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186-044
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-26_22025_KRU_2T-14_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22025 KRU 2T-14 50-103-20061-00 LeakPoint Survey 26-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:186-044 T36683 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 09:07:02 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-26_22025_KRU_2T-14_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22025 KRU 2T-14 50-103-20061-00 Caliper Survey w/ Log Data 26-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:186-044 T36682 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 09:05:46 -08'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. _/ ~ ~- ~(~ Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: Other: ~}~ ORGANIZED BY: DIGITAL DATA Diskettes, No. [] Other, No/Type NOTES: BREN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: PROOFED BY: E~EVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI SCANNED BY: BEVERLY BREN VINCEnneS)MARIA LOWELL RESCANNEDBY-' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file; //~)//? /~) ~ / , PAGES: ~? / Quality Checked (done) Rev1NOTScanned.v4~d • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 11, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: 2T -14 Run Date: 5/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20061 -00 ( L'j 0 6 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: l 11 Signed: la 611^--1/ /8( -6`1`( • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 10, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2T -14 Run Date: 5/4/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20061 -00 l ts1 8 \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 1 A 1 / Signed: Lk (S AS — • • WELL LOG 1 ......,r3 TRANSMITTAL PROACTivE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken ..z ,,f,aj 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Correlation Log 12- May -11 2T -14 CD 50 -103- 20061 -00 2) -#P -j73Z ��w - Date : oZA l 1 Signed : V 0 3 , Print Name: I�- 4 5 wrv- C�kl .3 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillipsTransmit.docx JELL LOG III C TRANSMITTAL PROACTIVE Diwoos& SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C 3 `[Uv Anchorage, AK 99518 �L ! 1 s Fax: (907) 245 -8952 lac - 6 'tq 1) Caliper Report 12- May -11 2T-14 1 Report / CD 50 -103- 20061 -00 2) Caliper Report 17- May -11 1 C-184 1 Report / CD 50 -029- 23155 -00 0 40-1 -. o3. 6s=c Signed : � Date : o cli.r.._ l l Print Name: 1413 w u' I t\"'\*...d.- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245.8952 E-MAIL : PDSANCHORAGE (MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:V rchives\ Distribution \TransmittalSheets \Cono oPhillips_Transmit.docx 1 0 • Memory Multi- Finger Caliper to Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2T -14 Log Date: May 12, 2011 Field: Kuparuk Log No.: 10154 State: Alaska I Run No.: 1 API No.: 50- 103- 20061 -00 Pipet Desc.: 9.625" 35 Ib. J-55 Top Log Intvll.: Surface Pipet Use: Casing Bot. Log Intvll .: 1,609 Ft. (MD) 1 Inspection Type : Subsidence Inspection COMMENTS : 1 This caliper data is correlated with the Halliburton Radial Cement Bond Log May 9, 2011. This log was run to assess the condition of the 9.625" casing for indications of subsidence. I The caliper recordings indicate a severe bend in joint 25 at 983', restricting the I.D. to 8.51", and oval deformation in several joints above and below this point. Buckling is also recorded in the first full joint below the casing hanger. 3 -D log plots across the interval logged displaying off - center, centered and a combination I overlay to highlight areas of buckling and oval deformation are included in this report. The caliper recordings indicate the 9.625" casing logged appears to be in good to fair condition with respect I to corrosive and mechanical damage. A maximum wall penetration of 33% is recorded in an apparent wear in joint 38 (1,516'). No other significant wall penetrations or areas of cross - sectional wall loss are recorded throughout the casing logged. Heavy deposits restrict the I.D. to 7.55" at 1,751' and 4.38" at 1,603'. 1 MAXIMUM RECORDED WALL PENETRATIONS: Apparent Wear (33 %) Jt. 38 © 1,516 Ft. (MD) 1 No other significant wall penetrations are recorded throughout the casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional (> 14 %) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS: I Heavy Deposit Minimum I.D. = 4.38" Jt. 40 @ 1,603 Ft. (MD) Apparent Centralizer Remnant Minimum I.D. = 6.68" Jt. 10 @ 428 Ft. (MD) I Apparent Centralizer Remnant Minimum I.D. = 7.54" Jt. 9 © 370 Ft. (MD) Slight Oval Deformation Minimum I.D. = 7.60" Jt. 39 © 1,571 Ft. (MD) Slight Oval Deformation. Deposit Minimum I.D. = 8.45" Jt. 36 © 1,421 Ft. (MD) 1 1 I Field Engineer: E. Gustin Analyst: C. Lucasan Witness: Lee. Hinkel I 9r oActive D aanostic Services, Inc, / 8,0 Box 1369, Stafford, TX 7749 Phone: (281) or (888) 565 -9085 Fax: (281) 595 -1399 5 -mai!: PDS Prudhoe Bay Feld Office Phone: (990 ) 659 -2307 Fax: (907) 659 -231- 1 1 1 g6 I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T -14 Date : May 12, 2011 I Description : Detail of Caliper Recordings Across 9.625" Casing Logged (Off-Center) Comments Depth ff Maximum I.D. 3 -D Log (Off -Cent) Image Map (Off- Center) 1ft:750ft 6.6 inches 9.6 0° 0° 90° 180° 270° 0° U r—. Minimum I.D. .. l 6 -6 inches 9.6 Average I.D. I 6 -6 inches 9.6 Nominal I.D. 6.6 inches 9.6 I 0 !r _ r— ____ II 5 Lt. Deposits I_ - Joint 1 " ' 1 " Buckling ��� --- I Min ID = 8.76" ..--a Joint 2 100 MI — — — i Mill! _ II _ Joint 3 a I 150 �_� -. -as NM = . 1111111111111.11 Joint 4 ..... ...._ - ..-- i`. • 200 111111111111111111111111 r- • gigiamt Joint 5 Me ' _ _.... sir 1 Joint 6 250 IMIIIIIIIIIIIIIIIIIIIM — �� �....._V 1 _ +m- Joint 7 •••••• Buckling MN -lilt I Oval 300 NM at, Deformation mil ) - - e _ Buckl g 1.11111111111111111 : Oval ..---- Deformation 350 1.11.11111111111. L II �MM�N�� 1 ,.ice _ .�, r Joint 9 �� .1����i ..., 1 Cent. Remnant Min ID = 7.55" IIMIIMIMrMMIIIMIIIIf,I 400 -.--- ~" Cent. Remnant � ..- °"'� M in ID =6.68" l� .. m Joint 11 EMU - MilllEM :, evil Oval 450 . ••-- J Deformation ..... . do Joint 12 EM I= as,,.. i Slight 1.111. ' s Buckling 500 ...... M , ' Joint 13 .....aifli ""?. Buckling •-•••• Oval ......11 � 1 -.- ice' Deformation -- 1...� .. ...Kf 550 ......�1 Irk Jo 14 UIIIIIIIP -All Joint 15 •••-• Buckling 600 ---- i` .....- Oval uuI.Ii; Deformation 77 ii �, ......Ii M I 11.•...1E Joint 16 650 11111111 '' _ I Joint 7 11111 it , _.. ... ,____, „,. Oval .1111 I Deformation -.-- 700 - R Joint 18 ......��� Buckling ...111111.117 Oval ..•...1111 11 Deformation ..•...r�i� Joint 19 750 ......1111`M Buckling ......`NP Oval ......IIIHR 1 Deformation .---..` Joint 20 .M r Buckling 800 Oval .....b - ._ _ . . . 111 Deformation ..--- Joint 21 11.11. ' r Buckling 11111111MMEI i Oval - Deformation 850 — Joint 22 1111111111 • Y _ Buckling d ' Oval Deformation lir Joint 23 900 A N Buckling III •i -r - -- Oval NI Mai ....„.11 Deformation MI " 111:1.' I r Joint 24 950 lc =I f."' r Buckling = Oval Deformation _ _ - - _ I Joint 25 R. „,'",wp�+ Severe Bend 1000 Min ID = 8.51” 11111111t vittstr 111112t - Joint 26 M _' C ..y I Buckling Oval •11/2 „yr.+ 3k Deformation 1050 .`tt�ii Joint 27 PAL „- 1 . I buckling Oval -_ - Deformation I I _ — Joint 28 1100 Buckling - Oval Deformation - I Joint 29 Buckling 1150 Oval _ _ Deformation _ — . _ _ . r Joint 30 � Buckling --- Oval 1200 -- � viii I Deformation Joint 31 '" Buckling 1 Oval — _i. :rte. 0,='10w1" I Deformation 1250 — _ Buckling iii Joint 32 .� — Oval -.-. _ I Deformation - Joint 33 1300 11111111 Buckling — - Oval ` Deformation ` Joint 34 Slight 1350 _s I Buckling Oval Joint 35 mow Slight liF I Buckling Oval 1400 .11g/mw Joint 36 ���M�E;l+ Slight •-••MIIM _ -+ —. I Buckling ..-.it Oval Min ID = 8.46" 1450 , ric I Joint 37 .... \ Slight — ""'i — Buckling _,,,, Oval AMIN- 1500 "'O' I Joint 38 Apparent Wear '~' ••f I k 7. Joint 39 -- Heavy 1550 — - Deposits 7 Min t 40 nio _ I Heavy - — Deposits s— �� . Min ID = 4.39" 1600 I I I I I I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T -14 Date : May 12, 2011 I Description : Detail of Caliper Recordings Across 9.625" Casing Logged (Centered) Comments Depth Maximum I.D. 3-D Log (Cent) Image Map (Centered) I 1ft:750ft 6 inches 9.6 0° 0° 90° 180° 270° 0° 1 __ __ _ Minimum I.D. I 6.6 inches 9.6 Average I.D. I 6.6 inches 9.6 Nominal 1.0. 6.6 inches 9.6 : . . I Tree 0 lr. Pup " . Joint 1 50 Buckling Lt. Deposits i \ Min ID = 8.76" 1! - • i Joint 2 100 , I } L Joint 3 f1 1 150 _ 1 Joint 4 1, I t 200 j1 r 1 Joint 5 1 I - Joint 6 250 I. l ) Joint 7 Buckling ' I Oval Deformation 300 - -- , � Joint 8 I Buckling )I Oval Deformation -- 350 == Joint 9 ", - I Cent. Remnant — _ - - Min ID = 7.55" _ Joint 10 400 Cent. Remnant 4 1 Min ID = 6.68" Joint 11 ..1111,1 I Oval 450 • i Deformation I Joint 12 Slight -- _— Buckling 500 ONS I Joint 13 "� Buckling ( - Oval — Deformation 1 Si NI 550 Joint 14 sea ms Ala I Joint 15 f — Buckling 600 Oval .....7--• Deformation 1 , Joint 16 - t•+ 650 ""-" t —H- ..., Joint 17 Buckling -•. Oval Deformation 1. 700 --- — — Joint 18 Buckling Oval ' I Deformation Joint 19 750 Buckling fi Oval I Deformation Joint 20 I :71..; Buckling 800 I Oval Deformation Joint 21 Buckling i ' Oval D 850 • Joint 22 ' Ibibe Buckling Oval j • Deformation 900 Joint 23 Buckling �. <. Deformation NW •` Joint 24 950 • I Buckling Oval Deformation Aft Joint 25 ±� - Joint 27 I Severe Bend 1000 Min ID = 8.51" Al Joint 26 I Buckling t -- Oval Deformation 1050 – " �-- 1 • I Oval .Deformation ' Joint 28 1100 MINI . , -, Buckling .....� d Oval 11111111111111111111111111N Deformation ...-- = - - Joint 29 Buckling 1 150 Oval " Deformation MINI --- , - ... IIMMM Joint 30 Buckling MINIMM 1 Oval 1200 MINININI I Deformation . Joint 31 6 � Buckling Oval ����M I Deformation 1250 p Joint 32 rr MEI I Oval Deformation 41111011 Joint 33 1300 80.1 Buckling i��MI °"a' iiiiiii� ai 1 D MEINIMM.114/111111 __ Joint 34 MINIMINIMIai MIMI Slight 1350 1 Buckling NININIMINI`�►,MI _ Oval MINININIMI`ifaMI Joint 35 MMMWMM� E .1• �- ; A Slight MM.r9Fa 11 Buckling lila Oval 1400 MIMIMItff „�_ = = =NIMI in II Joint 36 ____� � " Slight -MINIMIMI t — I Buckling -= Oval Min ID = 8.46" 1450 -- Joint 37 I Slight Buckling •• •MIMI Oval 111111EIMMEI 1500 Milli= Joint 38 Mai ii A pparent Wear WNW Joint 39 -NI IEMErEd I Heavy 1550 MININIMIM �s�: • Deposits - � Min ID = 7.56" I Joint 40 — = +r- ^^. Heavy � Deposits I�_�� Min ID = 4.39" 1600 = — I I I I I • • fi-r; PDS Multitinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T -14 Date : May 12, 2011 I Description : Detail of Centered and Off - Center Caliper Recordings Across 9.625" Casing Logged M aximum I.D. Depth 3 -D Log (Off -Cent) Image Map (Off - Center) 3-D Log (Cent) Image Map (Centered) 8.5 inches 9.5 1ft:750ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I Minimum I.D. 8.5 inches 9.5 Average I.D. I 8.5 inches 9.5 Nominal I.D. 8.5 inches 9.5 11 0 _ _ zJt ■■ _ .1.1611111-1.1 50 . liell. - _-_ sr mig. ■■ ■[11'1•■ 111 1111111061/111111 • ■ ■ ■El1i■ ■■ 100 1 1111 a _ _ Eli 150 a _ i - II1I .... _ _ 200 �- Wiil M - _Nil b �1 250 '� I ■■III %!� _ ■ ■ ■ Z - ■ ■ MIME 300 4 ■■ 1fa1 is v ...< . ■ ith■■■ ■ �;: ■■ - R 350 - m . - W il ,,, +t _ I �' = 4 o -- 400 I ' NP ! s =1 2 i I I a I" r, ..... . k - it i : t it'd ate P? Vit1l#mt1 t $ #lir '1 ++ l ' P. VON itc ) a T 7 .,.. i W f , 0, , . ,s ! , -, , #,„ i , 1 J NI ' i " .$ a 1 4 1 11 1 * �1 ., eitm't t i'�sur , i +� .A 0 in 0 U) 0 in 0 1A 0 10 0 in et in 1Q 1D ep I■ h 00 00 co O) v - { ! — I • I • _ ■■•■■•■1 ■■fi■U■ , ■I1U I ,III � w' I Ili ►:r1i��a7�1�111 ■L► 7 w ` .1Y1 1 •1 Ili 1:111I'M'Eliviii 1 H 1 I I ■■ + -} I r r !■ MI r r or r ow r 11111 r— 111111 111111 r— — I I I - I �• s it 1100 t - A :i i & ; 1150 _ - _ — st 1 1200 - „E1 � 1„ - rt atow I _ _ II 1250 „F _ _ 1 ..... _ ...... 1300 -r _ . I I '�El I _ :". I — 1350 , - _ . Ill II i 1400 fir i. , _ ., till ,fit M _� 1450 4. , 1 I ilf--i— „ • 1 1500 MI b . MI' . 1550 -- - - 1600 Nominal I.D. 8.5 inches 9.5 Average I.D. I 8.5 inches 9.5 Minimum I.D. 8.5 inches 9.5 I Maximum I.D. Depth 3 -D Log (Off -Cent) Image Map (Off- Center) 3 -D Log (Cent) Image Map (Centered) - a a a.. -amt ice. I I • • I Minimum Diameter Profile c_ . Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool: UW MFC 40 Ext. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches 1 Country: USA Tubing I.D.: 8.921 inches I Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 2 1 4 6 III 8 I 12 1 14 16 I G! 18 E Z 20 r 1 22 24 I/ 26 28 1 30 32 i 34 it 1 36 38 III 1 40 - -- 1 1111 I • • I TI";;;;F.„. PDS Report Overview Body Region Analysis I Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool Type: UW MFC 40 F\t. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J-55 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 9.625 ins 36 ppf J-55 8.921 ins 9.625 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 50 1 Penetration body emo Metal loss body 0 50 100 E _____________ 0 ' I 10 0 10 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 411 40 1 0 0 20 I Damage Configuration ( body ) 10 I 5 __ 30 I 0 Isolated General line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 40 1 Number of joints damaged (total = 3) 2 0 0 1 0 Bottom of Survey = 40 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: 9.625 in 36.0 ppf J -55 Well: 2T -14 Body Wall: 0.352 in Field: Kuparuk Upset Wall: 0.352 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 8.921 in Country: USA Survey Date: May 12, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 32 0.07 0.05 15 3 8.88 Pup Shallow Line of Pits. I 1 37 0 0.05 15 4 8.76 Buckling. Shallow Line of Pits. Lt. Deposits. 2 76 0 0.03 8 2 8.79 Lt. Deposits. L 3 115 0 0.03 7 1 8.91 F 4 155 0 0.02 6 1 8.93 I 5 195 0 0.03 7 2 8.91 6 234 0 0.03 7 3 8.93 II 7 272 0 0.02 6 3 8.96 Buckling. Oval Deformation. I 8 311 0 0.02 7 3 8.92 Buckling. Oval Deformation. 11 9 350 0 0.03 7 3 7.54 Apparent 7" Casing Centralizer Remnant. 10 388 0.07 0.03 7 3 6.68 Apparent 7" Casing Centralizer Remnant. 11 432 0 0.02 6 4 8.93 Buckling. Ova Deformation. 12 466 0 0.03 7 6 8.88 Slight Buckling. I 13 504 0 0.02 6 3 8.86 Buckling. Ova Deformation. 14 543 0 0.02 6 2 8.89 15 583 0 0.02 6 2 8.89 Buckling. Ova Deformation. 16 622 0 0.02 6 3 8.90 17 661 0 0.03 7 5 8.88 Buckling. Ova Deformation. I 18 701 0 0.03 7 5 8.88 Buckling. Ova Deformation. 19 740 0 0.03 7 2 8.84 Buckling. Ova Deformation. 20 780 0 0.04 10 3 8.79 Buckling. Ova Deformation. 21 820 0.12 0.03 7 7 8.78 Buckling. Ova Deformation. I 22 23 859 0.10 0.03 7 7 8.81 Buckling. Ova Deformation. 899 0.10 0.02 6 5 8.79 Buckling. Ova Deformation. 24 938 0 0.03 7 5 8.76 Buckling. Ova Deformation. 25 978 0.08 0.03 7 6 8.51 Severe Bend. I 26 1018 0.06 0.02 6 6 8.79 Buckling. Ova Deformation. 27 1058 0 0.02 6 5 8.81 Buckling. Ova Deformation. 28 1097 0.06 0.02 6 3 8.76 Buckling. Ova Deformation. 29 1136 0.06 0.03 7 5 8.68 Buckling. Ova Deformation. I 30 1176 0.05 0.02 7 5 8.81 Buckling. Ova Deformation. 31 1215 0.09 0.02 6 5 8.76 Buckling. Ova Deformation. 32 1255 0.07 0.02 6 5 8.53 Buckling. Ova Deformation. I 33 1295 0 0.02 6 3 8.88 Slight Buckling. Slight Oval Deformation. I 34 1334 0 0.02 7 6 8.84 Slight Buckling. Slight Oval Deformation. I 35 1373 0.05 0.02 7 5 8.77 Slight Buckling. Slight Oval Deformation. 36 1413 0 0.02 6 3 8.46 Deposit. Slight Buckling. Slight Oval Deformati 37 1452 0.05 0.02 6 5 8.87 Slight Buckling. Slight Oval Deformation. i ll.. 38 1492 0.09 0.12 34 5 8.89 Apparent Wear. I 39 1532 0.02 0.04 10 4 7.55 Heavy Deposits. 40 1572 0.52 0.03 7 4 4.38 Heavy Deposits. Penetration Body I Metal Loss Body I I Page 1 I I I • • ' s PDS Report Cross Sections r I Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 9.625 ins 36 ppf J -55 Analyst: C. Lucasan I I Cross Section for Joint 38 at depth 1516.020 ft Tool speed = 50 Nominal ID = 8.921 _ I Nominal OD = 9.625 '� Remaining wall area = 92% -------"' / Tool deviation — 11° .- 1 i t - 1 1 1 Finger = 22 Penetration = 0.118 ins Apparent Wear 0.12 ins. = 33% Wall Penetration HIGH SIDE = UP I I I I I 1 . • , PDS Report Cross Sections 1 Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J -55 Analyst: C. Lucasan 1 Cross Section for Joint 40 at depth 1603.260 ft Tool speed = 49 Nominal ID = 8.921 ' Nominal OD = 9.625 Remaining wall area = 100% Tool deviation = 15° 1 1 1 1 111 1 Minimum I.D. = 4.385 ins Heavy Deposit Minimum I.D. = 4.38 ins. HIGH SIDE = UP 1 1 1 1 1 I • • I PDS Report Cross Sections w Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 9.625 ins 36 ppf J -55 Analyst: C. Lucasan I I Cross Section for Joint 10 at depth 428.200 ft Tool speed = 50 Nominal ID = 8.921 1 Nominal OD = 9.625 Remaining wall area = 100% Tool deviation = 0° 1 1 1 1 I F i ---,T- i i 1 Minimum I.D. = 6.680 ins Apparent Centralizer Remnant Minimum I.D. = 6.68 ins. HIGH SIDE = UP I 1 1 I I I • • I PDS Report Cross Sections I Well: 2T -14 Survey Date: May 12, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 9.625 ins 36 ppf J -55 Analyst: C. Lucasan I I Cross Section for Joint 25 at depth 982.920 ft Tool speed = 50 Nominal ID = 8.921 I Nominal OD = 9.625 ' Remaining wall area = 78% , 4141121111 1 Tool deviation = 3° I f'''.7 / 1 I I I Minimum I.D. = 8.505 ins Severe Bend Minimum I.D. = 8.51 ins. HIGH SIDE = UP I I I I I I • • KRU 2T -14 Of ConocoPhillips Alaska, Inc. � . �, 2T -14 API: 501032006100 Well Type: PROD Angle @ TS: 44 deg @ 7804 TUBING — SSSV Type: LOCKED OUT Orig Completion: 5/4/1986 Angle @ TD: 44 deg @ 8262 (0 -7403, Annular Fluid: Last W /O: Rev Reason: GLV design oD:3.500, Reference Log: Ref Log Date: Last Update: 7/27/2005 ID.2.992) Last Taq: 7435 TD: 8262 ftKB Last Tag Date: 7/17/2003 Max Hole Angle: 53 deg t) 6500 Casing Str ing - AL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H -40 I SUR. CASING 9.625 0 3170 2804 36.00 J -55 26.00 J -55 PROD. CASING 7.000 0 7675 5754 LINER 5.000 7445 8260 6173 18.00 L -80 Tubing String - TUBING (Video Log shows Leaks ID 7446' & 7800'; Leak 0 7476' not shown, (1 I Size Top Bottom TVD Wt Grade Thread I 3.500 0 7403 5572 9.30 4.70 J -55 EUE 8RD AB -MOD 2.375 7403 7894 5909 EUE 8RD AB -MOD P erforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 7804 - 7850 5844 - 5877 C-4 46 12 10/5/1986 IPERF 60 deg. Phasing;3 3/8" Casing I HyperJ 7931 -7967 5935 -5961 A-3 36 4 10/5/1986 IPERF 60 deg. Phasing; 33/8" Casing HyperJ Gas Lift MandrelsNalves I f St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date VIv 1 2782 2545 Camco KBUG GLV 1.0 BK 0. 156 1258 7/11/2005 Run 2 4993 4039 Camco KBUG OV 1.0 BK 0.250 0 7/10/2005 Cmnt 3 6298 4872 Camco KBUG DMY 1.0 BK 0.000 0 9/12/2001 4 6892 5239 Camco KBUG DMY 1.0 BK 0.000 0 9/12/2001 I 5 7237 5463 Otis LBX DMY 1.5 RM 0.000 0 9!12/2001 Production MandrelsNalves S t MD I TVD Man Mfr Man Type V Mfr I V Type V OD La P ort TRO Date Vlv I f l J I Run Cmnt 6 7333 5526 Camco KBUG CV 1.0 BK 0 0 6/9/1999 I , - Other plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 1751 1736 SSSV Camco TRDP -IA -SSA *Locked Out 12/27/95* 2.812 7277 5489 PBR Baker 3.000 I 7294 5500 PKR Baker'FHL' 2.750 7369 5549 NIP AVA. BPL PORTED NIPPLE 2.750 I 7369 5549 SLEEVE -O AVA BPC SLEEVE 2.310 7871 5893 PKR Baker'DB' 3.500 7885 5903 NIP Camco 'D' Nipple NO GO 1.812 7893 5908 SOS Camco 1.995 I 91 7894 5909 TTL 1.995 G eneral Notes Date Note 12/18/1996 Tubing tally RKB elevations are 1 joint lower than actual -30' difference; corrected 4/2/99 10/7/1998 Leak detect 11/6/95 - Leaks @ 7446, 7476 and 7800 RKB. Downhole video 11/15/95 - leak @ 7294 PKR, hole @ I 7446 RKB, hole @ 7800 RKB. 4/22/2004 DRIFTED TBG TO 7411' WLM, EXCESSIVE DRAG, P/U WGT DUE TO SEVERE SCALING & POSSIBLE CORKSCREWING. I TUBING — (7403 -7894, OD2.375, I D:1.995) PKR I (7871 -7872, OD:4.151) II I NIP - -__ (7885-7886, OD:2. 375) SOS (7893 - 7894,. 0 0:2.375) II I Pert I ( 7931 -7967) STATE OF ALASKA • ALASKAIDAND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Abandon r Repair well fp. Plug FFrforations r Stimulate r Other r Alter Casing r Pull Tubing F Perforate New Pool r Waiver r Time Extension "' Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - 186 - 044 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service " t 50- 103 - 20061 -00' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 f - 2T - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8262 feet Plugs (measured) None true vertical 6175 feet Junk (measured) None Effective Depth measured 8171 feet Packer (measured) 7222, 7291, 7869 true vertical 6107 feet (true vertucal) 5453, 5498, 5891 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115 115 SURFACE 3137 9.625" 3170 2804 PRODUCTION 7645 7 7675 5754 LINER 817 5" 8262 6173 RECEIVED Perforation depth: Measured depth: 6260'- 6262', 7804'- 7850', 7931' -7967' ; l t N ., A )01' True Vertical Depth: 4846- 4849', 5845'- 5878', 5936-5961' Aligka Oil & tiaA Cos. Commission Tubing (size, grade, MD, and TVD) 3.5, L -80, 7265 MD, 5481 TVD Anchnage Packers & SSSV (type, MD, and TVD) 2 PKRS - 2 BAKER 'FHL' @ 7221 MD / 5453 TVD and 7291 MD / 5498 TVD PKR - BAKER DB @ 7869 MD / 5891 TVD NIPPLE - CAMCO DS NIPPLE @ 502 MD / 502 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable SOMED JUN 2 3 201 Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 153 193 1890 -- 221 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ]✓ - Service r Stratigraphic "" 15. Well Status after work: Oil J Gas r" WDSPL r Daily Report of Well Operations XXX GSTOR f WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -099 Contact Brett Packer 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature ` �� l -- L Phone: 265 -6845 Date h ('7. / 1 7( ti Form 10 -404 Revised 10/2010 ` E JUN 01 t Yf u 6. 'il Submit Original Only • f t . KUP • 2T -14 Iv CCN t�llip5 Well Attributes Max Angle MD TD Alask.6 t1(,' Wellbore AP WWI 'Field Name Well Status Inc r) IMD(ft6 6) Act Bt (ftKB) 501032006100 KUPARUK RIVER UNIT PROD 52.63 6,500 00 8,262 0 " Comment H2S (ppm) !Date .Annotation End Date KB -Grd (ft) Rig Release Date ••• well Conlg 2714,5/2,5rsi i12 9,29 PM SSSV- NIPPLE 155 1/17/2010 : Last WO_ 5/22/2011 41.70 5/4/1986 Schematic,NAal A otat Depth (ft613) End Date Annotation Last Mod ._ End Date Last Tag- I 7435 -0 7/17/2003 I Rev Reason- WORKOVER I ninam I 5/24/2011 ' ' ' 0 " Casinr Strin.s 1 '. __: :- . 5 Casing Description String 0... Stang ID ... Top (ftKB) Set Depth (9... Set Depth (ND) ... String Wt... String ... String Top Thrd � P CONDUCTOR 16 15.062 33.0 115.0 115.0 62.50 H WELDED Casing Descdption String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd " - - •' ' SURFACE _ .95/8 8.921 32.5 3,169.7 2,804.1 36.00 J - 55 y BTC Ca sin g Descdption Strin 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd Prod T ie Back 7 6.276 30.5 1 1,626.2 26.00 L -80 TC -II CONDUCTOR, '„ Casing Description String 0... String ID... Top (MKS) Set Depth (f... Set Depth (ND) ... String Wt... String Top Thr 1 33 - 115 PRODUCTION 7 6.276 30.5 7,677.6 5,756.2 26.00 J -55 BTC '.i _ 1 Casing Description String O._ String ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... String Wt... String . String Top Thrd LINER 5 4 276 7,444 8 8,262 0 6,174.5 18.00 L-80 Liner Details ,' Top Depth (TVD) Top Ind N mi.. 4 Top MKS) (ftKB) 0) Item Description Comment ID (in) 7,444.8 5,599.5 48.59 HANGER BAKER MOD A LINER HANGER I, 4.276 Protuenon Tie Hack, 31 -1,635 Tubing Strings Tubing Description String 0... String ID Top (ftKB) Set Depth (f . Set Depth (ND) .. String Wt... String .. String Top Thrd li k GAS LIFT, TUBING I 3 1/2 � _ - - 2 992 I 28 3 7,265 1 5,481 1 9 30 L-80 1 EUE 8rd 2,793 F1 '' Completion Details Top Depth (ND) Top Inc! Nomi... Top(ftKB) (B) (9 Kern Description Comment ID (in) 28.3 28.3 0.26 HANGER McEvoy Gen 4 Tubing Hanger 3.500 SU 32 -3,179 RFACE, 501.9 501.9 0.48 NIPPLE 3.5" x 2.875" Camco " DS " Landing Nipple 2.875 7,191.0 5,432.8 49.54 SEAL ASSY Baker "PBR" Seal Assembly w/ 7.30 -ft space out 3.000 GAS LIFT, J 7,198.8 5,437.9 49.51 PBR 20' Baker "PBR" Polish Bore Receptacle 4.000 llEt 6,356 IV' . .. 7,221.7 5,452.8 49.27 PACKER _Baker "FHL" Retrievable Packer 2.920 Z 7,241.4 5,465.6 49.21 NIPPLE 3.5" x 2.812" Camco "DS" Nipple 2.812 7,256.8 5,475.7 49.16 OVERSHOT Poorboy Tubing Stub Overshot w/ 1-9 spaceout 4.000 GAS LIFT, __ . - - 5,546 - Tubing Description String 0... String ID ... Top (ftICB) Set Depth (f..- Set Depth (TVD) ... String Wt... String ... !String Top Thrd Ilk TUBING Original 2 3/8 - _ 1.995 . 7,265 -1 7,892.2 5,907 7 ... I 4 70. I J 55 I EUE8rdABMOD IPERF, ' Completion Details 6,260 - 6,262 -- - -- Top Depth (ND) Top Intl N aml... Top (ftK8) (ftKB) _ C) Nem Description Comment ID (In) GAS LIFT, 7,276.2 5,488.3 49.10 SEAL ASSY Baker "PBR" Seal Assembly w/ 7.30 -ft space out 3.000 6,513 .. . .__ -_�. 7,277.5 5,489.2 49.10 PBR 13.71' Baker "PBR" Polish Bore Receptacle 4.000 7,291.3 5,498.2 49.06 PACKER Baker "FHL" Retrievable Packer 2.920 GAS LIFT. 7,365.9 5,547.3 48.83 SLEEVE AVA BPL Sleeve w/ 2.320" ID Profile 2.320 7.136 4;. �.._ -. 7,369.0 5,549.3 48.82 XO Reducing 3 1/2" EUE 8rd x 2 3 EUE 8rd Cross over sub 2.375 AV illit 7,791.7 5,835.7 44.33 BLAST RINGS 2 -2 3/8" BTC Blast Joints w/ Carbide Rings F/ 7,79341 T/ 7,849 -ft 1.995 7,867.8 5,890.3 44.33 SEAL ASSY Baker Locator Seal Assembly 2.000 � 7,868.8 5,891.0 44.32 PACKER Baker 5" x 2 3/8" DB Packer w/ 5' SBE and crossover 2.920 . Y ; f it l "D" N C 7,883.0 5,901.1 44.31 NIPPLE amco Nipple w/ 1.812" Profile 1.812 1. PACKER,7,222 '. tai a5 7,890.7 5,906.6 44.31 SOS 2 7/8" Cameo Shear out Sub wi crossover to 2 3/8" EUE 8rd 1 -995 Perforations & Slots Shot Top (TVD) Btm (ND) Dens Top (ftKB) Bbn (ftKB) (ftKB) (ft68) Zone Date (sh ... Typo Comment _ _ 6,260 6,262 4,847.9 4,849.2 4/18/2011 1.0 IPERF USING SINGLE SPLIT SHOT, 18" LONG PERF BETWEEN GLM 85 & PBR SEAL ASSY, = 7,804 7,850 5,844.7 5,877.5 C-4, 2T -14 10/5/1986 12.0 IPERF 60 deg. Phasing;3 3/8 "Casing 7,276 PBR, 7,278 ._.0 -'1 HyperJ } I PACKER, 7,291 , _,_ 7,931 7,967 5,935.9 5,961.4 A-3, 2T -14 10/5/1986 4.0 IPERF 60 deg. Phasing; 3 3/8" Casing HyperJ PROOUCrION,_ ' °:_ Notes General&fety -- Safety - -- __ .. � 7 ` 7329 "�".%.� C`z5^ *x End Date Annotation SLEEVE, 7,366 - - 12/3/2010 NOTE: w /Alaska Schematic9.0 PRODUCTION, f 1 31 -7,678 PERF, 5 7,806-7,850 Illt SEAL ASSV, - -__- - _ _ -_- 7,666 Mandrel Details PACKER, 7,869 - - -- - - - -- Top Depth Top Port ! (TVD) Inc! OD Valve Latch Size TRO Run Stn TopiftKB) (ftKB) ( Make Model On) Sera Type TYPE ON (Psi) Run Date Com._ NIPPLE, 7,683 1 2,793.3 2,552.7 49.16 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/21/2011 2 4,354.0 3,608.2 47.18 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5212011 SOS, 7,881 -- - - -- 1 3 5,546.0 4,395.4 50.44 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/21/2011 4 6,513.5 5,004.2 52.63 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/21/2011 IPERF. - _. 5 7,136.3 5,397.5 49.80 CAMCO MMG 1 12 GAS LIFT OPEN 0.000 0.0 5/212011 7,931 - 7,867 - . - 6 7,329.5 5,523.3 48.94 CAMCO KBUG 1 12 GAS LIFT DMY BK 0.000 0.0 6/9/1999 LINER, 7,445 8,262 TD, 8,262 -- - 2T -14 Well Work Summary ai DATE SUMMARY 3/28/11 PRE RWO T -POT ( PASSED ), T -P POT ( PASSED ), IC -POT ( FAILED ), IC -APOT ( UNABLE TO TEST) FT -LDS ALL NORMAL. 4/17/11 ATTEMPT TO RIH W/1.375" 5' TUBING PUNCH GUN (4SPF, 6.1GRAM CIRCULATION CHARGES 20 TOTAL SHOTS) TOOLS BRIDGEOUT AT 385' COULD NOT FALL AFTER SEVERAL ATTEMPTS. STANDBY FOR 1" SPLITSHOT HOTSHOT FROM DEADHORSE, JOB IN PROGRESS. 4/17/11 PERFORATED TUBING MID -JOINT BETWEEN G LM #5 AND PBR USING 1.0" SPLIT SHOT. SPLIT SHOT 18" LONG AND " D CENTERED AT 7261' (REFERENCING SCHEMATIC DEPTHS). POSITIVE SHOT INDICATION FROM CHANGES IN TUBING AND IA PRESSURES. 5/24/11 PULLED BALL & ROD @ 7235' RKB. IN PROGRESS. 5/25/11 SET DV @ 7136' RKB. MIT IA 3000 PSI, GOOD. PULLED DV @ 4354' RKB & REPLACED WITH OV. PULLED DV @ 2793' RKB & REPLACED WITH GLV. BLED IA TO 0 PSI. ATTEMPTED PULL RHC. IN PROGRESS. 5/26/11 PULLED RHC @ 7241' RKB. BAILED JUNK METAL DEBRIS & SCALE FROM 7250 - 7271' SLM. IN PROGRESS. 5/27/11 BAILED SCALE & CaCO3 FROM 7272' - 7282' SLM. TAGGED IBP WITH EQ TOOL @ 7282' SLM. IN PROGRESS. 5/28/11 BAILED FILL OFF IBP @ 7272' SLM. CHASED IBP DOWNHOLE FROM 7282' TO 7328' SLM. IN PROGRESS. 5/29/11 PULLED IBP @ 7328' SLM. PULLED AVA PORTED SLEEVE @ 7366' RKB. BAILED DEBRIS INCLUDING METAL PIECES, BANDING, RUBBER ELEMENT. IN PROGRESS. 5/31/11 ATTEMP TO REMOVE DEBRIS IN TBG @ 7337' SLM, INSIGNIFICANT RETURNS, IN PROGRESS 6/1/11 REMOVE DEBRIS FROM WELL, TAGGED @ 7412' SLM, SET 2.75 AVA BPC SLEEVE @ 7366' RKB, JOB COMPLETE • • Conoc Phillips Time Log & Summary We/Niew Web Reporting Report Well Name: 2T - 14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/30/2011 3:00:00 AM Rig Release: 5/22/2011 5:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/28/2011 24 hr Summary Move Nordic rig back to Kuparuk 21:00 00:00 3.00 MIRU MOVE MOB P Move Nordic rig from PBU V pad access towards Milne Point turn off. 04/29/2011 Move Nordic Rig 3 from BP side of Milne Pt. to 2A -Pad 00:00 05:30 5.50 MIRU MOVE MOB P Continue rig move from BP side of Milne Point turn off to 1 D -Pad 05:30 07:00 1.50 MIRU MOVE MOB T Standby for Kuparuk Field crew change out. 07:00 09:30 2.50 MIRU MOVE MOB P Move rig from 10 Pad to KCC Parking lot 09:30 10:00 0.50 MIRU MOVE MOB T Standby for Shared Services airline to land on Kuparuk Field runway. 10:00 17:00 7.00 MIRU MOVE MOB P Move rig from KCC Parking lot to CPF2 17:00 19:30 2.50 MIRU MOVE MOB T Standby for Kuparuk Field crew change out. 19:30 00:00 4.50 MIRU MOVE MOB P Move rig from CPF2 Parking lot to 2A Pad. 04/30/2011 Move Nordic Rig 3 from 2A -Pad to 2T -14. Load tree in cellar and Pull over 2T -14 and set down. MIRU, Accept Nordic Rig 3 at 03:00 hrs on 4- 30 -11. Pull BPV. Circulate well with 8.6 ppg SW in attempt to kill well. 00:00 03:00 3.00 MIRU MOVE MOB P Move rig from 2A Pad to 2T -14 03:00 03:30 0.50 MIRU MOVE OTHR P Load tree in cellar. 03:30 04:00 0.50 MIRU MOVE RURD P Pull Nordic 3 over 2T -14 and set down. Accept Nordic rig 3 at 03:00 hrs on 4- 29 -11. Berm up 04:00 05:00 1.00 COMPZ WHDBO MPSP P Obtain well pressures - 2,100 psi, (SITP), 1,900 psi (SIIAP), 10 psi (SIOAP) Attempt to lubricate out BPV - Lubricator failed allowing pressure to release through rod packing - release off and pull above master valve with retrieving tool assy. SWI on master valve. Contact Valve shop 05:00 07:00 2.00 COMPZ WHDBO OTHR P Lay hardline to kill tank and PT at 3,500 psi. Load pits with sea water. 07:00 12:00 5.00 COMPZ WHDBO DHEQ T Wait on another BPV lubricator from Prudhoe. No other lubricator available in Kuparuk. Lubricator on location. 12:00 13:30 1.50 COMPZ WHDBO MPSP P RU Cameron lubricator and Pull BPV. 13:30 14:30 1.00 COMPZ WHDBO CIRC P RU circulating lines for well kill. PT surface equipment 3,500 psi. Page 1 of 23 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:30 15:00 0.50 COMPZ WELCTL SFTY P PJSM ( Well Kill) 15:00 00:00 9.00 COMPZ WELCTL CIRC P Start bleeding gas from tbg /casing. Start pressure 2,100 psi. on TBG, 1,900 psi IA - bleed down both to 750 psi. Bring pumps on at 3 bpm at 790 psi ICP, Pumped 365 bbls of 8.6 ppg SW, FCP = 230 psi. Shut down with 160 psi (SITP), 120 psi (SICP). Blow down hard line. Pull 100 bbls of return fluid from kill tank while loading pits with 8.6 ppg sea water. Continue to Reverse Circulate 324 bbls of 8.6 ppg SW at 8 bpm at 640 ICP and 750 FCP. SITP = 180 psi, SICP = 190 psi. Pull 155 bbls of return fluid from Kill tank, while loading pits with 240 bbls of 8.6 ppg Sea water. Circulate 286 bbls of 8.6 ppg SW at 4 bpm at 560 psi ICP, 560 psi FCP. Recovered 229 bbls of returns at kill tank. Monitor SIP'S 70 psi TBG, 90 psi IA after 15 minutes. Load pits with 268 bbls of 8.6 ppg Sea water and prepare to weight up 9.3 ppg = SIP + 125 psi over balance. 05/01/2011 WT up to 9.3 ppg and Circulate surface to surface. Monitor well for flow. ND Tree and NU BOPE. Attempt to Test BOPE at 250/3,500 psi. - Unsuccessful 00:00 05:00 5.00 COMPZ WELCTL OTHR P Bring wt up to 9.3 ppg on 300 bbls of 8.6 ppg SW in rig pits. 05:00 09:00 4.00 COMPZ WELCTL KLWL P Reverse Circulating at 4 bpm @ 140 psi, total of 180 bbls. Load & Mix additional 9.3 ppg SW. Load pipe shed with 3 1/2" DP. Bullhead 75 bbls SW down tubing. 09:00 10:30 1.50 COMPZ WELCTL OPNW P Monitor well for flow. Well on vac after 30 mins. RD circulating equipment. Set BPV 10:30 13:00 2.50 COMPZ WHDBO NUND P Take picture of tree orientation. ND old tree. 13:00 20:00 7.00 COMPZ WHDBO NUND P NU 11" Bop stack with VBR's, Swap out VBR's for 3 1/2" Solid body rams. 20:00 00:00 4.00 COMPZ WHDBO BOPE P RU test equipment and Fill BOP stack. Attempt to get a shell test - unsucessful 05/02/2011 ND BOPE replace API ring, NU BOPE. Test BOPE. Circulate surface to surface. Pull BPV, Spear TBG hanger and BOLDS. Release spear and leave TBG in neutral wt. RU for slick line and Had to shut well in on Blind rams. Bullhead and kill well. 00:00 03:00 3.00 COMPZ WHDBO NUND T ND BOPE and install proper API ring gasket. NU BOPE. Page 2 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 09:00 6.00 COMPZ WHDBO BOPE P RU BOP test equipment. Begin Testing BOPE at 250/3,500 psi. 24 hr Notice was given to AOGCC at $` t, 4 -29 -11 at 09:45 hrs, Call back received at 9:56 hrs on 4- 29 -11, Updated at 18:00 hrs on 4- 30 -11. Right to witness was waived by Chuck Scheve 09:00 10:00 1.00 COMPZ WHDBO MPSP P Attempt to pull BPV. Found 1,200_ psi of gas below BPV. Pump 80 bbls of 9.3 ppg SW down tubing through BPV @ 2 bpm ICP 1,250 psi. 10:00 12:00 2.00 COMPZ WHDBO MPSP P Make another attempt to pull BPV. Stack drained initially than began to fill up again. Lay down pulling tool. Circulate down tubing and up casing @ 2 bpm through BPV 200 bbls, 20 psi of gas on IA. 12:00 14:00 2.00 COMPZ WELCTL CIRC P Continue circulating, pump another 260 bbls @ 2 bpm ICP 210 psi FCP 50 psi. 14:00 15:30 1.50 COMPZ WELCTL OWFF P Monitor well 30 mins, well on vac. Pull BPV, well drinking @ 80 BPH, load pits. 15:30 18:00 2.50 COMPZ WHDBO FISH P PU and MU spear, engage TBG hanger. Stack top drive wt on spear. BOLDS, TBG grew 30 ", PU additional 36" to 114k. Release spear and lay down same. 18:00 18:30 0.50 COMPZ WELCTL SLKL P Prepare to RU Slick line, during make up of landing pups to hanger, observed flow, lay down pups.Had to shut well in on Blind rams - had 60 psi. Bled tubing off to tiger tank. Start bullheading 9.3 ppg SW down tubing. 18:30 00:00 5.50 COMPZ WELCTL CIRC P Monitor SIP. Load pits with 582 bbls of 9.3 ppg KWF. Bull head 310 bbls staging up to 5 bpm at 260 psi ICP up to 510 psi before break over then pump another 110 bbls at 5 bpm with pressure stabilized at 450 psi. Shut down pumps and pressure fell to 210 psi initially then to 130 psi in 15 minutes. Pressure stayed the same for the next 15 minutes. Bleed off pressure to kill tank. 05/03/2011 RU Slick line and PT lubricator at 1,000 psi. RIH w/ 2.70" OD Gauge ring to ava nipple and POOH, RD Slick line RU E line. RIH with WRP. Unable to get WRP past 1,126 -ft elmd. Call out Weartherford Inflatable Bridge Plug. 00:00 00:30 0.50 COMPZ WELCTL OTHR P Screw into hanger and set in slips at 50k and RU for slick line. 00:30 05:00 4.50 COMPZ WELCTL SLKL P RU slick line. PT lubricator to 1,000 psi, RIH with 2.70" OD Gauge ring to 7,369 -ft RKB SLM. POOH and RD Slick line. Page 3 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 08:00 3.00 COMPZ WELCTL ELNE P MIRU HES E -Line equipment. Open TIW valve, tbg pressure 450 psi. RIH w/ Weatherford 3.5" WRP (Special Clearance 2.69" OD) to 1,117 -ft, unable to worh through restriction, Weatherford rep not willing to try pumping. Rig back E -Line equipment. 08:00 12:00 4.00 COMPZ WELCTL CIRC P RU circulating lines and test to 3,000 psi. Reverse circulate 200 bbls 9.3 ppg SW, bull head additional 70 bbls down tubing, 60 psi on well. 12:00 13:30 1.50 COMPZ WELCTL SLKL T Wait on timed out S/L crew. 13:30 18:00 4.50 COMPZ WELCTL SLKL P PJSM. RU S/L equipment and test lubricator 1,000 psi. RIH w/ 2.72" Dumbbell assembly to 775' and 1,125' WLM, tap through each spot, tag BPL nipple @ 7,359'WLM, POOH. RIH w/ 2.70" Dumbbell assembly with same result to 1,200'WLM, POOH. Rig back S/L equipment. 18:00 20:00 2.00 COMPZ WELCTL CIRC P WHP = 730 psi. Fill Annulus with 23 bbls 9.3 lb/gal Brine. Bullhead Tubing volume with 9.3 lb/gal Brine. (Ordered and 1 11/16" IBP from Weatherford in case attempt to get the WRP past tight spot in the 3 1/2" Tubing, fails). 20:00 20:15 0.25 COMPZ WELCTL SFTY P PJSM with All. Discuss Rigging up E -line and picking up Tool String. 20:15 21:30 1.25 COMPZ WELCTL ELNE P Rig up E -Line Equipment. Plck -up Tool String and a 2.69" Weatherford Retrievable Plug. Pressure test Lubricator at 1,000 psi. Open Well and record WHP at 330 psi. RIH. Set down with the WRP at 1.126 -ft elmd. Attempted several times to pass through. No -Joy. POOH. 21:30 22:30 1.00 COMPZ WELCTL ELNE P Rig down Tools and Lubricator. E -Line stand -by for Weatherford IBP and Running Tool. 22:30 00:00 1.50 COMPZ WELCTL PACK T Wait on Weatherford to complete re- building and testing the Running Tool to set the Inflateable Bridge Plug. 05/04/2011 Pick up 1 11/16" Weatherford IBP. RIH. Record Tie -in Log. Set on E -Line at 7,320 -ft. Failed Press Test. However, greatly reduced fluid loss to the Perforations. Attempted to set a Baker IBP as a back -up. No Set. RU S -Line Unit. 00:00 01:30 1.50 COMPZ WELCTL PACK T Continue to wait on Weatherford Tools to arrive on Location. WHP = 650 psi. Fill Annulus with 20 bbls 9.3 lb/gal Brine. Bullhead Tubing Volume at 3.0 bpm /400 psi. WHP = 0 psi. Weatherford IBP on Location. 01:30 01:45 0.25 COMPZ WELCTLSFTY P PJSM. Pick -up Weatherford IBP. Page 4 of 23 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 03:00 1.25 COMPZ WELCTL ELNE P Rig up E -Llne and pick up Weartherford IBP. 03:00 08:00 5.00 COMPZ WELCTL ELNE P WHP = 300 psi. Run in with 1 11/16" IBP. Pass through the tight section at 1,126 -ft with no problems (saw a sight bobble). Continue RIH with IBP at 80 ft/min. Log Tie -in Strip and correlate to the Wellbore Z i7 Schematic. Log IBP into place with (L) the center of the element at 7,320 -ft. in the full Joint just below the Packer. Let Plug set on depth for 15 minutes before setting. Begin setting procedures. Element fully expanded at .670 amps. Let set for 5 minutes. Increase amps to 1.13 and saw setting tool release. Also saw line tension drop off slightly. POOH with E -Line and setting Tool. 08:00 09:30 1.50 COMPZ WELCTL CIRC P Bleed off gas head 350 psi. Pump 250 bbls down tbg up IA to kill tank @ 4 bpm 260 ICP. 09:30 10:00 0.50 COMPZ WELCTL OWFF P Monitor well 30 mins, little or no gas, 1:1 return rate during circulation.. 10:00 11:00 1.00 COMPZ WELCTL CIRC P Pump additional 124 bbls down tbg up IA, 1:1 return rate, 250 ICP. No gas or pressure at surface. 11:00 12:00 1.00 COMPZ WELCTL PRTS P RU and test Weartherford IBP @ 7,320 -ft to 1,000 psi, not holding after several attempts, RD test equipment. Decision made by town Engineer to set additional IBP. Well losing 6 BPH while waiting on IBP. 12:00 15:00 3.00 COMPZ WELCTL PLUG T Wait on Baker IBP from Prudhoe. Ready E -Line equipment for second IBP run. 15:00 17:00 2.00 COMPZ WELCTL ELNE P Finish MU of E -Line surface equipment. MU Baker 1 11/16" IBP 17:00 21:00 4.00 COMPZ WELCTL ELNE P (Fluid loss — 6 bbl /hr). Run in with Baker 1 11/16" IBP. Log tie -in pass and correlate to the log used to set the Weatherford IBP. Log Baker IBP into place with the center element at 7,310 -ft. Begin normal setting procedures with .170 amps. Amps very slowly increased to .225. l However, amps never increased from there. Continue attempted setting procedures. Abort further attempt. No indication the the element expanded. POOH with IBP and Setting Tool. Rig down IBP and Tool string. Rig down E -Line equipment. 21:00 21:30 0.50 COMPZ WELCTL SLKL P PJSM with S -Line Crew. Discuss Rig up and Dump Bailer Runs. 21:30 00:00 2.50 COMPZ WELCTL SLKL P Spot S -Line Unit. Rig up S -Line Equipment. Page 5 of 23 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/05/2011 24 hr Summary Dump Bail CaCO3 Sluggets on top of IBP at 7,320 -ft. RD S -Llne. RE E -Line and cut 3 1/2" Tubing. Pull Tubing Hanger to Floor. RD and release E -Line. Circulate Well. Begin to single down 3 1/2" Completion. 00:00 13:00 13.00 COMPZ WELCTL SLKL P Complete S -Line Rig up. Pick -up 2" Dump Bailer. Make a drift run through the tight section at 1,125 -ft. No problems. POOH. Start Dump Bailer runs to cover the Weatherford IBP at 7,320 -ft with CaCO3. Make six bailer runs to dump bail 10' of CaCO3 above IBP. Make 2.5" x 5' Dummy Drift through tight spots to 1,200 -ft. Had to jar through 774', 954' and 1,124 -ft. Stand back S/L equipment, pull on tubing string to just below string weight 50K, set in slips. Rerun 2.5" x 5' Dummy drift to 1,200 -ft, only small bobble @ 1,126 -ft. POOH. Rig back S /L. 13:00 14:00 1.00 COMPZ WELCTL PULD P Put additional weight on tubing string to 60K just above string weight, set in slips. Ready rig floor for E -Line. 14:00 18:00 4.00 COMPZ RPCOM ELNE P RU E -Line equipment for tubing cut @ 7,264 -ft. Test lubricator to 1,000 psi. RIH w/ 2.5" RCT cutter @ 120 FPM, only slight bobble at tight spot 1,126 -ft. Continue in hole with cutter, make correlation passes, stop CCL @ 7,249 -ft. Cut depth is 7,263 -ft, just below split shot depth, fire cutter. POOH. Hung up initially, let jars go off twice, pulled free. POOH. 18:00 20:00 2.00 COMPZ RPCOM THGR P Pulled Tubing Hanger to Floor. Tubing moved at 120K. Pull Hanger to Floor at 106K and dragging. Unable to go back down. Breakout Landing Pups and Tubing Hanger. Secure Well. 20:00 20:45 0.75 COMPZ RPCOM ELNE P PJSM. Complete E -Line rig down and release Unit. 20:45 22:00 1.25 COMPZ RPCOM CIRC P Circulate Well at 5.0 bpm/ 690 psi. Total volume circulated = 300 bbls. No gas to surface. (Rig -up Control Line Spooling Unit). 22:00 00:00 2.00 7,264 6,774 COMPZ RPCOM PULL P PJSM. Single down 3 1/2" Completion while spooling Control Line. Tubing dragging. Control Line is wrapped around Tubing. 05/06/2011 Continue to single down the 3 1/2" Completion. Test Blind Rams. Begin to single in with 7" Casing Scraper on 3 1/2" Drill Pipe. Circulate out gas influx. Continue to single in 3 1/2" Drill Pipe. Page 6 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 6,774 5,515 COMPZ RPCOM PULD P Continue to Single down the 3 1/2" Completion while spooling Control Line. Kick out Tubing from Pipe Shed as required. Lay down SSSV. Rig down Spooling Unit. 30 SS bands recovered complete. Noticeable corkscrew to tubing pulled, more noticeable in the 70 to 1,150' depth. 02:30 10:30 8.00 5,515 0 COMPZ RPCOM PULD P Continue to single down remainder of the 3 1/2" Completion, on surface, minimal scale and erosion on tubing. Kick out the completion equipment from pipe shed and stage to be norm tested. Take pictures of cut joint just below split shot area. 10:30 17:00 6.50 0 0 COMPZ WELCTL BOPE P Set test .plug for blind ram test to 250/3,500 psi. Had diffculty with test plug holding, after several attempts, lay down test plug, MU old hanger with BPV, land hanger for test plug. Perform blind ram test, good test. Test waived by AOGCC (Lou Grimaldi). Rig down test equipment. 17:00 19:30 2.50 529 COMPZ RPEQPI PULD P MU 7" Casing Scraper assembly. Begin to single in with 3 1/2" Drill Pipe from the Pipe Shed. 19:30 20:30 1.00 529 529 COMPZ WELCTL CIRC P Driller noticed a 0.2 bbl Trip Tank gain. Secure Well and monitor. Pressure observed on Choke Pannel. Monitor pressure build -up. Pressure on both the Tubing and the Casing at 170 psi. Line up to pump down the Drill Pipe and take returns through Manual Choke through the Gas Buster. Bring pump on line with 9.3 lb/gal Brine at 1.0 bpm to clear gas cut fluid that has risen to surface. TP = 220. CP = 180. Maintain 160 psi on Choke and circulate out gas cut fluid. Circulated 4 hole volumes from end of BHA at 529 -ft. Close in Well with TP at 160 psi and CP at 160 psi. Monitor SI pressure for 15 minutes. Pressures remained stable at 160 psi. Bleed TP and CP to "0" psi. Monitor. Open Well. Fluid level static. 20:30 23:00 2.50 529 1,950 COMPZ RPEQPI PULD P Continue to single in with 3 1/2" Drill Pipe. Monitor Drill Pipe displace in Trip Tank very closely. Slowly observe a gradual 0.2 bbl increase from calculated Drill Pipe displacementment. Stop. Shut in Well to condition Well from 1,950 -ft. 23:00 00:00 1.00 1,950 1,950 COMPZ WELCTLCIRC P Circulate Well with 9.3 lb/gal Brine at 1.0 bpm taking returns through Manual choke and Gas Buster. Page 7 of 23 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/07/2011 24 hr summary Continue in with 7" Csg Scraper. Stop and condition Well as needed to get to bottom with present wellbore fluid, 9.3 lb/gal Brine. Tag top of the 3 1/2" Tubing Stump at 7,252' dpmd. Swap Well over to 9.6 lb/gal Brine. TOOH. TIH with 7" Baker RBP. 00:00 01:30 1.50 1,950 1,950 COMPZ WELCTL CIRC P Continue to circulate Well from 1,950-ft with 9.3 lb/gal. End _ Circulating. Monitor Well static. 01:30 03:30 2.00 1,950 3,885 COMPZ RPEQP1 PULD P Continue to run in hole with 7" Casing Scraper with single 3 1/2" Drill Pipe from Pipe Shed. Continue to closely monitor Drill Pipe displacement. Stop at 3,885 -ft to monitor Well. Observe Well static. 03:30 04:30 1.00 3,885 4,850 COMPZ RPEQPI PULD P Up weight = 90K. Down weight = 72K. Continue to single in with 3 1/2" Drill Pipe. Stop at 4,850 -ft to condition Well. 04:30 06:30 2.00 4,850 4,850 COMPZ WELCTL CIRC P Citculate Well with 9.3 lb/gal Brine at 4.0 bpm /500 psi. 06:30 07:00 0.50 4,850 4,850 COMPZ WELCTL OWFF P Monitor well for flow, static 30 minutes. 07:00 09:30 2.50 4,850 7,240 COMPZ RPEQP1 PULD P Continue to run in hole with 7" Casing Scraper with single 3 1/2" Drill Pipe from Pipe Shed. Up weight 140K Down weight 85K. Continue to closely monitor Drill Pipe displacement. Stop at 7,240 -ft to monitor Well. Observe Well static. 09:30 11:30 2.00 7,240 7,240 COMPZ WELCTL KLWL P Weight up fluids in pits from 9.3 to_ 9.6 ppg KWF 11:30 13:30 2.00 7,240 7,252 COMPZ WELCTL CIRC P Displace with 9.6 ppg KWF @ 4 bpm 670 ICP, Continue in hole with scraper, tag top of tubing stub @ 7,252 -ft. Blow down top drive and monitor well for 30 mins, well static. 13:30 15:00 1.50 7,252 7,252 COMPZ RPEQP1OTHR P Slip and cut drill line. 15:00 18:30 3.50 7,252 0 COMPZ RPEQP1 PULL P Trip out hole casing scraper, continue to closely monitor trip tank 18:30 00:00 5.50 0 7,138 COMPZ RPEQP1TRIP P PJSM. Pick -up Baker Model "GI Lock -Set 7" Retrievable Bridge Plug. Trip in on 3 1/2" Drill Pipe from the Derrick. 05/08/2011 Set Baker RBP at 7,235 -ft center element. Circulate Well. PT RBP at 3,000 psi. Good. Dump Sand. Tag Sand. TOOH. Perform Weekly BOPE Test. RU E -Line. Record Caliper /GR Log in the 7" Casing. 00:00 00:30 0.50 7,138 7,235 COMPZ RPEQP1PACK P Up weight = 135K. Down weight = 90K. Set Baker Model "G" Lock -Set Retrievable Bridge Plug with the center element at 7,235 -ft (Top at 7,230 -ft, bottom at 7,242 -ft). Release Running Tool. 00:30 02:00 1.50 7,235 7,075 COMPZ RPEQP1 CIRC P Pull 5 Joints of Drill Pipe. Rig up to circulate Well. Circulate and condition Well with 9.6 lb/gal Brine at 6.0 bpm /1,070 psi. Page 8 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:30 0.50 7,075 7,075 COMPZ RPEQPI PRTS P Pressure test Retrievable Bridge_ Plug at 1,500 psi x 5 minutes and at 3,000 psi x 10 minutes. Good test. Record test on Chart. 02:30 06:00 3.50 7,075 7,178 COMPZ RPEQPI PACK P POOH to 7,075 -ft. Sack dump 20/40 Mesh Sand down Drill Pipe while trickling in 9.6 lb/gal Brine. Allow sand to settle 30 mins, tap top of sand @ 7,178 -ft. 06:00 10:00 4.00 7,178 0 COMPZ RPEQP1TRIP P TOOH w/ Baker setting tool, standing back 3.5" DP in derrick. On surface with setting tool, lay down same. 10:00 11:00 1.00 COMPZ WELCTI PULD P MU test equipment and shell test to 3,500 psi. 11:00 15:00 4.00 COMPZ WELCTI BOPE P Perform weekly BOPE test. Function and PT BOP rams, choke manifold, and annular to 250/3,500 psi. Test (t' waived by AOGCC (Lou Grimaldi) @ �) 09:30 on 05- 08 -11. 15:00 16:00 1.00 COMPZ EVALWE SFTY P Prep floor for E -line equipment. PJSM. 16:00 19:30 3.50 COMPZ EVALWE ELOG P MIRU E -Line equipment and PT Lubricator to 500 psi. 19:30 00:00 4.50 COMPZ RPEQPI ELOG P RIH and record 40 -Am, Caliper /GR Log from 7.160 -ft, just above the Top of Sand at 7,178 -ft back to surface. 05/09/2011 Complete Gyro Log. Record Cement Bond Log. Pick Top of Cement from Log. RIH with String Shot to "rattle" the 7 Collar to be backed -off. RD E -Line. Run and set Baker RBP at 2,190'. Test at 3,000 psi. Dump Sand. Tag Sand top at 2,140 -ft. 00:00 09:00 9.00 COMPZ EVALWE ELOG P Lay down Caliper /GR Tool String. Pick -up and calibrate Gyro Tool. Run in and begin recording data from 7,160 -ft. to surface. 09:00 10:00 1.00 COMPZ EVALWE PULD P Lay down Gyro equipment and MU tools for CBL run. PT surface equipment to 500 psi. 10:00 14:00 4.00 COMPZ EVALWE ELOG P RIH w/ CBL tool string to 7,160 -ft. Set down @ 5,390 -ft, work string to 5,410 -ft, unable to make hole, suspect centralizer. Decision made from town, up log from 5,410 -ft to surface. On surface with logging tools, lay down same, check data. Cement top @ 1,690 -ft, log also showed good cement bold from 1,700 to 3,160 -ft, free pipe from 3,160 -ft to 5,410 -ft tag depth. 14:00 14:30 0.50 COMPZ RPEQPI SFTY P PJSM with Halliburton crew. 14:30 17:30 3.00 COMPZ RPEQPI ELNE P MU tool string for string shot run. PT surface equipment to 500 psi. RIH w/ 240 grain string shot to 2 nd collar above TOC @ 1,622 -ft. POOH. Confirm shot. RDMO Halliburton E -Line equipment. Page 9 of 23 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 0 2,107 COMPZ RPEQPI PACK P PJSM. Make up Baker 7" Model "G" Retrievable Bridge Plug in and set at 2,190 -ft, center element (top of fish neck at 2,185 -ft). Pressure test at 3,000 psi x 10 minutes. Good. Record on chart. Pull up hole to 2,045 -ft. Sack dump 20/40 Mesh Sand while trickling in 9.6 lb/gal down Drill Pipe. Flush Drill Pipe volume at 1 bpm. Wait on Sand to settle. Tag top of Sand at 2,140 -ft. Pull up hole to 2,107 -ft. 05/10/2011 Swap Well over to hot Sea Water, TOOH. ND BOP Stack. Control Casing growth using Hydratight Equip. ND Tubing Spool and pull 7" Pack -off. Spear Casing. Stretch Casing and re -set Slips. Begin NU BOP Stack. 00:00 01:30 1.50 2,107 2,107 COMPZ RPEQP1CIRC P Swap Well over to Hot Sea Water at 3.0 bpm /110 psi. (prep for Arctic Pack recovery). 01:30 02:30 1.00 2,107 0 COMPZ RPEQP1TRIP P Trip out with 3 1/2" Drill Pipe and stand back in Derrick. Lay down Running Tool. 02:30 05:00 2.50 0 0 COMPZ RPEQP1 NUND P Nipple down BOP Stack and set back on Stump. 05:00 11:30 6.50 0 0 COMPZ RPEQPI NUND P R/U Hydratight Equipment & Tools. Had to Bleed down pressure from the OA. 11:30 17:30 6.00 0 0 COMPZ RPEQPI NUND P Start Nipple Down procedure to allow casing head growth. Completed Nipple down of CSG. Total growth of CSG was 42 -1/8" . Initial Pressure 17k and Finial Pressure 1k. 17:30 19:00 1.50 0 0 COMPZ RPEQPI NUND P Make -up 5 3/4" ITCO Spear. Pull up to 137K. Re -set Slips. Release and lay down Spear. 19:00 00:00 5.00 0 COMPZ RPEQP1NUND P Rig -up WACHS Cutter. Cut off 7" Casing growth. Rig -down cutter. Nipple up Cement Cross and install 4 Valves. Begin to nipple up BOP Stack. 05/11/2011 Complete NU BOP Stack. Install 7" Pipe Rams. Make -up 5 1/2" MS Cutter. Cut 7 ". Circulate out Arctic Pack. Pick -up BOP Stack and pull Emergency Slips. NU BOP Stack. Pull Csg to Floor. Lay down 7" Csg. 00:00 03:00 3.00 0 0 COMPZ WHDBO NUND P Finish Nipple up 11 "BOP Stack. • 03:00 04:00 1.00 0 0 COMPZ WHDBO RURD P Change out Lower pipe ram's from _ 3.5" to 7" Pipe Rams. 04:00 05:30 1.50 0 368 COMPZ RPEQP1TRIP P Make -up Baker 5 1/2" MS Cutter and a 6 1/8" Stabilizer. Start in with 3 1/2" Drill Pipe from Derrick. Set down at 368 -ft. POOH to re- configure BHA. Removed 6 1/8" Stabilizer for another attempt. Page 10 of 23 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 05:30 09:15 3.75 0 1,605 COMPZ RPEQP1TRIP P TIH with 5 1/2" MS Cutter and no Stabilizer. Checked Torque @ 500' and 1000' ( 700 # ) for both checks. Continue in hole and located 7" casing collar at 1,585.10' and 1625.0' at 50 spm, 200 psi. Correlated depth to Togs for depth control. PUH and MS Critter at 1605' feet. position _ 09:15 10:00 0.75 1,605 1,605 COMPZ RPEQPICPBO P Set Parameters to start cutting 7" casing. On line with Rig Pump @ 70 spm, 450 psi at 80 RPM, 1 -2k top drive torque, increase pump rate to 100 spm at 800 psi, with 80 RPM and 1 -2 k torque. After 3 mins of cutting seen psi fall off to 650 psi and down to 210 psi. Killed pump and PUH 5 feet, back on line with pump at 50 spm, 200 psi and confirm cut at 1,605 feet. 10:00 11:00 1.00 1,605 0 COMPZ RPEQP1TRIP P Blow down top drive. POOH standing back drill pipe. 11:00 11:15 0.25 0 0 COMPZ RPEQP1PULD P Lay down MS cutter assembly. 11:15 11:30 0.25 0 0 COMPZ RPEQP1SFTY P PJSM. Discuss next step of the operation. Rigging up spear. 11:30 12:00 0.50 0 14 COMPZ RPEQPI RURD P MU 5 3/4" ITCO packoff spear assembly. (3.5" RG bull nose, 7" spar pack -off, spear, spear Ext, spear stop sub W/ 7 1/8" stop ring and XO sub to drill pipe 12:00 12:15 0.25 14 29 COMPZ RPEQP1FISH P Engaked 7" CSG w/ 53/4" ITCO spears PUH 2' feet, Max up wt 135k and sliding up hole weight 108k. Close Pack around Drill Pipe. Prep to Circulate. 12:15 12:30 0.25 29 29 COMPZ RPEQP1SFTY P PJSM. Discuss hazard of circulating Arctic pack. 12 :30 13:45 1.25 29 29 COMPZ RPEQP1CIRC P On line with Rig Pump Circulating 80 degree Diesel at 3 bpm, 150 psi. 13:45 15:00 1.25 29 29 COMPZ RPEQPI CIRC P Circulated a total of 285 bbls of 80 degree Diesel. Swapped over to Hot Seawater at 5 bpm, 160 psi. Continue to circulate until well bore is clean. Pump a total of 198 bbls of 150 degree Seawater. 15:00 15:30 0.50 29 29 COMPZ RPEQP1SFTY P PJSM. Discuss hazard of ND the Bop stack to remove the emergency slips. 15:30 17:00 1.50 29 29 COMPZ WHDBO NUND P Drain Stack. Lift BOP Stack. Remove 7" Casing Emergency Slips. 17:00 19:30 2.50 29 29 COMPZ WHDBO NUND P Nipple up BOP Stack 19:30 20:00 0.50 29 29 COMPZ RPEQP1SFTY P PJSM. Rig up to handle and lay down 7" Casing. Page 11 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 1,605 0 COMPZ RPEQP1 PULL P Pull 7" Casing to Rid Floor._ Release and lay down ITCO Spear. Single down 7" Casing in Pipe Shed. Number and tally casing. (Began pulling Casing at 120K. Broke back to 95K. However, observe over pull once and a while. Casing severally cork screwed). Recovered 38 full joints and a 20.89 -ft cut -off stub. Cut was good. 05/12/2011 Tally Csg and off -load Pipe Shed. Change Pipe Rams in lower Gate to 2 7/8" x 5" VBRs. Test BOP Body and VBRs. Make -up 9 5/8" Csg Scraper. RIH. Tagged up at 374 -ft. POOH. RU E -Line. Record Gyro Log data. 00:00 01:00 1.00 0 0 COMPZ RPEQP1RURD P Rig down casing handling equipment. Complete 7" Casing tally (1,578.31 -ft). Cear Pipe Shed. 01:00 07:00 6.00 0 0 COMPZ WHDBO BOPE P Pull 7" Pipe Rams in lower gate and, install 2 7/8" x 5" VBRs. Rig up test equipment. Make -up and install Test Plug. test Body breaks and the 2 7/8" x 5" Pipe Rams. 07:00 09:00 2.00 0 0 COMPZ WHDBO RURD P Pull test Plug. Rig down testing equipment and Install Wear Ring 09:00 11:30 2.50 0 309 COMPZ RPEQP1RURD P Rack & Tally 6 1/4" Drill Collars. PJSM. Rig Up Scraper Assembly. 9 5/8" CSG Scraper,bit sub,bumper sub, Oil jars, XO sub, and (9 ) 6 1/4" Drill Collars. 11:30 12:00 0.50 309 374 COMPZ RPEQP1TRIP P TIH with 9 5/8" CSG scraper assembly on 3.5" Drill Pipe. Sat down with scraper assembly at 374 feet, made several attempts to work thru tight area. No success. Call E -Line Crew and Equipment. 12:00 12:15 0.25 374 374 COMPZ RPEQP1SFTY P PJSM on TOOH and laying down Scraper Assembly. 12:15 13:45 1.50 374 0 COMPZ RPEQP1TRIP P POOH, laying down scraper assembly. 13:45 20:00 6.25 0 0 COMPZ RPEQP1NUND P Nipple Down Riser and Install Shooting Flange and Prep for E -Line operation. Start Loading 7" Casing and Tie -back completion. 20:00 00:00 4.00 0 0 COMPZ EVALWE ELOG P PJSM. Rig -up Eline equipment. Pick -up and calibrate Gyro Tool. Run in hole and make station stops. Lightly tag top of the 7" Casing Stump at 1,602 -ft (bottom of tool). Begin to log back to surface and record Gyro data. 05/13/2011 Continue with E -line Logging. Record PDS 40 -Arm Caliper /GR Log data. RD E -line. RIH with Tandem String Mill Assembly to 374 -ft. Dress tight sections in the 9 5/8" Casing. Tag top of the 7" Casing Stump. TOOH. Make -up Casing Back -Off Assy. RIH to top of the 7" Csg Stump. Attempt to enter same. No -Joy. Page 12 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 0 0 COMPZ EVALWE ELOG P Complete recording Gyro data. Lay down Gyro Tool. Pick -up PDS 40 -Arm Caliper /GR Tool. Run in hole to top of the 7" Casing Stump at 1,605 -ft. Log back to surface and record Caliper data. Lay down Caliper Tool. Rig down E -line equipment. 04:30 06:00 1.50 0 0 COMPZ EVALWE NUND P Rig down Shooting Nipple. 06:00 06:15 0.25 0 0 COMPZ RPEQP1 PULD P Load baker tools to rig floor. 06:15 06:30 0.25 0 0 COMPZ RPEQP1SFTY P PJSM. Discuss Hazard of making up Sring mill assembly. 06:30 07:15 0.75 0 261 COMPZ RPEQP1 PULD P MU Tandem string mill assembly. 8 3/8" lower string mill and 8 1/2" upper string mill with bumper sub and jars with 6 1/4" drill collar. 07:15 10:30 3.25 261 261 COMPZ RPEQP1 RGRP T After installing riser on top of annular,had small leak on hose connection going to trip tank. Had to work on pump that is used to drain stack. Pump was plug off with debris. Fix pump and drain stack to make repair to connection. Made repairs and Re -fill stack with fluid and perform static test on connection. Good test. 10:30 11:00 0.50 261 374 COMPZ RPEQP1 MILL P RIH w/ milling assembly and set with lower mill at 374 feet, milled thru tight spot on 9 5/8" casing @ 3 bpm, 50 psi, rotating at 80 rpm, 1.5 torque with 3 -5k WOB. Able to milled thru tight area, swivel packing started V leaking on top drive. 11:00 11:30 0.50 374 374 COMPZ RPEQP1 RGRP T Trouble shoot swivel packing. 11:30 15:15 3.75 374 1,601 COMPZ RPEQP1 MILL P Continue with milling operation. Able to mill thru tight spot at 374' at 3 bpm at 50 psi, rotating at 80 rpm, 1.5 torque with 3 -5k WOB. Continue to work both mills up and down thru damage area of 9 5/8" casing until milling assembly is able to slide thru with no problem.Tag Depth lower mill 374' upper mill position 351' / lower mill 388' upper mill position 366' / lower mill 429' upper mill position 407' able to work thru each section. Continue in hole to 1601 feet, did not encounter any other tight spots while TIH to target depth. 15:15 16:30 1.25 1,601 1,601 COMPZ RPEQP1CIRC P Mix and pump 30 bbls high -vis sweep at 10 bpm, 560 psi and CBU until clean. Recovered rubber balls and Platelets in sweep with a small trace of metal shavings. Page 13 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:00 2.50 1,601 261 COMPZ RPEQP1TRIP P Blow down top drive.TOOH with milling assembly standing back drill pipe. 19:00 20:00 1.00 261 0 COMPZ RPEQP1PULD P PJSM. Lay down tandem sting milling assembly. (The 8 3/8" String did the "work ". The 8 1/2" String did very little of the work, if any). 20:00 21:30 1.50 0 311 COMPZ RPEQP1PULD P PJSM. Make -up BHA #9, Casing Back -Off Assembly. 21:30 00 :00 2.50 311 1,601 COMPZ RPEQP1TRIP P Trip in with BHA #9 on 3 1/2" Drill Pipe from the Derrick. Tagged top of 7" Casing Stump. Attempt to enter Casing Stump. Continue to work to enter top of Casing Stump. No -joy. X5/14/2011 TOOH and re- configure bottom of the Back -Off BHA, TIH with Back -Off BHA. Back -off 7" Csg Collar at 1,624 -ft. TIH with Tripple Connection /ES- Cementer Drift Run. TIH with ITCO Spear and complete Csg back -off. Recovered the 7" Casing Stub. Attempt to pull Wear Bushing. 00:00 01:00 1.00 1,601 0 COMPZ RPEQP1TRIP T Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down Back -Off BHA to re- configure bottom of the BHA. 01:00 03:45 2.75 0 1,624 COMPZ RPEQP1TRIP T Take the Bull Nose Shoe off of the bottom of the Break -Off BHA. Installed a 3 1/2" Tubing Pup Joint whit a full Mule Shoe. Trip in to the top of the 7" Casing Stump. After several attempts the Bottom Anchor section finally entered the Stump. Fill Drill Pipe with fresh water. 03:45 04:30 0.75 1,624 1,624 COMPZ RPEQPI BKOF P Set bottom Anchor below the 7" Collar at 1,624 -ft. Pressure up and observe the initial pressure to break collar at 550 psi. Gained 1/2 round on the initial break. Continue to cycle Tool for a total of 10 cycles and a gain of 4 3/4 rounds. Release Tool. 04:30 06:00 1.50 1,624 340 COMPZ RPEQP1TRIP P Trip out standing back 3 1/2" Drill Pipe in the Derrick. 06:00 08:00 2.00 340 0 COMPZ RPEQP1 PULD P Lay down Back -off assembly. Rig down floor equipment. Rig up Casing equipment. 08:00 08:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss Hazard of Making up Dummy Drift BHA. 08:30 10:30 2.00 0 299 COMPZ RPEQPI PULD P M/U Dummy Drift assembly with ES Cementer. Triple connect screw in sub, ES cementer, jars,string magnet with six 6 1/4" drill collars. Bakerlok'd all connection below ES cementer. Rig down casing equipment. 10:30 12:30 2.00 299 1,600 COMPZ RPEQP1TRIP P Continue in hole Dummy drift assembly on Drill pipe. 12:30 13:45 1.25 1,600 299 COMPZ RPEQP1TRIP P Drifted down to 1,600 feet with ES Cementer. Did not encounter any restriction with dummy drift. Page 14 of 23 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:45 14:00 0.25 299 299 COMPZ RPEQP1SFTY P PJSM before laying drill collars and dummy drift assembly. Had metal shavings on string magnet. 14:00 15:45 1.75 298 0 COMPZ RPEQP1PULD P UD 6 1/4" Drill collars and Stand -back ES cementer assembly.UD Baker tools. 15:45 18:30 2.75 0 1,622 COMPZ RPEQP1TRIP P PJSM. Make up ITCO spear Assembly. Trip in to 1,550 -ft. Up Weight = 65K. Down Weight = 67K. Bring Pump on line at 4.0 bpm /120 psi. Wash down to the top of the 7" Casing Stump at 1,605 -ft. Plant Spear. Pick -up to 100K to set Grapple. Complete back -off on the Casing Collar at 1,624 -ft. with 11 turns. Pick -up 2 -ft. Stub free. 18:30 20:00 1.50 1,622 1,622 COMPZ RPEQP1 CIRC P Circulate Well at 5.0 bpm /200 psi with Hot Sea Water to warm up Wellbore and to clean out any remaining Arctic Pack. 20:00 22:30 2.50 1,622 0 COMPZ RPEQP1TRIP P Trip out with 3 1/2" Drill Pipe and Spear Assembly. Lay down Spear and recovered 7" Casing Stub (19.45 -ft). 22:30 00:00 1.50 0 0 COMPZ RPEQP1BOPE T PJSM. Drain Stack. Pick -up Pulling Tool and attempt to pull the Wear Bushing (Unable to get a stright pull on the Wear Bushing due to a very crooked Wellhead). 05/15/2011 ND BOP Stack. Pull Wear Bushing. NU BOP Stack. Install 7" Pipe Rams. Perform Weekly BOPE test. RU and run 7" Tie -Back Casing String as designed, 00:00 02:30 2.50 0 0 COMPZ RPEQP1 BOPE T Nipple down BOP stack and set back on Stumg. 02:30 02:45 0.25 0 0 COMPZ RPEQP1SFTY T PJSM. Discuss remove) of Wear Bushing. 02:45 03:30 0.75 0 0 COMPZ RPEQP1 BOPE T Pick -up Pulling Tool and Landing Joint. Make -up into Wear Bushing. Observe Wellhead leaning —10 degs from being vertical. Attempt to pull with Air Tugger. No -joy. Finally pulled Wear Bushing free with Bridge Crane. Lay down Landing Joint, Pulling Tool, and Wear Bushing. 03:30 05:30 2.00 0 0 COMPZ WHDBO BOPE T Nipple up BOP Stack. 05:30 06:30 1.00 0 0 COMPZ WHDBO BOPE P Change Out LPR's from VBR's to 7" Rams. 06:30 08:00 1.50 0 0 COMPZ WHDBO BOPE P Make Up String Magnet and Swizzle Stick. Wash BOP Stack, clean String Magnet and Repeat unitl clean. Lay down cleaning assembly and blow down top drive. 08:00 09:30 1.50 0 0 COMPZ WHDBO BOPE P Make and Install Test Plug. R/U Testing Equipment. 09:30 10:00 0.50 0 0 COMPZ WHDBO SFTY P PJSM. Discuss Duties and Hazard of Testing BOPE. 10:00 10:30 0.50 0 0 COMPZ WHDBO BOPE P Fill BOP Stack and body test same. Page 15 of 23 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 16:00 5.50 0 0 COMPZ WHDBO BOPE P Start Weekly BOP Test. Jeff Jones UP Waived Witness test. Test Rig Alarms. 16:00 17:00 1.00 0 0 COMPZ WHDBO PULD P Pull Test Plug and Rig Testing Equipment. 17:00 22:00 5.00 0 1,620 COMPZ RPEQPI PUTB P Rig up to handle 7" Tie -Back Casing. Review running order, Perform final inspection of the Triple Connection Bushing (Pin end looking down) and the ES- Cementer. Single in with 7 ", 26 lb /ft, L -80, TC -II Casing. Install Centrilizer on every full Joint. Make -up Torque = 10,000 ft/lbs. Space -out Casing. 22:00 23:30 1.50 1,624 1,624 COMPZ RPEQP1 PUTB P Up Weight = 75K. Down Weight = 75K. Make -up TC -II x BTC Cross -Over Pup Joint. Make -up BTC x IF Cross -Over Sub. Pick -up a 10 -ft 3 1/2" IF Pup Joint and make -up Top Drive. Ease in hole and rotate Triple Connection Bushing over the 7" Casing at 1,624 -ft. Continue to rotate and screw 7" Pin into the 7" Collar at 1,624 -ft. Total turns = 16. Final torque 8 -9 K. Continue to work Casing several times to work torque down. Pull Tested at 50 k over string weight. 1,624 1,624 COMPZ RPEQPI RURD P Install Long Bails on Top Drive. 05/16/2011 Rig up Cmt Equip. Stage Vac Trucks. Cement the 7" Tie -Back String per procedure. WOC. ND and lift BOP Stack. Mix and "bucket dump" cement to bring TOC to surface. Set Slips. Cut off Csg with Wachs Cutter. Set BOP Stack back down. Install VBRs in lower gate. 00:00 02:30 2.50 1,624 1,624 COMPZ CEMEN" PRTS P Schlumberger rig -up complete. Rig up Cement Head. Wait on remainder of the Vac Trucks ordered. Pressure test "screw -in" connection at 2,000/2,500 psi. Good. Record on Chart. Increase pressure and observe the ES- Cementer at 1,610 -ft open with 3,300 psi. Mix Retarder Pills. 02:30 03:30 1.00 1,624 1,624 COMPZ CEMEN" CIRC P Circulate and condition Well with 95 deg F Sea Water at 5.0 bpm /140 psi. Pumped a total of 145 bbls. 03:30 04:00 0.50 1,624 1,624 COMPZ CEMEN" SFTY P PJSM with all. Discuss high pressure, spills, tripping hazards, safe area, communications. Review pumping schedule. Page 16 of 23 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04:00 05:00 1.00 1,624 1,624 COMPZ CEMEN "CMNT P Bring Schlumberger Pump on line with 5 bbls of Fresh Water. Pressure test line at 4,000 psi. Good. Batch up Cement. Start Lead Cement at 5.7 bpm /555 psi, density 15.7 lb/gal, 10 bbls away. Start AS -1 Cement at 5.6 bpm /320 psi, density 15.7 lb/gal. 25 bbls of A1- Cement away at 5.6 bpm /290 psi, density 15.8 lb/gal. End AS1- Cement with 52 bbls pumped at 5.4 bpm /522 psi, density 15.8 lb/gal. Start Tail Cement at 5.2 bpm /540 psi, density 15.7 lb/gal. 10 bbls away. Launch Plug. Plug away. µ Chase Plug with 1 bbl of Cement and ` � �N 5 bbls of Fresh Water. End ( Schlumberger. Bring Rig Pump on line to complete cement displacement. Bumped Plug at 2.0 bpm /590 psi, right at calculated displace volume (56 bbls /1,186 strokes). Increase pressure to 1,500 psi. Increase pressure and saw ES- Cementer shift and close at 2,200 psi. Plug in place at 04:56 hrs. Hold pressure for 5 minutes. Release pressure and observe "no -flow back ". 05:00 06:00 1.00 1,624 1,624 COMPZ CEMEN "CMNT P Rig down Cementer & Equipment. 06:00 07:30 1.50 1,624 1,624 COMPZ WHDBO NUND P ND BOP and Lift. 07:30 09:00 1.50 1,624 1,624 COMPZ CEMEN" CMNT P No cement found at surface. Mix and fill 7" x 9 5/8" casing with 15 gallons of cement that was left on location in three buckets 09:00 13:00 4.00 1,624 1,624 COMPZ CEMEN "CMNT T Order out more dry product from SLB. 13:00 13:30 0.50 1,624 1,624 COMPZ CEMEN" CMNT P Dry Product on location. Mix 5 gallon buckets of cement and top off cement in 9 5/8" X 7" Annular. Was able to get cement up to OA port. 13:30 15:00 1.50 1,624 0 COMPZ WHDBO CPBO P Install Emergency Slips & Land 7" CSG w/ 50k tension. RU Wach cutter and cut 7" CSG. 15:00 22:30 7.50 0 0 COMPZ WHDBO NUND P Change out bonnet seal on one of the Blind Ram. (Load and tally Completion Tubing in Pipe shed). (Change out Bails on the Top Drive). Install VBPR in the lower gate. Test Blind Ram seal. Good. 22:30 00:00 1.50 0 0 COMPZ WHDBO NUND P Nipple down BOP Stack. 05/17/2011 Nipple down BOP Stack. Nipple down Cement Cross. Install Pack -Off. NU Tbg Spool. Install Test Plug. Test BOP body breaks and the VBR. MU BHA to drill out the ES Cementer. Drill up ES Cementer. Test Casing. POOH and clean out Boot baskets. Wash out BOP's. Page 17 of 23 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 COMPZ WHDBO NUND P Nipple down Cement Cross. 00:30 06:30 6.00 0 0 COMPZ WHDBO NUND T Attempt to install 7" Pack -Off. However, the 7" Casing OD measures 7.06" ( -1/16" oversize) Pack -Off ID is 7.00 ". Measure several random 7" Joints that were on location. Measurements ranged 7.06 to 7.07 ". Cameron Wellhead Serviceman removed the pack -off from the Tubing Spool and took both Pack -Offs to Baker Machine to be machined to fit the Casing Stub in the Well Head. (Crew cleaning 3 1/2" Completion Tubing. Many joints have dirt and grit on threads). 06:30 10:00 3.50 0 0 COMPZ WHDBO NUND P Install 7" Pack -off assembly. NU Gen 4 Tubing Head and Pressure test to 3000 psi for 15 mins. Good Test. 10:00 13:00 3.00 0 0 COMPZ WHDBO NUND P PJSM. NU BOP stack with VBR's in bottom cavity. 13:00 14:45 1.75 0 0 COMPZ WHDBO PRTS P PJSM. Set Test Plug in TBG head. Test BOPE to 250/3000 for 15 mins each. Pull Test Plug. Install Wear Bushing 14:45 15:45 1.00 0 305 COMPZ RPEQPI PULD P PJSM. MU Plug Milling Assembly. 6 1/8" Mill Tooth bit, boot basket, string magnet,jars,pump out sub, DC & DP. 15:45 16:30 0.75 305 1,587 COMPZ RPEQP1TRIP P TIH with milling assembly down to top of cement plug and ES cementer. ( Kick While Tripping Drill at 1600 hrs.. 40 second responds time). 16:30 20:30 4.00 1,587 2,140 COMPZ RPEQPIMILL P Tagged Cement Stringer at 1,587ft, Set Parameters, start milling on cement stringer down to cement plug. Up Wt & Dn Wt 65k, RPM 80, 260 psi at 5 bpm. 5 -10k WOB. Mill down and tagged cement plug @ 1,613 ft, continue milling at same parameters to TOS plug at 2,140 -ft MD. 20:30 21:00 0.50 2,140 2,044 COMPZ RPEQP1 PRTS P POOH to 2,044 -ft. MD. -Pressure Est 7" Casing to 3onn psi Chart and Hold Pressure for 15 mins. 21:00 22:30 1.50 2,044 305 COMPZ RPEQP1TRIP P TOOH w /Milling assembly. 22:30 23:30 1.00 305 0 COMPZ RPEQP1 PULD P UD 6 1/8" Mill Tooth bit and empty boot baskets. 23:30 00:00 0.50 0 0 COMPZ RPEQP1 CIRC P Wash BOP Stack with Swizzle stick and string magnet. 05/18/2011 RIH w/ 6.125" OD concave mill assy to Wear ring - un able to get thru. Fish wear ring w/ spear due to damage. Install new wear ring and RIH w/ 6.125" OD concave mill assy to TOS, Dry drill on remanents from 2,135 -ft. to 2,148 -ft. POOH. RIH w/ RCJB to 2,168 -ft and c/o to 2,173 -ft. POOH. PU 6.125" OD Concave mill assy and RIH to 2,170 -ft and dry mill to 2,181 -ft. POOH to 1,185 -ft. Page 18 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 28 COMPZ FISH PULD P PU and MU 6.125" OD Concave mill assy and RIH to 28 -ft MD and set down on wear ring. Unable to get thru. 01:00 06:30 5.50 28 28 COMPZ FISH FISH T Drain stack and found that the wear ring was lipped over to the inside. PU 6" Tapered mill and attempt to friction bite wear ring. Swage out to drift, unable to recover. PU setting tool, unable to engage. PU 7" Spear and engage. Recover wear ring. Replace with new wear ring. 06:30 08:00 1.50 0 310 COMPZ FISH PULD P PU Milling Assembly. 6.125" OD Concave mill, 4 3/4" Boot basket,7" CSG Scraper,bit sub,string magnet,oii jar, pump out sub and (9) drill collars 08:00 08:45 0.75 310 2,135 COMPZ FISH TRIP P TIH with milling assembly on drill pipe. Set down at 2,135 ft. 08:45 09:30 0.75 2,135 2,144 COMPZ FISH MILL P Set parameters,Up & Dn Wt 65k, ROT 65, RPM 60, 1K Torque,WOB 10k, 1000 psi at 8 bpm. 09:30 10:00 0.50 2,144 2,148 COMPZ FISH MILL P Work Mill down to TOS. Shut down pump and dry drill at 60 RPM. 10:00 10:30 0.50 2,148 2,144 COMPZ FISH CIRC P PUH to 2,144 ft and CBU until clean at 8 bpm, 1470 psi 10:30 11:45 1.25 2,144 310 COMPZ FISH TRIP P BD/TD, TOOH with Milling Assembly f/ 2,144 ft. Up Wt =65k 11:45 12:30 0.75 310 0 COMPZ FISH PULD P Stand -back Drill Collars and Lay down Milling Assembly. 12:30 13:15 0.75 0 319 COMPZ FISH PULD P PU Clean Out Assembly. 6 1/8" Junk basket head, 5 3/4" wash pipe,(2) 4 3/4" boot basket,string magnet,oil jar and (9) Drill collar. 13:15 14:30 1.25 319 2,090 COMPZ FISH TRIP P TN with clean out assembly on drill pipe down to 2,090 ft. Drop 7/8" Steel Ball, On line with Rig Pump at 83 spm, 210 psi, ball on seat at 380 psi.Set depth to 2090 ft. 14:30 17:00 2.50 2,090 2,173 COMPZ FISH CIRC P Increase pump rate to 7 bpm, 1,480 psi, Continue in hole clean out sand and debris with RCJB down to 2,170 ft, rotating at 50 rpm, 1 -2k WOB. Clean Down to 2,168 ft, Appears we have something around Bottom hole assembly, Start Jarring to free BHA. Pull up to 165k and let jars fire and straight pull to 225k. Pull free and continue to c/o to 2,173 -ft. 17:00 17:30 0.50 2,173 2,173 COMPZ FISH OTHR P Conduct derrick inspection - post jarring. 17:30 18:00 0.50 2,173 2,047 COMPZ FISH TRIP P POOH f/ 2,173 -ft MD to 2,047 -ft. 18:00 18:30 0.50 2,047 2,047 COMPZ FISH SVRG P Grease crown 18:30 20:00 1.50 2,047 319 COMPZ FISH TRIP P Continue to POOH from 2,047 -ft to 319 -ft. Page 19 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 319 0 COMPZ FISH PULD P POOH w/ DC's and breakdown RCJB - recovered small amounts of rubber plug and aluminum. Small piece of 9.625 csg. 20:30 21:00 0.50 0 314 COMPZ FISH PULD P PU and MU 6.125" OD Concave Mill BHA to 314 -ft. 21:00 22:00 1.00 314 2,170 COMPZ FISH TRIP P RIH w/ BHA #16 to 2,170.0 22:00 23:30 1.50 2,170 2,181 COMPZ FISH MILL P Dry mill on junk from 2,170 -ft to 2,181 -ft. with 15k WOM. 23:30 00:00 0.50 2,181 1,185 COMPZ FISH TRIP P Blow down top drive. POOH from 2,181 -ft. to 1,185 -ft. 05/19/2011 Continue to POOH and PU RCJB BHA. RIH to 2,170 -ft and C/O to 2,190 -ft (top of RBP). POOH, RIH to 2,188 -ft. Change hole over to 9.6 ppg KWF. Retrieve RBP. POOH. RIH to 7,178 -ft and wash off sand to 7,230 -ft. Retrieve RBP #2. POOH and lay down same. PU and MU 3 1/2 Dress off assy. 00:00 00:30 0.50 1,185 314 COMPZ FISH TRIP P Continue to POOH from 1,185 -ft. to 314 -ft. 00:30 01:00 0.50 314 0 COMPZ FISH PULD P Stand back DC's and break down milling BHA. 01:00 01:30 0.50 0 326 COMPZ FISH PULD P PU BHA# 17 RCJB assy to 326 -ft. 01:30 02:00 0.50 326 2,170 COMPZ FISH TRIP P RIH w/ BHA 17 from 326 -ft to 2,170 -ft. 02:00 04:00 2.00 2,170 2,189 COMPZ FISH CIRC P Begin functioning RCJB and clean out from 2,170 -ft to 2,180 -ft. Hung up, attempt to jar free. Continue to clean out to 2,189 -ft. Seen slight increase in torque, PU off of the RBP. Blow down Top drive. 04:00 05:00 1.00 2,189 326 COMPZ FISH TRIP P POOH from 2,189 -ft to 326 -ft. 05:00 06:00 1.00 326 0 COMPZ FISH PULD P Stand back DC's and break down RCJB BHA. Empty out boot baskets and RCJB. 06:00 07:15 1.25 0 2,140 COMPZ FISH TRIP P MU and RIH with RBP retieving tool to 2,186 -ft. 07:15 09:00 1.75 2,140 2,187 COMPZ FISH PULL P PJSM. Continue in hole, sat down and latched fishing neck on RBP. PUH to 80k, sat and let element to relax. 09:00 09:30 0.50 2,187 2,187 COMPZ FISH OWFF P Observe well for flow. 09:30 10:30 1.00 2,187 326 COMPZ FISH TRIP P Blow down top drive. TOH with RBP. 10:30 12:00 1.50 326 0 COMPZ FISH PULD P Stand -back Drill Collars and Lay RBP. Had problems getting the J -Latch to release from RBP. Remove Retriever tool and RBP together. 12:00 15:00 3.00 326 7,153 COMPZ FISH TRIP P MU & RIH with Retriever head on Drill Collars and Drill Pipe. Page 20 of 23 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:00 17:30 2.50 7,153 7,234 COMPZ FISH FISH P On Depth to remove sand from top of lower RBP @ 7,175 ft. Set depth to joint #71, 7,153 ft. Up Wt 133k / Dn Wt 93k. Set parameters, Pump rate,8 bpm at 2010 psi, 1 -2k torque,rotating at 40 rpm, continue in hole to estimated top of sand at 7,178 ft and clean down to 7,204 ft at same , arameters start 15 bbl P high -vis sweept at 7,204 ft and CBU. Continue in clean out sand to top of RBP at 7,234 ft, Pump 15 bbl high -vis sweep and CBU at 8 bpm, 1800 psi. Latch RBP, rotate and PUH seen overpull. Let RBP relax while CBU. 17:30 17:45 0.25 7,234 7,229 COMPZ FISH OPNW P Observed Well for Flow. 17:45 22:30 4.75 7,229 0 COMPZ FISH TRIP P POOH with RBP from 7,229 -ft. to 0.0 and laydown RBP assy. 22:30 23:00 0.50 0 0 COMPZ FISH OTHR P Offload RBP's from rig and load 3 1/2 sizing equipment 23:00 23:30 0.50 0 0 COMPZ FISH SFTY P Held PJSM on PU and MU of 3 1/2 Dress off BHA. 23:30 00:00 0.50 0 COMPZ FISH PULD P PU and MU 3 1/2 Dress off assy (BHA #20) 05/20/2011 RIH and dress off 3 1/2 TBG stub at 7,252 -ft. Reverse circ 265 bbls. Spot 10 bbls of CI 9.6 ppg KWF from 7,252 -ft to 6,991 -ft. POOH laying down 3 1/2 DP and BHA. Change over and RIH with 3 1/2 Completion string to 6,439 -ft. 00:00 02:30 2.50 326 7,233 COMPZ FISH TRIP P RIH w/ BHA #20 to 7,233 -ft, gather parameters: 98k do wt, 132k up wt, 112k ROT wt at 60 rpm's circulating at 3 bpm at 330 psi. 4k free torque. 02:30 03:30 1.00 7,233 7,254 COMPZ FISH MILL P Locate TBG stub at 7,253 -ft and slide over to 7,261 -ft with nutter mill shoe. Set 5k down on inner mill and mill off 1 -ft. to 7,254 -ft with inner mill on TBG stub. PU 5 -ft and dry tag Top of TBG stub at 7,254 -ft. PU to 7,247-ft. 03:30 05:00 1.50 7,254 7,254 COMPZ FISH CIRC P Reverse circulate 20 bbl sweep and chase out with 245 bbls of 9.6 ppg KWF at 5.5 bpm at 1,800 psi, Spot 10 bbls of CI 9.6 ppg KWF 05:00 05:30 0.50 7,254 7,254 COMPZ FISH OWFF P Monitor well for flow. Blow down Top Drive. 05:30 06:30 1.00 7,197 6,231 COMPZ WELLPF PULD P Standy back 1 stand of 3.5" drill pipe. POOH laying 3 1/2 DP and BHA #20 from 7,197 -ft. Up Wt 130k / Dn Wt 95k. 06:30 08:00 1.50 6,231 6,231 COMPZ WELLPF SLPC P PJSM. Slip & Cut Drilling Line. 08:00 14:00 6.00 6,231 326 COMPZ WELLPF PULD P Continue to POOH 3.5" DP and BHA f/6,231 ft, kicking out drill pipe when pipe shed is full. Page 21 of 23 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:00 15:45 1.75 326 0 COMPZ WELLPF PULD P Done Laying down Drill Pipe. Lay down Drill Collar and Baker BHA. Kick out Drill pipe and Drill collars. Load out Baker tools. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard of Making up completions equipment. 16:00 16:30 0.50 0 0 COMPZ RPCOM PULD P PU and Install 3.5" Handling Equipment. 16:30 00:00 7.50 0 6,439 COMPZ RPCOM PUTB P PU and RIH with 3.5" Completion String to 6,439 -ft 90k UP wt 73k DN wt 05/21/2011 Con't to RIH w/ 3 1/2 Completion f/ 6,439 -ft. to 7,258 -ft. space out and set FHL PKR at 7,222 -ft. Shear out PBR at 7,191 -ft. , Space out and land hanger. PT TBG - SOV failed. RU slick line and pull SOV and install DV. Pressure test TBG and CSG to 3,000 psi. Pull DV, RD Slick line. Set BPV. ND BOPE, NU Tree and test. 00:00 02:30 2.50 6,439 7,265 COMPZ RPCOM PULD P Continue to RIH w/ 3 1/2 Completion from 6,439 -ft. to 7,258 -ft. w/ shoe at 7,265 -ft, locate stub and shear out shear pins at 8k and NO -go out. PU to string wt of 95k + 1 -ft. and drop ball and rod. Pressure up to 2,100 psi and seen FHL set, continue to increase pressure 2,500 psi. Shear out PBR at 7,199 -ft. PT IA to 3,000 psi for 10 minutes. Bled off pressure. 02:30 03:30 1.00 7,265 7,204 COMPZ RPCOM HOSO P Space out and land hanger w/ seal assy nogo 7 -ft off PBR at 7,191 -ftt. w/ 14 -ft of seals in PBR. 03:30 17:00 13.50 7,204 7,204 COMPZ RPCOM PRTS T Pressure test TBG and had communication with IA. Call out Slick line to pull SOV at 7,136 -ft. RIH w/ LIB and located Ball & Rod at 7,241 ft. RIH and Set Catcher sub. l RIH and pulled SOV that was sheared.RiH and set Dummy valve. PT TBG to 3,000 psi for 15 minutes and IA to 3,000 for 30 minutes. Bleed of pressure and RIH and retrieve dummy valve.RIH and Pulled catcher sub. RD Slick line. 17:00 17:30 0.50 0 0 COMPZ RPCOM MPSP P Pull Landing jt and Set TWC 17:30 20:30 3.00 0 0 COMPZ WHDBO NUND P ND BOPE and Change UPR's from 3 1/2" Solid rams to VBR's 20:30 21:30 1.00 0 0 COMPZ WHDBO NUND P Change out 2 lock down rams and replace - NU CIW TBG Head Adapter (Type: DP -1 -D, 7 1/16" 5,000# Studded btm x 3 1/8" 5,000# studded top, PN - 257683) and 3 1/8" 5,000# Tree 2T - Pad DSO ( Jerr 21:30 22:30 1.00 0 0 COMPZ WHDBO PRTS P Test void and secondary seals at 250 / 5,000 psi for 10 minutes. Test Tree at 250 / 5,000 psi. 22:30 23:00 0.50 0 0 COMPZ WHDBO MPSP P Pull two way check. Page 22 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ RPCOM SFTY P Held PJSM with Little Red Services on rigging up and PT lines at 3,000 psi. 05/22/2011 Swap hole over to diesel. RDMO. Release Nordic Rig 3 at 0500 hrs. 00:00 02:30 2.50 0 0 COMPZ RPCOM FRZP P Pumping 259 bbls at 2 bpm with FCP of 950 psi. Max circulating pressure was 1,600 psi. 02:30 03:15 0.75 0 0 COMPZ RPCOM OTHR P Blow down lines to open top tank and rig circulating system. 03:15 03:45 0.50 0 0 COMPZ RPCOM MPSP P PU and RU lubricator and lubricate in BPV TBG Pressure - 500 psig. IA Pressure - 400 psig 03:45 04:00 0.25 0 0 COMPZ RPCOM RURD P Dress tree and prepare to jack up rig and pull off 2T -14. 04:00 04:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM on moving rig off well 04:30 05:00 0.50 0 0 COMPZ MOVE MOB P Back off well and clean location. Clean cellar area. Release Nordic rig 3 at 0500 hrs. Page 23 of 23 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 11, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log / String Shot: 2T -14 Run Date: 5/9/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -14 Data in LAS format, Digital Log Image files n U1 ) (7) 1 CD Rom 50 -103- 20061 -00 J Cement Bond Log 1 Color Log 50- 103 - 20061 -00 { MED SEA' :.201 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com RECEIVED / Lot j Date: Signed: MAY i 6 2011 Alaska OSa Gas Cont C Anchorage • • Page 1 of 2 Regg, James B (DOA) From: Schwartz, Guy L (DOA) /�� — o4q Sent: Monday, May 09, 2011 8:58 AM Pit To: DOA AOGCC Prudhoe Bay Cc: Brooks, Phoebe L (DOA) Subject: FW: 2T -14 (PTD186 -044) BOP Usage Guy Schwartz Senior Petroleum Engineer AOGCC ` MAY ZU1' 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Saturday, May 07, 2011 4:47 PM To: Packer, Brett B Cc: Nordic 3 Company Man; CPA Wells Supt; Gober, Howard Subject: Re: 2T -14 (PTD186 -044) BOP Usage Brett, Thanks for update and report. Your BOP testing plan is approved. Guy Sent from my iPhone On May 7, 2011, at 2:19 PM, "Packer, Brett B" <J. Brett .Packer(,,conocophillips.com> wrote: Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE usage on Nordic 3 with a written report. Date, Time of BOPE Use: 05/06/11 1930 hrs WeII /Location /PTD Number: 2T -14 /Kuparuk River Unit/186- 044 /Sundry #311 -099 Rig Name: Nordic 3 Operator Contact: Brett Packer 907 - 265 - 6845 i.brett.packer(c @ conocophillips.com Operations Summary: On 5/4/11, e-line set an IBP below the upper packer in order to provide reservoir isolation and minimize our fluid losses which were at approximately 60 bph. Following setting of the IBP, the well was static, but upon pressure testing the IBP to 1000 psi, the IBP appeared to be leaking. Although not isolated, losses were reduced from 60 bph down to 6 153F - They attempted to set another IBP above the previously set IBP, but the setting tool failed and were unsuccessful. The well had been stable throughout this entire time, and it was decided to dump CaCO3 on top of the original IBP, cut and remove the tubing, then run in with a 7" bridge plug to provide reservoir isolation prior to running any of the planned 7" a -line logs. After placing 10' of CaCO3 on top of the plug, losses were reduced once again from 6 bph down to 1 bph, and the well continued to be stable. The tubing was cut and pulled from the well without incident. Prior to setting the 7" bridge plug, a scraper was to be run to bottom to clean up any scale and gauge the hole. On the trip in the hole with the scraper, at 529' MD, the driller notice a 0.2 bbl gain in the trip tank and immediately took action to SI the well. BOPE Used: Upper 3 -1/2" pipe rams J Reason for BOPE Use: Control flow of fluids from the wellbore due to gas migration from formation. Actions Taken /To Be Taken: The upper pipe rams were closed and the well secured. 5/10/2011 • Page 2 of 2 While monitoring the well, 170 psi was observed on both the drillpipe and casing. ey began circulating 9.3 ppg brine while maintaining 160 psi on the choke to circulate out the gas cut brine. They SI the well with 160 psi on the drillpipe and casing, monitored for 15 minutes and pressures remained stable. They bled the drillpipe and casing pressures to zero, monitored the well, opened it up and the fluid level was static. They then continued in the hole with the scraper run to bottom, stopping occasionally to circulate and condition the well. Once on bottom, the fluid weight was increased to 9.6 ppg and circulated around. They are currently pulling out of the hole, and would like to immediately turn around and head back in with the 7" bridge plug. Technically, we are required to test the upper pipe rams once we are out of the_hole ollowinq the BOP usage, but it would be our preference to quickly turn around and head back in with the 7" bridge plug and qet the well sec ured; then perform a full BOP test, as our weekly BOP test is coming up on 5/9/11 anyway. The rig supervisor has discussed this plan with Bob Noble and he has a•reed this would be a •rudent elan of action. Please contact me if you have any questions or if you require more information. Thanks, Brett Packer Rig Workover Engineer ConocoPhillips Alaska, Inc. 907 - 265- 6845Office 907 - 230 -8377 Cell J. Brett. Packer(a�conocophi Ilips.com 5/10/2011 • • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, May 07, 2011 4:47 PM To: Packer, Brett B Cc: Nordic 3 Company Man; CPA Wells Supt; Gober, Howard Subject: Re: 2T -14 (PTD186 -044) BOP Usage Brett, Thanks for update and report. Your BOP testing plan is approved. Guy Sent from my iPhone R „.Ao On May 7, 2011, at 2:19 PM, "Packer, Brett B” <J. Brett .Packer@conocophillips.com> wrote: Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE usage on Nordic 3 with a written report. Date, Time of BOPE Use: 05/06/11 1930 hrs FTD Well /Location /PTD Number: 2T -14 /Kuparuk River Unit/186- 044 /Sundry #311 -099 Rig Name: Nordic 3 Operator Contact: Brett Packer 907 - 265 -6845 j. brett.packer @conocophillips.com Operations Summary: On 5/4/11, a -line set an IBP below the upper packer in order to provide reservoir isolation and minimize our fluid losses which were at approximately 60 bph. Following setting of the IBP, the well was static, but upon pressure testing the IBP to 1000 psi, the IBP appeared to be leaking. Although not isolated, losses were reduced from 60 bph down to 6 bph. They attempted to set another IBP above the previously set IBP, but the setting tool failed and were unsuccessful. The well had been stable throughout this entire time, and it was decided to dump CaCO3 on top of the original IBP, cut and remove the tubing, then run in with a 7" bridge plug to provide reservoir isolation prior to running any of the planned 7" a -line Togs. After placing 10' of CaCO3 on top of the plug, losses were reduced once again from 6 bph down to 1 bph, and the well continued to be stable. The tubing was cut and pulled from the well without incident. Prior to setting the 7" bridge plug, a scraper was to be run to bottom to clean up any scale and gauge the hole. On the trip in the hole with the scraper, at 529' MD, the driller notice a 0.2 bbl gain in the trip tank and immediately took action to SI the well. BOPE Used: Upper 3 -1/2" pipe e rams p p Reason for BOPE Use: Control flow of fluids from the wellbore due to gas migration from formation. Actions TakenITo Be Taken: The upper pipe rams were closed and the well secured. While monitoring the well, 170 psi was observed on both the drillpipe and casing. They began circulating 9.3 ppg brine while maintaining 160 psi on the choke to circulate out the gas cut brine. They SI the well with 160 psi on the drillpipe and casing, monitored for 15 minutes and pressures remained stable. They bled the drillpipe and casing pressures to zero, monitored the well, opened it up and the fluid level was static. They then continued in the hole with the scraper run to bottom, stopping occasionally to circulate and condition the well. Once on bottom, the fluid weight was increased to 9.6 ppg and circulated around. They are currently pulling out of the hole, and would like to immediately turn around and head back in with the 7" bridge plug. Technically, we are required to test the upper pipe rams once we are out of the hole following the 5/9/2011 Page 2 of 2 • • BOP usage, but it would be our preference to quickly turn around and head back in with the 7" bridge plug and get the well secured; then perform a full BOP test, as our weekly BOP test is coming up on 5/9/11 anyway. The rig supervisor has discussed this plan with Bob Noble and he has agreed this would be a prudent plan of action. Please contact me if you have any questions or if you require more information. Thanks, Brett Packer Rig Workover Engineer ConocoPhillips Alaska, Inc. 907 - 265- 6845Office 907 - 230 -8377 Cell J.Brett.Packer@conocophillips.com t 5/9/2011 • • Page 1 of 1 Regg, James B (DOA) . From: Schwartz, Guy L (DOA) Prb 186 -o 44 Sent: Tuesday, May 03, 2011 4:38 PM To: Brooks, Phoebe L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: FW: 2T -14 (PTD186 -044) BOP Usage Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) MAY 2 444 -3433 (cell) 5�� From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Tuesday, May 03, 2011 4:32 PM To: Schwartz, Guy L (DOA) Cc: Packer, Brett B; Toomey, Ian A; Nordic 3 Company Man; CPA Wells Supt Subject: 2T -14 (PTD186 -044) BOP Usage Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 05/02/11 1830 hrs WeII /Location /PTD Number: 2T -14 /Kuparuk River Unit/186- 044 /Sundry #311 -099 Rig Name: Nordic 3 Operator Contact: Brett Packer 907 - 265 -6845 j.brett.packer anconocophillips.com Operations Summary: The rig completed the initial BOP test at 0900 hrs on 5/02/11. Due to noticeable damage of the threads on the tubing hanger a spear was used to engage the tubing hanger. The weight of the top drive was stacked out on top of the spear, BOLDS and slowly PU to allow for tubing growth until the top drive was at neutral weight. The tubing was then pulled into tension and marked the pipe for spacing out E- line /slickline. The tubing hanger was lowered back into the bowl, released the spear and laid down. While preparing to RU slickline flow was observed and the blind rams were closed trapping 60 psi. The gas was bled off to the tiger tanks and 310bbI of 9.3 ppg seawater was bullheaded into the well to displace any remaining gas. BOPE Used: Blind Ram Reason for BOPE Use: Control flow of fluids from the wellbore due to gas migration from formation. Actions Taken /To Be Taken: After the well was shut in, the gas was bled off to the tiger tanks. Any remaining gas was swept from the wellbore by bullhead 9.3 ppg seawater down the well into the formation. We will set an IBP in the tubing below the top packer to isolate the formation and POOH with the existing completion. Once on surface, we will set a test plug and test the BOP components that were f utilized. Please contact Brett Packer if you have any questions or if you require more information. - Thanks, Howard Gober Wells Engineering Supervisor ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 5/9/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch: 2T -14 Run Date: 4/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20061 -00 x : .IMF MAY 3 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. l % - Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907 -273 -3535 klinton.w ; - '\ Date: `' Signed: • • 8110[E Cif AELASEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Wells Engineer O W ConocoPhillips Alaska, Inc. `Q P.O. Box 100360 4 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -14 Sundry Number: 311 -099 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, sr- Daniel T. Seamount, Jr. Chair DATED this t day of April, 2011. Encl. • • Conoco Phillips Alaska E l P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 L�R 9 . O March 25, 2011 Nob Crd &Gas Cos Commisslatl ,r ctlacage Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -14 (PTD 186 -044). 2T -14 was originally completed in October of 1986. The well is a selective single gas lifted producer completed in the Kuparuk A and C sands. This well is currently shut -in awaiting a workover to replace the corkscrewed tubing and proactively repair the 7" production casing. This well is located in an area where surface subsidence has been an issue. Indications of corkscrewed tubing were first observed as early as July `05 when slickline tools had to work past tight spots around 400' MD. The tubing was recently drifted to 7330' MD with a 1.5" x 5' BHA, which is below the upper packer, but recent drift runs larger than 1.5" OD have been unsuccessful in getting past 1100' MD. Consequently, we are unable to set any downhole plugs. An MIT -OA failed on 12/29/00 and diagnostic casing tests indicate a hole in the vicinity of 313' MD. The OA repeatedly passes a no -flow test (NFT), so it appears the production casing has integrity. On 3/9/11, the tubing failed a TIFL and now is in need of a workover. On 3/15/11, the SBHP was determined using the SIWHP and a static diesel column to surface. The SBHP is calculated to be 2466 psi at a mid -perf depth of 5903' TVD, and the MASP is 1876 psi assuming a 0.1 psi/ft gradient. Plans are to test the BOP's to 3000 psi, which is at least 1000 psi above the MASP to abide by the ConocoPhillips Well Control Policy. The purpose of this workover is to pull the existing tubing, cut & pull —2000' of the 7" casing, re- install ✓ new 7" casing, and circulate cement into the 9 -5/8" x 7" annulus which will ultimately plug the leak in the 9 -5/8" casing at —313' MD and also provide a more structurally sound wellbore to combat surface subsidence. New 3 ' /z" tubing will be run into the well to repair the corkscrewed tubing. Zo' P$ If you have any questions or require any further information, please contact me at 265 -6845. Sincer J. Brett Packer Wells Engineer CPAI Drilling and Wells, STATE OF ALASKA ' ` ►� ALASKA" AND GAS CONSERVATION COMMISSI• 4 ( 1 ( ( • APPLICATION FOR SUNDRY APPROVALS 4' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell • Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing 17- ' Other. r i 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 'I ConocoPhillips Alaska, Inc. Development '.. Exploratory r 186 -044• 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20061 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 2T -14 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 • Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8262 • 6175 ' 8171' 6107' Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115' 115' SURFACE 3137 9 -5/8" 3170' 2804' PRODUCTION 7645 7 7675' 5754' LINER 817 5" 8262' 6173' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7804'- 7850', 7931' -7967' 5845- 5878', 5936' -5961' 3.5 / 2.375 J - 7403 / 7894 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PKR - BAKER 'FHL' MD= 7294 TVD= 5500 PKR - BAKER 'DB' MD= 7871 TVD= 5893 SSSV - CAMCO TRDP -IA -SSA MD= 1751 TVD= 1737 12. Attachments: Description Summary of Proposal ri 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/25/2011 Oil Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name Brett Packer Title: Wells Engineer 377 i// Signature r 2 7- ?/ ( j 4 Phone: 265-6845 Date Commission Use Only r� Sundry Number ! -�\ \- ci Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test K Mechanical Integrity Test r Location Clearance r RECEIVED Other: * 36oa P S` s o f 7 - �- / 1 A 9 201' JA-2_5'06 p 5•- A nh. w tee, r c 7 l S 1' - Al gka Gil & Gas Cane Commission Subsequent Form Required: ' 0 _ -' O ci „ : � APPROVED BY I - Approved b ' n COMMISSIONER THE COMMISSION Date: Ili Form 10 -403 ` ° r`�Vl �' PR 04 21 I, 1 RI G I N A L 3. 3 < // Submit in Du irate I.3' .0(4 • • 2T -14 Expense Rig Workover (PTD #: 186 -044) Current Status This well is currently shut -in awaiting a workover to replace the corkscrewed tubing and proactively repair the 7" production casing. This well is located in an area where surface subsidence has been an issue. Between April 1995 and February 2009, the measured wellhead subsidence was 49.7 inches, an average rate of approximately 3.6 in. /year. Prior to April 1995, no wellhead surveys are available, but based upon the average subsidence rate, there • could be as much as 83 inches of subsidence. Indications of corkscrewed tubing were observed as early as July `05 when slickline tools had to work past tight spots around 400' MD. We are still able to drift the tubing down to 7330' MD with a 1.5" x 5' BHA, which is below the upper packer, but recent drift runs larger than 1.5" OD have been unsuccessful in getting past 1100' MD. Consequently, we are unable to set any downhole plugs. An MIT -OA failed on 12/29/00 and diagnostic casing tests indicate a hole in the 9 -5/8" casing in the vicinity of 313' ' MD. This well has been operating under a waiver, and waiver requirements allowed the well to produce, so long as the OA pressure did not exceed 200 psi and there was no T x IA communication. The OA repeatedly passes a no- flow test (NFT) to this day, but recently on 3/9/11, the well failed a TIFL and consequently has been SI. The current condition of the well is as follows: 3 -1/2" Tubing — TIFL failed on 3/9/11. 7" Casing — No indication of IA x OA communication. 9 -5/8" Casing — MIT -OA failed on 12/29/00. Hole estimated to be at 313' RKB. Passes No Flow Test (NFT), most recent test on 1/5/11. Scope of Work ✓ Replace the corkscrewed tubing, cut & pull a portion of the 7" casing, re -run new 7" casing, cement the 9%" x 7" annulus, and install new 3 'h" tubing. General Well info SBHP/MASP: 2,466 psi / 1,876 psi (Based upon current SITP of 400 psi and a diesel gradient to the mid -perf depth of 5903' TVD. All supporting injectors have been SI. Wellhead: Cameron Gen IV, 11" 3K btm x 7- 1/16" 5K top flange BOP Configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MITOA — failed on 12/29/00, OA NFT— passed on 1/5/11, TIFL — failed on 3/9/11 Well Type: Producer Est. Start Date: April 25, 2011 Prod. Engineer: Mike Balog / Evan Reilly RWO Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre-Me Work Request 1. Punch holes in tubing for circulation. 2. PT tubing and casing packoffs, FT LDS's. 3. Set BPV. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Reverse circulate KWF through holes in the tubing. Bullhead KWF down the tubing to the formation. Verify well is dead. Set BPV. ND tree. NU 11" 5K BOP. Pressure test BOP including annular to 250/3000 psi. L Tt3f 61rsF 2. Pull blanking plug and BPV. Pull tubing in tension, set in slips and close the annular around the landing joint. 3. RU Slickline: attempt to set a WRP in the tubing below the upper packer. 4. Attempt to pull the tubing from the PBR. If the tubing does not pull free, RU E -line and RIH w/ RCT and cut . the tubing mid joint above PBR. RDMO E -line. • • Proposed Procedure Continued 5. POOH laying down tubing and spooling up control line. • 6. Run 7" scraper assembly to top of tubing stub. Circulate well clean. 7. RU E -Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. Based on cement top, determine depth of 7" collar to back -off following casing cut. RIH and fire string shot across that collar. RD E -Line. 8. Set retrievable bridge plug below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. Dump sand on top of RBP. POOH standing back workstring. 9. ND BOP stack. ND tubing head using Hydratight Tensioners to safely allow 7" casing to grow. Spear 7" csg and pull in tension and re -land in slips. RU Wachs cutter and cut 7" casing growth. Tack weld slips to casing. 10. NU 11" 5M BOP on casing head. (Cannot test break due to leak in the surface casing, BOP stack will be or--- considered a diverter, there are 2 barriers in the well at this point.) ✓ 11. Cut 7" casing with mechanical cutter above TOC. Circulate Arctic Pack from the 9 -5/8" x 7" annulus with w/ heated diesel followed by heated seawater. 12. Spear 7" casing and POOH sideways. 13. Run 9 -5/8" casing scraper to top of 7" stub. Circ clean. L hie. e 3 t 3 • 14. RU E -Line. Run caliper to and gyro survey in 9 -5/8" casing. RD E -Line. P g gY Y g 15. Run back off tool and back off casing stub. ✓ (7" 5446) 16. Run tandem string mills to gauge the 9 5 /g" csg for the ES cementer. 17. Spear and recover backed off 7" casing stub. 18. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 19. Open ES cementer and pump cement into 9 -5/8" x 7" annulus to surface. Close cementer. a/ 20. WOC. ND BOP, pull casing in tension and land in slips. Cut 7" casing, install packoff. NU new tubing head. 21. NU 11" 5M BOP and test break to 3000 psi. ✓ 22. Drill out cement. Pressure test casing to 3500 psi. Continue until tag up on top of sand, dry drill to break up debris. Circulate well clean. 3 w pt,; 7 4.. 3.5' 23. RIH with wash shoe, boot baskets, magnets, etc. and circulate out sand on top of RBP. POOH. • 24. RIH w/ RBP retrieving tool on work string. Release RBP and POOH standing back drillpipe. A. RIH w/ overshot and pull tubing stub from PBR if necessary. 25. RIH with seal assembly, FHL packer, and 2(.' $.R on 3 -1/2" drillpipe. Circulate in corrosion inhibited fluid, locate in old PBR, drop ball & rod and set FHL packer. PT IA to.3S 1t psi. Shear new PBR, POOH laying down drillpipe. 300o 26. Redress seal assembly if necessary, RIH to locate in PBR, space out, circulate corrosion inhibited fluid and land the hanger. RILDS. 300 P 27. Pressure test tubing to 2500 psi, PT IA to -3'StR psi. Shear SOV. 28. Set 2 -way check. ND BOP. NU tree and pressure test. 29. Pull 2-way check. Freeze protect well. Set BPV. RDMO Nordic 3. Post -Ri2 Work request: 1. Pull SOV and run DV. Pull WRP if installed. Pull ball & rod. 2. Return well to production. • • COMCOPhiilips Well: 2T -14 3 -1/2" Gas Lift Com letion Conductor: 16 ", 62.5#, H-40 to 115' MD * *New** 3 GL Components os Surface Casing: • Tubing = 3 9.3 ppf, L -80, 9.625 ", 36.0#, J -55 BTC to 3170' MD 8rd EUE Prod Casing: • 2.875" DS- nipple. 7 ", 26.0#, L -80 TC -II to -2000' MD **NEW** 7 ", 26.0#, J -55 BTC from -2000' - 7675' MD • Baker locator w/ 17' seal assy. Liner: • Baker 20' PBR. 5 ", 18.0#, L-80 FL4S from 7445' - 8260' MD • Baker FHL Stack Packer. • 2.812" DS- nipple. • Baker locator seal assy. 20'P R 2 2 FHL Packer • os Z FHL Packer 0 AVA Ported Nipple ■ • Crossover to 2-3/8" Model 'A' Liner Hanger Z �- DB Packer KU P • 2T -14 ConocdPhillips 03 Well Attributes Max Angle & MD TD Al' Alaska, Inc, Wellbore APUUWI Field Name Well Status Inc! (°) MD (RKB) Act Btm (RKB) Corco3Phillips 501032006100 KUPARUK RIVER UNIT PROD 52.63 6,500.00 8,260.0 Comment 1 1425 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' Camco TRDP -1A -SSA `Lock... 41.70 5/4/1986 Well Conft - 2T-14, 8/22/2009 3:52:57 PM -- - - - - - -- _ Schematic - Actual Annotation Depth (WED End Date Annotation Last Mod By End Date Last Tag: 7,435 0 7/17/2003 Rev Reason: add TTL comments ehelton 5/20/2009 Casing Strings I String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (RKB) (RKB) (RKB) (lbs/ft) Grade String Top Thrd Conductor, 115 I C onductor 16 15.062 0.0 115.0 115.0 62.50 H-40 Surface 95/8 8.765 0.0 3,170.0 2,804.3 36.00 J -55 1 Production 7 6.151 0.0 7,675.0 5,754.4 26.00 J -55 SSSV, 1,751 1111 Liner 5 4.151 7,445.0 8,260.0 6,173.1 18.00 L -80 Tubing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Tubing Description (in) (in) Top (RKB) (RKB) (MB) ( (!bs/ft) Grade String Top Thrd -- GAS LIFT -__ TUBING 31/2 2.992 0.0 7,403.0 5,572.3 9.30 J -55 EUE 8RD 2,782 AB -MOD TUBING 23/8 1.995 7,403.0 7,894.0 5,909.0 4.70 IEUE 8RD C AB -MOD Surface, 3,170 Other In Hole ( Jewelry: Tubing Run & Retrievable, Fish, etc.) - -- - --- Top Depth - -- -- - - I (TVD) Top Inc! GAS LIFT, Top (f KB) (a3) (°) Description Comment Run Date ID (in) 4,993 1,751 1,736.2 20.87 SSSV Camco TRDP -IA- SSA *Locked Out 12 /27/95* 10/5/1986 2.812 2,782 2,545.3 49.20 GAS LIFT CAMCO/KBUG /1/GLVBK/.156/1258/ Comment: 7/11/2005 2.875 4,993 4,039.5 49.26 GAS LIFT CAMCO/KBUG/1 /OVBK/.25// Comment: 7/10/2005 2.875 6,298 4,872.1 51.43 GAS LIFT CAMCO/KBUG/1IDMYBK/ // Comment: 9/12/2001 2.875 GAS LIFT, _ 6,892 5,239.3 50.10 GAS LIFT CAMCO/KBUG/1/DMY/BK/ll Comment: 9/12/2001 2.875 6,298 7,237 5,462.8 49.23 GAS LIFT OTIS/LBX/1.5 /DMY /RM/ // Comment: 9/12/2001 2.907 1 7,277 5,488.9 49.10 PBR Baker 10/5/1986 3.000 7,294 5,500.0 49.05 PKR Baker'FHL' 10/5/1986 2.750 GAS LIFT, 6,892 7,333 5,525.6 48.93 PRODUCTION CAMCO/KBUG/1 /CVBK/ // Comment: 6/9/1999 2.875 7,369 5,549.3 48.82 NIP AVA. BPL PORTED NIPPLE 10/5/1986 2.750 7,369 5,549.3 48.82 SLEEVE-0 AVA BPC SLEEVE 6/9/1999 2.310 7,871 5,892.5 44.32 PKR Baker'DB' 10/5/1986 3.500 GAS LIFT, __. 7,237 7,885 5,902.6 44.31 NIP Carrico 'D' Nipple NO GO 10/5/1986 1.812 7,893 5,908.3 44.31 SOS Camco 10/5/1986 1.995 7,894 5,909.0 44.30 TTL ELMD TTL @ 7893' during PL on 02/06/87 10/5/1986 1.995 PBR, 7,277 - - -- r Perforations & Slots [1 - - -- - - r -- __--- r---- - - - -- Shot Top (TVD) Btm (TVD) Dens Top (RKB) Btm (WS) (RKB) (RKB) Zone Data (sh Type Comment 7,804 7,850 5,844.7 5,877.5 1 0/5/1986 12.0 IPERF 60 deg. Phasing;3 3/8" Casing .� � HyperJ PKR, 7,294 - -- 7,931 7,967 5,935.9 5,961.4 10/5/1986 4.0 IPE 60 deg. Phasing; 3 3/8" Casing Hyper) __ Notes: General & Safety PRODUCTION, End Date Annotation 7,333 10/7/1998 NOTE: eak detect log 11/6/95 - Leaks @ 7446, 7476 and 7800 RKB. 10/7/1998 NOTE: Downhole video 11/15/95 - leak @ 7294 PKR, holes © 7446 & 7800 RKB. 4/22/2004 NOTE: P/U WGT DUE TO SEVERE SCALING & POSSIBLE CORKSCREWING. NIP, 7,369 SLEEVE -0, 4/22/2004 NOTE: DRIFTED TBG TO 7411' WLM, EXCESSIVE DRAG i 7 ' 9 5/25/2006 NOTE: WAIVERED WELL: MINOR SURFACE CSG LEAK © 350', OR IA x OA COMMUNICATION 1 1 Production, 7,675 IPERF, - -_ 7,804 -7,850 - -- _ - - -- PKR, 7,871 r•M.MI • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • :,~ ~iAR ~ ?C~~!a ~'4~~f34'~SSS~~'3~-. ~r88k~ 011 ~ ~C1G1l~lt aQR Dear Mr. Maunder: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we112T-14 PTD 186-044 Brinker Platelet job. Please call or a any questions. Sincerely, Perry Klein . ~, a, ... Well Integrity Projects • STATE OF ALASKA • ~~~ ~ ~ ~~'~~ ALASKA OIL AND GAS CONSERVATION COMM~~~~1~~~ ~ ~aBS ~Oti~. Cdf>'ICt11SSi0it REPORT OF SUNDRY WELL OPERATIOI~~t~or~a~ 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other Q Platelet SC repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 186-044 ' 3. Address: Stratigrephic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20061-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 117' 2T-14 ' 8. Property Designation: 10. Field/Pool(s): ADL0025569 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 8262' feet true vertical 6175' feet Plugs (measured) Effective Depth measured 8171' feet Junk (measured) true vertical 6107 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' SURFACE 3053' 9-5/8" 3170' 2804' 3580 2090 PRODUCTION 7558' 7" 7675' 5754' 4980 4320 LINER 815' S" 8260' 6173' 10140 10490 Perforation depth: Measured depth: 7804-7850 7931-7967 true vertical depth: 5844-5877 59 35-5961 Tubing (size, grade, and measured depth) 3.5",J-55,7403' - 2.375",7894' and Packers &SSSV (type & measured depth) pkr= BAKER 'FHL' ; BAKER 'DB' pkr= 7294' ; 7871' SSSV= SSSV SSSV= 1751' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A •k~y~: j~ ry J 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 462 1327 3938 1025 235 Subsequent to operation 462 1327 3938 1025 235 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA contact Loveland ry ein Prin ame Title WI Project Supervisor Signature Phone 659-7043 Date Form 10-404 Revised 04/2004 I ~--` Submit riginal nly~~ 2T-14 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/01 /09 Brinker Platelets SC repair- Unsuccessful; Rigged up pump to the platelet skid and started pumping diesel down the OA and established a LLR of 4bbls. per min. @ 260psi. Loaded batch #1 200 - 8mm cube light platelets and pumped at a rate of 2bbls. per min. @ 300psi. Loaded batch #2 200 - 10mm cube heavy platelets and pumped at a rate of 2bbls. per min. @ 285psi. Loaded batch #3 200 - 15mm with 1/2" core heavy round platelets and pumped at a rate of 2bbls. per min. @ 260psi. Loaded batch #4 500 -10mm w/hard core platelets and pumped at a rate of 2bbls. per min. @ 255psi. #5 100 - 25mm x 10mm disc platelets and pumped 4bbls.per min. @ 320psi. Waited 5min. and pumped 4bbls. per min. @300psi. Rigged down pump and platelet skid. Final T/I/0= 235/1025/20 Brinker Platelets SC repair- Unsuccessful TUBING (0-7403, OD:3.500, ID:2.992) PKR (7871-7872, OD:4.151) NIP (7685-7886, OD:2.375) TUBING (7403-7894, OD:2.375, 10:1.995) Per( (7931-7967) ColnocoPhillips Alaska, Inc. KRU 2T-14 2T-14 API: 501032006100 Well T e: PROD An le TS: 44 d 7804 SSSV T e: LOCKED OUT Ori Com tetion: 5/4/1986 An le TD: 44 d 8262 Annular Fluid: Last W/O: Rev Reason: WAIVEF2ED WELL Reference L Ref L Date: Last U date: 5/30/2006_ Last T : 7435 TD: 8262 ftK6 _ Last Ta Date: 7/17/2003 Max Hde An le: 53 d 6500 Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 3170 2804 36.00 J-55 PROD. CASING 7.000 0 7675 5754 26.00 J-55 LINER 5.000 7445 8260 6173 18.00 L-80 Tubin Strin -TUBING Video Lo shows Leaks 7446' & 7800'; Leak 7476' not shown, 1 Size To Bottom TVD Wt Grade Thread 3.500 0 7403 5572 9.30 J-55 EUE 8RD AB-MOD _ 2.375 7403 7894 5909 4.70 EUE 8RD AB-MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7804 - 7850 5844 - 5877 C-4 46 12 10/5/1986 IPERF 60 deg. Phasing;3 3/8" Casin H erJ 7931 - 7967 5935 - 5961 A-3 36 4 10!5/1986 IPERF 60 deg. Phasing; 3 3/8" Casin H erJ Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 2782 2545 Camco KBUG GLV 1.0 BK 0.156 1258 7/11/2005 2 4993 4039 Camco KBUG OV 1.0 BK 0.250 0 7/10/2005 3 6298 4872 Camco KBUG DMY 1.0 BK 0.000 0 9/12/2001 4 6892 5239 Camco KBUG DMY 1.0 BK 0.000 0 9/12/2001 5 7237 5463 Otis LBX DMY 1.5 RM 0.000 0 9/12/2001 Production Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 7333 5526 Camco KBUG CV 1.0 BK 0.000 0 6/9/1999 Other lu s, a ui ., etc. -JEWELRY De th TVD T e Descri lion ID 1751 1736 SSSV CamcoTRDP-IA-SSA'Locked Out 12/27/95' 2.812 7277 5489 PBR Baker 3.000 7294 5500 PKR Baker'FHL' 2.750 7369 5549 NIP AVA. BPL PORTED NIPPLE 2.750 7369 5549 SLEEVE-O AVA BPC SLEEVE 2.310 7871 5893 PKR Baker'DB' 3.500 7885 5903 NIP Camco'D' Ni le NO GO 1.812 7893 5908 SOS Camco 1.995 7894 5909 TTL 1.995 General Notes Date Note 2/18/19 Tubin tall RKB elevations are 1 'pint lower than actual -30' difference; corrected 4/2/99 10/7/1998 Leak detect 11/6/95 -Leaks @ 7446, 7476 and 7800 RKB. Downhde video 11/15/95 -leak @ 7294 PKR, hde 7446 RKB, hde 7800 RKB. 4/22/2004 DRIFTED TBG TO 7411' WLM, EXCESSIVE DRAG, P/U WGT DUE TO SEVERE SCALING & POSSIBLE CORKSCREWING. 5/25/2006 WAIVERED WELL: SURFACE CASING LEAK @ 350', MINOR OR SUSPECT IA x OA ANNULAR COMMUNICATION MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE DEPT. OF NATURAL RESOURCES April 12, 1991 DIVISION OF OIL AND GAS ~' D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcur)ine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data t ! ! ? / WALTER d. HICKEL, GOVERNOR PO. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 .. .; ;.~, .3,. .." .-- ;, ',.~ i'- 'i' · ..;. b~',~ .. -. · '- [' "'fi~; ,. Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T1 IN R7E Umiat Meridian could be offered for lease. The unleased, land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, es E. Eason ector cc: J. L. Dees, ARCO Alaska Inc. REEEIVED APR 1 6 t991 Alaska.0il .& Gas Cons. Commission Anchorage paper /STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION COMMI,.%SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 52' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1206' FSL, 1300' FEL, Sec. 11, T11N, R8E, UM At effective depth 961' FSL, 1379' FEL, Sec. 11, T11N, R8E, UM At total depth 901' FSL, 1398' FEL, Sec. 11, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8262' 6173' Effective depth: measured 81 71 ' true vertical 61 0 7' Length 80' 3135' 7640' 817' measured 7804'-7850' 7931 '-7967' true vertical 5844'-5877', 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-14 9. Permit number/approval number 86-44 / 90-62(~ 10. APl number 5o-1 03-20061 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Size 1 6" 9 5/8" ,1 12 SPF 4 SPF feet Plugs (measured) feet Cement: 8171 '-8262' feet Junk (measured) feet None Cemented Measured depth True vertical depth 225 Sx CS II 1 1 5' 1040 Sx AS III & 31 70' 350 Sx Class G 200 Sx Class G&300 Sx AS I 7675' 140 SX CLASS G 8262' 60 degree phasing 60 degree phasing 5936'-5961' TVD 115' 2804' 5754' 6175' JAN Tubing (size, grade, and measured depth Gas C0.s. C. mmiss[ 3 1/2" J-55 set at 7372', 2 3/8" J-55 set from 7372'-7894' '"'~"~"~.. ,,~-- - ' Packers and SSSV (type and measured depth) Baker FHL @ 7294', Baker FB-1 @ 7871', Camco TRDP-1A-SSA @ 1751' 13. Stimulation or cement squeeze summary Attempt stimulation 8/7/90, screen out w/ 2000 lbs proppant in formation, successful frac 9/4/90 Intervals treated (measured) 7931' to 7967' Treatment description including volumes used and final pressure 485 bbls gelled water, 69 bbls diesel, 37,500 lbs 16/20 & 12/18 Carbolite~ final press. 5200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 440 250 6 1250 352 Subsequent to operation 'i"5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1160 600 100 800 357 16. Status of well classification as: Water Injector Oil .... X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,¢~'~' ~'~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atl&ntic Richfield Compan) · 'VELL 2T" t q CONTRACTOR REMARKS IPBDT ~ ._~ELL SERVICE REPORT IFIELD - DISTRICT - STATE OPERATION II~T REPORT TIME 15oo ! f,, zo 1'TZo I 2, o3z I~-Zo I~-zo Zo 2.0 ~ i I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK l Signed knotsI · RCO Alaska, In~. <) Subsidiary of Atlantic Richfield Coml~ CONTRACTOR FIELD- DISTRICT- STATE KRL,/ OPERATION AT REPORT TIME WELL SERVICE REPORT REMARKS - ,,, FR/C..T~IR.F. ",&,' 5At~> ' -- 05'00 - Pu,~P 167 · CC,' K 81107 ~r: ~ . ' .: - . '..' I-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knotl ISigned ~~ STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMi,.,~ION APPLICATION FOR SUNDRY APPROVALS 1' TYpe of Request: Abandon _ Suspend _ Operation ~hutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate .~ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: ' 6. Datum elevation (DF or KB) Development X ARCO Alaska. lng, Exploratory _ RKB 117 .feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk Riv..er Unit 4. Location of well at surface 8. Well number 52' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-14 ...... At top of productive interval 9. Permit number 1206' FSL, 1300' FEL, Sec. 11, T11N, R8E, UM 86-44 At effective depth 10, APl number 961' FSL, 1379' FEL, Sec. 11, T11N. R8E, UM 5o-103-20061 At total depth 11. Field/Pool Kuparuk River Field 901' FSL, 1398" FEL~ Sec. 11~ .T11N~ R8E~ UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8 26 2' feet Plugs (measured) true vertical 61 73' feet Cement' 8171'-8262' Effective depth: measured 81 71 ' feet Junk (measured) true vertical 61 0 7' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 225 Sx CS II 1 1 5' 1 1 5' Surface 3135' 9 5/8" 1040 Sx AS III & 31 70' 2804' Intermediate 350 Sx Class G Production 7 6 4 0' 7" 200 Sx Class G&300 Sx AS I 7 6 7 5' 5 7 5 4' Liner 8 1 7' 5" 140 SX CLASS G 8 2 6 2' 61 7 5' Perforation depth: measured 7804'-7850' 12 SPF 60 degree phasing R ECE~ VED 7931'-7967' 4 SPF 60 degree phasing true vertical 5844'-5877', 5936'-5961' TVD ~UG .). 0 Tubing (size, grade, and .measured depth '~' ~;~;:~.0JJ ~.nm 3 1/2" J-55 set at 7372', 2 3/8" J-55 set from 7372'-7894'~. &6asC0ns. Packers and SSSV (type and measured depth) ~')0[101'a~;~0 :"' ...... Baker FHL ~ 7294'., Baker FB-1 .~ 7871'~ Camco TRDP-1A-SSA @ 1751' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ Refracture stimulate A Sands with gelled water and Iow density ceramic proppant. 14. Estimated date for commencing operation 15. Status of well classification as: Auaust. 1990 Oil X Gas __ Suspended _ 16. If proposal was verbally approved ~ ...-~_ Name of approver ~)tA~ ~,~(~-~--~,{ Date approved Service ~~th.~- "~-Lgis true and, correct tO the best of my knowledge. 17. I here e foregoin Sicjned "" . ~ Tit. le Senior Operations Engineer Date us o.. , , , ,,, Conditions of approval: Notify Commission so representative may witness IApprov_aI.LNo. Plug integrity __ BOP Test Location clearance ! y ~)--- ~ ,, Mechanical Integrity Test_ --Subsequent form require 10-/-~:~z'P ..,,g~o,~eO ORIGIN AL SIGN EOB' '~;-"/ Approved by the order of the Commission I nNNIF, C,. SMITH Co , -,~-~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Application for Sundry- Well 2T-14 A Sand Refracture Treatment No BOP's are used during the fracture. The fracture treatment will be pumped through a manifold on surface. A Sand Pressure (6200' SS) = 3191 psi 7/18/87 SWHP/FL No workover fluid will be used during this process. ---' 8/1/90 Kuparuk Well 2T-14 A Sand Fracture Procedure Cost Tracking AFE #K81107 PRE-FRAC SLICKLINE . MIRU Slickline unit. Tag bottom. Pull C Sand AVA commingling sleeve at 7369' RKB and replace with blanking sleeve. Pull GLV's @ 7237', 6892', 6298', 4993', and 2782' RKB. Run DY's. Set standing valve in Camco 'D' nipple at 7979' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO. NOTE: Fill last tagged at 8019' RKB, 52' below bottom perf. 2. Obtain 24 hour A Sand well test. FRAC TREATMENT 3. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. . Carry out all fluid quality control procedures(Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water and gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. 5. Pump the 100 bbl pre-pad at 20 BPM. Shut down and determine the ISIP. . Pump fracture treatment per the attached schedule. Expected wellhead treating pressure: WHTPE = 4035 psig Fracture Gradient = 0.72 psi/ft (5939' TVD) Tubing Friction -- 300 psi/1000 ft (7866' MD) Recommended Max WHP = 6500 psi * If excessive treating pressures are experienced, reduce rate to 15 BPM, adjusting additive rates as appropriate. , Rig down frac equipment. Follow attached flowback procedure. After well has completed flowback, obtain a 24 hr well test. The well should be left on A Sand only production for about three weeks. Obtain 24 hr tests at one-week intervals. Contact Operations Engineering for a new gas lift design following evaluation of increased productivity. RECEIVED AUG 1 o lfl O Al~r~..0.ii A Gas Cons. C;0mmissio~ '~ ~chorag~ ARCO Alaska, Inc. Date: November 28, 1989 Transmittal #: 7610 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File 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. 2 X-01 Kuparuk Well Pressure Report 5 - 2 9 - 8 8 Amerada 2 H - 0 1 Kuparuk Fluid Level Report 1 I - 1 6 - 8 9 Tubing 1 Q-02 Kuparuk Fluid Level Report 1 1- 1 6- 89 Tubing 2 T- 1 4 Kuparuk Fluid Level Report I I - 1 6 - 8 9 Tubing 1 Y-25 Kuparuk Fluid Level Report I I- 1 8- 8 9 Casing Receipt Acknowledged: DISTRIBUTION: BP Chevron RECEIVED Date' Alaska 0il & Gas Cons. CommiSS[0¢ ,.. Anchorage D&M Mobil State of Alaska Unocal CC: DS Engr.--- '[-~ NSK Files .~:QP?E~grg..Files Prod. Foreman --- KUPARUK FLUID LEVEL REPORT Well Fluid Level Shot Down: 1/ SSSV GLM DV or GLV Casing Tubing CSG Press During Shot =, # TBG Press During Shot--~# Reason For Shooting FL: To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press = GL Rate (If Available)= #Alaska Oil & Gas Cons, Corn Anchora9~ MCFD On Intermittent GL On Time Off Time Min. Hr. Min. Delta Time From End Of On Cycle No GL Min. Comments: DEI'ART~iENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staf'f, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until fur.ther notice. Sincerely, ames E. Eason i rector cc: C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR I' ECEIVEI) ~XUG - ~ ltJB8 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5961 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. ~3N-9 · CEL 4-7-86 7500-9272 ~3N-8A CEL .4-7-86 5100-9272 ~2T-7 'CET/CEL 10-29-86 6200-6712 ~2T-4 CET/CEL 10-4-86 7350-8160 ~T-15 CET/CEL 10-7-86 6900-7465 ~'2T-11 TM CET/CEL 10-11-86 5965-6620 Receipt Acknowledged: DISTRIBUTION: NSK Mobil Drilling SAPC --- STATE OF ALASKA .... ALASKA ~J[L AND GAS CONSERVATION CU,~iMISSION (~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well //,' OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2./[~e/~t Op'erat°c 7. Permit Number asKa, 1nc. 3. Address 8. APl N'umber ..... P. 0. Box 100360, Anchorage. AK 99510 50- 4. Location of well at surface 9. Unit or Lease Name 52' FSL, 556' FWL, Sec. 1, T11N, RSE, bM I<~JnaY~Jl~ ~iv~ Ilnif At Top Producing Interval lO'.-~e]'l' 1~'~1~ ....... 1206' FSL, 1300' FEL, Sec. 11, T11N, R8E, bM 2T-14 At Total Depth 11. Field and Pool 901' FSL. 1398' FEL. Sec. 11. TllN: ~E, IM Kuparuk River Field 5. Elevation in feet (indicate I~S, DF, etc.~ 6. Lease Designation and Serial No. Kuparuk River 0il Po01 117' RKB I ADL 25569 ALK 2667 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. J 15. Water Depth, if offshore }16. No. of Completions 04123186 05~03/86 1]/73/~*~1 N/A feet MSL] 1 17. Total Depth ,MD+TVD, 18. P'lug Back Depth ,MD+TVD, 19.'DirectiOnal Survey I 20. Depth where SSSV set ] 21.Thickness of Permafrost 8262'FD.6173'TVD 8171'IVD.6107'TVD YES~ NO[]1781 feet MD !550'(Approx) 22. Type Electric or Other Logs Run nTI/C,q/SP/SR_~ ~C/CNL, Ca.!, CET.~ C~T 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~ ~" ~? ~ u_mn ~"~ 115' 24" 225 sx /~¢ T T ~ ~/ ~ ~.~. v ~.,~, ~,,~.~i i ~,~.l~/ ,~- J./ T /~"-r~ ,.~a ~ II~/%.~ ,~A 7" 9~ IqJ .1_~1:; S,,'~ 7~7~' 0 I lO" ~, ~ ~--, ~ 200 sx Class G & °~ ............. .~ sx,~ I ~" 19, n~ i_qn 7/l/1~' ~9~9' ~_l/Q" 1/iff ~-v el~,-,- P_ 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} 7804'-7850'~ w/12 spf, 60° phasing 3-1/2" 7894' 7325', 7871' 7931'-7967'MD w/ 4 spf, 90° phasing :~. ACID, FRACTURE, CEMENT SQUEEZE, ETC] 5844'-5877'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5934'-5960'TVD See attached Adden, lun, dated 12/13/86, for fracture dati , ,, 27. N/~ PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested pRoDUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing CaSing pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithologyl porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None CO [ , ,r, *Note: Drilled RR 5/04/86. Tubing was run & well perforated 10/05/R6. Form 10-407 Rev. 7-1-80 DAM/WC1:168 CONTINUED ON REVERSE SIDE Submit in duplicate~ GEOLOGIC MARKERS ~ i '- '' '~ ~ RMATIONTESTS : . ~. - ,-..-. . :~. ?:.'. - u- ,J:'. ~ ~': ' ' "'~ ': i ~ "'~.:~.~';. ~'," .... ' :' .' ' .,':' ~ ' ," ~." ' · ' - · · y t ' ·. '.::~ ,. -: . .' . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ToP Kuparuk C 7801' 5841' N/A Base Kuparuk C 7852' 5878' Top Kuparuk A 7888' 5904' Base Kuparuk A 8063' 6029' · :32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)//~.~,~) ~~Title Associate Engineer Date INSTRUCTIONS , ..~ :::,- . General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. . Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 5/12/86 11/22/86 11/23/86 2T-14 Arctic Pak w/300 sx AS I, followed by 49 bbls Arctic Pak. Pmp 26 bbls diesel & 5% Musol spear. Displ spear w/66 bbls diesel. Frac Stage #1: Pmp 17-3/4 bbl gelled diesel pad. Stage #2: 17.3 ppg 8# 20/40 gelled diesel. Stage #3: 66.5 bbls gelled diesel flush. - rD~iliing Supervisor .~_ ~'~- S UB-$ URFA CE ~DIRECTIONAI. SURVEY ~UIDANCE ~]ONTINUOUS [-~ OOL Company ARCO AIASKA~ INC. Well Name 2T-14 (52'FSL.~556'FWL.j SEC 1.jTllN,RSE.jUM) Field/Location [(u-~AR~. NOR~T-I SIA3PF. ALASJ(A , Job Reference No. 71749 RUBENSTEIN Date 10/4/86 Computed Ely: GCT 9!~ECT!DN~L SURVEY C US T 3", L- R LISTING ARC3 .~LASKZN, INC. KLj~ARUK N£RT'~ SL~'P: ,~L~SKA SU~V%'f gaTE: 94-C, CT-86 RU }FN ST METHZDS Z~ CC'.',~JTATZC'q TDDL L£CATZO,";: T&.,'SGEi;TiZL- AVEK&3-E3 DEViATiON AN3 ~ZIMUT'-t iNTERP3L~TZCN: VErTiCAL S~LCTZCN: dCRZZ. CiST. P~,CJECT~C O:"JT9 & TARGET ~Z_TMUT'-t gF SOUTH 25 DES Mi'i wEST CCMPUTATZCN ~T=; 14-00T-$5 PAGE ARCO ALASKA, INC. 2T-14 KUP&RUK NORTm SLGPE,AL,~SKA.~ iNTER°CLATED V~LUES FO.~ e. vEi'i 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTM 3EPT~ DEPTH 0.00 0.00 -117.00 10,3.00 100.00 -17.00 200.00 200.00 83.00 300.00 300.00 1~3.00 400.00 399,99 282.99 500.00 499.99 3~2.99 600.00 599.9~ 482.9~ 700.00 699.93 582.98 600.00 799.96 652.93 900.00 ~99.97 782.97 1000.00 999.&3 882.88 1100.00 1099.55 962.56 1200.00 1199.02 1082.02 1300.00 129B,11 1181.11 1400.00 1396.86 !279.~6 1500.00 1495.28 1378.2~ 1600.00 1592.31 i475.61 1700.00 1588.~6 1571.4~ 1800.00 1781.~8 i564.68 1900.30 1572.71 1755.71 2000.00 1950.94 ' i843.94 2100.00 2046.56 1929.6~ 2200.00 2129.42 2012.42 2300.00 2209.95 2092.95 2430.00 2287.50 2173.55 2500.00 2359.70 22~2.73 2600.00 2426.67 2309.67 2700.00 2491.~5 237~.46 2800 O0 P556 5A ~39 ~ 2900.03 2522.42 2505.42 3000,03 2689.39 2572.39 3100,00 2756,33 2539,33 3200,00 2824,32 2707,32 3300.00 2892.9~ 2775.9~ 3400.00 2961.48 264~.~8 3500.00 3329.99 2912.99 3600.00 3098.32 25~1.32 3700.00 3!66.~0 30~9.40 3300.00 3234.07 3117.07 3900.00 3301.35 31~4.55 COURSE V':RTICAL DOGLEG DEVIATION ~Zi~UTH SECTICN SEVgRiTY DEG MIN SeG ~iZN FEET DES/lO0 O. N 0 C, E 0.00 0.00 18 .,~ 27 4:~, W 0.03 0.07 21 N 24 55 ,4' -3.35 O.O0 17 N 27 ~2 W -~.70 0.27 36 N 29 58 E -1.43 0.06 29 N 24 54 W -2.3~ O.O0 21 N 20 5~ w -2.8.~ 0.04 25 N 0 1 W -3.43 ~7 N 49_~. ~z -4._=4 0.00 3.5 S 3~ 45 E -5.16 3.~0 3 40 S 24 9 vi -1.21 1.75 ~ 5 S 23 S W 6.65 0.99 6 57 S 31 ii W 16.98 2.22 8 27 S 35 55 W 30,26 1,37 9 39 S 36 25 N 45.73 1.02 10 54 S 33 46 ~ 63.10 2.i3 ..... ~ 5 15 1,~ ~ S ~, 2i W ~5.0~ . ~' 44 S o~ ~- - .... · ~ ~.~ 114.07 P.d7 22 55 S 28 a~ W 149.55 ~.20 25 2~ S 2~, 44 ~N I~1.26 3.49 29 32 S 28 ~5 W 23~,21 2,94 32 27 S 23 3 W 2~9.59 3.~1 35 34 S 26 ~4 W 3~5.63 1,80 37 lo S 25 53 ~ 404.90 2,72 41 25 S 2,5 15 W 407.93 ~.85 45 5E $ 26 35 v~ 537.10 ~.77 49 3! S 25 37 W 611.31 1.5~ 49 32 S 25 3 W 5~7.4~ 0.25 45 :~ S 25 I ~ 763,37 3,72 4~ 29 S 25 5 W ~38.64 O.,3C ~7 5c S 25 12 ~., 913.18 0.2~, 47 31 S 25 22 W '957.19 0.27 45 ~0 S 25 17 W 10.60.51 3,97 ~6 *6 3 2~ ~9 '4 1133.25 0.45 46 ~1 o 2'3 55 ~ 1206.06 3.73 46 ~7 % 2~ 23 W 127e.89 0.41 ~7 O S 23 0 W 1351.87 0.20 .., a2 5J ~-i l~p=.~.OA~ 0.79 47. '27 $ P~ 25 W i~98.62 0.63 47 ~3 S 22 ~ N 1572.34 3.30 ,~4E ~SURED R E CT A NS NORTd/S FZET 3.0 0.2 0.2 0.7 1.4 2.3 3.0 3.7 ~.5 4.9 1.2 5.9 15.2 26.3 39.0 53.4 97.9 129,i iC5.7 -'nAT= O=, SURV=Y: 04-007-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: RU~_ENST~IN 3EPTH ULAR CCORDIN.ATES HSRIZ. DEPARTUR5 OUTH EAST/WEST DIST. AZIMUTm F~ET FEET OEG MIN 0,00 E 0,00 N J 0 0,54 E 0,61 S 61 58 0,28 E 0,38 N z*7 52 E 0,01 .= 0,77 N O 59 E 0.32 E' t,46 N 12 31 E 0,57 E 2,43 N 13 39 E 0,27 ~ 3,07 N 5 7 0,16 E 3,72 N 2 29 0.59 E 4.55 N 7 27 1.56 E 5.21 N 17 23 E 0,25 E 1,24 N 11 39 E. 2,90 W 6,55 S 25 49 7,58 W 15,98 S 26 29 W 15.12 w 30.35 S 29 51 24.51 W 45.08 S 32 8 34.78 W 63.72 S 33 4 45.96 W 85.71 S 32 25 W 59.7P, w 114.76 S 31 23 76.93 W 150.31 S 30 46 97.01 W 192.07 S 3'3 20 W 207.01 252.25 332.06 355.21 411.92 473.80 5~0.35 60~.22 577,95 746.14 ~13, 3:30. 94 6. lu12. 1078. llZ. 5. 1212. 12~0. 13~8. 14lin. 61 53 77 65 99 72 30 24 54 119.67 W 23~.11 S 30 1 w 144.21 W 290.55 S 29 ~5 %~ 170.00 W 346.61 'S 29 22 W 195.24 W 405.81 S 28 55 W 223.$9 W 46~.83 S 28 31 W 254.74 W 537.94 S 2:5 1: N -°87.61 W 612.1~. S 2~ I ~ 320,15 W 68~.12 S 27 43 352.33 W 764.04 S 27 27 . 384.15 W 83~.24 S 27 1~ w ~i5.63 W 913.74 S 27 4 w 447.49 w 957.71 S 2~ 55 W ~7~.94 ~ 1061.02 S 26 50 H 50~.75 W 1133.72 S 26 43 '~ 53:3.78 W 1206.48 S 25 34 N 569.02 W 1279.24 S 25 24 N 597.76 ~ 1352.15 S 26 14 ~ 626.29 w 1425.27 S 26 4 W 654.66 W I~98.75 S 25 53 N 6~2.64 W 1572.44 S 25 43 ,4 C~"!PdT~T':-~ , .~ D~TE: 14-r'CT-56_ P,6,3E ARCO ALASKA, ibC. 2T-14 KUPARUK NJRTH SL~.PE,ALASK& ZNTEROCL,~TED VALUES FOR ~VEN 100 FEET OF TRUE SU~-SEA M~ASbRED VERT!C~L VERTICAL DEPTH DEPTH DEPTH 4000.00 336'9.00 4100.00 3436.22 4200.00 3503.30 4300.00 3570.85 ~400.OO 3638.79 4500.00 3707.17 4600.00 3775.8'9 4700.00 3844.14 4~00.00 3~I!.40 4900.0,3 3977. ~6 5000.00 4043.23 5100.00 410~.~7 5200.03 4173.15 5300.00 4237.55 5400.00 4301.51 5~00.00 4365.24 5600.00 4~25.91 5700.00 4492.59 5800.00 4556.24 5900.00 4519.73 6000.00 6100.00 ~7~6.32 6200.00 4509.57 6300.00 4872.39 6400.00 4~34.15 6500.00 4993.S5 6600.00 5055.56 6700.00 5117.38 6800.C0 5179.~5 6900 OO · ~.~7 7000.00 5307.3~ 7100.00 3372.~8 7200.00 3437..53 7300,00 5502.83 7400.J0 5568.62 7500.00 5534.9~ 7500.00 5702.1~ 7700.00 5770.16 7800.00 5840.55 79~0.00 5912.18 CL]UFS$,.. V~RTI~'AL,~ D~'~GLEG_ DEVIATION AZIMUTr~ SECTICN SEVERITY D:G MIN D~G ~qlN ~EET 3E,S/IO0 3252,00 3319.22 3386,30 3453,85 3521,79 3590,17 3658.89 3727.14 3794.40 3860,3.6 47 34 S 22 21 W !545.06 1.0'5 47 57 S 24 39 W 1720.07 1.06 47 41 S 25 27 W 1794.23 0.81 47 21 S 25 5n W 1~67 96 O o: 47 2 S 25 56 W 1941.33 0.30 46 41 S 25 57 w 2014.29 0.12 46 31 S 25 5~ W 20~6.92 0.12 47 31 S 26 o W 2150.00 1.11 47 46 ~q 26 11 W .P2~_,.~. 99 O · O1 4~ 58 S 26 23 W 2308.65 1.03 3926.23 3991.37 4056.15 4120.55 4184.51 4248.24 4311.91 4375.5'~ ~439.2~ 4502.70 49 17 S 26 33 u 23.34.34 0.31 49 27 S 26 27 W 2460.18 0.50 49 46 S 25 39 W 2536.3~ 0.29 50 5 S 26 25 W 2612.82 0.62 5~ 21 $ 26 22 W 2689.66 0.30 50 26 S 26 29 W 2766.71 0.20 50 27 ~ ~ ~4~ 79 0 i7 ~ ~6 ~3 ~ ~ .... 5C 28 S 25 51 ~ 2920,86 0,22 50 2~ S 26 51 W 2997,94 0.85 50 ~8 S 26 27 W 3075,20 0,51 45~6.0S ~629.32 4592.57 47p5.35 ~617.15 .878.05 493~.55 5062.'95 512o.37 50 45 S 25 ~4 ;~ 3i52.&0 0.51 50 43 S 25 2 W 3230.00 0.55 50 ~7 q 24 ;2 W 3~07.a5 J.5~ 51 27 S 23 50 W 3385.24 0.7~ 52 14 S 23 2'~ ,~ 3~o3,~7 0,5~ iZ 3~. S 23 19 W 3~3.15 $.29 52 36 $ 23 5 N 3622.72 1.86 51 21 S 22 22 N 3701.25 0.55 5i 9 5 21 ~5 ,'! 37F9.16 50 4 S 20 45 W 3~56.30 1.17 51)C "~ 5320.63 5355.~5 545i.~2 55i7.95 55~5.14 5653.16 5723.55 ~795.1~ 4= ~0 S i-5 34 N 39~2.~7 0.98 49 31 _~ 1S 46 w ~'=Oe,. ~.18 0.6x.. 49 30 S 15 2 $~ ~053.71 0.7~ ~ 2 S 17 15 W 4158.8~ 2. ~4 ag 43 3 16 31 ,~ 4233.4~ 0.70 4S 10 $ 15 7 ~ 4307.37 0.11 ~6 35 S i5 25 W 445'2.~2 2.69 *~ 7 S 19 2S ',~ ~523.17 1.46 4. if S 1'~ 6 ~ ~592.62 0.72 ME&SURE RECT,~N NC RIM/ FEE 1~84 . 1552. 1620 · 1686. 17522. 1~i8. 1,~83. 1949. 2015. 2052. ATE CF SURVEY: 04-~CT-86 ELLY BUS~IN$ ELEVATION: 117.00 FT ENGINEER: RUBENSTEIN D DEPTH GUL~R COS~OINAT~S H~RIZ. DEOARTURE SOUTH EAST/mEST DIST. AZIMUTh - T FEET FEET DEG MIN 92 S 710.47 ~ 164,5.13 S 25 34 W 82 S 739.95 ~ 1720.11 S 25 28 ~ O0 S 77~.3~ W 179~.Z7 S 25 27 W 44 S 803.35 W 1865.01 S 25 28 W 44 % 335.40 W 1941.38 S 25 29 'N 05 S 867.33 W 2314.35 S 25 30 W 36 S 899.15 W 2095.99 S 25 31 W 02 S 931.24 W 2150.07 S 25 32 , 45 S 963.~5 ~ 2234.07 S 25 33 ~ 44 S 996.94 W 2303.77 S 25 34 W 2150.14 S 1030.77 ,N 2384.44 S 25 36 W 221.5.05 S i06~.58 W 2460.31 S 25 38 ~ 22~6.18 i 1098.69 W 2536.4B S 25 ~0 N 2354.62 S 1132.87 W 2612.98 S 25 41 W 2423.47 S 116,7.05 W 2689.83 S 25 42 ~ 2492.49 S 1201.33 W 2766.90 S 25 43 w 2561.43 S 1235.87 W 2844.00 S 25 45 W 2630.26 $ 1270.63 W 2921.09 S 25 47 W 269W.05 S 1305.50 W 299a.20 S 25 48 W 2763.11 S 1340.20 W 3075.48 S 25 50 ~ 2~7~_ ,62 q_ 1~74~ .~5 W 315~.. 88 S 25 50 W 2907.54 S 1~07,47 W 3230,29 S 25 49 N 2977,'91 S 1439,83 m 3307,73 S 25 45 W 3048,93 S I~71,60 W 33B5,50 S 25 45 N 3121.01 S 15C3.07 ¼ 3464.09 S 25 42 , 3193.82 S 1534.52 W 3543.3~ S 25 39 W 32~6.97 S 1~65.9~ N 3622.88 S 25 36 W 3339.47 S 1595.30 W 3701.38 S 25 32 ~ 3411.76 $ lO25.63 N 3779.26 S 25 28 ~ 3483.81 S 1653.66 w 3~56.36 $ 25 23 W 3555. 3627. 369~. 3771. 3B43. 3915. 3~36. 4057. 4125. 4191. 55 S 1650.05 W 3932.50 S 23 17 w ~7 S 1704.99 w ~003.18 S 25 10 w 62 5 1729.00 W 4083.71 S 25 2 N 86 S 1752.00 W 4155.90 S 24 54 W 93 S 1773.90 W ~233.50 S 24 46 W 73 S 1794.88 N 4307.50 S 24 37 W 95 S i515.2~ W a3bO,7~ 5 24 2~ w 51 S 1334.55 ~ 4453.13 S 24 19 W 32 S 1556.12 ~ 4523.55 S 24 13 ~ 13 S 1879.36 ~ 45~3.20 S 2~ 9 W ARCO ALASKA~ INC. 2T-14 KUPARU~ NORTH SLOPE,ALASkA C S ,",l PO T A T. ~ n._ N D~TE: i4-0CT-85 INTERPOLATED VALUES FOR EVeN I00 FEET OF TRUE SuB-SEA MEASURED VERTICAL VERTICAL DEPTH SEPTM D~2PTH CCURS~ VERTICAL D3GLEG DEVIATION AZ-~UTm SECTION SEVERITY DEG MIN DEG ~Ii'~ FE~T DES/lO0 44 13 S 17 37 ~ 4661.98 1.10 43 28 S 15 39 W 4730,61 io05 43 31 S 16 40 W ~7'9~.72 43 31 ~ 16 ~8 ~ 46~0.95 8000.00 5983.76 5856.76 8100.00 6055.8~ 5935.$~ 8200,00 612~.37 6011.37 8262.00 6173.33 6055.33 PAGE 2. ATE DF SURVEY: 04-~CT-86 KELLY 3USMi,'~O ELEVATION: 117.00 ENGINEER: RUE~ENSTEtN RECTANGULAR CCOR3iNATES HORiZ. DEPARTURE NO~Tm/SCUTH EAST/WEST CZST. AZIMUTH FEET FEET FEET DEG MIN 4257.39 S 1901.40 W 4662,69 S 24 3 W 4323,65 S 1921.72 W 4731,48 S 23 57 W 4389.60 S 1941,48 W 4799.79 S Z3 51 W 443~,E0 S 1~53.7B W 4842.15 $ 2] 47 ~.~ FT CC. MFdT~T!CN U.aTE~ i~-OCT-8~ ARC3 ALASKA~ INC. 2T-14 KUP~UK NORTH SLOPE,ALA~K.~ INTSROSLATE~ V~LUES F3~ 'VSN 1000 F=ST OF TRUe SUa-SE~ MEASURED VERTICAL VERTICAL DEPTH DEPTH D~PTH 0.00 0.00 -117.00 1000.00 999.8B 882. ~J8 2000.00 1960.94 18,~3.94 3000.00 2689.05 2572.09 4000.00 3369.00 3252.00 5000.00 4043.23 3526.23 6000.00 ~683.00 7000.00 5307.,53 5190.83 8000.0'3 3983.76 5866.76 8262.00 6173.33 6056.33 DATE OF SURVEY: 04-OCT-86 K:LLY BU~HiNG~ EL=VATION:. 117.00 PI E,NGINE~R: RUEENSTEIN MEASijR'-- CCURS~ VErTiCAL DJGL:G RECTANG DEVIATiJN A,-_'ii,~UT~I SECTION S~V~JRiTY NGRTH/S D~-G MiN 3~-G~. MiN FE~T DEG/IO0 ~-F-~T, ,.~. D DEPT 0 0 N 0 0 '-'- 0.00 0.00 3 ~+0 S 24 9 J -!.21 i.76 ~9 3.~. ~q ~":l ~5 W ~3~.21 ~ 94 ~7 ~5 S 25 i2 ,~ 913.18 49 17 S 2~ 33 W 2384.34 ~.31 50 ~5 S 25 ~4 W 3152.50 0.51 49 40 $ 1~ 34 ',~ 3932.47 0.98 44 13 S 17 37 ~ 4651.98 1.10 ~3 31 S 1~ 40 W ~340.96 0.00 ULAR COORDINATES HORIZ. DEPARTURE OdTH EaST/wEST DIST. AZIMUTH FEST ~ET DEG MIN 0.00 1.22 207.01 313.61 14~4.9~ 2150.14 2337.62 3555.35 4257.39 4430.50 N 0.00 E 0.00 N 0 0 a N 0.25 E 1.24 N ii 3')E S 119.67 ~ 239.11 S 30 1 ,~ S ~13.35 W 913.74 S 27 , N S 710.47 w 1645.13 S 25 34 w S 1030.77 W 2384.~4 S 25 36 W S 137~.25 W 3152.88 S 25 50 S 1680.05 w 3932.50 S 25 17 · S 1901.40 W 4562.69 S 2~ 3 W S 1953.73 W 4842.15 S 23 4'7 W CGMPUTAT£i':)N DAT": L4-CCT-8~ P~,SE ~%RC3 ALASKA, INC. 2T-14 KUPARUK NORTri SLOPE,ALASKA INTERPOLATED V~LUES FOR EVSN 100 FEET OF TRUE SUB-SEA MEASUREJ VERTICAL 'VERTICAL DEPTH D:PTH_ DcPTh_ COURS= VERTICAL DJGL~' DEVIATI3N AZIMUTH SSCTICN S~VERiTY OEG MIN ~SG MiN F~T OEG/IOO C.O0 0.00 -i17.00 17.00 17.00 -100.00 117.00 117.J0 O.OO 217.00 217.00 t00.00 317.00 317.00 200.00 417.01 417.~0 300.00 517.01 5!7.00 617.02 617.00 500.00 717.02 717.00 600.00 ~17.02 817.00 700.00 917.03 917.00 800.00 1017.17 1017.00 ~00.00 1117.51 1117.00 1000.00 1218.12 1217.00 I100.00 1319.11 1317.00 1200.00 1420.44 1~17.00 l~O0.O0 1522.14 1517.00 1400.00 1625.10 1617.00 1500.00 1730.27 1717.00 1~38.34 1817.00 1700.00 1 6 S 3 17 3 59 S 24 21 5 19 S 23 ~5 7 15 S 32 23 8 44 S 36 27 9 50 S 36 16 Ii 33 ~ ~ 26 16 0 S 23 10 19 50 S 2~ 48 2~ 23 S 2'3 ~2 1949.83 1917.S0 i800.00 2065.02 2017.00 1900.00 2184.77 2117.$0 200~.0S 2308.84 2217.00 2439.90 2317.00 Z2~0.00 2585.22 2417.C0 2300.00 2739.31 2517.00 2891.63 2617.00 2500.00 30~1.61 2717.00 2~C0.~0 3189.31 2817.S0 2700.00 ~ 4 S 28 7.5 15 S 26 55 37 2= ) 25 50 ~3 15 ~ 25 27 49 i2 ~ 25 51 ~9 £~ S 25 5 / ~7 ~6 S 25 15 3335.12 2917.30 2~0,3.0~ 3481.02 3017.00 2~00.00 3627.41 3117.00 3006.00 3774.76 3217.}0 3100.00 3922.93 3317.00 3200.00 ,071.34 3417.00 3300.00 4220.3* 3517.00 3~O0.OJ 4367.9~ 3517.00 3500.~ 4514.33 3717.30 3600.0-3 4~60.00 3817.00 3700.C0 ~0 ~7 S £~ 29 47 £ S 22 57 ~7 35 $ 22 5 ~7 52 ~ 24 2 47 55 ~ 25 ~5 47 9 S 25 5g 45 3~ S 2~ 5~ 0.00 0.00 0.II 2.ii -0.03 0.10 -0.42 0.00 -O. 75 i .20 -1.61 0.00 -2.4~ -2.95 0.33 -3.55 O.OO -~.55 6.15 -4.96 4.42 -0.06 1.9,3 ~.24 1.75 '~ 21 ~ 60 33.06 1.71 ~9.13 0.B6 57.37 ~!.63 ~.43 16~· 91 214.04 2.9~ 27!.0~ 2.64 336.$3 2.2~ 53'2.13 2.40 717.36 13.45 {32.~2 ~.'~3 5~4.03 0.62 1052.73 1.27 115:~.84 0.77 1265.06 0.41 1371.91 3.11 1~0.25 :3.77 i5~9.25 J.i7 !5~.80 1.99 180~.27 C.70 19i7.{~ 0.29 202~.71 0.27 -130.61 1.413 DAT= OF SURVEY: C4-3CT-86 KILLY BUSHING ELeVATiON: 117.00 Fi ENGINEER: RUBENSTEIN SU!,-SEA OZOTm ~TANGUL~R r,~ D~PARTURE ~oORDiN&T~S HDRI~. NORTH/SOUTH ~A.ST/WEST DIST. AZIMUTH - FEET FEET F~ET DEG MIN 0.00 N 0.00 ~ 0.00 N 0 0 f 3.20 S 0.15 f 0.24 S 37 0 E 0.20 S 0.50 E 0.54 S 57 51 f 0.35 N 0.24 E 0.43 N 34 lC E 0.84 N 0.01 W 0.84 N 0 42 ~ 1.~c~ N 0 .41 P.. 1 .. 63 N 14 22 E 2.50 N 0.52 E 2.55 N 11 40 3.16. N 3.24 :: 3.17 N 4 19 ~. 3.64 N 0.15 : 3.04 N 2 25 c 4.65 N O · 77 E 4.72 N 9 22 ~ 4.74 0.17 7.44 17.11 2~.64 41.61 57.01 78.23 105.80 I~2.62 1.58 E 5.00 hi 18 25 E 0.22 W 0.28 N 53 7 W 3.53 W 3.24 S 25 22 N ~.76 W 19.22 S 27 7 N 16.80 W 33.20 S 30 24 W 26.56 W 49.53 S 32 25 W 37.13 w 6,8.03 S 33 4 ~ 49.13 W 92.3~ S 32 7 W 64.62 W 124.83 S 31 i0 W 64.33 W~ 165.68 S 30 35 W 165.78 S 108.01 w 214.90 S 30 lO N 235.51 S 135.45 ~ 272.03 S 29 51 W 294.23 S 156.02 ~ 337.81 S 2'9 25 W 360.C1 S 19:~.5~ W 411.14 S 28 52 W 435.99 S 235.81 W 495.57 S 20 24 W 530.30 S 282.72 W 500.96 S 28 3 ~ 536.28 S 332.6~ W 71~.07 S 27 36 ', 740.61 S 381.59 W $33.13 S 27 15 341.52 S ~29.03 W '~44.57 S 27 0 w 939.73 S ~75.61 W 1053.24 S Z6 50 w 1035.91 S 520.44 W 115'9.30 S 25 40 W 1133.03 S 363.51 W 1253.43 S 26 26 N 1231.31 S 605.60 w 1372.17 S £~ 11 ~ 1331.06 S 647.56 W 14~0.22 S 25 56 W 1432.23 S 6~9.$1 W 1589.34 S 25 41 W 1533.43 S 7~1_, ._22 W 1698.05 ~< 2~ 29 ~ 1~33.57 S 777.B5 W 1~09.31 S 25 27 N 1731.36 S 825.15 N 1917.94 S 25 28 w 1027.a? S ~7!.90 W 2024.77 S 25 30 w 1922.63 S 918.32 k 2130.68 ~ 25 31 ~ CCMPUT.&T!ON D~T:: 14-$CT-SS PAGE ARCS ALASKA, INCo 2T-14 NORTH SLOPE,ALASKA TRUE MEASUR;D VERTICAL DEPTH DEPT~ 4808.36 3917.00 4959.80 4017.00 3113.27 4117.00 5268.02 4217.00 542~.2~ 4317.00 5581.29 4417.00 5738.37 4517.00 5895.75 4617.00 6053.70 4717.00 5211.75 4517.00 6372.06 4917.00 653,5.24 5017.00 6699.39 3117.00 6858.73 5217.0C 7014.15 5317.00 7168.23 5417.00 7321.57 5517.00 7473.01 5617.00 7,621.93 5717.00 7767.03 5817.00 7906.74 5917.00 80~6.2B 6017.00 8184.32 6117.00 8'262.00 6173.33 SUD-SEA COURS= VERTIC&L D~VI~TISN ~ZI*,~UTH DEPTH DEG MiN 3800.00 47 49 S 25 il N 3900.00 49 14 S 2,5 37 ~ gO00.O0 49 2'9 S 2~ 29 ,4 4100.00 49 56 .S 20 29 W ~2OO.O0 50 25 S 25 z2 w 4300.00 50 27 S 25 40 w 4400.00 50 28 3 26 53 ~, 4300.00 50 38 S 26 ZO w 460o~.00 50 42 S _~,~= .73 N 41¢00.00 5~ 3 '~ Po .... 4900.00 52 49 S 23 18 ,~ 5000.00 51 21 S 22 22 W 5100.00 50 32 S 21 9 W 5200.00 49 37 S 19 25 w 5300.00 4~ 31 S 18 16 W :400.00 4B ,,~4 ~ 17 = W 5500.0C 4~ i9 S 16 I0 W 5~0.00 47 16 5 15 37 ~ ~70C.O~ 4~ 37 5 18 22 W 5'~,Oa.O'* ~ ~7 S 19 ~ 5900.00 43 53 S 17 i w ~056.33 43 31 :5 16 ~O X 100 FE=T OF V%RTICAL SECT'iON FEET 2240. ,:353 · 2470. 2555. 2~£9. 2:~50. 30 'l I. 3194. 3~i6. J441. 3571. 5700. 3 ~ 24. 39 ~ 5 · ~059. %175. %~7 45,00. 45~7. ~593. 47{!. 19 36 ~7 17 97 63 19 72 O1 48, 44 26 ~0 O~ 96 DATE OF SU~'VEY: O~-OCT-96 K~LLY BUSHING ELfVATiON: 117.00 FT' ENGINEER: RUBENSTEIN SUB-SEA DEPTH DOGLEG RECTANGULAR COORD!NATmS HORIZ. DmPARTURE SEV=,RiTY NORTh/SOUTH EAST/W~ST DIST. AZIMUTH . gE~/lO0o ...... ;~FT FEET ;=~T DEG MiN 0.27 0.25 0.65 0.33 0.01 0.12 0 =C 0.55 0.63 0 · .~; 3 0.75 ~,.56 1.72 0.90 0.65 0.97 0.88 0.65 4.7~ 3.77 1.33 0.00 S.O0 2021.01 S 966.60 2122.90 S 1017.14 2227.02 S 1069.05 2332.69 S 1121.95 2440.22 S :1175.36 254,~.~:, ~' S 1~29.39~ 2656.66 S 128~.01 2765.17 S 1338.73 2~75.13 S 1392.19 29~6.20 S 1443.59 2240.27 2353.99 2470.38 270. B.54 2629.57 2950.68 3072.19 319~.46 331,5.83 S 25 33 w S 25 36 W S 25 33 w S 25 41 W S 25 43 N S 23 45 W S 25 47 S 25 30 S 25 50 ,,~ S 25 47 '~4 3100.76 S 1494.30 3220.30 S 1545.93 3339.03 S 1596.12 3454.16 S 1642.31 3565.72 $ 1~83.64 3676.66 $ 1721.48 3787.41 5 1756.82 389.5.39 S 1789.2~ 4002.~,~ S 161'9.54 4103.52 $ 184~.65 3442.05 S 25 43 w 3572.15 S 25 38 W 3700.91 S 25 32 N 3324.71 S 25 25 W 3943.22 S 25 16 'd ~059.72 S 25 5 w ~175.03 $ ~4 53 W 4287.58 S 24 39 W 4395.59 S 2~ 26 W ~300.71 S 24 15 W 4195.57 S 1880.90 W 42,~8.13 S 1910.99 W 4379.25 S 1:)3,8.38 w 4430.50 S 1'953.73 W 4597.:39 S 24 8 W 4.594.57 S 24 1 W 4789.08 S 23 5~ ,,~ 4~42.15 S 23 47 W ARCD AL~SKA~ iNC. 2T-14 KUPARUK. NJRTM DLOPE~&L~SKA TOP B6SE TOP S~SE PETD TD MARKER KUP~RUK C KUPARUK C KUPARUK A KdPARUK A ME,~SGLED DEPTH SELOW K: 7801.00 7352.00 ~0~3.00 8171.00 8262.0C $OR C,HDSFN 1~-CCT-86 HORZZONS JR!GIN= TVD 584!.25 5877.~3 5903.50 6029.07 5107.34 5173.33 5Z' FSL, SU~-SEA 5724.2~ 57_~6.50 5912.07 5990.34 c, 05~.33 PAGE DATE DF SURVEY: 04-:3CT-88 KELLY BUSHING ELEVATIJN: 117.30 ENGINEER: RUBENSTEIN SURFACE LOCATZDN AT 556' FWL, SEC !, TllN, ROE, dM RECTANGULAR COORDINATES NDRTH/SOUTH EAST/WEST 4125.98 S 1856.35 ~159.49 S 1868.25 4133.21 S 187,5.59 ~299.20 S 1914.3.5 4370.47 S 1935.75 4430.50 S 1953,73 ARCO ALASKA, iNC. ZT-14 KUP~,RJK NORTH SLOPE,ALASKA TOP BASE TCP BASE PBTD TD MARKER KUPARUK C KUP&RUK C KdP&RUK A M£ASUR~D 5~- L3W KF-j 7301 7,35Z.00 7 ;3 83 · 00 3171.00 8 >'~2. on S U M M A R Y ORIGIN= T v' C PROM KS 5~!.28 5877.~3 5903.50 6029.07 6107.34 6173.33 DATE C; SURVEY: O~-DCT-BO KELLY BUSHING ELEV4TIDN: ENGiNUER,_ .' RUBENSTE'r,-, N .5'~',_ ,F-SL, SUB-SEA 556 ' SORFA FWL~ SEC i, RECT4NGU N3RTH/S 117.00 572e.28 5760.23 E7~6.60 5~12.07 5990.34 6056.33 4125.9 4159.~ 4183.2 4299.2 4370.4 ~430.5 CE LOCATION 4T TI1N, RSE, UM LAR COORDINATES OUTM E4ST/WEST 1855.35 N 1868.25 N 1876.59 ~i 1'914.36 '~ 1935.75 H 1953.73 '~ FIN&L MEASURED D ~ P T;,-t NELL LOCATiGN 4T TD: TRUE Su8-SEA VERTICAL VERTiC4L 3EgTn DEPTH MJRIZJNTSL D~iPARTURE DiST4NCE ~ZIF~UTM FEET DEG MIN 8262.00 6173.33 6056.33 ~$.2.15 S 23 ~7 W SCHLUMBEROER D ~[ RECT 1' ONAL SURVEY COMPANY ARCO ALASKA INC NELL 2T- 1 4 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 04 - OCT - 86 REFERENCE 00007 ] 749 WELL' 2T-14 (52~'FSL,556'FWL, SEC 1,TllN,R8E,UM) HORIZONTAL PROJECTION NORTH 1000 -ID00 REF 000071743 SCALE = 1/1000 IN/FT -ZOO0 -BO00 -4000 -SO00 SOUTH -6000 -4000 WEST -3000 -2000 - 1000 0 1000 2000 3000 4000 EAST 25. WELL: 2T-14 (52:FSL,556'FWL, SEC 1,TllN,R8E,UM) VERTICAL PROJECTION -ZOO0 -lOOO 0 0 ]000 2000 3000 4000 5000 6000 205. II (D (::3 PROJECTION ON VERTICAL PLANE 20S. - 2S. SCALED IN VE~T!CAL DEPTHS HORIZ SCALE = !/lO00 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: / ~- ~--~g ~ DA~e Required Date Received Remarks , Completion Report ...... ~-~ ,.,l~.-a~--~ .. .... ~-,~ -~ ., Samples ,.. ~- ~,I - .. Mud Log ~/~~/ ~ .~ . ..... ~ ,. ~f .... Core Description ~egistered Survey Plat ' , inclination.,. Survey , Directional Survey Dr~ll Stem Test Reports ..... ~roduct~on Iest Reports'~~ ~ ~~/ ' ' '- Ok. ,. -- STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COlt SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [] Complete 2. Name of Operator ARCO Alaska; Inc, 3. Address P.0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 52'--FSL, 556' FWL, Sec.1, T11N, R8E, UM At top of productive interval 1206'FSL, 1300'FEL, Sec.11, T11N, R8E, UN At effective depth 962'FSL, 1380'FEL, Seco11, T11N, R8E, UH 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-14 8. Approval number 136 9. APl nUl~l~e..r20061 50-- 10, Pool r, uparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3168' Production 7645' Liner 817' 8262'MD 6173'TVD 8171 'MD 61 07 ' TVD Size 1 6" 9-5/8" 7 1' 5" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 225 sx CS I I 115'MD 1040 sx AS II! & 3170'MD 350 sx Class G 200 sx C1 ass G 7675 'MD 140 sx Class G & 7445'-8262'MD 300 sx AS I ~ue Verticaldepth 115'TVD 2804'TVD 5753'TVD 5599'-6173'T% Perforation depth: measured true vertical T804' - 7850 'MD - RECEIVED 5844' - 5877'TVD 5934, - 596o,Tv OCT 29 ]986 Tubing (size, grade and measured depth) 3 - 1 / 2", J - 55 , t b g w / t a i 1 ~ 7894' Rla~ Oil & Gas Cons. C~nmi~lon Packers and SSSV (type and measured depth) Ailchora~e FHL pkr @ 7325', DB pkr (~ 7871' & TRDP-1A-SSA SSSV ~ 1781' 12. Stimulation or cement squeeze summary ~,.. ~ ~ ;~ ? '~. ~- ' In~e/r0als treated (measured) Treatment description including volumes used and final pressure 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 w/Addendum, dated 6/09/86. Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~; Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form '10-404 Rev. 12-1-85 ~/ Date Submit in Duplicate ( I'~AM % gwn/11n ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I parish or borough. Alaska iC°unty' North Slope Borough Field ILease or Unit Kuparuk River ADL 25569 Auth. or W.O, no. ~Title AFE AK0812 I Completion IState Alaska JWell no. 2T-14 Nordic 1 API 50-103-20061 Operator ARCO Alaska, Inc. ARCO W.I. IPror status if a W.O, Spudded or W.O. begun IDate IHour Complete 10/1/86 Date and depth as of 8:00 a.m, 10/02/86 10/03/86 Complete record for each day reported 5" @ 8262'/7" @ 7675' 6051', RIH w/bit & scrpr 12.1 ppg Gel Mud Accept rig @ 0100 hrs, 10/1/86. & build new surf sys. & scrpr. 0100 hrs. ND tree, NU & tst BOPE. Wt up RIH, displ diesel cap. RIH w/6-1/8" bit 5" @ 8262'/7" @ 7675' 7489', CBU 12.1 ppg Gel Mud Tst BOPE. TIH to 7151', circ out gas. Drl cmt stringers to 7210', DO cmt to 7438', CBU, tst lnr lap to 1000 psi; OK, POOH. TIH w/3-1/4" BHA to 7438', drl 6' cmt & wsh dn to 7489', circ. 56.24% The above is correct Date -- I Title For form preparation 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" shoutd 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" Iorm may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit Kuparuk River ADL 25569 Auth, or W.O. no. Title AFE AK0812 Completion Nordic 1 API 50-103-20061 Well no. 2T-14 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete A.R.Co. W.I. 56.24% Date 10/1/86 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0100 hrs. Date and depth as of 8:00 a.m. 10/04/86 thru 10/06/86 Complete record for each day reported 5" @ 8262'/7" @ 7675' 8163', RR 11.8 ppg NaC1 Wsh & circ to 8087', tag cmt. Drl cmt f/8087'-8163', tag LC. Circ, tst csg to 1000 psi, CBU. Displ 12.1 ppg w/wtr, rev circ. Displ wtr w/ll.9 ppg NaC1, POOH, LD 31 jts DP. RU Schl, rn CET. RU & perf f/7850'-7824' @ 12 SPF, 7804'-7824' @ 6 SPF (twice) & 7931'-7967' @ 4 SPF. RIM w/retry pkr, set @ 7870'. RD Schl. RU & rn compl assy. Lnd tbg & set pkr. ND BOPE, NU & tst tree. Tst pack-off to 250/5000 psi. Displ well w/diesel. RR @ 1900 hrs, 10/5/86. (SSSV @ 1781', FHL Pkr @ 7325', DB Pkr @ 7871', TT @ 7894') Old TD New TD PB Depth 8163 ' PBTD Released rig Date Kind of rig 1900 hrs. 10/5/86 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) 0il ISingle Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day !T.P. C.P. Water % GOR Gravity Allowable Pump size, SPM X length Choke size Effective date corrected The a,~,~ is correct Sign "'" For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ]Title Drilling Supervisor ADDENDUM WELL: 2T-14 Arctic Pak w/300 sx AS I, followed by 49 bbls Arctic Pak. Drilling Supervisor Date ARCO Alasl(a. Inc. Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 05-27-86 TRANSMITTAL # 5676 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus Listing: Schl: One copy of each ---~-3N-16 -----3N-15 '--2T-14 ------2T-13 05-18-86 Run #1 1'990,5-9269.0 05-10-86-' Run #1 2186.5-8523.0 05-03-86 Run #1 7600.0-8215.5 05-11-86 Run #1 1491.0-7878.0 Open '~ Nasi~ 011 & 6as Cons. Commission Anchorage Receipt Acknowledged: %stat~ ~'~Of 'Alaska*'~ ~'~ ' ARCO Allll[l. Inc. Il · Subsidiary of AlllnhcRichf,eldCompl,~, Date: STATE OF ALASKA -- ALASk.. OIL AND GAS CONSERVATION COMk...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well ,%£ Alter casing Time extension © Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ,~ Amend order i7 Perforate i; Other 2. Name of Operator 5. ARCO Alaska, Inc. 11 3. Address 6. p. O. Box 100~60 Anr. hor~. _ AK qqr~l 15 K'J 4. Location of well at surface 7. 52'FSL, 556'FWL, Sec.1, T11N, ESE, UN 2T At top of productive interval 8. 1409'FSL, 1279'FEL, Sec.11, T11N, ESE, UM (approx.) 86 At effective depth 9. 910'FSL, 1367'FEL, Sec.11, T11N, RSE, UM (approx.) At total depth 844'FSL, 1385'FEL, Sec.11, T11N, ESE, UM (approx.) 11. Present well condition summary Total depth: measured 8262 true vertical 6132 Datum elevation (DF or KB) 7 ' RKB feet Unit or Property name n4r,,b I~v~r Iin-li- Well number Permit number APl number 50---103- 20061 10. Pool Kuparuk River 0ii Pool feet Plugs (measured) None feet Effective depth: measured true vertical 81 71 6071 Casing Length Conductor 80' Size 1 6" Surface 3168' 9-5/8" Production 7645' 7" Liner 817' 5" feet Junk (measured) feet N o n e Cemented Conductor report not available. 1040 sx AS III & 350 sx Class G 200 sx Class G 140 sx Class G Measured depth 115'MD 3170'MD 7675'MD 7445'-8262'MD Rue Verticaldepth 115'TVD 2821 ' TVD 5742'TVD 5589 ' -6132 ' TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Well Hi story 13. Estimated date for commencing operation August, 1986 14. If proposal was verbally approved Name of approver DescriPtion summary of proposal [] Detailed operations program [] BOP sketch [] Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/¢~° 0//'~J'/~ ~L~_.Y Title Associ ate Engi neet Date Commission Use Only ( DAM ) SA/041 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ?~]~t: ~.': ;":~i. V~, ,;i <'~ ?~.~r-. ~. -Commissioner [ Approval No. /,~,,¢7~, by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate wo. Instructione: Prepare and submit the '"Initial Report" on the first Wednesday after a well is spudded or workoYer operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field I County, parish or borough IState Alaska North Slope Borough Alaska j kease orUnit IWoll no. Kuparuk River ADL 25569 2T-14 Dri 11 Auth. or W.O. no, AFE AK0812 Rowan 34 Date and depth as of 8:00 a.m. API 50-103-20061 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 4/23/86 IH°ur 0930 hrs. [Prior status if a W,O. Complete record for each day reported 4/23/86 4/24/86 . - 4/25/86~ 4/26/86 thru 4/28/86 4/29/86 The a~e is~correct _ 56.24% A. ccept rig ~ 2230 hrs, 4/22/86. NU diverter sys. 16" @ 115' 2034', (1919'), Navi-Drlg Wt. 9.3+, PV 15, YP 16, PH 10.5, WL 16.2, Sol 10 SEud well e 0930 hrs, 4/23/86. Drl 12¼" hole to 799', Navi-Drl to 2034'. 951', 3.4°, S23W, 950.91TVD, 4.48 VS, 4.12S, 1.75W 1224', 7.4°, S34.1W, 1222.71TVD, 29.30 VS, 26.27S, 13.00W 1471", 10.7°, S33.4W, 1466.51TVD, 68.06 VS, 58.41S, 35.77W 1879', 26.1°, S26.7W, 1852.79 TVD, 195.24 VS, 170.51S, 96.26W 9-5/8" @ 3170' 3200', (1166'), Cmt'g -Wt. 9.8+, PV 18, YP 24, PH 10.5, WL 16.2, Sol 11 Drl & surv 12~" hole to 3200', circ, POOH. RU & rn 79 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3170', FC ~ 3087'. RU Dowell & begin pmp'g cmt. 1879', 26.1°, S26.7W, 1852.79 TVD, 195.24 VS, 170.51S, 96.26W 2132', 34.1°, S27.5W, 2071.70 TVD, 321.57 VS, 282.95S, 154.08W 2414', 42.5°, S26W, 2295.00 TVD, 493.34 VS, 437.58S, 228.89W 2914', 48.4°, S25.9W, 2628.29 TVD, 865.63 VS, 771.99S, 392.64W 3140', 47.4°, S25.3W, 2779.81TVD, 1033.31VS, 923.22S, 465.09W 9-5/8" ~ 3170' 7493', {4293'), Drlg Wt. 9.7, PV 9, YP 7, PH 9.5, WL 13.6, Sol 10 Cmt 9-5/8" w/1040 sx AS III, followed by 350 sx C1 "G". Displ using rig pmps, bump plug. CIP @ 0900 hfs, 4/25/86. ND diverter, NU & tst BOPE. RIH w/8~" BHA to 3087', DO flt equip & cmt + 10' new-hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8~" hole to 7493' 3454',46.9°, S24.1W,2993.35 ~VD, 1263.50 4544', 46.7°,S26.1W,3732.64 TVD, 2063.64 5538', 50.7°,S28W, 4382.47 TVD, 2815.28 6036', 50.9°,S25.2W,4697.22 TVD, 3201.02 VS, 1132.35S, 561.28W VS, 1869.02S, 875.10W VS, 2540.49S, 1213.35W VS, 2885.53S, 1386.14W 6716', 51.5°,S22.9W,5117.79 TVD, 3735.00 VS, 3376.59S, 1596.60W. 7335', 49°, 516.1W, 5515.86 TVD, 4206.62 VS, 3822.52S,1756.37W 9-5/8" @ 3170' 7675', (182'), Circ hole cln Wt. 9.9, PV 10, YP 7, PH 9.5, WL 8.4, Sol 10.5 Drl & surv 8½" hole to 7675', 10 std short trip, RIH to 7604' att circ, packing off. Wsh & rm to 7675', circ hole cln, PO0~; tight f/7461'-7160' Fin POOH, LD turbine & MWD. RIH, tag up @ 7523' wsh to 767~' circ hole cln , , * 7600'~, 47.6°, S14.9W, 5692.14 TVD, 4401.73 VS, 4013.17S, 1809.25W IDate / / I Title Drilling Supervisor For fo~'m preparet, i~'~d distributl,q~ see Procedures Jllant/al, Section 10, Drilling, Pages 8'6-a4~d 87. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Alaska Field Kuparuk Ri 4/30/86 5/01/86 5/02/86 Date and depth as of 8:00 a.m. County or Parish fer Lea .... UnitADL 25569 'Complete record for each day while drilling or workover in progress I State North Slope Borough Alaska Cmt w/200 sx C1 "G" w/3% KCl, Displ using rig pmps, bump ND BOPE, cut 7" csg, dress IWell no. 2T-14 7" @ 7675' 7675', (0'), Instl pack-off Wt. 10, PV 13, YP 6, PH 9.0, WL 8.6, Sol 11 Circ hole cln, POOH. RU & rn 188 jts, 7", 26#, J-55 HF ERW R-3 BTC csg w/FC @ 7589', FS @ 7675'. .9% D-127, .3% D-13 & .2% D-46. plug. CIP @ 0340 hrs, 4/30/86. f/pack-off. 7" @ 7675' 7755', (80'), Chg BNA Wt. 11.5, PV 16, YP 14, PH 9.0, WL 7.8, Sol 15 NU & tst BOPE. TIH, DO FC & cmt to top of shoe. Raise mud wt to 11.3+, drl to 7685' Conduct formation tst to 13.5 ppg EMW. Drl 6-1/8" hole to 775~', circ, TOH f/BHA chg. 7" @ 7675' 7917', (162'), Drlg Wt. 11.7+, PV 15, YP 14, PH 9.5, WL 7.8, Sol 15 Chg BHA, TIH to 2500', chg brake bands & bearing in Dynamatic. TIH to 7665', rm to 7755', drl 6-1/8" hole to 7917'. The/~e is correct For form prep.~on and distrib~ see Procedur s~..~anual Section 10, Drilling, Pages 86 and 87 ITitle 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. Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25569 Auth. or W.O. no. ~Title AFE AK0812 I Dri 11 Rowan 34 API 50-103-20061 Operator IA.R.Co. W.I. rTotal number of wells (active or inactive) on thisI ARCO Alaska, Inc. 56 24% icost center prior to plugging and · labandonment of this well Spudded or W.O. begunSpudded IDate 4/23/86 IH°ur 0930 hrs, IPri°r status if a W'O' 5/03/86 thru 5/04/86 Date and depth as of 8:00 a.m. cost center code Alaska Well no. 2T-14 Complete record for each day reported 5" @ 8262' 8262', (345'), RR Wt. 12.1, PV 15, YP 11, PH 9.5, WL 5.8, Sol 16 Drl f/7917'-8199', 6 std short trip, circ (mud cut f/11.7 ppg - 11.2 ppg on btm). TOH 25 stds, TIH, hit bridge @ 7900', wsh to TD, circ & raise mud wt to 12.1 ppg, circ, TOH. RU Schl, log DIL/GR/SP/SFL f/8202'-7678', FDC/CNL f/8202'-7678', CAL f/8202'-7678', RD Schl. TIH, wsh f/8163'-8199', drl 6-1/8" hole to f/8199'-8262', short trip to shoe, circ, TOH. RU & rn 18 jts + mkr it, 5", 18#, L-80 FL4-S lnr f/8262'-7445'. Cmt w/140 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmp, bump plug. Displ 2000' 7" w/diesel. ND BOPE. NU & tst tree. RR @ 1800 hrs, 5/4/86. Old TD Released rig JNew TD PB Depth Date K nd of rig 5/4/86 1800 hrs. Classifications (oil, gas, etc.) 0il Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary 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 i T.P. C.P. Water % GOR Gravity Allowable Effective date corrected T,. ~eh,~ is correct ~ Date Title ~~~-~. I~/~.,J~ I Drilling Supervisor Drilling, Pa'g~s 86 and ~7. ' ARCO Alaska, Inc. Post Office Box 100360 Anct~orage. Alaska 99510-0360 Telephone 907 276 1215 RETURN T0: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-15-86 TRANSMITTAL # 5628 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~31-15 '~N-10 N-9*** Open Hole LIS Tapes plus Listings: Schl: One copy of each 2T -16 04-08-86 Run #1 1495.0-B961.0~_ ~ ~k~ ~ ? - 3 --~p~; --/~_~-- ~// 31-14 03-30-86 Run #1 1592 5-8297.00~,~~~~ ~ . -3-~ ~-- /~--F~?7 04-06-86 R~ ~1 0090 0-7973.~~Z~--~~- ~-- ~~ 04-03-86 o~-~-~ ~ ,~ oo~.o-~ ~~ ~-~- ~~ --~;_ ~Z 7~ ***There was previously transmitted on transmittal #5613 a 3N-9 OH LIS tape · but it was for Run #1 only. Receipt Acknowledged: State of AK ARCO AIItKI. IPIC. ,I · SuostO~lr¥ of AtllflllCRlCPIhtlOCoflll~lfly ....... STATE OF ALASKA '- ALA~., OIL AND GAS CONSERVATION CON,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request.: Abandon [] Suspend [] Operation Shutdown [] -Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate D Pull tubing [] Amend order D Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchorage .- AK ggR1 f) 4. Location of well at surface 52'FSL, 556'FWL, Sec.1, TllN, R8E, UM At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) 117' RKB PAD 82' 6. Unit or Property name Ku?_=ruk R,.'ver IJn'.'t 7. Well number ~T-14 8. Permit number 86 -44 9. APl number 50-- 1 03-20061 10. Pool Kuparuk River 0il Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Size Conductor 80 ' I 6" feet Plugs (measured) N o n e feet feet Junk (measured) feet N o n e Cemented Measured depth 200 cf 115' True Vertical depth 115' Perforation depth: measured No ne true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) N on e 12.Attachments Description summary of proposal ~ Detailed operations program I~ BOP sketch 13. Estimated date for commencing operation April 27, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~ _..//~1.2_~1~i~ Title As sec i ate Engineer ~ Commission Use Only ( LWK ) 5A/019 Conditions of approval Approved by Date 4" ~'-~'~ I Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI NO. · ~.,.~.~.?..,,~.~.-,,-~.~..'~.~.... by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 2T-14 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to lost circulation zone encountered above the Kuparuk Sand in well 2T-15, ARCO Alaska, Inc., proposes to: 1. Drill 8-1/2" hole to 7529'. 2 · . Run and cement 7" casing as per dr'illing permit ~ 7529'MD. Drill 6~hole to original planned TD ~ 8095'MD. Run and cement 5" 18 O# L-80 FL4S production liner from 7329' - 8095'MD with 100 sx Class "G" cement. 5. Complete well as per drilling permit. SA/01 9 a: tw 04/24/86 February 19, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.' (907) 276-7542 Re: Kuparuk River Unit 2T-14 ARCO Alaska, Inc. Permit No. 86-44 Sur. Loc. 52'FSL, 556'FI.fL, Sec. 1, TI!N, RSE, UM. Btmhole Loc. !098'FSL, 1424'FEL, Sec. 11, TllN, RSE, UM. Dear Mr. Kewin: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Ir Post Offic~ ~,.~ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 3, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2T-14 Dear Mr. Chatterton' Enclosed are- We estimate spudding this well on March 15, 1986. questions, please call me at 263-4970. Sincerely, ~~'1~' ~~~'~_ in JBK/LWK/tw PD/L226 Enclosures An application for Permit to Drill 2T-14, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION C~MMISSIO~/, PERMIT TO DRILL 20 AAC 25.005 DRILL I~x lb. Type of well EXPLORATORY [] SERVICE [] STRATI(~,A~Ht(~ REDRILL [] DEVELOPMENT OIL [~(Z SINGLE ZONE ~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE la. Type of work. 2. Name of operator ARCO Alaska~ Inc. 3. Address P. O. Box 100560~ Anchorage~ Alaska 99510 4. Location of well at surface 52' FSL, 556' FWL, Sec.1, T11N, R8E, UN At top of proposed producing interval 1409' FSL, 1279' FEL, Sec.11, T11N, R8E, UM At total depth 1098' FSL, 1424' FEL, Sec.11, T11N, RSE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 117', PAD 82' ADL 25569 ALK 2667 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Wel12T_14number 1 1. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 2T-1 ~vvell 25 ' (~ surface feet 18. Approximate spud date 03/15/86 2965 psig@__._80 °F Surface 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1098 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8095' MD, 6141 ' TVD feet 2560 19. If deviated (see 20 AAC 25.050) i 20. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 47 oI (see 20 AAC 25.035 (c) (2) 3404 psig@ 6006 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing 24" 16" 1 2-1/4" 9-5/8" 8-1/2" 7" 22. Describe proposed Weight 62 .~# 36.0# 26.0# program: :ASING AND LINER Grade Coupling H-40 / WeldJ J-55/HF-EIW BTC -55/HF-EIW BTC J Length SETTING DEPTH MD TOP TVD 80 35' I 35' 3128 35' I 35' MD BOTTOM TVD 115~ 115' 31631 2801 ' 1 QUANTITY OF CEMENT (include stage data) I I 34' 8095! 6141' 300 sx Class G 8061 34 I ± 200 cf 920 sx AS Ill & 350 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8095'MD(6141' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2965 psi. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2T-14 will be 25' away from 2T-15 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well The 7" x 9-5/8" annulus will be left ' with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certif~A~that the foregoing is true and correct to the best of my knowledge SIGNED /~__~~/~ TITLE Regional Drilling Engineer DATE~_~_~/ The spac~'f'orC~/nm/sion~use v - CONDITIONS OF APPROVAL Samples required []YES ;~]~0 Permit number Mud log required []YES ~ Directional Survey required APl number ~..y. ES [:::]NO 50-/o2'-- ¢.¢oC I Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS Form 10-401 Submit in triplicate Rev. 7-1-80 APPROVED BY ,COMMISSIONER DATE February 19, ]986 by order of the Commission PERMIT TO DRILL 2T-14 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. '-ARCO AL-~SKA, i PAD 2T..WELL NO. 1,; PROPOSED KUPARUK FI ELD,_._NORTH _SLOPE?_ .ALASKA EASTMAN WHIPSTOCK. INC - ............................. , _ 1000_ 2000__ ~000_ 4000_ 5000_ ........ 6000 _ KOP: 3 BUILD 3 DE~ 9 PER !00 FT 15 BASE PERMAFROST-- 21 TOP UGNU SNDS 27 TVD= 1000 .TMD=.I.O00 DEP=O ...... TVD= 1 561 TVD--1701 TMD-1 569 DEP-84 TMD'"171 8 DEP"'I 33 39 TOP W SAK SNDS TVD=2261 TMD=2377 DEP=475 4.5 EOC TVD=2405 TMD=2579 DEP=616 ................... /~-12" TVD=2601 TMD=2868 DEP=82g 9 5/8' CSO PT TVD=2801 TMD=3163 DEP=1046 -5 TVD=4321 TMD=5407 DEP=2697 AVERAGE ANGLE ' -47- .DEG ' 22, HI N .. , 7000 mi ...... i ...... I I T/ ZONE C TVD=S826 !THD=7629 DEP=4331 T/ ZONE A TVD=5890 TMD=7723 DEP=4401 TARCET CNTR .... TVD=5916-TMD=7762-DEP=4429 B/ KUP SNDS TVD=6006 THD=7895 DEP=4527 TD (LOG'PT) TVD=6141THD=8095 DEP=4674 .......................... ~ ...... ............. : ................ VERTICAL_______SECTION ....... . . . o . '- ' looo 2000' · . I I I 3000 4000 5000 HO~IZJONTAL .... PROJECTI ~.. .~E 1-IN. = 1000 FEET _. ' PAD 21. NELL' NO~ 14 PROPOSED :'' / !1 " KUP^RUK FIELD, NORTH SLOPE. ALASKA ................... ..... ............. --..' ' .............. ................. WEST-EAST ...... 3000 2000 i000' O_ ...... 1000 4' ~ ~ .... i' ........ ._. _..l.:l li:l._':..-., i!" ...... "" ..1000 _ Z - 2000 ................... ~000 1000 SURFACE LOCAT!ON ~ 52' FSL. 556' FWL -- - 'SEC. 1. T11N. RSE .... _.-- . _ ...... .... TARGET CENTER . . ........................... TVD=$9! 6 ............................................ ~- ....... TMD"??62 --- ...... DEP-4~29 'Il LOCATION~ ......... :.... ' ....... TARGET LOCAT[ON~ ' 1098' FSL. 1424' FEL --- / ' ' ' ......... : ...... SOUTH:4012 1320' FSL, 1:~20' FEL ...................... ,, - . . . ................. . . . : ............................................................ '_ .................... , .......................... ,~ -- ..... " '- ..... ' -- S 25 DEG 4 MI N W -- -- ~--4429' [TO TARGET) lO0 700 Boo 9OO KUPARUK RI VER UNIT 20" DIVEI TER SCHEMATIC DE S CR I P T I ON. I. 16' C~CTOR. 2, TAI~O STARTER I-~AD. 5. TANKO SAVER SUB. 4, TAI~O LOlh~R (:301CK-C~CT ASSY, 5. TAI~O UPPER QUICK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/I O' OUTLETS. 7. I0" HCR BALL V~VE~ DIVERTER LII~I'J VALVE~OPEN AUTOMATICALLY UPC~ CLOSURE OF A~AR PREVENTER. 8. 20' 2000 PSI A~LAR PREVENTER., MAINTENANCE & OPERAT!ON' 4 I. UPON INITIAL INSTALLATION- CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. ~ 2. CLOSE At,/~LAR PREVENTER AI~:) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3; CLOSE ANt~LAR PREVENTER IN THE EVENT 'THAT AN IhFLUX OF YiELLB~ " FLUIDS OR GAS IS DETECTED. IF .. NECESSARY, ; CLOSE APPROPRIATE VALVE TO ACHIEVE DONWWIND DIVERSION. RECEI.V~D Do NOT SHUT IN ~LL FE~O S lgSG UN~R ANY CIRCUMSTA~ES._ AI~::.,;, ..... :.~ C,~ns. Co'mmi~sion < < T.: 6 5 > > - DIAGRAM #1 I ~-:,, 8 3Q(X] PSI RSRRA BOP STACX I. 16' - 2000 PSI TAN<CO STARTING ~EAD 2. 11' - 3000 PSI CASING FF_.AD 3. I1' - 3COO PSI X 1~8' - ~ ~I ~A~ ~ 4. i~8' - ~ ~I PI~ ~ 5. i~8' - ~ ~I ~I~I~ ~ W/~ ~ KI~ LI~ ~. ~8' - ~ ~I ~ ~ W/PI~ ~ ~ T~, ACCL~LATOR CAPACITY TEST I. CHECX AhD FILL' AC~TDR RESE~OIR TO'PR~ LEVEL WI~ ~~IC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~I ~T~ ~ ~ ~~T~. 3. ~~ TI~. ~ ~ ~ ~ITS SIXThlY ALL ~ITS ~ ~~ ~I~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ 12~ ~I ~INI~ P~~. 4 2 13-5/8" BOP STACK TEST I. FILL BCP STACX AhD C~ MANIFO_D WITH ARCTIC DIESEL. 2. (]-ECX THAT ALL LOCX D(~ S~ IN ~ELL~ ARE FgJLLY RE-TRACTED. SF_AT TEST PLUG IN WITH RUNNING JT AND RLIN IN LC~ SC~. 3. CLOSE ~ PRE~q~NTE~ AN:) MANJAL KILL AN3 LINE VALVES ADJA(~ TO BCP STACX, ALL OTI-F_R VALVES AN30-K]<ES SNOJLD BE PRESSL~ UP TO 250 PS~AAD-I~ FOR I0 MIN. IN- CRF~ PRESSl~ TO~ PSI~AhE) HOD FOR lO MIN. BLEED PRES~ TO 5. CPEN AN~ PREVENTER AbE) MANUAL KILL AAD CHOKE LINE VALVES. CLOSE TOP PIPE ~ AND HCR VALVES ON KILL AbE) CHOKE LINES. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. ?. CONTIh~ TESTING ALL VALVE~,$~,~J,,INES, AhD WITN A 250 PSI LCd/ AND-~O~ PS~) NIGH. TEST AS IN STEP 4. DO NOT ~9~>ES~J~-~NY J~OT A ,F1JLL CLOSING PC~TIVE SEAL (~ ON_Y F-I~ICN TEST Cl-~$ THAT gX2 NDT FULLY CLOSE. 8. (~ TO:~ PIPE RAMS AhD CLOSE BOTg'C~ PIPE RAMS. TEST BOTTChl PIPE RAMS TO 2_,90 PSI AhD 3000 PSI. 9. CPEIq BOTTOVl PIPE RAMS, BACX OJT RUN4INO JT AhD .10. CLOSE BLIhD RAMS AAD TEST TO 250 PSI AND .3000 PSI. II. CPEN BLIN3 RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFO_D AhD LINES ARE FgJLL, C~' NOq-FREE-ZING. FLUID. SET ALL VALVES IN DRILLING POSITI(]N. - 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCXS, DRILL PIPE SAFETY VALVE, AhD INSIDE B(:~ TO 250 PSI AhD 30O0 PSI. 13. RECO~ TEST IhF'CI~TICAI CN BL(~ ~ TEST ~-~ ...... ~, SIGN, AhD SEAD TO DRILLING SLPERVISO~. 'WE~_KLY THEREAFTER Fg.~ICNALLY CF~TE BOF~ DAIL . II i II 510084001 REV. 2 ARCO Alaska, h Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer If JG/tw GRU13/L44 Enclosure RECEIVED FEB 0 5 Oil & G,~,s Con,~. u~:,, ......... ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfietdCompany LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. I~ TIIN~R8E~ U.M. SEC. I ~ TIIN~R8E~ U.M. 2- Y = 5,970,382.43 LAT. 70't9'49.1287" I0 - Y = 5,970,132.65 LAT. 70019'46.6719" X = 498,944.93 LONG. 150~00' 30.807'' X = 498,945.27 LONG. 150~00' 30. 796" ~2' FSL, 556' FWL OG = 77' .PAD = 81.5 152'FSL, 556' FWL OG - 76.0 PAD · 81.7 3 - Y ~ 5,970,357.42 ~T. 70~19'48.8828" 11 = Y = 5,970,107,71 LAT. 70019'46.4267" X = 498,944.91 LONG. 150~00" 30.808'' X = 498,945.10 LONG. 150°00' 30.801" 377' FSL, 556' FWL OG = 77' PAD = 81.5 127' FSL, 556' FWL OG = 75.9 PAD ~ 81.7 4 - Y = 5,970,332.46 LAT. 70~19'~.6372" 12- Y = 5,970,082.58 LAT. 70°19'46.1794" X = 498,944.84 LONG. 150~00' 30 809" ~ ' · o X : 498,944.98 LONG.150°O0 30.804" 352" FSL, 556' FWL OG = 77' PAD = 81.6 '~ 102' FSL, 556' FWL OG - 75.7 PAD - 81.7 5- Y : 5,970,307.52 LAT. 70~19'48.3919'' ~ 13- Y : 5,970,057.59 LAT. 70°19'45.9336" X = 498,944.91 LONG. 150000, 30.808" ~ ~ X : 498,945.08 LONG 150000' 30.801" 327' FSL, 556' FWL OG = 77' PAD ~ 81.6 77 FSL, 556' FWL OG - 75.5 PAD ~ 81.6 6 - Y = 5,970,282.50 LAT. 70°19'~ 1459" ~ 14 - Y = 5 970,032.60 LAT. 70°19'45.6879" , ' ~ O~ ~ ~ ' X = 498 944.95 LONG.150°00 30.806" ~ m ~ X = 498,944.91 LONG 150000'30.806" 302' FSL, 556' FWL 0G = 77' PAD = 81.7~ ~ ~ o~' 52' FSL, 556' FWL OG = 75.3 PAD = 81.7 x. x 277' FSL, 556' FWL 0G = 77' PAD = 81.6 ~ 27' FSL 556' FWL 0G = 75 2 PAD = 81.6 ~ 8 - Y = 5,970,232.63 LAT. 70019'47.6553" 16 - Y = 5,969,982.85 LAT. 70°19'45.1985" ~ ~ ~ i'~ X = 498,944.96 LONG. 150000' 30.806" ~ ~ ~ X = 498,944.88 LONG. 150°00' 30.807" ~:~;~?:~ ~ 2sz' FSL, SS6' FWL 0G = 76.9 PAD - SE.6 ~ 2' FSL, SS6' FWL 0G ~ 9 - Y = 5,970.207.62 LAT. 70019'47.4093" c~ LOCATED IN PROTRACTED :~ x = 498,945.01 LONG. 150°O0'30.804'' ~ SEC 12, TI I N, RBE, U L.n-:,~: -~. 227' FSL, 556' FWL OG = 76.3 PAD = 81.6 ' ' ~::~:L~.--~ 17 - Y = 5,969,957.72 LAT. 70°19'44.9514" .... - X = 498,944.94 LONG. 150°00'30.805" {~...~.~'.?.. _~ 23' FNL, 556' FWL OG = 75.0 PAD = 81.6 ~'~ ~'~h NOTES ...... I. ALL COORDINATES ARE A.S.P.~ZONE4. ~ 2. SECTION LINE DISTANCES ARE TRUE. ~.HORIZ; POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WEST ~ 2T-MIDDLE PER LHD~ 4. VERT. POSITIONS BASED ON TBM's 2T-6 & NI9+75, Ell+ 52 PER F.R.B. ~ ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-~140 rev. C ERTI~IC ATE OF SURVEYOR ;/ HEREBY CERTIFY THAT t AM ~ROPERLY SURVEYING IN THE STATE Of ALASKA ~D THAT ~umm ~ ~ ~UPARU~ DRnJECt lUll D. wN w~ DRILL SITE 2T CONDUCTOR ~.~: ~ECKED SH ~ AS- BUilt LOCATIONS - ......... ........... 1~DWG. No. NSK 86-6 Arctic Boulevard, Suite 201, Anchorage, Alaska ~9503IIJIS~LEJOB ~.N'T'S' b~,'.bl~ Llbl I~UK NEW Wt~LL FEFuXlITS ITEM APPROVE DATE (1) Fee ~./~--- ~L-fL~( (2) Loc /~.~x-- q--,%-~'Z thru 8) 1. Is . 4. 5. 6. 7. 8. (3) Admin ~-~ ~ '/~ 9. (/9 thru 1~, -~- 10. '(10 and '1-2) /" 12. (13 thru 21) (5) (22 thru 26) 13. 14. 1.5. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. (6) Add: ,'~.~."~ ~-/Z'~ 27. G'ompany., /~CGa Lease & Well No. YES NO the permit fee attached ......................................... Is well to be located in a defined pool ............. '.~.~ Is well located proper distance from other we is ....... Is sufficient undedicated acreage available in this pool Is well to be deviated and is wellbore plat included ... Is operator the only affected party ........................ ~ Can permit be approved before ten-day w;it ..1 . ..]. i] .i]...1 Does operator have a bond in force ................................... ~ Is a conservation order needed ...................................... ~ Is administrative approval needed ...................... Is the lease number appropriate ... ii ~]] ..].] ...1 i..]]o..i .... ] ~ (~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface .... ].~] ] Will cement tie in surface and intermediate or production strings. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ......... , .................. Is a diverter system required ....................................... z~ ., Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to .~D~D psig .. ?~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. __ Additional requirements Additional Remarks: REMARKS o HO Geology: Engipeering: /'_ ~' HJH /~/~7-/~ rev: 03/13/85 6.011 ....... INITIAL ceo; UNIT "' oN/OFF' ' POOL CLASS STATUS AREA NO. SHORE , Al:ii iNi-i](]Ni 1VilN (II NOD Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ~::----SCHLUMSERGER- --~ LIS T~PE ~ERIFICATI~N LISTINS CONF*OE VP O!O.HO2 VERi;IC~T'12~ LISTZNS P&GE 1 ERViCE NAME :E2ZT ~ATE :85105112 ~RISIN : 'E~L NA~4E :143393 ,ONTINJATISN ~ :01 'REVIOUS REEL : O~MENTS :LIBRARY ;ERVIC: N4ME :EDIT lATE :85/05/12 IRISIN :gO00 'APE NA~E :1~55 :O~T!NU4TiON ~ :01 ~REVIOUS T~PE : :OMMENTS :LIER~RY T&PE ~g FILE HE&DER :ILE N&ME :EDIT ~ERVlCE NAME : ~ERSIDN ~ : DATE : IAXIMUM LENGTH :!LE TYPE ~REVIOUS EZLE INFORMATION .001 : 1024 : RECCR~S ~NEM CONTENTS 'N : ARSO ALASKA, ~N : 2T-14 :N : KUPARUK ,OWN: iEC~T: ~O~N: NORTH SLOPE ~T~: AL~SK~ ~T~Y: US~ ~NEM CONTENTS ~R~S ' ,.-,.-... C mMMENTS. ~:."~ UNIT 'TYPE 000 000 000 000 000 000 000 000 000 3 DO0 DO0 DO0 DO0 000 DO0 000 300 300 C ATE 000 SIZE 005 008 002 00~ 002 012 005 003 001 CODE 055 065 065 065 065 0,.55 065 065 065 VP 013.H02 V.=R!FIC~,TZ3'~ LISTIN3 PA',T~E 2 03 NUMBER AT ACC: 71455 UN ~1, gATE LOSG~D: 03-MAY-S6 DP: RICK (RUWELL ASING : 7.003" ~ 7575' - aZT SIZ= : 5 1/8" TD 8201' Y:E ~L3ID : WT. ~AT SLAY tENSITY : 12.1 LB/S RM : 3.03 @ 58 DF 'IS30SI~Y : 41 S RMF : 2.02 @ ~5 DF IH : 9.5 RMC : ~.~3 @ 53 DF :LOID LOSS = 5.8 23 RM AT 5HT = 1.495 ~ 145 Dr IATRIX SANDSTONE :~ ~HIS DATA HAS NOT SEEN DEPTH SHIFT~ - OV~RL.A¥S FIELD mRiNTS VO 010.~02 V-'ql;i~aTi,3".~ t!$TIN3 PA,Si 3 · ',: S'HLU~BE~SER LOGS iNCLUD.ED WITH THIS M~G~',t=Ti.~ TAP--: '.~ DJAL IND'JSTIDN SPHERICALLY FOSUSED LgC, (OIL) ~ D~T~ AVaILaBLE: 819~' T2 7678' :~ F]RM&TION DEnSiTY C~MP~NS~TE] LOS (FDN) ¢ C2MPENSAT~D ~UTR]N LOG (~DN) .,- 2&T~ ~V~ILAB~:_ 5168 Tn. TST8 :~ DAT~& ~ORM~T R!ECDRO ~: NTRY ~LOCKS TYPE SIZE REPR C03E EN'TRY 2 I 6,6 0 ~ 1 66 1. 8 4 73 50 9 4 65 .lin ~ 1 66 0 iATgM SPECIFICATION BLOCKS iNEM SERVICE SERVICE JNIT :~PI APl ~PI ~Pi FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS ~OD NO. CgO~ (OCT'AL) 'EPT F~, O0 000 O0 0 0 4 1 68 O000OO00000000 ,VO OIO.HOZ VDRi~ICATI3N LISTING )EPT ;P &PHI )EDT ;P ~HOB ~PMI )EPT iP {HOB IPHI )EPT ~HOO ~PH! )EPT ~P ~HOB ~PHI ~P ~HDB ~P~I DF_ ~' T ~P ~MCB ~PH l DEDT DHMM O0 220 O! D OHMM O0 120 45 O 3qM~ O0 120 ~4 D MV 00 010 O1 0 G~PI O0 310 O1 0 S~PI O0 310 O1 0 IN O0 280 O1 0 · S/C3 O0 350 02 0 S/C3 O0 355 O1 0 O0 420 01 0 O0 000 O0 3 PJ O0 890 O0 O C~S O0 330 31 0 C~S O0 330 30 O 8215.5000 -26.5107 2.0~62 38.818~ 8200.0000 -26.0~20 2.0862 39.5996 8!00.0000 -Z9.5~20 2.4592 42.1387 8000.0000 -31.9~83 2-4065 35.3027 7900.0000 -39.9883 2.3?72 27.9785 7800.0000 -23.4951 2.~729 39.1113 7700.0000 -26.4951 2.3596 ~4.2383 7560.0000 SFLJ GR ORH~] NCNL SFLJ SR DRHD NCNL SFLJ GR 9RHD NCNL SFLJ GR DRHD NCNL SFLU NCNL SFLJ GR NCNL SFLJ SR NCNL SF~.J 3.O354 105.3398 -0.0039 2012.6875 3.0334 105.3398 -0.0039 .2012.6875 3.2737 97.4548 0.0505 1979.6875 4.8171 93.3398 0.0073 2365.5000 8.6035 ~8.4023 0.0024= 28~3.5000 3,1350 141.4375 0.0454 2221.5000 1,7657 108.1523 0.0303 16~5.$~75 2000.6875 ILD NR~T FCNL ILD NRAT FCNL ILD GR NRAT FCNL ILO GR NRA? FCNL ILO GR NR~T FCNL ILO GR NR~T FCNL T! NRAT FC NL ILO 3.0 105.3 3.1 523.3 3.0 105,3 3.1 523,3 2.7 97.4 3.3 577.3 . 93. 2. 77 '?. . 11.32. . 141. 3. 561. . 108. 439. 4.3. 315 39~ O38 125 042 038 125 229 342 t 25 2234 3398 9280 3125 5281 4023 4512 6.975 8850 4375 I721 3125 5030 1523 5018 8906 51 t 7 t 58 00000000000000 1 $~ 00000000000000 I 58 00000000000000 1 5~ OOOOOO00000000 I 53 00000000000000 i 5B OOOO000000OO00 i 58 00000000000000 1 58 00000000000000 1 5~ OOO00000000000 1 58 OOOO000000O900 t 58 00000000000000 I 6~ 00000000000000 i 5~ 00000000000000 I 58 O000DO00000000 ILM 3.0002 CALl 6.125T RNRA 3-2288 ILM 3,0002 CALl 5.4148 RNR~ 3.2288 ILM 2.8870 CALl 6.9578 RNRA~ 3.6299 ILM' 4.3640 CAL,I 6.4070 RNR~ 3.0413 ILM 6.9109 CALl 6.3601 .RNRA 2.5100 ILM 2.9456 CA:LI 7.0046 RNR4 3.357'7 ILM 1.5225 ~ALI 9.0332 RNR~ 3.7405 ILM 2000.6875 Vo OiO.MOI VERi~IC~II9~ LIETIN3 ~A55 3 P -25.0107 Gq HS~ 2.2112 Dq~~ iPqI 60.400~ -0.4853 Nq~T 1336.5875 FC~L :~ mILE TRAIL~q. ~.~ :IL: N~qE :EDIT .00! ;ER¥ICE NAME : ?ERSION ~ : )ATE : I~XIHUM LEN,GTH : 1024 :ZLE TYPE : ~EXT FILE NAME : ,..,. TAPm TRAiLeR ~',~ ~ERVICE NAME :EDIT )ATE :85/05/12 ]RI'GIN :O00O ?APE NAME :1465 20NTINUATIDN ~ :01 ~EXT TAPE NAME : CDMMENTS :LIBRARY TAPE ~ REEL TRAILER SERVICE NAME :EDIT DATE :85/05/12 gRI~IN : REEL N~ME : lZ, 9~93 CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :LIBRARY TAPE 6Z.9~05 Z73.!~05 CALi RNR~ 6.~890
