Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout182-031MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 7, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-16RD KUPARUK RIV UNIT 1A-16RD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/07/2025 1A-16RD 50-029-20713-01-00 182-031-0 W SPT 5959 1820310 1800 2600 2600 2600 2600 80 1980 1930 1910 REQVAR P Josh Hunt 7/8/2025 2-year MIT-OA required by AIO 2B.075 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-16RD Inspection Date: Tubing OA Packer Depth 120 250 250 240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709091418 BBL Pumped:1.5 BBL Returned:1.4 Thursday, August 7, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 7, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-16RD KUPARUK RIV UNIT 1A-16RD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/07/2025 1A-16RD 50-029-20713-01-00 182-031-0 W SPT 5959 1820310 3000 2600 2600 2600 2600 130 350 360 370 REQVAR P Josh Hunt 7/8/2025 2-year MIT-IA Required by AIO 2B.075 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-16RD Inspection Date: Tubing OA Packer Depth 100 3300 3180 3160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709090950 BBL Pumped:2.3 BBL Returned:2.2 Thursday, August 7, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-16RD KUPARUK RIV UNIT 1A-16RD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-16RD 50-029-20713-01-00 182-031-0 W SPT 5891 1820310 1800 2600 2600 2600 2600 180 2010 1940 1910 REQVAR P Adam Earl 7/12/2023 MIT-OA tested as per AIO 2B.075 to 1800psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-16RD Inspection Date: Tubing OA Packer Depth 480 600 590 580IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714084725 BBL Pumped:1.6 BBL Returned:1.2 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-OA AIO 2B.075 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 15:48:40 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-16RD KUPARUK RIV UNIT 1A-16RD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-16RD 50-029-20713-01-00 182-031-0 W SPT 5891 1820310 3000 2600 2600 2600 2560 200 420 430 430 REQVAR P Adam Earl 7/12/2023 MIT-IA tested as per AIO 2B.075 to Max Ant. Inj. 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 UNIT 1A-16RD Inspection Date: Tubing OA Packer Depth 450 3510 3390 3360IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714084152 BBL Pumped:2.5 BBL Returned:2.3 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-IA AIO 2B.075 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 15:46:07 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor 1 FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July l4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A-16RD KUPARUK R1V UNIT 1A-16RD Src: Inspector Reviewed B�� P.I. Supry JJ Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: Austin McLeod Permit Number: 182-031-0 Inspection Date: 7/3/2021 Insp Num: mitSAM210704163807 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-16RD - Type Inj W T DV 5891 Tubing 2535 -I 2540 2530 _ 2530 - PTD 1820310 'Type Tet PT%iTOSt psi 3000 IA 52 3300 3210 _ 3200 -L — -- BBL Pumped: 2 IBBL Returned: 1.8 OA lao 335 63 0 370 Interval% REQVAR— P/F P _ _ V Notes: MITIA to MAIP. AIO 213.075. Wednesday, July 14, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A-16RD KUPARUK RIV UNIT IA-16RD Src: Inspector Reviewed By: P.I. Suprv� — Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: Austin McLeod Permit Number: 182-031-0 Inspection Date: 7/3/2021 Insp Num: mitSAM210704164021 Rel Insp Num: Packer Depth Well IA-I6RD !Type Inj WTVD 5891 Tt PTD 1820310 Type Test SPT- Test psi - 1800 BBL Pumped: 1.3 JBBL Returned: Interval REQVAR P/F P V' Notes: MITOA t 1800psi. AIO 213.075. Pretest Initial 15 Min 30 Min 45 Min 60 Min I bing 2540 2530. 2530• j 2530- [A 540 660 - 650 _ 650 - )A 120 2000 1935 - 1905 - Wednesday, July 14, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, July 30, 2019 P.I. Supervisor1 \ f ly SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IA-16RD FROM: Jeff Jones KUPARUK RIV UNIT IA-16RD Petroleum Inspector Ste: Inspector Reviewed B-y-:�� P.I. Supry s.J11'� = NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA-16RD API Well Number 50-029-20713-01-00 Inspector Name: Jeff Jones Insp Num: maJn90716093454 Permit Number: 182-031.0 Inspection Date: 7/14/2019 ' Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well! IA.16RD Type Inj w TVD 5891 Tubing 2400 2400 2100 2400 PTD! —1820310 Type Test SPT 1Test psi 3000IA 20 3300 3210 3184 BBL Pumped: .8 ' BBL Returned 1.7 OA 560 735. 234 71-9 - Interval REQVAR Notes: 2 year MIT -IA to MAIP per AIO 26.075. 1 well inspected, no exceptions noted. Tuesday, July 30, 2019 Page I of 1 MEMORANDUM State of Alaska Insp Num: mitJ1190716093934 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Thursday, July 18, 2019 TO: Jim Regg P.I. Supervisor I�Y.(q �c( SUBJECT: MechanicalAlIntegrityTests (_c ConocoPhillipsAlaska, Inc. TVD IA-16RD FROM: Jeff Jones KUPARUK RIV UNIT IA-16RD Petroleum Inspector 2400 Src: Inspector PTD Reviewed By: Type Test SPT P.I. Suprv<,i�� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA-16RD API Well Number 50-029-20713-01-00 Inspector Name: Jeff Jones Permit Number: 182-031-0 Inspection Date: 7/14/2019 Insp Num: mitJ1190716093934 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A -IBRD Type lnj TVD 5891 Tubing 2400 2400 - 2400 - 2400 PTD 820310 Type Test SPT Test psi 1800 IA 831 940. 959- 976 - BBL Pumped: o9 ' BBL Returned: O9 OA 550 2000- 1950 - Interval REQVAR — P/F.. _P Notes: 2 year Mit-OA to 1800 psi per AIO 26.075. 1 well inspected, no exceptions noted. Thursday, July 18, 2019 Page I of I • s MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 11,2017 P.I.Supervisor � 'i t S(1 7. SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-16RD FROM: Adam Earl KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: Adam Earl Permit Number: 182-031-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708072144 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-16RD - Type Inj W'TVD 5891 - Tubing 875 875 - 875 - 875 PTD 1820310 Type Test SPT Test psi 1800 - IA 210 310 325 330 BBL Pumped: I - BBL Returned: 1 - OA 620 1985 1940 1920 Interval REQVAR P/F P Notes: MIT OA as per AIO 2B.075 - asp SEP 2 5 2017, Tuesday,July 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggj DATE: Tuesday,July 11,2017 P.I.Supervisor 1\rt -7(1S(1 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1 A-16RD FROM: Adam Earl KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 68,2- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: Adam Earl Permit Number: 182-031-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708071803 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA-16RD Type Inj W 'TVD 5891 Tubing 875 - 910 -1 875 875 PTD 1820310 'Type Test SPT Test psi 3000 IA 140 3290 3210 3200 - BBL Pumped: 2.1 BBL Returned: 2.2 OA 620 835 830 - 830 Interval REQVAR P/F P ✓ Notes: MIT IA as per AIO 2B.075 S SEP 2 5 2U17 Tuesday,July 11,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Wednesday,April 08,2015 P.I.Supervisor "el 4-16115- SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I A-16RD FROM: John Crisp KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvi '/-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: John Crisp Permit Number: 182-031-0 Inspection Date: 3/22/2015 Insp Num: mitJCr150325124358 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min IA 16RD W 5891 2360 • 2350 - I 2350 - 2350 - WeIIT - Type Inj TVD � Tubing PTD 1820310 Type Test'SPT Test psi 1800 IAS- 429 555" 582 601 - Interval REQVAR P/F P OA 311 2008 1973 ---1959 - Notes: Per AIO 2B.075 MIT OA 1.2 bbls pumped for test Wednesday,April 08,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Wednesday,April 01,2015 P.LSupervisor e 4.1i3/PC SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 1A-16RD FROM: John Crisp KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry SPS NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: John Crisp Permit Number: 182-031-0 Inspection Date: 3/22/2015 Insp Num: mitJCr150325124013 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 1A-16RD • IType Inj r W TTVD I 5891 - Tubing i 2350 .! 2360 2360 -i 2360 . PTD 1820310 Type Test SPT Test psi I1500 IA 304 3384 • 3280 3261 - T-- — — + 7 Interval,REQVAR - PAF P OA 1 329 531 • 1527 525 , Notes: Per AIO 2B 075 2 1 bbls pumped for test.MIT IA , MNTA Wednesday,April 01,2015 Page 1 of I Ima ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J ~'c~-03 -ii_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BEVERLY ROBIN Project Proofing BY; VINCENT SHERYL,~INDY ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL~ARI~/VINDY Production Scanning Stage BY: Stage 2 BY: WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY ROBIN VINC~ MARIA NO NO DATE; ReScanned (individ(Ja! page [.~pecial af/:e¢~fi~t~] seasoning compler, ed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /$/ Quality Checked 12/10102Rev3NOTScanned.wpd • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,April 12,2013 P.I.Supervisor l�etpGt L(? (1 zj SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I A-16RD FROM: Jeff Turkington KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: Jeff Turkington Permit Number: 182-031-0 Inspection Date: 3/23/2013 Insp Num: mitJAT130324084109 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type In' TVD OA I IA-]6RD �� yp Inj W� 5891 IA 630 i 630 750 750 PTD 'Type Testy 'Test psi 1820310 i yp SPT 1800 600 2000 1960 i 1940 j Interval OTHER fP/F I P 1Tubin g I 1350 1350 1340 1350 - 1— - , Notes: Test required by Area Injection Order#2B.075 due to suspected IA x OA pressure communication.Also witnessed MIT1A. - Att.JA—13o'3z4t7S23o ED MAR 1 3 2014 Friday,April 12,2013 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday,April 12,2013 P.I.Supervisor -0l 1 4.(Z 1/t 3 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC l A-16RD FROM: Jeff Turkington KUPARUK RIV UNIT 1A-16RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvcj NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-16RD API Well Number 50-029-20713-01-00 Inspector Name: JeffTurkington Permit Number: 182-031-0 Inspection Date: 3/23/2013 Insp Num: mitJAT130324075230 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1820310 Type J p i IA_ -- 1 - Weill 1A-16RD �T a In W•�TVD } 5891 790 3315 3230 3220 1 PTD1 REQVAR Type Test',SPT ITCSt Sl 3000 OA 1340 _ 1340 . 1340 1340 Interval P/F Tubing] Notes: MITIA.-AIO 28.075 ,., QED MAR I. 3 2014 Friday,April 12,2013 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg g elo I ( (p( lr P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 A -16RD FROM: Chuck Scheve KUPARUK RIV UNIT 1A -16RD Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 30 NON - CONFIDENTIAL Comm Well Name: KUPARUK R1V UNIT 1A - 16RD API Well Number: 50 029 - 20713 - 01 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727071348 Permit Number: 182 - 031 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A -16RD Type Inj. 1 w ,1 TVD 5891 I 591 2040 , 2000 2000 - — P.T.D 1820310 TypeTes 1 SPT Test psi i 1500 OA 200 290 290 290 Interval 4YRTST - P/F P l Tubing i 2400 2400 2400 2400 Notes: A., 4 sAi W F �:r Z U l Wednesday, July 27, 2011 Page 1 of 1 • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 ° "3q . { Commissioner Dan Seamount 4 i' s�l pp �Q1� p�y +�,� i a i f � IIS: • RB:. Alaska Oil ♦♦and Gas Commission i .R N � � pj °. , .; v'' '`i } ' 333 West 7 y Avenue, Suite 100 Y t,:;Rz;y °'' Anchorage, AK 99501 s.- 2,,- Off' Commissioner Dan Seamount: ` A r(oR-`P Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, / MJ L veland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -03 50029206150000 1810880 16" N/A 23" WA 1.7 6/20/2011 1A-04A 50029206210100 2001940 r 18" N/A 23" I N/A 2.5 6/20/2011 1A -16R0 50029207130100 1820310 SF WA 22" N/A 5 6/18/2011 c —> 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21 /2011 1B-05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1 B -07 50029206160000 1810890 72" 1.00 22" 5/9/2011 2.5 6/21 /2011 1B-08A 50029206350100 _ 1971120 18'8" N/A 29" _ N/A 4.5 6/21/2011 18-09 50029206550000 1811340 SF N/A 23" _ N/A 5 6/20/2011 1B -10 50029206560000 _ 1811350 SF N/A 23" _ N/A 6 6/21/2011 1B -12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B -101 50029231730000 2031330 3" N/A 22" _ N/A _ 1.7 6/21 /2011 1B -102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21/2011 1E -05 50029204790000 _ 1800580 _ 19" N/A 19" N/A _ 1.7 6/19/2011 1E -22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 _ 1821840 _ 58' 10.75 2'5" _ 5/23/2011 _ 3.4 6/19/2011 1E-30 50029208140000 1821390 15'5" 1.75 16" _ 3/21 /2011 _ 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L -16 50029212020000 - 1641810 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 - 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1A-16RD Run Date: 6/4/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -16RD Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 -2071 3 -01 Injection Profile Log A 4 i bi 't'� V 2 2009 1 Color Log 50- 029 20713 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Oz- t 2 03 Anchorage, Alaska 99518 `)l-) Office: 907 -273 -3527 Fax: 907-273-3535 rafael.barreto zc NOV n 5 7009 Date: Signed: desks Oil Gas torts, Gorm e;ncboraQ ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 19, 2008 $:15 AM To: 'Ennis, J J' Subject: RE: 1A-16RD (182-031) No further questions. From: Ennis, J J [mailto:).].Ennis@conocophillips.com] Sent: Tuesday, August 19, 2008 7:16 AM To: Maunder, Thomas E (DOA) Subject: RE: 1A-16RD (182-031) Tom, Page 1 of 1 It is not unusual for us to push the 7" back down if it only "grows" a few inches. This well has a mandrel hanger but we did have slips on hand in case the casing popped up more. I wouldn't describe spearing the casing as undesirable but rather more expedient to return the well to its previous state w/ new seals. Let me know if further questions. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (tM (907)632-7281 (C) °°".N~~ AUG ~. 2008 ~~~v From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Monday, August 18, 2008 4:28 PM To: Ennis, J J Subject: 1A-16RD (182-031) Jim, I was reviewing the 404 submitted for the recent workover. It is noted that when the packoff was released that the casing "grew" 4". When the new packoff was installed, the tubing head was used to compress the casing back down. This seems unusual. The casing was obviously slightly in compression. Was it determined undesirable to spear the casing and put it tension? Was a mandrel casing hanger employed or was the casing set with slips? Given the "early" vintage of the well (1982) I would suspect slips. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 8/19/2008 • 8=/• ~ ~.~ ~-~ STATE OF ALASKA ,?~~ ~~ ~: 4.~v$ ALASKA OIL AND GAS CONSERVATION COMMISSION ,1~ REPORT OF SUNDRY WELL OPERAT~~1~~5~ 1. Operations Pertormed: Abandon ^ Repair Well ^~ - Plug Perforations ^ Stimulate ^ O'tller '^ Alter Casing ^ Pull Tubing ^~ ~ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 182-031 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20713-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' • 1A-16RD 8. Property Designation: 10. Field/Pool(s): ADL 25647 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7411'- feet true vertical 6525'° feet Plugs (measured) Effective Depth measured 7057' feet Junk (measured) 7190' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2356' 10-3/4" 2456' 2456' PRODUCTION 7270' 7" 7370' 6500' Perforation depth: Measured depth: 7014'-7022', 7032'-7054' ~~~~ A~} ~ .t. ~ 2008 true vertical depth: 6206'-6212', 6220'-6237' Tubing (size, grade, and measured depth) 3.5" , L-80, 6670' MD. ~ Packers & SSSV (type 8~ measured depth) pkr= FHL retriev. Pkr, Otis RRH, Otis WD pkr--66 6699' ; 6920' Camco'DS' nipple @ 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 5000 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-172 contact m Ennis @ 265- 1544 Printed Nam ~ En i~. Title Wells Group Engineer ~ ~ v ~ g Signature Phone: 265-1544 Date Pre aced b aron Alls Drak 263-4612 ORI~I~IAL ~~ Form 10-4 evised 04/2006 Submit Original Only S Ft:.1a~G ~ ~ 1008 rp y ~~'1tJCt3P~t~~l~5 ~ ~ Well Attrihutes tom. KK ,r ~ API11iW1 / 5002920713 Comment ~ WRDP ' n~ai c~.,i~ - a. +cFO sai _rrel ~s ~a F °_~T.,r. nr~.aa v _ - Mnohtion Depth (f 'Last lag: 7,057 - ..- Casing Strings RKB,O ~ '~ Ge ng Gesufp[bn HANGER, 25 .: Tubing,~ , ~ ~ rveiro Pw, 61 rudro.71 NIPPLE, 510 Burtace, 0.2,458 Toeing, 518 GAS LIFT, 6,547 seal.assv. 6,599 PBR, 6,599 'ACKER, 6,613 NIPPLE, 8,68 IPERF, 8,7716,632 IPERF, 8,87G6,883 i ~l ~~ IPERF, _ 7,m47,022 IPERF, , 7,032-7,054 Fish, 7,190 Last WO: 4/20/2008 39.01 3121!1982 :nd Date MnotaBon End Date 7/10/2008 Rev Reason: GLV CIO, SET TPC, PULL RHC 7/11Y1008 ~P 1A-16RD Wdl SW We Maumum Inchnanan (' ) Towl Depih (ttltB) RIVER UNIT INJ 44.25 7,370.0 Dab Mnotati... End Date KB-0round Disbllce (R) Rig Release Dale COnc11~ClOf vv peg 16 av Ina 1$.063 ,ary 1,anur 0.0 ova uaya„ 1,a... 80.0 .ace aicyxa 1, rail lea.., 80.0 rra 1,uw... 6$.00 v,.,ac 1130 ,vy w,n,w.a,w, Casing oescNption OD pn) ID (in) Top (RKB) Set Depth IR.. Set Depm (TVD) IR.. Vk (lbsl... Grade Top Connecton Surface 103/4 9.794 0.0 2,456.0 2,455.7 45.50 K-55 Casing O!scNptlon OD Iin) ID (in) Top (RKB) Set Depth IR.. Set Depth (TVD) IR.. VJt Qbsl... Grade Top Connection PrW~cl~on 7 6.151 0.0 7.370.0 6.491.9 26.00 K-55 Tukting Strings... Tubing Desuiption OD (in) ID (fn) Top ln... Sel OepcA lie(.. . Set Wpih (TVD) (nKB) YTt (Ide/R) Grade Top Connecton TUBING-Original 31/2 2.992 6,937.0 8,944.0 6,150.4 9.30 .L55 i 7ubirp Desedptlon OD Iin) ID pn) Top IR.. Set Depth (M(.. . Sat Deptl1 (TVD) (RKB) VYt pbsM) Onde ToP Connection TUBING-Original 2718 2.441 6,920.0 6,937.0 6,144.9 6.50 J-55 8RD Tubing Dwcriptbn OD lin) ID lin) Top IR.. Set Depth (/RC.. . Set Depth (TVD) (RKB) VYt ObalR) Grade Top Connection TUBING-Original 31/2 2.992 0.0 6,920.0 6,131.5 9.30 J-55 BTC Tubirg DascNption OD Qn) 10I1n) Top IR.. Set Depth IRK.. . Set Depth (TVD) (RKB) VYt (IbsRt) Grade Top Connection Taping - Wnrkavw 3 1/2 2 992 0.0 ~ 6 fi70 0 5.936.? 9.30 L-80 EUE RRD Notes: General S Safety Hyp II - C+ther In Hole (plugs, euip., Fish, etc.) Perforations TopBtm Shot Tup Btm._ (TVD) (TVD) Dena (RKB) (RKB) (RKB) (RKB) Tvx Zone (sho... Dap Comment Mandrel Details. Sel Daptn ) Port Top (TVD) Valve Lebh I Size (TRO Run Sm (RKB) (RKB) Make Model OD lint ~ TYPe TYPe IIM (Pail Run Date Comment ~ono~oPhitlips Time Log & Summary We!lulew Web ReportJrrg Report Well Name: 1A-16 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/16!2008 5:30:00 PM Rig Release: 6/20/2008 2:30:00 PM Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment ~ 6/16/2008 za hr summary Move Nordic rig 3 f/ 1 D-130 to 1A-16. Spot and RU. Pull BPV and RU circ. lines. Prepare berm to set Tiger tank. Nordic Ri was acre ted 17:30 hrs on 6-16-08 12:00 17:00 5.00 MIRU MOVE MOB P PJSM, Jack up and move Nordic Rig 3 from 1 D-130 to 1A-16 17:00 17:30 0.50 MIRU MOVE OTHR P Spot rig over well and set down. Berm u 17:30 00:00 6.50 COMPZ RPCOM OTHR P RU on 1A-16. Lubricate out BPV. RU circulation lines. Grease IA valve. Construct berm to set Tiger tank. 6/17/2008 Set Tiger tank and run hard line. PT hard line. Reverse circ. w/ 233 bbls 9.6 ppg taking returns to Tiger tank and switch to pits for 117 bbls. Monitor well and set BPV, RU and tested BOP's (witnessed by Bob Noble), ulled han er to ri floor and CBU. 00:00 02:00 2.00 COMPZ RPCOM OTHR P Continue to Set Tiger Tank and RU hardlines. PT 02:00 04:00 2.00 COMPZ WELCTI CIRC P Open up well 200 tbg, 300 IA, and 0 OA. Reverse circulate w/ 233 bbls 9.6 ppg brine taking returns to tiger tank. Switch to rig pits and continue to reverse circulate for 117 bbls. 1.5 x's hole vol. 4 b m 530 FCP. 04:00 05:00 1.00 COMPZ RPCOM OWFF P Moniitor well for flow. Set BPV. 05:00 06:30 1.50 COMPZ RPCOM NUND P ND Tree and remove from cellar. 06:30 09:30 3.00 COMPZ RPCOM NUND P NU BOPE 09:30 21:30 12.00 COMPZ WELCTL BOPE P Testing ROPE 250/3000 psi. Witnessed by AOGCC, Bob Noble. RD test a ui ment. 21:30 22:15 0.75 COMPZ RPCOM RURD P MU landing jnt, BOLD's and pull hanger to floor. Up wt 93K with no roblems. 22:15 23:00 0.75 COMPZ RPCOM IRC CBU 5 bpm at 670 psi w/ 9.6ppg brine. 23:00 00:00 1.00 6,665 6,480 COMPZ RPCOM RIP P LD hanger and landing jnt, POOH from 6,665' to 6,480'. 6/18/2008 POOH LD tubing to SSSV, RIH w/storm packer and change out tubing spool, MU BOP and test, cunt POOH and LD 31/2" tubin . 00:00 00:30 0.50 6,480 6,390 COMPZ RPCOM PULD P Cont POOH LD tubing f/6,480' to 6,390' 00:30 01:00 0.50 6,390 6,390 COMPZ RIGMNT SVRG P Service top drive and draw-works, C/O YT inserts for 31/2" BTC tubin . ~.~...~~_M_ ~~r~= 1 of 3 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 03:30 2.50 . 6,390 4,830 COMPZ RPCOM PULD P Cont POOH LD 3 1/2" BTC, control line and SSSV. Up wt 70K, dwn wt 67K. Recovered 32 control line bands. MISSING 1 BAND. 03:30 04:30 1.00 4,830 4,830 COMPZ RPCOM DHEQ P C/O handling equip, PU Baker Storm .Packer and RIH, set at 57' and tested to 500 si as er Baker re . 04:30 06:30 2.00 4,830 4,830 COMPZ RPCOM NUND P PJSM, drained stack, ND 11" BOP for tubin head and ack-off chan e. 06:30 08:30 2.00 4,830 4,830 COMPZ RPCOM OWFF P Bleeding gas off the IA. Pressure builds to 10 psi when SI. RU for Little Red to pump diesel down the IA 08:30 09:30 1.00 4,830 4,830 COMPZ RPCOM OTHR P Laod pipe shed with 3-1/2" com letion. Rack, tall and drift. 09:30 10:30 1.00 4,830 4,830 COMPZ RPCOM OWFF P PJSM. LRS pumped down the I '(~ with charge pum .Pressure up to r ~8 f~' ~ L to swap over and 150 psi. Allow J, bleed. Pumped several times, total volume pumped into was 1 bbl of diesel. RD LRS q~, 10:30 14:00 3.50 4,830 4,830 COMPZ RPCOM NUND P With the open to the kill tank, ND tubing head. BOLDS, casing extended 4". Remove casing ackoff. 14:00 17:00 3.00 4,830 4,830 COMPZ RPCOM NUND P Install new packoff assembly. Attem t to com ress the casino with . the BOP stack short about 0.5" Attach tubing head to the BOP stack, set on top of casing and compress. Tighten bollts to compress the casing the remaining 0.5". RILDS 17:00 20:00 3.00 4,830 4,830 COMPZ RPCOM NUND P NU BOP stack, choke line, kill line and riser. 20:00 21:00 1.00 4,830 4,830 COMPZ RPCOM SFEO P MU test plug, set, and shell test BOP at 250 and 3,000 psi. Test OK. RD test a ui . 21:00 22:00 1.00 4,830 4,830 COMPZ RPCOM PACK P PJSM, MU retrieving tool, RIH and engage storm packer, POOH and LD same. 22:00 00:00 2.00 4,830 3,410 COMPZ RPCOM PULD P PJSM, RU and cont POOH LD 31/2" BTC tubin , u wt 60K, dwn wt 60K. 6!19/2008 Cont POOH and LD 3 1/2" tubing, PU RIH with 3 1/2" completion, set FHL, spaced out and landed hanger, ress tested 31/2" tubin and 7" cs ,set BPV, ND choke and kill line, start C/O H dril element on 11" BOP. 00:00 04:30 4.50 3,410 0 COMPZ RPCOM PULD P Cont POOH LD 3 1/2" tubing. 04:30 08:30 4.00 0 0 COMPZ RPCOM OTHR P Clean rig floor, load pipeshed, load 'ewele . S & C drill line, service ri . 08:30 16:30 8.00 0 6,660 COMPZ RPCOM RCST P PJSM. PU/MU overshot, and FHL acker. RIH with 3-1/2" com letion. 16:30 18:00 1.50 6,660 6,660 COMPZ RPCOM CIRC P Tubing -10 ft above stub. Reverse circulate 175 bbl of inhibited brine w/ 1 % CRW-132 @ 3 bpm, 300 psi. Down wt = 75#, u wt = 85K#. Page 2 ~sf ~ ~1~.. • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 18:00 18:30 0.50 6,660 6,660 COMPZ RPCOM PACK P Pumping down tubing with charge pump. Sit down on stub with internal shear pins in the overshot. Sat down 10K# and sheared, RIH 3' and sat down 15K#. Charge pump pressure increased from 70 psi to 120 psi. PU 85K#, drop ball and rod. Pressure u tubin to 2500 si and ubin down to 1000 si. Shear out of PBR with 115K#. RIH and no 0 on PBR. PU strip . 18:30 20:00 1.50 6,660 6,670 COMPZ RPCOM HOSO P Run pup joint to space 1.97'. Land hanger and RILDS. Up wt 85K, dwn wt 75K. 20:00 22:00 2.00 6,670 6,670 COMPZ RPCOM DHEQ P RU and tested tb at 2 500 si f/15 min test ood bled tb to 1 500 si RU and tested csg to ? 50, 0 psl , f/30 min (test good), bled tubing to 0 si and sheared dkv. 22:00 22:30 0.50 6,670 6,670 COMPZ RPCOM OTHR P Installed BPV. 22:30 00:00 1.50 6,670 6,670 COMPZ RPCOM NUND P ND choke and kill lines, removed top of H dril for element Chan e. 6/20/2008 NU tree and test, RU and freeze protected well, RDMO. Nordic Ri 3 released from 1A-16 on 06-20-08 14:30. 00:00 04:30 4.50 6,670 6,670 COMPZ RPCOM NUND P CO element in Hydril, and HCR-manual choke valves on BOP. ND stack and rack back. 04:30 06:30 2.00 6,670 6,670 COMPZ RPCOM NUND P NU tree. 06:30 07:30 1.00 6,670 6,670 COMPZ RPCOM SFEQ P Test upper and lower seals to 5000 si. 07:30 10:30 3.00 6,670 6,670 COMPZ RPCOM SFEQ P Test tree to 5000 psi. 10:30 13:00 2.50 6,670 6,670 COMPZ RPCOM FRZP P RU and pump freeze protect. Pump 70 bbl of diesel down the IA and allow to u-tube with the tubin . 13:00 14:30 1.50 6,670 6,670 COMPZ RPCOM Blow down / RD. PU lubricator and set BPV. Nordic Rig 3 released from 1A-16 on 6-20-08 14:30 F'age3of3 1A-16RD Well Events Summary • DATE SUMMARY 3/27/08 (PRE RWO) T POT= PASSED; PPOT=PASSED; LDS FUNCTIONAL; MITOA=PASSED. 4/5/08 PERFORMED FLUID DETERMINATION LOG WITH GRADIO. DIESEL PRESENT AT CUT DEPTH. STRING SHOT FROM 6655-6667'. PLAN INCLUDES DISPLACING AN ADEQUATE VOLUME OF TUBING TO SEAWATER TO ENSURE WATER AT CUT DEPTH. ((IN PROGRESS)) 4/6/08 PUMP 20 BBLS SM/ DOWN TUBING, U-TUBE I/A TO INSURE S/W AT TUBING CUT DEPTH. WELL READY FOR E-LINE. 4/7/08 PERFORMED FLUID DETERMINATION LOG AND CONFIRMED WATER PRESENT IN TUBING BELOW 4150'. CHEMICAL CUT TUBING AT 6665'. HIT JAR LICK TO FREE ANCHORS IN-ORDER TO PULL OUT OF HOLE AFTER CUT. 7/7/08 PULL BALL & ROD & RHC-M PLUG @ 6656' RKB, PULL SOV & SET 1.5" DMY VLV W/ RK LATCH @ 6547' RKB. MITIA TO 2500 PSI, PASS. PULL CATCHER @ 6705' SLM. JOS IN PROGRESS. 7/8/08 ATTEMPTED TO MIT TBG, UNABLE TO GET TO HOLD (POSSIBLE LEAKING SLEEVE OR IBP). PULLED 1.875" TPI @ 6902' RKB, PUMPED 40 BBLS DIESEL DOWN TBG INTO C-SANDS. JOB IN PROGRESS. 7/9/08 EQUILIZED AND PULLED BAKER 1.69" IBP @ 6934' RKB. JOB IN PROGRESS. ~[, ~\ C., ~Q~r~~ 7/10/08 TAG BTM @ 7057' SLM, SET 1.875" x 1.375" AVA TPC @ 6906' RKB, JOB COMPLETE. ~~®~~~ To= Jim Regg P.I. Supervisor, ~ ~• ~ FROM: $ob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 30, 2008 SUBJECT: Mechanical Inteb ity Tests CONOCOPHILLIPS ALASKA INC 1 A-16RD KUPARUK RIV UNIT 1A-16RD Src: Inspector NON-CONFIDENTIAL Reviewed Byr• n P.1. Suprv ~ ~I~ Comm Well Name: KUPARUK RN UNIT IA-16RD Insp Num' mitRCN08073008s517 Rel Insp Num: API Well Number: 50-029-20713-01-00 Permit Number' 182-031-0 Inspector Name' Bob Noble Inspection Date: 7/27/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A-16RD Type Inj. i W TVD s959 IA i 40 2380 2310 2280 p.T. 1820310 TypeTest ~ SPT Test psi 1 soo ~ pA aso 600 600 600 Interval n`'ITAL ~ P/F P "~ Tubing ~ 92s 92s 92s 9zs Notes: Wednesday, July 30, 2008 Page 1 of 1 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Group Engineer MAY ~ ~ 20Q8 ConocoPhillips Alaska Inc~~~~~~ PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-16RD Sundry Number: 308-172 ~~1 ~~ ~r Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Chair DATED this ~ day of May, 2008 Encl. ~,~ RECE~ ~ , STATE OF ALASKA • ~' / MAY €D 7 '[` ,O~c ~LASKA OIL AND GAS CONSERVATION COMMISSION ~1''1 APPLICATION FOR SUNDRY APPROVAL~~aska Oil & Gas COns.~ommissivn 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^ Alter casing ^ Repair well Q Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 182-031 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20713-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ 1A-16RD - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25647' RKB 100' Kuparuk River Field /Kuparuk Oil Pool - 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7411' 6525' 7055' 7190' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SUR. CASING 2356' 10-3/4" 2456' 2456' PRODUCTION 7270' 7" 7370' 6500' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6771'-6832', 6870'-6883', 7014'-7022', 7032'-7054' 6015'-6063', 6092'-6103', 6206'-6212', 6220'-6237' 3.5" X 2.875" x 3.5" J-55 6920', 6937', 6944' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- OTIS RRH ; OTIS WD pkr= 6699' ; 6920' Camco TRDP SSSV= 1840' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby ce ify tha he foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Na Jim Ennis Title: Wells Group Engi eer Signature Phone 265-1544 Date ~ ~ ~~ Commission Use Onl Conditions of ap oval: Notify Commission so that a representative may witness Sundry Number: ~ ~' ~ p~. Plug Integrity ^ BOP Test y~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~~V ~? ~ ~ C~~ n ~ ~v ~"h ~ ~ ~ ~ S~ Subsequent Form Required: (~, y ~,`~ Approved by: COMMISS ON R APPROVED BY TH CO ISSION ~ ~~ Date: ~~~/// UUU Form 10 Revised 06/200 (= ,. ~ ~"°~ ~ ~,{` ~ ~ Submit in Duplicate S. 7.~ V~~IV-'r IIV .. ~D • KRU 1 A-16RD 1292 JP 'Casio Strin -ALL STRINGS iNJ _ - An le TS: 39 de 6770 3/21/1982 Angle @ TD: 36 deg @ 7411 Gas Lift Desai lion Size 7o Bottom TVD Wt Grade Thread ~ndrel/Dummy CONDUCTOR 16.000 0 80 80 65.00 H-40 vales 1 (6641-6642, ~... SUR. CASING 10.750 0 2456 2456 45.50 K-55 OD:5s3s) PRODUCTION 7.000 0 _ _ 7370 6492 26.00 K-55 Tubing String -TUBING Size To Bottom TVD VVt Grade Thread SBR 3.500 0 6920 6132 9.30 J-55 BTC (ss85~sa6, 2.875 6920 6937 6145 6.50 J-55 8RD oD:3.5o0) _ - 3.500 6937 6944 6150 9.30 ___ J-55 Perforations Summary TUBING Interval TVD 7Ane Status Ft SPF Date T Commem (o-s9zo, OD:3.500, ID:2.992) PATCH (6732b752, OD:2.750) Perf (s771~a3z) Pert (6870883) SLEEVE I--~-~ (ssos~so7, y ~ OD:1.875) , PKR (6920921, OD:6.156) TUBING (ss2o~s37, OD:2.875, ID:2.441) NIP (6936b937, OD:3.500) TUBING (6937944, OD:3.500, ID:2.992) SOS ~:~~~~~j ~ (6943b944, J 111 J OD:3.500) Perf _ (7014-7022) Perf (7032-7054) - 'RODUCTION - (0-7370, OD9.000, Wk26.00) 6771 - 6832 6015- 6063 C-4 C-3 CLOSED 61 4 6/9!1986 IPERF 4" H II - DO NOT OPEN 6870 - 6883 6092 - 6103 C-1 CLOSED 13 4 6/9/1986 IPERF 4" H II - DO NOT OPEN 7014 - 7022 6206 - 6212 A-5 8 4 3/8/19ffi IPERF EnerJet 7032 - 7054 6220 - 6237 A-4 22 4 3/8/19ffi IPERF EnerJet -- - - Gas Lift MandrelsNalves - - - S[ MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 6641 5914 Otis LBX Merla DMY 5.0 RO-5 0.000 0 6/10/1986 1 f. 06s Mandrel Injection MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmrrt 2 6737 5989 Camco 31/2X 1 Camco DMY 4.0 BK 0.000 0 12/5/1992 1 1. _ Extentled Pkg - -- - s, equip., etc.) - SLEEVE/PATCH Other ~plug -- -- _ _ De h TVD T e Descri ion ID 6732 5985 PATCH Set 20' AI ha Tubin Patch on 12/27/92 over GLM #2 6737 1.937 6906 6121 SLEEVE 2/17/2008 AVA TPI 1.875" x 1.375" x 16.5" NIPPLE REDUCER set 1.375 _ Other plugs, equip., etc.) -COMPLETION De h TVD T e Descn lion ID 1840 1840 SSSV Camco TRDP 2.813 6685 5948 SBR Otis SBR w/ X rofile 2.813 6699 5959 PKR Otis RRH 3.500 6920 6132 PKR Otis WD 3.500 6936 6144 NIP Camco DNIPPLE w/NO GO NIPPLE• NIP REDUCER set 12/21/1992 1.810 6943 6150 SOS Otis 2.992 6944 6150 TTL __. 2.992 Fish -FISH _ Comment Depth ~ Descripriort ~ 7190 1" CV Dropped in Rathole No Latch General Notes Date Note 1/9/2002 NOTE: WAIVERED WELL - T x IA communication; IA x OA communication• water in'ection onl . 1/16/2005 NOTE: *DO NOT OPEN C-SAND *CLOSED TO PROVIDE 2 LEVELS OF PROTECTION, PASS MITIA/MITOA ` • • 1A-16RD Repair Top Packer Leak Workover Procedure for Sundry Pre-riq Work 1. Set 1.69" IBP @ 6934' KB. 2. Remove AVA TPI sleeve. 3. Obtain 'C' sand static BHP. 4. Install AVA TPI sleeve. 5. Pull DV @ 6641' KB. 6. Lock out SCSSV. 7. Perform CMIT 1500 psi. 8. Chemical cut tbg mid joint @ 6665' KB above SBR. 9. Set 3" `H' BPV within 24 hrs of MIRU. 10. Prepare location for Workover Rig. Rig Work 1. Verify sundry approval to repair packer leak. 2. MIRU Nordic #3. Pull BPV. Circ seawater. Verify well is dead. Install BPV. ND tree. NUBOP, 11" w/ 3.5" pipe rams. Function test BOP. Pull BPV. Install blanking plug. PT BOP rams 250/2500, annular 250/2500 psi. AOGCC 24 hr advance notification of BOP test required. (Note: MASP using 1/18/08 BHP 8~ 0.1 psi/ft gradient is 2365 psi) Pull blanking plug &BPV. 3. Unland tbg hanger. POOH w/ tbg sideways, spooling SSSV control line as necessary. After laying down SCSSV, install storm packer @ +/-100'. NDBOP. Remove tbg head & replace casing packoffs. NUBOP. Test BOPE. POOH w/ storm packer. Finish laying down tubing. Survey all equipment pulled for NORM. 4. RIH w/ 3'/2', 9.3#, L-80, EUE 8rd Mod completion as follows: a. Slick tbg overshot b. 2.813"'DS' nipple w/ `RHC' plug c. 'FHL' packer &PBR d. GLM w/ SOV e. 3.5" tbg f. 2.875" Camco 'DS' nipple @ 500' 5. Locate tbg stub w/ slick overshot. Spot corrosion inhibited brine in IA to tbg stub. Tag btm & pull up to string weight. Drop ball & rod. Pressure tbg to 2500 psi to set'FHL' @ 6600' KB. 6. Shear PBR. Space-out 2' off btm, land tbg hanger. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 15 minutes. Bleed off tubing • • pressure to shear the dump kill valve. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC & install BPV. RDMO. Post-riq Work 1. Freeze protect well with diesel. 2. RU slickline. 3. Replace shear valve w/dummy. PT tbg 2500 psi to test dummy. 4. Retrieve ball/rod & `RHC' plug. 5. Retrieve AVA TPI sleeve. 6. Retrieve 1.69" IBP. Page 1 of 2 Maunder, Thomas E (DOA) From: Ennis, J J [J.J.EnnisQconocophillips.comJ Sent: Thursday, May 08, 2008 2:41 PM To: Maunder, Thomas E (DOA) Subject: 1A-16RD (182-031) and 1A-12 (181-178) BOP stack diagram Attachments: Nordic 3 11in 5m stack.pdf Tom, BOP stack diagram attached as requested. Do we need to start including wl all 403's? Jfm Ennis j j.ennis@conocophillips.com (907)265-1544 (UI~ (907)632-7281(C) T~e,a.~s'~~'~~ J l.i L . :;. ~ ~v~:~ From: Maunder, Thomas E(D~A) [mailto:tom.maunder~a aiaska.gov] Sent: Thursday, May 08, 200$ 12:46 PM To: Ennis, J J Subject: RE: 1A-16RD (182-p31) and 1A-12 (181-178) Jim, Sorry I missed that. Yes, if you have a new drawing that would be appreciated. Electronic would be great. { presume the stack is 3-~am and two sets of pipe will be available. I know MASP might not require 2, but back-up never hurts. I also noted that you planned a 2500 psi BOP test, again in line with the MASP. However, the requirement that I have placed on the sundry is 3000 psi minimum. Call or message to discuss. Thanks again for the quick response. Tom Maunder, PE AOGCC From: Ennis, ] J [mailto:).J.Ennis@~onocophillips.com] Sent: Thursday, May 08, 2008 11:31 AM To: Maunder, Thomas E (DOA) 5ubject: RE: 1A-16RD (182-031) and 1A-12 (181-178) Good morning Tom, As noted in Rig Work Step #2, we will be using Nordic #3 and their 11" stack. Do you need a stack diagram? Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (W/J (907}632-7281(C) 9/23/2008 Page 2 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 07, 2008 4:55 PM To: Ennis, J J Subject: 1A-fSRD (182-031) and 1A-12 (181-178) Jim, I just finished reviewing the sundries to workover 1A-16RD and 1A-12. A couple of questions ... 1. What rig witi be empioyed to conduct the work? 2. What stack configuration will be employed? Tom Maunder, PE AOGCC 9/23/2008 1 A- 16 PTD # (182-031) notice of T X IA comm Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, October 16, 2007 3:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) `~~ ~ i ~~~ ~ r/ a Cc: CPF1 Prod Engr; CPF1 DS Lead Techs T Subject: 1A-16 PTD # (182-031) notice of T X IA comm Attachments: 1A-16 90 day TIO.jpg; 1A-16RD.pdf ~t~~`. ) ~~~ ~' +~ Z~Qt~ Jim, 1A-16 PTD # (182-031), produced water injector, has T X IA communication. The well is waivered internally for IA by OA communication, review a-mail conversation on 7-27-07, AOGCC request for internal waiver documentation. The well has atypical C / A sands selective straddle packer completion. We suspect the well has a one way leak to the IA in the top packer. The C sands do not have enough force to exceed the 2000 psi IA DNE pressure and the well will pass a MITIA. Last passing MITIA on 7/15/07 @ 1800 psi -witnessed. On the 6th of Oct the AVA iso sleeve at 6906' was pulled and the well returned to injection on the 8th of Oct. The IA quickly equalized with the injection pressure. ~'~ Operations unsuccessfully attempted to limit the IA pressure by choking back the tubing pressure. Operations bled the IA three times and contacted our office when the IA re-pressured a 4th time. At that point the decision was made to shut the well in. T/I/O at the time reported = 970/1493/115 psi. ~~ Immediate action will be to leave the well shut in. We will notify you at a later date with intent to repair or pursue an AA to resume injection. °--- T/I/O = 650/750/440 psi on 10/16/07 Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «1A-16 90 day TIO.jpg» «1A-16RD.pdf» 10/ 19/2007 (~-f~~- I ~Z- - a3( ,~,t~NULUS ~'l~~~UR: TF~~I~lL~ SC 3000 2700 2400 2100 1800 1500 1200 900 600 3D0 0 PLOT START TIME MINOR TIME PL09' DtIRA"PION PLOT END TxME 18-JUL-07 13:30 MAJOR TIME WEEK +02160:00:00 xRF;16-OCT-07 13:30 PICK TIISE 03-O CT-07 23:32::13 f,C TAG NAME DESCRIPTION 1'-YALOE LATEST ~ WL1A-16-CHOKE FLOW TUBING CHOKE 40- SCRATCH 30 FLOW TUBING PRESSURE 2385. SCRATCH_30 FLOW TUBING TEMP 135. ~ 7777777 ~ 77777?? ~ 777?777 SCRATCH_30 INNER ANNULUS PRES 1181. SCRATCH_30 OUTER ANNULUS PRES 950. R PREV WELL DRILLSITE WELL lA 16 NEXP WELL h;PrrRY TYPE OPERATOR OPERATOR VERIFIED I~ :;'r:>"ITEM Auxa t•:rrrRY ~ BOTH WELL NAME WLKRUlA-16 `~~~ KRU 1A-16RD 4~ Cono~oPhillips tiias~Ca, Ir>IC. .... ~ 1A_f_6Rd -__- ANI: 5uuG91u713u1 Well 1 e: INJ An le ~ Ta 39 de m 67/U sssv (1840-1841, SSSV Type: TRDP Orig Com letion: 3/21/1982 Angle @ TD: 36 deg @ 7411 Annular Fluid: Last W/O: 6/10/1986 Rev Reason: SET TPC Reference L Ref L Date: Last U date: 1 0/1 312 0 07 Last Ta : 7108' RKB TD: 7411 ftK6 Last Taq Date: 10/23/2006 Max Hnle Anole: 44 deg (a~ 5600 Casin Strin -ALL STRINGS Gas Lift E: Description I Size I Top f Bottum i TV"D i V1lt Grade Thread I sndretroummy ~~ ~ CONDUCTOR 16.000 0 80 80 65.00 H-40 Value 1 ,.. ... -...,...,- ,.. _,... ,. ..._.. ~ .~ .-,. ~,-~-~ (6641 fi642, OD:5.938) SBR (sss5ssss, OD:3.500) TUBING (o-ss2o, OD:3.500, ID:2.992) ~ .Tubing String -TUBING Srze To Bottom TVD Wt Grade Threao -- 3.500 0 6920 6132 9.30 J-55 BTC 2.875 6920 6937 6145 6.50 J-55 8RD r 3.500 6937 6944 _ _6150_ 9.30 J__-55_ _ _ _ _ _ _ Perforations Summary i r..i~~..~i Tvn ~~.,,~ - G. . ewe . n~~o i T..~.~ i ~, o., PATCH ` I r - l (6732752, OD:2.750) i ~- I. ~ ~ ',. d .. _..... (6771-6832) _ F. --` : ~ : ~_ °~- Perf _ i (i (6870.6883) ~ ~- I f ~ii.. SLEEVE ~ l (6906-6907, , ~~ OD:1.875) ~, PKR ~ ~ (6920F>921, ~~ ~,~ OD:6.156) f t i TUBING I 1 (6920-6937, OD2.875, ID:2.441) y ! ~' NIP i. (6936-6937, OD:3.500) TUBING (6937-6944, ~ ~ 1._... SOS (6943944, OD:3.500) < :3 I ~ ~~-- (7014-7022) ~~~ ~ _.__ i i. Pert ---- 1 (7032-7054) I - - i i 6771 - 6832 6015 - 6063 C-4,C-3 CLOSED 61 4 6/9/1986 IPERF 4" H II - DO NOT OPEN 6870 - 6883 6092 - 6103 C-1 CLOSED 13 4 6/9/1986 IPERF 4" H II - DO NOT OPEN 7014 - 7022 6206 - 6212 A-5 8 4 3!8/1982 IPERF EnerJet I /U3Z - /U64 I 6210 - 6237 I A-4 I I12 1 4 1 3/8/1982 I IPERP I EnerJet I Gas Lift MandrelslValves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 6641 5914 . Otis LBX Merla DMY 5.0 RO-5 0.000 0 6/10/1986 1 1. Otis Mandrel Injection Mandrels/Valves I St I MD I TVG I Man Mfr I Man Type I V Mfr I V Type I V GG I Latch I Poii I TRG I Gate Run I Vlv ~ iOther (plugs, equip., etc.) -COMPLETION De th TVD f e Descn tion ID 1840 1840 SSSV Camco TRDP 2.813 6685 5948 SBR Otis SBR w/ X rofile 2.813 6699 5959 PKR Otis RRH 3.500 6906 6121 BPL AVA 2.750 on Other (plugs, equip., etc.) - SLEEVEJPATCH De th TVD T e Desch Son ID 6732 5985 PATCH Set 20' AI ha Tubin Patch on 12/27/92 over GLM #2 6737' 1.937 6906 6121 SLEEVE AVA TPC 1.875" x 1.375" set 1016/2007 1.375 6906 6121 NIP AVA; Set on Set on 12/21/92 1.875 RFDUr_,FR Fish -FISH Geplh DeSefl pllOrl cOmrtl~nl I ~:~L~,~~~ ~1 in F;,itl I ~ iJ~~ L itch General Notes 'RODUCTION (0-7370, OD:7.000, Wt26.00) KRU & CRU MITIAs lA, IG, IF,. & CD3 & CD4 Regg, James B (DOA) . Page I of2 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, July 29, 2007 1 :02 PM 1t-;,\\)1 To: Regg, James B (DOA) lfJ111 Subject: RE: KRU & CRU MITIAs 1A, 1G, 1F, & 1J & CD3 & CD4 Attachments: 1A-16RD 90 day TIO plot.jpg; 1A-16RD bleed log.jpg; 1A-16RD CPAIIAxOA waiver.pdf ~ IA- tfo1Z-D PTD ~ 187--03 f Jim, I've attached the documents that you requested. Additionally I've attached the bleed log assuming that you would want info on the recent drop in OA pressure. Let me know if you need any further info or have any other questions. À444cbtM(l~ Perry Klein ú) T3ð r~SS\AJr_S ~ W C{ I Ve..- (CPA-J:) (]) BlteJ M kl~hd Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com ¡CANNED AU G.O 6 2007 ,." . '...,/JII. _...,..t_·-'.. ( ,..'~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, July 27, 2007 10:03 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: Cawvey, Von Subject: RE: KRU & CRU MmAs lA, lG, lF, & 1] & CD3 & CD4 Please provide current 90-day TIO pressure plot for 1A-16RD (PTD 1820310); according to the MIT form documenting 7/15/07 testing, this well has a CPAI waiver for IAxOA. Also please provide a copy of the CPAI waiver for this well. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, July 26, 2007 9:55 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: Cawvey, Von; NSK Problem Well Supv Subject: KRU & CRU MmAs lA, lG, lF, & 1] & CD3 & CD4 Tom, Jim, & Bob, Attached are passing MITIAs as witnessed by Bob Noble on 7/14 and 7/15. 1J, CD3 & CD4 were initial MITIAs for new wells. 7/30/2007 KRU & CRU MITIAs lA, IG, IF, . & CD3 & CD4 1 A, 1 G, & 1 F are 4 yr M ITIAs. 31 pad is the on Iy pad left to MITIA before 7/31/07, win to sched ule it soon. Page 2 of2 Please let me, Perry Klein, or MJ Loveland know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n 1617@conocophillips.com «MIT KRU 1J 07-14-07.xls» «MIT KRU 1F-02 07-15-07.xls» «MIT KRU 1G 07-14-07.xls» «MIT KRU 1G 07-15- 07.xls» «MIT KRU 1A 07-15-07.xls» «MIT CRU CD3-302 7-19-07.xls» «MIT CRU CD4-302 7-18-07.xls» 7/30/2007 1 to 21tH! HUH! lSIH! 121111 91HJ 6 III! 3í}!J ~ __ __ ~ ___ ___ ~ __ ~ _ _ ~ ___~ w __ __ ~ _ ___ _ _ ~ __ _ ~ ~ _ ~ __ _ __ H --- ~ WEEK 30-APR-07 09:38 2396. SCRATCH 51 mITER PRES SCRATCH_51 ~ - - - ~ -- ~ -- - ~ -- -- - - -- - -- ~ -- - --~ KRU IA-I6RD Pressure Bleed History f Ie \¡it'N "1"'11 I !!!L1111 j¡!f;':";~fi!i"i:~'::{:~;:~¡:(;;i".ç;;;;:f::;;;;;;:!;\ A'I'ELL' AN N U· LUS BL' EEO' SU M MARY:";::;·:; ;:!.%{,(;.;. /.':(Ç;(),';(:;);!¡;¡/(;ff";:;': :::::1;:,"/':~::}:;'::::i: ,~:~:-:):::::~:~;:::::::;.::: ~:¿;¿:;'~¿;:::;;:ß: V V ;,;;:; :';;':;,.:, ';f:::· ;":::[::;:::f;;:;t:?:í;;//::,:;';f:; I, '. ;¡;:'/'-"//;í;.,,?:'-,;/, ~,://.?", >/:."%/,;;.:;.,,,/',>.;././.;. ,/./.' , ',', ','., , ,.,.." ","',',' ',' ,.",'" "','," "/'" '"., , . '.'" "'; '.' " , , "./ ' , " : 'íZ';" ././. '';' "/'" "//';,z,."" '/,'/·.í'.í' IIII ...... .... ""Â. ""Â. ""Â. ........ ..... ""Â. ...... DS VL TIKE DURATIOlf STR-PRES ElfD-PRES DIY-PRES CASIHG SERVICE KATERI.U COKKEHTS Paqe 1 1A 16 22-JUL-07 16:53: +000:10 1450 200 1250 OUTER PVI qas bled bv DSO 1A 16 21-AUG-05 04:10: +000:03 1500 1050 450 INNER PVI GAS 1A 16 14-0CT-04 13:58: +000:10 1650 1200 450 INNER PVI qas SORT Err" COLUMt·. . . . CLEAR . CLEAR . RESET SELECTION DAYS DISPLAYED FROM III ~~illIJÌiI.m~ I~III~~_ _ TODAY PRODUCTION STATUS ON _ _ifl·] OFF _ BOlli _ lliIS SELECTION RETURNED 3 RECORD POINTS 360 POINTS MR~:U1UM / .... .~.: ý- ·n·· \.... )! ( ') . . Notice of Kuparuk WaiveredWel1 WELL: lA-16 DATE: 01-09-02 WELL TYPE: Water Injector -..-- Injection Data: 1000 BWPD RIR --- Pressures: Injecting: Tubing 1400 psi IA 1000 psi OA 1000 psi REASON FOR NOTICE: Tubing x Production casing communication (T x IA) Production casing x surface casing communication (iA x OA) TUBING x IA COMMUNICATION? YES xx NO · History of T x IA communication dating to 1988. including Sundry reports to AOGCC In 1989 and 1990; . MITJA's passed 12/11/00. 10/1 0/00. and 5/19/96; . Tubing packoff assembly has consistently tested good (leak appears to be downhole). · Umlting tubing Injection pressure will help maintain IA pressure. IA x OA COMMUNICATION? YES xx NO · Production casing packoff has been known to leak and has been sealant squeezed several times; · High IA pressure slowly leaks to OA which leads to frequent OA bleeding; · Surface casing packoff has been known to leak and has been sealant squeezed several times; IMPORTANT CONSIDERATIONS/COMMENTS: · The well has shown T x IA communication problèms since 1988; · MITIA's will pass. so T x IA and IA x OA leaks are small and do not rapidly track; · Wellhead packo~assemÞJies are known to leak. and hove been sealant squßeled; · All communication problems appear to be worse on gas injection than on water injection. ~._.- PLAN OF ACTION: ~_._,__ Grant waiver to continue operations · Water injection only; gas injection is NOT allowed; · IA & OA pressures are not to exceed 1500 psi (limiting tubing pressure may be required); · OOA pressure is be monitored and kept bled off to near zero; · Monitor well head pressures daily and log weekly into Setcim; · Perform the following waiver compliance testing: · MITIA every 2 years to monitor change in leak(s) status; ... Perform annuallC & OC casing packoff tests and use sealant as needed; · Shut-In well if MIT fails or annulus pressures indicate further communication problems. Distñbulion: DS Operator CPF PE Central Files A TO Wells File and schematic Central Files Kuparuk MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor "0 )"(211 7('2].;1 D 7 DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA fNC lA-16RD KUPARUK RIV UNIT IA-16RD \BJ;°31 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: ~¡"") P.I. Suprv ...J+;£- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-I6RD Insp Num: mitRCN070719133808 Rei Insp Num: API Well Number: 50-029-20713-01-00 Permit Number: 182-031-0 Inspector Name: Bob Noble Inspection Date: 7/l5/2007 Notes: \,J Q.. \ \. \u:c s Depth / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. : 5959 vi IA : 1300 i 1800 T 1790 ! 1790: ~---- 1800 1"/: OA i13SO¡-ms¡msi 1375 I~--r---~ ~~--r----- , I ! I I __~ TuiJiilg i 2300 I 2300 r 2325 I 2325 i ! I __ I; ..~~ , '"'- () cf!4- ", r. II'¡¡KrìVL--c Y\jtu Vt:r ~~- C1V\i'\u.Lu..~ r,>êS'S\A;t<; i1 Packer W~II : IA-16RD ¡Type I~j.~;, I TVD P.T.D¡ 1820310 IITypeTest ¡ SPT ¡I. Test psi __. I... Interval 4YRTST P/F P v ,¡Jù-\€ t2tc~ ~f*" (TV~) CÄ.b~:*s 9152- I i.lú <;I- rece.J- <S~tN:~ qPpiìV~~ ~ b ì ~c~^Q ,-tes'./- (J.regS i,".ìt è ~ i ~"^- S,AJ"v;J SCANNED AUG 0 6 2007 Friday, July 20,2007 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Jj~-1\{ikJ\ Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us:andJim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KuparuklKRU/1 A-16RD 07/28/04 Arend/Sauvageau Packer Depth Pretest Initial 15 Min. 30 Min. Well 1A-16RD Type Inj N T.V.D. 5959 Tubing 800 800 800 800 P .T.D. 1820310 Type Test P Test psi 1500 Casing 850 3000 2925 2900 Notes: Internal waiver compliance test, well is currently not injecting (81) for CPF1 facility repair work. Interval 0 P/F P Interval P/F Interval P/F Interval P/F Interval P/F Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj .:; = Salt Water i.-.j N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle ~ ::. intêmai rtadjoêlctrvè -:-:¡aCêi Suívêy \/ = Required by Variánce A = Temperature Anomaly Survey D = Differential Temperature Test Test during Workover 0 = Other {describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1A-16RD 07-28-04-1.xls 7/29/2004  STATE OF ALASKA (~ ' OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate __ Plugging Perforate Puli tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1409' FSL, 494' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1641' FNL, 902' FWL, Sec. 5, T11N, R10E, UM At effective depth 1333' FNL, 929' FWL, Sec.5, T11N, R10E, UM At total depth 1255' FNL, 938' FWL~ Sec. 5, T11N~ R10E~ UM 12, Present well condition summary Total Depth: measured 741 1' true vertical 6 5 2 5' Effective depth: measured 7 2 7 8' true vertical 641 7' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet Plugs (measured) feet None feet Junk (measured) feet None 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well numbe[ 1 A- 10~"~~ 9. Permit number/Approval number 9-752 10. APl number 50-029-2071 ;)-01 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool 13, 14. Casing Length Size Structural Conductor 8 0' I 6" Surface 2456' 10 3/4" Intermediate Production 7 3 7 0' 7" Liner Perforation depth: measured 6771-6832, 6870-6883, true vertical 6015-6063, 6093-6103, Cemented Measured depth True vertical depth 286 Sx AS I 8 0' 8 0' 1000 Sx Fondu 2456' 2456' & 250 Sx AS II 1000 Sx Class G 7370' 6500' & 25O AS II 7014-7022, 7032-7054' MD 6205-6212, 6220-6237' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6944' Packers and SSSV (type and measured depth) RH Pkr @ 6699', WD Pkr @ 6920'; TRDP @ 1840' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Convert from water injector to an A Sand WAG injector. Prior to well operation (injecting) ,Subsequ, ent to operation (injecting) '15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X RECEIVED ReDresentative Daily Average Production or In!ection Dat~ OiI-Bbl 0- - 0 - 16. Gas-Mcf Water-Bbl Casing Pressure 0 - 4000 400 1 0000 - 0 - - 0 - Status of well classification as: Water Injector __ WAG Injector × Oil _ Gas Suspended Service Tubing Pressure 2500 3900 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-40~ Rev 05/17/89 Title Senior Operations Engineer Date ~/3 --/~3~ SUBMIT IN DUPLICATE W Z S EOT LN A LET I BPR 2 A SI 3BPR 4 B PR 5BPR & APR 8 BPR 10 B TS TOTALS: W Z S EOT L N A LET 7 B 9AOI 11 A SW 12 B PW 13 B SW 14 B SW 15 A OI l& A PW TOTALS: KDGS MORNING WELL REPORT FOR 08/23/89 DRILLSITE lA PROBUCTION WELL STATUS :?' 7" 10" TP TT WC H2S CSG CSG PSI CHK DEG % PPM PSI PSI 130 12 98 92 1050 1300 700 0 0 0 0 25 1320 500 140 176 118 44 75 1175 1000 125 17& 40 5 32 825 1000 275 17& 132 84 87 1300 600 160 176 78 I 25 1260 760 175 176 114 31 20 1100 975 175 176 110 65 43 1240 875 GAS LIFT STATUS GAS INd TEMP METER RATE DEG READING MSCF 92 2092 487 0 0 0 90 5392 699 96 4993 278 100 5792 735 104 5793 1378 105 7793 1001 95 6293 1528 6106 INdECTION WELL STATUS INdECTION RATE ALLOW INd PSI ACT 7" 10" INd TT CSG CSG PSI DEG CHK PSI PSI 2500 2450 95 66 2480 80 4000 3900 120 209 640 60 2500 2500 90 66 2800 40 2500 2350 140 176 400 360 2500 2300 95 6~ 0 0 · 2500 2500 95 176 0 150 4000 3950 115 209 0 0 2500 2500 158 176 340 400 ,. INd INd METER RATE RATE READING BPD MMSCFD 8441843 4848 0.000 0 0 1.516 3336061 2139 0.000 4728241 8693 0.000 7654489 6383 0.000 3821692 4592 0.000 0 0 1.536 247333 3791 0.000 SWI: 17962 + PWI: 12484 = PAGE 1 S/I IMPACT C H M 0 R I D EPL S N E BBLS 0000 0 0 2212 63 148 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 148 S/I C HM 0 RI D SN E 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 W Z S E 0 T L N A L E T 1BSI 2ASI 3BPR 4 B PR 5BPR (~APR 8BPR 10 B PR TOTALS: W Z S E 0 T L N A L E T 7BSW 9AGI 11 A SW 12 B PW 13 B SW 14 B SW 15 A GI 16 B GI TOTALS: PAGE 1 KDGS MORNING WELL REPORT FOR 08/27/89 DRILLSITE lA PRODUCTION WELL STATUS GAS LIFT STATUS 7" 10" TP TT WC H2S CSG CSG PSI CHK DEG % PPM PSI PSI 0 0 0 95 1050 1290 700 0 0 0 0 0 25 1250 500 0 140 176 114 44 75 1125 1000 90 150 176 40 5 32 825 1000 96 275 176 132 84 87 1290 600 100 140 176 77 I 25 1200 760 104 200 176 116 31 20 1100 975 104 180 176 110 61 43 1220 870 92 ALLOW INd PSI INdECTION WELL STATUS ACT 7" 10" INd TT CSG CSG PSI DEG CHK PSI PSI 2500 2450 90 66 2450 80 4000 3800 100 209 700 60' 2500 2500 80 66 2800 60 2500 1100 140 3 0 60 2500 2300 92 47 0 0 2500 2490 88 176 0 150 4000 3800 104 209 0 0 4000 3000 106 20 0 0 SWI: 18512 + PWI: GAS INO TEMP METER RATE DEG READING MSCF 4093 670 5391 460 4392 567 4993 278 4592 580 3092 715 8092 1029 6193 1504 5803 INdEOTION RATE INd INd METER RATE RATE READING BPD MMSCFD 8454435 5012 0.000 0 0 1.026 3341713 2311 . 0.000 4749257 908 0.000 S/I IMPACT C HM 0 R I D EPL S N E BBLS 02T~8 63 22 0258 63 20 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 HM 0 R I D SN E · 0000 0 0000 0 0000 0 0000 0 7670988 6432 0.000 ' 0000 0 3833504 4757 0.000' 0000 0 0 0 1.478 0000 0 0 0 2.281 0000 0 908 = 19420 4.785 42 Post Office ..,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Chatterton: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. J Well Action 2G-13 2G-15 2G-08 3H-04 1A-11 1A-1:6a 1A-04 1F-08 1F-15 Refracture Refracture Refracture Acidize Tbg. Leak Packer Leak Acidize WAG Conversion WAG Conversion If you have any questionS, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:Rjr cc: J. Gruber J. R. Brandstetter L. L. Perini KeEl .4-9 ATO 1478 ATO 1120 ATO 1130 w/o attachments ECEIVED Alaska Oil & Gas Cons. L;ommissio .4nchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieidCompany )~-vSKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS Stimulate w Plugging Perforate _ I Repair well Pull tubing Other X I /~ 1. Type of Request: Operation Shutdown m Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 1409' FSL, 494' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1641' FNL, 902' FWL, Sec. 5, T11N, R10E, UM At effective depth 1333' FNL, 929' FWL, Sec. 5, T11N, R10E, UM At total depth 1255' FNL, 938' FWL, Sec. 5, T11N~ R10E, UM 12. Present well condition summary Total Depth: measured 741 1 ' feet true vertical 6525' feet Plugs (measured) 6. Datum elevation (DF or KB) lO0' RKB 7. Unit or Property name Kuparuk River Unit [eet 8. Well number 1A-16A //0 9. Permit number/approval number ~1-31/~)-65~ 10. APl number 50-029-2071:3-00 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7278' feet true vertical 6417' feet Junk (measured) Casing Length Size Structural 80' 16" Conductor 245 6' 10 Surface Intermediate Production 7379' 7" Liner Perforation depth: measured 6771 '-6832', 6015'-6063', Tubing (size, grade, and measured depth) 3 1/2" J-55, 6944' Packers and SS~V (type and measured depth) RH Pkr @ 6699'MD, WD Pkr 13. Stimulation or cement squeeze summary 3/4" Cemented Measured depth 286 Sx AS I 80' 1000 Sx Fondu 2 4 5 6' & 250 Sx AS II 1000 Sx Class G & 7 3 7 0' 250 AS II 6870'-6883', 7014'-7022', 7032'-7054' 6093'-6103', 6205'-6212', 6220'-6237' @ 6920'MD, TRDP @ 1840'MD Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 80' 2456' 6500' 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ,,X .... Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1D-404 F~v 05)17/89 Title SUBMIT IN DUPLICATE WELL ARCO Alaska, II~~''. ~ ' Subsidiary of Atlantic Richfield Con~ iPBDT CONTRACTOR REMARKS WELL SERVICE REPOR'I FIELD-DISTRICT-STATE IDAY~ 11.,.0 ~ E_.Lc I~oo ~/~u o¢/S Anchorage ['-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK OIL AND GAS C,(]YSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program ~ Pull tubing _ Op~,~ration Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Variance m Perforate _ Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ExPloratory Stratigraphic 4. Location of well at surface 1409' FSL, 494' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1641' FNL, 902' FWL, Sec. 5, T11N, R10E, UM At effective depth 1333' FNL, 929' FWL, Sec.5, T11N, R10E, UM At total depth 1255' FNL~ 938' FWL~ Sec. 5~ T11Nr R10E~ UM 12. Present well condition summary Total Depth: measured 741 1 ' true vertical 6 5 2 5' Effective depth: measured 7 2 7 8' true vertical 6 41 7" feet Plugs (measured) feet None feet Junk (measured) feet None RKB 100 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-I§A 9. Permit number . 81-31 10. APl number 50-029-2071 3-01 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 8 0' Surface 2456' Intermediate Production 7 3 7 0' Liner Perforation depth: measured 6771-6832, 6015-6063, Size 16" 10 3/4" , 7# 6870-6883, 6093-6103, Cemented Measured depth True vertical depth 286 Sx AS I 80' 80' 1000 Sx Fondu 2456' 2456' & 250 Sx AS II 1000 Sx Class G 7370' 6500' & 250 AS II 7014-7022, 6205-6212, Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6944' Packers and SSSV (type and measured depth) - RH Pkr ~ 6699'~ WD Pkr ~ 6920';.TRDP @ 1840' 13. Attachments Description summary of proposal _ Continue Injection. 7032-7054' 6220-6237' Detailed operation program X.~ .%RECEIVED 14. Estimated date for commencing operation 15. Status of well classification as: August 1989 Oil __ Gas __ Suspended 16. If proposal was verbally approved Name of approver Date approved Service Water Injector 17. I hereby certify that the foregoing is true .and ~orrect to tli~ best of my knowledge. /z~ ~~~~ltle ~¥~__~ ~,~~ x~, Date S ' g n e d ,/r~(:::~C~-,'<'f./G:~'~ - / ' ' F~R COMMISSION S~E ONLY " ~__~" Conditions of approval: Notify Commission So representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form require 10-~/'/ Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. ~,pprOved Copy Returned Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Procedures 1A-16: A Only SPFQ/SRT. A Only Gas IniectiQrl 1. Pull ported AVA at 6899' RKB. 2. Run AVA blanking sleeve. 3. Allow well to stabilize at maximum water injection rate. 4. Operations Engineering to perform SPFO. 5. Operations Engineering to perform SRT after well has stabilized. 6. Convert well to A Sand only gas injection for 10 weeks. NC Water Injection 1. Fill wellbore with liquid to avoid being blown uphole. 2. Pull AVA blanking sleeve at 6899' RKB. 3. Run ported AVA with 2 ea 28/64" ports. (port size may change based on SPFO/SRT results from above) 4. Begin A/C water injection. 5. Operation Engineering will communicate when to switch well to A/C water injection, based on gas injection rates. RECEIVED Alas~ Oil & ~s Cons. ~omm'mio[~ Anchorage Water Injection Well 1A-16A Conversion to WAG Injector No workover fluids or BOP's will be used for the conversion. Estimated reservoir pressure is 2900 psi. RECEIVED rala,~ Oil & Gas Cons. k/omm'~io[~ Anchorage 1A-16 Water Injector Sundry Notice to Continue Injection Reouest -- Approval to continue injection on Well 1A-16. Slight communication from the upper packer to production casing has been noted, yet is not enough to cause the well to fail an AOGCC witnessed MIT nor to subject the production casing to a pressure that exceeds the hoop stress regulation set forth in Rule 4 of AOGCC Area Injection Order No. 2. The present condition of the well is operationally safe and poses no threat to the integrity of the production casing. The communication will be monitored closely to note any changes in its present condition. Backeround -- This water injector was noted to have slight communication from the tubing to production casing. The production casing would be bled below 2000 psi (tubing=2550 psi), only to have the pressure increase back to 2200+ psi over the course of 5 days. Continued bleeding of the production casing was halted in fear of drawing water up into the permafrost region of the production casing. S, equence of, Events 8 / 1/8 8' Failed an AOGCC witnessed MIT. 8/2 5/8 8' Wellhead check found no leaks. 10/3/88' Passed an AOGCC witnessed MIT. Report attached. 6/1/89' Annulus pressured to above 2000 psi. bleed down failed. 8/06/89' Dummied C Sand to' lower pressure on C Sand side of upper packer. Annulus did not repressure. Conclusion: Attempts to Source of communication is from the C Sand side of the upper packer to the 7" casing. Attachments' 1) 2) AOGCC MIT of 10/3/88 lA-16 Well Schematic RECEIVED Ala~ Oil & Gas Cons. f, ommi~io[~ Afldm~e Water Injection Well 1A-16A No workover fluids or BOP~s will be used for the conversion. Estimated reservoir pressure is 2900 psi. RECEIVED Alaal~ Oil & ~as Con~. ~l~im~ Anchorage OIL ~ GAS (X)NS~VATI~ JL I I III III · i ....... PR~t'~r $~rAFJ? !' 15 I-liN 30 MIN *P *I TYPE OF P~ c. Asn~ T~ WE[~' *S --- ~S IYD SIZE/Wr/GRADE SIZE TE5~ CSG TBG TBG 71~G ~1 ~N FIIIID Mi:) PRESS PRESS CSG CSG CSG PRESS PRESS PRESS · i i i i ii ii ii i ii _ ,.- i · i i ii i i i i iii i · i i L i i i ii ii i ii i i i i iii i i i _  i i i · i i i i · i ii i ii i i i i i IIIL I I i ' ~ ~ ii i i i  ~ ii .... i i i i~1 i ii i iii i i i i i i i i , , , · ] ii .1 · i i i ii ~ I i i iii *IIIBING IRIEUrlON FIIIID, P - PR(II.L"E WAltI( S -SALT WATER INJ M = MISCIBIJ,. IRIF. UrlON I = IRIECIIN0 It - }lJI IRJ~ · DIF. SI~. , ~'_.~ i.//' ~ GLYGOL ' :: ... CCIqP~ REP SIGNAllJRE ~/',_z..'-/7.l t/'F,~--.~'_. SALT WATER DRIll.lNG [lid - : 20 AAC 25,030(a) orrlu?:R. .... 20 AAG 25,612(c) O11~ .... " ' 20 AAC 25,252(d) KUPARUK WELL 1A-16A APl #: SPUD DATE: 500292071301 03/01/82 ORIGINAL RKB: 100 ADL LEASE: 25647 COMPLETION DATE: 06/10/86 PERMIT #: WORKOVER DATE: SURFACE LOCATION: 1409-FSL,494-FWL, SEC5,T11 N,R10E TOP OF KUPARUK: 1641 -FNL,902-FWL,SEC5,T11N,R10E TD LOCATION: 1255-FNL,938-FWL,SEC5,T11 N,R10E All depths are MD-RKB to top of equipment unless otherwise noted TUBING SPOOL: 27 PAD ELEVATION: WELLTYPE: CASING and TUBING DETAILS .-l~m SiZE WEIGHT GRADE DEPTH 16' 62.5# H-40 80 10.75' 45.5# K-55 2456 7' 26# K-55 7370 3.5" 9.3# J-55 BTC 6937 I~ STN 1 2 66 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 6633 1.5' 6730 1 · 82-31 PORT SIZE LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP 2.812" 1833 SBR OTIS SBR 6677 PKR OTIS RRH 6692 AVA AVA 'BPL' NIPPLE 6899 PKR OTIS WD 6913 NOGO CAMCO 'D' NIPPLE 2.25" 6929 SHROUT OTIS 6936 PERFORATION DATA INTERVAL ZONE FT 6771-6832 61 6870-6883 13 7014-7022 8 7032-7054 22 SPF PHASE 4 4 4 COMMENTS MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: HOLE ANGLE THRU KUP: LAST TAG DATE: RATHOLE: FISH/OBSTRUCTION: PBTD: PBTDSS: deg deg DEPTH 7278 6317 ] RECEIVED Alaska Oil & Gas Cons. uu. miss m- Anchorage REVISION DATE: 05/11/87 REASON: ~ARCO Alaska, Inc~" Post Officeb,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 26, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Ancho?age, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date I R- 1 4 Storm Choke July, 1989 1A-16A Tbg. Leak July, 1989 3 N- 1 2 Tbg. Leak July, 1989 If you have any questions, please call me at 265-6840. Sincerely, G.B. Senior Operations Engineer CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION ~MlSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging_ Time extension _ Stimulate _ Pull tubing _ Variance :X Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service . RKB 100 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 1409' FSL, 494' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1641' FNL, 902' FWL, Sec. 5, T11N, R10E, UM At effective depth 1333' FNL, 929' FWL, Sec.5, T11N, R10E, UM At total depth 1255' FNL~ 938' FWL, Sec. 5~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 741 1 ' true vertical 6 5 2 5' Effective depth: measured 7 2 7 8' true vertical 641 7' feet Plugs (measured) feet None feet Junk (measured) feet None 8. Well number 1A-16A 9. Permit number 81-31 10. APl number 50-029-2071 3-01 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 2456' 10 3/4" Intermediate Production 7 3 7 O' 7" Liner Perforation depth: measured 6771-6832, 6870-6883, true vertical 6015-6063, 6093-6103, Cemented Measured depth True vertical depth 286 Sx AS I 8 0' 8 0' 1000 Sx Fondu 2456' 2456' & 250 Sx AS II 1000 Sx Class G 7370' 6500' & 250 AS II 7014-7022, 7032-7054' MD 6205-6212, 6220-6237' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6944' Packers and SSSV (type and measured depth) RH Pkr @ 6699'~ WD Pkr @ 6920'; TRDP ~ 1840' 13. Attachments Description summary of proposal_ Interim injection during annular communication testing Detailed operation program X BOP ~l~etch .... 14. Estimated date for commencing operation ~ 15. Status of well classification as: . JuN. 1989 I Oil __ Gas __ Suspended 16. If proposal was verbally approved Name of approver Date approved Service Water I niector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMI,~ION't~E 0NL~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Commissioner IApproval No. Approved Copy Returned Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE 1A-16A Sundry Notice Annular Communication This notice is to request approval to continue injection into water injection well 1A-16A. This well has tubing by 7" annulus communication and is undergoing tests to identify the source of communication. Well 1A-16A passed an AOGCC wittnessed MIT on 10/4/88. The well's 7" pressure built to 2000+ psi in June 1989. No tree problem was found and the dummy valve in the lone GLM has been repacked. The 7" annular pressure on well 1A-16A builds to 2000+ psi when the well is injecting water at a wellhead injection pressure of 2550 psi. Upon bleeding the pressure to below 2000 psi, the annular pressure builds back to 2500+ psi within 3-5 days. The 2500 psi 7" annular pressure is well below the 4980 psi hoop stress rating of the casing (3400 psi at 70% hoop stress rating). The current testing program will attempt to confirm if the packer is the source of the annular problem. Further information will be provided as the testing program is performed. STATE OF ALASKA ( ~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well REV I SED (FRACTURE DATA) Classification of Service Well OIL ~ GAS '~ SUSPENDED ~ ABANDONED '~] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-31 3. Pl~.dr~.s Box 100360, Anchorage, AK 99510 8. APl Number · · 029-20713-01 50- 4. Location of well at surface 9. Unit or Lease Name 1409' FSL, 494' FWL, Sec.5, T11N, R10E, UN Kuparuk River Unit ,, At Top Producing Interval 10. Well Number 1641' FNL, 902' FWL, Sec.5, T11N, R10E, UN 1A-16A (sidetrack) At Total Depth 11. Field and Pool 1255' FNL, 938' FWL, 5ec.5, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk Ri vet 0i ] Pool 100' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/01/82 03/15/82 03/21/82I N/A feet MS L[ 1 17, TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey ! 20. Depth where SSSV set 121. Thickness of Permafrost 7411 'MD,6525'TVD 7278'MD,6417'TVD YES [~X NO [] 1840 feet MD 1650' {approx) 22. Type Electric or Other Logs Run D IL/SP/GR/SFL/FDC/CNL/Cal~ RFT, Gyro/CCL, CBL/VDL/CCL/GR, GR/CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62,5# H-40 Surf Rn, 24" 286 s.v. AS I! 10-3/4" 45.5# K-55 Surf ?/~r,~;, 1~.'!/~"; !000 s.v. Fond'_' & 250 s.v, AS I! 7" 26.0# K-55 Surf 7370' 8-3/~.'' !000 sx C!~.~. G & 250 ,x AS II 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER sET (MD) 6771 ' -6832 'MD 6015' -6063 'TVD 3-1/2" 6944 ' 6920 ' 6870 ' -6883 'MD 6093 ' -6103 'TVD 7014 ' -7022 'MD 6205' -6212 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7032'-7054'MD w/4 spf 6220'-6237'TVD I'"DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6968' 6970' 150 sx Class G See attached Well Service Reports dated 7/3/86~ for :fract,re data. 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) 3/28/'82I F1 nwi n~_] Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL i CHOK'E SIZE'1 GAS-OIL RATIO 6/9/82 2_~ TEST PERIOD I~ ')~;/~,) ~ ~c~- nI I ........ WAT~'R-BBL OIL G~/vCi~'Y-API (corr) 5'32 Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF Press. 260 -. 24-HOUR RATE a~' ?~ l~n~ n .,~ ~-o .~v~ v 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED FEB 10 J, o0.~ Note: Well was recompleted 6/10/86. Alaska Oil & Gas Cons. C0mmissi0a Form 10-407 in duplicate Aflch0ragesubm~t Rev. 7-1-80 ~C1/083 CONTINUED ON REVERSE SIDE GEOLOGIC'MARKERS FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6770' 6014' Depth H),dro. Press. Shut-in Pressure Base Upper Sand 6872' 6094' 7041' 3449 psi 2811 psi Top Lower Sand 7004' 6198' 6880' 3345 psi 2949 psi Base Lower Sand 7123' 6292' 6802' 3311 psi 2926 psi 31. LIST OF ATTACHMENTS Well Service Report (dated 7/3/86) ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' if this well is completed for separate production from more than one interval (multiple .completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for ea~!h additional interval to be. separately produced, showing th~ data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc! St~bsidi&ry of Atlantic Richfield Company CE,~TRACTOR REMARKS WELL SERVICE REPORT l FIELD ' D,~R,~o' 2TE IDAY~, iOA~, . . -3 J lk4. v'o/~/, 7' ,fo !1~ ~asl<a Oil ii Bas Cons. Commiss~g ~ ~ Anchorage l 0 ~ O ['-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK l Signed knots [ ARCO Alaska, lnC. B~^ Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal # 5898 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · ---3I-3 ~ 31-14 --31-14 z~31-14 .._31-12 --lA-5 -~iA, 16A --3N-17 ---3N-18 CET 5-19-86 6815-7828 CET 5-4-86 6690-8293 CBL/CBT 5-5-86 6590-8292 CBL 5-5-86 6588-8295 CET 5-4-86 6789-7344 CET 6-6-86 6270-7024 CET 6-6-86 3991-6976 CET 6-10-86 7446-8902 CET 6-10-86 8742-10500 Receipt Acknowledged: · DISTRIBUTION: NSK Drilling Mobil SAPC Anchorage Date.' Unocal Vault (film) Chevron ARCO Alaska, Inc. is a Subsidiary of AllanticRIchfieldCornpany ALASK IL AND GAS CONSERVATION ,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 7. Permit Number 2. Name of Operator ARCO Alaska, Inc. 82-31 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20713-01 4. Location of well at surface 9. Unit or Lease Name 1409' FSL, 494' FWL, Sec.5, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1641' FNL, 902' FWL, Sec.5, TllN, R10E, UM 1A-16A (sidetrack) At Total Depth 11. Field and Pool 1255' FNL, 938' FWL, Sec.5, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk River Oi 1 Pool 100' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/01/82 03/15/82 03/21/82 *J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'l'VD)19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 7411 'MD ,6525 'TVD 7278'MD,6417'TVD YESY~ NO [] 1840 feet MD 1650, (approx) 22. Type Electric or Other Logs Run D IL/SP/GR/SFL/FDC/CNL/Cal, RFT, Gyro/CCL, CBL/VDL/CCL/GR, GR/CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 b" 62.5# H-40 Surf 80' 24" 286 sx AS I I 10-3/4" 45.5# K-55 Surf 2456' 13-1/2" 1000 sx Fondu & 250 sx tS II 7" 26.0# K-55 Surf 7370' 8-3/4" 1000 sx Class G & 250 s~ AS II 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6771 ' -6832 'MD 6015 ' -6063 'TVD 3-1/2" 6944 ' 6920 ' 6870 ' -6883 'MD 6093 ' -6103 'TVD 7014 '-7022 'MD 6205'-6212 'TVD 26. ACl D, FRACTURE, CEMENT SOUEEZE, ETC. 7032' ,7054 'MD w/4 spf 6220'-6237'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6968' - 6970' 150 sx Class G 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 3/28/82J F1 owl ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/9/82 25 TEST PER IOD I~ 2642 1566 0 50/64I 592 Flow Tubing Casing Pressure CALCULATED =~ 'OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. 260 -- 24-HOUR RATE~ 2536 1503 0 25.5° 28. CORE DATA _ ,-, % ! ~_ ~'~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submi1~o~c~p~. [ I~ ~ None ........ Form 10-407 WC1/083' *NOTE: Well was recompleted 6/10/86. ., Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .' 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH TRUE VERT. DEPTH 6770' 6872' 7004' 7123' 6014' 6094' 6198' 6292' · 30. ', · ( i-,, FORMA¥10N TESTS · .. Include interval tested, pressure data, all fluids reccv~red GOR, and time of each phase. Depth Hydro. Press. Shut-in Pressure 7041' 3449 psi 2811 psi 6880' 3345 psi 2949 psi 6802' 3311 psi 2926 psi 31. LIST OF ATTACHMENTS None 32. I hereby certify that the fOregoing is true and correct to the best of my knowledge - Signed ~ ~ ~(J~Y~-~ Title Associate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' ClassificatiOn of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item. 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion); so state in item 16, and in item 24 show the. producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing too~. 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 i~, STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM .,.,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubingx~ Alter Casing [] Other:Xl~ :Recom~plete 2. Name of Operator ARCO Alaska~ Inco 3. Address P.0. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 1409'FSL, 494'FWL, Sec.5, TllN, RIOE, UN At top of productive interval 1641'FNL, 902'FWL, Sec.5, TllN, RIOE, UM At effective depth 1333'FNL, 929' FWL, Sec.5, T11N, RIOE, UM At total depth 1255'FNL, 938'FWL, Sec.5, T11N, RIOE, UM 5. Datum elevation (DF or KB) RKB 1 00 ' 6. Unit or Property name -Kupar,,k River Unit 7. Well number 1A-16A 8. Approval number Permit #82-31 9. APl number 50-- 029-20713-01 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7411 feet 6525 feet 7278 feet 641 7 feet Casing Length Size Conductor 80 ' I 6" Surface 2425 ' 1 0-3/4" Production 7340' 7!, Plugs (measured) None Junk (measured) None Cemented Measured depth 286 sx AS I I 80 'MD 1000 sx Fondu & 2456'MD 250 sx AS I! 1000 sx Class G 7370 'MD Wue Verticaldepth 80'TVD 2456'TVD 6469 ' TVD · Perforation depth: measured true vertical 6771 '-6832'MD 6870 ' -6883 'MD 601 5 ' -6063 ' TVD 6093 ' -61 03 ' TVD 701 4 ' -7022 'MD 7032 ' -7054 'MD 6205 ' -621 2 'TVD 6220'-6237'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 6944' Packers and SSSV (type and measured depth) RRH pkr @ 6699', WD pkr (~ 6920', & TRDP SSSV ~ 1840' 12. Stimulation or cement squeeze summary Intervals treated (measured) 6968' - 6970' Treatment description including volumes used and final pressure 150 sx Class G 7 1986 Cons, Commission Anchor3ge 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer (DAM) SW0/061 Date Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Inet~uctionl: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on t~e form giving inclusive dates only. District Field Alaska lCounty, parish or borough North Slope Borough Lease or Unit ADL 25631 Title Recompletion Kuparuk River State Alaska Well no. IA-I6A Auth. or W.O. no. AFt 894401 Nordic AP1 50-029-21492 Operator ARCO Alaska, Inc. Spudded or W.O. begun [Date [Hour Workover 5/30/86 Date and depth as of 8:00 a.m. 5/30/86 5/31/86 thru 6/02/86 6/03/86 6/04/86 6/05/86 Complete record for each day reported 6/06/86 0500 hrs. ARCO W.I. Prior status if a W.Oj 56.24% 7" @ 7370' 7278' PBTD, Prep to kill well Accept ri; @ 0500 hfs, 5/30/86. RU to kill well. 7" @ 7370' 7278' PBTD, POH w/mill shoe #1 10.4 ppg NaC1/NaBr Kill well w/50 bbls Bridgesai pill spotted to perfs, circ w/9.8 ppg brine. Wt up to 10.5+, monitor well. ND tree, NU & tst BOPE. POH w/3½" CA, chg out colts. TIR w/5-3/4" OS w/4-3/4" grapple, caught SBRmandrel, POH. Lower brine wt to 10.3+, RIH w/mill shoe, cut over 24" of pkr, POH. 7" @ 7370' 7278' PBTD, Fsh'g @ 7179' 10.4 ppg NaC1/NaBr POH w/shoe #1. RIH w/shoe #2, tag pkr @ 6597', cut over, POOH w/mill; no fsh. RIH w/4" spear, tag fsh @ 7179'. 7" @ 7370' 7278' PBTD, RIH w/7" retry BP 10.3 ppg NaC1/NaBr POOH w/fsh. RU Schl, perf 6968'-6970' w/4" gun, 4 SPF. RIH w/WL BP, set @ 7000'. RIH w/WL CR, set @ 6920', RD Schl. RIH w/stinger, sqz perfs w/150 sx C1 "G" w/.72% FL-28, .3% CD-31 & .2% FD-8. Dipl w/brine. Unable to rev out due to C sand perfs. POH w/stinger. RIH w/Bkr retry BP. 7" @ 7370' 7278' PBTD, Drlg cmt 10.3 ppg NaC1/NaBr Set retrv BP @ 5997', POE. Chg out wellhead. RIH, POOH w/retry BP. RIH w/bit, tag cmt@ 6802', begin drlg cmt. 7" @ 7370' 7278' PBTD, Rn GR/CET log 10.3 ppg NaC1/NaBr DO cmt f/6828'-6930', CR @ 6930' &cmt f/6932'-6997', POE w/bit. RIH w/R-3 pkr on 3½" DP, set @ 6910', tst psi; OK, POH w/pkr. RU Schl, RIH w/GR/CET log. ~z~ ~1~ E D J U N 7 ,..,, ,~_,,, Commissio,n The above is correct For form ~reparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting .the entire operation if space is available. D i st rict Alaska Field Kuparuk River Auth. or W.O. no. AFE 894401 Nordic 1 ICounty or Parish Lease or Unit Title North Slope Borough Accounting cost center code State Alaska ADL 25631 IWell no. 1A-I6A Recomplete AP1 50-029-21492 Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. W.I. 56.24% IDate 5/30/86 Workover Date and depth as of 8:00 a.m. 6/07/86 6/10/86 Complete record for each day reported Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0500 hrs. I 7" @ 7370' thru 7278' PBTD, RIH w/pkr on WL 6/09/86 10.3 ppg NaCl/NaBr RU Schl, rn GR/CET log f/7000'-4000', RD Schl. RIH w/bit, drl BP, POOH; possible junk in hole. RIH w/bit & JB, wsh metal cuttings off BP, unable to make footage, POH w/bit. RIH w/mill, mill up plug, chase dn hole to 7252', POOH. RIH w/6-1/8" bit & csg scrpr to 7154', POH. RU Schl, re-perf "C" sand f/6771'-6832 & 6870'-6883' w/4 spf. Rn 6.092" gage ring/JB to 7000'. RIH w/pkr on WL, set dn @ 5635'. Att to wrk past tight spot. 7" @ 7370' 7278' PBTD, RR 10.3 ppg NaC1/NaBr Set WL pkr @ 6913'. Rn 216 its, 3½", 9.3# EUE 8RD BTC tbg w/RRH pkr @ 6699', WD pkr @ 6920', SSSV @ 1840', TT @ 6944'. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/diesel. RR @ 0400 hfs, 6/10/86. AlaSka Oil 8: Gas Old TD Released rig 0400 hrs. Classifications (oil, gas, etc.) Oil Producing method FlOwing Potential test data New TD Date PB Depth 7278' PBTD JKind of rig Rotary 6/10/86 IType completion (single! dual, etc,) - · Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ATTACHMENT I I Drill Site lA KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Well No. Log Date 1A-4 7/6/83 1A-5 10/29/83 1A-7 2/8/82 5/7/82 1A-9 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 1A-14 4/1/82 1A-15 6/5/82 ~A~16~ 5/11/82 6/8/82 Drill Site .18 Well No. 18-1 18-2 18-3 18-6 18-7 18-8 18-9 Loo Date 12/26/81 6/25/81 11/16-18/81 3/12/82 11/18/81 9/10/82 11/23/81 12/28/81 8/4/82 6/24/82 8/3/84 Drill Site 1C Wel 1 No. Lo.9 Date lC-1 5/9/81 lC-2 5/8/81 lC-3 7/13/81 lC-4 11/8/81 3/9/81 lC-5 2/26/81 1C-6 ~" 11/30/81 1C-7 5/19/81 1C-8 ' 5/21/81 Drill Site 1D Wel 1 No. Lo9 Date 1D-1 ~ 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 ~_.~D-8 (WS-8) 5/i0/78 Oil & Gas Co,,~ ,. ....... Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date 1 q ilqr_~~ lZ/1785' Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo9 Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 2/19/83 1F-2 2/3/83 1F-3 1/31/83 1F-4 5/29/83 1F-5 10/25/82 1F-6 10/28/82 1F-7 11/19/82 5/7/83 3/!2/83 Alaska Oil & Gas Cons. Attach.ment 1~ Page 3 Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~li~.-~ll. 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site Well No. Lo9 Date 2Z ' ' 12Z~,._ 7/10/83 2Z-2 ': 6/24/83 2Z-3 ' 2Z-4 2Z-6 2Z-7 2Z-8 7/19/83 8/5/83 7/12/83 7/27/83 7/28/83. 8/3/83 VLF' pg' 0052 Alaska Oil & Gas Cons. Anchorage. Drill Site lA Well No. ~ 1A-4 ~1A-5 '~1A-7 ~1A-9 ~1A-11 %). '~1A-12 '~IA- 14 "~ 1A-15 ~,lA-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 716183 10129183 2/8/82~x, / 5/7/82/~ 1/25/82~.. ~- 3/23/83,./ ~. · 1/19/83'~ /- 3/21/83/ " 3/8/82 4/1/82 6/5/82 5/11/82~ ~ ~ 6/8/82/2 ~' Drill Site Well No. Log Date ~18-1 12/26/81 ~ 12/82/ ~-18-6 11/18/81~ ~, '~ 9/10/82/ ~ ~.. ~18-7 11/23/81 ~18-8 12/28/81"~ ~. '~ 8/4/82/ ~ ~18-9 ~ 6/24/82'- --- lB Drill Site 1C Well No. \ "~1C-1 '~1C-2 "1C-3 ',~1C-4 ~'~1C-5 '~1C-6 "~1C-7 "~ 1C-8 iLog' Date 5/9/8'1 5/8/81 7/13/81 11/8/81'~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 ~ Drill Site Well No. Log Date 1D '~1D-1 ~' 5/23/83 ..,"- '''''ID-3 8/5/80 1D-4 ~7/30/80"~ --, ~ 8/13/80/ ~ ~ ~lD-5 6/11/81 ~1D-6 6/9/81 ~-1D-7 6/8/81 X'JlD-8 (WS-8) 5/10/78 · RECEIVED FEB 2 1 1986 Alaska 011 & (las Cons. Commission Anchorage TO SUBJECT JAT DATE .,.Sor~ 4bo-I- Urhcsc hc:!.vc hov"c 4 SIGNED I!1 ~f o. n vonc hc~a qxc~--hon~ Or- DATE SIGNED I~ir-~le 4S 469 POLY PAK ($0 Sets) 4P 469 · . SEND PARTS I AND 3 INTACT. - PART 3 WILL BE RETURNED WITH REPLY. ( STATE OF ALASKA ~ (M ALASKA 0IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK Location of Well Surface= 99510 1409' FSL, 494' FWL, Sec.5, T11N, R10E, UN 7. Permit No. 82-31 8. APl Number 50-- 029-20713 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-16A 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 100' J ADL 25647 ALK 465l 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well I~ Change Plans [] Repairs Made Pull Tubing [] Other l~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (C early state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-16 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally~bested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: December 4, 1985 ov.2 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space belo{~ for Commission use Date Conditions of Approval, if any: Approved by Approvect Copy Jteturrted By Order of COMMISSIONER the Commission Form 10-403 (JLQ) SN/113 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TO: Willism VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI0WASE NOTE: BL -. BLUE~INE, S - SEPIA, F - FILM, T - TAPE, ~ - PH~PY~ · ~ ACKNO~.~qDGED: DATE: A!aska 0il &,~Gas.,~h,,Cons.,,,,,,, Commission ~l~N: LORIE L. JOHNSON - AF~/B ll P. O. BOX 360 · ' ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TO: DATE: .~~ /~-~~ FROM: D.W. Bose/Lorie L. Johns'on Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED ATE: PLEASE RETURN RECEIPT 'TO: ARCO .ALASKA, INC ;~nch~ra~e -' ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 995'10 ARCO Alaska, Inc. Post Office B~"-- 50 Anchorage, Al~o~a~ 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Coma. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: · Enclosed are well completion reports~.for Kuparuk Wells lA-10 through IA-16A. Very .~truly yours, . ~/J. S. D~yton JSD/er cc: L. K. Blacker -AFA 330 w/o Attachment L. M. Sellers -ANO 332 w/Attachment E. A. Simonsen -AFA 311 w/Attachment H. C. Vickers -AFA 326 w/o Attachment ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany O("' STATE OF ALASKA .ISS ALASKA AND GAS CONSERVATION COf~ ION . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE E] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 82-:~1 3. Address 8. APl Number P.0.Box 360; Anchorage: AK 99510 50- 029-2071:~-01 , 4. Location of well at surface 1409'FSL? 494'FWL, Sec 5, T11N, R10E, UN 9. Unit or Lease Name Kuparuk River Unit At Top Producing lnterval 1641'FNL, 902'FWL, Sec 5, T11N, R10E, UM lO. WellNumber 1A-16A (sidetrack) At motal Depth 1255'FNL, 938'FWL, Sec 5, T11N; R10E, UM 11. Field and Pool Kuparuk River Field ,5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. IO0'RKB ADL 25647 ALK 465 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 3/01/82 3/15/82 3/21/82 -- feetMSLI 1 17. Total Depth (MD+TVD)7411' 65251 18.PlugBackDepth(MD+TVD)7278,6417'YES19' Directional SurveyE~ NO [] I20' Depth where SSSv set1884' feet MDI21' Thickness Of PermafrOst1650' (approx) 22. Type Electric or Other Logs Run DZL/SP/GR/SFL/FDO/CNL/Oal, RFT? Gyro/COL, CBL/VDL/OCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE: WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lg" g?.5¢~ H-4O Surf 80' 24" 286 sx AS II 1fl '~//," 45.5¢t K-55 Surf 2456' 13 1/2" 1000sx Fondu & 250 sx AS II 7" ?A~t K-55 .q~mrf 737[1' 8 3/~" 1000 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and ., 25.. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6771-6832 ' 3 1/7" ~:;ARfl ' 66~ ' 6870-6883 ' , ' :'~ 7014-7022 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7032-705'4'~ w/4 SPF //~ .DEPTH !NTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A - i - · , 27. P'RODUCT~ON TEST Date First.Production -, I Method of Operation (Elowing, gas.I ft, etc.) 3/28/82I Flowino . , · Date of Test Hours Tested PRODUCTION FO~ OIL-BBL GAS-MCF WATER-BBL CHOKESlZE GAS-OIL~ATIO A/9./R? ?5 , TEST PERIOD I~ 76~? ' 1566, fl 5fl/Aa,, 597 Fl~)~v-T'ubi~g Casing Pressure , CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GI~AVlTY-API (corr) -Press.?Arj _- .. 24-HOUR RATE I~ ' '75~'~ .15n~. .0 25 5° 28. CDR E DATA - , . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. N/A ' .'"' ' ~ : '.. ,, ' JUL :t 4 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in dUPlicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6770' 6014' Base Upper Sand 6872', 6094' Top Lower Sand 7004' 6198' Base Lower Sand 7123' 6292' 31. LiST OF ATTACHMENTS ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~_ (~ ,(~~~--'~// TitleRegion 0ps. Engr. Date '7///Z/~7-- 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 thi:s~,well is completed for separate production from more thanone interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 KUPARUK ENGINEERING TO: DATE: TRANSMITTAL FROM: WELL N~14E: Transmitted PLEASE NOTE: herewith are the - BLUELINE, following: SEPIA, F - FILM, T - TAPE KUPARUK ENGI.NEERING TRANSMITTAL .'--.' ~ TO: /~' ~~ FROM: D. W. Bose/Ann Simonsen DATE: .~/~//~_ WELL NA/4E: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE /.,,~A-SE RETURN RECEIPT TO: '. ARCO 'ALASKA, .INC. : . ~i~' ~ ' - ATTN: ANN SIMONSEN - AFA/3tl P. O. BOX 360 .' ANCHORAGE, AK 995t0 .. ARCO Alaska, In Post Office c~ox Anchorage, Alaska 99510 Telephone 907 277 5637 May 26, 1982 Mr. C. V. Chatterton Commi ssi one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Rorcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - Kuparuk Dear Hr. Chatterton: Enclosed are well completion reports for the following drillsites: ~!~I~A~,~ 6A, :~ ( Sz de t r ac k ) 1E-9 1E-10 Also enclosed are monthly reports for April on these wells: 1E-11 1H-5 Sincerely, ~.^. Van Dusen ~e~ional ~rilling Engineer PAV/OG:llm Enclosures GRU6/BZ; ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~ · . ALAS~.' .. AND GAS CONSERVATION[ ..~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, 1:nc. 82-31 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 ' so-029-20713-01 4. Location of well at surface 9. Unit or Lease Name 1409'FSL, 494'FWL, Sec. 5, T11N, RIOE, UM __ Kuparuk River Field At Top Producing Interval LOCATIONSi 10. Well Number 1641'FNL, 902'FWL, Sec. 5, T11N, R10E, UM VErIFiED 1A-16A (Sidetrack) SorfL ~ 11. Field and Pool At Total Depth 1255'FNL, 938'FWL, See. 5, T11N, RIOE, UN ~t F.~__. r_ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/01/82 03/15/82 03/21/82I N/A feet MSLI 1 17. motalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 7411 'MD 6525' TVD 7278'MD 6417' TVD YES~ NO [] 18841 feetMD 1650' (Approximat:e) 22. Type Electric or Other Logs Run · DIL/SP/GR/SFL/FDC/CNL/Cal, RFT, Gyro/CCL, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 286 sx.AS II 10-3/4" Z~5.5# K-55 .Surf 2456' 13-1/2" 1000 sx'Fondu & 250 sx AS II 7" 26.0# K-55 Surf 7370' 8-3/4" 1000 sx Class G , · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ]'~i]"-¥OB'ING RECORD interval, size and number) SIZE DEPTH SE~ (MD) PACKER SET (MD) N/A 3-1/2" 6680' 6607' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production '1 Method of Operation (FlOwing, gas lift, etc.) N/AJ , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~ TEST PERIOD t Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A "'RECEIVED . , MAY 2 6 ]982 A!~ska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GRU5/B30-6/AI&2 ' 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 6770' 6872' 7004' 7123' TRUE VERT. DEPTH 6014' 6094' 6198' 629~' GOR, and time of each phase. N/^ 31. LIST OF ATTACHMENTS Drilling Hist:ory~ Gyroscopic Survey (2 copies) 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~---C'~l~-, ~)~,~~ Title Senior Dr lg Ener ' 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 we~l is completed~for separate production from more than one interval (multi.pie completion), so state in itc'? 16, and in item 24 show the producing intervals for only the interval reported in item 27'. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: A}tached 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 DS 1A-16A Drilling History NU Hydril & diverter. Spudded well ~ 0930 hfs, 03/01/82. Drld 13-1/2" hole to 2470'. Ran 59 its 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe ~ 2456'. Cmtd w/lO00 sx Fondu & 250 sx AS Il. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd formation to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7722'. Abandoned 1A-16 (RBTD 4400'). KO ~ 4400'. Drld 8-3/4" to 7411'. Ran DIL/SR/GR/SFL/FDC/CNL/Cal. Ran RFT. Ran 179 jts 7", 26 #/fl, K-55, BTC csg w/shoe ~ 7370'. Cmtd 7" csg w/600 sx Class G (lead) & 400 sx Class G (tail). Instld 7" packoff & tstd to 3000 psi - ok. Tstd 7" csg to 1500 psi' - ok. Arctic packed 7" x 10-3/4" annl w/300 bbl H20, 250 sx AS II, & 100 bbl Arctic Pack. Displ well to NaC1. Tstd csg to 3000 psi - ok. Drld cmt to 7278' PBTD. Ran Gyro/CCL f/PBTD to surface. Ran CBL/VDL/CCL/GR f/PBTD to 2000'. Ran 3-1/2" completion assy w/tail ~ 6680' & pkr ~ 6607'. Tstd tbg hanger & packoff to 3000 psi - ok. Chg over ~ 6680' f/NaC1 to clean diesel. Dropped shear sub ball & set pkr. Tstd tbg to 3500 psi & annl to 500 psi - ok. ND BORE. NU tree & tstd to 3000 psi - ok. Pulled BPV. Tstd tbg to 3000 psi & annl to 200 psi - ok. Closed SSSV ~ 1884'. Secured well & released rig ~ 0600 hfs, 03/21/82. 3G:llm 05/17/82 GRU3/B15 RECEIVEI) MAY 2 5 1982 Oit & Gas Cons. Commission ^nchorag~ ARCO ALASKA INC, ' PAll ......... iA, t,JEL.~ NO1 1,.) ~'f-~ ~ GbiS ...... .~r~B Nf'~, ~ AO382G0418 KLIPARUK ~'IEL..r~ NORTH ,..LUFE.~ AL.A~KA GMS, 0 .... 728(} ~4D, SL.IRVI~JYOR~ B JAHN DATE RUN~ 19-.NAR-82 RIGI ROWAN S4 GYRO1 562 CAMERAI 1644 A/U 90 DEG~ 11t0 SIGHTZNGi S00E VERTICAL. :.:.';ECT ]: ON CAL. C'UI_ATE:[~ IN PLANE OF' F'ROF'OSAL DIRECTION~ N 90EG, 43 MIN, E RECORD OF:' SURVEY '9' k°., RADIUS OF CURVATLIRE AD IA, WELL. NO~ 1.6A GHS' ,JOB NO~ 'UPARUK FIEL. D, N~qF.:TH ,.:,LLFE, AI..ASKA T R U E ,::~URED DRIFT DRIFT COURSE VERTICAl_ VERTICAL OE. RTH ANGLE DIRECTZON LENGTH DEF'TH ,.~:.L-TIONR ~'-' F E E T i) f'i D M F E E T F' E: E T F E E T AOS82G0418 SUBSEA T ~-~D F' E E T R E C 1' F: Fi 0 1::4 CO?iF'UTAT ION' T I i'iE DATE 1,':,* . · -, ~ 48 ~ 45 .-,o " ~.'~.~ .'.o-AF R-"_ ' F' A Gr-!: ?40. 1 A N G LI L. A R C L 0 I) I i'4 A T E S TJISTANCE F'EET FEET U R E I)OGLEG DIRECTION SEVERI'T'Y ]] N D G / 100 F T .... 0.-. 0 0 0 0 0. 0.00 0.00 100. 0 0 0 0 100. !00. O0 0 ~ 00 200. 0 0 0 0 100. 200.00 0. O0 SO0,,. 0:30 S 33 () W 100. 300+00 -0.40 400. 0 4,5 N 59 30 E: 100. 399.99 -0°87 -100.00 0.00 t0()~00 200.00 299.99 0.00 0~00 0~00 o7 0~94 0.00 0.00 0.00 0.00 0.00 0.00 S 0.24 W 0.44 S 0.31 E 0.99 0 0 O. O0 0 0 0.00 0 0 0,00 S 33 0 W 0.50 S 18:1.7 E: 500., 0 30 N al 0 E 1(':,(3 499,9':-" - · ....... :, -0., 05 600+ 0 45 N 27 30 E 100, 599.98 0~94 700, ;3 4'~'".::, i',,' -49 30 E 10,'"' ..... 699 9/'-' 2,,08 800, 0 "~':'' i"J '77; ...... 4., .......... ':") E 10C:,. 7'.-/v. 96 ;:: .~ ,_,~"7" 9'00, 0 15 N :_54 0 E 100+ 899:96 S~.48 399+99 499~98 599.97 699~96 799.96 0~24 S 1~14 E 1.17 0.65 N 1.76 E 1.87 1~67 N 2+57 E 3.06 2.28 N. 3.7')~ E 4.36 2°77 N 4~41 E 5.21 c. 77 o/='""E 0.S2 ..) c., ;- ,:.,.5 E '2', 29 N 56 54 E 2,~29 N ff.;8 ..30 E 0.7S N 57 '::'0E r, 58 i000,, 0 SO S 41 0 W 10()+ 999,9'6 3,68 J. lr',F;, i C) c. ,':' ...... ',2 "'; W 100. 10'-"-' 95 ~ ........... .-, ," · 2 6.'3 1 '::' ;'" ;", i 1 '::' S =; ='; ,"', W 100 · ,, .......... , ....... 1199 93 1.,19 1-SO0+ :l 15 S 57 .5:;0 W 100+ 1299,91 -0,34 1400+ I ~= S 5;o ,"', W 1.000 13o9.88 -:1..7c' o~ .'9 .:. 9o 99?., O "-' ., ~,.1 1099 · 93 1.199 + 91 12ge' ~;8 ,04 .14 0.94 0.30 1.46 4+07 E 5+08 3.12 E 3.78 1.56 E 1.82 0.23 W 0.38 ~ O-q W 2,54 N 5 S i 5 E 0.75 ,_,,. 34 E: O.,_=;,..: ~ N 58 Y:;3 I:[ 0 '-"::' ..... :3 ,37' 31 W 0.10 · _.,4 48 W r,,O]. .1.....,,u 0 · 1. I Y; ...... S 6~:. ''') o W I. 0 o, 1499,. 8,=':, -,_,+'~ :t. 9 1600+ :1. 0 S 68 (} I;J 1.00. 1599.84 --.4~31 17;'~0. 1 ,.~ c. /,a 0 W i00. 1699.82 -' -- ,, , ..... -".~', + 27 1800. 0 30 i'4 SO 0 W 100. t799.8t -5~12 1900, C, 1.5 N 2 3(} E :t. O0.. 1.899,81 -4.53 !. 39'9.86 :I. 499.84 1 =' :q 2 099 ...... t699,8t 179'9+81 2 + ":'" C:; '~ · · _sA ._ o (5'6 W 4.72 :.=5.+.]58S ,...=+74 W 6+67 4~,')g'=. S 7.-z4..: W 8,40 3+77; S 8.47 bi 9,27 · -z :1.'-' "" ,c: 63 W o · -'. . :1. 7' · --' + 0 4 S 57 '1.''').,~. W 0.0'2 S r.:' ¢*' ;,' '" · J V :.29 l.J 'q + 2:: ~.:: S 60 50 W 0 S 66 9' tO 1 S 70 ,c.:;I,,J 0. ,.~ Z 2000. 1 15 N ::29 0 E 10o 1'-7'99.80. S+ '~'~ °,i. 00 I c:, N 49 0 E 100 ~090 78 1,54 '-' "~ ", C + 5 . ":i ...... .,:.,.:.(..: .:)I _I...N ... 1 0 E 10(', + 2199 76 -0.04 ..... 2300. . I 0 ?'J 43 C,:, E 100.., ' '~ '") 9 9,,:. .,= ';'4 I ., ="~ 2400,, 1. 7,0 N .,:I.:.::'. S0 E 100. 2399,, /::-:: ~.,=.-./' 1.899.80 1.? ./~ 2099.76 2199.74 :L .87. ,...c 8.o8.,... W 8.48 0.35~c:; 7+0"='. ,_, W 7,06 0+91 N ._,=',54 I/J 5.62 · ")-~'~ I:.:' .,-..,=:,_, N 4,11 W 4,68 '= -'-' iW "::' · 5 4 W 4,5 ~:' · .., , / / S 77 16 W 1,OS S 87 9 W 0.46 N 80 40 W 0.25 N 61 17 W 0.29 N 34 0 W 0,51 2 50 o. "':':1. 5 ,= N 49 30 E: :I. 00, o49o 67 ~:; 82 ._,uO.. 2 :.'.gO N 48 ,5;0 E: ':J. O0. ~.'")599+5.8 270 .... o, ._.z, 0 N. 2 ='., 0 E 100. ,=o'">, o, 9. ,:.°9 1 ,..~:;, 5.," 8 .2800. 9 o ...... i'4.J 2:30 E 100, ,=."')70'''~,o,4©.,. 28+44 2900, 13 15 ........ N 1'."., 30 E: 100+ ") :::; ° 6 ,, 5 ';,= 47,7:2: 5'}:c,:'9o67 5.92 N 0.07 W 5.9:2 '=' 4 '""-' ~ 8 8 ~ 64 ?-4 '~ "':':' 0--, g ,:. 7 ::, , _ 16 --% ~-'.' ~"% ~% 2~?] -'.' '-1 --t -Y ~:: ,.., 77 , :L 4 ~ '::',.5 N .,' -, :: . 45 E 2A9~q 4':' 26 87 ?4. '~ 1,64 E 29,":~8 27c./A, 5:2 4~':'.., + 77 ?.,; .1. 5,49 E 48. S'') N 0 ,1 :_-z, W 0· ...... / ,..,' N. 1. (;'. 28 E: ,:';.., z.'-:.J ~':' N 27 9 E 3,8 4 ?'4 '::?:326 E 3.40 N 1.8 4'"),:. I::: 4. '?7 ?<CO AL,.ASKA INC, AD lA, WEI...t... NO: 16A L.IF'ARUI'~ F'IEL..I'jl, NORTH GMS SLOPE, ALASKA JOB NO ~ <5: A._,° U R E I) D F.: I F' T :0 E F' T H A N G L. E F E E T D N TRUE:_' DRIFT r2OURSE VERTICAl_ VERTICAl.. DtREC-t"ION L_ENGTH--.DEPTH SECTION D N F' E E T F' E E T F E E T ~t0~ 82G;3'418 T I M E ri A T E 1 ":' ~':' 28 -- -" ..,: 4:3: 4.., AF'R :-.~2 SUBSEA T V D F:' E E T R E C T A N G U L A R C 0 0 R D t N A T E S FEET CLOSURE DISTANCE DIRECTION F E E T D M SO00, 16 SO 3100, '~ 15 S200, 22 45 S 300, ~'-' =' 1 5 3400, ~o 0 N- tl SO E 100, .... 2-99-3,-].6 - 73,S9 N 1'? SO E 100 S087 4~ lO6 N 20 0 E 100, :179,84 ].44.~i'~ N 22 0 E 100, S271,19 184,40 N..,.":""~. 0. E :l. 00 ,. S'~60,58~. 228, ].8 2893,16 70 ~'A ' ....... · ,~_N ...... 2Q .b,3_ 8 E ~7~'* · 4~ 10S.40 N ~°7.~8~ E S079~84 140,11 N S7,98 E :5171,19 17~' 08 N 52,~= E 3260,58 219,AS N 69oS4 E 7S,83 N 16 2 E 106,94 N 14 47 E 145,17 N 15 10 E 185,67 N 16 27 E 2S0oS1 N 17 31 E N~.~'":""~ ..... SO E 1 O0 ~ .~448, OS 275;, =;o_.~ N 2'-' S 0 l.r.': 10,'"',, -z ~.'-, ....~ ... ,~3, .... 63 .~..-.',-""'=, 91 N 23 ,"',Iii: :l.O,"', :'417~0.1. :57o,68 N 23 0 E 100, 3697,91 436~,88 N. 2a, o,. ~:."" lO0_. , 377,4,98 496,34 334F:, 0',-3 34.=-~ ~...-~ 3517,01 :559' 7 . 91 3676, c;.$: 264~50 N 87,70 E · 3; 1 '-) '-"::' ..-_,,::,., N 107,48 E 36S~ .1.4, N. 1'-~::3,8'-)~. ~ E 4.t. 7.~25 N 151,78 E 47.3.,S9 N 176,19 E 278,66 N 18 21 E 330,23 N J. 9 0 E 385,32 N 19 32 E 444.00 N 19 5;9 E 50.5,1..° N 20 ~."~5E 400C:,., ,¥8 J. 5.; 41 ,.h c) '"' ,"', ~-" ..... . ,~. o 1 ,..~ 4'-.20¢5, 38 50 4:500 ~ .S 8 'S 0 4400. -zo 30 N 24 "; E :1. 00 · S u,..,._,, 51 5 ,_, 6 · 3 S N 23 2;0 E 100, 3934,04 616,.39 N 23 SO E ].0<)~ 4012,44 676,69 N 23 SO E 100~ 4090-;7'0 ............. 737~.15 N 22 ,:'-:, E 100, 4168,96 -/97,79 3834~04 3912,44 3990~70 (~ 0 4.~6~,~96 566,92 N 20 48 E r..-,o 75 N 2!1 6 E 690.79 N 21 19 E 753,00 N '2.1 :50 E 815,2:5 N 21 S5 E 4500~ 36 45 4600~ 34 0 4700, 32:1.5 4800, 32 0 4900, 33 30 N 20 0 N ]. S 0 N z. 0 N 0 'S 0 N 0- .S 0 :[00~ 4248,16 857~66 1000 4329,69 91=',10. ~ _ J. O0, 4413,43 969~71 t00, 4498,1.2 1022~5S ].0()~ 4582,22 1075,9S 4:[48, 16 ~ "p"> 9 69 4S 1 .-.~_., 4"z._: 4S c;'8 · 12 4482,22 815,03 N 321,84 E 870,50 N 338~27 E ;,,24~.-4.4 N '-'""" 28 E ..... :, .q. / · 977,4:"4 N 3'.":;0,29 E 1,";31 ~"S N .%!:50,7"' ..... , .... / E 876,27 N 21 33 E 933,91 N 21 14 E 987,45 N 20 35 E 10S8,:51 N .1.9 4:3 ;:il ..,.. /~.~ ~.~ ... uo7,5"~, N 18 47 E 5000, :56 0 N 0 30 5100, 37 SO N 0 30 5200, .S9 () N i 0 · _,Y, O0. 40 '~ ~'' N 2 ,. 4 .:, 0 5a00 ~ ,'.'~'.-, "~ .... 40 N 2 0 E 100, 4664,:58 1132,19 E 100, 4744,50 1191,25 E t00, 4823.03 1~'='''z-,~:. 40 E .1.00, 4899,7.7 13i5,85 E J. 00~ 4974,38 1TM --,e. 4 · Sc:',., 1088 · ..,~:'"'...: N ..351,26 E 4644.5 o i I:TS-~N ~ E 472:::3~.0L3 1210,25 N 352,60 E 47'99...7'7 1274.34 N 3'.:':J4.27 E 4874.,38 1._,-z40,88 N S'.56..60 E 1143,79 N 17 53 E 1201.02 N .1.7 2 E 1260,57 N 16 1= E.., 1322,66 N 15 S2 E 1Z, 87.49' N ].4 54 E ,-,,,00~ 43 .4,: N ,,"zSO.. "..560C', 44 .t. 5; N 3 0 5700, 42 30 N :3 () ...,ouO., ]. :3;0 N e, 5900. 40 4~:' -" S0 .... ,i",! .:'. i:.-". J. O0, 5047,21 1449,84 E 100, 5119,15 1518,86 Ii.':: J. 0 O, ..=; 19' 1 · 8:5 1 oc., =' "' ?', ,07. E 100. 5266,15 165S. 55 E ].00~ 534t .47 1718,94 4947. ? .~.'>:L 5019 .,. 15 .5091 ~ 8:5 5166.15.:.; 5241 +47 1409 .%2 N -'¢:59 88 ].478~di, 7 N S6:5,82 04/ ,~.-.., .... ~'..~. :547_, · 4'~.- 1614+05 N 371.,.21 :L 679.70 N. 375; · ~'. ~, "" '" 1454.54 N 14 20 E 1522.77 N .1.3 49 E ..,90,.Cu N ].~ ..:.2E 1656,j. 9' N 1 '> ,5.57 ,. E i)'21,10 N 12:56 E NO. , 2 B 0 G L. E G S E V E R I T Y ZiG/100F'T 3,26 5,76 2,63 2,01 2,25 05.2 2,50 1,17 C:,, 00 0 ,, .31 0, ,c.: ,..J (), 00 4 . 89 1., L, .,,' '-' 50 1,50 i ,5,'-3 1 · 86 2,00 1 0 · 61 1,05 0,75 RCO...AL.ASKA INC, qD IA, WEL. L N.O; J. 6A GMS UF'ARUK F'IEL.O~' NORTH SLOF'E, ALASKA JOB NO~ AOS82r~r, 418 COMPUTATION ' T I M E D A 1" E 1',:3 ,~ 48: 45 28-AF'R-8'2 .-' F'AGE NO, 3 TRUE '"ASURED DRIFT T.~RIF'Y' COLtRSE VERTICAl_ VERTICAL SUBSEi& R E C 'l' A N G U L A R C L. 0 S U R E DOG/..EG [;EF,]'Ft ..... ANGLE I)IRE:CTION L. ENGTH~ DE:F, TH ....... SEC]LION TVD C 0 0 R D I N A T E: S DISTANCE DIRECTIOi'.~ SEVERI'/Y F'EET D H D H FEE'T' FEET FEET FEE;T FEE:T FEET D H DG/IOOFT .,6000-. ..... 40:1.5 N .73 S."; E~. 100 ...... ..417.z,.1 ....... l_7~J 50 52;17.51 1T-"4-i.53 N ,~'7~.].9 E 1785.26 N 12 16 E 6100 ....... 40 0 N .-1 0 E 100. 5493.98 1847.59' ~"""93;.98:. 1808.8:5 N S83.41 E 1849.02 N :1.1 58 E 6~.00 40 0 N S .'_fO E:: i00, 5=70 =-o 5; ':' 5 " ' o ,do 19'11, S 54,0+ 8 1g:v.o 9'7 N 3;:-<7,A1 g 191~ 66 N 11 42 E 6S00, S9 1=.'-_., N S S0 E 100, 5647,60 19:74,93 5547,60 19S6,6S N S91,50 E 1975,81 N ].1 26 E 6400, S8 45. N. S S0 E 100, 5725,,_,.~:) 203;7,4g' ..,62=: ~;_,,,-~2 1999~45 N. .:.~._,,=.' ~.-~5 E z"038,:1.6 N 11 1:1. E 0.50 0,41 0.32 0.75 ,4500, ,.,:°._, 45 N ,7, 0 E: 6600~ SE: SO N S O. ~' 6700, S8 30 N 3 30 E 6800. 3;9 0 N S S0 E 6900, 38 S0 N 5 3;0 E 100, 5803,S1 2099,68 .570S~,-.-'.:1 2061,94 N I~'",;'~ 5881 43 21A~,67 ~'7E:1,43 21~.:.1,27 N :1. 00, 5959,69 '.-::22S, 5S 5859 ~ 69 2186,42 N 100, 60S7~68 2285,75 59S7,68 2248,90 N :].0,",. .,.. 6].1=. 67._, . · ._'?S47,97 .60i='~67.., 2Sll..3;7 N ,5:H.F':9_.. E ~_.7100.17 N 10 ._,='7 E ~ L ,:· i 6 E .-~ J. 62 · 00 N. 1 r,._. 4 ,.'~, E: 4C)F;.Ac;', E: 2223.74 N 10 ._.'Zl E: 409.51 E: 228,5.88 N 10:1,';' E: 4 :t .:-~, 3; ¥ E 23; 48,04 N .1. 0 8 I::: 7000. 37 45:; N 4 S0 E: 7100, 3;7 C, N 5 3;3 E 7:200.~ ..-5:6, 0 ?4 6 .::~0 I.'7 7250, :.36 O. N -:', o.. E: 100, 6J. 94.34.: 2409~40 6094.34 2372.96 N t00, 6273,80 2469,90 617S~80 24SS,43 N ].hr,+ '6354 19 ~,~'o +~5 9 ~'-' .... · ~o~.9 ~, 6254.1 2492.~8 N 50 6394°64 ~:,.,~.60 6294~64 2521./7 N 417.64 E: 2409.4S N 9 59 E: 422.93 E: 2469.91 N 9 52 E: 429,15 E: 2529,26 N 9 46 E 432,60 E 2558,60 N 9 44 E 0,97 0~7C) 0,59 HE: I::OLt...OWIh/G E;TAI'IONS ARE: PROJE:CI"ED FOR ]:N'I'ERPOLAT]:Oh~ VALUF!:S 7280. ~6 0 N 7 0 E: St:}~ 641 ~'. 91c., ::'.'576 · "~2,:. ,5o18.91"" . ~:'-~ 5"z.~' .2'7. N 454, -"'.:5/_ E ~ 576. o ~, . ~ N 9' 43; E 0,00 41J. MD --. 1'I) 7-111, 36 0 N 7 0 E 1AJ.. A~-'-' '~ ~. ,-o-'.-~.89 °6.- .-,e..13 6424.89 2615,'70 N 2653,13 N 9 3;8 E 0.00 FINAL CI_OSURE - DIRECT]:ON.~ D ]: STANCE: ~ N 9 I)EGS 38 Fi INS :1.2 SECE; E 26~:· .., 3; · 1 S F' E E T ARCO ALASKA Ib,IC~ PAI) lA., IJELL. NOS 16A GNS NUF'ARUK F:IE[..i), NORTft ~L:FjF'E ~ At..ASF~;A GNS~ 0--7280 HB~ E:URVEYCIR$ B JAHiW RZGI ROWAN S4 G" ":'~ ...... ~R[-]~ 562 CAMERA~ t6~ A/t~ ~'o OEG lI!O ~ Z G H T I N G ~ S 00 E ( W E L. L H E ~ I) ':, · JOB iWO~ AOS82G0418 DATE RUN~ 19-NAR--.82 RECOR[; OF INTERF'OLATEI:; SURVEY RCO. ALASKA INC ~AO lA, WELL NO: 16A GHS' .JOB NO~ A~-" ...... '-'"' _ ~,,::,.~: L~ 0 41 ~ TI ME DATE UPARUK FIELD, N. OF;:TH. SL. OPI:i;, At~ASKA t5.~51 .~47 28'"AF:'R-82 MARKEF;,.' .............. TRUE SUBSEA CODE ---': ........... NEASUF;:.E]] VER. TICAL MO-TVfl VERTICAl.. F;.: E C T A N G U L A R C L 0 S U R E ',=;'=---.'~===-..NA/"iE ............ ~ ..... · ]:)EP]'H DEPTH .............. i"~IEK .......DEP.TH C 0 0 F;; []I N A T E S DISTANCE OIRECTION FEET F:'EET FEET FEET FEET FEET r_~ M COHF, UTAT-ION . F'AGE NO., 1 V E R T I C A L. TH I CI'-;:N E S S .TOF' OE....UF~E!IER .SANDS 6770,.00 ..... 6014 .... 29. .......... ,-¢.55,_Z ....5914o.29 2230,15 N BASE OF' L.tPPE;R SANDS 6872,00 6093,83 778,2 5993,83 229.7,,88 N TOP OF' LOWER SANDS 7004,00 6197,52 806,5 6097,52 2375,38 N BASE OF:. LOWER SANDS 7123,00 .6292,2..9 ...... 830,2 6192,2.9 2447,03 N r'B]Z ~o-~o O0 6417~°9 860,/ 6~17~29 "'~:' .... ~,, ~ =.,.,38,1"~,, N. 408,37 E 2267,2S ..... N 10 23 E 412,26 E 2S30~63 N 10 11 E 417~85 E 2411,85 N 9 59 E 424~56 E 2483,56 N 9 50 E 4S4~61 E ~/~'-~,04 N ~, 43 E T D 7411 00 A~'° ' 5 , , · _0.,:.4 89 886.,1 A424 ,:.,o · _ ,c:: 261 ,70 N 444 13 E 2653 13 N '9 38 E RRCO RL'-RSI~R INi:.~-- PRE]; :IR.' :NELL : 161t 'GMS CER TilCRE-- PRO:JE BCRLE I' iN,'-" ~= ~oo0 'FE[i~ --KUPRR - [ U_K._ :F ! E_kO,~: N_OR__T_~__:_$_LO! '_Ez_. :_R.L. RS*R .. I I ' i J 45Oo' i ' ' . . 5000 ' 1 Suggested form to lm ±nsertcd in each "Active" well folder to 'dleck for tin'~ly cc~mpliance with our regulations. · Olmrator, W~ll NareS'and Number Reports and Materials to bo received by: ~-~0'--~ Date Rc:(luired Date Received Remarks Dire~ional Su~ey KUPARUK ENGINEERING TO: TRANSMITTAL # ~ ,, V/OJ~/4'L~ FROM: D. W. Bose/Ann Simonsen Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE  EIPT ACKNOWLEDGED: /.PLEASE RETURN RECEIPT TO: " l~,ti&~ot'age ARCO"ALASKA, INC. '.ATTN: '.ANN SIMONSEN - AFA/311 2~£~C~O~GE ,. AK 9 9 510 KUPARUK ENGINEERING TRANSMITTAL # ~O TO: ~ ~~ FROM: D. W. Bose/Ann Simonsen DATE: t~- / ? -~ L WELL NAME: //~-/~ Transmitted herewith are the following: PLEASE NOTE: ~-BLUELINE, ~ SEPIA, F- FILM, T- TAPE T' ACKNOWLEDGE g!~A~PE ,, PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: ANN SIMONSEN - AFL/311 P. O. BOX 360 ANCHO~GE, . AK 99510 · _ ARCO Alaska, Inc. ', '. F.:::': .OIfi¢(..'.=-:.' :i'. .. April 30, 1982 Mr...C.V. Chatterton State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska Subject: State Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following drill Sites: 11-6 11-7 14-29 15-2 1A-15 (Revised) Also enclosed are monthly reports for March on these drill sites: 2-19 15-4 2-20 Eileen #1 13-17 West Sak 24 13-23A ,:~!1A-16A.(Sidetrack) 14-9B IE-9 14-28 Oliktok Pt. #1 14-30 West Sak 25 15-3 We are also including plug and abandonment subsequent sundry reports on Eileen #1 and 1A-16. The reports on Eileen #1, Oliktok Pt. #1, and the two West Sak Wells are of a confidential nature. We would appreciate it if you could store information concerning these wells in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:pb eno. GRU4/B4 STATE OF ALASKA ALASKA ~.~ AND GAS CONSERVATION CCi( .... /llSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-31 3. Address 8. APl Number P, 0, Box 360, Anchorage, AK 99510 50-029-20713-01 4. Location of Well at surface 494' FWL, 1409' FSL, Sec. 5, T11N, RiOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 100' RKBI ADL 25647 ALK 465 9. Unit or Lease Name Kuparuk River Field 10. Well No. 1A-16A (Sidetrack) 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of March ,19R2 -12. Depth'at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0930, 03/01/82. Drld 13-1/2" hole to 2470'; ran & cmtd 10-3/4" csg. Drld 8-3/4" hole to 7722'. Abandon 1A-16. KO @ 4400'. Drld 8-3/4" hole to 7411'. Ran logs. Ran & cmtd 7" csg. Displ well to NaC1. Ran logs. Ran 3-1/2" completion assembly. Secured well & released rig on 03/21/82. See Drilling Hi story. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5 #/ft, H-40, conductor set @ 80' Cmtd w/286 sx AS II. ;,10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe ~ 2456'. Cmtd w/1000 sx Fondu & 250 sx AS II' 7", 26.0 #/ft, K-55, BTC csg w/shoe @ 7370' Cmtd w/1000 sx Class G. See Drilling History. 14. Coring resume and brief description N/A. 15. Logs run and depth where run DIL/SP/GR/SFL/FDC/CNL/Cal (7411'). RFT (7411'). Gyro/CCL (PBTD to surf ace). CBL/VDL/CCL/GR (PBTD to 2000'). i~,16. DST data, perforating data, shows of H2S, miscellaneous data U/A. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE Sr. Dri 11 i n§ Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU3/B 1 3/14 Submit in duplicate Rev. 7-1-80 DS 1A-16A Drilling History NU Hydril & diverter. Spudded well @ 0930 hrs, 03/01/82. Drld 13-1/2" hole to 2470'. Ran 59 its 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe @ 2456'. Cmtd w/lO00 sx Fondu & 250 sx AS II. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd formation to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7722'. Abandoned 1A-16 (PBTD 4400'). KO @ 4400'. Drld 8-3/4" to 7411'. Ran DIL/SP/GR/SFL/FDC/CNL/Cal. Ran RFT. Ran 179 jts 7", 26 #/ft, K-55, BTC csg w/shoe @ 7370'. Cmtd 7" csg w/600 sx Class G (lead) & 400 sx Class G (tail). Instld 7" packoff & tstd to 3000 psi - ok. Tstd 7" csg to 1500 psi - ok. Arctic packed 7" x 10-3/4" annl w/300 bbl H20, 250 sx AS II, & 100 bbl Arctic Pack. Displ well to NaC1. Tstd csg to 3000 psi - ok. Drld cmt to 7278' PBTD. Ran Gyro/CCL f/PBTD to surface. Ran CBL/VDL/CCL/GR f/PBTD to 2000'. Ran 3-1/2" completion assy w/tail @ 6680' & pkr @ 6607'. Tstd tbg hanger & packoff to 3000 psi - ok. Chg over @ 6680' f/NaCl to clean diesel. Dropped shear sub ball & set pkr. Tstd tbg to 3500 psi & annl to 500 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Pulled BPV. Tstd tbg to 3000 psi & annl to 200 psi - ok. Closed SSSV. Secured well & released rig @ 0600 hrs, 03/21/82. JG:hrl 04/17/82 GRU3/B15 RECEIVED APR 0 i982 Alaska Oil & Gas Cons. Commission] f'-mchorao~ -STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY DEScR I PT I ON DATED: RECEIVED Oil & Gas O~as. Commi~ltlll Copy sent to sender YES ~'"'/" NO NORTH ~LOPE ~,GI~.,E~RII~G TRAi!St-!ITTAL # /--~o o J. J. Pa,,.,,elek/Ann Simonsen Transmi ,~d herewith are the following -,.. PL~.~= HOTE' BL - BLUEL!,~E S SEPIA ·. F- FILM, T - TAPE ?,ECE I PT DATE' RETURN I~ECZ~?T TO' ARCO ALAS~CA, INC. ATTH: AHa; SIMO~SE~! = AFA/311 P.O. BOX 360 A ..... ~n~ " 9951 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator Arco Alaska, Inc. 3. Address P O Bo× 360 Anchorage AK 995~_~skaOii&^..~. _GasC°ns' 4. Location of Well Surface Location' 494' FWL, 1409' FSL, Sec. 5 TllN, R10F, UM Bottomhole Location: 1712' FWL, 1001' FNL, Sec. 5, TllN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 61' GL~ 100' RKB I ADL 25647 ALK 465 12. (Submit in Triplicate) Perforate ~X~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other X] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) OTHER ~ 7. Permit No.- 8. APl Number }~]0- 029-20713 9. Unit or Lease Name Kuparuk 25647 10. Well Number 1A-16A 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In order to establish the ability to inject into the Lower Kuparuk Sands, Arco Alaska, Inc. intends to perform a third water injectivity test. Previous tests have proven unsuccessful in establishing injection into the Lower Sand at pressures below formation parti~ng pressure. Because of the importance of this information to Increment I Waterflood planning, we plan to attempt injeCtion into the Lower Sand of Kuparuk 1A-16A. The well will be initially perforated from 7016'-7024' and 7034'-7056'. After perforating, the well will be allowed to flow to production for approximately one month to clean up the formation. A well test will then be conducted to determine the extent of any formation damage present. Based on the well test, a decision will be made with regard to an acid stimulation. If no stimulation is required, or after the stimulation is- performed, the injectivity test will be run. We will inject water for 2-5 days, shut in for pressure falloff, perform a step rate test, and shut in. for a final pressure falloff. After the test, we will attempt to flow the well back for 1-2 weeks, at which point we will perforate and test the Upper and Middle Sands at 6772'-6842' and 6870'-6884'. The well will then be flowed to the CPF. Perforating of the Lower Sand will~'.begin March 24, 1982. Injection testing is currently planned for early l~ay and should last no longer than 10 days. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~. ~), ~ _~ TitleArea Operations Engineer Date3/23/8~ The space (~low for Commission u~ Conditions of Approval, if any: v By Order of Approvedby ~¥ ~.~¥ ~, [~[E~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~' Post Office Bo&~ .,60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 11, 1982 Mr. C. V. Chatterton Commi ss i one r St ate of A1 aska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1A-16A (Sidetrack) Dear Mr. Chatterton' Attached is a diagram showing the proposed horizontal and vertical projections for Kuparuk Well 1A-16A (Sidetrack). Forms 10-401 and 10-403 were submitted March 10, 1982. A wellbore proximity map for well 1A-16 was submitted with the original application. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer JBK'JO/hrl Attachments ONI1/A6 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~larch 12, 1982 ~,!e. Jeffrey B. Eewin Senior Dril ling Engineer ARCO Alaska, Inc. P, O, Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Field lA-16 RD ARCO A I asks, I nc. Permit No. 82-31 Sur. Loc.. 494'FWL, 1409'FSL, Sec Bott~ole ~c: 936'F~, 43~$'FSL, See 5, TllN, ~I~B, U~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced wel I, Well samples and a m,~d 1o~ are not required. A continuous directional survey is required as per 20 AAC 25.0§0(b)(5). If available, a tape containing the digitized log, information shall be submitted on all log's for copying except experin~enta/l logs, velocity surveys and dipmeter surveys. ~lany. rivers in Alaska and their drainage, systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are 'subject to ~At~ 15-,O§,i}?0 and the regulations p~ulgated thereunde~ (Title 5, Alaska Administrative Code). Prior to c~enci~ operations you ~y be contacted by the ~abitat ~o~dinator~s Office, Department of Fish and G~. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ?. and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water P.ollution Control Act, as amended. Prior to commencing operations you may be oontaeted by a repl'esentative of the Department of Environmental Conservation. Mr. Jeffrey Kuparuk River Field lA-16 RD -2- March 12, 1982 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well ia spudded. ~/e would also like to be notified so that a representative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chainman of BY C~D~H OF THE COMM~SSi:ON Alaska Oi'l and Oas Conservation Con~ission Ene 1 o sure Department of Fish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o enel. C~C z be ARCO Alaska, Inc. ~' .... Post Office I~~-' 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 10, 1982 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK'~ 99501 Dear Mr. Chatterton' SUBJECT' ?'Kuparuk 1A-16 ~'~ ~ "'"-~, Attached are: · A Sundry Notice to plug back Kuparuk 1A-16. An application for Permit to Redrill Kuparuk 1A-16, along with a $100 application fee. · An as-built drawing of "E" pad showing the surface location. A determination of the maximum pressure to which BOP equipment could be subjected. · A diagram and description of the BOP equipment. The operations proposed in these applications were verbally approved by Mr. Jim Trimble on March 9, 1982. The~ proposed 'directional plan and proximity map are currently being prepared. These will be.~forwarded to your office as soon as they are prepared. If you have any questions, please call me at 263-4970. Sincerely, ~. Sr. Drilling Engineer JBK'JO/hrl Attachments cc- Mr. Ron Podboy ONI1/A4 ARCO Alaska, Inc. i;~ a Subsid,~ry of All~,rHic[-~ichfiei,.iCo~par~y Oil 8, G~s Cons. Commission Anchorage la. Type of work. 2. Name of operator ARCO Alaska, Inc. PERMIT TO DRILL 20 AAC 25.005 / DRILL [] ~ lb. Type of well EXPLORATORY [] REDRILL [~ / DEVELOPMENT OIL [] DEEPEN [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 3. Address P. O. Box 360, Anchorage, AK 99510 4. Location of well at surface 494' FWL, 1409' FSL, Sec. 5, TllN, RiOE, U.M. At top of proposed producing interval 890' FWL, 3630' FSL, Sec. 5, TllN, RIOE, U.M. At total depth 936' FWL, 4308' FSL, Sec. 5, TllN, RiOE, U.M. 61' GL, 66' PD, 100' RKB D 25647 ALK 465 12. Bond information (see 20 AAC 25.025) Federai insurance Co. Type Statewi de surety and/or number 8088-26-27 9. Unit or lease name Kuparuk River Fi eld 10. Well number 1A-16 ~0 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 Mi. NW Deadhorse miles 16. Proposed depth (MD & TVD) 7811' MD, 6826' TVD feet 19. If deviated (see 20 AAC 25.050) 14. Distance to nearest property or lease line at TD, 936' feet 17. Number of acres in lease. 2469 15. Distance to nearest drilling or completed 1A-3we' 78'@ 2000' TVD feet 18. Approximate spud date 03/10/82 ~psig@60" F - surfac. ' 120. Anticipated pressures KICK OFF POINT 4500+ feet. MAXIMUM HOLEANGLE39.2°/(see20AAC25.035(c) (2) 3100____psig@599 ! ft. TD'(TVD) 21 SIZE Casing 16 10-3/4 Weigh~ '65# 45.5# Proposed Casing, CASING AND LINER Grade H-40 K-55- Hole 7 26# K-55 Coupling I Length WeldedI 80 BTC }2422 BTC' 17777 22. Describe proposed program: NOTE' Liner and Ce .rp~nting Program ~'~!~"?~ETT I N G DEPTH MD TOP TVD MD BOTTOM TVD Pad IPad Pad [Pad I Pad ~Pad 114 ~) 114 2456 12456 I 7811 16826 I I QUANTITY OF CEMENT (include stage data) 200 cf lO00sx Fondu + 250sx Arcticset II 1318sx Class G cement This redrill proposal was verbally approved by Mr. Jim Trimble, AOGCC, on March 9, 1982. ARCO Alaska, Inc., proposes to redrill this Kuparuk River Oil Pool development well to approximately 7811' MD, 6826' TVD. The sidetrack depth will be 4500'± MD. In all other aspects, the proposed drilling program will be identical to that described in the original Permit to Drill that was approved February 26, 1982. MAR 1 O 1982 23. I hereby ce~t the foregoing is true and correct to the best of mY knowledge a~Brl a~i~J~J~ ~1~$ ~ ~ ommi~io~ SIGNED C ~~-- ~~~ TITLE Sr. Drillin. .' ~ch0 03/] 0/87. Thespacebe~r~~n~, CONDITIONS OF APPROVAL Samples required Mud log required I-lYES /~.N O [-J YES ,;~NO Permit number Approval date APPROVED BY~ __/~/ / / Form 10-401 Directional Survey required fl~YES F-]NO IAPI number 50- o '~-'/- ~- a 7i_~ -~ i~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE [Vla]~ch 12, 1982 by order of the Commission Submit' in triplicate Rev. 7-1-80 ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been' determined to be 3100 psig from RFT and pressure build-up data. This pressure @ 5881' SS = 5991' TVD will be balanced by 9.95 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during .drilling of the Upper Kuparuk and remaining intervals. This will result in a 140 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2598 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3100 psi), gas migration to the surface without expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservOir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf : volume final (surface) PiVi = PfVf Ti Tf Since Vi : Vf, i.e., no expansion. Pi = Pf Then Pf = Ti Tf PiTf : (3115 psia)(60°F + 460) Ti (160°F @ 460) Pf = 2613 psi a = 2598 psig JO:hrl 03/10/82 ONI1/A5 ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been-determined to be 3100 psig from RFT and pressure build-up data. This pressure @ 5881' SS : 5991' TVD will be balanced by 9.95 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 140 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2598 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3100 psi), gas migration to the surface without expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi :'volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf : volume final (surface). PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi =Pf Ti Tf PiTf : (3115 psia)(60°F + 460) Then Pf : Ti (160°F @ 460) Pf = 2613 psi a = 2598 psig JO:hrl 03/10/82 ONI1/A5 UAR 1 j I982 Alaska Oil & Gas Cons. ComrnJss)o~ Anchorage ye ~.gTG, Itl GS .... · . eO0 O' ~ , , sAT MEfliDIAN.ALASKA j ~.1 EXISTING ... .... ,~o. ,~,. ...,~'..1 ~ lf.O I I~.1 I~.1 190' 120' 120' lEO' ....................... 1-7;; ......... TIIN, RIOE, PR~ITH/~TED LEGEND A NOTEq ~ P[qla~N[NI lUxV(¥ l,OCATION DATUM, Al.I. LOClllOhl lilt' ~llllllJ JJJC ~.JlllllJllJJ[, SURVEYORS CE:RT I FICA'I'E AS DUtLt ~ ........ *'"- .................. KUPARUK PROJECT IIChCON~I~ ~CVfl&l[ JO Till ~JlJ I)p MV '. --- F---q 2 16 2000 PSI x lO" 3000 PSI casino head :" 3. 10" 3000 PSI tubing bead adapter spool RNhqJL.qR 5 13-5/8'i 5000 PSI pipe rams / PREVENTOR / ' . 9 ' 6. 13-5/8" SO00 PSI drilling spool w/choke ' , /J 7. 13-5/8" 5000 PSI pipe ~:ams - ' ) { .... . ) · PLUMP OFF. DR_T LL I NG m~U~Z~G P~ESSU~. - ' . SPOOL - '-' 13-s/s- Bo~ s~Acx r' ~' Z. ~EC~ T~T ALL HOLD. D~ SCR~S ~E ~L,L~ E- ' _J T~ED. PRED~E~INE D~5 ~AT T~T ~LUG J  ~ 3. CLOSE ~NU~R PREVEi~E~ ~J~ ~O~S ~;g ~P~S Pt PE RAHS ~ wv~s o~ ~'~FOC~. - 5 ,. S~ I~CR~E PRESSURE TO ISm PSI ~D fired 10 MINU~S. ~LEED TO, ~ ~SI. - ~' - ~ ~ 6. OPEN ~NU~ PREVENT~ ~ CLOSE ~P S~ OF ' 7. INCR~E ~R~SURE TO ~ ~S~ AND ~ ' B~ED ~RSTR~M PRES~ ~0 ZE~O PSi TO T~ - ] ' ' VALVe. TEST R~I~ ~ESTED ~IFOLD . ' v~vEs, [F &'fY, ~ 3~ ~St UPST~ff l~ V~VE ~D ZERO PSI ~'~~.. BLEED S~ST~ TO ZERO PSI. HD 9. OPEN TOP SET OF PIPE ~ AND CLUE BO~ 3 S~ OF PIPE ~S. ' j ~o. INCRE~E PRESSU~ TO 3~ PSI ~;D HOLD H[I~TES. BLEED lO ZERO ~SI. -_~ . CS~ ~ ll. OPE~ BO~-t S~ OF PIPE ~MS. BACK OFF ~- .. NING JO]~T ~D PULL O~ ~F HOLE. ~E BLI~ ' ~ " BLEED TO ZERO PSI. . '-' ~. 12. OPeN BLIMD ~>tS ~;D REC~ER TESI PL~. ~ - ' L. I ., i 4 ,,c o o o -o. o ¢ o o::1:', elm,, RESERVE PIT Lf. GLNO & i. PAt' [IMEN:I~.N$ S,tt eN AkE MEAN.: I,~KFN . [L['/ATICb~ ~HC~[: t.I.e.I.,I.I..*IN'ATIVE EgE- YATICNS TAKEN F~['M ASEUILT SUfl~EY NOTES. DATUM ' T~.~ · A ; .) -i ....· SLRVEYJR.c, CERI'CICA'T.I:' i '4[~EB¥ CERT,rY .lq:.1 I~,e .;e;.~. ,LT,)K DR __.S,1E"/.'I;,Le. ~qVEYE[ .:lCE~ AS Bblt. T KUPARUK PROJECT DRILL SITE "A'; ATLANTIC RICHFIELD COMPANY a~k, NORTH AMERICAN PROOUCING DIVISION G~NERAL ENGINEERING GROUP BOMNOFF & ASSOCIATES , INC. ENGINEERS-PLANNERS' SURVEYORS ANCHORAGE , ALASKA DATE ./*N 1980 ISCALE~ DRAWN BY ,FIr ~ NrA I CHECKED BY:MK. CHECK LIST FOR NEW WELL PERMITS Company. Lease & Well No. IT~ APPROVE DATE ,, Loc · 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool .................. .... .. 3. IS well located proper distance from property line '''ii' ' "i i i i-ii!''- 4. Is well located proper distance from other wells ....... 5. Is sufficient .undedicated acreage available in this po . 6. Is well to be deviated and is well bore plat included .. · 7. Is operator the only affected pa~ty .................... 8. Can permit be approved before ten-day wait ............. (,9//thru 11 ) 10. 11. (4) ~Ca~sg~~ g °//~ ~2 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. (5) BOPE ~j~ 3'~/'~ ~1 thrU 24) (6) Add :~'-~. ~ 2'71/~~/ Does operator have a bond in force ................................. Is conservation order needed Is administrative approval needed .................................. Is conductor string provided ................ Is enough cement used to circulate ~'~~o~ ~nd ~u~ Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ........ Will surface casing protect fresh water zones Will all casing give adequate safety in collapse, tension and ~u..rs.t. Is this well to be kicked off from an existing wellbore ...... Is old wellbore abandonment procedure included, on 10-403 .......... Is adeqUate well bore separation proposed ......................... YES NO REMARKS Is a diverter system required ...... ' ........... Are i grams ...... . Does BOPE have sufficient pressure rating -Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. · AdditiOnal requirements . Additional Remarks: ~~7'~.~ ~L~v~ Geology: Engin~ ~r~ng: HWK~ LCS~ BEW rev.~ 01/13/82--- - - ' INITIAL GEO"' :UNIT "O~/bFF .. POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. bis ~tPE VERIFICATION LISTING L~'P 009,H03 VERIflC.~TION LISTIN3] P,~GE I ** REEL HS~D~R ~, SERVi.'E NAMg] : SERVIC. DATE :82104/ 0 ORIGIN : HEEL NAME :REEL ID CONTInUATiON ~ :01 PREVIOUS REEL : COMMENTS :REEL CO~MEN~$ *~ TAPE HEADER *~ SERV1ZE NAMg] :SER¥I2' DATE :82/04/ ~ ORIGIN :~070 TAPE NAbIE ~162664 CONTINU.~TiON # :0! PREVIOUS TAPE : COMMENTS :T~PE COMMENTS *~ FILE HEADER ~* FILE NAME :SERVIG,O( SERVI~.E NAMe] : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 f~ILE TYPE : PREVIOUS FILE : ~* INFORM%~ION RECORDS MNEM i(ONTENIS CN : ARCO ALASKA INC, WN : KUPARUK 1A-16A FN : KUPARUK RANG: ~O~N: lIN SEC~ 5 CO~N: NORTH SLOPE STAT: ALASKA CTRY: USA MNE~ CDN~E~T~' PRES: DIL~O1F RECORD TYPE 047 ~* RECORD ~YPE 047 ~ 'INIT TYPf] CBTE SIZE 000 OCO 016 065 000 000 01.4 065 000 0~0 007 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 011 065 000 000 006 065 000 000 003 085 UN1T TYPE CATE SIZE: CODE 000 003 007 065 LYP g09.HQ2 YERI~ICATION LISTING PAGE 2 #~ ~ECORD TYPE 047 \ SCHLUMBERGER \ ALASKA CO~PDTING CENTER COMPANY = ARCO ALASKA iNC. WELL :: KUPARUK 1A-lbA fIELD = KUP%RU~ COUNTY : NOR~E 6LOP~ STATE = ALASKA dOB # 10707,A62664 OIL RUN ~1, LUGGED 15-~,AR-82 BOTTOM LO~ INTERYAL = 7392 FT. TOP ,LOG IN]ERVAL = 2458 f'T. CASING-LOGGER -- 10.75 IN. BJ~'] Sf2E = 8.75 IN. TYPE HOLE f'LUID = DEXTRiD = ~0.4 LB/G DENSITY VISC SITY = 45,.0 S PH :-- 10 0 ~LUID l~OSS = 4.~ C3 2458 LVP O09.HQ= YERIFICATION LISTING PAGE RM @MEAS. TEMP. = 2.640 ~ 68.0 F RMF @ MEAS. TEMP. = 2.400 @ 68.0 F RMC @ MEAS. TEMP. = 2.170 @ 68.0 F RM @ BHT = 1.31 @ !44 F SANDSTONE · ~-DATA FORMAT R~CORD ~. ENTRY BLOCKS TYPE SIZE REPR CODE 4 I 66 8 4 73 9 4 65 0 1 66 DATUM S[~C1M]CATI,ON ,fLOCKS ~NEM SERVICE SER,VIC~t UNiT AP1 AP,I AP1 API FILE ID ORDER ~ LOG ~]PE CLAa~ ~OO NO. )gPt~ Fl" 0 0 0 0 0 ~FLU DIL OHMN 7 0 0 0 0 ILS DiL OHMS 7 0 0 0 0 [LD DIL OHM~ 7 12 46 0 C ~P DIL MV 7 I 0 0 0 ;R DiL GAPI 7 31 32 0 C ~PHI FDN PO 42 68 2 0 0 ~]AbI FDN ,IN 42 28 3 0 C ;R FDN GAPi 42 31 32 0 0 qHOB FDN G/C3 42 35 1 0 ~ )RHO FDN G/C3 42 44 0 0 0 ~rCNL FDN 42 34 93 0 C 4CNL FDN 42 34 92 0 0 ~RAT ~DN 42 42 1 0 C EN~'RY 1 60 .! iN 0 SIZE! PROCESS SAMPLE] LEVEL 4 0 1 4 0 1 4 0 1 4 O 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 4 0 1 4 0 1 4 0 I CO 6 6 6 6 6 6 6 6 6 6 6 6 6 6 PR DE 8 8 8 8 8 8 DATA ** )EPT 7421.0C0 SFLU 2.682 iLS :½P -45.R12 GR 91.750 NPHI ;R -999,2~0 RHOB -999.250 DRHO ~CNL -999.250 NRA~ -999.250 )EPT '7400.000 SFLU 2.682 ;fILM ~P -44.781 GR 91.750 NPHI ;R -999.250 RMOB -999.250 DRMO 2.i492 ILD -999.250 CALl 0.i071 FCNL 2.492 -999.250 CALl 0.071 FCNL 2.633 -999.250 -999.250 2.320 -999.250 -999.250 -~¥P 009.H03 VERIFICATION LISTING PAGE 4 {CNL )EPT ;P ICNL )EPT ICNL ;P ICNL IEPT ;P JCNL _~EPT 3P ,CNL EPT P ?R 'CNL EPT P 'CNL EPT P CNL EPT P R P CNL EPT P -999.250 730D. 300 SFLU -2 5.5( 3 GR 104.813 RHOE 2174.0( 0 NRA~ 7200.000 SFLU -23.531 97.875 HHOB 1869.000 NR~'I 7 10 D. 300 SFLU ,-I, 3 3.8 ~ 3 GR 77. ]12 RHGE 243 4. O( 0 NRAT 7000.000 SFLU -31.563 GR 82,625 RH00 2236.000 NR~I 6909. )00 SFLU ~34.0(3 GR 68.750 RMOB 2688.0( 0 NRAI 6800.000 SFLU -59.813 GR 39.781 RHGB 2688.000 NB~I U/O0.O00 SFLU -27.547 GR 116.375 RHOB 1768.000 660~. 300 SFLU -99.5(3 G~ -999.250 NR~'I 6~00.000 $FLU -69.063 GR -999.250 RHGB -999.250 NR~'I 6~00.000 SFLU -67.125 GR -999.250 RHOB -999.250 NR~ b~O0.O00 SFLU -'77.625 GR 999.250 RHOb -999. . f(4. 2. 3. . 97. 2. 3. 2~0 727 813 457 229 688 875 395 408 6.809 ,77.312 2.398 2.875 375 ~'625 . 2.420 2.939 15. 2. 2. 39. 39. 2. 2. 116. 2. 3. . 121. -999. -999. . 147. -999. -999. . 114. -999. -999. . 94. -999. 641 750 438 465 063 781. 291 771 530 309 389 063 25 :) 25O 355 2~0 250 25O 395 1~8 250 250 672 625 250 ILM NPHI DRHO ILM NP~I DRHO NPHI DBHO NPHI DRHO IbM NPHI DRHO iLM NP, 5I DRHO ILM NPB1 DRHO ILM NPhI DRHO NPHi DRHO NPHI DRHO ILM NPHI DRHO 2.770 37.3~5 0.012 2.410 39.893 0.002 5.832 30.664 0.017 3.977 3i.445 -0.000 10.266 25.0C0 0.015 45.688 30.078 0.022 1.780 {44.629 0.026 2.342 -999.250 ).D40 4.2i9 -999.250 0.043 2.879 -999.250 0.015 3.949 -999.250 ~.010 ILL CALl FCNL ILD K AL I F'NL ILL CALl FCNL ILD K Al I FZNL ILL CALl FCNL ILD FZNL iLD ,CALl ILD CALl FCNL ILD CALl F"~NL ILD C AL I F."NL iLD ,CALl F:NL 2.719 9.375 606.500 2.314 9.820 506.75O 5.582 9.594 814.000 3.924 9.773 689.500 9.1.17 9.195 1035.000 46.031 8.828 879.500 1.771 9.945 425.750 2.459 -999.250 -999.250 4.219 -9c. 9.250 -999.250 2.88] -9c. 9.250 -999.250 3.918 -9~_ 9.250 -999.250 ~ YP 009.B03 'VERIFICATION LISTING CNb -999.250 NRAI -999. EPT 6200.000 SFLU 2. P -70.813 GR 1.12. R -999.250 RMOB -999. CNb -999.250 NRA~ -999. EPT 61¢0.0(0 SFLU 2. P -71.312 GR 101. R -999.250 RH08 -999. =Nb -999.250 NRAT -999. EPT 6000.000 SFLU 3. P -89.063 GR 118. R -999.250 RHOB -999. 2NL -999.250 NRA~: -999. EPT 5900.0(0 SFLU 3. P -81.813 GR 171. R -999.2~0 RH~8 .-999. 2NL -999.250 NRAI -999. ~PT 5800.000 SFLU 3. ? -80.813 GR 189. R -999.250 RHOB -999. :NL -999.250 NRA~ -999. ~PT 57C0.0(0 $FLU 1. ~ -78.813 GR 135. ~ -999.250 RHOB -999. ~NL -999.250 NRAT -999. ~PT 5500.000 SFLU 2. ~ -77.125 GR 154. ~ -999.250 RHO8 -999. 2NL -999.250 NRA~~ -999. ~PT 55(0.0(0 SFLU 1. ~ -84.563 GR 156. { -999.~50 RHOB -999. ~NL -999.250 NRA~' -999. ~PT 5400.000 SFLU 2. ~ -84.125 GR 101. { -999.250 R~OB -999. ~:NL '999.250 NRA~ -999. ~PT 53C0.0(0 8FLU 2. ' -82.312 GR 94. ~ "999.~t0 RH~b '999. ~NL '999.250 NRAT -999. gPT 5200.000 SfLU O. ~ -81.813 GR 61, { -999.250 RHO8 -999. 25O 545 25O 25O 250 477 75O 25O 250 416 000 250 25O 043 000 25O 250 330 ~75 250 250 357 5OO 25O 250 732 25O 250 250 999 875 250 250 260 063 250 250 076 312 250 250 993 406 250 2.451 [lEI -999.250 CALI~ 0.026 3PCNL 1.338 ILD -999.250 CALl 0.031 FCNL 3.301 -999.250 CALl 0.:02.3 2.180 !LD -999.250 CALl 0.002 FCNL 2.930 FIB[ -999.250 CALI. 0.006 ]fC~L 1.302 ILD -999.250 CALl -0.006 FCNL 2.063 -999.250 CALI. -0.002 :~C~L 1.8Cl ILD -999.250 CALl 0.027 FCNL 2.219 -999.250 CALI~ 0.006 ;fC~L 2.152 ILD -999.250 CALl 0,026 P'CNL 1.959 '999.250 CALl -0.010 FCNL [-'AGE 2.490 -999.250 -999.250 1.119 -999.250 -999.250 3.406 -999.250 -999.250 2.117 -999.250 -999.250 3.066 -999.250 -999.250 1.216 -999.250 -999.250 2.000 -999.250 -999.250 1,.760 -999.250 -999.250 2.254 -999.250 -999.250 2.168 -999.250 -999.250 2.014 -999.250 -999.250 IP 009,H03 VWRlflCAT10N LISTING PAGE 6 -999.250 SPT 5100.000 SFLU ~ -85.563 GR { '999.250 :Nb -999.250 NR~T ~PT 5000.000 SFLU ' '36.563 GR { '999.250 :Nb '999.250 ;PT 4~00.000 SFLU ~ '36.781 GR { '999.250 RHOB :Nb '999.250 ;PT 4300.000 SFLU ' -36.031 GR { -999.250 RH00 :NL '999.250 NR~I :PT 4700.)00 SFLU ' "40.]~2 GR ': '999.250 RHUB :Nb -999.250 N~ ':PT 4~00.000 8FLU ' '42.344 GR "; '999.250 RHOB INb -999.250 :PT 4~00.000 SFLU ' -40.312 GR : -999.250 RHOB INL -999.250 :PT 4t00.000 SFLU ' -62.594 GR ; -999.250 RHUB NL -999.250 NR;~ :PT 4~00.000 SFLU -61.094 GR : -999.250 RH00 Nb -999.250 ':PT Nb PT 4200.000 8FLU -49.563 GA -999.250 R~OB -999.250 NR~2 4100.000 SFLO -51.844 GR 999.250 RHG5 -999. 93. -999. -999. 2. 70. -999. -999. 2. 68. -999. -999. 2. 83. -999. -999. 97. -999. -999. 2. 82. -999. -999. 2. 78. -999. -999. 3. 8~. -999. -999. . 82. -999. -999. 80. -999. -999. . 79. -999. 25O 275 125 25O 25O 835 250 25O 455 813 25O 25O 484 563 25O 250 342 938 ~50 25O 246 250 25O 455 125 25O 25O 0O2 312 25O 250 365 335 250 25O 352 25O 250 250 523 438 250 ILM NPHI DRHO ILM NPHI DRHO NPH1 DRHO ILM NP5I DRHO IbM NPHi D~HO 1LM NPHI DRHO NPHI DRHO NPHI DRHO NPHI DRBO ILM N~HI DRBO ILM NPS1 DRHO 2.398 -999.250 0.032 2.719 -999.250 0.025 2.674 -9~9.250 0.011 2.393 -9~9.250 0.008 2.279 -999.250 0.067 2.344 -999.250 0.018 2.266 -999.250 0.08i 3.186 -9~9.250 0.021 2.494 -9§9.250 0.044 4.098 -9c. 9.250 0.086 2.939 -9~9.250 0.020 ILD ,CALl F 3NL 1LD ~CALI ILD .CALl ILD ~( AL I F:NL ILD CALl FCNL ILD ,¢ AL I F~NL ILD ,CALI FZNL ILD -CALl F3NL ILD ,CALl F 3~1, ILD ~£ AL I F 2NL ILD ~(: Al. 1 F 'Jl',~ b 2.436 -9c. 9.250 -999.250 2.738 -9c. 9.250 -999.250 2.73~ -9c~ 9.250 -999.250 2.420 -999.250 -999.250 2.311 -999.250 -999.250 2.436 -9c, 9.250 -999.250 2.328 -9~. 9.250 -999.250 3.51 ~t -9~9.250 -999.250 2.699 -9~9.250 -999.250 4.207 -999.250 -999.250 3.148 -999.250 -999.250 P 009,H03 VERIFICATION LISTING NL PT Nb PT NL PT PT NL PT NL PT NL PT PT Nb -999.250 NRAI -999. 4000.000 SFLU -48.531 GR -999,250 RHOB -999.250 NRAT . 92. -999. -999, 3900,000 SFLU -50,531 GR -999.250 If, HOB -999.250 NRAI 77, -999 -999 3800.000 SFLU -51,063 GR -999.250 RHOB -999.250 NRA~ . 78. -999. -999, 37C0.0(0 SFLU -52.28! GR -999,250 RH00 -999.250 NRAI . -999. -999. 3600.000 SFLU -61.312 GR -999.250 RHOB -999.250 NRAI . 64, -999. -999, 35G0.0{0 SFLU -56,}63 GR -999.2~0 RHG~ -999,250 NRAT . 69. -999, -999. 3400,000 SFLU -62.031 GR -999.250 RHOB -999.250 NRA~ . 73. -999. -999, 33C0,0(0 SF'LU -63,363 GR -999.~0 REOB -999,250 NRAT . -999. -999. 3200.000 SFLU -64,063 GR -999.250 RHOB -999.250 NRA~ 129. 38. -999. -999. 31C0,0(0 $FLU -69,813 GR -999,2[0 RHGB -999.250 NRAT . 65. -999. -999. 3000.000 SFLU -61.031 GR -999.250 R~GB . 73, -999. 25O 344 438 250 250 836 000 250 250 824 250 250 250 285 500 250 250 129 125 250 25O 063 000 250 25O 324 875 250 250 047 188 250 250 625 688 25O 250 723 938 250 250 820 438 250 ~ILN DRHO NPfiI DRMO NPHI ILM NPHI DRHO :ILM NPHI iLM NPH! DRHO ~ILM NPHi ILM NPHI DRHO NPBi :[ KkO iLM NPH1 DRHO NPHI 2,527 -999.250 0,003 . 3,086 999.250 0.028 3,990 -999.250 0.017 3,232 -999,250 0.033 5.918 -999.250 0,023 4.473 -999,250 0.068 5.125 -999.250 0.094 7.430 -999.250 0,104 13.625 -999.250 0.097 7.691 -999.250 0.046 6.969 -999.250 0,053 ~ILD CALl FCNL iJLD CALl FCNL lll][ CALl ;~ C5 L ILD CALl FCNL [113[ CALl l~ CI~L IDD CALI PCNL [IIl[ CALl :f C5 L ILD CALl ~'CNL [] U[ CALl ILD CALl FCNL llI][ CALl PAGE 2.598 -999.250 -999.250 3.289 -999.250 -999.~50 4.453 -999.250 -999.250 3.521 -999.250 -999.250 6.207 -999.250 -999.250 5.039 -999.250 -999.250 5.438 -999.250 -999,250 8.156 -999.250 -999.250 11.078 -999.250 -999.250 8.0'70 -999.250 -999.250 7.871 -999.250 -999,250 P 009.H03 YERI~'ICATION LISTING PAGE NL -999.250 NRAT PT 2900.000 SFLU -64.563 GR -999.250 RHOB Nb -999.250 NN~ PT Nb PT ~b Nb PT .~T 2~00.000 SFLU -76.125 GR -999.250 RHUB -999.250 NR{~ 2100.000 SFLU -b8.813 GR -999.250 RHGB -999.250 NR~2 2~00.000 $~LU -72.312 GR -999.250 -999.250 2~00.000 SFLU -75.312 GR -999.250 RHOB -999.250 NR~2 2t95.000 SFLU -68.312 GR -999.250 RHOB -999.250 NB~2 -999.250 7.191 71.625 -999.250 -999.250 ~5.07D 38.844 -999.250 -999.250 ~.859 40.0§4 -999.250 -999.250 10.883 40.4(9 -999.250 -999.250 15.391 38.719 -999.250 -999.250 18~.375 33.8~4 -999.250 -999.250 ILM NP, 5 I DB~O ILM NPHI ILM NPHI DRHO IL~ NPHI DBHO ILM NPHI DRHO ILM NPHI DR~O <~ ?~bE TRAILER ** ~ · bE NAME :SERg]C.O01 RVI.~E NAME : ~ RSION # r~: · . - XIMUM LENGTH : 1024 bE TYPE : ~T FILE NAME : TAPE TRAILER ~* RVIZE NAME :SERVIC] · ~E :821041 b [GIN :1070 ~g NAME ~62664 qTINU~TION ~ :01 (T ~ NA~E : 4MENTS :TAPE COMMENT6 7.844 -9~9.250 0.054 13.352 -999.250 -0.005 10.188 -999.250 0.041 12.461 -9~9.250 0.043 16.578 0.021 2000.000 -999.250 -0.547 ILD ~( AL I ILD ,CALl ILD ,CALl FZNL ILD CALl F :N L ILD CALl F .~N b ILl) CALl f" 2NL 8.383 -999.250 -999.250 13.758 -9S9.250 -999.250 19.367 -9~. 9.250 -999.250 14.406 -9~.9.250 -999.250 17.797 -9S9.250 -~99.250 105.]12 -9S9.250 -,)99.250 ~ 00~..H0] VERI~ICATiOI~ LISTING ?AGE 9 · .: REEb TRAILER ~V I01~ NA~E 1~: :82/04/ 6 [G1N : ~. EL NAME :REEL ~TiNUATION ~ : · (T RE gL NAME : 4~iENT$ :RS~L O£MMENT$ EOF **********