-065 10' 2" 1.0 5" 5/31/2023 1 7/2/2023Date 07/03/20231A, 2L, 2N, & 3G Pads2L-3235010320282-0000198-251N/A11"7/31/20223.47/2/2023Post Conductor Ext MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-323 KUPARUK RIV U TARN 2L-323 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-323 50-103-20282-00-00 198-251-0 W SPT 5236 1982510 3000 1700 1700 1700 1700 260 480 450 450 REQVAR P Austin McLeod 8/3/2022 Two year MITIA to MAIP. AIO 16.005. 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 U TARN 2L-323 Inspection Date: Tubing OA Packer Depth 340 3300 3255 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804185722 BBL Pumped:1.8 BBL Returned:1.8 Friday, September 2, 2022 Page 1 of 1 9 9 99 9 9 9 9999 Two year MITIA AIO 16.005. James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:36:14 -08'00' By Anne Prysunka at 3:37 pm, Aug 02, 2022 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2SHUDWRU1DPH&XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ"<HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU)LHOG3RROV 7RWDO'HSWK0'IW7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH &RQGXFWRU 6XUIDFH 3URGXFWLRQ 3DFNHUVDQG66697\SH3DFNHUVDQG66690'IWDQG79'IW $WWDFKPHQWV3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV2,/ :,1- :'63/6XVSHQGHG 9HUEDO$SSURYDO'DWH *$6 :$* *6725 63/8* $2*&&5HSUHVHQWDWLYH*,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH $XWKRUL]HG7LWOH &RQGLWLRQVRIDSSURYDO1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\%237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ 1$ /HQJWK 6L]H / 79'%XUVW 0' 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ 32%R[$QFKRUDJH$. &RQRFR3KLOOLSV$ODVND,QF .83$58.5,987$51/ .83$58.5,9(57$512,/ 2WKHU&RQGXFWRU([W 1$ 7XELQJ*UDGH7XELQJ0'IW3HUIRUDWLRQ'HSWK79'IW7XELQJ6L]H 3DFNHU%DNHU6HDO$VVHPEO\ 6669&DPFR'61LSSOH 3DFNHU 0' 79' 6669 0' 79' 3HUIRUDWLRQ'HSWK0'IW ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< %UHQQHQ*UHHQ5RJHU0RXVHU 1#FRQRFRSKLOOLSVFRP :HOO,QWHJULW\)LHOG6XSHUYLVRU W )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 9:03 am, Jul 05, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ 97/ '65 ; '/% ; 3KRWR GRFXPHQW DOO VWHSV GWV Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.07.18 09:05:03 -08'00' 5%'06 -6% 32%2; $1&+25$*($/$6.$ -XO\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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Supervisor ' / FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 12, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2L-323 KUPARUK RIV U TARN 2L-323 Sre: Inspector Reviewed By: %2ComP.I. Supry 3,6111— Comm m Well Name KUPARUK RIV U TARN 2L-323 API Well Number 50-103-20282-00-00 Inspector Name: Lou Laubenstein Permit Number: 198-251-0 Inspection Date: 8/3/2020 Insp Num: mitLOL200804122412 Rel Insp Num: Packer Depth Well 21--323 . Type Inj w ' TVD X236 Tubing PTD j 1982510 Type Test SPT Test psi 3000 IA BBL Pumped: 2.3 BBL Returned: 2.1 OA Interval REQVAR WF P Notes: MIT -IA to Maximum anticipated injection pressure per AIO 16.005 Pretest Initial 15 Min 30 Min 45 Min 60 Min 1800 1800 - 1800 - 1800 - 50 3320 3280 3280 ' 250 450 - 450 450 Wednesday, August 12, 2020 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,January 20,2017 TO: Jim Regg P.I.Supervisor ', r ( zO(t 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-323 FROM: Brian Bixby KUPARUK RIV U TARN 2L-323 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 5-,6,z---- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-323 API Well Number 50-103-20282-00-00 Inspector Name: Brian Bixby Permit Number: 198-251-0 Inspection Date: 1/17/2017 Insp Num: mitBDB170117163727 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2L-323 - Type Inj - W -TVD i 5236 � Tubing, 1800 1800 " � 1800 - 1800 PTD 1982510 - Type Test SPT Test psi 3000 IA 1040 3300 3270 3270 - BBL 1.2 Pumped: p BBL Returned: 12 - OA 290 400 - 400 400 " Interval REQVAR P/F P Notes: This well was tested to the maximum anticipated injection pressure as stated on the AIO 16.005 NNED APR 0 6 2(317 Friday,January 20,2017 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, August 31, 2015 9:46 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Status update Tarn injector 2L-323 (PTD 198-251) Attachments: MIT KRU 2L-323 Diagnostic non witnessed 02-01-15.xls Chris, SCANNED SF' 0 3 2015 2L-323 was brought on gas injection on 08/22/15 to begin the 30 injection test on gas. The SSV failed the test when brought on injection and needs to be replaced. The well was SI on 08/27/15 and has been WAG'd to water for a minimum of one week and the SSV can be replaced. It is ConocoPhillips intention to return the well to gas injection for the remaining 25 days of the test period once the SSV has been replaced. Attached is a 90 day TIO plot for reference. In the 5 days the well was on gas, there were no signs of communication so we would like to finish the test to confirm over a longer period. Please let me know if you disagree with this plan. CHOKE - FTP FTT IAP T/I/O Plot - 2L-323 OAP 3500 3000 2500 —_ � I;`4 0 2000 - = i 1500 { 1000 — __ _ 500 0 $ + l l i + ► t i t + l lit Ili II I 01-Jun-15 14-Jun-15 27-Jun-15 10-Jul-15 23-Jul-15 05-Aug-15 18-Aug-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, February 21, 2015 6:28 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report Tarn injector 2L-323 (PTD 198-251) 1-31-15 Attachments: 2L-323 90 day TIO 2-21-15.JPG; MIT KRU 2L-323 Diagnostic non witnessed 02-01-15.xls Chris, 2L-323 was shut in on 1/30/15 after having been on gas injection since 12-18-14. Diagnostics with DHD were completed on 2/1/15. MITIA, IA DDT and tubing packoff tests all passed. The well has been on water injection since 2/4/15. We had intended to WAG the well back to gas injection shortly after that as proposed in the initial report. However sim-ops issues with a rig nearby have prevented the WAG. When the rig is off diverts,the WAG to gas will proceed, at which point the 30 day monitor on gas will begin. It is estimated to occur sometime later next week. woe) Well Name 2L-323 Notes: Start Date 11/23/2014 Days 90 End Date 2/2112015 Annular Communication Surveillance 4000 - — 180 _MP 1AP 3500 OAP — 160 01114411r — 140 3000 — 120 2500 — 104 on 2000 O. — 80 1500 — 60 1000 .✓� ._ ._ J — 40 500 — 20 0 0 Nov-14 No.-14 Cec-14 Dec-14 Cec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Mar-15 60:C 5030 rCCC — •n. m 1070— 5f• xcc. 1000 111•0.1\ C. Nov-14 Nor-14 Dec-14 Jan-15 Jan-15 Feb-15 Mar-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Saturday, January 31, 2015 9:15 AM 2 • To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report Tarn injector 2L-323 (PTD 198-251) 1-31-15 Chris, Tarn WAG injector 2L-323 (PTD 198-251) is displaying a rising IA pressure with two bleeds performed in the last 2 weeks, the most recent bleed occurring yesterday. There had been an increase in injection temperature so the pressure increase was initially believed to be thermally induced. 2L-323 has been on gas injection since 12-18-14 and we plan to keep the well on gas injection during the initial diagnostic phase; (with the caveat that there may be some brief WAG'ing to address a failed surface safety valve). Initial diagnostics with DHD will include MITIA/DDT/packoff testing. A 30 day monitor on gas will then be conducted. If the well continues to display the IA pressure rise while on gas injection,the well will be WAG'ed to water and monitored for an additional 30 days, in anticipation of an AA submittal. If the well fails the MIT,the well will be shut in and freeze protected as soon as possible. A follow-up email will be provided at the conclusion of the diagnostic monitoring. Please let us know if you disagree with the plan. Attached are the schematic and 90 day TIO plot. « File: 2L-323 schematic.pdf» « File: 2L-323 90 day TIO 1-31-15.JPG » Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 3 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday,January 31, 2015 9:15 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report Tarn injector 2L-323 (PTD 198-251) 1-31-15 Attachments: 2L-323 schematic.pdf; 2L-323 90 day TIO 1-31-15.JPG Chris, Tarn WAG injector 2L-323 (PTD 198-251) is displaying a rising IA pressure with two bleeds performed in the last 2 weeks, the most recent bleed occurring yesterday. There had been an increase in injection temperature so the pressure increase was initially believed to be thermally induced. 2L-323 has been on gas injection since 12-18-14 and we plan to keep the well on gas injection during the initial diagnostic phase; (with the caveat that there may be some brief WAG'ing to address a failed surface safety valve). Initial diagnostics with DHD will include MITIA/DDT/packoff testing. A 30 day monitor on gas will then be conducted. If the well continues to display the IA pressure rise while on gas injection,the well will be WAG'ed to water and monitored for an additional 30 days, in anticipation of an AA submittal. If the well fails the MIT,the well will be shut in and freeze protected as soon as possible. A follow-up email will be provided at the conclusion of the diagnostic monitoring. Please let us know if you disagree with the plan. Attached are the schematic and 90 day TIO plot. ,i • • • Well Name 2L-323 Notes: Start Date 11/2/2014 Days 90 End Date 1/31/2015 Annular Communication Surveillance 4000 — 180 INN 3E00 — 160 — 140 3000 — 120 2E00 — 1 o O 2000 f — 80 1E00 r — 60 1000 — 40 E00 / — 20 a o Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-1E 5047 5000 va FJ o_ . Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 2 KUP 2L-323 Conor Phillips a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(I MD(MB) Act 1312n(ftKB) t.WrnPlalhps __501032028200 TARN PARTICIPATING AREA INJ 67.81 8,796.46 10400.0 Comment H2S(ppm) Dab Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Confq:-2L-323,7/18/2012 2'.20:16 PM SSSV:NIPPLE Last WO: L 36.59 12/26/1998 Schematic-Actual Annotation Depth(ftKB) End Date Annotatlon Last Mod...End Date Last Tag:SLM 9,687.0 8/13/2011 Rev Reason:WELL REVIEW osborl 7/18/2012 - Casing Strings Casing Description String 0... String ID...Top(ftKB) Sat Depth(f...Set Depth(TVD)...String Wt...'String...String Top Thrd CONDUCTOR 16 15.062 28.0 108.0 108.0 62.58 H-40 WELDED HANGER,25 Casing Descriptlon 'String 0... 'String ID...Top(NKB) Set Depth(f...Set Depth(TVD)...String Wt..String•••String Top Thrd SURFACE 75/8 6.875 28.5 2,602.0 2,288.6 29.70 L-80 BTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 51/2 4.950 25.2 10,395.2 5,770.9 15.50 L-80 EUE-8RD 5.553.5"@ 9470' Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth It...Set Depth(TVD)...String WI...String...String Top Thrd jp TUBING 31/2 2.992 25.0 9,463.3 5,245.9 9.30 L-80 EUE-8rd Completion Details Top Depth (TVD) Top Incl Nand- Top(SI(B) ((*(8) r) Item Deesriptlon Comment 12221; D nn) 25.0 25.0 0.56 HANGER FMC GEN V TUBING HANGER 3.500 CONDUCTOR, 518.0 518.0 0.21 NIPPLE CAMCO DS NIPPLE 2.875 28-708 9,338.6 5,174.4 56.52 SLEEVE BAKER CMU SLIDING SLEEVE(CLOSED 2/26/1999) 2.81 NIPPLE.518 tr 9,439.4 5,231.8 54.06 NIPPLE CAMCO D NIPPLE 2.750 9,446.3 5,235.8 53.89 LOCATOR BAKER LOCATOR 80-40 -2.985 9,447.8 5,236.7 53.85 SEALS BAKER SEAL ASSEMBLY w/15'STROKE 2.900 Perforations&Slots Shot Top(ND) Bbn(TVD) Dens Top(ftKB)Ban(SKB) (SKBI (ftKB) Zone Date (eh... Type Comment 9,670.0 9,706.0 5,367.8 5,388.8 S-5,2L-323 2/25/1999 6.0 IPERF 60 deg phase deep penetrating;2.5"HC 9,746.0 9,774.0- 5,412.0 5,428.OS-3,2L-323 2/25/1999 6.0 IPERF 60 deg phase deep penetrating;2.5"HC SURFACE,__ - 9,796.0 9,928.0 5,440.6 5,515.5 T-2,2L-323 225/1999 6.0(PERF 60 deg phase deep 2S'2,80z penetrating:2.5"HC Notes:General&Safety End Date Annotation 11/9/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT. 4,423 SLEEVE,9.339 0 GAS LIFT, 9,387 al I NIPPLE,9.439 LOCATOR ii�� 9.446 SEALS.9448 ' I IPERF.__ - 9,670.9,706 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run 9.]48-9.]]d IPERF. - Stn Top 181(8) (ftKB) (°) Make Mods! (In) eery Type Type (in) (psi) Run Date Com... 1 4,422.9 3,077.767.87 CAMCO KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 12/27/1998 2 9,386.8 5,201.4'55.34 CAMCO KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 12/27/1998 9.]96-9.928 PRODUCTION 5.5.03.5'5 0470•. 25-10,395 , . TO,10,400 MEMORANDUM TO: Jim Regg ~ l ~j'~ ~~ ~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-323 KUPARUK RIV U TARN 2L-323 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~- Comm Well Name: KUPARUK RIV U TARN 2L-323 Insp Num: mitRCN100809170038 Rel Insp Num: API Well Number: 50-103-20282-00-00 Permit Number: 198-251-0 Inspector Name: Bob Noble Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We^ ' 2L-323 -Type Inj. ~' ~ TVD 5236 - IA ~ 800 2800 ' 2750 2740 ' P.T.D I9a2slo ~ TypeTest sPT 1Test psi 2soo - pA aoo szs soo soo Interval aYRTST _ p~ P ~ Tubing zloo ztoo 2100 2l00 . Notes: ~ ~ ,~ ~ ~-~ g ~C~ -~S~ i ~~ci ~; Tuesday, August 10, 2010 Page 1 of 1 i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2L 08/08/10 Colee /Coleman - AES Robert Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 2L-305 Type Inj. G TVD 5,244' Tubing 3,740 3,740 3,740 3,740 Interval 4 P.T.D. 1982400 Type test P Test psi 1500 Casing 2,390 3,230 3,200 3,200 P/F P Notes: OA 325 340 330 330 Well 2L-317A Type Inj. W TVD 5,350' Tubing 1,100 1,100 1,100 1,100 Interval 4 P.T.D. 2002100 Type test P Test psi 1500 Casing 850 1,830 1,780 1,770 P/F P Notes: OA 250 375 375 375 Well 2L-319 Type Inj. W TVD 5,225' Tubin 1,300 1,300 1,300 1,300 Interval 4 P.T.D. 2071120 Type test P Test psi 1500 Casing 230 2,150 2,080 2,060 P/F P Notes: ~ OA 361 482 458 457 Well 2L-323 Type Inj. W TVD 5,237' Tubing 2,100 2,100 2,100 2,100 Interval 4 P.T.D. 1982510 Type test P Test psi 1500 Casing 800 2,800 2,750 2,740 P/F P Notes: OA 400 525 500 500 Well 2L-329A Type Inj. N TVD 4,899' Tubing 1,500 1,500 1,500 150 Interval 4 P.T.D. 1982250 Type test P Test psi 1500 Casing 520 2,270 2,200 2,200 P/F P Notes: OA 900 900 900 900 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~gI ~V~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2L Pad 08-08-10.x1s . . Conoc6Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 G\ \fA.~/r sCANNED SEP 0 6 2007 Dear Mr. Maunder: 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 còiidiiêtor. These voids were filled with a corrosion inhibitor, engineered to prevent water :trom 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 corrosion inhibitor/sealant was pumped between August 12-13,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. 4~~¿ M.J. Eoveland ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/13/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2l-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A N/A N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 03/20/07 Schlumberger oiJ-/ NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Clomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Cy ~I t,' t'iAR '.ì. i1')'" ull GOInï4rANNEO APR 03 2007 Field: Kuparuk ) Ie... ¡O,8" -()S ( Well Job# Log Description Date BL Color CD 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1 E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1 E-117 11626471 INJECTION PROFILE 03/14/07 1 1 Q-09 11638839 INJECTION PROFILE 03/16/07 1 3S-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1 C-1 0 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 10-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i6~' . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,,.--., .-' "'\" , i-- /. . . , (..;,11 ti"J~ (..I¡'-" ¡:'t-Cjf ¿; ''', - l DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-323 KUPARUK RIV U TARN 2L-323 \,,'(S~J..t;1 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: -f::>þ _ P.I. Suprv ~Jb~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2L-323 API Well Number 50-103-20282-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808193730 Permit Number: 198-251-0 Inspection Date: 8/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2L- 323 !" . : TVD I I I Well [ ,Type InJ. ! G I 5237 I IA 1800 i 2980 [ 2970 I 2970 : -~._- I I --~---~----~----.!-- P.T. [ 1982510 ¡TypeTest i SPT ¡Test ~ 1500 [ OA I 350 I 400 I 400 I 400 , , I I I I --..- Interval 4YRTST P/F P / Tubing I 2920 2920 i 2920 [ 2920 ./ , I , .-. Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED AUG 2 4 2006 Wednesday, August 09, 2006 Page I of I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2L-323 07/02/05 Arend 1 Rogers AES ,,¿;.\ (}..-, r \0.... '\J Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depth Pretest Initial 15 Min. 30 Min. Well 2L-323 Type Inj. G TVD 5,237' Tubing 3300 3300 3300 3300 Interval 0 P.T.D. 1982510 Type test P T est psi 1500 Casing 1900 3000 2950 2950 P/F P Notes: Diagnostic MIT Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Test Details: SCANNED ..!UL 0 7 2.005 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 T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 2L-323 07-02-05.xls Casing Detail 7.625" Surface Casing 11~-d51 ARca Alaska, Inc. WELL: TARN 2L-323 DATE: 12/18/98 1 OF 1 PAGES Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.50' TOPS Above RKB 75/811 Landing Joint 28.50 FMC GEN V- Prudhoe 7 5/811 Csg Hgr 2.71 28.50 jts. 39-61 75/811,29.7#, L-80 BTC-mod(23 jts) 971 .72 31.21 TAM 7 5/811 Port Collar 2.41 1002.93 jts. 3-38 7 5/811, 29.7#, L-80 BTC-mod (36 its) 1512.41 1005.34 Gemeco Float Collar 1.32 2517.75 its 1-2 7 5/811, 29.7#, L-80 BTC-mod(2 its) 81.41 2519.07 Gemeco Float Shoe 1.48 2~OO.48--\ CasinQ shoe @ 2ß01 .96 ) ~ T.D. @ 26121 leaving 10' of rathole 29 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, 38, 39, over stop collars and over casing collars on Jts. 3-14 and over collars of its. 17,20,23,26,29,32,35,42,45,48,51,54,57. Joints 62 - 65 (4 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 75K Up, 65K On, 12k Blocks. Ran 61 joints of casing. Drifted casing with 6.75011 plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 ~C(4,li~~~~EF~ MAR 1 5 2004 Drilling Supervisor: DA VE BURLEY ~~ ~" ARCa Alaska, Inc. Well Name: 2L-323 Rig Name: DOYON 141 Cementing Details Report Date: 12/18198 AFC No,: AK9757 Report Number: 4 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7-518" 9-718" 2602 2518 Centralizers State type used, intervals covered and spacing Comments: Detailed on casing tally. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after con d): Comments: 10.2 27 27 37 35 Gels before: Gels after: Total Volume Circulated: 12/15 9/13 700 Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 10.5 Lead Cement 0 Type: Mix wtr temp: N? of Sac~: I Weight Yield: Comments: ASIIILW 65 363 \ 10.7 4.43 Additives: \ )\ Standard blend Tail Cement 0 Type: Mix wtr temp: N(~~CkS} I Weight: Yield: Comments: G 65 15.8 1.17 Additives: \..__~7 1 % 51, 0.2% D46, 0.3% D65. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7bpm 7bpm 75 Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 7fpm 65 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 115.5 bbls 115.8 bbls Calculated top of cement: I CP: Bumped plug: I Floats held: 100 bbls of cement to surface. Date: 12/18198 yes yes Time:0950 hrs. Remarks:Staged pumps up to 7 bpm and cond mud. Pumped 20 bbls of preflush, 40 bbls of spacer and lead cement untill spacer seen back at shakers (286 bbls) followed with 50 bbls of tail cement. Displaced with 25 bbls of fresh water and 90.8 bbls of mud. Reciprocated casing untilllead cement back at surface, bumped plugs to 1500 psi, full returns throughout. Cement Company: I ~igcontràctor: I Approved By: DS DOYON D.BURLEY ~1Ir.. ~~ ARCO Alaska, Inc. Daily Drilling Report AFC No. AK9757 Date 12/18/98 RptNo 4 Rig Accept - hrs 12/16/9805:00:00 AM Days Since AccepVEst: 2.8 I 2.8 Rig Relase - hrs: Well: 2L-323 Contractor: DOYON Rig Name: DOYON 141 Depth (MDfTVD) Daily Cost $ 240360 Last Csg: 7-518" 2602' 2612/2303 Prev Depth MD: 2612 Cum Cost $ 507124 Next Csg: 5.112" x 3.1/2" 10409' Progress: 0 Est Cost To Date $ 475000 Shoe Test: Operation At 0600: Cleaning out cement from 2510'. Upcoming Operations: Change over to new 9.1 ppg mud, LOT, drill 6-3/4" Production hole. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND N TST 12/17198 12/18/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.2ppg 12/02/98 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 65sqc N SPACE 12/11/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 27 I 35 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1335 9/131 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1500 4.6 12/17/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 117 mV30 min INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 2L-325 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP OF 27 120bbl III I I 2L.323 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 17.5 11211 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 15° 9.8 61611 750 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 18.39 1.9% III Water Base Muds 1220 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 100 III 11111 1111I 195 Diesel 80 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $16840 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $48929 III III III 1495 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 BAROID III III III 2598 PERSONNEL TOTAL 44 " 'TIME, . . HOLE SECT PHA$EOPS . .. '.' '. ...()PERATIONsFRQM;'Q()OO.~~OOOO . '.' 12:00 AM SURF Making Hole PJSM. POH, several tight spots from 9120' to 730' pulled 20-40k over. Suñace check mwd, laid down mwd and motor. 02:00 AM 06:00 AM 4.00 RUN_CSG SURF Casing and PJSM. RU and run 7-5/8" casing PU landing joint and Cementing cement head. Worke d casing past tight spot @ 950' with slight effort. 06:00 AM 08:30 AM 2.50 CIRC SURF Casing and Staged pumps up to 7 bpm 450 psi and conditioned mud Cementing for cementing, full returns throughout. Held safety meeting with Dowell and crew. 08:30 AM 11:00AM 2.50 CMT_CSG SURF Casing and Cemented casing (one..~age) with 286 bbls lea and 50 Cementing bbls of tail s!un:y,Displated with 25 bbls of wat rand 90.8 5üëí; had 100 bbls of 10.7 ppg cereturns to uñace. Bumped plugs, !!~~~d;'" returns thoughout. .~I.I..Iiace-&qtripIfient and hnes, laid down cement head and landing joint. 11:00 AM 12:00 PM 1.00 NU_ND SURF Casing and ND Divertor system. Cementing 12:00 PM 05:30 PM 5.50 NU_ND SURF Casing and ND Divertor system, install casing head and tubing spool. Cementing NU BOPE. 05:30 PM 10:00 PM 4.50 BOPE SURF Casing and Tested BOPE 250/3500 psi, install wear bushing. Cementing 10:00 PM 12:00 AM 2.00 OTHER SURF Other Laid down 6.3/4" drill collars from derrick. 24.00 Daily Drilling Report: 2L-323 12/18/98 Page 5 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-323 Date: 12/19/1998 Supervisor: D.P .BURLEY Casing Size and Description: 75/811,29.7 ppf, L-80, BTC Casing Setting Depth: 2,602' TMD 2,296' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,315' TVD 850 psi + 9.1 ppg EMW LOT= (0.052 x 2,315') = 16.2 ppg Fluid Pumped = 0.91 bbls Pump output = 0.101 BBUSTK 2,357 psi - TIME lINE J I I ! I I I I I I j I - ONE MINUTE I , ¡ I . I . . . . I I ¡ J'. 1 ¡ I 11' . . . . ir-*'"'"'-...L.I. I II I IT, ~ '¡-'-r ¡ ! I I I I I I I ' , I I I I I I! I I . i II III II I I II, I I '1' 'I I ! I JI. I . I I ¡I! I-e-LEAK-OFFTEST ¡If ! I 'II J I 1 I ~CASING TEST IflJ I I -~~>"LOT SHUT IN TIME I J,. } I I I I I ,III I I ---*-CASING TEST SHUT IN TIME I I ! II I ! 1 I --+-TIME LINE I ' If"r¡, 'I' I II' I! I I I I JI , , I II I . I PI I 111'11 '1111 1,1 I i J ,I" I ! . I II 2,020 psi 1,683 psi ~ 1,347psi :;) tn tn W Œ 1,010 psi 673 psi 337 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 56 60 62 64 66 68 70 72 74 76 78 60 82 84 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r---------l--------¡----------------; f======-=~1~~J~Ì~~==E~~i\~=J ! ! 2 stks i 70 psi i 1-----------1-------+----------------1 ¡ ! 3 stks ! 190 psi! r----------T4 stks---T-3"õõ-p-šT--l L~-====-~~J~=}-štks-=~X~~~QYš-C~J ! ! 6 stks ! 520 psi! r--------T----7Si-ks---I-- 61 õpš¡--l r---------T----Š-ši-ks---r--73õ-P-šT-l I-------i-------+------------- I ; 9 stks ; 850 psi; r--===~~--1=====-~~--r==~~=~~~~==~i t----------1-------------t--------------1 Ë=~ -=t:~=~:$===:==1 F--~-=~======f==:~ ~~~~~:~1~~~~~~Þ~~~ L~!lUT_!..~!.!.~------~lt~.:!_~ PRÉ~~~~E L__-9:_~~!~-_J_---______L___~~9-_!?2J_--j ! 1.0 min ! ! 840 psi! .---------1------+----------------1 L-- 2'~2!l~--L--------l..---~C!P_~}----~ L~S> min__j__------L---~-C!.P_~--.J ! 4.0 min ! i 830 psi! C=-i~~~=l=====--==~I=~~~~~~~~] L-"§:Q. mi~--L-_-------L-~30 psi___j L_2:Q.~~__1____--_____L___~?i>- psi___J i 8.0 min ! ! 820 psi! 1--------------1--------------+--------------1 ! 9.0 min ! i 820 psi! [=I.Q~2_~~=I===I=~!~~ psf] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-----------------r-------------------'-----------------¡ I , I I ~------------------~-----------------+------------------4 ! ! 0 stks I 0 psi! [=:==:=:=~I=f:r~Ef]~ll~fj L--------------L--~_~tk~__--L--~-~-Q-p-~~--j ! ! 4 stks ! 450 psi! [=~~=~~~~=~~~r~=§~tk~=~~I=~~~~~Q~~~--J ¡ ! 6 stks ! 860 psi! r--------------T----~ršt-kS---T--91fõ-pši--l r---------------¡------ã- stks--¡--1~16ÕpšT-1 .-----------------t--------------...--------------;-; ~---------_____~m__~_~~!..~----i-_l!~~QJ~~~-~ ! ! 10 stks ¡ 1 ,550 psi ¡ r~==~~~~=~=~~~~=c~=n~~~~~=~~~j~~~~~~=] ~-----------------_¡____1~~!-~~---i--~~~Q-p-~--~ t~~~~~~~~~~~~~~~~~~J~=~~===-~~~~~t~~~~==~~=~=j I I I I r=~:~=~~¡==~~:===:t====~ L~~.l!..~!~_!)M~L----------~~_l!_~_!~_~~~~~RE ¡ 0.0 min ¡ ! 2,050 psi! [=fQ~!ñ[~~-=!~==~~=~=~=~=r~~~~~1!~[] ! 2.0 min I I 2,040 psi! ~----------------t--------------------~-----------------..J ! 3.0 min ! ! 2,030 psi! [~[~I==-~=:=t:~~1~B ! 6.0 min I i 2,020 psi i r~I~~I~~~~l~~~~I~JliI~ ! 15.0 min ! ! 2,000 psi! L______-------------t----------------------------------.. ! 20.0 min ; I 2,000 psi! ~-------------------t--------------------i----------------..J ! 25.0 min ! I 1,990 psi! [~~Q~~~!ñ[~==[~=~~~~==~=~I~j~99~=p~~] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since AccepUEst: 3.8 14 Rig Relase - hrs: AK9757 12/19/98 5 12/1619805:00:00 AM Well: 2L-323 Depth (MDfTVD) 4142/2973 Prev Depth MD: 2612 Progress: 1530 Contractor: DOYON Daily Cost $107117 Cum Cost $ 614242 Est Cost To Date $ 610000 Rig Name: DOYON 141 Last Csg: 7-5/8" @2602' Next Csg: 5.1/2" x 3.1/2" @ 10409' Shoe Test: 16.0 Operation At 0600: Well shut In, bit @ 2642'. Clrc out gas cut mud thru choke. Upcoming Operations: Staballze well, Increase mud wt. to 9.6 ppg and RIH, cond mud and drill ahead. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 4142 2R1 N TST 12/17/98 12/18/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.4ppg 55 6.75 12/02/98 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc 80 HTC N SPACE 12/11/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 12/17 45 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1450 6/81 25 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 600 5.0 35 12/19/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 111 mV30 min 2000 2612 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER& 4.5% 1500 1530 2L-325 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF 24 145bbl III 6.15/1.05 I 2L-323 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 4 15 11211 5 -10 - 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 90° 10 61611 90 - 285 750 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 24.00 0.6% 70 III .518 Water Base Muds 365 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 550 294111 131131131131 I 11I11 45 Diesel 20 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $11707 20140 II 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $60637 43011050 1 I III III 430 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID 9.4111 III III 3028 PERSONNEL TOTAL 46 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 03:00 AM 3.00 BHA PROD Making Hole PJSM. MU BHA #2, scribe tools and install probe. Initialize tools and Istall sources. PU 64.75' dc's. 03:00 AM 04:00 AM 1.00 TRIP_IN PROD Making Hole RIH 2440'. 04:00 AM 04:30 AM 0.50 CIRC SURF Casing and Circ out cement contaminated mud. Cementing 04:30 AM 05:00 AM 0.50 TEST_CSG SURF Casing and Test 7-5/8" casing to 2000 psi, 30 min. Cementing 05:00 AM 07:00 AM 2.00 CLN- OUT SURF Casing and Wash to 2510', clean out cement and float equipment, drill Cementing 20' of new hole to 2632'. 07:00 AM 08:00 AM 1.00 CIRC SURF Casing and CBU, change well over to new 9.1 ppg mud. Cementing 08:00 AM 08:30 AM 0.50 TEST SURF Casing and Perform FIT to 16.0 ppg. Cementing 08:30 AM 09:30 AM 1.00 PRB_EFS PROD Other Troubleshoot mwd and obtain survey. 09:30 AM 12:00 PM 2.50 DRIL PROD Making Hole Drill from 2632' to 2881'. ART=0.6 hrsAST=0.3hr. 12:00 PM 03:30 PM 3.50 DRIL PROD Making Hole PJSM. Drill from 2881' to 3227'. ART=1.25 AST=0.25 hr. Back ground gas increased to 300.500 units connection gas reached 2000 units. 03:30 PM 04:00 PM 0.50 CIRC PROD Other Circ out gas cut mud and increase mud wt. to 9.4 ppg. background gas 35 units. 04:00 PM 12:00 AM 8.00 DRIL PROD Making Hole Drill from 3227' to 4142'. ART=3.25 hrs. AST=0.5 hr. Background gas 20-50 units.no connection gas seen. 24.00 Supervisor: D.BURLEY Daily Drilling Report: 2L-323 12/19/98 Page 7 Casing Detail 5-1/2" X 3-1/2" Production Casing WELL: TARN 2L-323 DATE:12/24/98 1 OF 1 PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LOS = 25.25 TOPS 5 1/211, LANDING JT. 34.01 OVERALL LENGTH 25.25 5-1/211 GEN V CASING HANGER 2.96 25.25 Jts. 1-221 5-1/211,15.5# L-80, LTC MOD (joints) 9410.65 28.21 PUP 5-1/2", 15.5# L-80, LTC MOD 10.00 9438.86 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/211 x 411 21.01 9448.86 XO 3-1/211 9.3# L-80 8rd EUE X 5 1/211 EUE 8rd (XO) 9469.87 pup 3-1/211 9.3# L-80 8rd EUE 10.12 9469.87 Jts.257 -259 3-1/211 9.3# L-80 8rd EUE (3 joints) 94.42 9479.99 pup 3-1/211 9.3# L-80 8rd EUE (marker) 8.15 9574.41 Jts.234-256 3-1/211 9.3# L-80 8rd EUE (23 joints) 714.75 9582.56 Weatherford Gemoco Float Collar 1.17 10297.31 Jts. 231-233 3-1/211 9.3# L-80 8rd EUE (3 joints) 93.92 10298.48 Weatherford Gemoco Float Shoe 1.84 10392.40 Bottom of Shoe @ 1 0394.24 ACTUAL TD= (10,4001) 5.761 RA THOLE. Bypass plug latch in receptical @ 10,265.6T. (top of jt. #234) (29) 3-1/211 x 6-1/211 straight blade centralizers(Jts.231-259 ) run centralizers in middle of jt on stop collars on shoe & fit collar jts (12) 5 1/211 x 63/411 bow spring centralizers (Jts.1-12) (16) 5-1/211 x 6-1/211 centering guidess on jts 220,216,212,208, & Jts 204,201,198,195,192,189,186,183,180,177,174,171 I Remarks: String Weights with Blocks: 130k Up, 55K Dn, 12K Blocks. Ran 29 Joints 3-1/211 and 221 Joints of 5-1/211 casing. Drifted 5.511 (4.7511)& 3.511 (2.86711) casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 DrHling Supervisor: R. W. SPRINGER ..... .,." ARCO Alaska, Inc. Cementing Details Well Name: 2L-323 Report Date: 12/24/98 Report Number: 10 Rig Name: DOYON 141 AFC No.: AK9757 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 5-1/2 X 3.1/2" 6.75 55 10394 10297 Centralizers State type used, intervals covered and spacing Comments: 29 @ 3.1/2 X 6-1/2" straight blade cent, 12 @ 5-1/2 x 6-3/4" bow spring cent, 16 @ 5-1/2 x 6-1/2" centering guides see csg detail flplacement. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.6 12 12 14 12 Gels before: Gels after: Total Volume Circulated: 5/7 417 650 bbl Wash 0 Type: Volume: Weight: Comments: ARCO B47 20 bbl Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: Additives: Tall Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 75 310 15.8 1.20 Additives: 3% D53,.6%D65,.7%D800,.2gal/sx D47,.1 gal/sx D135, 2.0 gallsx D600 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 5BPM 3 BPM 130 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10' 10'/MIN 55 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 232 BBL 231.5 Calculated top of cement: CP: Bumped plug: I Floats held: Date: 12/25/98 YES YES Time:0108 A.M. Remarks:BUMPED PLUGS W/2000 PSI, HELD F/10 MINUTES, LOST -160 BBL MUD CIRCULATING PRIOR TO CEMENTING (TOTAL OF 650 BBL CIRCULATED). FULL RETURNS THROUGHOUT CEMENTING. Cement Company: Rig Contractor: APproved By: DS DOYON R.W. SPRINGER ~1rIt.. ~" ARCO Alaska, Inc. Daily Drilling Report AFC No, I Date RptNo I Rig Accept - hrs Days Since AccepUEst: 8.8/ Rig Relase - hrs: AK9757 12/24/98 10 12/16/9805:00:00 AM Well: 2L-323 Depth (MDfTVD) 10400/5773 Prev Depth MD: 10400 Progress: 0 Contractor: DOYON Daily Cost $ 162320 Cum Cost $ 1221607 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 5.1/2 X 3.1/2" tm 10394' Next Csg: Shoe Test: 16.0 Operation At 0600: RUNNING 3-1/2" COMPLETION Upcoming Operations: COMPLETE WELL & MOVE MUD DATA DRILLING DATA BIT DATA EH&S DRILLs/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2R1 N TST 12/23/98 12/18/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 6.75 12/02/98 12122/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 46sqc HTC N SPACE 12121/98 PVfYP SOWT TYPE TYPE TYPE FUEL & WATER 12/12 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1750 4/7/ 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 650 4.6 10400 12/24/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 111 mU30 min 2612 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 6.0% 7788 2L-325 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -2 228bbl 2700 III 37.05/4.15 / 2L-323 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 10 15.0 1121 I 5 -10 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 225. 10.0 61611 90 - 285 625 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -23.38 19.02% III .518 Water Base Muds 169 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 850 III 131131131131 I 1I1I1 45 Diesel 20 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $1731 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $133024 III 2131WTIG III 234 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID 9.6111 X IN I ER I TD III 6461 PERSONNEL TOTAL 46 TIME 'I END HOORS I OPSCODE T 'HOLESECT lPHASEOPS I OPERATIONS FROM 0000 - 0000 12:00 AM 02:30 AM 2.50 TRIP_OUT PROD Other OBSERVE WELL F/FLOW @ SHOE, CONTINUE UD DRILLPIPE & HWDP. 02:30 AM 06:00 AM 3.50 BHA PROD Other UD DRILL CLRS- REMOVE SOURCES- DOWN LOAD MWD- PULL PROBE- BREAK BIT & CONTINUE UD BHA. 06:00 AM 07:00 AM 1.00 RIGS PROD Other CUT DRLG LINE, PULL WEAR BUSHING. 07:00 AM 07:30 AM 0.50 CASG PROD Casing and RIU TO RUN CSG, PJSM. Cementing 07:30 AM 11:30 AM 4.00 CASG PROD Casing and RUN 3-1/2 X 5.1/2" CSG. Cementing 11:30 AM 12:00 PM 0.50 CIRC PROD Casing and CIRC BTMS UP @ SHOE. Cementing 12:00 PM 03:30 PM 3.50 CASG PROD Casing and CONTINUE RUNNING CSG. Cementing 03:30 PM 04:30 PM 1.00 CIRC PROD Casing and CIRCULATE 130 BBL @ 6375' @ 2-1/2 BPM. Cementing 04:30 PM 08:00 PM 3.50 CASG PROD Casing and CONT. RUNNING CSG. Cementing 08:00 PM 11:30 PM 3.50 CIRC PROD Casing and BREAK CIRC & SLOWLY BUILD CIRC RATE TO 4-1/2 BPM Cementing TOTAL FLUID LOSSES WHILE CIRC -160 BBL MUD. 11 :30 PM 12:00 AM 0.50 CEMENT PROD Casing and BEGIN CEMENTING AS PER PLAN. Cementing 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-323 12/24/98 Page 1 5 ...~ ~" ARCa Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo -rig Accept - hrs Days Since AcceptJEst: 9.8 I Rig Relase - hrs: AK9757 12/25/98 11 12/16/9805:00:00 AM Well: 2L-323 Depth (MDfTVD) 10400/5773 Prey Depth MD: 10400 Progress: 0 Contractor: DOYON Daily Cost $ Cum Cost $ Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 5-1/2 x 3-1/2" @ 10394' Next Csg: Shoe Test: 16.0 Operation At 0600: MOVING RIG TO 2L-321 Upcoming Operations: FINISH MOVE, SPUD MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOP/DRill SW N TST 12/23/98 12/18/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRill LAST FIRE DRILL 8.5ppg 12/02/98 12/22/98 VISCOSITY PUWT MAKE MAKE SPill LAST CONFINED LAST SPill DRilL sqc N SPACE 12/21/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER I GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1540 I / APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRill WATER USED - 400 12125/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 121 ml/30 min INJECTION USED - BBlS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 2L-325 PERSONNELDA TA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF 5 228bbl III / / 2L-323 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 1121 I 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 225° 61611 675 LGS SPM 1 TFA TFA INJECTION FLUIDS CHill FACTOR of 0.65 % III Water Base Muds 1600 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 III 11111 11111 125 Diesel 90 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $500 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $133524 III III III 1815 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID III III III 8246 PERSONNEL TOTAL 46 ,',TIM!;, J ,'EN[) ,'. <, HOURSI.OPSQODE .1 'HOl,E S,ECT ,',IPI:"IASEOPS, ,,' 1<,' '.." ",OJ~E~TIQNS,fgQMQOOO"OQOQ : .:> ;"', 12:00 AM 01 :00 AM 1.00 CEMENT PROD Casing and CEMENTED W/56 BBL CMT(310 SX) AS PER PLAN, Cementing BUMPED PLUGS, FLOATS HELD, FULL RETURNS THROUGHOUT, CIP @ 0107 HR. 01 :00 AM 01 :30 AM 0.50 CEMENT PROD Casing and CHECK FLOAT EQUIPMENT, HELD 2000# F/10 MINUTES, Cementing OBSERVE WELL. 01 :30 AM 02:00 AM 0.50 CASG PROD Casing and RIG DOWN CEMENTING HEAD & LAY DOWN LANDING JT. Cementing 02:00 AM 03:00 AM 1.00 CASG PROD Other RIU & INSTALL PACKOFF, FMC TEST TO 5000# F/10 MIN. 03:00 AM 08:00 AM 5.00 RUN_COMP COMP Completion RIU TO RUN 3-1/2" TUBING, PJSM, RUN COMPLETION. 08:00 AM 08:30 AM 0.50 RIGS COMP Other SERVICE RIG. 08:30 AM 11:00 AM 2.50 RUN_COMP COMP Completion CONTINUE RUNNING TUBING. 11:00 AM 12:00 PM 1.00 SPAC_OUT COMP Completion SPACE OUT- M/U TBG HGR, LANDING JT & CIRC HEAD. 12:00 PM 01 :30 PM 1.50 CIRC COMP Completion DISPLACE WELL WIO STINGING INTO CSR W/280 BBL CLEAN SEA WATER. 01 :30 PM 02:00 PM 0.50 TEST - CSG COMP Completion TEST CSG TO 3500# F/30 MINUTES 02:00 PM 03:00 PM 1.00 CIRC COMP Completion FREEZE PROTECT TBG & ANNULUS BY PUMPING DOWN TBG W/35 BBl DIESEL & ALLOWING TO U-TUBE TO ANNULUS. 03:00 PM 04:30 PM 1.50 TEST COMP Completion LAND TBG RUN IN LOCK DOWN STUDS ATTEMPT TO TEST TBG & ANNULUS-NEITHER WOULD TEST 200# PRESS LOSS/MINUTE 04:30 PM 09:30 PM 5.00 PRB_TEST COMP Completion RIU TO RUN SLlCKLlNE RIH W/HALLIBURTON(OTIS) SHIFTING TOOL & SHIFT BAKER SLIDING SLEEVE INTO CLOSED POSITION- POH W/TOOL. Daily Drilling Report: 2L-323 12/25/98 Page 17 09:30 PM 10:00 PM 0.50 TEST 10:00 PM 10:30 PM 0.50 PRB_TEST 10:30 PM 11:00 PM 0.50 NU_ND 11:00 PM 12:00 AM 1.00 NU_ND 24.00 COMP Completion COMP Completion COMP Completion COMP Completion TEST TBG TO 3500# F/10 MIN & ANNULUS TO SAME. ALL OK. RIG DOWN HALLIBURTON WIRELlNE & LANDING JT. SET TWO WAY CHECK NID BOPE. Daily Drilling Report: 2L-323 12/25/98 Supervisor: R.W. SPRINGER Page 18 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-323 Date: 12121/1998 Supervisor: D.P.BURLEY Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2,296' TVD 2,602' TMD Mud Weight: 9.7 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 4,065' TVD 150 psi + 9.7 ppg EMW LOT= (0.052 x 2,296') = 11.0 ppg Fluid Pumped = 4.04 bbls Pump output = 0.101 BBUSTK 2,357 p&i -t TIME LINE I I j I J! I '! I ONE MINUTE I I I I . . , . ' I i I I ., . . 2,020 p&i -4. . "" .c- >. I i II III -I I I I i i I I ¡ 1,683 p&i I i II r I I I i ~ 1,347 p&i I I I I :;, I ,t II I I I I--LEAK-oFFTEST i I en ~11 en jl I w Œ 1.010p&i I I II II I I -"-CASING TEST --.0-- LOT SHUT IN TIME I I I I --:k-CASING TEST SHUT IN TIME ! -+- TIME LINE I 673 psi Irl, I I II I ~ i I I I I II, I I I I ! 337 p&i rill I I I I I I II i 0 ..ð"'-1 I I I I I p&1 0 2 4 6 8 10 12 14 16 18 20 22 24 26 2S 30 32 34 36 as 40 42 44 46 4S 50 52 54 56 58 60 62 64 66 66 70 72 74 76 78 so S2 S4 S6 sa --------------------------------------------- STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE !~~==J=--==---=~=~r-=~==~=--=~] ¡ i 0 stks ! 0 psi! ¡-------1--1 stk-Š---r--"2õ-pš¡--l ¡ I~--- 2 stk-Š-!7Õ-psi --1 I--------~---------+-----------I ! ! 3 stks i 110 psi! r-----l-~r stkš---T12õpSil ¡---------r--Š stkš-l-r4"opsI-¡ .---------~----------+-------------t ! ! 6 stks ! 150 psi i [---------[- 7 stks ==_L~I~fpsr-] ! i 8 stks ! 150 psi i t-----i---------+-----------I ~----~- 9 st~----~-QJ?~!_~ i i 10stks i 160 psi ! r----------r--ß stk-Š---I--r7opsr--l ¡--------¡---2õ-ši-ksl17õ-psf--¡ }------~--------+-------------I i i 25 stks i 170 psi i ¡------r 30 stkš--1-17õpsr-l ¡-------r-35 stkš---117õ-psi-1 ~ -:=:=~~~=~~=R~~~~ 1=~==---=I:::::::=:::=:::+-=--=:=~ r-----------l-------""'---T---"-------' 1---------,--------1-------1 ~!I..,!!.!N TIME L-------___~~UT I~_~~~~~Y-.RE LQ.:Q...~!!!__l________LJ2Q£~L_l ! 1.0 min i ! 150 psi! I------i--------+---------------I ! 2.0 min i ! 140 psi! r---------,-----------......----------, L___~.:Q...~J!!....l_------_l.._~~-Q..P~-~--_J ~-~Q-~~--~---------!-~-~-Q..P~~-i ~-~~!!1~-~-----____-.!-1!Q..p_!~--~ L- 6.0 m~--1------1- 130_'p~_~-.J i 7.0 min ! ! 130 psi! 1'------;--'1--------+--------:---1 ~ 8.0 mln -~---____¡_E!U>~~-I i 9.0 min ! ¡ 130 psi i r--1~~~ñiiñ-I====~~=~[~I!~£~C] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ~=~~~~==~[=~~~~==~[~=~~=~~=~-=4 L------------L-O stks --L---_Q..p~L_-! L_------------l----~~~!.~--i---~!!L...J i---------------~----~~~~~-__+___l60 .P_!!}--~ L----------L--~-~~I...E!»J?.!!}-! ~-------------_L___~_~tk~___- --_~_~~..p..!!L_J ~---------------i---§- stk~_-t- 680 psi-1 ~----------J---~ st~~---+--~-~~-! L_-_--------------~----_Z- stk~__---L-~_80 .P..~L.J ! I 8 stks ! 1,160 psi! r------------t------------~-----;--i ~-----------------¡----~-~~~-+--) ,3~~.!_-! L---------------L--~9 stk~_-.L-_!!~5°..p~LJ i______------~---~!..~~-t-!z800-1!~1_J t-------------t----~~~~~t-~~~~-P~1-1 ~==~~~=~~-=~~=-~=~-=~=~=~r~~-=~===~~-=~ , I I I }--------------i----------------I------~ ¡ I I i f~~=~-=~~~~~~~=~~f~~=~===~~=-~+=~=~-===~=i ¡ SHUT IN TIME ¡ SHUT IN PRESSURE r---------;-----Y----------------ì----------:--l L--q.:~rnln____~_-----------_...__.sP5q~-.J L_-1.:2-~~--~-----------I! --~Q~_p~lJ i 2.0 min I 2,040 psi! }------------i---------------+------------~ L--~.:Q-~!~-----!-----------_}._~!~30 p'si_J L_~;..~~!~-_.l_------_____--L_~~3°-1!~!J i---§;Q-~!~--i-----------_-i-~,022_p'si -i L--~;Q-~~-+------------+-_¥PJ~~!_-j L__Z':~~~--_._--------------T-~!Q~QJ~~~J ~----~.:QJnt~-!----------------i--~!~~~_P.~~-~ ~---~Q_!!!!~----~-------------_--!---~!~12_P.~!...~ L--'!~Q-!!!!~--+-------_----L~!~-~Q_P.~~.J i_!..~q.!n!~--t---------------i-~,OO~~LJ i---~q.:Q.!n!!!_-+------------+-~'OOO _P.~J L-~§.:~~!~--l-------------+-_!~!!Q.P.~ L_~Q;..q_~!~--_L_----------_-L_!!~~~p.~l__J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ...~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since AccepVEst: 5.8 I 6.2 Rig Relase - hrs: AK9757 12/21/98 7 12/16/9805:00:00 AM Well: 2L-323 Depth (MDfTVD) 7868/4545 Prev Depth MD: 5894 Progress: 1974 Contractor: DOYON Daily Cost $ 115064 Cum Cost $ 843222 Est Cost To Date $ 920000 Rig Name: DOYON 141 Last Csg: 7-5/8" @ 2602' Next Csg: 5-1/2" x 3-1/2" @ 10409' Shoe Test: 16.0 Operation At 0600: Drilling Production hole @ 8520'. Upcoming Operations: Wiper trip @ 8900', drill to TD +1- 10409'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL LSND 7868 2R1 N TST 12/21/98 12/18/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 77 6.75 12/02/98 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 49sqc 95 HTC N SPACE 12/21/98 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 15/15 60 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1960 6/91 18 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1250 3.8 25 12/21/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mU30 min 300 2612 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 6.0% 2500 5256 2L-325 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP OF 30 303bbl 2600 III 21.55 1 2.45 1 2L-323 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 15 18 11211 5 -10 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 275° 10 61611 90 - 285 - 675 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 8.99 2.1% 70 III .518 Water Base Muds 535 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 550 294111 131131131131 1 11111 90 Diesel 40 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $20604 20140 II 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $99448 5501114011 III III 665 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 BAROID 9.6111 III III 4634 PERSONNEL TOTAL 44 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 02:45 AM 2.75 DRIL PROD Making Hole PJSM. Drill from 5894' to 6175'. ART=1.3 hrs. Fluid losses increased to 50-60 bph. 02:45 AM 03:30 AM 0.75 CIRC PROD Making Hole Pump sweeps around and circ clean. 03:30 AM 09:00 AM 5.50 DRIL PROD Making Hole Drill from 6175' to 6801'. ART=3.1 hrs. AST=0.1 hr. Fluid loss +1- 30 bph. Hole giving back fluid during connections. Background gas average 15 units. 09:00 AM 11:30 AM 2.50 CIRC PROD Making Hole Pumped sweeps and circ clean. Monitor well, initial flow 108 bph reduced to 15 bph in 30 min. Pump dry job. 11:30 AM 12:45 PM 1.25 WIPERTRP PROD Making Hole Wiped hole to 4531'. Flow rate continued to trend downward during trip, no other problems. 12:45 PM 01:15 PM 0.50 TEST PROD Other Performed LOT established EMW=10.4 ppg TVD=4065' 01:15 PM 02:00 PM 0.75 WIPERTRP PROD Making Hole RIH to 6801', no problems. 02:00 PM 02:30 PM 0.50 CIRC PROD Making Hole CBU, max gas 240 units. 02:30 PM 12:00 AM 9.50 DRIL PROD Making Hole Drill from 6801' to 7868' ART=4.2 hrs AST=0.5 hrs. Initial losses 50-60 bph. Pumped 100 bbls of 10 ppb LCM cocktail; losses 20 bph @ midnight. 24.00 Supervisor: D.BURLEY Daily Drilling Report: 2L-323 12/21/98 Page 11 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU' Jim Regg P.I. Supervisor-- ~,~ FROM- John Crisp Petroleum Inspector DATE: July 4, 2003 .,,~\,\~ ~'.? SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2L Pad Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 1982510 ITypetestl P ITestpsil 2000 I Casingl 1600 I 25501 2510 I 2505 I P/F .I,_P I Notes: Pretest OA psi. 350 Pressure during test 425 3 BBL pumped I P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: Type Inj. Type test Type testI ITM psil I Casing IType Inj. Type test Type Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. ,cc.'. MIT report form 5/12/00 L.G. 8OANNEE:;,, ¢.UG 0 1 2003 2003-0704_M IT_KRU_2L-323_jc.xls 7/17/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Tarn / KRU / 2L 07/04/03 Arend/Brake - APC John Crisp Well 12L-323 P.T.D. 11982510 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I TypelnjI Gp I T.V.D. 15237 I Tubing { 3300[ 33001 33001 33001 Interval l i~ Type Test Test psiI 1500 I Casing I 16251 25501 25101 25101 P/F OA 400 400 425 400 P.T.D.I Notes: I Type InjI IT.V.D. Type Test Test psi IntervalIP/F P.T.D.I Notes: Type T.V.D. Type Test Test psi Interval]p/F P.T.D.I Notes: I Typelnj I I T.V.D. Tubing IntervalI Type Test Test psi P/F P.T.D,I Notes: Type Test Test psi 1500 Casing Interval]p/F : Test Details: 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 2003-0704_M IT_.K RU_2L-323,xls 7/11/2003 '198-251-0 KUPARUK RIVU TARN 2~]323 502 103,20282,00 PH/LLiPS~XSKAiNC Roll #1: Start: Stop Roll #2: Start Stop MD 10400 TVD 05774 Completion Date: 12/25/98 Completed Status: 1WINJ Current: WAGIN T Name Interval D 9204 2 SPERRY MPT/GR/EWR4/CNP/SLD OH 6/17/99 6/17/99 fL CBL/SCMT FINAL 9375-10150 CH 5 3/12/99 3/18/99 ../L DGR/CNP/SLD-MD FINAL 2612-10400 OH 6/24/99 6/29/99 ...,.,,L DGR/CNP/SLD-TVD FINAL 2296-5773 OH 6/24/99 6/29/99 ,..--'L DGR/EWR4-MD FINAL 2612-10400 OH 6/24/99 6/29/99 /-"L DGR/EWR4-TVD FINAL 2296-5773 OH 6/24/99 6/29/99 ~.-L MI INJP-SPIN/TEM FINAL PRES 9280-9910 Cid 2 2/17/00 2/25/00 ,,,,-E' PRES/TEMPSRVY FINAL 9550-10186 CH 5 3/12/99 3/18/99 .j,"L SCMT-PSP FINAL BL(C) 9375-10150 2/21/99 CH 5 6/8/99 6/16/99 R SRVYRPT SPERRY 0-10400. OH 1/11/99 1/13/99 Sent Received T/C/I) Thursday, January 25, 2001 Page 1 of 1 Schlumberger NO. 121203 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2L-323 ~ 4__ MEM INJECTION PROFILE 000204 I 1 2N-307 i MI INJECTION PROFILE 000203 I 1 2N-321AL MEM INJECTION PROFILE 000205 I 1 2N-325 MI INJECTION PROFILE 000206 I 1 31-06 L~t (L.- INJECTION PROFILE 000207 I 1 3J-17 PRODUCTION PROFILE 000208 I 1 3M-07 L~ ~ r._._ INJECTION PROFILE 000207 I 1 .~, ~ ~.. i~ ~ i,,,., i~ i-- · o/nne Alaska Oil & Gas (;on,:;. {;ol'l'l:~lisstor _.Anc,.l'~orage Please sign and return copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. mnanK you. 2/17/00 0 I::! I I__1__ I IM I~ To: State of Alaska June 24, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evakmfion Logs 2L-~:I; AK-MM-90051 The technical data listed below is being submitted herewi~ Please address any problems or concerns to the attention of.' Yam Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, gG, Anchorage, AK 99518 2L-321: 2" x 5" MD Resistivity & Cramma Ray Logs: 50-103-20286-00 2" x 5" TVD Resistivity & Cranmla Ray Logs:. 50-103-20286-00 2" x 5" MD Neutron & Density Logs: 50-103-20286-00 2" x 5" TVD Neutron & Density Logs: 50-103-20286-00 1 Blueliae 1 Folded Sepia 1 Btuetine 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 3999 Ala~Oil&6asCon~.~n 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL State of Alaska Alaska O~ and Gas Conservation Comm. Attm: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June 17, 1999 2L-323, AK-MM-90041 1 LDWG fo~ Disc with verification listing. API~: 50-103-20282-00 PI,le.S~E ACKNOWLEnGE RFX2EIFT BY SIGNING AND RETURNING ~ ATrACglEB COPY OF ~ TRANSMYUrAL LETTER TO ~ ATTENTION OF: Spen'y-Sun Dnqling Service Attn: Jun Galvin 5631 Silvemdo Way, Suite G. ,..!!.Jtq 1 ? 1999 Date: Ala,flta Oil & Gas Cons. c,,omm~ion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Nalliburton Company 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b,~ 99239 CBTW/PSP/SCMT 990221 1 11C-18 99243 CBT W/PSP/SCMT 990402 1 '1D-132 ~__. 99248 SCMT 990216 1 1D-125 99249 CBT W/PSP/SCMT 990220 1 1 D- 114 ~,.~ ~ ~ .... 99246 CBT W/PSP/SCMT 990421 1 1 D- 128 99247 SCMT 990215 1 1 D- 122 b~. ~ c~, 99244 CBT W/PSP/SCMT 990226 1 1 D- 111 1,,.~ ~ .- 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 ~,~ f ¢_ 99242 SCMT 990122 1 '~ k_~ '~ DATE: SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 3/12/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12431 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Dri.ve Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date Blueline Sepia 1 E-36 MEMORY GR/CCL 990304 1 1 1 G-07 PRODUCTION PROFILE W/PSP 990218 1 1 1 D-122 C B L/SCMT 990226 1 1 1 D-125 CBLW PSP/SCMT 990220 1 1 2L-323 CBLW PSP/SCMT 990221 1 1 2L-323 PRESS/I'EMP SURVEY 990223 1 1 2N-320 CBL/SCMT 990303 1 1 2N-345 PRODUCTION PROFILE (PSP) 990227 1 1 qs./ql SiGNE~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: IREG IVE[,, 1999 Oil & Gas Co~s. O~nn'~ion STATE OF ALASKA ,~4SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS [~ SUSPENDED E~ ABANDONED~ SERVICE [~ .......... Lnjector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-251 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20282 4 Location of well at surface .' ~ 9 Unit or Lease Name 212'FNL, 836'FEL, Sec. 22, T10N, R7E, UM ., ;','"!':"~ i,~':~ ? '~1~._ Kuparuk River Unit At Top Producing Interval ¢ .... :~ 10 Well Number 456'FSL, 5,,'FEL, Sec. 23, T10N, R,E, UM i'~ -~' '~/~i 'i 2L-323 At Total Depth "~ i 11 Field and Pool 31' FSL, 109' FEL, Sec. 23, T10N, R7E, UM ....... -' ~ KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 117" ADL 380051 ALK4599 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ils Water Depth, ~ offshore 16 No. of Completions 16-Dec-98 23-Dec-98 25-Dec-98I NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of pe~afrost 10400' MD & 5774' ~D 10297' MD & 5718' ~D YES ~ NO ~ NA feet MD 1201 APPROX 22 Type Electric or Other Logs Run GR/Res/Neu/Dens,SCMT, CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM · HOLE SIZE CEMENT RECORD 16" 62.5~ H-40 SURF. 108' 24" 9 cu yds High Eady 7.625" 29.7~ L-80 SURF. 2602' 9.875" 363 sx AS III LW, 240 sx Class G 5.5" x 15.5~ L-80 SURF. 9470' 6.75" 310 sx Class G 3.5" 9.3~ L-80 9470' 10394' 6.75" (included above) 24 Pedorations open to Production (MD+~D of Top and Boffom and 25 TUBING RECORD intewal, size and number) :SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9463' 9449' (CSR) 9796'-9928' MD 5434'-5516' ~D 6 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9746'-9774' MD 5411'-5424' ~D 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9670'-9706' MD 5368'-5389' ~D 6 spf N/A N/A 27 PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas I~, etc.) I Injector Date of Test Hours Tested PRODUCTION FOF',OIL-BBL GAS-MCF WATER-BB~ ~'~~IZE'~ GAS-OIL ~TIO I TEST PERIOD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (~) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presen~ of oil, gas or water. Submit ~re chips. N/A ORIGINAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. ~f 30. '~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T~3 9618' 5337' T-2 9952' 5529' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Dally Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~.~ '~~~.~ Title "~J~ I I.~.l~_, 'T~AI~ L~')~.~ DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 Jn item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/5/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-323 WELL ID: AK9757 TYPE: AFC: AK9757 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/16/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20282-00 12/15/98 (D1) TD: 108' ( 108 SUPV:D.BURLEY 12/16/98 (D2) TD: 756' ( 648 SUPV:D.BURLEY 12/17/98 (D3) TD: 2612'(1856 SUPV:D.BURLEY 12/18/98 (D4) TD: 2612'( 0) SUPV:D.BURLEY 12/19/98 (D5) TD: 4142' (1530) SUPV: D. BURLEY 12/20/98 (D6) TD: 5894'(1752) SUPV:D.BURLEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 NU DIVERTIOR SYSTEM, TAKING ON WATER IN PITS. Moving rig to well 2L-323. MW: 10.0 VISC: 138 PV/YP: 27/57 APIWL: 10.8 DRILLING SURFACE HOLE FROM 1325' Move rig to 2L-323. Accept rig @ 0500 hrs. 12/16/98. NU diverter system and function test. Drill from 108' to 756' MW: 10.2 VISC: 89 PV/YP: 28/36 APIWL: 4.8 MU 7-5/8" LANDING JOINT AND CEMENT HEAD. Drill from 756' to 1672'. Max background gas. Drill from 1672' to 2612'. Wiped hole to 370' tight spots 900'-750' MW: 10.2 rISC: 65 PV/YP: 27/35 APIWL: 4.6 CLEANING OUT CEMENT FROM 2510' Run 7-5/8" casing. Cement casing. ND diverter, NU BOPE and test to 250/3500 psi. MW: 9.4 VISC: 50 PV/YP: 12/17 APIWL: 5.0 WELL SHUT IN, BIT @ 2642'. CIRC OUT GAS CUT MUD THRU CHOKE. Circ out contaminated cement. Wash to 2510', clean out cement and float equipment, drill 20' of new hole to 2632' Perform FIT to 16.0 ppg. Drill from 2632' to 3227' Background gas increased. Increase mud weight to 9.4 ppg. Drill from 3227' to 4142' MW: 9.7 VISC: 50 PV/YP: 13/15 APIWL: 4.2 DRILLING AHEAD FROM 6370' Drill from 4172' to 4643'. Pump sweep and circ clean. Wipe hole to shoe. Observe well flowing, shut in well. Circ out gas kick thru choke. Shut in well. No flow. Drill from 4643' to 5894' Date: 2/5/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/21/98 (D7) TD: 7868'(1974) SUPV:D.BURLEY 12/22/98 (D8) TD: 9813' (1945) SUPV:R.W. SPRINGER 12/23/98 (D9) TD: 9813'( 0) SgPV:R.W. SPRINGER 12/24/98 D10) TD:10400' 587) SUPV:R.W. SPRINGER 12/25/98 Dll) TD:10400' 0) SUPV:R.W. SPRINGER 12/26/98 (D12) TD:10400' ( 0) SUPV:R.W. SPRINGER MW: 9.6 VISC: 49 PV/YP: 15/15 DRILLING PRODUCTION HOLE @ 8520' APIWL: 3.8 Drill from 5894' to 6175'. Fluid losses increased to 50-60 bph. Pump sweeps around and circ clean. Drill from 6175' to 6801' Fluid loss. Hole giving back fluid during connections. Pumped sweeps around. Performed LOT, EMW=10.4 ppg. Drill from 6801' to 7868' Initial losses 50-60 bph. Pumped LCM cocktail. MW: 9.6 VISC: 49 PV/YP: 10/14 DRILLING @ 10,210' APIWL: 4.4 Drill from 7868'-9813' MW: 9.6 VISC: 46 PV/YP: 11/15 LAYING DOWN BHA APIWL: 4.6 Drill from 9813' to 10400'. Sweep hole, circ clean. POH to casing shoe @ 2552' SLM, no correction, RIH, break circ in 3000' intervals, 15 bbl fluid loss, hole in good condition. Circ and condition mud, sweep hole, observe well, Pump slug. MW: 9.6 VISC: 46 PV/YP: 12/12 RUNNING 3-1/2" COMPLETION APIWL: 4.6 Run 3.5" x 5.5" casing. Start cement job. MW: 8.5 VISC: MOVING RIG TO 2L-321 0 PV/YP: 0/ 0 APIWL: 0.0 Continue to pump cement. RIH w/3.5" tubing. Freeze protect tubing. MW: 8.5 VISC: 0 PV/YP: 0/ 0 RIG RELEASED & MOVED TO 2L-323 APIWL: 0.0 ND BOP's and NU master valve and test to 5000%. Rig released @ 0200 hrs. 12/26/98. Date 02/23/99 Well Na 2L~323 Service Type ELECTRIC LINE Desc of Work PREFORATE Supervisor FITZPATRICK Complet I~ Accident r- Injury F Spill l-- Summary Upcoming Job Num 0219991648.1 Unit 8345 AFC AK9757 0 Contractor Key Perso SWS-STEPHENSON Successful r~ Initial Tbg Press o Final Tbg Press 0 Initial Int Csg Press 0 Final Iht Csg Press 0 Initial Out Csg Press 0 Final Out Csg Press 0 PERFORATED FROM 9928' TO 9848' RKB WITH 2.5" HC, 6 SPF, 60 DEG PHASING, DEEP PENETRATING SHOTS. [Perf) Prop 180KNU2T Uploaded to Sar, Date printed: 03/03/99 at: 16:01:10 Date 02/24/99 Well Na 2L-323 Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor FITZPATRICK Complet I-- Accident F- injury F- Spill F Summary Upcoming I-- Job Num 0219991648.1 Unit 8345 AFC AK9757 0 Prop 180KNU2T Uploaded to Sen Contractor Key Perso SWS-STEPHENSON Successful r~ Initial Tbg Press 0 Final Tbg Press 0 Initial Int Csg Press 0 Final Iht Csg Press 0 Initial Out Csg Press 0 Final Out Csg Press 0 PERFORATED FROM 9796' TO 9848' RKB & FROM 9754' TO 9774' RKB WITH 2.5" HC, 6 SPF, 60 DEG PHASING, DEEP PENETRATII SHOTS. (Perf] Date printed: 03/03/99 at: 16:01:28 Date 02/25/99 Well Na 2L-323 Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor FITZPATRICK Complet Accident F- Injury F- Spill F- Summary Upcoming F- Job Num 0219991648.1 Unit 8305 AFC AK9757 0 Prop 180KNU2T Uploaded to Sep Contractor Key Perso SWS-STEPHENSON Successful r~ Initial Tbg Press 250 Initial Int Csg Press 0 Initial Out Csg Press 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED FROM 9746' TO 9754' RKB & FROM 9670' TO 9706' RKB WITH 2.5" HC, 6 SPF, 60 DEG PHASING, DEEP PENETRATII SHOTS. MEASURED BHP @ 9863' RKB: 2355 PSI. (Per0 Date printed: 03/03/99 at: 16:01:44 11-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-323 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,400.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Arco Alaska Inc. North Slope Alaska ASP Zone 4 Kuparuk 2L, Slot 3L-323 3L-323 Job No. AKMM90041, Surveyed: 16 December, 1998 SURVEY REPORT 8 January, 1999 ORIGINAL Your Ref: API-501032028200 KBE-146.10 MWD SURVEY INSTRUMENT Surface Coordinates: 5927634.29 N, 460815.00 E (70° 12' 47.6604" N, 150° 18' 57.6721" W) Survey Ref: svy1318 Sperry-Sun Drilh'n g Services Survey Report for 3L-323 Your Ref: AP1-$01032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -146.10 23.00 0.000 0.000 -123.10 160.90 0.270 37.560 14.80 250.64 0.080 76.770 104,54 341.31 0.410 16.240 195.21 431.83 0.190 359,010 285.73 528.68 0.190 29.090 382,58 589.10 0.070 334.450 443.00 677.50 0.970 121.160 531.39 769.49 2.400 128.160 623.34 857.37 4.280 131.150 711.07 947.40 6.480 131.580 800.69 1038.03 9.290 133.220 890.46 1129.49 12.370 134.490 980.28 1219.72 15.490 131.290 1067.85 1310.26 18.380 127.900 1154.45 1404.51 22.320 125,910 1242.80 1497.16 24.900 127.090 1327.69 1590.63 27.070 126.820 1411.71 1685.00 29.700 127.760 1494.73 1784.18 33.480 128.230 1579.19 1879.05 37,540 128.930 1656,40 1971.18 40.030 128.410 1728,21 2066.11 41.870 129.340 1799.91 2160.16 44.370 132.060 1868.56 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northlngs Eastlngs (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0,00 E 5927634,29 N 460815,00 E 23.00 0.00 N 0.00 E 5927634.29 N 460815.00 E 160.90 0.26 N 0.20 E 5927634.55 N 460815.20 E 250.64 0.44 N 0.39 E 5927634,73 N 460815.39 E 341.31 0.77 N 0.54 E 5927635.05 N 460815.54 E 431.83 1.23 N 0.63 E 5927635.51N 460815.63 E 528.68 1.53 N 0,70 E 5927635.81 N 460815,71 E 589,10 1,65 N 0.74 E 5927635.93 N 460815.74 E 677.49 1.31 N 1.35 E 5927635.59 N 460816.36 E 769.44 0,28 S 3.53 E 5927633.99 N 460818,53 E 857.17 3.58 S 7,45 E 5927630.67 N 460822.43 E 946.79 9,16 S 13.78 E 5927625.06 N 460828.73 E 1036.56 17.57 S 22.94 E 5927616,60 N 460837.85 E 1126.38 29,49 S 35.31 E 5927604.62 N 460850,16 E 1213.95 44.22 S 51.26 E 5927589.81 N 460866.03 E 1300.55 60.97 S 71.62 E 5927572.95 N 460886.30 E 1388.90 80.60 S 97,85 E 5927553.18 N 460912,43 E 1473.79 102.69 S 127.66 E 5927530.94 N 460942.13 E 1557.81 127.30 S 160.39 E 5927506,16 N 460974.72 E 1640.83 154.49 S 196.06 E 5927478.78 N 461010.26 E 1725.29 186.48 S 236.99 E 5927446.59 N 461051,02 E 1802.50 220.85 S 280,05 E 5927411,99 N 461093,90 E 1874,31 256,90 S 325.11 E 5927375.71 N 461138.77 E 1946.01 295.95 S 373.54 E ' 5927336.41 N 461187.00 E 2014.66 337,89 S 422.24 E 5927294.22 N 461235.48 E Dogleg Rate (°/lOOff) 0.000 0.196 0,239 0.416 0.260 0.102 0,265 1,164 1.568 2,148 2,444 3.110 3.377 3.560 3.372 4.244 2.831 2.325 2,827 3,819 4.301 2.726 2.042 3.312 Vertical Section (ft) 0,00 0.00 -0.01 0.02 -0.08 -0.31 -0.44 -0,49 0.20 2,89 8.01 16.45 28,87 46,01 67.69 94.05 126.77 163.80 204.70 249.51 301,42 356,50 414.19 476.40 540.66 ASP Zone 4 Kuparuk 2L Comment Continued,.. 8 January, 1999 - 14:14 - 2 - Dr/I/Quest Sperry-Sun Drilling Services Survey Report for 3L-323 Your Ref: AP1-$01032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 2254.52 48.050 133.130 1933.85 2348.67 51.100 134.520 1994.89 2443.40 53.430 130.850 2052.88 2532.90 54.770 131.640 2105.36 2683.25 57.150 130.180 2189.52 2775.47 60.040 129.590 2237.57 2870.61 62.140 128.400 2283.56 2965.30 65.080 128.780 2325.64 3059.97 65.990 127.800 2364.85 3151.48 66.000 128.270 2402.08 3246.30 66.160 129.270 2440.52 3340.04 66.700 128.740 2478.01 3435.07 67.720 128.660 2514.82 3529.91 65.660 128.400 2552.34 3625.57 66.150 129.080 2591.40 3719.42 64.950 128.790 2630.24 3814.88 64.640 129.670 2670.89 3909.51 65.170 129.600 2711.03 4004.37 63.930 128.160 2751.79 4096.84 63.940 129.690 2792.43 4191.56 64.250 129.360 2833.81 4286.30 64.990 128.970 2874.41 4381.76 66.050 129.530 2913.97 4473.74 66.720 127.830 2950.82 4567.90 64.600 130.640 2989.63 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) 2079.95 383.99 S 472.36 E 5927247.85 N 461285.36 E 2140.99 433.63 S 524.05 E 5927197.95 N 461336.79 E 2198.98 484.37 S 579.12 E 5927146.92 N 461391.60 E 2251.46 532.17 S 633.63 E 5927098.84 N 461445.86 E 2335.62 613.74 S 727.79 E 5927016.79 N 461539.59 E 2383.67 664.20 S 788.18 E 5926966.01 N 461599.72 E 2429.66 716.59 S 852.91 E 5926913.28 N 461664.18 E 2471.74 769.50 S 919.20 E 5926860.03 N 461730.19 E 2510.95 822.89 S 986.83 E 5926806.29 N 461797.55 E 2548.18 874.39 S 1052.68 E 5926754.44 N 461863.12 E 2586.62 928.67 S 1120.25 E 5926699.82 N 461930.42 E 2624.11 982.75 S 1187.02 E 5926645.40 N 461996.90 E 2660.92 1037.52 S 1255.39 E 5926590.27 N 462064.99 E 2698.44 1091.78 S 1323.52 E 5926535.66 N 462132.84 E 2737.50 1146.42 S 1391.64 E 5926480.66 N 462200.67 E 2776.34 1200.11 S 1458.09 E 5926426.62 N 462266.84 E 2816.99 1254.74 S 1524.99 E 5926371.66 N 462333.46 E 2857.13 1309.40 S 1590.99 E 5926316.65 N 462399.17 E 2897.89 1363.17 S 1657.66 E 5926262.54 N 462465.57 E 2938.53 1415.36 S 1722.28 E 5926210.01 N 462529.91 E 2979.91 1469.58 S 1788.00 E 5926155.45 N 462595.35 E 3020.51 1523.64 S 1854.37 E 5926101.05 N 462661.44E 3060.07 1578.61 S 1921.64 E 5926045.73 N 462728.43 E 3096.92 1631.27 S 1987.43E 5925992.72 N 462793.94 E 3135.73 1685.51 S 2053.88 E 5925938.14 N 462860.11 E Dogleg Rate (°/100fi) 3.985 3.429 3.928 1.659 1.776 3.181 2.464 3.126 1.346 0.469 0.979 0.775 1.076 2.187 0.827 1.309 0.895 0.564 1.894 1.486 0.453 0.865 1.232 1.843 3.530 Vertical Section (ft) 608.69 680.18 754.98 827.46 952.01 1030.72 1113.98 1198.77 1284.90 1368.45 1455.11 1541.02 1628.61 1715.68 1802.98 1888.40 1974.77 2060.46 2146.10 2229.15 2314.35 2399.94 2486.81 2571.06 2656.83 ASP Zone 4 Kuparuk 2L Comment Continued... 8 January, 1999 - 14:14 - 3- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3L-323 Your Ref: API-501032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. 4661.80 64.790 128.770 4756.15 64.910 129.310 4850.75 63.630 129.930 4942.94 64.090 131.890 5037.99 64.080 133.220 5131.41 64.600 131.610 5225.27 65.230 132.690 5320.54 65.790 133.000 5414.8o 66.700 132.160 5508.89 66.770 132.04o 5600.89 65.320 130.910 5695.87 65.670 131.480 5787.82 66.170 132.030 5881.69 64.840 130.000 5974.81 65.050 130.270 6068.50 65.260 129.770 6163.62 66.240 129.710 6256.80 66.840 .128.770 6349.39 66.410 130.620 6441.98 66.470 130.430 6536.52 66.660 130.670 6631.8o 64.840 131.170 6729.76 64.890 13o.990 6820.94 65.170 130.450 6914.51 64.910 130.130 Sub-Sea Depth (ft) 3029.77 3069.87 3110.94 3151.56 3193.10 3233.55 3273.35 3312.84 3350.81 3387.97 3425.33 3464.72 3502.24 3541.16 3580.60 3619.96 3659.03 3696.13 3732.86 3769.87 3807.47 3846.60 3888.21 3926.70 3966.19 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3175.87 1739.74 s 2119.19 E 5925883.58 N 462925.13 E 3215.97 1793.53 S 2185.52 E 5925829.44 N 462991.18 E 3257.04 1847.87 S 2251.17 E 5925774.76 N 463056.55 E 3297.66 1902.07 S 2313.71 E 5925720.24 N 463118.80 E 3339.20 1959.88 S 2376.68 E 5925662.10 N 463181.48 E 3379.65 2016.68 S 2438.85 E 5925604.98 N 463243.35 E 3419.45 2073.72 S 2501.87 E 5925547.61 N 463306.07 E 3458.94 2132.68 S 2565.43 E 5925488.32 N 463369.33 E 3496.91 2191.05 S 2628.96 E 5925429.62 N 463432.55 E 3534.07 2249.00 S 2693.10 E 5925371.34 N 463496.39 E 3571.43 2304.69 S 2756.08 E 5925315.33 N 463559.09 E 3610.82 2361.61S 2821.11 E 5925258.07 N 463623.82 E 3648.34 2417.51 S 2883.74 E 5925201.84 N 463686.15 E 3687.26 2473.57 S 2948.18 E 5925145.45 N 463750.30 E 3726.70 2527.95 S 3012.68 E 5925090.74 N 463814.51 E 3766.06 2582.62 S 3077.78 E 5925035.73 N 463879.34 E 3805.13 2638.06 S 3144.47 E 5924979.94 N 463945.74 E 3842.23 2692.13 S 3210.67 E 5924925.53 N 464011.66 E 3878.96 2746.41 S 3276.07 E 5924870.91 N 464076.77E 3915.97 2801.56 S 3340.58 E 5924815.43 N 464141.00 E 3953.57 2857.95 S 3406.49 E 5924758.70 N 464206.61 E 3992.70 2914.85 S 3472.13 E 5924701.46 N 464271.96 E 4034.31 2973.12 S 3538.98 E 5924642.84 N 464338.50 E 4072.80 3027.05 S 3601.63 E 5924588.59 N 464400.87 E 4112.29 3081.90 S 3666.34 E 5924533.40 N 464465.29 E Dogleg Rate (°ll00ff) 1.812 0.533 1.476 1.973 1.259 1.650 1.240 0.658 1.264 0.139 1.935 0.659 0.771 2.425 0.346 0.534 1.032 1.127 1.892 0.199 0.308 1.969 0.174 0.618 0.416 Vertical Section (ft) 2741.71 2827.11 2912.32 2995.07 3080.47 3164.59 3249.53 3336.12 3422.29 3508.67 3592.71 3679.11 3763.02 3848.42 3932.77 4017.79 4104.52 4189.99 4274.97 4359.84 4446.58 4533.43 4622.10 4704.75 4789.57 ASP Zone 4 Kuparuk 2L Comment Continued... 8 January, 1999-14:14 -4- DrlllQuest Sperry-Sun Drilling Services Survey Report for 3L-323 Your Ref: AP1-$01032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 7009.34 63.030 131.760 4007.81 7102.13 63.070 131.930 4049.86 7196.95 63.300 131.240 4092.63 7291.42 63.110 133.140 4135.22 7386.03 62.970 130.640 4178.12 7478.26 63.080 129.960 4219.96 7571.95 62.890 129.290 4262.51 7666.98 62.420 128.320 4306.17 7762.73 62.340 127.340 4350.56 7856.08 62.340 128.050 4393.89 7951.08 63.990 129.160 4436.78 8045.40 63.840 129.550 4478.25 8139.31 65.220 129.280 4518.64 8233.57 65.950 128.970 4557.60 8328.55 66.960 129.790 4595.54 8423.58 67.700 129.120 4632.17 8517.05 67.650 128.770 4667.67 8608.25 66.720 128.650 4703.03 8702.70 67.430 127.620 4739.83 8796.47 67.810 127.800 4775.53 8891.26 66.230 129.030 4812.54 8984.59 64.170 129.620 4851.68 9078.19 61.850 128.610 4894.16 9171.19 59.690 127.310 4939.57 9266.77 57.770 126.890 4989.18 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4153.91 3137.73 S 3730.70 E 5924477.24 N 464529.36 E 4195.96 3192.91S 3792.32 E 5924421.74 N 464590.69 E 4238.73 3249.08 S 3855.61 E 5924365.25 N 464653.70 E 4281.32 3305.71S 3918.09 E 5924308.29 N 464715.88 E 4324.22 3362.01S 3980.86 E 5924251.67 N 464778.36 E 4366.06 3415.17 S 4043.55 E 5924198.18 N 464840.77 E 4408.61 3468.40 S 4107.83 E 5924144.62 N 464904.78 E 4452.27 3521.30 S 4173.61E 5924091.38 N 464970.28 E 4496.66 3573.33 S 4240.62 E 5924039.00 N 465037.02 E 4539.99 3623.89 S 4306.04 E 5923988.10 N 465102.18 E 4582.88 3676.78 S 4372.28 E 5923934.87 N 465168.14 E 4624.35 3730.50 S 4437.78 E 5923880.81 N 465233.36 E 4664.74 3784.33 $ 4503.28 E 5923826.64 N 465298.58 E 4703.70 3838.49 S 4569.87 E 5923772.14 N 465364.88 E 4741.64 3893.73 S 4637.17 E 5923716.54 N 465431.90 E 4778.27 3949.45 S 4704.87 E 5923660.47 N 465499.31 E 4813.77 4003.80 S 4772.12 E 5923605.77 N 465566.28 E 4849.13 4056.37 S 4837.72 E 5923552.86 N 465631.60 E 4885.93 4110.09 S 4906.14 E 5923498.79 N 465699.74 E 4921.63 4163.12 S 4974.73 E 5923445.40 N 465768.06 E 4958.64 4217.34 S 5043.11 E 5923390.83 N 465836.15 E 4997.78 4271.03 S 5108.65 E 5923336.81 N 465901.41 E 5040.26 4323.65 S 5173.35 E 5923283.85 N 465965.84 E 5085.67 4373.57 S 5237.33 E 5923233.60 N 466029.56 E 5135.28 4422.85 S 5302.48 E 5923183.98 N 466094.45 E Dogleg Rate (°ll00ff) 2.513 0.169 0.693 1.806 2.360 0.668 0.669 1.033 0.911 0.674 2,026 0.404 1.492 0.830 1.326 1.015 0.350 1.027 1.255 0.442 2.051 2.281 2.659 2.623 2.044 Vertical Section (ft) 4874.76 4957.43 5042.02 5126.27 5210.54 5292.73 5376.20 5460.59 5545.37 5627.99 5712.73 5797.44 5882.22 5968.04 6055.11 6142.79 6229.24 6313.29 6400.23 6486.88 6574.11 6658.82 6742.21 6823.32 6904.91 ASP Zone 4 Kuparuk 2L Comment Continued... 8 January, 1999 - 14:14 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 3L-323 Your Ref: AP1-$01032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9361.50 55.960 129.110 5040.96 5187.06 4471.67 S 5364.99 E 5923134.84 N 466156.71 E 9455.59 53.660 131.380 5095.19 5241.29 4521.32 S 5423.69 E 5923084.88 N 466215.15 E 9550.10 53.810 130.640 5151.09 5297.19 4571.32 S 5481.19 E 5923034.58 N 466272.39 E 9643.76 53.890 130.760 5206.34 5352.44 4620.64 S 5538.52 E 5922984.97 N 466329.47 E 9737.10 54.780 130.930 5260.76 5406.86 4670.24 S 5595.89 E 5922935.07 N 466386.58 E 9830.29 55.300 130.860 5314.16 5460.26 4720.24 S 5653.62 E 5922884.78 N 466444.05 E 9924.42 55.800 131.210 5367.41 5513.51 4771.20 S 5712.17 E 5922833.51 N 466502.33 E 10016.77 56.290 130.890 5418.99 5565.09 4821.50 S 5769.94 E 5922782.91 N 466559.84 E 10111.84 56.650 130.410 5471.51 5617.61 4873.13 S 5830.07 E 5922730.97 N 466619.70 E 10206.68 57.180 130.550 5523.28 5669.38 4924.71S 5890.51 E 5922679.07 N 466679.87 E 10329.57 57.530 131.210 5589.57 5735.67 4992.44 S 5968.74 E 5922610.94 N 466757.75 E 10400.00 57.530 131.210 5627.38 5773.48 5031.58 S 6013.45 E 5922571.57 N 466802.25 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°ll00ft) 2.739 3.140 0.651 0.134 0.965 0.561 0.613 0.603 0.566 0.572 0.534 0.000 Vertical Section (ft) 6984.18 7061.06 7137.25 7212.87 7288.69 7365.05 7442.66 7519.25 7598.49 7677.95 7781.41 7840.81 ASP Zone 4 Kuparuk 2L Comment Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 129.920° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10400.00ft., The Bottom Hole Displacement is 7840.81ft., in the Direction of 129.920° (True). Continued... 8 January, 1999 - 14:14 - 6 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 3L-323 Your Ref: API-501032028200 Job No. AKMM90041, Surveyed: 16 December, 1998 Arco Alaska Inc. North Slope Alaska ASP Zone 4 Kuparuk 2L Comments Measured Depth (ft) 10400.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5773.48 5031.58 S 6013.45 E Comment Projected Survey 8 January, 1999 - 14:14 - 7- DrillQuest TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 15, 1998 Paul Mazzolini Drilling Team Lcadcr ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kupamk River Unit 2L-323 ARCO Alaska Inc. Permit No: 98-251 Sur Loc: 212'FNL, 836'FEL Sec. 22, TION, R7E, UM Btmholc Loc. 29'FSL, 107'FEL, Sec. 23, T10N. R7E. UM Dear Mr. Mazzolini: Enclosed is thc approved application for permit to drill thc above referenced well. Annular disposal of drilling xvastcs will not be approved for this well until sufficient data is submittcd to ensure that thc requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confimmd by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to thc Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which arc pumped doxvn the surface/production casing annulus ora well approved for annular disposal on Drill Site 2L must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space ora single well or to use that well for disposal purposes for a period longer than one year. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Bloxvout prevention equipment (BOPE) must bc tested in accordance xvith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given m field inspector on thc North Slope pager at 659-3607. David W. Johns~Wn~-- ~~.~.~.~.~.~~ ~ Commissi'Ou~~ ~ BY ORDER OF THE COMMISSION dlf/Enclosurcs cc: l)epartmcnt of Fish & Game, I labitat Section w/o encl. l)¢partment of l'hwiromnental Conservation w/o t,mcl. Phone: 263,,4612 Fax To: Diana From: Sharon AIIsup-Drake Fax; 9-907-276-7542 Date-' December 15, 1998 Phone: Patios: 1 Ro: 2L-323 Permit to Drill CC= [] Urgent [] For Review [] Please Comment [] Please Reply [] Please Recycle ,Comments: Diana - Please consider this a request to expedite the processing of the Permit to Drill for 2L-323. We will be finishing up the ddlling on 2L-315 much earlier Wan expected. I know this is short notice but I would appreciate your help in processing this permit by this afternoon. Thanks, Sharon STATE OF ALASKA AL/A.~..A OIL AND GAS CONSERVATION COMe. SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI ' Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 212' FNL, 836' FEL, Sec.22, T10N, R7E, UM' Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 354' FSL, 494' FEL, Sec. 23, T10N, R7E, UM 2L-323 #U-630610 At total depth 9. Approximate spud date Amount 29' FSL, 107' FEL, Sec. 23, T10N, R7E, UM 12/16/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2L-325 10409' MD 29' @ TD feet 30' @ 100' feet 2560 5783' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 65.21 ° Maximum s,rrace 1357 psig At total depth (-I-VD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 2569' 28' 28' 2597' 2300' 1) 30 Sx Arcticset III L & 240 Sx Class G 2) 240 sx AS I I IL & 60 sx AS 6.75" 5.5" 15.5# L-80 LTC-M 9412' 28' 28' 9440' 5227' 280 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 969' 9440' 5227' 10409' 5783' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Siz'~ii~ F /''~ ~! i'';''~' ? ~ ~'~:~ented Measured depth True Vertical depth Structural ~"~.~ ~ ; ~) ~' Conductor Surface Intermediate i" :-?(~' i ~" ~¢~"' Production ,._ ....... Liner ORIGINAL Perforation depth: measured ,~ .... '~,,f,~P~$' ...... L;O[:G,' -~ ,;'~Fp'qi'~iSSiO(! ! true vertical .pj~b~,¢. 0ii & Anchors~d-'-z 20. Attachments Piling fee X Property plat F BOP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Time vs depth plot [--' Refraction analysis F Seabed report F 20AA025.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~,_~_, ~r~~'.~ Title Drilling TeamLeader Date I Alii ~ Commission Use Only PerrnJ.t Npmber I number i Approval date J See cover letter tor ¢-2.G1 50- lO.3 - o..2-,? /,¢--i.¢ -- _ other requirements Conditions of approval Samples req~-ired E] Yes ~ No Mud log required F' Yes [~ No Hydrogen sulfidemeasures F' Yes J~ No Directional surveyrequired ~ Yes F' No Required working pressure for BOPE [--' 2M F Q F 5M r- 1OM [-- 15M Other: t)i-;i~il;3, i '-';~u~' . by order of Approved by David W. Jo[l;is[on Commissioner the commission Date 10-401 Rev. 7-24-89 ARCO Alaska, Inc. Post Office Box 100366. Anchorage, Alaska 995iur=0360 December 14, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-323 Surface Location: 212' FNL 836' FEL Sec 22 T10N R7E, UM Target Location: 354' FSL, 494' FEL Sec. 23, T10N, R7E, UM Bottom Hole Location: 29' FSL, 107" FEL ,Sec. 23, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-323, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H=S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H=S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johns'-q Application for ~.r__,'mit to Drill Page 2 KRU 2L-323 -~ 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration /Tarn Development Group Attachments cc: KRU 2L-323 Well File ARCO Alaska, Inc. GENERAL'~RILLING AND COMPLETION PRO~CEDURE KUPARUK RIVER FIELD ~ PRODUCER KRU 2L 323 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +!000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, su--Effi-Eient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. Secure well. Rig down and move out. !3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING'rFLUID PROGRAM, PRESSURE CA~CCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-323 Drilling Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be ~2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: The nearest well to 2L-323 is 2L-325. The wells are 30' from each other at a depth of 100'. ARCO Alaska, Inc. Drilling Area Risks: The primary risk in the 2L-323 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-323 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-323 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDVV~s open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe -I'VD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure = 2,810 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi ARCO Alaska, Inc. ~ ~o~1~o,~o ~s,I ~,~ Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Created by Rixse For: T Br-B,fieldI I Slruoture: Torn Drill Slte 2L Well : 525 Del. I~otted: 4-D~-98 P~ R~r~n~ ~ 325 Veto;on I,.~ v.~, ~..,. ..... ~iiB (~'n 141)'[ [Ffeld : ~orn Development Field Location : North Slope, 145'1 ~ I East (feet) -> 400 800 1200 1600 2000 2400 2800 5200 3600 4000 4400 4800 5200 5600 6000 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 t I I I I I I I II II I I II I I II I I II I I I.-- r'~ Base Permafrost KOP TVD=700 TMD=700 DEP=O [ [ "~op West Sok Sands 3.00 SURFACE LOCATION: 212' FNL, 8a6' VEL ~xs: West SOk Sand5 129.98 AZIMUTH 9. SEC. 22, TION, R7E ~ 5/8 Coslng Pt 1500B/ PER"AFRO~ WD=1195 ~MD=1201 DEP=65 7337'(TO TAROET) ' r/ ~K SNDS WD=1239 TMD=1246 DEP=78 [21.00 27.00 DLS: 3.00 deg per 100 ft 33.00 9.00B/ W SAK SNDS WD=1896 TMD=1992 DEP=421 ~5.00 . ~5~.00 7.00 7 5/8" CSG ~ WD=2500 TMD=2597 DEP=867 ' ~'OOE~ WD=2434 TMD=2874 DEP=1109 2470 TMD=2960 DEP=1187 ~ . . MAXIMUM ANGLE ~ I TARG~ LOCATION: I . ~ 6b~-gl-- DEG c50 WD=3796 TMD=6122 DEP=4058 I 354' FSL~9¢ FELI ~ ~ J S~ION. RTE j ~lceberg Internal ~ TA~G~ __ ' Begin Angle Drop C40 WD=4147 TMD=6959 -nd Angle Drop T~ 35 ~D - Casing ~ ICEBERG INTERVAL WD=4942 TMD=8855 5or BEGIN ANGLE DROP 1VD=4973 TMD=8929 DEP=6607 ,, 64.00 DLS' 2 O0 de,~ per 100 ft END ANGLE DROP TVD=5227 TMD=9440 DEP=7049 "-,., 60.00 ' ' ~ T4 TVD=5246 TMD=9472 DEP=7075 ~_56.00 T3 TOP/BERMUDA TVD=5542 TMD=9640 DEP=7212 ~ TARGET - MID BERMUDA TVD=5429 TMD=9791 DEP=7337 ~ · T2 - B/BERMUDA TVD=5515 TMD=9941 DEP=7459 ~ ' TD - CASING'PT TVD=5783 TMD=10409 DEP=7842 "~ TARGET ANGLE 55 DEG [ i i I i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 ,3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Vertical Section (feet) -> Azimuth 129.98 with reference 0.00 N, 0.00 E from slot //323 lOOO 15oo 2000 2500 ,,.-,, I 5500 4000 ',, 4500 5000 5500 ID LOCATION: 29' FSL, 107' FEL SEC. 25, TION, R7E Alaska, Inc Structure : Tam Drill Site 2L Well : 325 [F~eld : Tarn Development Field Location : North Slope, Alaska ....WELL PROFILE DATA ~ m o.~ o.~ ~.~ o.~ o~ o~ o.~ o.~ 320 330 ~x340 \ \ \ 350 TRUE NORTH 0 10 20 30 40 300 310 50 :300 rio 2100 290 28O 80 270 260 25O ~o0 9O lO0 1700 %110 240 120 230 130 22O 210 2300 0 Normal Plane Travelling Cylinder - Feet 190 ',, 2100 150'., 140 160 180 170 All depths shown are MeasUred depths on Reference Wel Alaska, LoCation : No~h Slope, Alaska 80 8O 120 160 200 24O 280 320 I V 360 400 480 520 560 600 64O 680 80 40 East- (feet) -> 0 40 80 120 160 200 240 280 320 ,560 4.00 4.40 480 520 560 80 ::°o°oi ~ .,c. '0' ~,500~3~C1'~- ~ 70n "-- ... 1100 -- -- -- -- ---=_ 1500 o --5o0 . oo '~" - -- - - *'-- ~ ~.500 .~ 1 .,, ~.~.1200 iD 1000 q~ 1 O0 800 ,oo . oo 1100 .~ \_1100 ~1100 1~0~_ 1400~-~ 1200~ %~X ' ~- 1500~ ~. 1~~ 1100 1300'., ~ 200 '. ~2~ 1 600' ~x ~ x ~o~ ~ ~- ~Joo ~°3k ,~o( . .~o ~~U~ ,~oo~ ,~0 X -X. '~x ~~ 160 1 k ~ %1700 200 ~ ~2100 1500-\ '~ \ X~1800 \ 1 600% '" \ \ \ ',, 1900 x. 1 700 \ "'%2000 1900 600 2200%x,~x 0 ~ 280 ~ 520 ...+. % , 3~o V -~ 2~00 x 4O0 4-80 520 560 6OO 40 80 640 2 680 120 160 200 240 280 520 560 400 440 480 520 560 East (feet) -> A-gC0 Alaska, Inc; c,~ w n~h For: BRAE{SFIELD Structure : Tarn Drill Site 2L Well : 323 ~ ~.,..~, ~ ~z~ ~ ~ ] Fie d : Tarn Deve opmenf Field Location : No~h Slope, Alaska East (feet) -> 4aO 500 600 700 800 900 1000 11 (30 1200 1300 1400 1500 1600 1700 1 BOO 1900 X . % 2500 ~ ~ .... ~ 1800~ X ~ 2200 ~ ~ x. 2~~ ~/uu ~ 500 ~ ~ _ 1800% x % - ~ ~ ~. x% ~x '%2600 ~~ ~ '. ' ~.2~0 ''5'. ~ ' ' 800 90O 1000 1100 1200 1300 I V 1~o 1500 1600 1700 1800 1900 2000 2100 2200 2200 'x \ %2500 xx. ~ ~-, 2900 ~ x, ~'~-~.2000 2500 2100%\ \ 30 ~ ~ 2600 2400 25OO 2600 2700 x. x. ~ ~' ,...2100 ' 2200~' ~. ~%.2700 ..,. ~ -,. ,,, 3200 -~ ~ \ 3300 ~ ~' 2300 2800 '~ ~ ~ ~ ~ ~%2200 x xx x, 2900 350~ 2~oo~ xx x ~ x 3000 2500%' x 2800 ~ ~ 29OO 5000 5100 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 400 500 600 700 800 900 1000 11 O0 1200 t 300 14.00 1500 1600 1700 1800 1900 Easf (feet) -> 300 400 500 6OO 700 800 - gOO 1000 1100 0 r- 1200 1500 I 1,,,oo V 1500 1600 1700 1800 1900 2000 2100 22OO ructure : Tarn Drill Site 2L Well : 325 Id : Tarn Development Field LoCation : North Slope, 1200 1600 2000 24OO 2800 3200 5600 East (feet) 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 I I I I I I I I I I I I I I I I I I =1 I I I I I I I I I I I I ' 2DO0 %* l~q) ~O0/ 27~0 ~DOO ' leO0 X~ 500 ~ 5700 k ~Tmn X_4900 ~ ~.' ~o ~3~oo ~ ~ 2000 ~ ~93~ .... 31 d~' . 5100 , 3~°°'%1-~. ~ 2,00 ,.~ ,s~oo 7 2800 9OO O0 5100 500 5200 4500~ ~'~ 3~00 x _ 4500 X' ~ 59~-~ ~ 350U 4700 ~ 40OO ~ 440O -~- 4800 0 5200 I 5600 6000 640O 6800 7200 7600 8000 4700 "'" \ ,.4100 ~ ,,. 3700 4900 % 'x 4900 x x % ~' ~.4300 -. 5100% ~ ,.3900 51 O0 '~ '" 5300'"' ..~' ~%,4500 5~00 5500" -. 5500 57o~' 8400 "41 O0 4900 -., 5100 5300"%% I I I I I [ I I I I I I I I I t I I I I I I I I I I I I I I I 1200 1600 2000 2400 2800 5200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 East (feel) -> 5600 4000 4400 5200 5600 - 6000 6400 6800 7200 7600 8000 84OO ARCO Alaska, Inc. Tarn Drill Site 2L 323 slot #323 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref= 323 Version #5 Our ref= prop2889 License = Date printed : 7-Dec-98 Date created = 17-Mar-98 Last revised : 4-Deo-98 Field is centred on nT0 12 49.742,w150 18 33.%14 Structure is centred on n70 12 49.742,w150 18 33.%1~ Slot location is nT0 12 47.660,w150 18 57.672 Slot Grid coordinates are N 5927634.254, E 460815.003 Slot local coordinates are 211.65 S 835.61 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is T=ue North Object wellpath Last revised Distance M.D. PMSS <0-9200'>,,325,Tarn Drill Site 2L 19-Nov-98 30.0 100.0 PMSS <0-9210t>,,305,Tarn Drill Site 2L 2-Dec-98 269.9 100.0 PMSS <0-11140>,,313,Tarn Drill Site 2L 25-Nov-98 150.1 280.0 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 16-Nov-98 88.1 380.0 PMSS <0-7650'>,,Tarn#2,TARN #2 7-Dec-98 86.3 7840.0 PMSS < 0 - 6150~>,,TA~N#4,TARN #4 13-Nov-98 11726.9 10408.8 PMSS < 2250 - 7162t>,,3A,TARN #3 13-Jul-98 9376.4 '7320.0 Closest approach with 3-D Minimum Distance method Diverging from M.D. 100.0 7460.0 280.0 380.0 7840.0 10408.8 7320.0 ARCO Alaska, Inc. Diverter Schematic Doyon 14'1 21%" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT MANUAL GATE VALVE ~ [--J KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE L] w/hydraulic actuator ! DSA 13-5/8" 5,000 psi W~ x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple D;~I~ .C~~ /§h.a~. ~,(~,~y/~,VE w/pipe rams on top and blind rams on bottom / 1 3" 5,000 psi WP Shaffer GATE VALVE 1;/hydraulic actuator CHOKE LINE 13-5/8" 5,000 psiWP DRILLING SPOOL I__I ~ w/two 3" 5M psi WP outlets I~SiNGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. GENERAL ~,~ILLING AND COMPLETION PRO~-EDURE KUPARUK RIVER FIELD ~ PRODUCER KRU 2L 323 1. Move in and rig up Doyon 141. . , Install diverter system. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job, NOTE: TAM Port Collar will be placed in the 7-5/8" casing +!000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). . , Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present aboVe the Tarn, su--Eff~ient cement will be pumped for isolation in accordance with 20 AA© 25.030(d)(3)(C). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. ]2. Secure well. Rig down and move out. ]3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING I-~CUID PROGRAM, PRESSURE CAECULATIONS, AND DRILLING AREA RISKS Well KRU 2L-323 Drilling Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System- Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the prodUction hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be ,,-2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a 'i-VD of 5,100'. Well Proximity Risks: The nearest well to 2L-323 is 2L-325. The wells are 30' from each other at a depth of 100'. Drilling Area Risks: ARCO Alaska, Inc: The primary risk in the 2L-323 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300'-I-VD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-323 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-323 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure - (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure - 2,810 psi This pressure is conservative, since frictional losses while pumping have not been' taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 Psi ARCO Alaska, Inc. I 3~"1 g.3 L-80 l'~'2 ~u~ Modj10,530 psiI s,~-i ps, I~0,~0 psi1 8,~3~ psiI Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 400 800 1200 ! 6OO ~) 2000 a. 2400 O. ~800 ~) 3200 =~ 3600 0 ~ RKB ELEVATION: 145' 4800 5200 5600 6000 I ARCO Alaska, Inc. Creot~ by R~x~ For:. T Braeefleld1 I Slruolure: Torn Drill Slt~ 2L Well : 323 I ~ R~w.~ ~ 323 ~ ~, East 0 500 1000 15~ 2000 2~ 5000 55~ 4000 45~ 5000 5500 6000 65~ KOP WD=700 TMD=700 DEP=O I 3.00 SURFACE LOCATION: I 212' FNL, 836' FEL 9. SEC. 22, TION, RTE 15.00 B/. PERMAFROST '1¥D=1195 TMD=1201 DEP=65 T~ WSAK SND5 'IVD=1239 TMD=1246 DEP=78 21.00 27.00 DLS: 3.00 deg per 100 ft 33.00 39.00B/ W SAK SNDS '[VD=1896 TMD=1992 DEP=421 45.00 51.00 57.00 7 5/8" CS(; PT TVD=2500 TMD=2597 DEP=867 iS'OOEoc WD=2454 TMD=2874 DEP=1109 C80 TVD=2470 TMD=2960 DEP=1187 (~Tose Permofros! ap West Sok Sands ",~s,,e West $ok Sands '~7 5/8 Cosing Pt C50 129.98 AZIMUTH 7337' (TO TARGET) C40 MAXIMUM ANGLE 65.21 DEG C50 WD=3796 TMD=6122 DE C40 1VD=4147 TMD=695g DEP=4818 TARGET LOCATION: 354' FSL. 494' FEL SEC. 25. TION. R7E TARGET WD=5429 TMD=9791 DEP=7357 SOUTH 4714 EAST 5622 Iceberg Interval Angle Drop Drop T;3 - Top Bermuda Target - M~d T2 - Base x.C.3§ TI] - Casing ICEBERG INTERVAL TVD=4942 TMD=8855 · BEGIN ANGLE I]ROP WD=4973 TMD=8929 DEP=6607 ,,. 64.00 DLS' ~ O0 de,, END ANGLE DROP WD=5227 TMD--9440 DEP=7049 ~ 60.00 . ~.. ~ per 100 ft T4 TVD=5246 TMD=9472 DEP=7075 '"-%.56.00 ' T3 TOP/BERMUDA TVD=5342 TMD=9640 DEP=7212 TARGET ANGLE TARGET - MID BERMUDA TVD=5429 TMD=9791 DEP=7337 '~ · 55 DEG T2 - B/8£R"UDA TVD--§515 TMD=-""41 DEP--74§g ~ ' , . ' C35 1VD=5611 TMD=10109 DEP=7597 ' TD - CASING'PT TVD=5783 TMD=10409 DEP=7842 "~ i ! i ! i [ i i i i i ! i i ! ! ! i ! i i ! i ! ii i 400 800 1200 1600 2000 2400 2800 3200 ;3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Vertical'Section (feet) -> Azimuth 129.98 with reference 0.00 N, 0.00 E from slot //;325 50r ,, 1ODD 1500 U3 2OO0 O. --I- 2500 ,,-.,, =.,I- 5000 ~ I V 5500 4000 - 4500 5000 5500 ITD LOCATION: 29' FSL, 107' FEL SEC. 23, TION, R7E 0 Alaska, Structure : Tarn Drill Site 2L Well : 325 Field : Tarn Development Field Location : North Slope, Alaska WELL PROFILE DATA Ta~d 2~.-.323 #Nd. i~ T~. & EM od' J.IMd 520 330 340 \ \ \ 350 \ TRUE NORTH 0 10 2O 310 3OO 3O 4O 300 290 280 8O 270 260 25O 24O lO0 9O 100 1700 ~110 120 230 220 210 2300 O0 190 130 180 170 ~=~oo 140 \ 150'.~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well IStructure : Tarn Drill Site 2L Well : 325 Field : Tarn Development Field Location : North Slope, Alaska At, CO Alaska, Ine':-' 80 40 80 120 160 200 240 280 320 4OO . 480- 52O - 560 - 6O0 640 68O 8O 4O 1 11 East- (feet) -> 0 40 80 120 160 200 240 280 320 550 400 440 480 520 560 I I I I I I I I I I I I I I I I I~I I I I I I I I II I I ' ~0 ~ e ee~ 8 8-~e~ 700 ' 1600o~ _---% .-. (~) ~0 ~ ~ ~ ~00 1000 11 O0 .... I ~ ~ ~ 500 ~ ~900 ~ ~ ~ ,~ 40 ~ ~ ~Ouu -~ ~ 7nO ~ ~ ~1100 ~ ~ ~ ~ 1500 ~ ~ e ~o~5°° ~oo~ ~oo9~ ~ ~ ..~ - -~2oo - - ~ - ~ 500 ~ % 900 ~900 1200~ ~'~ ~ ~oo ~ ~ 1400 1000 ~ ~- 1000 ~--1000 .... · -~ 1300~~ ~ ~ ~ uu x_X 1100 x-1100 l~O~x_ 1400~~ --__l~Ok~ J ~ 140~x ' x .... 1700 ' x ~4zuu ~3o( 13oo ~5o~ ~&~ ~7oo~. \ %1 700 . % ,. ~. 1500 150 \ -, -. ~ ,. 200 \ ,,, ~ ~,21 O0 \ "-%1800 \ -,, \ 1600~' \ \ \ 1900 600 % 1900 ~ ~ 280 \ \ x. ~ 320 \ ~ 2000 1 700 \ .,. 360 '1 2100 '" % 400 \ \ \ . \ \ · \ 1800~' \ 480 - 520 % 560 East (feet) -> ' 6OO 640 , , , 680 480 0 Alaska, Inc: Structure : Tarn Drill Site 2L Well : 525 IField : Tarn Development Field Location : North Slope, Alaska 500 400 500 600 700 800 900 1000 1100 1200 1300 I V 1~o 1500 1600 1700 1800 1900 2000 2100 2200 East (feet) -> . 400 500 600 700 800 900 10O0 11 O0 1200 1.900 1400 1500 1600 1700 1800 1900 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ' ~00 - ~ ~,21oo ~'- '-, 23oo-"~,"-, ""'--.2500- ~. x x. '.. 2500 ~" ~ .... " 1800~' '~, 2200 ~ % ... ~ '.~ 1/UU \. '~ ~ '% 2600 ~ ~ ' ~. \ -.. ~. 2500~ .~ 1800 19oo~ x ~ ~.. ~ ..... '"-.~ ~ x x ".". 2700 "'-~. ' ~ ', '%2400 ' ''~.~ ~. . ~~ 2ooox b. ~'.., ___~.,__ x, 2200 ~- ~ 0u ~ \ .. ,.: \ \, '\'x~.2000 . XX~ 2300 21 O0~' -. \, 3000~. ~ ~ '~ 2600 ~ .-,. ~ % \ 3100~' -. %2400 ~_ ~ ~ ~ _2100 . ~ 2200' x \~.2700 ~' ~2500 Xx X\ 330~" X ~' ____~'~ '~ 2800 ~ ~. '- ~. "~2200 2500x N 2600 '~ ~' ~ '-o 2,00 .. 7 x ~. 1400 'X~2 O0 ~ ,m. 1500 2800 2500~' '"~_ \ ' 1600 50 ~ 1700 00~ 1800 . 1900 2000 2100 i ' 400 500 ~oo 7OO I 800 90O 1000 1100 0 1200 1300 ('D --I-. I i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i 2.200 400 500 600 700 800 900 1000 11 O0 1200 t500 . 1400 1500 1600 1700 1800 1900 East (feet) -> " . [ANCO Alaska, Inc Structure : Tarn Drill Site 2L --~ Well : 525 [Field : Tarn Development Field LoCation : Nor'Ih Slope, Alaska East (feet) -> 1200 1600 2000 2400 2800 5200 ..1600 4000 4400 44500 5200 5600 6000 6400 6800 7200 7600 I I I I I I I I I I I I I I I .I I I I I I I I I I I I I ' 1200 ~ 4500 .4500 4700 1200 ~'~. 29'0~ 3500 - ~ ~ 5500 -%'~-~'~ ~ ~ -- --~ ~ --.= 4900 ' ~ .-~oo/ 27oo~- x N.~. '"-~'/-..~..5_00 ~"~-~ 3700 \. 5700 ' ' 4900 ' 2700' 'X 330Q 4"Lg, U 2900'"' ~-"%,._ 'X ,oo oo., 5 0 , oo° l~900 -~ 5600 5600 4500'--'~,"',,."~'~_ 3500 -~ 4500 '~' -, 59-0~ -~ 3500 \. ,, -~ 500~ . 4700 ~, \ 4700 ~' ~' ~ 4000 \ ,,. 4100 ~. -,. 5700 4900 % '~ 4900 \ \ 5100", 5100 ~ x ~,590~ 5300'~' -,,\ N%4500 Sa00 55o0" '~ .x ~ ~,aoo ~ =,,4100 -, N% 5200 % 4900 5600 % ,~. 5100 5600 5300' 6000 %'% 6000 6400 6400 6800 7200 7200 7600 7600 8000 - 8000 8400 8400 i s I I I I I I I I I I I I I I I I I I I I I I I I t I I I I 1200 1600 2000 2~t00 2800 .t200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 East (feet) -> ~oo 44OO ~00 5200 0 ~oo ~- 68OO ARCO Alaska, Inc. Tarn Drill Site 2L 323 slot #323 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : 323 Version 95 Our ref : prop2889 License : · Date printed : 7-Dec-~S Date created : 17-Mar-98 hast revised : 4-Dec-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 12 49.742,w150 18 33.414 Slot location is nT0 12 47.660,w150 18 57.672 Slot Grid coordinates are N 5927634.254, Z 460815.003 Slot local coordinates are 211.65 S 835.61 W Projection t~e~ alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object we11path Last revised Distance PMSS <0-9200'>,,325,Tarn Drill Site 2L 19-Nov-98 30.0 PMSS <0-9210~>,,305,Tarn Drill Site 2L 2-Dec-98 269.9 PMSS <0-11140>,,313,Tarn Drill Site 2L 25-Nov-98 150.1 329A PMSS <2506 - 6190~),,329A,Tarn Drill Site 16-Nov-98 88.1 PMSS <0-7650'>,,Tarn#2,TARN #2 7-Dec-98 86.3 PHSS < 0 - 6150'>,,TA~N#4,TARN %4 13-NOV-98 11726.9 PMSS < 2250 - ?162~),,3A,TARN #3 13-Jul-98 9376.4 Closest approach with 3-D Minimum Distance method 100.0 100.0 280.0 380.0 7840.0 10408.8 Diverging from M.D. 100.0 7460.0 280.0 380.0 7840.0 ' 10408.8 ?320.0 - ARCO Alaska, Inc. Diverter Schematic Doyon '141 21%" 2,000 psi wP DRILLING SPOOL w/16" Outlet Flowline ~ I 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 '13-518" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT I J I ~ I I b I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple D~I~ _°EPsJ' - /§h.a.J(. ~.(:~¢s~ ~Ib,VE w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE MANUAL GATE VALVE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE L 1 w/hydraulic actuator Fi J / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP w/hydraulic actuator [~~ CHOKE LINE ~ ~ % 3" 5,.0.0.q psi WP OCT F._i '~MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL bl'~,,~ w/two 3" 5M psi WP outlets I LE 13-5/8" 5,000 psi Wp, I HYDRIL MPL BOP wi pipe rams ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510:¢d60 December 14, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-323 Surface Location: 212' FNL 836' FEL Sec 22 T10N R7E, UM Target Location: 354' FSL, 494' FEL Sec. 23, T10N, RTE, UM Bottom Hole Location: 29' FSL, 107' FEL Sec. 23, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-323, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H=S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H~S. The following are ARCO's designated contacts for reporting 'responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AdanticRichfieldCompany David W. Johns~'-~ Application for [- .... Hit to Drill Page 2 KRU 2L-323 ..... ~ 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-323 Well File ARCO AiaSkal incl {~ ~-~ ALPINE DISBURSEMENT ACCOUNT CHECK.u~... 249001498 ~ P.Q. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE NOVEMBER 19, 1998 0990337 VOID AFTER 90 DAYS The First National Bank of ChlCago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville, Kentucky EXACTLY **********'100 DOLLARS AND O0 CENTS $**********'100.00 TRACE NUMBER: 249001498 ,' ;~ h qOO ], !., q,o,," ~-'OP, 3, qo [, 8 F-, 2,,' oqqo55 ?"' WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1 COMPANY . 3. 4 5. 6. 7. 8. 9. 10. 11 /~ DA,I'E 12. 13. ENGINEERING GEOLOGY _?_~,:::~_ .22 ~~'' INIT CLASS _/~ z/-~,,y GEOL · Permit fee attached ....................... N Lease number appropriate ................... N WELL NAME/~'~" ~/'-'"" -~ ,~ PROGRAM: exp [] dev/~ redrll [] serv [] wellbore seg II ann. disposal para r_e.!/,~ AREA ~,,~,"C~ UNIT#. /',//~__~___ ON/OFF SHORE C~,'~. Unique well name and number ................. Well located in a defined pool ................ Well Iocaled proper dislance from drilling unit boundary. . . Well located proper distance from other wells .......... Sufficient acreage available in drilling unil ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued wilhout conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... APPR 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17 CMi vol adequate to tie-in long string to surf csg ........ 18. CMI will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25 BOPEs, do they meet regulation ................ 26. BOPE press ratihg appropriate; test to ~'(30~::> psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~N (~N 30. Permit can be issued WIG hydrogen sulfide measures ..... YYY,.~-~ , /o ..................................................................................................................... 31. Data presented on potential overpressure zones ....... Y --- 32. Seismic analysis of shallow gas zones. ' /,~ i~__~__, ..................................................................................... ,?"/. 33. Seabed condition survey (if off-shore) ............. 34. Contacl namelphon,e.for weekly progress reports ....... Y N ............................................................................. [exploratory Gray] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminale freshwater; or cause drilling waste. ·. to surface; (C) will nol impair mechanical integrity of the well used for disposal; (I)) will nol damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UlC/Annular JDH '-~"'- COMMISSION: DWJ '"J'~"-.~_~.__~,, ,/~ RNC - ~ , Comments/Instructions: M cheldlsl ~,';v 05/2919B 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Jun 15 09:48:34 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-90041 B.HENNINGSEN R. SPRINGER RECEIVED !999 2L-323 501032028200 ARCO ALASKA, Alaska Oil & ( as Co s. Comm' ion And ora e INC. SPERRY-SUN DRILLING SERVICES 15-JUN-99 22 10N 007 212 836 146.10 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 144.60 117.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2602.0 6.750 10400.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA R3~Y (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 12/30/98. MWD DATA IS PDC. 6. MWD RUNS 1 & 2 REPRESENT WELL 2L-323 WITH API#: 50-103-20282-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10400'MD, 5773'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY) TNPS = COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COI/NT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY COMPENSATED (LOW COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT BIN). POROSITY LOG PROCESSING PAP~AMETERS: HOLE SIZE: 6.75" MUD WEIGHT: 9.1 TO 9.7 PPG MUD SALINITY: 250-450 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2557 5 PEF 2592 0 DRHO 2592 0 RHOB 2592 0 FCNT 2592 0 NCNT 2592 0 NPHI 2592 FET 2592 RPD 2592 RPM 2592 RPS 2592 RPX 2592 ROP 2612 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: STOP DEPTH 10345.0 10323.5 10323 5 10306 0 10306 0 10306 0 10352 0 10352 0 10352 0 10352 0 10352 0 10400 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2612.0 10400.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPD ROP FET RPX RPS RPM NPHI FCNT NCNT RHOB DRHO PEF Min 2557.5 37 94 0 05 0 11 0 22 0 08 1 22 0 06 11.9 71.95 549.76 1.39 -0.49 0.55 Max Mean Nsam 10400 6478.75 15686 270.59 123.061 15576 2000 6.3771 15521 1151.01 251.429 15576 75.76 0.84571 15521 72.67 4.74417 15521 61.67 4.87927 15521 2000 7.2936 15521 79.93 38.5155 15429 962.5 239.075 15429 42108.8 25393 15429 2.93 2.3361 15464 0.75 0.0928692 15464 11.16 2.41657 15464 First Reading 2557.5 2557.5 2592 2612.5 2592 2592 2592 2592 2592 2592 2592 2592 2592 2592 Last Reading 10400 10345 10352 10400 10352 10352 10352 10352 10306 10306 10306 10323.5 10323.5 10323.5 First Reading For Entire File .......... 2557.5 Last Reading For Entire File ........... 10400 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. ST~LIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2557.5 PEF 2592 0 DRHO 2592 0 RHOB 2592 0 FCNT 2592 0 NCNT 2592 0 NPHI 2592 FET 2592 RPD 2592 RPM 2592 RPS 2592 RPX 2592 ROP 2612 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 10.87 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA STOP DEPTH 10345 0 10323 5 10323 5 10323 5 10306 0 10306 0 10306 0 10352 0 10352 0 10352 0 10352 0 10352 0 10400 0 23-DEC-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD MEMORY 10400.0 2612.0 10400.0 53.7 67.7 TOOL NUMBER Pl177NLM4 Pl177NLM4 Pl177NLM4 Pl177NLM4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.750 6.8 LSND 9.60 49.0 10.0 400 4.4 1.600 1.119 4.000 3.100 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 NPHI MWD 2 PU-S 4 1 68 24 7 ROP MWD 2 FT/H 4 1 68 28 8 FET MWD 2 HOUR 4 1 68 32 9 RHOB MWD 2 G/CM 4 1 68 36 10 DRHO MWD 2 G/CM 4 1 68 40 11 PEF MWD 2 BARi~ 4 1 68 44 12 FCNT MWD 2 CNTS 4 1 68 48 13 NCNT MWD 2 CNTS 4 1 68 52 14 42.6 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET RHOB DRHO PEF FCNT NCNT Min 2557.5 37.94 0.08 1.22 0.06 0.05 11.9 0 11 0 22 1 39 -0 49 0 55 1 95 9 76 7 54 Max 10400 270.59 72.67 61.67 2000 2000 79.93 1151.01 75.76 2.93 0.75 11.16 962.5 42108.8 Mean Nsam 6478.75 15686 123.061 15576 4.74417 15521 4.87927 15521 7.2936 15521 6.3771 15521 38.5155 15429 251.429 15576 0.84571 15521 2.3361 15464 0.0928692 15464 2.41657 15464 239.075 15429 25393 15429 First Reading 2557.5 2557.5 2592 2592 2592 2592 2592 2612.5 2592 2592 2592 2592 2592 2592 Last Reading 10400 10345 10352 10352 10352 10352 10306 10400 10352 10323.5 10323.5 10323.5 10306 10306 First Reading For Entire File .......... 2557.5 Last Reading For Entire File ........... 10400 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File