Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
186-141
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-02 KUPARUK RIV UNIT 2T-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-02 50-103-20072-00-00 186-141-0 W SPT 5752 1861410 3000 2675 2675 2675 2675 140 140 140 140 REQVAR P Adam Earl 6/21/2025 MIT-IA tested as per AIO 2C.001 to max ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-02 Inspection Date: Tubing OA Packer Depth 1420 3410 3350 3330IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625072159 BBL Pumped:1.7 BBL Returned:1.7 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-02 KUPARUK RIV UNIT 2T-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2T-02 50-103-20072-00-00 186-141-0 W SPT 5752 1861410 3000 2170 2170 2170 2170 132 136 136 135 REQVAR P Guy Cook 6/10/2023 MITIA to maximum anticipated injection pressure per AIO 2C.001. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-02 Inspection Date: Tubing OA Packer Depth 1010 3300 3250 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230609154729 BBL Pumped:2.1 BBL Returned:2.1 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MITIA t James B. Regg Digitally signed by James B. Regg Date: 2023.07.27 11:11:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Tuesday, June 22, 2021 P.I. Supervisor `\e�/ l 7114 VZ4 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-02 FROM: Brian Bixby KUPARUK R1V UNIT 2T-02 Petroleum Inspector Sre: Inspector Reviewed By P.I. Supry `J r NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2T-02 Insp Num: mitBDB210619061343 Rel Insp Num: API Well Number 50-103-20072-00-00 Inspector Name: Brian Bixby Permit Number: 186-141-0 Inspection Date: 6/18/2021 „ Tuesday, June 22, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-02 - - Type Inj ! W -'!TVD L _ 5752 Tubing 2630 -2640 2640 2640 PTD 1861410 .Type Test I SPT Test psi ! 3000' I jA 1080 3410f 3370 3360 BBL Pum ped: 2.4 111;L Returned: 24 QA 115 --- 120. 120 ' - — — - —_�_ I' 12�— — - Intervale REQVAR PIF P - -. - Notes: 2 Year MITIA as per AIO 2C.001 ' Tuesday, June 22, 2021 Page 1 of 1 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg �tny�7/ DATE: Thursday, July 25, 2019 p P.1. Supervisor e,,(I l —1 ( SUBJECT: Mechanical Integrity Tests 1840 ism - Iedo- ConocoPhillips Alaska, Inc. - T.Npe Test SN Test psi 2T-02 FROM: Jeff Jones KUPARUK RIV UNIT 2T-02 Petroleum Inspector 21 OA w 109 1 Sre: Inspector REQVAR lnNot¢S:MIT-L4 Reviewed By: P.I. Supry ..) NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-02 Insp Num: mitJ1190725100734 Rel Insp Num: API Well Number 50-103-20072-00-00 Inspector Name: Jeff Jones Permit Number: 186-141-0 Inspection Date: 62/2019 Thursday, July 25, 2019 Page 1 of I Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min Well -!-I1' - TN pe Inj TVI) 5-1' Tubing 1840 1840 ism - Iedo- PTD , 1861410 - T.Npe Test SN Test psi 3000 -I IA >40 3310 - 3300 cSU BBL Pumped: 2? BBL Returned: 21 OA w 109 1 Interval REQVAR lnNot¢S:MIT-L4 to max. anticipated inJectPrress, Per O 2C -001I well inspected, no exceptions noted. Thursday, July 25, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jinn Re t� DATE: Thursday,June 15,2017 P.I.Supeer�visor ��� 6 Ic. 1 (7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-02 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-02API Well Number 50-103-20072-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-141-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607150757 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-02 Type Inj W- TVD 5752 - Tubing 2625 2650 2650 _ 2650 PTD 1861410 - Type Test SPT Test psi 3000 . IA 1061 3400 - 3340 - 3330 - BBL Pumped: 2.2 BBL Returned: 2.2 OA 110 110 - 110 - 110 . Interval REQVAR - P/F P - Notes: MITIA per AOI 2C.001 to MAIP SCANNED ;E 1" I 3 2 1( Thursday,June 15,2017 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 02,2016 TO: Jim Regg � P.I.Supervisor 1l `' Ilk Id I!to SUBJECT: Mechanical Integrity Tests ( l CONOCOPHILLIPS ALASKA INC 2T-02 FROM: Brian Bixby KUPARUK RIV UNIT 2T-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-02 API Well Number 50-103-20072-00-00 Inspector Name: Brian Bixby Permit Number: 186-141-0 Inspection Date: 10/25/2016 Insp Num: mitBDB161026045856 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-02 Type Inj W' TVD 1 5752 • Tubing 2560 . 2560 2560. 2560 , PTD 1861410 , Type Test SPT Test psi! 3000 , IA 740 3310 . 3250 - 3240 ., Interval REQVAR P/F �1 P ✓ OA 100 100. 100 - 100 . Notes: Area Injection Order No.2C.001 Tested to maximum anticipated injection pressure.2.4 BBLS Diesel to fill IA and 2.6 BBLS bled back.y Wednesday,November 02,2016 Page 1 of 1 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) ~l~'wo-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type ~ Poor Quality Originals: /~ Other~~_~.~ ~ [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~'~'/ (at the time of scanning) SCANNED BY: BEVERLY BREN VINCE~ARIA LOWELL DATE ReScanned {done) RESCANNEDBY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: PAG ES: Quality Checked (done) RevlNOTScanned.wlxl • • WELL LOG TRANSMITTAL PROACTIVE DAGNOSTic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. t MAR 3: () all j Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Robert A. Richey 130�West International Airport Road U Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 13- Mar -11 2T -02 EDE 50- 103- 20072 -00 2) Signed : . Date : , Print Name: 4, CA .:,,, :3 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PH0NE: (907)245 -8951 FAX: (907)245 -88952 E : cdssanchorageAmemoryloc com WEBSITE : wtf /.merory oq.Com C:\Documents and Settings\Diane Williams\Desktop \Transmit Conoco.docx • • WELL LOG TRANSMITTAL IB° PROAcriWE DiAgNOSric SERVICES, INC- To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road 5UPIMED MAR l) 3 2O Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 03- Feb-11 2T -02 1 Report / EDE 50- 103- 20072 -00 2) FEB 10 2011 Signed : �� Date : Gas' Con e 4 ssi f1 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E -MAIL : pdsanchoraae(D_memorvlou.com WEBSITE : WWW.memorvloq.COm C:\Documents and Settings \Diane Williams \Desktop \Tiansmit_Conoco.docx 1 • II 1 -r Memo ry Multi- Finger Caliper � r S Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2T -02 Log Date: February 3, 2011 Field: Kuparuk Log No.: Ser. No. 7949336 State: Alaska I Run No.: 2 API No.: 50-103-20072-00 Pipet Desc.: 2.875" 6.5 Ib. J -55 EUE 8RD AB -MOD Top Log Intv11.: Surface Pipet Use: Tubing Bot. Log Intvll.: 8,344 Ft. (MD) 1 Inspection Type : Buckling & Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the tubing jewelry off wellbore schematic 9.0 modified by LMOSBOR on 01/31/2011. I This log was run to assess the condition of the tubing with respect to buckling and corrosive and mechanical damage. The caliper recordings indicate the 2.875 in tubing logged is in good condition with respect to internal I corrosive and mechanical damage, with a maximum recorded wall penetration of 23% in Jt. 88 (2,798 ft.). No significant areas of cross - sectional wall loss recorded. Deposits restrict the I.D. to 2.26" in joint 174 (5,462'), and to 2.29 inches in Jt. 173 (5,456 ft.). Although not presenting a significant I.D. restriction, the caliper recordings indicate slight buckling from —800 ft. to 8,344 ft. (EOL). I This is the second time a caliper has been run this well. A comparison to the first log ran on April 15, 2009 indicates little if any increase in corrosive damage. A comparison plot is included in this report. I In reviewing this data and the data recorded previously we believe the updated schematic (01 -31 -2011) which lists the tubing size at 2375 throughout this interval maybe incorrect, we used tubing size of 2.875 for this interpretation and comparison. I This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: I Line of Pits ( 22 %) (21 %) Jt. 88 @ 2,798 Ft. (MD) Line of Pits Jt. 66 @ 2,110 Ft. (MD) No other significant wall penetrations (> 20 %) are recorded throughout the interval of 2.875 in. tubing logged. 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall Toss (> 15 %) are recorded throughout the interval logged.. I MAXIMUM RECORDED ID RESTRICTIONS : I Deposits Minimum I.D. = 2.26" Jt. 72 @ 5,462 Ft. (MD) Deposits Minimum I.D. = 2.29" Jt. 72 @ 5,456 Ft. (MD) Deposits Minimum I.D. = 2.30" Jt. 72 @ 8,300 Ft. (MD) 1 No other significant I.D. restrictions are recorded throughout the 2.875" tubing logged.. I I Field Engineer: K. Heid Analyst: J. Thompson Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 431 -7100 Fax: (281) 431 -7125 E -mail PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 115(0 -- / I a o. 3a I • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 2.875 in (49.4' - 8337.1') Well: 2T -02 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: February 03, 2011 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 49 • R. 25 4.. 793 I 50 1573 1 75 2366 I GLM 1 100 3143 0 1 25 3929 Z s I — a. 150 4705 0 I GLM 2 175 5492 I 200 - o 6304 GLM 3 I I 225 7098 GLM 4 ■ GLM 5 ! - ' 7884 GLM 6 264 8337 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 264 I I I • • I Maximum Recorded Penetration " r 3 S I. 111-, Comparison To Previous Well: 2T -02 Survey Date: February 03, 2011 I Field: Kuparuk Prey. Date: April 15, 2009 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No 10000428 Hal Country: USA Tubing: 2.875" 6.5 lb 1 -55 EUE 8RD AB -P I Overlay Difference Max. Rec Pen. (mils) DiiL in Max Pen. (mils) I -50 0 50 100 150 200 -25 0 25 50 1 0 11 -....._ " -_. 11 "ft z1 II 21 31 31 41 -- 41 I .- 51 51 59 59 _ 69 I 69 79 79 89 — 89 E -- 1 99 99 108 108 118 - - -- r- - - 118 a z 128 i 128 138 = 138 I _ 148 148 I 158 -- 158 168 168 - 178 _ 178 187 187 197 1.-.--'-----= 197 207 -= 207 ,._— 217 217 226 226 I __— 236 236 2 45 245 — I 254 254 263.1 2 63.1 -28 -14 0 14 28 1 i •1ebmary 03, 2011 •Apr1 15, 2009 Approx. Corrosion Rate (rrpy) I I • . I PDS Report Overview ti 11. Body Region Analysis I Well: 2T -02 Survey Date: February 03, 2011 Field: Kuparuk Tool Type: UW MFC 24 No 10000428 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins I Penetration(% wall) D amage Profile (% wall) 300 - - -_ Penetration body Metal loss body 0 50 100 250 I 200 ___ 1 - -_ 150 __- ya I 100 51 -__ a 0 I 0 to 20 to 40 to over y 20% 40% 85% 85% Number of joints analysed (total = 265) ' 261 4 0 0 GLM 1 et ri I Damage Configuration ( body ) 150 150 I 100 GLM 2 I 50 200. GLM 3 0 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole GLM 4 GLM 5 250 I Number of joints damaged (total = 137) 133 0 4 0 0 Bottom of Survey = 264 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf J -55 EUE 8RD AB -MtI Vell: 21-02 Body Wall: 0.217 in Field: Kuparuk I Upset Wall: 0.217 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in USA Survey Date: February 03, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 49 0 0.02 11 3 2.38 Lt. Deposits. • 2 80 0 0.02 11 3 2.40 ■ 3 110 0 0.02 9 2 2.39 • 4 141 0 0.02 9 5 2.39 ■ I 5 172 0 0.02 11 3 2.40 6 203 0 0.01 7 2 2.39 7 234 0 0.02 9 4 2.39 • 8 265 0 0.02 10 3 2.38 • 9 296 0 0.02 10 3 2.39 ■ I 10 327 0 0.03 14 4 2.40 Shallow Line of Pits. • 11 358 0 0.02 10 3 2.39 ■ 12 389 0 0.02 10 2 2.39 • 13 421 0 0.02 10 3 2.40 • I 14 452 0 0.02 10 3 2.39 15 483 0 0.02 8 2 2.41 16 514 0 0.02 8 2 2.39 17 545 0 0.02 11 2 2.39 I 18 19 576 0 0.02 8 2 2.40 607 0 0.02 8 2 2.40 20 638 0 0.02 10 2 2.40 • 21 669 0 0.02 9 2 2.40 • 22 700 0 0.02 10 2 2.39 • I 23 731 0 0.02 10 3 2.38 • 24 762 0 0.02 10 2 2.39 ■� 25 793 0 0.02 9 1 2.39 ■I 26 824 0 0.02 10 3 2.41 • I 27 856 0 0.03 12 4 2.39 Shallow Pitting. ■ 28 887 0 0.02 10 3 2.41 • ■ 29 918 0 0.02 10 4 2.40 • 30 949 0 0.02 9 4 2.40 I 31 980 0 0.02 9 3 2.41 32 1011 0 0.03 14 4 2.41 Shallow Pitting. • 33 1042 0 0.03 12 3 2.41 ■ 34 1073 0 0.03 15 4 2.41 Shallow Line of Pits. • 35 1105 0 0.02 11 4 2.40 ■ I 36 1136 0 0.02 10 3 2.41 • 37 1168 0 0.02 11 3 2.41 ■ 38 1199 0 0.03 12 3 2.41 Shallow Pitting. • 39 1230 0 0.03 12 3 2.40 • I 40 1261 0 0.03 12 3 2.41 Shallow Pitting. • 41 1292 0 0.03 12 4 2.41 Shallow Pitting. • ■ 42 1323 0 0.03 12 3 2.41 • 43 1354 0 0.03 12 3 2.40 Shallow Pitting. • I 44 1385 0 0.02 11 4 2.41 • 45 1417 0 0.03 14 3 2.41 Shallow Pitting. • ■ 46 1448 0 0.02 10 2 2.41 • 47 1479 0 0.02 10 3 2.39 • 48 1511 0 0.03 12 3 2.40 ■ I 49 1542 0 0.02 10 3 2.41 • 50 1573 0 0.03 12 3 2.39 Shallow Pitting. Penetration Body I Metal Loss Body Page 1 I I I 0 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB- MtWell: 2T -02 1 Body Wall: 0.217 in Field: Kuparuk I Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: February 03, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 51 1604 0.03 0.03 15 6 2.40 Shallow Pitting. ■ 52 1635 0 0.04 19 6 2.40 Shallow Pitting. ■ 53 1666 0 0.03 13 4 2.40 Shallow Pitting. • 54 1697 0 0.03 13 3 2.40 Shallow Pitting. • 55 1729 0 0.02 10 4 2.42 • I 56 1760 0 0.02 11 2 2.41 ■ 57 1791 0 0.03 14 2 2.40 Shallow Line of Pits. ■ 57.1 1822 0 0.03 14 3 2.40 Pup Shallow Line of Pits. 57.2 1830 0 0 0 0 2.33 SSSV I 58 1839 t) 0.03 12 2 2.42 Shallow Pitting. • 59 1870 0 0.03 16 4 2.43 Shallow Line of Pits. ■ 60 1901 0 0.02 11 3 2.43 • 61 1932 0 0.03 13 3 2.40 Shallow Pitting. • I 62 1962 0 0.03 14 3 2.39 Shallow Line of Pits. • 63 1993 0 0.03 13 3 2.39 Shallow Pitting. • ■ 64 2025 0 0.03 14 2 2.39 Shallow Line of Pits. • 65 2056 0 0.04 18 3 2.40 Shallow Line of Pits. • I 66 2087 0 0.04 21 5 2.41 Line of Pits. ■ 67 2118 0 0.03 16 4 2.43 Shallow Pitting. • ■ 68 2149 0 0.03 14 5 2.40 Shallow Line of Pits. ■ 69 2180 0 0.03 16 3 2.41 Shallow Line of Pits. • 70 2211 0 0.04 17 3 2.40 Shallow Line of Pits. • I 71 2241 0 0.03 13 3 2.38 Shallow Pitting. • 72 2272 0 0.03 14 3 2.40 Shallow Line of Pits. ■ 73 2303 0 , 0.02 10 2 2.40 • 74 2334 0 0.03 15 4 2.40 Shallow Line of Pits. • I 75 2366 0 0.03 14 3 2.38 Shallow Line of Pits. Lt. Deposits. • 76 2398 0.03 0.03 16 3 2.42 Shallow Pitting. • 77 2428 0.03 0.03 15 3 2.41 Shallow Line of Pits. • 78 2459 0 0.03 14 3 2.40 Shallow Pitting. • I 79 2490 0 0.03 13 2 2.40 Shallow Pitting. • 80 2520 0 0.03 13 3 2.40 Shallow Pitting. • ■ 81 2552 0 0.03 15 4 2.41 Shallow Line Corrosion. ■ 82 2583 0 0.04 16 3 2.43 Shallow Line of Pits. • 83 2613 0 0.03 15 4 2.39 Shallow Pitting. ■ I 84 2645 0 0.03 15 3 2.41 Shallow Line of Pits. • 85 2676 0.03 0.04 18 3 2.39 Shallow Pitting. ■ 86 2708 0 0.03 14 6 2.40 Shallow Pitting. ■ 87 2739 0 0.03 12 3 2.43 Shallow Pitting. • I 88 2770 0 0.05 22 4 2.40 Line of Pits. ■ 89 2800 0 0.03 16 3 2.39 Shallow Line of Pits. ■ 90 2832 0 0.03 14 2 2.39 Shallow Pitting. • 91 2863 0 0.03 13 3 2.43 Shallow Line of Pits. • ' 92 2894 93 2925 0 0.03 16 4 2.41 Shallow Line of Pits. • 0 0.03 12 3 2.39 • 94 2957 0.04 0.04 16 3 2.42 Shallow Line of Pits. • 95 2988 0 0.03 12 3 2.40 ■ 96 3019 0 0.03 12 5 2.38 Lt. Deposits. • I 97 3050 0 0.03 15 4 2.41 Shallow Line of Pits. • 98 3082 0.03 0.03 13 3 2.40 Shallow Pitting. rat I Metal Loss ion Body Page 2 Penet I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf J -55 EUE 8RD AB- MCWell: 2T -02 Body Wall: 0.217 in Field: Kuparuk I Upset Wall: 0.217 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in USA Survey Date: February 03, 2011 Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Iris.) (Ins.) % (Ins.) 0 50 100 99 3112 0 0.03 14 6 2.40 Shallow Line of Pits. ■ 100 3143 0.03 0.04 18 5 2.39 Shallow Line of Pits. ■ 101 3174 0.03 0.02 10 3 2.40 _ 101.1 3204 0 0 0 0 2.39 GLM 1 (Latch I@ 3:30) 102 3212 (1 0.04 18 6 2.34 Shallow Pitting. Lt. Deposits. ■ I 103 3244 0 0.03 13 5 2.31 Shallow Line of Pits. Lt. Deposits. ■ 104 3275 0 0.03 15 4 2.40 Shallow Pitting. ■ 105 3306 0 0.04 18 5 2.33 Shallow Line of Pits. Lt. Deposits. • 106 3337 0.03 0.03 14 4 2.40 Shallow Line of Pits. • I 107 3368 0.03 0.04 20 7 2.39 Line Corrosion. a 108 3399 0.03 0.03 14 3 2.40 Shallow Line of Pits. • 109 3431 0 0.02 10 2 2.41 • 110 3461 0 0.03 12 2 2.39 Shallow Line of Pits. • I111 3493 0 0.03 15 3 2.36 Shallow Line of Pits. Lt. Deposits. • 112 3524 0 0.02 10 3 2.40 • ■ 113 3556 0 0.02 9 2 2.38 Lt. Deposits. ■ 114 3586 0 0.03 16 3 2.38 Shallow Line of Pits. Lt. Deposits. ■ 1 5 3618 0 0.03 13 4 2.40 Shallow Pitting. I l 116 3649 0 0.03 12 2 2.39 Shallow Pitting. ■ 117 3680 0 0.02 10 2 2.38 Lt. Deposits. ■ 118 3712 0 0.04 19 3 2.42 Shallow Line of Pits. • 119 3742 0 0.02 11 3 2.40 • I 120 3773 0 0.02 11 2 2.38 Lt. Deposits. • 121 3805 0 0.03 12 3 2.39 Shallow Pitting. ■ 122 3836 0 0.03 12 2 2.39 • 123 3867 0 0.03 12 3 2.40 Shallow Pitting. ■ I 124 3898 0 0.03 13 3 2.40 Shallow Pitting. • 125 3929 0 0.02 10 2 2.39 in 3960 0 0.03 12 4 2.40 • 127 3991 0 0.03 14 2 2.42 Shallow Pitting. • I 128 4021 0 0.02 10 3 2.39 • 129 4052 0 0.03 13 2 2.38 Shallow Pitting. • ■ 130 4084 0 0.02 11 2 2.40 ■ 131 4114 0 0.02 9 2 2.40 132 4145 0 0.02 9 2 , 2.42 I 133 4177 0 0.02 10 2 2.40 • 134 4208 0 0.02 11 3 2.41 ■ 135 4238 0 0.03 15 2 2.39 Shallow Pitting. • 136 4270 0 0.03 14 3 2.41 Shallow Pitting. ■ I 137 4301 0 0.02 11 2 2.38 • 138 4333 0 0.03 13 3 2.41 Shallow Line of Pits. • ■ 139 4363 0 0.02 10 2 2.38 ■ 140 4395 0 0.02 11 3 2.39 • I 141 4424 142 4456 0 0.02 11 3 2.39 0 0.02 7 2 2.42 143 4486 0 0.02 11 2 2.39 11 144 4518 0 0.03 15 2 2.40 Shallow Line of Pits. ■ 145 4548 0 0.02 10 2 2.37 Lt. Deposits. I 146 4579 0 0.03 15 3 2.38 Shallow Line of Pits. Lt. Deposits. • 147 4610 0.04 0.04 18 3 2.37 Shallow Pitting. Lt. Deposits. I rat Body Metal Loss ion Body Page 3 Penet I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf J -55 EUE 8RD AB- MEWell: 2T -02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.441 in Country: USA Survey Date: February 03, 2011 I Joint Jt. Depth I'en. Pen. Pen. Meial Min. Damage Profile No. (Ft.) Upset Body % I c ss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 148 4641 149 4674 0 0.03 13 2 2.40 Shallow Pitting. 0 0.03 14 2 2.40 Shallow Pitting. 150 4705 0.03 0.02 11 3 2.40 151 4735 0 0.03 12 2 2.40 Shallow Pitting. 152 4766 0 0.02 10 3 2.41 I 153 4797 0 0.02 11 2 2.41 154 4828 0 0.03 15 3 2.39 Shallow Line of Pits. 155 4860 0 0.02 10 3 2.42 156 4891 0 0.03 12 3 2.41 ' 157 4922 0.04 0.04 19 4 2.38 Shallow Pitting. Lt. Deposits. 158 4953 0 0.02 9 2 2.41 159 4985 0 0.03 12 3 2.40 Shallow Pitting. 160 5015 0 0.02 8 2 2.38 Lt. Deposits. il I 161 5047 0 0.02 9 2 2.41 162 5076 0 0.02 8 3 2.37 Lt. Deposits. 163 5109 0 0.01 7 2 2.41 II 164 5139 0 0.02 10 2 2.38 Lt. Deposits. 165 5171 0 0.02 10 3 2.38 Lt. Deposits. I 166 5203 0 0.03 12 4 2.36 Shallow Pitting. Lt. Deposits. 167 5233 0 0.02 11 2 2.36 Lt. Deposits. 168 5266 0 0.03 16 7 2.35 Shallow Pitting. Lt. Deposits. ■ 169 5298 0.03 0.03 13 4 2.40 Shallow Pitting. ■ I170 5329 171 5362 0 0.03 15 4 2.40 Shallow Line of Pits. 0 0.03 12 2 2.39 172 5394 0.03 0.02 11 2 2.35 Lt. Deposits. 173 5428 0.04 0.04 16 2 2.30 Shallow Line of Pits. Lt. Deposits. I174 5458 175 5492 0 0.03 13 3 2.27 Shallow Line of Pits. Deposits. 0 0.03 12 3 2.40 176 5523 0.03 0.04 18 4 2.39 Shallow Line Corrosion. 177 5556 0.03 0.03 14 3 2.38 Shallow Line of Pits. Lt. Deposits. I 178 5589 0 0.03 14 4 2.39 Shallow Line of Pits. ■ 179 5620 0.03 0.04 17 5 2.35 Shallow Line of Pits. Lt. Deposits. ■ 180 5653 0 0.04 16 5 2.39 Shallow Line of Pits. 180.1 5684 0 0 0 0 2.38 GLM 2 (Latch @ 9:00) 181 5692 0 0.03 14 4 2.40 Shallow Line of Pits. ■ I 182 5723 0 0.04 17 4 2.35 Shallow Pitting. Lt. Deposits. 183 5755 0 0.03 12 4 2.37 Lt. Deposits. 184 5786 0 0.03 14 3 2.36 Shallow Pitting. Lt. Deposits. 185 5819 0 0.03 13 3 2.38 Shallow Line of Pits. Lt. Deposits. I 186 5852 187 5884 0 0.03 12 3 2.36 Lt. Deposits. 0 0.03 12 3 2.36 Lt. Deposits. 188 5917 0.03 0.02 11 1 2.39 189 5949 0 0.02 11 3 2.35 Lt. Deposits. I 190 5980 0 0.03 14 4 2.34 Shallow Pitting. Lt. Deposits. • 191 6015 0 0.03 13 4 2.36 Shallow Pitting. Lt. Deposits. 192 6046 0 0.02 11 3 2.39 193 6079 0 0.02 10 3 2.39 194 6110 0.03 0.03 13 3 2.40 Shallow Pitting. 195 6142 0 0.03 12 3 2.38 Shallow Pitting. 196 6175 0.03 0.03 12 4 2.37 Shallow Pitting. Lt. Deposits. I rat Metal Loss ion BBody ody Page 4 Penet I I s 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf J -55 EUE 8RD AB- MCA/ell: 2T -02 Body Wall: 0.217 in Field: Kuparuk I Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: February 03, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I197 6207 198 6241 0 0.03 13 5 2.35 Shallow Pitting. Lt. Deposits. 0 0.02 10 2 2.40 • 199 6272 0.04 0.04 20 5 2.38 Shallow Line of Pits. ■ 200 6304 0.04 0.03 15 5 2.37 Shallow Pitting. Lt. Deposits. 201 6338 0 0.02 9 2 2.37 Lt. Deposits. I 202 6370 0 0.02 11 3 2.37 Lt. Deposits. • 203 6401 0.03 0.03 15 4 2.35 Shallow Pitting. Lt. Deposits. • 204 6434 0.03 0.03 13 4 2.35 Shallow Line of Pits. Lt. Deposits. ■ 205 6466 0 0.03 13 2 2.40 Shallow Pitting. • I 206 6498 0.03 0.03 13 3 2.39 Shallow Pitting. • 207 6529 0 0.03 15 4 2.34 Shallow Pitting. Lt. Deposits. ■ 208 6563 0 0.03 12 3 2.38 Lt. Deposits. ■ 209 6594 0 0.02 10 2 2.38 Lt. Deposits. ■ I 210 6625 0.03 0.03 14 5 2.35 Shallow Pitting. Lt. Deposits. 211 6658 0 0.02 8 2 2.39 212 6688 0 0.03 14 3 2.40 Shallow Line of Pits. • 213 6720 0 0.03 12 2 2.39 Shallow Pitting. • 214 6749 0 0.02 9 2 2.38 Lt. Deposits. • 215 6781 0.03 0.02 11 3 2.38 Lt. Deposits. • 216 6813 0 0.03 12 3 2.38 Shallow Pitting. Lt. Deposits. ■ 217 6845 0 0.02 9 3 2.40 218 6874 0 0.02 11 3 2.40 I 219 6904 220 6935 0 0.03 15 3 2.39 Shallow Line of Pits. 0 0.02 11 3 2.35 Lt. Deposits. 221 6969 0 0.02 8 2 2.37 Lt. Deposits. 221.1 7000 0 0 0 0 2.35 GLM 3 (Latch @ 2:00) I 222 7005 0.03 0.03 15 4 2.37 Shallow Line of Pits. Lt. Deposits. 223 7037 0 0.02 10 3 2.37 Lt. Deposits. 224 7067 0 0.02 9 2 2.38 Lt. Deposits. 225 7098 0.03 0.03 14 2 2.36 Shallow Pitting. Lt. Deposits. I 226 7131 0 0.04 17 3 2.33 Shallow Line of Pits. Lt. Deposits. ■ 227 7160 0 0.03 12 2 2.36 Lt. Deposits. 228 7191 0 0.02 9 2 2.37 Lt. Deposits. • 229 7224 0.03 0.03 14 2 2.33 Shallow Line of Pits. Lt. Deposits. ■ 230 7255 0 0.02 10 3 2.40 I 231 7287 0 0.03 12 3 2.36 Shallow Pitting. Lt. Deposits. 232 7317 0.03 0.02 11 2 2.38 Lt. Deposits. 233 7347 0 0.02 8 3 2.39 • 234 7377 0 0.03 14 3 2.37 Shallow Line of Pits. Lt. Deposits. I 235 7410 0 0.02 10 2 2.37 Lt. Deposits. 236 7441 0 0.03 12 3 2.37 Shallow Pitting. Lt. Deposits. 237 7472 0 0.02 10 2 2.38 Lt. Deposits. 238 7504 0 0.02 8 2 2.40 I 239 7534 0 0.02 9 2 2.37 Lt. Deposits. C 239.1 7566 0 0 0 0 2.34 GLM 4 (Latch 3:00) 240 7572 0 0.03 12 2 2.33 Lt. Deposits. 241 7603 0 0.02 10 3 2.37 Lt. Deposits. I 242 7633 0 0.02 10 2 2.37 Lt. Deposits. 243 7665 U 0.03 15 2 2.36 Shallow Pitting. Lt. Deposits. 244 7696 0 0.02 11 2 2.38 Lt. Deposits. rat I Metal Loss ion Body Page 5 Penet I • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J -55 EUE 8RD AB- M@Vell: 2T -02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: February 03, 2011 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 245 7727 0 0.03 16 2 2.36 Shallow Line of Pits. Lt. Deposits. 246 7759 0 0.03 12 3 2.37 Lt. Deposits. 247 7790 0 0.02 9 2 2.38 248 7819 0 0.02 10 2 2.36 Lt. Deposits. 249 7851 0 0.02 7 2 2.37 Lt. Deposits. 250 7884 0 0.02 9 2 2.36 Lt. Deposits. 251 7912 0 0.02 10 3 2.35 Lt. Deposits. 251.1 7945 0 0 0 0 2.33 GLM 5 (Latch @ 2:30) 252 7952 0.03 0.03 14 4 2.38 Shallow Line Corrosion. Lt. Deposits. 253 7983 0 0.03 12 2 2.35 Lt. Deposits. 254 8013 0.03 0.03 13 3 2.37 Shallow Pitting. Lt. Deposits. 255 8044 0 0.02 9 2 2.35 Lt. Deposits. 256 8075 0 0.03 14 3 2.36 Shallow Line of Pits. Lt. Deposits. 257 8107 0.04 0.03 15 3 2.36 Shallow Line of Pits. Lt. Deposits. 258 8137 0.03 0.03 13 3 2.37 Shallow Pitting. Lt. Deposits. 259 8170 0 0.03 16 5 2.33 Shallow Line of Pits. Lt. Deposits. 260 8202 0 0.04 18 6 2.34 Shallow Line of Pits. Lt. Deposits. 261 8235 0.03 0.04 18 3 2.37 Shallow Line of Pits. Lt. Deposits. 262 8269 0 0.03 13 4 2.34 Shallow Pitting. Lt. Deposits. 263 8298 0.04 0.03 14 3 2.31 Shallow Line of Pits. Lt. Deposits. 263.1 8329 0 0 0 0 2.34 GLM 6 (Latch @ 1:30) 264 8337 0 0.03 12 3 2.35 _ PUP Shallow Line of Pits. Lt. Deposits. I ' Prat Meta l Loss ion Body I Page 6 I 1 I • • I PDS Report Cross Sections S I Well: 2T -02 Kuparuk Survey Date: February 03, 2011 Field: Tool Type: UW MFC 24 No 10000428 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD Analyst: J. Thompson I I Cross Section for Joint 88 at depth 2797.860 ft Tool speed = 51 Nominal ID = 2.441 I Nominal OD = 2.875 ��— Tool wall area = 97% / �\ Tool l deviation = 54° / I I 1 I I Finger = 23 Penetration = 0.048 ins Line of Pits 0.05 ins = 22% Wall Penetration HIGH SIDE = UP I I I I I • • I s PDS Report Cross Sections ID I Well: 2T -02 Kuparuk Survey Date: February 03, 2011 Field: Tool Type: UW MFC 24 No 10000428 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD Analyst: J. Thompson I I Cross Section for Joint 66 at depth 2110.060 ft Tool speed = 51 Nominal ID = 2.441 I Nominal OD = 2.875 Remaining wall area = 96% / /, Tool deviation = 45° I //V 7 ■ 1 I I I __ Finger = 23 Penetration = 0.045 ins Line of Pits 0.05 ins = 66% Wall Penetration HIGH SIDE = UP I I I I • • 1 PDS Report Cross Sections Well: 2T-02 Survey Date: February 03, 2011 Field: Kuparuk Tool Type: UW MFC 24 No 10000428 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD Analyst: J. Thompson ' Cross Section for Joint 174 at depth 5462.320 ft Tool speed = 51 Nominal ID = 2.441 I Nominal OD = 2.875 Remaining wall area = 98% Tool deviation = 53° I f Minimum I.D. = 2.269 ins Deposits Min ID = 2.26 ins. HIGH SIDE = UP I I • • I PDS Report Cross Sections 11 4 -7 :- .3 S.. I Well: 2T -02 Survey Date: Tool Type: February 03, 2011 Field: Kuparuk UW MFC 24 No 10000428 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 2.875 ins 6.5 ppf J -55 EUE 8RD AB -MOD Analyst: J. Thompson I I Cross Section for Joint 1 73 at depth 5456.770 ft Tool speed = 51 Nominal ID = 2.441 I Nominal OD = 2.875 Remaining wall area = 98% -- - To Tool deviation = 52° / NIL l i 1 II I Minimum I.D. = 2.298 ins Deposits Min ID = 2.29 ins. HIGH SIDE = UP I I I I Conoco Phillips KUP 1 2T -02 n II Angle & MD TD 'J0'ektwre ASSIJW1 FIek 1: (1 Name Viva statue tl hsl f ° ) MD(ttk 6i I Act eta Ittil Edit "e' Ile . 501032007200 I KUPARUK RIVER UNIT I I NJ 55.43 4,700.00 8,890 •., comment 'Edit H1S(ppm) Lab KB. !Edit lEhdDate I ;.; »IGrd Pig F 29/ 1e Edit I/ SSSV: TRDP Last WD: 40.00 929119 ° •i - IY m Io- koI Annotation Depth (mce) ma 1 Ire Armotaton Last Mod... Endm Et11[ Loot Tag: SLM 8,623.0 If1 Rev Reason:TAG, SET PLUG /CATCHER Imosbor 1/31,AJT1 Casing Strings cotng Cesenpton siring 00... string ID... Top 11010) Set Dept it.. Set Depth (TvD)... sting Wt.. Sting... sting Top Ill CONDUCTOR 16 15062 32.0 115.0 115.0 62.50 H40 Oaring Deeeripton String OD_ Sting ID... Top (MB) Set Depth ft.. Set Depth (,Tern... Sting Wt.. Sting... Sing Top Til - . SURFACE (GC) 9518 8.525 31.8 3,555.0 2,775.7 36.00 J-55 BTC Ceiling neecnpton Sting OD.. Sting ID... Top (10.6) set Depth ft.. Set Depth (TJD)... Sting Wt.. Siring ... sting Top ill, PRODUCTION [DC) 7 6.151 30.2 8,8832 6,103.2 26.00 J-55 ETC l 1 I 111 1 1 Tubing Strings I Tubing Calonpeon string on.. string ID... Top Stn! BS Set Depth 7t... TD . not Depth i'... s trin g Wt.. ng... 001 Top ill TUBING 23/8 1.995 0.0 8,420.0 5,768.4 I 4.70 N-00 EUEBrdABMUU CfiaPU TOP, , YtiF Is Other In Hole reline retrievable plugs, yams, pumps, fish, etc.) I Top Cepth Top iTVDi Top hcl (ttRBI (M.' 15•1 i °i Delo t:Mon Comment Bun Cete Olin i 1,817.0 1,704.5 40.66 SAFETI'VLV Camoo TRDP- 1A-S SA 10118/1986 2.312 1.7317 3,196.0 2,562.3 54.15 GAS LIFT CAMCO/KBMG11/DMY /B KU / Comment: EXT PKG STA. 1 2/8/1992 2.371 5,6810 40379 52.16 GAS LIFT CAMCO/KBMGWI/DMWB Kill Comment:EXT PKG STA 2 2/0/1992 2.371 6,998.0 4,863.0 51.30 GAS LIFT CAMCO/IBMG/1 @MY1BK// Commerd:OCr PKG STA3 2,8/1992 2.371 G•D LIFT, �$ 7,566.0 5,218.4 51.3$ GAS LIFT CAMCO /KBMG /1/DM/BKi / /Commene:EXTPKG STA 4 2/8/1992 2.371 3,1% �•� i F 7,946.0 5,457,3 51.26 GAS LIFT CAMC OMB MG/1/DMY /B Kip Comment:EXT PKG STAB 2/8/1992 2.371 8,335.0 5,708.6 4627 GAS LIFT MMHR7/ 8x1.5 /1.5/DMY /RK/ / /Comment: STA6 121411991 2.347 8,358.0 5,724.7 4533 NIPPLE Coenon D' Nipple NO GO 10/18/1986 2.250 8,375.0 5,736.4 45.32 PBR Brown PBR 10/1871986 2.500 8,398.0 5,752.6 44.78 PACKER Brown 11B-1 PACKER 1011811986 2.500 CUP FlRE ... 8,409.0 5,760.6 44.68 CATCHER CATCHER SET ON PLUG 1/182011 0.000 •4C , 323$15 8,4100 5,761.3 44.68 NIPPLE Carnco'D' Nipple NO G0 10/18/1986 1.812 0001 8,410.0 5,761.3 40.68 PLUG SET CA-2 PLUG IN NIPPLE 1/18/2011 0.000 8,418.0 5,767.0 44.65 SOS Brown 10/1811986 1.995 I 8,419.0 5,767.7 44.64 TEL 10/18/1986 1.995 Perforations & Slots EdR G4^, LIFT, 6,996 Shot 13im ropfTD'I Mil rrv•rl [ant Top5TSFO1 itt66/ inb:8) itti(B, Tow [ate I SIS... Type Comment 8,487.0 8,510.0 5,816.0 5,832.5A3,2T -02 10/18/1586 4.0 IPERF 90 deg. phase; 4 "HyperJetI i G• LIFT, , 8,537.0 8,550.0 5,851.9 5,8612 A2, 2T -02 10/18/1986 4.0 IPERF 90 deg. phase; 4' F 'perJet I I o• 8,567.0 8,571.0 5,873.4 5,876.3 A,2, 2T -02 10/18/1986 4.0 IPERF 90 deg. phase; 4" HyperJet l Notes: General & Safely idlt Bid Date Annotrton 1129/2010 NOTE: VIEW SCHEMATIC w /Alaska Sohematio9.0 I GAL CIF «. I11� G• '"8,335 i I I IIP P LE, 8.35E P PP ,13,3:6 I PAD in 8,3#1 IALIiiiibi 8. I ■1P PLE,8,410 ', P LUG, 6.410 DOC, 8.418 TTL,8.419 I Mandrel Details IEdbt - Top Depth Port Top (TVD) Top OD Latsil sl r TRO Run Stn (01/0) (ttk81 WW1 moo Model fin) Sery 4LIVeTDe Tlpe (in) (N Bun con... P EPf, s,.xl�,no I I 3 CAM... KBMG 7 GAS LIFT DMY BK 0.000 0.021&/1992 2 5 CAM... KBMG i GAS LIFT DMY BK 0.000 0.0 2/8/1992 853�a. 3 65::3811..60 ,9976 CAM... KBMG 1 GAS LIFT DMY BK 0.000 0.0218/1992 -- I 4 7,5665 CAM... KBMG i GAS LIFT DMY BK 0.000 0.0 2/811992 IP EPF, - 5 7,945.8 CAM... KBMG 1 GAS LIFT DMY BK 0.000 0.0 218/1992 fi.i5T671I • 6 8,335.0 MMH 27t8sr7.5 112 GAS LIFT DMY RK 0.000 0.0 12/4/1991 I P PO OUrTr7P EGG •, 3trE,883 TV, • s • WED AIASKA SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL Area Injection Order 211.059 Ms. M J Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. `M P.O. Box 100360; Anchorage, AK 99510 -0360 RE: KRU 2T -02 (PTD 18614 10) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order ( "AIO ") 0211.000, the Alaska Oil and Gas Conservation Commission ( AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 2T -02 exhibits a subsidence related surface casing leak at about 350' below pad surface. The Commission finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2T -02 exhibits at least two competent barriers to the release of well pressure. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 2T -02 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. IA pressure not to exceed 2000 psi. 5. OA pressure should be maintained as low as practicable. 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 2B.059 • November 18, 2010 Page 2 of 2 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date remains June 4, 2009 unless CPAI performs new MIT s the well is returned to operation. �L� �a 1 4 at ge, Alaska and dated November 18, 2010. at y Foe ster Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, November 19, 2010 11:17 AM To: (foms2 @mtaon line. net); ( michael .j.nelson @conocophillips.com); ( Von. L.Hutchins @conocophillips.com); AKDCWellintegrityCoordinator; Alan Dennis; alaska @petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Penrose; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; caunderwood; Chris Gay; Cliff Posey; Crandall, Krissell; dapa; Daryl J. Kleppin; Dave Matthews; David Boelens; David House; David Steingreaber; ddonkel @cfl.rr.com; Deborah J. Jones; Delbridge, Rena E (LAA); Dennis Steffy; Elowe, Kristin; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; gspfoff; Harry Engel; Jdarlington (jarlington @gmail.com); Jeanne McPherren; Jeff Jones; Jeffery B. Jones Qeff.jones @alaska.gov); Jerry McCutcheon; Jill Womack; Jim White; Jim Winegarner; Joe Nicks; John Garing; John Katz; John S. Haworth; John Spain; John Tower; Jon Goltz; Judy Stanek; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; Kim Cunningham; Larry Ostrovsky; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley @anadarko.com); Mark Kovac; Mark P. Worcester; Marquerite kremer; Michael Dammeyer; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker @alaska.gov); Paul Figel; PORHOLA, STAN T; Randall Kanady; Randy L. Skillern; rob.g. drag nich @exxonmobil.com; Robert Brelsford; Robert Campbell; Rudy Brueggeman; Ryan Tunseth; Scott Cranswick; Scott Griffith; Scott, David (LAA); Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjrl; Valenzuela, Mariam; Vicki Irwin; Walter Featherly; Will Chinn; Williamson, Mary J (DNR); Yereth Rosen; Aaron Gluzman; Bettis, Patricia K (DNR); Dale Hoffman; David Lenig; Gary Orr; Jason Bergerson; Joe Longo; Lara Coates; Marc Kuck; Mary Aschoff; Matt Gill; Maurizio Grandi; Ostrovsky, Larry Z (DNR); Richard Garrard; Sandra Lemke; Talib Syed; Tiffany Stebbins; Wayne Wooster; William Van Dyke; Woolf, Wendy C (DNR); Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Davies, Stephen F (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Johnson, Elaine M (DOA); Laasch, Linda K (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Shartzer, Christine R (DOA) Subject: co640 (Nikaitchuq OP17 -02), co233 -001 (South Barrow Gas Field), co274 -001 (Walakpa Field), aio2b -059 (KRU 2T -02) Attachments: co640.pdf; aio2b- 059.pdf; co274- 001.pdf; co233- 001.pdf Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793 -1221 (phone) (907)276 -7542 (fax) 1 Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201 -3557 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton 408 18 Street President 6900 Arctic Blvd. Golden, CO 80401 -2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI K &K Recycling Inc. Land Department Baker Oil Tools P.O. Box 58055 P.O. Box 93330 795 94 Fairbanks, AK 99711 Anchorage, AK 99503 Anchorage, A AK 99515 -4295 North Slope Borough Jill Schneider Gordon Severson P.O. Box 69 US Geological Survey 3201 Westmar Circle Barrow, AK 99723 4200 University Drive Anchorage, AK 99508 -4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Cliff Burglin Refuge Manager 399 West Riverview Avenue 319 Charles Street P.O. Box 2139 Soldotna, AK 99669 -7714 Fairbanks, AK 99701 Soldotna, AK 99669 -2139 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 ConocoPhillips Alaska 30. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 N ®v 7 2010 ILI November 15, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 "' Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 213, Rule 9, to apply for Administrative Approval allowing well 2T -02 (PTD 186 -141) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and P q resume the ability to inject MI. If you need additional information, please contact myself or Perry Klein at 659 -7043, or Brent Rogers / Martin Walters at 659 -7224. Sincerely, MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments ConocoPhillips Alaska, Inc. Kuparuk Well 2T -02 (PTD# 186 -141) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 213, Rule 9, to continue water only injection with a known surface casing leak for Kuparuk injection well 2T -02. Well History and Status Kuparuk River Unit well 2T -02 (PTD# 186 -141) was drilled and completed in 1986 as a producer and converted to a service well in May 1992. 2T -02 was reported to the Commission on 04/03/09 with a subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak at approximately 348' below the surface (conductor shoe is at 115' RKB). A passing MITIA to 3000 psi was conducted on 03/03/10, 7/15/10, & 10/07/10. Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests an AA to continue water only injection until the well can be repaired. Barrier and Hazard Evaluation Tubing: The 2 -7/8" 6.5 # J -55 tubing has integrity to the Packer @ 8398' MD based upon a passing MITIA to 3000 psi on 10/7/10. Production casing: The 7 26# J -55 production casing has integrity to the Packer @ 8398 MD based upon a passing MITIA to 3100 psi on 10/07/10. The production casing is set at 8883' and has an internal yield rating of 4980 psi. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing in the upper portion of the hole with an internal yield pressure rating of 3520 psi. The surface casing is set at 3555' MD, was arctic packed in 1986, and has a leak to formation at 348'. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 11/15/2010 Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum). 3. IA pressure not to exceed 2000 psi (40% internal yield). 4. OA pressure will be maintained as low as hydrostatic pressure allows. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 11/15/2010 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regg(ci)alaska.gov: doa .aogcc.prudhoe.bavo_alaska.gov: Phoebe.brooks(rDalaska.gov: tom.maunder0alaska.aov OPERATOR: ConocoPhillips FIELD / UNIT / PAD: Kuparuk/ KRU/ 2T DATE: 10/07/10 OPERATOR REP: Colee /Phillips ASRC AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -02 I Type In'. I N TVD Tubin 1350 1350 1350 1350 Interval 0 P.T.D. 1861410 ITypetestj P Test si Casin 1,250 3,000 2,925 2,900 P/F I P Notes: Diagnostic MITIA in preparation for AA OA 130 130 1301 130 Well Type In'. TVD Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D.1 Type testi I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. Type test I I Test psil Casing P/F Notes: OA Well Tye In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT KRU 2T -02 10-07- 10.xls KUP 2T -02 ConocoP'h Attributes An le & 0 TO a '+ W.Ilbore APIIUWI Flaid Nams Well Statue ProdllnJ Type ') MD (flK0) Acl at. (ftK8) Alaska, Inc. 501032007200 KUPARUK RIVER UNIT IN 55.43 4,700.00 8,390.0 Comment 1423 (pp Date A...II on End Data Kg - Grd (R) Rig Rat.... Data "' SSSV: TRDP Last WO: 40.00 912911986 Well Con - 2Tmatk - 028 12 M SchemaHuai � Annotation Daplh (RKB) End Dab lAnnotation End Date Last Tag: SLIM 8,642.0 3114/2009 IRev Reason: TAG 41262009 Casing Strings String OD String IO set D.ptn Set Deptn (TVD) String wt slang ME cash D.- Iption II ^) 1 (m) ToptR1(8) (RKB) (MS) (Ibam) Grad. String Top Thrd CONDUCTOR 16 15.062 0.01 115.0 115.0 62.50 H CONDUCTOR, 115 SURFACE 95/81 8.525 0.0 3,555.0 2,775.7 36.00 J -55 PRODUCTION 7 6.151 0.01 8,883.0 6,103.1 26.00 J -55 Tubin Stri s SAFETY vLV, StringOD String ID Sat DaDth Set Depth (TVD) String WI String 1 817 Tuhing Descrlptlon 11 ^) 11 ^) Top (RKB) (flKB) (flKB) (IbelR) Grade String Top Thrd TUBING 27/8 2.441 0.0 8,398.0 5,752.6 6.50 J -55 EUE8rdABMOD TUBING 2 318 1.995 8,398.0 8,420.0 5,768.4 4.70 N - EUEB D Cher in Hole 1 Jevre Tubing Run & RetrloVabk F16111, etc. GAS LIFT. Top Depth J.196 (TVD) Top Intl Top (RKB) (RKB) (•) Oasoriptlon Comment Run Dal. ID (In) 1,817 1,704.5 40.66 SAFETY VLV ICamm TROP IA - SSA 1011811986 2.312 SURFACE 3,555 3,196 2,562.3 54.15 GAS LIFT CAMCO/KBMG /1/OMY /BK/!I Comment: EAT PKG STA. 1 21811992 2.371 5,681 4,037.9 52.16 GAS LIFT CAMCOIKBMG /1IDMYIBK/I/ Comment:EXT PKG STA 2 2/8/1992 2.371 6,998 4,863.0 51.30 GAS LIFT CAMCO/KBMG /l/DMY /BK/ /1 COmment:EXT PKG STA 3 21811992 2.371 GAS LIFT, 5 ,681 7,566 5,218.4 51.38 GAS LIFT CAMCOIKBMG1110MY /8K/1/ Comment:EXT PKG STA 4 2/811992 2.371 7,946 5,457.3 51.26 GAS LIFT CAMCO/KBMG /I/DMY /B '/Comment: ERT PKG STA 5 2/811992 2.371 8,335 5,708.6 46.27 GAS LIFT MMH /2 7/8x1.5 /1.5 /DMY /RKI // Comment: STA 6 121411991 2.347 8,358 5,724.7 45.73 NIPPLE Camco'D' Nipple NO GO 10/1811986 2.250 GAS LIFT. 8,375 5,736.4 45.32 PBR Brown PBR 10118/1986 2.500 996 5,7 6, 8,398 52.6 44.78 PACKER Brown HB -1 PACKER 10118!1986 2.500 8,410 5,761.3 44.68 NIPPLE Camoo'D'Nipple NO GO 1011811986 1.812 8.418 5,767.0 44.65 SOS Brown 1011811986 1.995 GAS LIFT. 8,419 5,767.7 44.64 TTL 1011811986 1.995 7.566 Perforations & Slots shot Top (TVD) St m (TVD) Dan. Top(RKB) Stm(RKB) (RKB) (RKB) Zone Data ph... Type Comment GAS LIFT. 8,487 8,510 5,816.0 5,832.5 A -3, 2T -02 1011811986 4.0 IPERF 90 deg. phase; 4" HyperJet 1 7s46 B,537 8,550 5,851.9 5,861.2 A -2, 2T -02 10/18/1986 4.0 IPERF 90 deg. phase; 4" HyperJet II 8,567 8,571 5,873.41 5,876.3 A -2, 2T -02 10/1811986 4.0 IPERF 90 deg. phase; 4" HyperJet I GAS LIFT. 8.335 NIPPLE, 8, 356 PBR, 6,315 PACKER, 6.398 NIPPLE, 8.410 SOS, 8,418 TTL, 8.419 IPERF, 8,487E 510 fPERF, 8.537 -6,550 IPERF. 8.587-8.571 PRODUCTION. 8 883 TD. 11.890 MEMORANDUM TO: Jim Regg ~ ~~~ Z~z ~~ ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector ~ LJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-02 KUPARLTK RIV LJN1T 2T-02 ~ Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv.'~~- Comm Well Name: KUPARIJK RIV LTNIT 2T-02 Insp Num: mitCS090605065358 Rel Insp Num: API Well Number: 50-103-20072-00-0o Permit Number: 186-141-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-02 Type Inj. W~ TVD s~s3 IA ioao zazo ~ z3so Zs~o P.T.D ls6~aio TypeTest -- ~ - SPT Test psi -~~_ isoo , pA lao iao iao iao Interval antTST ~ p~ r ~ Tubing voo i~oo i~oo »oo NOtes: Pretest pressures observed and found stable . E + iC~` 91~~ t- ?s ~ vx:~~ ~~'~Flv' K~~ _ _~d.._ ... /t.P: Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM TO: Jim Regg ~~~ G (~G,ldy P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-02 KUPARUK RIV UNIT 2T-02 Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv .' ~- Comm Well Name: KUPARUK RIV UNIT 2T-02 API Well Number: 50-103-20072-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608115s47 Permit Number: 186-141-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zT-oi TYPe Inj. N~T~ s7s I3 A o - ~i7oo ~- P.T.D 1861a10 TypeTest sPT Test psi Isoo OA T b Izs I7oo _ ~ I Interval aYxTST p~ P ~ u ing i NOtes• Pumped 10 BBLS diesel; IA didn't pressure up. Wednesday, June 10, 2009 Page 1 of 1 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/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907 2458952 .~`2~ 1 J Caliper Report 19-Apr09 2T 10 1 Report / EDE 50-103-2006400 iJZ ~ f ~~ ~ 1~! I ! ~-~v3 ,y+q~~ry n1 /n1 ~' 4L ~~°kiL YJfaa~ ~~19 ' ~ ~ ~a~ / ~ i~ -. - Signed : Date Caliper Report 15-Apr-09 2T-02 1 Report / EDE 50-1 Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (9071245-88952 E-MAIL : WEBSRE C:\Doc,m,en~ and Settu,gs\Ovmer\Desktop\Transmit_Conoco.docx ~i Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, tnc. Well: 2T-02 Log Date: April 15, 2009 Field: Kuparuk Log No.: 7317 State: Alaska Run No.: 1 API No.: 50-103-20072-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD AB-MOD Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log intvl1.: 8,390 Ft. (MD) ' Inspection Type : Buckling & Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the D Nipple @ 8,358' (Drii/er's DepthJ. ' This log was run to assess the cond~ion of the tubing with respect to buckling and corrosive and mechanical damage. Although not presenting a significant I.D. restriction, the caliper recordings indicate slight to moderate buckling from 800' to 8,390' (EOL). The caliper recordings indicate the 2.875" tubing logged is in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations or areas of cross-sectional wall loss recorded. A ring of deposits restrict the I.D. to 2.13" in joint 72 (2,261'). No other significant I.D. restrictions are recorded throughout the 2.875" tubing logged. ' The caliper recordings are partially impaired in this log over the interval 7,000' to 7,500' due to various fingers intermittently sticking in the tool body. The majority of fingers that were working properly in this interval show no significant damage and point to a low probability of any significant damage within this interval. The data intervals with stuck fingers will be apparent in the '3D Data on CD' for this log. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18%) are recorded throughout the 2.875" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> fi%) are recorded throughout the 2.875" tubing logged.. MAXIMUM RECORDED ID RESTRICTIONS Ring of Deposits Minimum I.D. = 2.13" Jt. 72 ~ 2,261 Ft. (MD) No other significant 1. D. restrictions are recorded throughout the 2.875" tubing logged.. ~~v 1~ Field Engineer. Wm. McCrossan Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS;amemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 Correlation of Recorded Darnag S Pipe 1 2.875 in (5.5' - 8378.6') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 2T-02 Kuparuk ConocoPhillips Alaska, Inc. USA April 15, 2009 . A pprox. Tool Deviation ^ A pprox. Borehol e Profil e 1 6 25 753 50 1537 75 2335 GLM 1 3116 O .~ 125 3906 ;_ ~ ~ ._ Z s c '0 150 Q- 4685 a, 175 5478 GLM 2 200 6294 GLM 3 225 7094 GLM 4 GLM 5 7880 GLM 6 263.6 8379 0 5 0 1 00 Da mage Profile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 263.6 • • PDS Report Overview ~~, S~. Body Region Analysis Well: 2T-02 Survey Date: April 15, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Rngers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE SRD AB-MOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 250 Z00 150 100 50 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of'oints anal sed total = 267 pene. 0 109 loss 54 213 158 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /puss pitting corrosion corrosion corrosion ible hole Number of 'oints lama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ta• metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 263.6 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB•MC~D Well: 2T-02 Body Wall: D.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft.) I'cn. Upset (Ins.j Pen. Body (Ins.) Pen. °/~ Metal I oss °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 6 u 0.02 1l) U 34 2 36 U .02 t 6 66 l? t3 3 7 4 98 I I .0 ~ I 5 5 129 ~~ 0.03 13 .3 160 a 0.0 11 ' .36 7 191 U 0.0 1 1 Z 5 Lt De osits. 8 223 11 0.03 12 ~l 3 Lt e osi 9 2 4 U 0.03 I i > 2.32 t. De osits. 10 285 ~) 0.01 ~> .36 11 316 U 0.0 (~ 1 2.36 12 348 ~) 0.02 ~ Z 35 13 379 ~~ 0.01 4 2 2.36 14 410 It 0.02 t3 ~' 36 1 441 ~! 0.02 f3 7 1 473 ~I 0 02 1 tl 2. 17 504 U 0.0 ti ~~ 2.35 18 535 U 0.02 ti ~ .37 19 566 l) 0.01 b I 2.36 20 59 ~? 0.0 ~~ ~ 2.38 1 629 c~ .01 7 ' 2. 7 2 66 U 0.01 7 .3 23 691 O 0.02 11 _' .3 Lt. o its 24 722 a 0.02 11 _' 2.36 2 75 t) t3 26 785 I) 0.03 12 -1 2.35 Bucklin Lt De sits. 7 816 ~) 0.03 13 2.34 28 847 I ~ 0.02 1 1 -1 2.38 9 878 U 0.03 12 ,' .3 Lt. e sits 30 910 0 0.02 1 U ~t 2.38 Lt. osits. 31 941 I~ 0.0 13 4 2 35 32 972 ~~ 0.01 7 t~ 2.37 33 1004 ~) 0.02 1 'I t, 2 3 Bucklin . 34 1035 tl 0.03 14 ~ 2.37 Lt. D osits. 35 1066 U 0.02 11 .34 36 1098 U 0.02 1f1 4 2.37 37 1130 Il .03 1;~ _' 2.37 38 1161 li 0.01 ~ 2.37 39 1192 ~I 0.03 1? ~ 2.36 40 1224 a 0.03 14 (, .38 Bucklin . 41 125 ~l 0.0 14 Z 2. 5 Lt osi . 42 1286 I) 0.04 17 Z 2.37 Lt. a osits. 17 ~1 0.03 14 ~1 t. a osits. 44 1349 ~~ 0.03 14 ~' 2.36 4 13 0 11 0 0 14 I 2.35 Lt De si 46 1412 t) 0.03 12 ~' 2.35 l_t. Ue osits. 4 1443 l1 0.03 Ir 2 35 48 1475 I~ 0.03 1 "> ; 2.36 Lt De osits. 4 1506 ~ ~ 0 0 12 i .37 50 1537 i~ 0.02 II 1 2.35 _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf )-55 EUE 8RD AB-MOD Well: 2T-02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft.) I'r~n. t 11,>c~t Ilns.) Pen. Body (Ins.) Pen. % :Metal I ~>ss "~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 51 1568 (~ 0 03 12 -t 2 37 52 1599 t t 0.03 13 ? .36 53 1631 t t 2 1 1 7 54 166 t) 0.0 11 ~ .37 5 1694 ! ~ 0 03 1 ~~ .36 56 17 5 ~t 0.0 (, I 2 38 c li 57 1756 t) 0.03 1~ I .37 57.1 1788 U 0.03 1 Z 2.38 PUP 57. 1795 U 0 U (~ N A Camco TR P-1 A-SSA 8 1804 U 0.03 15 1 2.36 t. osi 59 1835 t~ 0.0 14 4 2.3 t. a osits. 60 1866 t) 0.03 1 ~3 (, .34 t. D i 61 1898 t ~ 0.03 13 I 2.36 62 19 9 U 0.02 1 l) I 2.34 uck in 63 1960 t1 0.0 12 -1 2.36 64 1992 tt 0.03 15 ? 2.37 65 2023 t~ 0.03 I3 5 2.34 Lt. De osits. 6 054 U 0.03 15 4 5 67 2085 t) 0. 3 13 G 6 2117 U 0.01 U ~ 3 69 2147 (~ 0.02 11 ~' .35 70 2179 (t 0.01 3 I 9 uck in . 7 2209 U 0.0 14 I .37 Lt. De osits. 72 2241 tl 0.03 12 2.13 Rin of De osits. 2' 73 a 0.0 ~) I 2. 74 2303 tt 0.04 1 ti 1 2.36 LL De osits. 75 2335 t~ 0.03 1.1 -1 .40 76 2366 a 0.04 17 s 2.38 77 2398 ll 0.02 11 1 .36 Bu kli 78 2429 U 0.02 11 ~' 2.37 Lt. osits. 79 246 U 0.03 ll I t. e si 80 2490 U 0.02 11 1 2.35 81 522 U 0.02 t3 O 2.38 82 2553 O 0.02 11 2 2.38 83 258 t) 0.02 11 3 34 84 2616 t ~ 0.02 I U I 2.35 Bucklin . 8 647 a 0.02 t3 .38 86 2678 a 0.02 1 I 1 2.34 Lt. De sits. 87 2710 a 0.0 1 ~ 5 2.35 88 2741 a 0.02 1O 4 2.35 Lt. De osits. 89 72 t) 0.0 14 4 2. 5 90 2803 t) 0.02 11 a 2.35 91 ' 834 t) 0.02 I 1 -t .37 92 2866 t ~ 0.03 1 ~ 4 2.38 Lt. De osits. 3 2897 t) 0.02 l U I 2.37 ucklin 94 2928 tt 0.02 1U _' 2.36 95 2960 U 0.0 12 ~ 2.36 96 2991 (~ 0.03 12 2.35 Lt. De osits. 97 302 n 0.03 12 2.37 98 3054 a 0.02 11 .38 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB-MOD Well: 2T-02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft.) I'~~n. 1 )I>set (In::.j Pen. Body (Ins.) Pen. °~ Vlet,d I ~~ss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 9 30 5 t t 0.02 1 1 I 2. 4 Lt. e si 100 311 (~ 0.04 1 t3 ~ 2.34 t. a osits. 101 3147 l~ 0. 3 1:3 2.37 101.1 3178 t i 0 U (~ N A GLM 1 La ch ~ 3:30 102 3186 t ~ 0 01 ~1 36 Buc lin . 103 3217 t ~ 0.0 l U Z .3 Lt. De s' 104 3249 t~ 0.01 (~ ~l .38 105 328 t) 0.03 14 ~ .32 106 3311 t) .01 ' 34 107 3342 t I 0. 3 13 I 2.33 t. D osi . 108 3373 a 0.03 13 2 35 109 3405 t ~ 0.0 1 I ~ 2 36 Bu kin . 110 3435 t~ 0.02 Ill U 111 3467 tJ 0.03 12 d .38 11 3498 It 0.0 11 t 2.36 113 531 U 0.03 I Z 1 2.35 t. sits. 114 3562 U 0.02 ~~ 2.38 1 5 3592 t~ 0.03 I~ .37 ucklin . 116 36 4 t) 0.01 7 _' 2.37 Lt. a osits. 117 3656 c l .02 1 1 -1 2. 7 118 3687 a 0.03 12 I .30 Rin of De si . 119 3717 ct 0.03 14 I 2.36 120 3749 U 0.02 I 1 .37 Lt. De sits. 121 3780 a 0.02 11 -1 2.36 12 3 11 tt 001 -~ .38 Lt. Ue osits. 123 3842 t I 0.03 I <1 -1 2.36 Lt De osits. 124 3875 tl 0. 3 12 2. 7 Lt. De osits. 125 3906 U 0.01 (~ _1 2.38 Bucklin . 1 6 3937 U 0.03 l I 2.36 127 3968 l~ 0.03 11 i, 2.34 128 3999 l~ 0.02 11 _' 2 5 129 4030 t ~ 0.02 1 U I 2.38 130 4062 t) 0. 1 ~ I 4 131 4093 l) 0.02 ~~ _' 2.40 Bucklin . 13 4123 U 0.03 1 ? 5 2.36 133 4154 tt 0.02 £3 ~ 2.38 134 4186 U 0.01 4 I 2.38 135 4217 t~ 0.02 9 2.38 136 4249 ~) 0.03 1 i ~ 2.36 137 4280 0 0.02 11 4 2.38 Buc lin . 3 431 U 0. 2 fS 5 .40 139 4342 l~ 0.03 1 1 2.37 140 4374 U 0.03 15 U 2.37 141 4404 t) 0.02 1 I 2.38 142 35 t) 0.03 14 2.36 143 4467 U 0.02 ti ~ 2.37 Bucklin . 144 98 a 0.02 11 4 .37 145 4530 a 0.02 F3 _' 2.36 Lt De osits. 146 4560 t I 0.01 7 .34 147 4592 ti 0.01 6 -1 2.38 Lt De osits. _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB-MOD Well: 2T-02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft) i'en. (/lxc~t (Ins.) Pen. Body (Ins.) Pen. % 'vlc~t.~l I cs~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 462 3 0 0.0 1 U 2.3 149 4654 O 0. 2 10 1 Lt D sits. 150 468 U 0.01 6 -1 2. 6 B ckli 151 4717 i) 0.01 ~ I 2.37 152 4749 t1 .01 (~ 2.3 15 4779 U 0. 3 14 =l 5 154 4811 (~ 0.01 7 .37 Lt De osi 155 4842 ~~ 0.02 1 I t~ 2.35 t De osits. 156 4872 t 1 0. 3 14 _' 2.36 . D osi ts. 157 4904 (~ 0.01 4 _' 2.37 ucklin . 158 4935 t~ 0.03 15 5 2.39 5 4966 t I 0.03 12 ? .35 lt. D o its 160 4998 t ~ 0.01 6 Z 2.3$ 1 1 0 u 0.02 1 tl .3 162 5061 U 0.01 b I .36 Bucklin . 163 5092 t) 0.01 t> 1 2.3 164 512 ~) 0.03 Li ; 2.37 165 51 6 u 0.0 8 _' .37 166 5186 t ~ 0.03 14 ~i 2.35 t. a sits. 167 21 U 0. 15 ; 2.35 Lt. De osits. 168 5250 U 0.04 17 _' 2.29 Bucklin Lt. sits. 169 5281 (1 0.04 17 7 2.34 t. a osits. 170 5315 t_I 0.03 1 G ~ .35 Lt. sits. ~, 171 5346 t ~ 0.02 1 1 ~' 2.32 Lt. De osi ts. 172 5 80 t? 0.02 I 1 I .36 173 5412 (~ 0.01 4 ~ 2.38 LLD osi ts. 174 5444 t ~ 0.03 14 :' 2.36 Lt. e o i 175 5478 t) 0.03 15 4 2.36 Lt. De osits. 176 550 t ~ .0 I U 4 2. ucklin . 177 5542 U 0.03 14 6 2.31 Lt. De osits. 178 5 5 U 0.03 1 3 !, .36 t. e o i 179 5607 tl 0.03 15 I 2.31 Lt De sits. 180 56 9 t) 0.03 15 4 .37 Lt. si 180.1 5671 t) 0 t) U N A GLM 2 Latch ~ 9:00 181 567$ U 0.03 15 !, .34 Lt. De osi 182 5712 a 0.03 12 -1 2.33 Bucklin Lt De sits. 183 5743 t) 0.03 12 5 5 t. D osi 184 5774 (I 0.03 14 3 2.34 Lt. De osits. 185 5807 U 0.03 1~ 2 4 Lt. D os' 186 5840 U 0.04 17 2 2.33 Lt. De osits. 187 587 (1 0.04 16 ; 2.3 t, a osi 188 5905 U 0.03 12 (, 2.36 Lt De osits. 189 5936 a 0.03 I i ~ 2.32 Bucklin L.t. De o its. 190 5971 tl 0.04 17 t> 2.33 Lt. De osits. 1 1 6 02 t! 0 0 I ~! 2.3 I_t. De osits. 192 6034 i ~ 0.03 15 I 2.37 193 067 ! ~ 0.03 I -! 2.35 lt. De osits. 194 6100 tt 0.04 1 ~ i ~ 2.38 LL De osit . 195 6132 t I 0.03 1 ~G ; .35 Bucklin . 196 6165 t ~ 0.02 ~1 I 2.37 _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-SS EUE 8RD AB-MOD Well: 2T-02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft.) Pen. Ulxc~l (Inti.j Pen. Body (Ins.) I'c~n. °ib ~1c~t,il I uss ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 197 6198 t) 0.03 15 -1 2.36 Lt. e i 198 6229 t) 0.02 1O 2. 3 Lt. De osits. 199 6261 ~? 0.04 I ti 5 2 36 t. e o its. 200 6294 U 0 04 1 ES _' 2.34 Lt. De its. 201 6327 U 0.02 11 2.37 Bucklin . 202 6360 ~) 0.04 I t; r, .32 Lt. e osits. 20 6392 (~ .03 16 -1 2.36 l.t. De osits. 204 6425 U 0.04 18 (> 2. t De osits. 05 455 U 0.04 17 2.2 Lt e o its. 206 6488 a O.D3 16 ~ 2.33 Lt. De os ts. 7 521 t 1 0.03 I (i 3 L. osi ts. 208 655 U 0. 4 I i 3 .36 Lt. De sits. 2 9 6585 a 0.03 I t 2.34 Lt. De osi ts. 210 6616 t) 0.01 4 2.37 Bucklin . 211 6648 ~) 0.02 8 I .39 12 667 ~ 0.01 6 I .39 213 6710 U 0.01 4 ~' 2.37 214 674 U 0.02 c) 3 .37 215 6773 O 0.0 8 4 .39 c I'n . 216 6804 tt .0 10 1 37 217 6835 a 0.02 7 4 218 8 6 t) 0.01 7 2.39 19 6898 (~ 0.0 8 4 .37 220 6929 t~ 0.01 ~ ti 2.35 Bucklin . 1 69 t~ 0.01 I 2.41 221.1 6993 t) 0 u i~ N A GLM 3 Latch Position N A 222 7005 U 0.00 ~ 1 9 T m ra 'I St ck Fi ers. 223 7030 t) 0.01 4 ? 2.36 Tem rari) Stuck Fin ers. 4 70 D U 0.02 7 i 2 35 Tem rari) k Fin ers. B cklin . 2 5 7094 t) 0.02 10 E, 2.34 Tem raril Stuck Fin ers. 2 7125 U 0 3 12 4 0 em rari Stuck F'n ers. L De sits. 227 7157 11 0.02 c) ~' 2.29 Tem raril Stuck Fin ers. 22 7187 t) 0.03 1 Z ~ .3 Tem rari) S ck Fin ers. L . osits. 229 7214 U 0.03 I "t 2.37 Tem rari) Stuck Fin ers. 30 7248 O 0.0 ti 1 em rari) Stuck Fin ers. Bucklin . 231 7279 l) 0.03 13 ~ 2.38 Tem rari) Stuck Fin ers. 32 7310 U 0.0 I 1 _' 2.3 m r ril St ck Fin er . 233 7344 l) 0.02 1(1 ? 2.39 Tem raril Stuck Fin ers. 234 7 75 O 0.0 c> ~' 2. Ter rari) Stuck Fines. 235 7404 t~ 0.01 5 2.38 Tem rari) Stuck Fin ers. Bucklin . 236 743 (~ 0.03 12 > 4 Tem rari) t ck Fin ers, t. e o 'ts. 237 7469 U 0.03 15 ~ 236 Tem oraril Stuck Fin ers. 238 7498 U 0.03 1? t 2.30 Tem aril Stuck Fin rs. Lt. De osits. 239 7530 a 0.01 6 Z 2.37 Tern rari) Stuck Fin ers. 39.1 7563 (1 0 0 t) N A GLM 4 Lath ® :0 240 7569 t) 0.01 ~ 1 2.37 Bucklin . 241 7599 a 0.02 10 I 2.35 242 7631 U 0.01 U 2.38 43 7664 U 0 0 £3 ~} .36 244 7693 U 0.02 ~3 > 2.37 '~ Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE SRD AB-MOD Well: 2T-02 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 15, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Ulsc~t (In5.) Pen. Body (Ins.) Nen. °i~ ~~~i,~l Iosti `;'~ Min. LD• (Ins.} Comments Damage Profile (%wall) 0 50 100 245 7726 ~~ 0.01 (~ Z 2.39 uckli . 246 7755 ~~ 0.02 ~) 2.39 247 7785 ~> 0. I 1 I 2 35 248 7 18 ~) 0. 11 .3 249 784 U 0.01 (, 1 .35 250 7880 (1 .O1 4 I 2.36 u kli 251 7911 a 0.01 4 ~ 2 251.1 7943 t) 0 U i~ N A GLM 5 tch ~ 2:30 52 7950 t) 0.0 ~) 2.35 5 7982 l) 0.02 ti 4 .36 254 013 i~ 0.01 6 4 2.38 B klin 5 8041 U 0.02 11 ~ 2.35 256 8073 ~ ~ .03 1 ~ 5 2.34 2 7 8104 a 0. 3 14 c, 2. 7 2 8 8 37 O 0 3 15 1 2 3 Bu I'n . 259 8170 t) 3 15 2 2.34 260 8204 n 0.03 15 ~' .35 2 1 8 37 i~ 0.03 12 -1 .36 62 8268 a 0.04 18 .34 Lt. a osits. 263 830 U 0. 3 13 a .34 cklin t. De s'ts. 263.1 8331 i) 0 U u N A G 6 a ch ~ :30 263.2 8339 t) 0.02 Ic1 •1 2.34 PUP 263.3 8358 ~) 0 U U 2.25 a co'D' Ni I No Go 263.4 8360 ~) 0.00 2 I 2.39 PUP 6 5 373 i~ it ~~ 2. 0 Brown P 263.6 8379 a 0.01 6 ~' 2.42 PUP _ Penetration Body Metal Loss Body Page 6 ~~ PDS Report Cross Sections tiu Well: 2T-02 Survey Date: April 15, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: l4 Tubing: ___ 2.875 ins__ 6.5 ppf )-55 EUE 8RD AB-MOD Analyst: C. Waldrop Cross Section for Joint 72 at depth 2261.493 ft Tool speed = 43 Nominal ID = 2.431 Nominal OD = 2.875 Remaining wall area = 100 Tool deviation = 61 ° Finger 14 P-ojection = -0.146 ins Ring of Deposits Minimum I.D. = 2.13 ins HIGH SIDE = UP Cross Sections page 1 ConocoPhillips Alaska, Inc. KRU 2T-02 ~i zr-o2 API: 501032007200 Well T INJ An le TS: 44 d 8473 sssv SSSV Type: TRDP Orig Com letion: 9/29/1986 Angle @ TD: 43 deg @ 8890 (1617-1616, oD:z.a7s) Annular Fluid: Last W/O: Rev Reason: FCO, POST FCO TAG Reference L Ref L Date: Last U ate: 1222/2005 Last Ta : 8529 TD: 8890 ftK6 Last Ta Date: 12/6/2005 Max Hole An le: 55 d 4700 Gas L"` i ndellDummy Casin Stri -ALL STRI NGS valve 1 Descri lion Size To Bottom TVD Wt Grede Thread (s19s-3197, ~ a 75o CONDUCTOR 16.000 0 115 115 62.50 H-40 : . ) SUR. CASING 9.625 0 3555 2776 36.00 J-55 PROD. CASING 7.000 0 8883 6103 26.00 J-55 GasLlft Tubin Stri -TUBING 11df~~""'my valve 2 Size To Bottom TVD Wt Grade Thread (5681-5682, 2,875 0 8398 5753 6.50 J-55 EUE 8RD A6-MOD oD:a.75o) 2.375 8398 8420 5768 4.70 N-80 EUE 8RD AB-MOD Perforations Summa Gas Lift Interval TVD Zone Ste s Ft SPF bats T Comment ~ ndreUDummy Valve 3 s99a x999 ~ 8487 - 8510 5816 - 5832 A-3 23 4 10/18/1986 IPERF 90 deg. phase; 4" HyperJet I ( - , oD:a.75o) 8537 - 8550 5852 - 5861 A-2 13 4 10/18/1986 IPERF 90 d hase; 4" H rJet e9• P YPe II Gas LiR 8567 - 8571 5873 - 5876 A-2 4 4 10/18/1986 IPERF 90 deg. phase; 4" HyperJet I ~"d~~D ~: Ga s Lift M andr elsNalve s (75s6-7567, oD:a.75o) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv CmM 1 3196 2562 Camco KBMG DMY 1.0 BK 0.000 0 2/8/1992 1 Gas Lirt 2 5681 4038 Camco KBMG DMY 1.0 BK 0.000 0 2/8/1992 inctevDunmy 3 6998 4863 Camco KBMG DMY 1.0 BK 0.000 0 2/8/1992 vaNeS 7sas 7sa7 4 7566 5218 Camco KBMG DMY 1.0 BK 0.000 0 2/8/1992 ( - ' oD:a.75o) S 7946 5457 Camco KBMG DMY 1.0 BK 0.000 0 2/8/1992 6 8335 5709 MMH 2 7/8x1.5 DMY 1.5 RK 0.000 0 12/4/1991 1. Extended PKG in Sta. 1 thru 5 cas L"1 i rnteWunm Other s ui .etc. - LRY y valves De TVD T Descri Lion ID (633s-a33e, 1817 1705 SSSV Camco TRDP-IA-SSA 2.312 oD.a.75o) 8358 5725 NIP Camco 'D' Ni le NO GO 2.250 8375 5737 PBR Brown 2.500 Nlp 8398 5753 PKR Brown HB-1 2.500 (8358-8359, 8410 5761 NIP Camco'D' Ni le NO GO 1.812 OD:2.675) 8418 5767 SOS Brown 1.995 8419 5768 TTL 1.995 PBR (8375-8376, OD:2.875) T B G U IN (0-8398, OD:2.875, ID:2.441) PKR (8398.8399, OD:6.151) NIP (8470-8411, OD:2.376) TUBING (8398-8420 , OD:2.375, ID:1.995) SOS (8418-8419, OD:2.375) Perf (8487-8510) PeA (8537-8550) PaA (~` 7-x`71) RE: KRU DS2T Suspected Sure Casing Leaks • Page 1 of 2 Regg, James B (DOA) From Sent: To: Cc: Regg, James B (DOA) Friday, April 03, 2009 3:47 PM ~~,~~ ~ ~ 3l~`l 'NSK Problem Well Supv' K~~~~ z 1-c~ ~ t4 Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31 /2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The to onsisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin draftin a li tions for administrative ap royal to continue water only injection with a known surface casing leak (OAx orm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Sure Casing Leaks • Page 2 of 2 the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf » « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf » « File: 2T-15 TIO Plot.pdf » « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « File: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Weil Name ~ ~ ~-? Notes: End Date 4/1 r20G9 Days 90 Start Date 1 /1 /2009 wHP Annular Communicaton Surveillance 140 4000 OAP - _ -. -- -- - WHT 3500 -- 120 3000 - - - - - - ---- -- - --- - 100 2500 - 80 ~ 2000 Q - . 60 1500 - - -- 40 1000 20 500 0 0 Jan-09 Feb-09 Mar-09 Apr-09 4500 ~DGI __------ _ _ - ------ ~MGI 4000 PWI 3500 ~SWI a 3000 ~gLPD m 2500 0 2000 ~ 1500 1000 500 0 Jan-09 Feb-09 Mar-09 Apr-09 Date • • V 6Q f;~ I ConocoPhillips Alaska, Inc. sss~ (1817-1818, OD:2.875) Gas Lift andrel/Dummy Valve 1 (3196-3197, OD:4.750) Gas Lift andrellDummy Valve 2 (5681-5682, OD:4.750) Gas Lift andrel/Dummy Valve 3 (6998-6999, OD:4.750) Gas Lift andrel/Dummy Valve 4 (7566-7567. OD:4.750) Gas Lift andrel/Dummy Valve 5 (7946-7947. OD:4.750) Gas Lift andrel/Dummy valve 6 (8335-8336, OD:4.750) NIP (8358-5359. OD:2.875) PBR (8375-8376. OD:2.875) TUBING (0-8398. OD:2.875. ID:2.441) PKR (8398-8399. OD:6.151) NIP (8410-8411, OD:2.375) TUBING - (8398-8420, OD:2.375. ID:1.995) ~ SOS - (8418-8419. OD:2.375) Perf (8487-8510) Perf (8537-8550) Perf (8567-8571) u KRU 2T-02 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Kf?4t? 6/7/D 1 P.I. Supervisor ({ DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-02 KUPARUK RIV UNIT 2T-02 Src: Inspector t.? \4\ ,lb FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: ..<7 !? P.I. Suprv ~ Camm Well Name: KUPARUK RIV UNIT 2T-02 API Well Number: 50-103-20072-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 1417 I 3 Permit Number: 186-141-0 Inspection Date: 6/2/2007 V Rellnsp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-02 Type Inj. G TVD 5753 IA 2060 3000 2940 2940 I P.T.D 1861410 TypeTest SPT Test psi 1500 OA 210 210 210 210 I Interval 4YRTST P/F P / Tubing 3900 3900 3900 3900 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ./' SCANNED jUN Z 02007 Wednesday, June 06, 2007 Page 1 of 1 ) ) State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg ? P.l. Supervisor 'h~ qli~DS" Chuck Scheve Petroleum Inspector DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -02 KUPARUK RIV UNIT 2T-02 /\~\ {~~ FROM: Src: Inspector Reviewed By: P.I. Suprv .."51312- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-02 Insp Num: mitCS050812185538 Rei Insp Num: API Well Number: 50-103-20072-00-00 Permit Number: 186-141-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. w~iï-I 2T-~Õ2'Type [nj. T-wr-TVD TS753-í IA --T~5Õ---¡'--26õõ----'------2520 "---'-r-25OO---¡ ------1"-------- ,---~--------···--------------',-·+-------æ--- --n----G----~-----..L---- L___ --t---.---~.----- '---r, -.,.------- P.T. I 1861410 TypeTest I SPT I Test psi 1438.25 OA I 120 I 140 I 140 . 140 I ______.L.___,,_.___.._-"-_.-L______ ---··---L·'-r- .------¡-...----t--.--..L----..¡---- "...L.______._ Interval 4YRTST P/F P Tubing 2250 -- 2250 I 2250 ! 2250 ¡ I _.______________ _._____. ,_______________... .___________ .._.____..,__,__. _~_______.._...L_____ _ _---1. __ ___________~___n __________.---'n_.__.___ Notes: Pretest pressures observed for 30+ minutes and found stable. ,r" {" 11~ \i\. \ '~,1 ::r;.' ~\ (' 'C. P ''',)f,l ,]"\ 5 '1t,~ '\ )~,~, ,J ,) L. ,I r·· t'rlel\':: ;!I, \~~ ¿ u ',} oJ Wednesday, August 17,2005 Page I of I Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 7!¿7 09/24/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color <'ilf -OL{ 2-3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 C,S -OS, 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 1-t- e~8 2B-12 10802934 INJECTION PROFILE 09/10/04 1 ~ If- I ~ 4 I 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 l~t- ~5 18-10 10922467 PRODUCTION PROFILE 09/21/04 1 () ". ~5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 ra.£-O z. ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 i ~'Í - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 I ~2. -,~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 1 2. - if 1 H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2 -Cìlo 1A-14 10802938 INJECTION PROFILE 09/13/04 1 ( Lý-- 070 2H-03 10802945 INJECTION PROFILE 09/18/04 1 1<&21-05' 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 '1-1- Oef'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H'2.. 3H-09 10922468 INJECTION PROFILE 09/22/04 1 I 'if6- ltil 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 '9()-I(,~1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~ '-..-r' S'8~ I. k1'~ ~ÇANNE!J NOV IJ & DATE: /{ f¿ Please sign and returle copy of this transm ¡Ital to Beth at the above address or fax to (907) 561.8317. Thank you. MEMORANDUM TO: Julie Heusser Commissioner THRU: Tom Maunder-~'"[ ~ P.I. Supervisor -,,~,~-~"¢~\ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 24, 2001 SUBJECT: Mechanical Integrity Tests Phillips 2T Pad 2T-02, 05, 11, 15, 16 KRU Kuparuk NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2T-02 Type lnj.! G ] T.V.D. I 5753 I Tubingl 3800 I 3800 I 3800 I 3800 I lntervall 4 P.T.D.I 1861410 Type testI P I Testpsil 1438 I CasingI 1950I 2525I 2525I 2525I PIE I P Notes: WellI 2T-05 I Type Inj. P.T.D.I 1881440 IType test Notes: We,,I2T-11IType,nj.I s I~.v.~. I~0 I TubingI 1200 I 1200 I 1200 J 1200 IlntervalJ 4 P.T.D.I 1860970 ITypetestl P I Testpsil 1330 I CasingI 1600I 2190I 2190I 2190 I PIEI P Notes: WellI 2T-15 I Typelnj. I G I T.V.D. 15470 I Tubing 13650 13650 13650 13650 I lntervall 4 P.T.D.I 1860450 Imypetestl P Imestpsil 1369 ICasingI 750 I 23251 23251 2325 I PIEI P Notes: WellI 2T-16 I Typelnj. I S I T.V.D. I "00 I "00 I'nterva'J 4 P.T.D.I 1860460 ITypetestl P ITestpsil 1374 ICasingI 1300I 2490I 2450I 2450I P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 2T Pad in the Kuparuk river field and witnessed the 4 Year MIT on wells 2T-02, 2T-05, 2T-1 l, 2T-15 and 2T-16. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: _5 Attachments: Number of Failures: 0 Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT KRU 2T Pad 6-24-01 CS.xls 6/25/01 MICROFILMED 9/~ ~/00 DO NOT PLACE ANY' NEW MA TERiA UNDER THIS PAGEL ARCO Alaska, Inc. Post Office E~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 4, 1992 Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION ~J 2T-02 Conversion to Water Inj. 3A-05 Fracture 3F- 1 0 Perforate 3F- 14 Perforate ~ 3K-07 Conversion to Water Inj. 3Q-07 Perforate If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer CC: J. D. Bolling KOE1.4-9 ATO-1196 (w/o attachments) (w/o attachments) RECEIVED MAY - 6 199~ Nas_Ifa .Oil & Gas Cons. CommiSsion Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany AR38-6003-C STATE OF ALASKA ALA~. , OIL ANDGASCONSERVATIONCOMMIS~,.,.,N REPORT OF SUNDRY WELL OPERATION 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate Repair well Plugging Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 402' FSL, 556' FWL, Sec 1, T11N, R8E, UM At top of productive interval 1597' FNL, 1244' FWL, Sec 2, T11N, R8E, UM At effective depth 1427' FNL, 1076' FWL, Sec 2, T11N, R8E, UM At total depth 1383' FNL, 1033' FWL, Sec 2, T11N, R8E, UM 12. Present well condition summary Total Depth' measured 8890 true vertical 6107 feet feet Plugs (measured) None 6. Datum elevation (DF or KB) RK~ 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-02 9. Permit number/approval number 86-141 10. APl number 50-103-~007~ 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8800 true vertical 6042 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production' Liner Perforation depth: Length Size Cemented 265 SX CS II 920 sx AS IV & 375 sx Class G 790 SX Class G & 175 sx AS I 80' 16" 3523' 9 5/8" 8853' 7" measured 8487' - 8510', 8567' - 8571' 8537' - 8550' true vertical 581 5' - 5831', 5851' 5860', Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 8403' Packers and SSSV (type and measured depth) Brown HB-1 @ 8398', Camco TRDP-1A-SSA @ 1817' Measured depth 115' 3555' 8883' True vertical depth 115' 2775' 6102' 5872' - 5875' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) MAY -6 1992 Alaska 0il & Gas Cons. C0rnrnissi0~ Treatment description including volumes used and final pressure Conversion from producer to water injector, i 2.- ! ~ '0I I Anchorage 14. Reoresentative Daily Averaae Production or Injection Data - OiI-Bbl Gas-Mci' Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 515 bbl 466 mscfd 11 bbl 1040 psi 292 psi Subsequent to operation 2749 bbl 850 psi 1400 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector x Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'- ['~ ~ Title Form 10-404 Rev 09/12/90 Date-~/~'/~ ~-- SUBMIT IN DUPLICATE .%-..-::~:~s-, : !.D =;.-,: ,.. I'~; ..-~ ..... ,=. OR.. , ~R ..,=, ~o,"'.'~"' , · ?' PRODUC ON NELL STA'T%:'3 'OAS t_iFT S]'ATUS i ::" i D" '; P TT WC H2~ CS'.] C 30 '~54 '24 97 33 =.0 124 83 0 279 I" I. 312 !2.4 266 !24 106 7 ~46 ~4 14~ 60 271 ~24 ~ 950 200 -) [ :P}O 250 20 1000 tO00 0 1200 700 3 [ 550 600 12 i 150 ~ 5 1450 379 I0 i I00 900 O 1460 950 31 '.~, ~.~ ., N..,; ."-.H 'r--3MP ?.ETER '-,'GLS ;_ { 0 0 ,%3 0 30 0 O (~.. 'r'; ~'[ .z. [ D · 5 7: '_. -' 0 ' 0 ;:' ©0,'5'..3 0 ., 0-' 0 0 OOC;O 0 0 9 ~ 9 0 0".300 67.5 0 0 0000 0 0 ~99 0 0000 '} 14278 0 0 0000 '3' 0 0 0 0000 0 0 0 0 0000 0 OT;L3' 31 '75 0 W Z S E 0 T L N A k. E T 2 B SW 4 B SW 5 A SW 7 A SW : A SW · B SW IN,JECTION WELL STATUS ALLOW ACT 7" iQ" .INJ INJ TT CSO CSQ · PSI PSI OEO CHK PSI PSI. . 2500 1400 && 56 850 50 2500 2400 &O 70 500 0 2500 2100 63 56 750 175 2500 2200 &2 50 800 0 2500 2100 &3 30 700 150 2500 I100 Og 14 600 0 2500 1100 && 12 879 250 .INJECTION VOLUME S/I C .- INd INO H M 0 ME'TER VOLS VOLS R I D READINO 8BLS MMSCF S N E 358~ 2749 0.000 0000 0 3139 1791 0.000 0000 0 98574 1078 0.000 0000 0 79010 1390 0.000 0000 248~3 1601 0.00.0 0000 0 ~6132 133~ 0.000 0000 0 73~97 985 0.000. 0000 0 ]TALS' SWI' 10933 0 = 10e;33 O. 000 RECEIVED WAY - 6 1992 Alaska Oil & Gas Cons. Gom~tSSiOt~ Anchorage ~.2../ U LJ U U L.~ CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.~ TELECOPY: (907) 276-7542 JUNE 9, 1992 WATTy STRICKLAND ARCO ALASKA IN. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 85-0163 81-0071 81-0096' 81-0104 86'0141 KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT 'KUPARUK RIVER UNIT KUPARUK RIVER UNIT 3J-2 lA-2 lA-4 lA-5 2T-2 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION APRIL 29, 1992 IN A CONVERSATION I HAD WITH YOU . THESE WELLS'HAD 403'S'SUBMITTED IN NOVEMBER OF 1991 TO CONVERT OIL TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS W~RE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S ONCE THE CONVERSION WAS COMPLETED.~ THIS MATTER NEEDS TO BE CORRECTED SO OUR FILE .ARE CURRENT AND UP TO DATE. . . WOULD 'YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS . STATISTICAL TECHNICIAN C: ROBERT'CRANDALL SR PETR GEOLOGIST -~.,'4, prinzed on rec¥c:ed p..w. er £' '~' :;'~. i~]. · AL/~KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Al~,~k~,, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension_ Stimulate _ Pull tubing _ Variance ×_ Perforate _ Other_ 5. Type of Well: Development Exploratory Service 4. Location of well at surface 402' FSL, 556' FWL, Sec 1, T11N, R8E, UM At top of productive interval 1597' FNL, 1244' FWL, Sec 2, T11N, R8E, UM At effective depth 1427' FNL, 1076' FWL, Sec 2, T11N, R8E, UM At total depth 1383' FNL~ 1033' FWL, Sec 2~ T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measure true vertical Length 80' 3523' 8853' 889O 6107 8800 6042 Size 1 6" 9 5/8" 7" feet Plugs (measured) feet None feet Junk (measured) feet None Cemented 265 sx CS II 920 sx AS IV & 375 sx Class G 790 sx Class G & 175 sx AS I 8567'-8571 ', 5851 '-5860', Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8537'-8550' 5872'-5875' measured 8487'-8510', true vertical 5815'-5831', Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 8403' Packers and SSSV (type and measured depth) Brown HB-1 @ 8398', Camco TRDP-1A-SSA @ 1817' 6. Datum elevation (DF or KB) RKB 117' 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-0~ feet 9. Permit number 86-141 10. APl number 50-103-20072 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3555' 2775' 8883' 6102' FCEIVED ¢~,a$J'~8.0ii & ~a$ C0r~s. C0rnmissi ~ch0raG,~ 13. Attachments Description summary of proposal X_ Detailed operation program _ BOP sketch _ Request a waiver to continue injection "as is" (Wellbore schematic attached). 14. Estimated date for commencing operation ~//~;Z. 15. Status of well classification as: Oil __ Gas ~ Suspended ~ 16. If proposal was verbally approved Name of approver Date approved Service Water I n!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned C- ~J ' ~ Title Operations Engineer FOR COMMISSION USE ONLY Date 2/,Z,.~ /~-- Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test _ Subsequent form require Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL SIGNED BY 10- Commissioner Date ~ 'l ct ' ~1 .,3 SUBMIT IN TRIPLICATE Application for Sundry Approval for 2T-02 Suspected Tubing 7" Casing Communication Attachment This application is to request a waiver in order to continue injection into Kuparuk Well 2%02. The well passed a state-witnessed pressure-type Mechanical Integrity Test on December 7, 1991, and was converted to water injection on December 15, 1991. A small tubing to casing communication was noted after placing the well on injection. After an extensive trouble shooting effort (see attached well service reports), it was determined that a small leak between the tubing and casing was located between the upper "D Nipple" and the packer (8360' to 8397'). This leak is of such a small magnitude that it would be difficult to detect the precise location with E-line. The trouble shooting effort indicated no deterioration in the casing integrity to the formation. Another in- house Mechanical Integrity Test was conducted and once again Well 2T-02 passed. Future plans for Well 2T-02 are for continued water injection while pressures are monitored. .... '~ -'. 't;:,, 1 f.) q'3 '~'~,'!,"-'..h: 2., ..... ',~--' Anchora~ WELL 2T-02 INJECTOR APl # 501032007200 SURFACE LOCATION: 402' FSL, 556' FWL, SEC 1, T11N, R8E, UM TOP KUPARUK: 1597' FNL, 1244' FWL, SEC 2, T11N, R8E, UM ALL DEPTHS MD-RKB (TUBING SPOOL RKB=28.3') TREE: CIW GEN 1 5000 PSI SPUD: 9/15/86 COMPLETION: 10/19/86 16": 62.5# H-40 @115' 9.625": 36# J-55 @ 3555' CAMCO D NIPPLE: 2.250" ID BROWN PBR: 2.5" ID BROWN HB-1 PKR: 2 7/8 X 2 3/8 XO: CAMCO D NIPPLE: 1.812" ID 2 3/8 X 2 7/8 XO: SHEAR OUT: BROWN @ 8358' @ 8375' @ 8398' @ 8403' @ 8410' @ 8418' @ 8419' C4 A3 A2 A1 7": 26# J-55 @ 8883' VOLUME: 0.0383 BBL/FT PBTD: 8800' L SSSV: CAMCO TRDP-1A-SSA 2.812" ID @1817' GLM1: GLM2: 3196'/1.0" CAMCO KBMG/0.1875 GLV 5681'/1.0" CAMCO KBMG/0.1875 GLV GLM3: 6998'/1.0" CAMCO KBMG/0.1875 GLV GLM4: 7566'/1.0" CAMCO KBMG/0.25 GLV GLM5: 7946'/1.0" CAMCO KBMG/0.25 GLV GLM6: 8335'/1.5" MMH/ 0.25 GLV 2.875" 6.5# J-55 ABMOD, XO @ 8403', VOLUME: 0.00579 BBL/FT VOLUME LESS IPC: 0.00574 BBL/FT 2.375" 4.7# N-80 ABMOD, TT @ 8419', VOLUME: 0.00387 BBL/FT VOLUME LESS IPC: 0.00383 BBL/FT 8487'-8510' 4 SPF, 90 DEG 8537'-8550' 4 SPF, 90 DEG 8567'-8571' 4 SPF, 90 DEG HOLE ANGLE ACROSS KUPARUK = 43 DEGREES MAX. HOLE ANGLE = 55 DEGREES @ 4800' VOLUME TO TOP PERF = 50.7 BBLS REVISION: 2/25/92 ,HCO AlaSl(a, inc. {~ ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Compar~ ..~BDT CONTRACTOR oT~5 Freeform 7 _MARKS FIELD - DISTRICT- STATE OPERATION AT REPORT TIME DAYLS/ I DATE 0'7oo o7H5' oq$o /6zt, 1650 I 7oo i7to 17Lo ~o ?~; 7" ~,~.¢ .~ --~ ,7. 3 7c: 2 5 CO ~00 f,~; 2. 5'Yo /IOO ?~; Z3oo rs' 173o %7~/5- i~oo IZ~o ~; 2-300 £., l ?~>o 2 i , ~ O0 2.0_5'0 ! ~ (~0 z0zo knots j Sigll'd ,~~-l~ ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor Visibility I Wind Vel. Report °Fl °F miles I I cOde,r- ._ ~ELL .,:RCO Alaska, Subsidiary of Atlantic Richfield Compa~ ~BDT 8500' ~ONTRACTOR MEMARKS FIELD - DISTRICT- STATE OPERATION AT REPORT TIME P, bp,d WELL SERVICE REPORT IDAYS DATE 070o o~3o o ffo 0~ 1055- ~o~ 37_oo ps; 7" /z (~o __ 2_Z~o f~; IH 0o fS.~o i ~5c~ I~155 ~,05~ p~>,re ,...? v,,~,,'~,~ 3 2-o0 7" Z I oo t ~1 05" 2 7o0 9,~55" P~'f~3 -~? tb~ +o ~15'o ps; 7" Weather Report CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Subsidiary of Atlantic Richfield Compar~. WELL SERVICE REPORT ,yELL ~BDT CONTRACTOR tEMARKS IFIELD - DISTRICT - STATE iDAYS :DATE ,',/S'~:, /~,,~'~:~ / ' O/- OPERATION AT REPORT TIME .~lt;liuli~ts'~ b+,~ bsv ec6r' ~'771 ~-''' dc.' Z~or'pSZ~'t. [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK We'thM' I TemP'Report "F Chill F'ct°r I Vl'ibilltY°F, mile. Iwind vel' knot. lSign~ /4fl~..,U ~la~Ka~ IRC. Sub$iaiaz'y of Atlantic Ri¢~fielcl WELL [PBDT I FIELD- DISTRICT-STATE CONTRACTOR o"r',~ ~ ('~~J OPERATION AT REPORT TIME 5'U$,~.~.,~ WELL SERVICE REPOt iDAY? ,3ATE Ol-'Zo- 97. REMARKS 17:1~ 17:{/.5 ca.: 2';sc:v.3~'zS'/'4. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weatl~ Rll:m~ milee [ Wind Vel. - . ,.RCO Alasl(a, nc. Subsidiary of Atlantic Ricl~field ComoaD~'----- ,VELL "")NTRACTOR LITT/.E RED SERVICE. 5 c3DT ! FIELD · DISTRICT - STATE i DAYS DATE OPERATION AT REPORT TIME 5~SPENDED REMARKS ~ Ti~OuI~L~$HOOT CS6- TB~ COMMu,~JIC.~TIO~ ~ ~ /~50 ~. /~s/~ rs~ : /540 ~/ 7 ~ c~4 · /Tlo ~/ Bz£E"~ ,D/£,SEL oFF 7'" ¢5G... T&G P£E35U/~E ,,~L30 DEC...L/~E"D. /400 7'z~' //4o ~/ T"cs~' /5oo ~/ I~./~ 116o 15/o 14. 5o 1160 1.52_o Pu~P uP 7" c$4 ~ DtEJE'I.. . . . T,B~G ?£ES~U,eE ,4L~O /NCleEAdEZ). /550 T84' z/zF ~t ?"c,,s4'2900 /650 2¢x.¢0 z T ~ O 'THAT DATE). DIFFERENTIAL PEE$$/.Ii~E$ ON ]/~5/9Z. ~ TODAY 170 Phi. '7" cs~ ~s L~A~EZ> ..ri ~~ ~ w~ DIsP~C~ ~/5 ~ /~ ~eOH ~585'~ 5855' Wb. 5u~gc~ RV cern< ~ ~L~ ~ ~ ~. ¢6' 25OD$ z.8 TL [--~ CHECK THIS BLOCK IF: SUMMARY CONTINUED ON BACK WeatherReport Temp. OF IChill FactOr visibility°F miles Iwind vel' knots iSigned ~H(.;U AlaSKa, Inc. Subsidia~ of Atlantic Richfield Compa'-~ ,NELL ZT- Z.. i® FIELD- DISTRICT- STATE CONTRACTOR OPERATION AT REPORT TIME n~:MARKS WELL SERVICE REPORT JDAYS ~ DATE 150~ ~,ej, oN 0/0592-- 7-86 ~ 2_000 9~ 7"CS~ (~ 50~ /'5/ 0~00 OIO~Z. 2940 1500 0/ /4 ~) ?... Z.900 3040 /045 0/i¢97.. Z ? O o .5000 Z~LE'Eb P~E,5,.51,//~E C~FF T~ ~) /HONITDi~.. . ~ I~OO 751 Ok) FLO~/LI~E) //OD o//5~Z.. TZSC~ ~ I$00 ~/ ~I" c$~ ~ Z95'~ /// ~ " ZlTfJ Zeoo 1150 " ZSZ5 Z850 114.5 " Z675 ZSZO /Z~o " 2675 28Z,0 IZIE " Z, G75 282,0 /zz5 ~sa ~ /600 7" c~ ~ z770 /415 ~oo ~ ~o /~o ~ ~ /5~ 7" c~ ~ /660 /5/~ /525 /68o /65o /~ /?/o [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility I Wind Vel. Report °F ~F miles I knots ISigned ,4RCO Alaska, Inc.~.~ Subsidiary of Atlantic Richfield Compar' ,NELL 2."r'" ~ ~SDT ~,ONTRACTOR L. ITTL£ J~Eb ~VC. FIELD - DISTRICT- STATE OPERATION AT REPORT TIME 5L/$PF_NDED WELL SERVICE REPORT IDAY/S REMARKS TEST '7" CSG /530 ~l~O~ Z/FILE £='--b P4/IP ~Ct6K. 7'E37' LI~E.$ 5000 P$1~ OK. E, LE~:b TSq P~E85U£e- FROM F_Z, O0 P~l ~ PSi ¢$c~ ~ zzoo ~t 17/5' /SZ~ z$zo ( ~J771W, ID~8 DEC,/../~E FR, DA4 17~o I~O z7~o /8~ ZoOO $o~0 PuM~E~) ~P ~" 88~ ~b L/L' /7.. r'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. IChill Factor I Visibility Report °F ~F miles Wind Vel. Signed knots Subsidiary/of Atlantic Richfield~Company WELL ,PBDT z r- 2. i 8goo CONTRACTOR FIELD - DISTRICT- STATE OPERATION AT REPORT TIME dob e;o~p~1~ WI-LL 61'-RVICE REPOR'I' DAYS DATE i / ~MARKS . . CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report ARCO Alaska, Inc. S,aos,char7 of Atlantic Richfield Company WELL SERVICE REPORT WELL -- __ CDP~ (RACTOR REMARKS PBDT FIELD - DISTRICT - STATE OPERATION AT REPORT TIME IDAYS j DATE 32So pi -2" l~i'o CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I Visibility j Wind Vel. Signed Weather Temp. i Chill Factor ] Report °F i °Fi miles i knots j ~,~ ARCO Alaska, Inc - Subsidiary of Atlantic Richfield Compa~ WELL FIELD- DISTRICT- STATE JOPERATION AT REPORT TIME WELL SERVICE REPORT J DAYS ~ DATE / I /:~ o7~ / Z.'F- 2., NTRACTOR /-IL.' REMARKS IPBDT -'-- INITIAL IRJECT/ON WELl.. M i 7" - [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility I Wind Vel. Report °F ~F miles knots lsigned ARco Ala~ska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1990 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action 2T-02 Conv to Wtr Inj 3A-02 Waiver to Continue Wtr Inj Anticipated Start Date November, 1991 November, 1991 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer CC: J. D. Bolling M. C. Pearson KOE1.4-9 ATO-1196 ATO-1176 (w/o attachments) (w/o attachments) R£CEIV D NOV 4/aska Oil & 6as Cons, _ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS ~VATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging _ Change approved program ..2L Pull tubing _ 2. Name of Operator 15. Type of Well: Development X ARCO Alaska. Inc. Exploratory _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 402' FSL, 556' FWL, Sec 1, T11N, R8E, UM At top of productive interval 1597' FNL, 1244' FWL, Sec 2, T11N, R8E, UM At effective depth 1427' FNL, 1076' FWL, Sec 2, T11N, R8E, UM At total depth 1383' FNL~ 1033' FWLr Sec 2r T11N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8 8 9 0 feet true vertical 61 0 7 feet Operation Shutdown _ Re-enter suspended well _ Time extension Stimulate Variance _ Perforate _ Other_ Plugs (measured) Effective depth: measure 8800 feet Junk (measured) true vertical 6 0 4 2 feet None 6. Datum elevation (DF or KB) Casing Length Size Cemented Structural Conductor 8 0' 1 6" 265 SX CS II Surface 3523' 9 5/8" 920 sx AS IV Intermediate & 375 SX Class G Production 8 8 5 3' 7" 790 SX Class G Liner & 175 SX AS I Perforation depth: measured 8487'-8510' ,8567'-8571', 8537'-8550' true vertical 5815'-5831', 5851'-5860', 5872'-5875' Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 8403' Packers and SSSV (type and measured depth) RKB 117' Kuparuk River Unit 8. Well number 2T-02 feet 9. Permit number 8(~-141 10. APl number 50-103-20072 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3555' 2775' 8883' 6102' RECEIVED NOV 2 1 1991 Alas!~ 0ii & Gas Cons. G0mmiSSi0n ~ch0rage BOP sketch Suspended Brown HB-1 ~ 8398'~ Camco TRDP-1A-SSA ~ 1817' 13, Attachments Description summary of proposal J~ Detailed operation program _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: November, 1991 Oil m Gas __ 16. If proposal was verbally approved Name of approver Date approved Service Water In!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C.{J,). ~ Title Operations Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval N,~ Plug integrity_ BOP Test_ Location clearance__ . J /~-~/-,~ ,.['-'~ Mechanical Integrity Test _ Subsequent form require 10-/--/,-'~''~''I,''-~;I''', i: ~ '~'''~J~ ' Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL S!GNED BY I,qNNI~ C. SMITH Commissioner Date li - L~"'/~ ~ j SUBMIT IN TRIPLICATE A history matched reservoir model of Drill Site 2T and the undeveloped acreage to the North and West was used to help optimize the waterflood conversion strategy. Several 2T/2U scenarios were investigated. The optimum waterflood configuration for each scenario includes 2T-02 as an injector. Model results also suggest converting 2T-02 expeditiously will maximize oil recovery. RECEIVED NOV 2 1 1991 J[Jas~ Oil & Gas Cons. Commissim-~ ~nchorage EELL 2T-02 PRODUCER APl # 501032007200 SURFACE LOCATION: 402' FSL, 556' FWL, SEC 1, T11 N, R8E, UM TOP KUPARUK: 1597' FNL, 1244' FWL, SEC 2, T11N, R8E, UM ALL DEPTHS MD-RKB (TUBING SPOOL RKB=28.3') TREE: CIW GEN 1 5000 PSI SPUD: 9/15/86 COMPLETION' 10/19/86 16": 62.5# H-40 @115' 9.625': 36~ J-55 @ 3555' CAMCO D NIPPLE: 2.250" ID BROWN PBR: 2.5" ID BROWN HB-1 PKR: 2 7/8 X 2 3/8 XO: CAMCO D NIPPLE: 1.812' ID 2 3/8 X 2 7/8 XO: SHEAR OUT: BROWN A3 @ 8;37s' @ 8,.'.'.'.'.'.'.'.'.~e' @8403' @8410' @8418' @ s41g' A2 A1 7': 26# J.55 @ 8883' VOLUME: 0.0383 Bi~L/FT L SSSV: CAMCO TRDP-1A-SSA 2.812' ID @ 1817' GLMI' 3196'/1.0' CAMCO KBMG/O. 1875 GLV 5681'/1.0' CAMCO KBMG/0.1875 GLV GLM3: 6998'/1.0' CAMCO KBMG/0.1875 GLV GLM4: 7566'/1.0' CAMCO KBMG/0.25 GLV GLMS: 7946'/1.0' CAMCO KBMG/0.25 GLV GLM6: 8335'/1.5' MMH/ 0.25 GLV 2.875' 6.5~ J-55 ABMOD, XO @ 8403', VOLUME: 0.00579 BBI../FT VOLUME LESS IPC: 0.00574 BBL/FT 2.375' 4.7# N-80 ABMOD, TT @ 8419', VOLUME: 0.00387 BBL/FT VOLUME LESS IPC: 0.00383 BBL/FT 848T-8510' 4 SPF, 90 DEG 8537'-855O' 4 SPF, 9O DEG PBTD: 856T-8571' 4 SPF, 90 DEG HOLE ANGLE ACROSS KUP~ = 43 DEC.4:tEES MAX. HOLE ANGLE = 55 DEGREES @ 4800' VOLUME TO TOP PERF = 50.7 BBLS "RECEIVED REVISION: 5/7/91 NOV t 1 199t 0il .& 6as. Con~s. Com~'~ss'~o" DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kupamk River Unit 2T Well Data WALTER J. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 ,,/. .. ,- 7, .-~ Ix~- ~ I 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 T11N 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, cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 1991 Alaska Oil .& Gas Cons. CommiSsion Anchorage ,";, ,,' pru~ted on rr_:'cyclgd paper RO. BOX 7034 DIVISION OF OIL AND GAS ANCHORAGE, ALASK,~ August 5, 1988 1 DEPARTMENT OF NATURAL RESOURCES 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 11 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 staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 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 v~ell 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 further notice. Sincerely, _jcames E. Eason irector cc: C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR STATE OF ALASKA - 0 R 16 IN A ALASKA uiL AND GAS CONSERVATION CC,,wMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-141 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20072 4. Location of well at surface ~'~ i!?~ii ?! i! i~-~' i i~*~i!' i~!~'~ !~i ~ii!~i ~ ~'.~..;:~, ii 9. Unit or Lease Name 402' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ;~ ~ i.i~ ~.-:(~ ~ Kuparuk River Unit i ' At Top Producing Interval ~,.t-%_~-: ~ ~.~ i~ ~:~,~ i .... ;~ '~ iJ "'~ ~;, i.~ lO. Well Number 1579' FNL, 1244' FWL, Sec. 2, T11N, R8E, UM ~';~-~ _'-~ ~ ~?:~' ~?~i?"ii ~ ..... ~:~ ~ ~i ~ ~' ~'~"~''~[~ ~\# 2T-2 At Total Depth ~:_-~i ~¢".~;.~ ~i!!i" ~ ~'i~ '~' 11. Field and Pool 1383' FNL, 1033' FWL, Sec 2, T11N, R8E, UM ~ ~. ~ ~ ~ ~: ~ -~ Kuparuk River Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool RKB 117'I ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 09/14/86 09/25/86 12/23/86'I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafr°st 8890'MD 6107'TVD 8800'MD 6042'TVD' YES I~ NO [] 1817' feet MD 1550' (Approx) 22. Type Electric or Other Logs Run DI L/SFL/SP/Cal/CNL/FDC/GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SIZE SETTING DEPTH MD CASING ,WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 265 sx CS II 9-5/8" 36.0# J-55 Surf 3555' 12-1/4" 920 sx AS IV & 375 sx (;lass G 7" 26.0# J-55 Surf 8883' 8-1/2" 790 sx Class G & 175 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTN SET (MD) PACKER SET (MD) 2-7/8" 8420' 8398' 8487'-8510'MD 5815'-5831'TVD 8537'-8550'MD 5851 '-5860'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8567 '-8571 'MD 5872 '-5875'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug f/1414'-1446' 320 sx AS I Perforated w/4 spf, 90~ phasing 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~ E j~' ~2 ~' ~ ~'~ Al~sk~ Oil & ~chora~r~ *Note: Drilled RR 09/29/86. Well perforated & tubing run 10/18/86. Form 10-407 WC2: 07: DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. ~ ' 30. GEOLOGIC MARKEF~S FORMATION TESTS ,. .. :. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8471' 5804' N/A Base Kuparuk C 8483' 581 2' Top Kuparuk A 8483' 5812' Base Kuparuk A 8628' 5916' 31. LIST OF ATTACHMENTS Addendum (dated 01/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ Associate Engineer /- ~/-~7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12/23/86 2T-2 Frac'd "A" sand perfs 8487'-8510', 8437'-8550' & 8567'-8571' in 10 stages per 12/17/86 procedure using diesel, Musol, gelled diesel, 100 mesh sand & 20/40 mesh sand. Press'd ann to 2510 psi w/diesel. Tst ins to 8000 psi; OK. Production Pmp'd: Stage 1: 30 bbls diesel w/5% Musol @ 1BPM, 2800 psi Stage 2: 49 bbls diesel, 2 BPM, 2800 psi Drilling Pmp'd: Stage 3: 75 bbls gelled diesel pad, 20 BPM, 5160 psi avg, 6800 psi max Stage 4: 50 bbls gelled diesel pad, 20 BPM, 4150 psi Stage 5: 22 bbls gelled diesel w/ I ppg, 100 mesh sand, 20 BPM, 4170 psi (915# 100 mesh sand) Stage 6: 100 bbls gelled diesel, 20 BPM, 4100 psi Stage 7: 36 bbls gelled diesel w/3 ppg 20/40 mesh sand, 20 BPM, 4450 psi Stage 8: 45 bbls gelled diesel w/ 6 ppg 20/40 mesh sand, 20 BPM, 4870 psi Stage 9: 22 bbls gelled diesel w/8 ppg 20/40 mesh sand, 6020 psi, 20 BPM Stage 10:48 bbls gelled diesel flush, 6000 psi, 5550 psi, 20 BPM Pmp'd 18,289# 20/40 & 100 mesh in formation leaving 741# 20/40 mesh sand in csg & tbg. Load to recover 456 bbls of diesel/gelled diesel. Job complete @ 1839 hrs, 12/23/86. Drilling Supervisor ' Da~e Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 October 22, 1986 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60072 Well: 2T-2 Field: Kuparuk, Alaska Operator: E. Sellers Survey Date: October 13, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Enclosures Sincerely, NL SPERRY-SUN, INC. District Manager NL Sperry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARCO ALASK'.'A ~, 2T-2 KUPARLIK VEI-x I I CAL_ SECT'I (iN (":AI_C:I...II_ATEI) ALANG Cl.. Oi::;I_II:~E: TRLIE ~tJB~SEA COIJRSE MEAg;I_IREI] VERT' I C:AL VERT I _.AL I NC:I_ I NAT I ON SF'IS. RRY-SUI',I WEI....L ::: .... r'~v.r...~ I Ixl('~ F:FUqF:'ANY F'AGE 1 A Ix.I C I".10 R A C; E A i... A :!""; I< -(-./ INC,, DATE OF SURVEY OCTOBER COMF'LITATI ON DATE BOSS oYR JouOPIC SURVEY OCTOBER 14, 19~5:6 JOB NUMBER AK-BO-6Op~i~i:i . ELEV. F"r'. DE:iZ, TFi ..... .,.:. C :300 5o 0 600 700 80 ('~ 10 ()0 1.1. O0 1 '2(") 0 1 ._-,£ 0 1400 1450 1 !:-] (~) 0 1600 1 '7 C) 0 iL--:O() 1900 2000 22 () C) :2: ::: C) 0 ....... 2500 :2'70C~ .5'.q. _ 1 Iq ._,'='1. :30 W 1.67 A'-.? 1_. . (")'7 N i:'~24 . .-=;:::: ..... W 1 1~;4 . :212 :2 8 C) 0 .. 2:3:32,, 81 2:2:15.81 54 55 N .50.5() 14 0.66 742. '72 :i::;F'E!:RF;:Y-SI...II',I WI.".'i;I....l_ F.:;I_II-RVI.:.i:Y I IqG CFIMI::'ANY (~,!:;!!::'.ik!EP.(!.'.LE.; .~..~:)L~:.k-':J.;!"::E ......................................... ARCO ALASKA, INC, 2T-2 COMPLITATZON DA'T'E KI..IF'ARI_IK C~C:'I'FiBER .1. 4 ~":';~"- A L... A S K A Vli::]RI"I CAI._ SECT I ON I:':(:i/.C I...II._A"FFD ALF)IqG (::I....O:.-.-..;I...IF:;~Ei: F'AGE' 2 DATE OF SURVEY OCTOBER 13, i986 BOSS GYROSCOPIC SURVEY ,..!OB NUMBER KEL..i:,.y. B!J.;~;H !_NG.. E.[.L..-...F....';~...... ......... .-7:' ....... !...!.Z..,..(;!.(..! FT, OPERAT'OF;:--.E, SEI_LE'R$ TRUE MEA.:, JRED VERT I. iS:Al_ D E F' 1" H D E P T H ,.LB .,~,EA CCILIRSE CI"'II_IR SE ~._11.:11~-- [.. E G TOTAl-. VERT !:CA L ........... '..J:.'.~!~i.!._...~.~[~_i~ .~_!._-.I_N.. ........... J~!...I....R..E !'~i..~ ~_!..--!.N... .... :_:;EVER I TY REC:TANF~UI_AR COORD I NATE~i:!':?:!i~?::~:::?:i:.:!:!!~[R T.I~:.~.L ...... DEFiTH D E:F.~ I"11N DE:C'~F?E:.E S DEG/10(-) IqFiF? I"H / SCILrl"H .E A:..::;T / W.E:.:'E.i.T.. ............................ L:.;F..i:C T' :[ Olxt 2:390 ,, :3:1. '2'2 '75: ,, i:: ] 54 52 N 50. 5 C) N A. (),..':, '794 ,, '7,:':, N 1051.26 W 1 :}:: i_..Z.._~.L: ...... 244 '7 '-?'::~ 2330 99 .. 4 40 N F; (') '-":~ ..... ';.:' ?; () 5 ':::,:::: ":'""":"::' ................. :., ,: ............... 4. 2 ..... .. ....... :, ::~ o. '76 N i 17 t'-,, ,-? 7 W 14,:, O, 49 '::' ~,"-, 4:2:4 2447.34 54 8 N 50. 19 W O, :2:2 '-?.=, 0 68 N :1. ":":' 9 41 W 15/-, 1 .~:; 5:: "' ...... ". . .............................................................. ' ............................................................... :'.._]'.'_ ....... ". .................................. _~__~'-~.:.' ' ......... ,.:v_-__-':_~ ..... "__.-_. ~.. ':::' A 7':'::. 3:1. 2506 ,, :31 5:5: :::-': 4 N 50 ,, 1 () W (). 5'7 1 ()(')2.43 N 1:30 :l. 41 W 1. ,,.,'-.,,.1. 2. 1:1. :;;:;682.66 2565./_-,5 5:.::: ::::7 N 5(). 1 ':? W O. ()9 1 ():": 4. ()1 N 1 :'-':6:':'.:. 20 N 1. 722.42 2:::(") 2.4 () .:'-:'/- ':' ~'; 4 F).. "' '::~':' i N :'"';0 . 19. N (").. . i 3 1 i ._.=;f_,. 6='.J N 1486 . i o'-' 1,4 1882. ....._,'-'=' :2::::6:2 A :3 '-' .... = 6 :52 '- ] ........ ..... ~/4 ..... :3 . 54 N .:,L 19 W 0,,11 1:.::0'7 75 N 15:4'7 51 W 19Al 91 292.7:. 13 2 :.'-)06. 1 "" · .:. ....... :,,:, N 49.89 W (...-., 6 1 ..:._,,:,. o ¢, N 1 ~, t>,: .... ,._, W .,:. 041..-,., ............................................................................................................................................................................................... .~..~.,, 29',iii:/-I-. 14 2 :iii: 6 '7. 14 ._,'='.,:"'"' ':J.. Iq 49 ,6'i:) 1,4 O. !::;_ 1 1 :L:: .1. O. 0:2 N J 669 ,0,".- W 21 ..... ';::' ('~. :3'7 '::',(')45, 83 '2'?28 ,, :'-'i: :.'-.':5:1 4() Iq Zl.,.':,. 50 N 2, ."_"!;'7 1 :.':':.,:':,2.5,":, N 1 727.64 W 2 '1 '?::::. 6,=! 2, ()'76, 4 :.-:', 2':? 59, 4-',E: 52 44 N 4:3. () N 5, 9 :.'.-i: 1 ;:ii: 9~"~. 62 N :/'755 · 44 N :;22:3'7,64 :3106 · ff';'~) .,,.'.-.' ¢*.. A_ ':,... 5. '-?. ._.=;._,':' 12 N :::_ t::'*.. 8'..'? N ..5.04 J 420...,.:, ~'-' N 1781 . ,_,,.':'.=, 1,4 ~.~'"" '-' -7:,·/' =:, '-y :3 J 6._"5.96 :304 :--:. 96 5:3 ._,'-,_",'-' N :::: ...../", . !'";*"~ N 2 · 84 14 CS :"4 .7'7 N 1 ,':3:31 · 60 gl .,,.:,._'-"-":s 4.02 :3224· ~ O. :3.1. 07.10 54 :55 Iq :'-': 5,60 ::.-'..:::;!:',ii!: i ....... ::i :1~'/_-, 4 ....... -.,.J _. . 1 ;- 1 <':,. :24 N l ':*";'7. :31 N 2509. :3.'.. 3:338.04 :32 '.:-" 1· · 04 5 =' _ ...... '-' ~:'''''-' .... , 22 N :::/-, :.30 W 0 50 1/_-,82. :--:2 N 1'775. 6:_:: W .-. ...... :,/. 64 ....................................... 3394. 'i.-?O 32'7'7.90 55 19 N :36.6(} N O. :2...=,, 174:_::.'i78 N 2024..55 W 2c'-,6/_-,. 09 :.:--:4~ 1 71 .... '"';":';':"' ......................... ~i~ ...... .:-'7 .................. ::; ...... ~': ............ - . .:,.:,.:,4· 71 . ,., .,:A N .-,A.._,( ) gl 0 .... 15 1 :.:: 15 09 N 2073. =/, :, gl 2744 .61 :--:, .... ?; c)'-? .03 :q ::: 92 .0 .... ::: 54 :36 N :::'.-? .10. W 2 . .,..'-.' 9 1879 .83 N ":'.,. 1 '-'~,_,,'--' 76 gl 2823 .29. :2:567.41 :2:450.41 53 56 N 41.10 W 1.75 1941,9'2 N 2176.04 W 2902, 10 ..................... 5:/-, '2/-.. :3.L:; () 9 8 ::'_:: 53 ':" _ ................. ..... N ,-1- 4. :::'::~ W :3 17 2000 7:2 N '2'25:(') :::F-i W 2'? 81 (') 1 29 () 0 3000 :31 ~:)() 3200 ::3 :.':'.-: 00 :3 400 3500 :>) 600 5:700 :2:800 3900 .40()0 4. <'-)!5 "410 O' 4200 4 :_::00 4 4. 00 45 () 0 46 0 4700 4800 4900 .................. 50 00 5100 5:200 2. 'F: 6 2 055, 4. 4 N 2':.2:39, 02 W 3 060.2:4 :3.0 ~ 2: I 0,':,, 4 8 N 2350. :35 W :':', 1-1. O. :26 2', 60 21 .=;,':' ,:,4 N 241 .=;, 79 W :::22~) 64 ·...., ....~ · ,,~ · · ........... ::;:.~:~,:~.:., 74 2197.21 N 24:3:2:. 07 W :3:300, 56 ::: :'! :!: ::'::~ 69 22:::7.96, N '..--:551.5/_-, W :3379.9::' 0.6.4, :22'7'7.7 0 N :;:-- A 20. ! :2 W :3458.74 O. 48 ':.:: 316.5'3:' N 268'.--:. 85 W 35:37. :;it (") ARCO AL..A.=,J,. A, I NC, 2]"-2 I<UPARUK A L A :=; K A SF'EF:;:F?Y..-.-S.'i;LIN Wl!i"'l....I .... SI...IRVEY I NG C:(')MF:'ANY F:'A(3E :'"i', A N E: I-"10 R A G E A L A S I.:.'.' A DATE OF SURVEY OCTOBER COMPL.i]"AT!ON DA'TE BU ...... GYROSCOF'IC ;:,L!RVEY .. ¢' in , ~ '.,. ,,,fi)l: :.:r::F., OCTOBER 14, 1 '.:~)86 ,_lOB NUMBEER AK-B :J-60().~;~:;:;.,,~i,i,::: KELLY B!JSHINF-~ EI.:E~.,. ....... -7.'. ....... !..,..!._7_.....!)0 F'"I", 0 P Ii.-:; I::~ A T 0 R - E ,, '..-E; E L L E R'..=_; ............................................. V ER T I C A I._. :":i; E C"I- I 0 N C A I.... (":I...IL.'~'~E'D' "A L Cf N (3 (": L O'.iii;I...IR E ] RL E. :$LtB~;$EA COLIRSE C'-'I i~''-''~' L,_ ~.:,r_ DOG-LEG - "" I ' '' I .... '" - ,-.- r, MEA.z, LRED VF.."RT IC:AL. VERT:ICAL INC:LINA'I"IAN [ IREf_.I ION .:,EVERI"rY [)E F' Ti::i ............ r.)~::F, ]"/--.I .................... £iEF' TH ............................... ~]~'i":..-'%-"H' ]-." gi ................... ~ii r:.~!'i~'i-:i'[~]'~i ........... r.:¢=.: (:~ / 1 oo ...... · ._,,::, (.) 0 .5900 /:, 0 00 4..-':' ._,':' 4 . .:, 6,10() 4296.7'."..~ 6 :;ii: () 0 4. :3 !!5'F:;' 74 6:300 4422. ::2:'::.> 6400 4485. :iii: ,/=,5C)0 "= ''~- 4 ..... 4 :~. 12 /:, A .... A () 4/:, 1 '-'~:. :--~.. '::~.. 6700 467/:,. 25 6800 4 ¥ :38.5'7 6'.:.? () (-) 48 () 0.88 7000 4 :i-:: 6:2:. 4 :.3 7100 492/:,. 2/:, 720c) 4 t:.~ :.=.:'F~. 22 7:2:0C~ 5051.70 '74 ()0 5113, 'iF,',/:-. 75 (')('_') 517' 6. :.3 4 44:3L=':, 1:2 ............ 50 .....:~:!~ .... 44'75.8'P tic:) 10 4= %,:~ .-:,% · _,._; ....... 1 10 4621. !q'7._ .._,'==' ![ 4:3 4/:,8:3, 88 51 :l 1 4'746.48 51 18 4872. ':":' 51 ..", .,:...... 49:34.70 51 :_--:6 . . N,..,/' ,'":'... 69. . 14 (")_. 1 ':'".._,..:'"':" ""'...,,.'-,,--, . c":,:::: .... iq ""1:, 74 . :37 W 4(')7'7 . 7 ..... N - Z:':,.:,'-' · 10 W' O. 48 .,=.:';,~":,L .:,,' ':="o7 hi o.,:.4;;' ::,"" ':'5 ..... '- ':':;:,.,:::; W 2:1. ...... 1 ...,4~'"' ....., .,::.'=' '7 N 6:3 :.'-': c)W 0./-,':' '-'/"-' .... , '-,"" ') ........ ~: :,._~/, 80 N 3:3 :L :2 2:3 W 4 ~_..:, (.. 24 N /:,:3. :30 W 1.07 2/:,72.26, N :3.381.49 W 4306.5'2 N' 61 /:":v W 1 :::/', :2:7 ()8. :3'7 Iq :345 () '-': ..... '= W 4:3:!ii::3. "-"S,::,., 7600 52:L::8.7 ? 7700 ..:,.=,L) 1 ,'6,2 7800 5:3/:,4, 77 7900 5427.69 80-00 ' 54'?C). 2(':, 810 (-~ "::'"='"=' '- 8 2: . ,,,I .__, .__1 .~L'. n 400:.=_':. 12 W 5000. 00 4148 6:-) W 51=.-' 4219 33 W F,'"'-"-' .... ~..'o. 73 4 ;2 '.-.? 0. (36. W 5:3(-~ 5. s..,.=.':, 54:3 F_;. E: '2 51 15 N 6, :3. :=:'.-.~ W '/ i. (-)'? :2:1 .:55. '20 N :=: 2 () 0 8300 8400 8500 86, 00 :.3 7 C.) ....... 7 ..... 1.. 1 ....~ N $4.,./ ...... W ...4 ....... 1.. 5 6,16,. 8:2 5 4'?'.:.). :=','...' 4 5.) 1 1 N 6,0. 10 t,4 's./ '=' '=" "' '=' '=~ %' '" '":' '-' '=~''':' '= .=i':' ' ':) c:: ,-,'-," 'E';.% ~-~ ..... -E:'.-=,- .............. i':-,~ .................... ~-' ,..,6,,=,.= .... ,.=, .=,....,6,,"_- .... ,.=, 47,. '-- /-, N · ,:.--:, 19 W' i~:'i, :ri- '-':." 7-~?, :":; ..... .:~'5:-4'L=,;--=-/,-i --'Fi ............ ',':,',","';5":., ..... ;=;7' 'h ................. ~",~:=;':=;--':=;:;," 5'75:2:. 1 I .=, 6,:=:/-, I i 44~' ' 44 N 54. :30 14 ' ':)-:=,? ''] 3.66, 2'=' 69 55 N "=;"= ...... ........................ ~ ..... 1 F;':) 14 .=,6A4.0'? 5:=:24, '2.:'.;¢ 5707.3'? 44.' 19 N 5'.::./:,c~ 14 ,?,~?.'q~4' ' 1,26, 33:11.31 N 46,07. ';?3 14 5/_-,74,21 !'q :=:'::'~ /-, ....... . 16 F, 77'P_ . 17-, .... -,.:.;4"";-;~'"-~::~,:.-.._,..., ........ ~,~' 2i,~¢ ~'~&:O-' (4 -' ~.,-, .._. 2. 1:3 - :'_:::355.0:..=: N 4/..,6:2 . 10 14 5'7"1.::.: · 7:}", 5'.:.:'6:.-3.65 5:'='.',5 ]. ,./:,:5 43 .'":¢ 11 Iq 4.4, :3() 14 L ',f. ?0' :3 7:..-.-', 3402. ()1 N 4712.4:_--: gl 5812.07 ..... ARF:O AL. ASKA, 2T-2 KLIF'ARUK A L A ~.:i; K A V E R ]" I C A L MEASURIED Ii E P T H '.F.; F::' I!"" IR I:? Y ...- '.:3 IJ N W E I._ I .... ::3 I...I R V F}.'; Y I Iq G C 0 M F'A N Y F' A G E:: 4 A N C H 0 R A G E A L A S K A INC DATE OF "' ' - '" ] ~' , "'-' oLIRVEY UL. TI_~ DER 1:3 1 F;o6 F:nMF'IITATION I')ATE B_h~o GYRO',RC:OPIC SURVEY ;']F:TF~BER 14, 19R() ,_lOB NUMBER AK-BO-<~.O072 .... KEI._/...Y BI...ISHIIxlG EI._EV. = 117.0C.)F'T. ................................................................................................................................. El F" ["~; R a T ("1 R '- E. ',":; F I... L. E R ~E;I.::j.';I;:::']" :[ I'.]l\l I;'.:AI....C I..II._AI'E[I ALON(': I]:L(]l'.iii;I...IF:;~E 'F R LIE S UB'~ SEn I'.:: C, LI F~ S E IL":O LI R S E D C, 0- L E G T CIT' nL VERT I r.':A L VERT ! CAE I NCi_ I NAT I ON D I RFCT I tIN SEVER I 'T'Y RE .~1 ~NL, I_II..AF~ CCICIRD I_._ · . ..................................... , F' ' " "N~"rE:,::~':":"::':. '~i::::'i~'EtR T.I GBL" ' ...... I][i!:F:"l"H DEF'I"H D[i-"F!i M I N DEGREE.'.:ii; DEG/:1. ()C) NI'"IIR TH / SEII_I'I"I-i E A'.E;T/NE:ST L--;ECT I ON ...................................................... 8 :::: 0 0 H 0 R I Z Fi ..... hi T A L ]["l I S F' I._ A C E M E N T = P; 9 4 (') .2'7 F E E 'T' A T N 0 R T I,-I ._,':: .:., ''"' L] ['-' G, 5 7 M I N, W E :.E; T A T M D := ':',.,,.~,°':~; ,.,'" "i" Fi E F': A I.. ]:1. I... A'T' I 0 N F:' R 0 C E D ...I Fit li.:::'.:i; A R E.': B A S E D 0 hi -I" H E I...I :.::i; E 0 F' 'l" I--I Fi: E [ii: D I M E hi S I (] hi A L. R A Ii I' I_1 F; 0 F C I..I R V A T I, IR E M E T FI O'I). ARCO ALASKA.. INc 2T-2 COMI::'LrTATI ON DATE K I..IF' a ~l.iK 0 C: TI'"IB E R 14~ 191L;:6 AL. ASKA SF:'E]::d:';;Y-::::;UN WEL..I... :.:.!;URVE¥ '[ N :~ (':OMF'AN¥ A N C H f_] R A ("~ E A I... A :.:.'i; I'(A DATE OF SLIRVEY OCTOBER 1.3, F'AGE 5 ,.lOB NUMBER AI<-BO-6OO~i,:!;'?:::? ...... K E L.. I... Y B U SFI I N("i E L E V. =:: I 17. O () F' T. 0 P E R A'l' 0 IR-.---IE. S E L. L E R S I N]ERP. LILATED VAL. UE...'.', F f_K EVEN 1OC)0 FEET "I"RL.IE SUB-SEA M E A :L:: I..I R E D V E R T I C A L V E'_' IR 1' I C A L.. D E P T H Ii E I:::' 'r' I.-.I I".f E P 1" H F,,,EL. I ~-,NL.,I_IL.~-.:tR L. UURD .[ NA FEb I"IL]..- TV[~ VERT I CAE NL')R"I"I--I / SI')I_I ]"H E A !~;'1" / WES'[' D I F'FEF~ENCE: C 0 F~ RE]i':T I ON ......................... 0 0 ,, ()(') 1 1 '7'. 0(]) · -- 0. OC) O. O0 .1. 000 '.:.h~;i:8.8'.:..~ 871. :E:'.-.'/ 7:3.04 N 75.80 W 2 0 0 0 ]. :::_ ._":: 9. . :2::3 1 7 ....... ";' '2 . .,::'-' ..::,"'" ._'",:: =i.._ '::.,... 0:3 N 4 'F; ('],. 4 '? W ::ii: 0 () () 2447. '..79 :2:330 ,, ? 9 .......... 84'.'2..:, 77 N 1:1. 14.24 W 40 ............... () ("~ :'::: (") 4 !=;. 8:3 .." .... :'"':.' "'", .... :',. 83 1 :':i', 62 ':":, ¢-,' N :1 '72 '7 .64 W 500(') .......... :':i: /-, '2 /-, . ,_,'::'c',..., :':F'5,(')':2 ......... .88 ...... '2(')(')() .72 N ....... ';::":::' :':: () . ,:-., ...,'"' ~= W 6 0 0 0 4 :;.2:3 4., :3:2 41 1 7. :3'2 ' 2 4 :'.:/7, ,....-.,,~ N 2 8'P ./::,. '7 4 W 7 c:, 0 0 4 :.:: 6 :}) ............... 4 :.:-: 4 7 4/-, 4 8 "::' 7 8 (':, '-::"::: i',1 .... .:.,._,,- .:' '='-'''':' . 14 W ::::O(:~C) ~:' '..': ' ...,4 .:~0 26 5:3¥:3 ";'/- °121 1:3 N 4.:2'P0 06 14 · m # .m .... m ...s ~ 88'.-7C~ 6107. :l 8 ;5'?'.::>0 ,, 18 ":~i4':)~ ,, ()8 1'4 4::30:::.:. 25 L4 I'HE CAI._FI.I....A'T'T(iN F::'I:;X](]E;i]I...II'-'4ES; AFi:E" BA!:;EO IZIN THE LI'.i:.:;E OF THREE' I]I MENSIONAI_. RAIl II...IS OF L"::I_IRVA]'I_IRE MET'HOD. :i~;F::'EF~RY-'.SL.IN WEI...I... SI...IF~VEYIIxlC~ COMF:'AlxlY F'AL'iiE A I",1C H 0 R A Fii IE h L_ A :.:.i:l< A ARC:F) 'Ai.,..A:-BKA ~ I NC. DATE [:iF:' SIJRVEY U'F'_.TCIBER' ' ' 1..,'"', l'~oZ:,'"" 2T-2 L. JMF. Ii] R] I ON DATE I-::.'LIF'ARI IF ] ....... , ,:~,-, - ' , .' .) .~ ......... .... · ................ _,. UL_..T...LJ~._E..B ..... 1_._4...,_ ....... _1_.._-..,?. ~ .................... ~U__MBEB_ AK-BO-60C 7z:: .. A L A S [::: A .................................. KE.L. !.~ Y. B L):ii!H,. I,,N.. G, !g !;.-...g V ..., ........ ~,,.,..,:t,L7,..,,..~:.! !;! F' 'T' ,.. OPE R A T 0 R'-- E:, S E'/... L. E R S TRI_IE sUB-;:,EA M Ii" A ::; I..I R [:.:". D V [:_". R 'l' I C A L.. V E R l' I C A L.. D E F' "F H D E:' F::' 'T' I"'1 Ef E P T Fi R E C T' A N r} I...I I.... A R C (] 0 R D I hi A 'l" E'.i.:.'; M D-- TV [) V E IR"I' I C R I .... NORI"H / :E;OI..I'I"H EAST'/NE:ST D I F F E RE]',II."::I:-".-:C:I_-IIRR E-"CT I i'j:lhl 0 O. O0 -11 '7 ,, 0C) ................ 'i'} ~"00"' 0. O0 :1.1'7 117.0(} 0.00 0.24 S 0. C)9 W 21. '7 .~.'":' 1. 7 , C) ("~ .... 1 ()("), 0 C) (") .54- F; 0. 19. W :':'. 17 3.1. 7. oo 20o. '0'0 ................................... i'~;]":~%q:-'"~iiii: 6 ~ 52 L.,j 4 _'1_ '7 41 '7. (-)() :3('-)(') ,, ()0 1., 41 N 2. :L 4 14 5 .1. 7 517,0 (:) 40 () ,, ()() 6, ::ii:2 Iq 6, 5 (.~ W 6 .1. 7 ,_,~- .t 7 ,0 () !=;_ (")_ (')_, O. 0 i 4.', .,_._";'.=; ' N' 1:3, c,,_, 4 W 71 'F~ '7 i 7, C) 0 6 (')('~ ,, C)(') '25.6:3 hi 24,5 L=: c'":'1 (::17 O0 7C)C) (')c) 4(:) .~"::' N :::9 :::9 W i..,.,,-.. ,. · - ,~ - .. . ,...,,. .... u ... ,:;,"::, z.] '::> ]. 7 (-)(') :::::F) C) C) (") ",.:i-,-, .... ,...., ........................... :: .... ::,z.Ixl 5'.:>. :7:5 ]. C)....... '2 9 ]. (") 1 '7, ,, 0 (-).. '::~.. ("). (")_. (').... (") 7'? . (")_ f-;._ I',1 :!'-': 2 . '="..., .._, = W 1. 1.:,'-'...., ''= ]. 11 '7. ,, 00 :L 0 ()0, C)0 ]. C)3.57 N :L ()9, () 5 W 12'4:--:" 1.217, (}0 .... 1'i'00, 0C) ' ' 1'3.1.'' 4L-~i' N i:'::':) ....W' 1:2:5:2: :L :317. O(Z) 12(z)('). C) C) 15.9. ,~.~ 7 I,,I .1. 74.., 6:2: W 14/- % I 4. 1 '7 (') c) 1:2:0 (') C)(') 1 '-'.=, ....... = ..... :,7 N ':::'16 C)4 W 1:5:.-] 1 .1. 5 '~ 7. ()()' 14.(~iC.), O0 ' "J:: i.':]'.-:-:'i.:.;!3 N 2'.4..::3, 82 1 '7 C)::',_ 1 F,_ 17 , C.~ ........ C) 1 F; (')(') , (')...... (') :2:48, 1 !":;N :':', :2: 8. ,::,....,'-' 1 ,,5: :-.: 2 .1. 71. 7, C) C) 1/: 0 ('). ()0 '::":¢":i 44 N :396.5 ....... 1 ?}L-~'~: ' '~ i:2i~{~7':'i.~iCi ............... ~":~;i~-]'~)-(?- ............. :346, 10 N 472.55 W 0.00 O. ()(:) O. 0C) (). 00 0 ,, C)() 0, (")0 ('), 04 C). (z) 4 C) ,, 27 0 ,, 2:3 0.86 0..5'F' '2. O'F~ 1.2:3 4:36 2. '-' 7.78 ::.:.:. 4. :}.': ]. 2.53 4.75 18 ,, :.::', 6 6 ,, :}.': :'3 26.99 8. 13 36.85 'F~. 85 48 06 11 '."'-:' W 6 4.2 8 ].6.2 2: W :3 6.4'2 2:2. 14 W 115.44 '27. (.')1 151.65 36.21 '.::.}PE~'F'~RY-:':!;L.IIq WEL..L.. '.iii;LIRVE;Y I NG COMPANY F-"AGE A N (": H 0 I'? A ("-i I:::; A I... A'.F; K A 2T-2 COMPLITATI ON DATE KLIPARUK OCTOBER 14, 198/_-. ._lOB NLIMBER AK-BO-E,Q'O.~.~. AL..A:i!ii<A KE:.I....I._Y 'SLIf:;H I NG EL. EV,. ........ !!..?. ........ .!,...!...]~..,-....f).() FT-]- ................... 0 P E R A T 0 R-.. [ii:. .'_:i; E L... L... E R'.3 ............................................. M I:-.. A S U F? E .r.) BE F"I" H "1" R IJ E SLIB- SE A T O'TA L . ................................................................................................................ ~i:?,:',:~']i]: '.::: ! · -...--,, ............................ /.~ -. J.'~.~. - VEFT]" I ...,..-,I .... VERT I CAL REC]"ANGL.II....AF~ '":OF)RD ~ N,..~ I I::..:::, MD-TUB VER"I' I CAE II E F:' 'T' Fi D E F"F F'I N I] R 'Il' H / '.~; El I_.1 '1" Iii E A S "1" ./N E S"I" II I I::: F:' E R E N C E C Ii R R E C ]" I I] N 4'? ::-:3 :361 7.0 0 '=._, i 4'.~ ' :3717' 0'0' 1800. ()0 ...... 40 8.0:2: N :1. ".:.'~()0, O0 4 7':.?. '~8 N 2Ac~0 ...... 00 560, c~..:~'-' N :2:1. ()()~' (".~0 ...................... 2_i12['~,' :3i~i' N ::.i',/:,o ,, :32 W 2200 ,, 00 728 ,, 4-() N ? 70 ,, '74- W 2:3()(),.00 818.88 N 1080.52 W 2400.00 ....... ,~C~A... _ ,'/-,'l.. N I 1 ,_,':":',_,. 84 N 25()0. O0 'P96,. !94 N 1294,84 W 2600, 00 108:3, '7'7 N 1:3'78, 'P 1 W 27 ()c). ()0 1:1. 6'P. 06 ' 'lxl :1. 501.07' W ...... '2 ::C~A ,, c~ A 1 '-":'"-' 71 N 160'2 41 N ......... ,:L ....I .,:) . ...... 29 ()O, ()0 1:3:37. '72 Ixl 17 ()O, 74- W · ~ .o 601. ':?~ 6 72. :5':7~ 6,72.37 70.41 740. ,:,0 68.4:3 8 ()'7.27 6/:, ,, 4- 7 8 '7:2', 'P () c,' ._,'::'. 64 '? :':.: 6. :2:':.? 6:2:. 4. 'F/ 17'?~0.74 W 1C}00.41 64.02 187 :.7 ,, 5'P W 1 ~"~ 70.6, 4 70. 2:3 ::::F'ERRY---SL.IN WI.--:I....I_ C-;UFtVEY I I',,IG COMF'AI',IY PAGE ANF I--IFU::;:(:~F:~E AL AF:;I-::(~ ARCO AI._ASKA, INC. DATE OF L:;LIRVEY OCTOBER. 13, 1'986 2T-2 L. UMFL TATION DATE I<11F'ARUI<' . ................................................................ OCTOBER 14, 1'-'-" - ............ : ..... yo,'.:, ,_lOB NUMBER. AL.~.4.:-,KA ......................... K.F.:iL~L~¥ ~I:.J:.-:.!H~.N!.3.. E.!=-.E.'V....... ......... -::.-.........!..1.7....,....!.-'.!(:.! F""['., M E A :5; U I:;t E D LiEF'TH ."::~:.: 'FRLIE SLIB-SEA ........................ ........ TOT VEI::~ T I CAI.._ VERT I CAL REC'r'Alql]iI..IL. AR 1::i]ii'2tR [II NATIVES M[)--I"V[i VER'T I CA~ ............................................ DEF"I"FI DEF'TFI IWCIR]"H/SCH_ITH EA'.B'I" / NE:'.3 ]" D I FF'EF~EINICE CORRECT I ON ............................................................................ ._,._', 17 54 °4 5/:,47 ~-.,~ ._ ,:, :1. 0 5 '? '72 61:32 62'....?0 ...... 6765 ~:, ?2 70 ::45 7244 74<:)4 7565 '7882 ................. i--i ,-i ')" ,.-_, .~ (. :3817. ":":> .1. '7 401. 7, 4 .1. ]. '7, 421. '7, 4:3.1. '7. 44:1.7, 4517', 4617, · .:, c, (2) 00 '-'"' ..... .,:.,:..:, 1 /:, 0 iq f..:' F;4 (') '72 W :1 F;/-, 7 19 6, 6, '-' 00 :':: ',:T~ (') (") (")(") ";".:"-.?A ~1 N ?/-.~l':' 04 W 1/-,::~(').9'::~ ~ ....... ........... :'..2_'%., '~_.:L.: .............................. .~.~_:__Z.,.~._C: .......... _"X' ~"]" "::' '_' ............................ ',r_:."._~ ...... .'.....i C)(') .......................... 4(")(")C) (')C) .--."-'.:,. ...., c,'" ..":'"'-', ."., N .,::.7/:"'""' ....... ":' 2.'.:C) W :1./-,':.7:::. '='-:, 7 62.59 · 00 41 (30.00 241 c, (-J),iF/N 28 '7 '7.40 W 1 '7 .""] !=;. 22 61,65 ()() 42Cx}. ()() 2474.5:3 N 2'.-:hL::::.:.':. '..:.>2it W ]. 815. :;!:'i~) ,.:'.:,C). ()7 ............................................................................................................................. ('] ..... (') 4.:, .) L). () .] .s.., ~; . .,:: 7 N :"4 ~ !':~ A '-':,..: '"'' 14 . ...... .='",,.-, . ._"k' (') (:) 44 (:) 0 ........... 00 .,.'::',_"'~,_,°._=;. A, :'-: Iq 320 :E.: 42: W 1932:2.:/-, =; o.71'-' 00 4500.00 26:3'.:.~. ':h~} N :2::_--:16.66 W i'F~F:9.42 57.06 _ 4. 717, 00 46 C)0. ()0 2/.:,'.-75, 4:1. Ixl 34 '26.7'? W :;;it 048, 18 58.76 4817., 00 4 '700.00 2 '754.4 '.:.~ Iq :2:..."l :3 '7.6 (") W 2108. '71 6 ('-). 5 :ii: 4'.-:;' .1. '7 (")(") 4 ::-::F)(") (')() .... "-' .1. C). /- F; .................. :. ,: ...... ....... N :7/:, 4 ::_':': . f:; .... :::: N .,_".:' 1/-,_ :::.:_. .:,'-' ..-."" .'=; ...... 9 /-, c) .-q017 ...... 00 4 "-:;' F) (') 00 z.o,/:,4'-"-' , o--,.-..~ N "::7.=;'-? !5.1. t4 .,:..',._'7,'-"-"-" .-.,o .=;,R ':.-;0 · 5117 () 0 5000.00 ")'-?'-"-' ....... . '-' '"" . . .......- ..:. 16 Iq :.:::::::/]. 46., W .,::z. b7 87 60.65 521 '7 (')F) = 100 00 '2 ? 7 '7. '- = ":":: ~ '-' - · _, .-Y.., N :'::: 9 :::":: 64 W 60. :2: I ............. .,:.._ ~,:.,..1.:~ ........................................................................... 5:31 '7. C)C~ f.:.:;2C)C.~, F.)C~ 30::': 1. :".:.'2 Iq -4- 0 'P 5 . 4- '.-.':' ' W 24()7, :::':'.:./ 5'::;', 21 54:/7, (-)c) ........... 5300, 00 :: o:::'F' ,6/.:, N 4207. .2:3 14 2465 . c)..-.,...,_ .~l::::_ ._....,.':-'-'."?.., .................. ":;'=;17 o() 5400 0(') ':'1::'=; :::/-, N 4:_::20,24 W '-'="-'=' 76 ."-~'-.-, :_--:4 -...._ . .... . . _ ._, ..... . _ _ ,".._l ..~.._1 . ._ . ARF ] ~ · - _:L AI..ASF'::A 2T-2 KLIF'AI"~LIK A L A '.::.: K A .1; N L':. SF:'E'F:;.,:R",. .... ::.';LIN WEL..I .... SLIF;.:VE::Y I NG F:OMF'ANY F'AGE A hi C I--I FI R A G lie A I... A'.i:; K A COMF'UTAI"ION DAI'E ........................ -I ......... * i "' ' " ' ~' ' ......................... _L...t_..:.~.!:!.i~!.f:~, ...... .j:.~_~ ..... _j:..,..z/_,~,,_/{.,. ....................... ]job NJ. HBER~ ~;~K--.BU**':6OC):Z~L.;.i,.:::~:::.,.:.~:i..,;.;~:..:',: _ .......... K I."-.'; L L. Y B I,.1:::;I..-t I N G E I... E V, = 1 1 7. c)0 F'T', . . . CI F'E F;: A T C) R- Ii..':;, .................................................... VALUES FOR EVE"N 1OO FEET' M E A S I...I F;~ I:.'~: El DEF']"H TRUE VERT I CAI .... DF.'ff::"T'H 834:..: 5717. O0 :F'":48:C~ 5817.00 ,:,/. "::, ,:, ,-..,.:/ · :,:: 1'70() 8 7 6/_':, 6 01 '7 ,, O. 0 8 8 i.':' 0 6.1. 0 7 ,, .1. 8 VENT I I]:AI_.. F;d.'.<C:"I'AI',Ir.3 I..11... AF-? C:CjEIF~I] I NA'T'E:F; MD--'l"VI'i VER'I' I CAI_ I:IE F"I"H N O F,:"F H / S L-)l...l'l" H lEAST / W Ei: :.:.]; -I" I:) I F F'F=':F;:E NCE: C:CIRRE:CT I C)N i=:At....I.'.::I_ILAT]' ON F:'IROC:E[,LIF(E?.h IjsE' I ~"' ' I '[~ ]~.'"N~i'~..~'~-'~ I'N'I=E;RtF'C~L.A-FI ON BETglE'E'N .......................................................................................................................... THE N[i:ARE:E;T 2() FOOT ML] (FROM F-,ALII_IS I.-jF I::I_IRV~I'I..IRE) F'OINTS ARCO ALASKA~ 2T-2 KUF'ARUK . . . AL_ASKA M E A S U R E D DE P T H :.'.:.: 4'71 ::3483 ::34:33 :,:.-i: 628: :3700 8890 I NC, TRUE V E F,' T i[ C A I .... D El:::' I"H · ::,k ERR'~ ..... .:::, ...IN WIEI....I,. ::::;URVEY I NG E:F)P'IPAi',IY ~ '~ F"- A N C H O I::( A G E F--', L. A.::, I':.. A PA C.~E :1. () DATE OF SURVEY OCTOBER _.UMF I_ll AT I ON DATE :' :: ·: ........................................................... L_-J..l~_;_;~!i'.!~!_~.?._F.:~ .... ~ ? ........ ][_'~'",__~_~ ................................................ , II;iB__r... NI I=MBER ..................... KELLY BUSHING E;I....EV, = OPE R ~ T O R- E, ~...=..; E [... I.... E IR S · _ UB-~:,EA TO'l'gL ':':'~ ?':'':~;' ................................................................................................................. '.:' L_. ....... VERT I C:AL RECTAI',ICiiLILAR (.".: I.".)I;.'.~ F;,' D I N A"F IF".i,'_:; ................................... D E F' l" FI N f-)R T H / ~; 0 U "1" H l-'ii[ A :.:;i; T / W E .'.'F,; T Fi A R K I:!il R .................................. ARCO ALASKA, INC. 2-F-2 STRAT I GR~F'H Z C . [~:RIVED I..ISING DIE BEFTH.::, AND SF'ERRY SI_IN .:,URVEY DATA .................................... ~.~._:. ~ ,-~ ............................................................................................................................ ~ ................. 1,., ..~ .., ......................... ............................................. C El O R D I N A T E S .......................... MARKER .......................... ' .... ~E~si_IRI~B [IEP'I"H ......................... "FVD ......................... '1]-II CKNESS W I TH 'R~'~": ...... ~F'"'~ELI._HEAD . : ': :. ]"OF' I<I...IF'A RI...IK "C 8471 ................................................... ~;:~{i;~:::~"'/-, 4'" ..... '='""c:,,:::,~:'::c" ....... ,, c,;";;~ ............................................................................................ 3 '2'F*'~*. 0 ] N ~._,~-":::::~ .......................... ~. 8:3W BASE I<UI:::'AI::~I...II< F': 84.8;3 '"'""' 2:2::~: ~:~/:'75,, ":'":' ' ..... ='"'"'" 4'~)~ ...... :::,,:::, .I ............ :3 ~: () 4. 10 N ~._, ;' c,. "I"I'"IP KLII:::'ARI,..II.::~ A :~:4:~:~;~: F:;81 .,:: .... :.:, F:; .... ='. 2?? . '~ .............. . .... .... '"". '"'"'" .. c, ::' .... :3:30 ~ 1 ON 4 ~ 9::::. 4 ? BASE KLIPARLIK A ...... ,:,6'-' :-'""',:' ,-, ............................................................. ~"~" :. ', '] 1/-,..",'-'"7 ..... ':'". ,7:';:~5/""':;;'~:..-, 7 ......................................................................................................... :;;'~/"-=.-,.-,6 7 ..... 77N ~676.70N F:'I._I...II3 BACI< TD 8800 /",(")41 ..... 5~ ........ 5'724 56 :-~4PqF) 'F)gN 4760 2:3N ........................................................................................................................................................................... ......................................... 1 ) F-':' R 0 M I... I N E A R E X T R A P 0 L_ A-I" I 0 N B E L 0 WDEEF'E S'I" S I"A T I Fi.. N. 2) L-:CIMPUTER PROGRAM - SPERRY SI_iN THREE [IMEN._-,IONAL RAEIIIIC' OF CLIRVATURE. L]ATA CALCULATION AND INTERPOLATION BY RADILIS OF CLIRVATLIRE DATE OF SI_IRVEY OCTOBER 1:3~, 1986 CCI M F'I_I T Ft T I I-I N El A"F E ....... i~,'~: l;i_~i'BE R-' --i-~':,'--' -i '!~';',']-;F~;- .................................. ,~'IOB.- NUMBER AK -BO-6F)F)72 ................ KEI._LY. BUNHIN_, ELEV = 117.00 FT. 5CBLE :- i IbC¼ O :000.00 z ~CO0. C qBCO qL~SKq. I~C. 8CTOBER ~. ~985 8890 · : .- j -SOOg.~ O{) -sooo. oo -2CCC. CC SoeO. Oo ' . ~. 5CRLE :- L iNCh TO i500. CO / '500.0 KdPqRjK qRCO qLqSKR. OCTOBER 27 -2 qK-80-60072 q -.. !NC. i986 ~8890 'l .,~CO Alaska, 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 December 31, 1986 TRANSMITTAL # 5864 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Final Prints: (1 blueline copy unless otherwise specified) 2T-5 ~. 5" DIL-SFL-GR 9-3-86 3014-7670 ~5" FDC Raw 9-3-86 3014-7645 ~ 2" DIL-SFL-GR 9-3-86 3014-7670 "2" FDC Raw 9-3-86 3014-7645 'x5" FDC Porosity 9-3-86 3014-7645 ~2" FDC Porosity 9-3-86 3014-7645 ~Cyberlook 9-3-86 3014-7635 2T-3 2T-2 ~5" DIL-SFL-GR 9-12-86 3178-7889 xA2" FDC Raw 9-12-86 3178-7863 x,42" FDC Porosity 9-12-86 3178-7863 'x~2" DIL-SFL-GR 9-12-86 3178-7889 "5" FDC Raw 9-12-86 3178-7863 ~5" FDC Porosity 9-12-86 3178-7863 Cyberlook 9-12-86 7350-7850 X~Cyberlook 9-26-86 8300-8670 ~2" DIL-SFL 9-26-86 3561-8778 ~2" FDC Raw 9-26-86 3898-8752 2" FDC Porosity 9-26-86 3898-8752 ~5" FDC Raw 9-26-86 3898-8752 ~5" FDC Porosity 9-26-86 3898-8752 5" DIL-SFL 9-26-86 3561-8778 Receipt Acknowledged: DISTIBUTION: NSK Drilling Vault (film) Rathmell D&M L. Johnston (vendor package).~ ARCO Alaska, Inc. Extension Exploration TRANSMITTA_L TO: ADDRESS: 0 1 P in FROM: DATE: Transmitted herewith are the following: ~ra|o Moseley -Arm -0rt_3n. lqR& Well Data ARCOi'~ Kuparuk 2T-2(K-lO sands) 9-25-86~ape~Edit Lis 3555.0 - 46OO.O ~-2.-q q -86' ~~' '----~~CNFD/Poro Blu/Sepia ~2'r~F-~ 5" 3561-4500 -/~/'~ ~ CNFD/Raw " ~ ~ " 97~5-86 ~DIL/Sfl Blu/Sepia ~2" ~5" 3561-4500 . _ ~ Kuparuk 2T-9(K-lO sands) 7-3-86 ~--~[is Tape--'--.) 1600 BPI 2666.5 - 3400.0 7-3-86 DN/Poro Blu/Sepia ~ 2,,~>~5'' 2666-6334,, ,, DN/Raw ,, ~d i,~j 7-3-86 DIL/Sfl Blu/Sepia ~2" &~5" ~668-6360 2680-6354 'Il .~ I II LSS-Gr..- Run 1 II II Run 3 II Run 3 II RECEIPT ACKNOWLEDGMENT: Return receipt to: ARCO Alaska, Inc. Extenstion Exploration ATTN: Lucille Johnston P. O. Box 100360 Anchorage, Alaska 99510 // / RJ?CE VED AII~ 011 & Gas Cons. Commission Anchorage A/~§- ~'7~6 ~-. ~-. :--tWr~de ed By: L. Johnston .... STATE OF ALASKA =- ALASKA ._,L AND GAS CONSERVATION COMMIt 3N REPORT OF SUNDRY WELL OPERATIONS ,. Operations performed: Operation shutdown .~ Stimulate ,rq Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other ,~ Complete 2. Name of Operator ARCO A'laska~ Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 402' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1579' FNL, 1244' FwL, Sec. 2, T11N, R8E, UM At effective depth 1427' FNL, 1076' FWL, Sec. 2, T11N, R8E, UM At total depth 1383' FNL, 1033' FWL, Sec. 2, TllN, R8E, UH 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number ?T-? 8. Approval number 481 9. APl number 50-- 103-20072 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth' measured true vertical feet 8890 'MD feet 6107'TVD Effective depth: measured true vertical 8800 'MD 6042 'TVD Casing Length Size Conductor 80 ' I 6" Surface 3523 ' 9-5/8" Producti on 8853 ' 7" feet feet Plugs (measured) Junk (measured) 1146' - 1446' Cmtd w/320 sx AS None Cemented Measured depth True Vertical depth 265 sx CS I I 115'MD 115'TVD 920 sx AS IV & 3555'MD 2775'TVD 375 sx Class G 790 sx Class G & 8883'MD 6102'TVD 1 75 sx AS I Perforation depth: measured - 8487' - 8510'MD 8567' - 8571'MD 8537' - 8550 true vertical 581 5' ,_-- 5,8 3,1,,' ,_T..._V,D.._,.__, 5851, Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) HB-1 pkr e 8398' & TRDP-1A-SSA SSSV 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressbre 13. Representative Daily Average Production or Injection Data N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments Compl eti on Wel 1 Hi story 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 ~--~,,~ _ ~..~ Associate En~~ S gned Tit,e g te Form 10-404 Rev. 12-1-85 ~ ( DAH ) SWO,'I 10 Submit in Duplicate '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. District Alaska County or Parish Field Lease or Unit Kuparuk River ADL 25569 Auth. or W.O. no. IT t e AFE AK0693 I Completion Nordic 1 API 50-103-20072 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Complete I 10/17/86 Complete record for each day reported Date and depth as of 8:00 a.m. 10/18/86 thru - 10/19/86 Accounting cost center code State North Slope Borough Alaska IWell no. 2T-2 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prlor status if a W.O, I 1300 hrs. 7" @ 8883' 8800' FC, RR Diesel Accept ri~ @ 1300 hrs, 10/17/86. ND tree, NU & tst BOPE. RU Schl, perf f/8487'-8510', 8537'-8550' & 8567'-8571', 90° phasing, RD Schl. RU & rn 263 jts, 2-7/8", 6.5# J-55 EUE 8RD AB Mod tbg w/SSSV @ 1817', HB-1Pkr @ 8398', TT @ 8420'. Tst ann & pkr to 2500 psi ok. Tst SSSV. ND BOPE. NU & tst tree. Displ well w/diesel. Set BPV. RR @ 1400 hrs, 10/18/86. Old TD Released rig 1400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD ]PB Depth 8800 ! Date [Kind of rig 10/18/86 ] Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, ! see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12'15 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 DATE' 11-7-86 Transmittal ~5819 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-2 CBL 10-12-86 7000-8786 Run 1 2T-3 CBL 10-12-86 3135-7780 Run 1 2T-5 CBL 10-11-86 3842-7548 Run 1 2T-6 CBL 10-13-86 3400-8007 Run 1 2T-8 CBL 10-10-86 5100-7475 Run 1 2T-9 CBL 10-!0-86 2900-6174 Run i Receipt Acknowledged' Distribution' E Oil & Gas Cons. Comm!sslon Anchora.qe BPAE(1 bl) Unoci bl+] ) Chevron(1 bl+l se) NSK(1 bl) Mobil(1 bl+l se 1 bl+l se) State of Alaska(1 bl+l se) Drilling(1 bl) L. Johnston(1 bl+l se) Vault(1 film) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb~ON APPLICATION FOR SUNDRY APPROVALS 1. Typ~ of Request: Abandon - Suspend - Operation Shutdow~ Re-enter suspended well - Alter casing Time extension % Change approved program- Plugging ~ Stimulate '- Pull tubing- Amend order-'- Perforate - Other '- 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360 Anchoracje~ AK 99510-0360 4. Location of well at surface 402' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1389' FNL, 1407' FWL, Sec. 2, T11N, R8E, UM (Approx.) At effective depth 1206' FNL, 1233' FWL, Sec. 2, T11N, R8E, UM (Approx.) At tgt%[I-~leFPl~, 1183' FWL, Sec. 2, T11N, R8E, UM (Approx.) 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8890 'MD feet Plugs (measured) 6106 'TVD feet 8800'MD 6045 'TYD feet Junk (measured) feet 5. Datum elevation (DF or KB) 117' RKB 6. Unit or Property name K,,part,k River Unit 7. VVell number 2T -2 8. Permit number 86-141 9. APl number 50-- 103-20072 10. Pool Kuparuk River Oil Pool 1146' - 1446' Cmtd w/320 sx AS I None Casing Length . Conductor 80' Surface 3523' Production 8853' Size Cemented Measured depth 16" 265 sx CS II 115'MD 9-5/8" 920 sx AS IV & 375 sx Class G 3555 'MD 7" 790 sx Class G 8883 'MD ~ue Vertical depth 115'TVD 2786'TVD 6101'TVD Perforation depth: measured true vertical Tubing (size, grade and measured depth) None None Packers and SSSV (type and measured depth) None 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation October, 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 & ~(.~ ~ Title Associate Engineer Date ~ Commission Use Only (DAM) SA/128 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI ...... ..:~;.~..~...-~,.~..~.-~2~¢.~ :~~.~, .'..: ..... .;~".~ If Commissioner the commission Dateu6mit~n F triplicate feet ARCO Oil and Gas Company,,'~' Well History - Initial Report - Daily . Inatructl~ne: 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0693 Rowan 34 Operator ARCO Alaska· Inc. Spudded or W.O. begun Spudded 9/15/86 9/16/85 9/17/86 9/18/86 9/19/86 Date and depth as of 8:00 a.m. County. parish or borough North Slope Borough ILe~se or Unit ADL 25569 ITitle Drill IState API 50-103-20072 IDate 9/14/86 I ARCO w.I. IHour · [Prior status if a W.O. 1000 hrs Complete record for each day reported 16" @ 115' 1780', (1665'), POOH f/BHA chg Wt. 9.1, PV 19, YP 20, PH 9.5, WL 9.6, Sol 5.8 Accept rig @ 0500 hrs, 9/14/86. NU diverter sys. Spud well @ 1000 hrs, 9/14/86. Drl, DD & surv 12¼" hole to 1780'. 369', Assumed vertical 528', 4.2°, N42.SW, 528 TVD, 5.81VS, 4N, 4W 984', 16.9°, N48.6W, 975 TVD, 91VS, 64N, 65W 16" @ 115' 1780', (0'), Jar on fsh Wt. 8.6, PV 20, YP 20, PH 10, WL 9.2· Sol 2 POOH, LD DD. RIH w/Navi-Drl, rm 1464'-1605', stuck pipe. Jar on pipe. RU GO, rn freept; free @ 1455'. Rn string shot & BO @ 1456', POH. PU FTA, RIH, engage & jar on fsh. 16" @ 115' 1780' TD, 1239' PBTD, WOC Wt. 8.6, PV 30, YP 32, PH 9, WL 9, Sol 3.2 Jar on fsh w/o progress. RIH w/string shot, BO @ 1455', POOH, LD fsh'g tls. TIH w/5" DP to 1446', spot 320 sx AS I cmt plug f/1146'-1446', POOH, WOC. GIH, wsh green cmt f/I139'-1239', circ, POOH & WOC. 16" @ 115' 1947', (556'), Drlg Wt. 9.4, PV 18, YP 27, PH 10, WL 8, Sol 5 WOC. TIH, wsh f/1239'-1391', circ, TOH. Chg BHA, TIH to 1350', wsh to 1396', KO @ 1414', drl to 1947'. 1287', 24.2°, N49W, 1259 TVD, 197 VS, 135N, 144W 1429', 25.7°, N58.gw, 1387 TVD, 256 VS, 170N, 192W 1681', 35.2°, N56W, 1604 TVD, 383 VS, 232N, 305W Alaska JWell no. 2T-2 56.24% 16" @ 115' , - · 3565', (1618'), Prep to rn 9-5/8" Wt. 9.8, PV 23, YP 26, PH 9.0· WL 9.0, Sol 6 Drl & surv to 3565', 24 std short trip· circ, TOH, LD DP. 1908'· 42.1°, N55.5W, 1781 TVD, 525 VS, 312N, 422W 2328'· 52.1°, N52.7W, 2066 TVD, 833 VS, 496N, 670W 3175' 54 3° N48 9W 2561 TVD 1520 VS, 933N, 1200W , · · · , · 3530' 53.3 N48.8W 2771 TVD 1806 VS, 1122N, 14 , , , · The above is correct 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--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 complelion. District ICounty or Parish I State Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25569 Complete record for each day while drilling or workover in progress Date and deptl~ as of 8:00 a.m. 9/20/86 thru 9/22/86 9/23/86 9/24/86 9/25/86 9/26/86 Alaska Well no. 2T-2 9-5/8" @ 3555' 4992', (1427'), Drlg Wt. 10.6, PV 25, YP 25, PH 8.5, WL 4.5, Sol 15 RU & rn 89 its, 9-5/8" 36#, J-55 BTC csg w/FC @ 3472', FS @ 3555'. Cmt w/920 sx AS III & 375 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND diverter. NU & tst BOPE. RIH w/8½" BHA, tst csg to 2000 psi; OK. DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 4024', packed off, stuck @ 3945'. Pmp 6 jts out, TOH, dragging to csg shoe. Circ stab cln, TIH to 3770', wsh & rm to 4024', control drl to 4337', raise mud wt to 10.3 ppg; packing off. Raise mud wt to 10.5 ppg, TOH. Pmp 10 jts out, chg BHA, TIH to 4050', rm to 4337', drl to 4992'. 3853', 52.6°, N48.9W, 2965 TVD, 2063 VS, 1291N, 1609W 4292', 54°, N37.4W, 3228 TVD, 2411VS, 1548N, 1850W 4793', 55°, N36W, 3518 TVD, 2805 VS, 1875N, 2094W 9-5/8" @ 3555' 7231', (2239'), Drlg Wt. 10.5+, PV 22, YP 18, PH 9.5, WL 4.8, Sol 15 Drl & surv 8½" hole to 7231'. 5089', 52.8°, N44.7W, 3692 TVD, 3040 VS, 2058N, 2249W 5420', 53.2°, N54.4W, 3891TVD, 3304 VS, 2229N, 2450W 5916', 51.9°, N59.8W, 4193 TVD, 3696 VS, 2443N, 2781W 9-5/8" @ 3555' 8137', (906'), Drlg Wt. 11.4, PV 20, YP 15, PH 8.5, WL 5.0, Sol 16 Drl & surv to 8137'. 7370', 51.6°, N58.4W, 5098 TVD, 4826 VS, 3040N, 3749W 7898', 50.9°, N61.1W, 5429 TVD, 5234 VS, 3247N, 4105W 9-5/8" @ 3555' 8890' (753'), POOH f/logs Wt. 11.4, PV 23, YP 20, PH 8.5, WL 5.2, Sol 19 L~..~,j :-, Drl 8½" hole to 8890', 10 std short trip, C&C, POOH f/logs. ..... '-" 0i! ~ ',~u'.; 8890', (0'), gTH w/Schl Wt. 11.3, PV 20, YP 10, PH 8, WL 4.4, $ol 19 POOP,. RLT Schl, rn triple combo; unable to get past 6868', log DTL/SFT./SP/CAL/CNL/FDC/GR f/6868'-3555', POOH, ~D $¢hl. Stage in hole, lost rtns @ 8890', POOH, filling thru DP, break ¢±rck 1300', CBU, fin POOH. RU Schl, RIH. 8890', 43°, N38W, 6106 TVD, 5953 VS, 3714N, 4653W The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Dale JTitle 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. Accounting District Le'sea or Parish Alaska County North Slope Borough State Field or Unit Kuparuk River ADL 25569 Auth. or W.O. no. T t e AFE AK0693 Drill Rowan 34 AP1 50-103-20072 Operator I A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 9 / 14/86 Date and depth as of 8:00 a.m. 9~27~86 thru 9/29/86 9/30/86 Complete record for each day reported cost center code Alaska IWell no. 2T-2 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our I Prior status ii' a W.O. I 1000 hrs. 7" @ 8883' 8890', (0'), CO mud pits Wt. 11.4 Brine Rn DIL/GR/SP/SFL/CNL/FDC f/8752'-6868', cont w/GR to 1000'. Stage in hole to 6400', lost rtns. Spot 50 bbl LCM pill, build vol, POOH to 1900', circ. Displ mud in pits, cut mud wt to 11.2 ppg. Stage in hole, CBU, POOH, LD DP. RU & rn 216 jts, 7", 26#, J-55 BTC csg w/FC @ 8800', FS @ 8882', Mkr jt @ 8352'. Cmt w/615 sx 50/50 Pozz C1 "G" w/4% D-20, .2% D-46 & .5% D-65, followed by 175 sx C1 "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps w/ll.4 ppg brine, bump plug. ND BOPE & tbg spool. Prep to Arctic Pak. 7" @ 8883' 8890', (0'), Demobilize rig Wt. 11.4 Brine RR @ 0600 hrs, 9/29/86. Demob rig. Old TD New TD PB Depth 8890' TD 8800' PBTD Released rig Date Kind of rig 0600 hrs. 9/29/86 Rotary C~assifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single 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 Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected The above is correct Signa~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor ARCO Alaska, inc. Post Office [ 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 Transmitted herewith are the following items. return one signed copy of this transmittal. Schl' DATE 10-08-86 TRANSMITTAL # 5789 Please acknowledge receipt and Open Hole Lis Tape plus listing: One copy of each 2T-2 09-26-86 Run #1 2T-3 09-12-86 Run #1 Receipt Acknowledged: D. Wetherell*Schl Pkgs. Date: ARCO Alaska. Inc. is a Subs,diary of AllanticRichfieldComc)al1¥ July 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer B=RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kupa_z~ak~,~v° ~ ~.~=~ Unit 2T- 2 ARCO Alaska, Inc. Permit TM · ~o. 86-141 Sur. Loc. 402'FSL, 556'F~., Sec. ]., TllN, R8E, U~{. Btm~hole Loc. t183'~.~.~. , i146'Ft~U~, Sec. 2, TllN, RSE, UM. Dear Mr 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 co~encing 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. Uhere a diverter system is requzzeo., please also notify this office 2~ hours prior to commencing equipment installation so that the Commnission may witness testing before drilling below the shoe of the conductor pipe. 7 ~ t ru,~Y?~ s 9~ / / d-,/ /I '~' .- ¢. V. Ch2atterton Chain-man of Alaska Oil and Gas Conservation Co~ission BY O~DER OF THE CO~[ISSION dtf Enclosure CC: Department ~.~ Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA..6 AND GAS CONSERVATION CU,,tMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill F11 lb. Type of well. Exploratory [] Stratigraphic Test Iq. Development Oil [] Re-Entry [] Deepen©1 Service ~ Developement Gas [] Single Zone i~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation ~(uparuk Ri ver 0i 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 -4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 20AAC 25.0251 k~O2'FSL, 556'FWL, Sec.1, TllN, R8E, UM Kuparuk River Unit '3tatewide At top of productive interval 8. Well nu ,mber Number 1389'FNL, 1407'FWL, Sec.2, T11N, RaE~ UN 2T-2 ~f8088-26-27 At total depth 9. Approximate spud date Amount 183'FNL, 1146'FWL, Sec.2, T11N, R8E, UN 08/01/86 ~;500,000 -12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD property line 8822 'MD 146' @ TD feet 2T-7 125'¢ surface feet 2560 (6065'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle52 0 Maximum surface 1658 psig At total depth O'VD) 3336 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) · .74" ~6" 62.5# ~4-an W,,ld 80' 35' 35' 115' !!5' +200 cf 17-1 /b,"q-~,/R" ~,~,.f')# .I-R~, RTr: ~,c,~q, Rg' ~,~, ~:,7/, , 9Rnl , 9~0 $¥ A_q I1! & HF-ER~ ~75 .~x Cla.~.~ fl, hlm. nrl ..8-1/2" ~" 26.0# J-55 BTC 8788' 34' 34' 8822' 6065' 200 sx Class G(minimum HF-ERW TOC 50(' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .~. ? i.~,. ~ ~ Surface : ~ Intermediate ~ ~ ~ ~ !, :-. ,:aec Production ~i ..... ] ~_.~, L_ ]. ¥'' Liner .~ s~ 0il & O~:s [;cms. uu~:,,, .... Perforation depth: measured Al0. ,.3 A;-,¢ true vertical '~ ~' ~ ':';':-::'; ~'':~'' ~: :~ ': "-: ~' ' ~ .... :'"'~ ~ 20. Attachments Filing fee .'~ Property plat C BOP Sketch ~ Diverter Sketch .~ Drilling program ,~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~., Seabed report © 20AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge -~,,.,~ ~¢_.~~~,_~.~.,~._~¢ Regional Drilling Engineer Signed ' Title Date ?/'''~ ~'~ 6/' Ce/'mmission Use Only ( LWK ) PD/PD298 I APInumbe.~ ,~..- I Appr°valdate I See cover letter Permit Number ~(-.. /~/f .,, ~-__'. 50- / o ~ ---~.¢~- ,' t.- 07/24/86 for other requirements Conditions of approval Samples required ~ Yes ~- No Mud Icg required ~ Yes '~ No Hydrogen sulfide measures .~ Yes iq, No Directional survey required ~Yes [] No Required workin~...crrelssur%~~ ~J~C3M; I~ 5M; .,~1 10M; ~, 15M Other:/ /~.,"~/~ .~/'~~ < ~,, ~~~~~ ~ byorderof ~/~~ Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-~ 5 / , / Subr~ [riplicate KUPARUK R I VER UN I T 20" DI VERTER SCHEM~T I C '1 DESCR I PT I ON 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CONNECT ASSY. S, TANKO UPPER QUICK-CONNECT ASSY, 6, 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS, 7. 10" HCR BALL VALVES N/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. 7 ~ 7 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035 (b) 4 MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. ' 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN HELL UNDER ANY C I RCUMSTANCES. 51(~D94002 RlO 6 i > > ACO..MJLATOR CAPACITY TEST 1. C~EC:,< AN3 FILL ACCLM3_ATCR RESERVOIR TO 'F:90:'ER LEVEL WITH HYDRALI_IC FLUID. 2. ~ THAT A~TCR PRE~ IS 3.__"203 PSI WITH 1500 PSI ~TRC~M ~ TH5 RE(//_ATCR. 3~ CE~VE TIWE, THF_N CLOSE AIL UNITS SIMLI_TAh~OJSLY ALL UNITS ARE CLOSED WITH ~ING PtlVP CFF. 4. RECO:~ CN NADC R~PCRT, THE ACCE~T~ LOMER LI~IT IS 45 StECI2N2~ CLOSING TIh45 AAD 12CO PSI RE]WkININ3 5 4 13-5/8" BOP STACK TEST FILL BCP STACX AN) ~ MANIFCLD WITH ARCTIC DI~. 2__ O-IEQ< THAT ALL LC~ DONN S~ IN ~~ ~ ~y ~~. ~T ~T ~ iN ~~ LI~ V~VES ~~ TO ~ STA~ ~ ~ V~S ~ ~ ~ ~ ~. 4. P~~ ~ TO 2~ ~I ~ ~ F~ ~0 ~IN. I~ ~ ~~ TO 3~ RSI ~ ~ F~ ~0 ~IN. BL=n~ ~~ TO 0 ~I. 5. ~ ~ P~~5~ ~ ~~ KI~ ~ ~E LI~ VALVES. ~ T~ RIRE ~ ~ ~ V~VES ~ K~ ~ ~E Li~S. 6. TEST TO 2~ PSI ~ 3~ RSI ~ IN S~ 4. 7. ~I~ TESTI~ ALL V~VES, LI~S, ~ ~S WI~ A ~ PSi L~ ~ 3~ PSI HI~. TEST AS IN ST~ 4. ~ ~T ~~ TEST ~ ~ ~T ~ ~I'~ 1EST ~S T~T ~ ~l F~LY ~. TEST B~ PIPE ~ TO ~ ~I ~ ~ ~I. 9. ~ 8~ PIPE R~, ~ ~ ~I~ ~ ~ ]O. ~ ~I~ ~ ~ TEST TO ~ ~I ~ ~ PSI. II. ~ tI~ R~ ~ ~I~ ~ST ~. ~ S~ - MANIFO_D ANO LIKES ARE F'L~_L CF FLUID. ~ A~ VALVES IN ~I~I~ P~IT)~ - I~'TEST STRIPE VALVES, K~ Y, ~ LY ~S, ~I~ PI~ S~ VALVE, ~ I~I~ B~ TO ~ PSi 3~ PSI. 13. RE~ ~ST I~~TI~ ~ ~~ ~ TESI ~ ~ ~ ~ ~.~ ~ GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. ~ Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS .-~ DE~I~SSER HUD CLEANER STIR STIR HUD CLEANER STIR CENTRIFUOEI LWK4 / ih TYPICAL MUD SYSTEM SCHEMATIC. ., ,: i; :: DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 Drill out to Weight Up 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. nw 5 / ±h ARCO ~ ALASKA.-- tN( ....... ~ ....... + .... ' PAD .2T.._WELL NO, 2 /- PROPOSED:L:. KUPARUK FtELD.~.'NORTH SL~OPE;-{-:ALASKA -'-/--~ _ . ...... :.- - ~-.-: .... ~--: .... : .............. ; ..................... m---- ........... . ........ T ............ ! .............. ! .......... .... ~-~'~ ~' .... '-~-': ..... R I .......~ ...... ~ ..... 4-: ....... ';- ' ' ' ~ ~ ~ ' ~ t ~ ~ ~ ' [ ~ . i_- KOP_ ~.T D. 400 TMD-400. DEP-O . ...... t5 BUILD 3-~- ~-- ' ........... ~ .... ~ ' ' · "'; ....... ' ...... ~ - 21'- ~ ......4 ..... ~ ........ : ......~ ....... i ...................... --', .' . . .-:~ ...... BASE_i~ER,A~R0~,~V-D~5~_-iNLf~b-=i . ......................... ; .... TOP ....... C ................. ~ ..... :9':'5/8~ :P_T.L}:TVD= -_TMD=3574 DEP= 1 862 L:-2~_'L~:-_' ...... ~ . ~ ..... - __~ _ ~ i ~ . ~ . , , ; ............. ~: .................... .............. ~ ........... - .......... ~ ..... t ...........~ ......... .......j --, ........ ........ ~ ..................... ; ......... ~ ............. -_ _ _ t ..... - · ~ ~ J .......... ~ ............... J ......................... r .... ~ ~ - _Z _ _ ' . > ...... ,. -: ~- ~ - ._ : .......... ............ : .... . .................... ; .... - . _ . _ _ . ~ ..... ; ............. .... :~m~.O= - ...................................... ~ ......... :- - - ' .... ~ ....... : ~ . - ' · ...... ~'- ............. .~ ' _.~ K-5 TVD=42Z1 . T~D=59~7 'DEP=~Z12 - ~ ~ . . _ ~ ....... ~ , - ...... .... ~ - _. ~ .... . - : ~ ': ~ ~. . ' --' ........................ AVERAGE' ANGLE?:-::-: .... '-' ..... : . ; ( . , : - ---) ...... L_ /'.7 ..... ~' ._/: :' . ~ .. ' ' ....................... : -T/ -~ZONE- :A - TVD=58~6 THD~845~- DEP=5683 ................... B/ KUP SNDS ~TVD=5941 T~D=8622 DEP=5815 ....... ~ ............... ~ .... TD ~(LOG PT) ~TVD=6065. THD=8822 DEP=59Z1 ....... ~ : , --T . , , - ~--'-~ .... . ' ' .--[ ......... ~ .......:-- - ,- ....... : ............. ~ .... - .... : ........ ~ ....... t .....i r ' , ......... . .....~' ' ..... i .....7000 .................................... ~ ......... ~ ....... ~ .................. ' .................. - : D ooo ooo' _ ooo:: - Sooo ooo -:-. :-." -':------ - ..... :'. :--- .... - ...... -'~-~ ......... ~ ~ ...... ~ ............ -'~ .....---;-~ ' J:-~ER T ICAL ,~ECT ~OH~ .... ..... ~ ........ - .... : ' --~,1 ....... .~.;~'::' ': ~:~= ~' ..... ~ ?~-" '-"', .: ', __:..-'-' ~' ._ ~_~._.....' ":" '~:, ~.~ ,:,"x~"~-~-~.,,~~' .... I ~ : ' ' - - - ~ ............. : .... , ...... ~ ..... : ........ i-~ --~.~ ...... ' .... - ,, i - :-:--' .- ~ - :~ :'~:,~ :--~'~ ..... ~' -' , - ; .......... i ......... : - ~ ............. :~ ..-~---. r . . -:.; ~ ...... i'll ,$889! I t ! DEP~'$Z:491 '!" 'i -'".-:'*¥-'?' '*T'* .~..~..,L'L'_~_:,,.,,:.:...~: .~..r!,. · .... ;l:i~ .'t:.i.:' .-'"'-' "+-' ' ~ , .... , ' "" .!"i ::! 'i , . _~i? . , .. t t/ . j , ...~ ..... ~.~ ..... ~ ................ ~ ......... ~ ................. ] . .... "~ '"~ ........ , 1':' t ' ~m; *p u~.~_:.l.~O~.'. ..,"~"~,,"' ..... :' .... '~ ........... '"~ '~'" ~ ;' 'J': ' ~ ' ..~.~ .............. ~.~.,_:~..2.L,. ....... ~ ...... ~,~:~-~.:~,~ '~ !~.t~ ~ ~ ~. I',.t~ ~ ~t~..i 1- ~-.~-I ~.! t.,.t.i.~'~i~ i i +-.[~ ..... , . . ,~ . .~ -~..~,,. : ~ ~ , ~ .... . 'i '~ .... ~'"~:~f:~"~' ~ 8~ " t-/ ~ ' ' ~ ~ ~ ~ , · ' , ~ ~ ~ '~~l ~ ~,: ..... : . . , ., . . , . .... ~ , ~ ; ~ ;' , . , . . . , ~ ............ ~ .... ~-.-e ..... ~--.~ ...... J ~ ......... : ....... ~'"':~'--~--~-~ ....... ~m~'q-'. .... ~ . .... ..~, t ,, . -t ~, , + -~: I~ :~-, SURFACE LOCA~I OH ....... + ........ I...-~ .' - - ~ - ~ .......... J '-: '-:: ~"-' ~...~ ,, ~ ~j~' 25,? ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 · Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 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 ARCO Alaska. Inc. is a Subsidiary of Atlan!icRJchfieldCompany 'TI2N ' LOCATED IN PROTRACTED SEC. I, TIIN,RSE, U.M. 2 - Y = 5,970,382.43 LAT. 70°19'49.1287" X = 498,944.93 LONG.150°00'30.807" 402' FSL, 556' FWL OG = 77' PAD = 81.5 3 - Y = 5,970,357.42 LAT. 70°19'48.8828'' X : 498,944.91 LONG.150°O0'30.808'' 377' FSL, 556' FWL OG : 77' PAD : 81.5 4 - Y = 5,970,332.46 LAT. 70°19'48.6372" X : 498,944.84 LONG. 150°00'30-809'' 352" FSL, 556' FWL OG = 77' PAD = 81.6 5 - Y = 5,970,307.52 LAT. 70°19'48.3919'' X = 498,944.91 LONG.150°O0'30,808'' 327' FSL, 556' FWL OG = 77' PAD : 81.6 6 - Y = 5,970,282.50 LAT. 70°19'~8.1459'' X = 498,944.95 LONG.150°O0'30.806'' 302' FSL, 556' FWL OG : 77' PAD : 81.7 7 - Y = 5,970,257.54 LAT. 70°19'47.9003'' X = 498,944.95 LONG. 150°O0'30-806'' 277' FSL, 556' FWL OG = 77' PAD : 81.6 8 - ¥ : 5,970,232.63 LAT. 70°19'47.655Y' X = 498,944.96 LONG. 150°00'30-806'' 252' FSL, 556' FWL OG : 76.9 PAD : 81.6 y : 5,970.207.62 LAT. 70°19'47.409Y' X : 498,945.01 LONG.!50°00'30.804'' 227' FSL, 556' FWL OG : 76.3 PAD = 81.6 LOCATED IN PROTRACTED SEC. I , TI I N, R8E, U.M. 10 - Y : 5,970,132.65 X : 498,945.27 152'FSL, 556' FWL 11 = Y = 5,970,107.71 X = 498,945.10 127' FSL, 556' FWL 12 - Y = 5,970,082.5B o X : 498,944.98 'E-6 102' FSL, 556' FWL ~ 13 - Y = 5,970,057.59 E X : 498,945.08 o 77' FSL 556' FWL ~ , c6 ¢> 14 - Y = 5,970,032,60 ~ ~ X = 498,944.91 o ,- 52 FSL, 556' FWL c~ -~; 15 -'Y = 5,970,007.69 ,._.q ,~ x ~98,944.93 ~ 27' FSL, 556' FWL _= 16 - Y : 5,969,982.85 ~ X : 498,944.88 2' FSL, 556' FWL LAT. 70019'46.6719" LONG.150°O0'30.796" OG - 76.0 PAD = 81.7 LAT. 70°19'46.4267'' LONG.150°DD'30.801'' OG = 75.9 PAD = 81.7 LAT. 70°19'46.1794" LONG.150°O0'30.804" OG = 75.7 PAD = 81.7 LAT. 70°19'45.9336" LONG. 150ooD'30.801'' OG = 75.5 PAD : 81.6 LAT. 70°19'45.6879" LONG.150°O0'30.806" OG : 75.3 PAD : 81.7 LAT. 70019'45.4428" LONG. 150°O0'30.806" OG : 75.2 PAD = B1.6 LAT. 70°19'45.1985" LONG. 150oo0'30.807'' OG = 75.1 PAD = 81.7 LOCATED IN PROTRACTED 9 - SEC.12, TI I N,R8E, U.M. 17 - Y : 5,969,957.72 LAT. 70°19'44-9514" X : 498,944.94 LONG. 150°00' 30. 805" 23' .FNL., 556'~ ~L;~ vOG !-:~"t:~ .~ '-~AI~ =~81,~ 6 NOTES :-_. -, i- l. ALL COORDI NATES ARE A.S.P., ZONE 4. ~ ~! =,i i~!':~ ~==~" !~ ';'~;.~.~ !!='~: ~!''= ~ '~'~ Z. SECTION LINE DISTANCES ARE TRUE. ' ~ ~ '~u ..... ~ -~ ~.~ ;~ ~'[~ ~ ?' ¥'~,~ ~ t{~ ~;'[~. ~ ~ 5. HOEIZ; POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WES~~J~D~LE PER LHDE ASSOC. 4. VERT. POSITIONS BASED ON TBM' , ' s ET-6 ~ N [9+75 Eli+ 5~ PER F.R.B. ~ ASSOC 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-5140 rev.~. CERTIFICATE TaSSOG, OF SURVEYOR: i HEREBY CERtiFY THAT I AM PROPERLY REGISTERED AND LICENSED TO ~RACTICE LAND SURVEYING IN THE STATE OF ALASK~ /)~D THAT THIS PLAT REPRESENTS A LOC~TION SURVEY MA~E BY ME OR UNDER MY SUPERVISION, ~ND THat ~L ~MENSIONS ~ND OTHER DETAILS ~RE CORRECT mi SURVEYED FOR' ~k~ ARCO Alaska, Inc. '~' KUPARUK PROJECT DATE 18 JAN 8~ ~w~w~ DRILL SITE 2T CONDUCTOR CHECKED S H FIELD ~(X:)K F.R.B.857-I AS- BUILT LOCATIONS mlIlm[)WG. NO. NSK 86-6 1I~4,Jllll .14 iisi ill,l,ili ~ A~cfic BoulevaN, Suife 20 f, Anchorage, ~lask~ ~503 ,.T.,. (8 ' 13). , .//,.r// (10 and 13) (4) Casg ~.~~ ~27-a/. --(14 thru 22) (5) BOPE 5. ,Is 'sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated' and.is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ® 10. 11. 12. 13. Does operatOr have a bond in force .................................. Is a conservation order needed ...................................... 15. 16. 17. 18. 19. 20. 21. 22. Is administrative approval needed ................................... IS the lease number appropriate ..................................... ~ Does the well have a unique name and number ............ ~ ............ z'-/~- Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 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 .......... '..., .............. (6) OTHER j/,~7.. '(29 thru 31) 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OoO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ (6) Add: ~-g-/._~./~/. "z-,~/-8/. Geology: Eng~qeering: rev: 07/18/86 6.011 32. Additional requirements ............................................. INITIAL GEO. UNIT CLASS STATUS AREA NO. ON/OFF' SHORE Additional Remarlcs: ~T_~ .~,~' b~r ,,~>/'/,, ;~ !_a__~' 'a~ ' ' ' ;t r-7 ' Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. 'VE:R! F! CATXON ~!STZNC~ bVP 010.H,02 VERXFZCATION bZSTING PAGE ** REEL HEADER R~VIDU$ EOF #G?H I 1024 ** ~NFORNA~IQN RECORD& · CONTENTS COMMENTS 0,00 000 018 065 ooo ~' o~ o~oo,:, o~ oo oooo~:~ o~to~ 000000 06~ 000 000 06:5' ooo ooo oo~ o~ UNI'T T¥'PE CATE SiZE COD~ 000. 000 O01 065, ' SCHLUMBeRGeR ; ~ S~ATg ~ ~UMBER AT A ' ?.25 SEP-96 ~., ltc~:~tlu~°'~'x?~.~ ?"'¥:P.B.,FLUXD = LSND T¥ ALASKA CO~:UTING CENTER ARCO ALASKA ZNC NORTH ~OP~ BOROUGH A~ASKA. LVP 010,H02 VERIFICAT/ON ~IST~NG PAGE SCHI~UHBERGER bOG8 INCLUDED ~ITH THIS MAGNETIC DUAl, ~NDUC~ION ~PHE~CA~ FOCUSED ~OG (D~) DA~A, AVA~AB~ 4500+, ~0 3561" FORNA~ZON DEN6X~Y COMPENSatED LOG (FDN) COMPENSATED NEUTRON bOG (FDN) TYP~, SIZE REPR CODE ENTRY 0 ,1 ! N C,OP~ T:¥gE CLASS MOD D:;ZP! r~ 0 000 O0 0 4 1 000000,00000000 LVP 010,H02 V£RIIFICA?IOH LISTIHG PAGE: 4 Ti:NS N A B:':~R.IPONPON " OHMMOHHN.v X20 46 OHM~ O0 12:0 44 ~¥ OO o10 0 GAP! O0 3 0 01 O0 6i5 21 XN O0 28O 0 G/C3 O0 350 02 G/C3 O0 356 O0 420 0 O0 000 o~ PU O0 890 oo pu O0 890 O0 ¢P$ O0 330 31 CPS O0 330 3 0 bB, O0 635. 2! 4500,0000 4400,0000 1o: TEN,5 RHOB 2,82~ 78,4375:' TENS DPHI' 87 ;,25{)0 TENS 2 DRHO 41 ,,': 4314 DeMi 3560,, 0000 T:EN.$ D:PHI 3:1 I ~ 0oo000o0000000 1 · 000o000000000o I 68 o0000000000000 1 68 0o00 00o0o00 i 68 0000~§0000o00 i 68 0'0000000000000 1 68 00000000000000 I ~ 0o0ooo0000000o 1 000o0o0o000000 I 68 0o0o0o00oo000o 1 68 00000000000000 ~ 68 ooooooo0000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 000o000o000000 I 68 000000000o0000 3.7 504 I b M 3650;,0000 GR N A 4,0'095 ~,LM' 3 5 60 .,'0 O00R 0 27, '~: NC Nb. , 313~ 26, NCNb , NCNb , ;0249 ~RAT 8 7,2500 3, 2033::,,0000 ,07,29, ;6250, 3, 4043: a4,0'O00 55,:8478 5! . o00o 2~24,0000 137,5435 4!,2500 :6 2216,,.0000 5,5855:4; 7500 34'0 bVP OlO,H02 VgRIFI~A?IDN hISSING PAGg 5 209375 NPH! 767,0000 TEN& ,, SOl) NPH! 482 2500 TEN& 3700 023 11 3 485 0000 SFLU 9 8 9160 NPHT 0000 TENS 3,°i .t 0000 &F'bU 6563 OR . 6326 RH. OB 3926 NPH~ 0000 'fEN T~N$ 91,,1660 DRHO ,8672 DPHI 35~4,'0000 42: DPHI 33t0, DPH! 2920 50:.~203 IbD: 880:?50 T N 2.:2'246 D~H~ 38;2813 DPHi :303'4:,0000 2~34:,0000 , # E NANE. = :NTB ILIBRARY TAPE 34,i922 NCNb NIRAT NCNb : GR 292~;,02,39 NRA 29,2211 NCN[ 3034;0 GR ~ 0,, 0 N,R AT 25,78 .NCNb 0,8: 3 2254.0000 4,5596 94,3750 3,4941 1847,0000 5,6767 ,9375 1809' 97 1 O0 *6675 3,6934 900,0000 8654 3750 2000,0000 ' 67,9375 1388.,. 0000 LYP 010,H02 VERIFICATION 6ISTING PAGE ** R£E~ TRAILER PATE :65/10! 1 Oil, ! t CO##ENT$ .9 '} 1 r,a N "' ?'. C 0 iq T = '."...t T $ 0 0 ij 000 093 800 ,,,,~, ,-,...., 004 002 012 .,,, 0 65 065 O 6 5 0 6 5 0 5 5 = .:;. ~3 = 2.5'~ F ,! ~ L:.) :-'3, 1:;4 ~ ~:~ O A T '~ ,: iL: [< !'," ,~'~ T · NTR'Y ~LL]CtqS TY? :~ ,? (: N T R 'f 'S 3, . L Z © )E! PT ~P 'ALil :CNL ~P }ALi :CNL )SPT ;AL1 ~NR A :CNL )~. PT' ;P )ALi ~NRA :CNL "AL1 ~'5a3 O:30a $i'::t!J :5. 75, "'~., '8 !,'< S C ,..:'":, ? . 3 :;; ':',. :} 2.3 4.7.5 ~ 9 ,. 0 3,3 i 02. :5 2.4 7023.0 ! i a 3 .,. ,e 3 5,7 62~i2, O 2! · a 7 ":-. S 000 :328 375 223 000 £ 39 000 2S3 315 '300 ,3,3 Y 30 0 ': 7 5 _, ,S. 75 iL 2 'T i >,I S It.L? T iNS 0 'q ~-i ~.'..', 2.79 ? 7 i L~-" 6, :>_' 5. 0000 GR 0.0 9 ~,6 NR,CT i '9.87 07 NC',': t -:799.2530 2.. 65 ;.'3 ~ i L, M 7 ] 28.00 00 G ,'~ ,*, ~ i3. 7160 1 4 : 7 37 l L '¢ '7 :.3 ¢ 0 ,, 00 v, 0 ,, '32 J :}, N .:k ,a. T 3.0025 " 33 . 9375 3.7246 1 S.: 5. O0 O 0 -S 99. '2500 3. O0 76 103,9375. 3,7£46 1.~56,0000 102.,5,000 3. 44. i 4 1787 .COOO -':} 9q. ,2500 2.9,50 5 l .I '~ ':~ .... ,.'. _. 7 3.2910 1298.0090 ,- 9 S' '.}, Z 500 14. i i 06 74,5 S 75 2. '74a i 2 :',,,I L ~ ~:,.: P T P ' C :',i ? ':' :~ T ,A L,Z : C N L CN L ~ P T NRA CNL ','~ L ~ : C N L )E P T :, i',,i R g :C NL )E ~T 'C N L :'.NRA 'C N L }dPT .54- ~ 0. :33, 53 S 5 = ,,.,: - i .7 . :) ! '57 '3,, .3. ,57 L 3 i",,~ F'-:: -33 . 022 S T "!,, 5, 5.. 7 ,.:' 15 i,,~ ?. r i ~73.""303 T- x~5 o :)c,,U· u,,~ 9.551,5 5 O 0. :30 "',~ 0 t <} ,,',4,' ;',,:~ b00C.0000 S ,: ,...'j -17.1552 4. C 2.2 ::,, :'3 ID T, ..= ?,.i 5 790 '3.0 '303' S ;' L U -2 5. $2. ! 9 GR ,... · ,..') D 3 · 659') ;"~ P ~ 2 5'70.'300~ '~ ..... ";,,3 '? 800,. 0 O O 9 S FL:j -," ,., .'"' '~ 52, 50G 25. 735! ?'2 :+ ::..? O ? 0 2.2 5: ~ 5 il, ~:14: * ,, . ') ,. :5 ",, ?. '73. 9~ 13~. 5"'50,_ 2. 343~ 4 3' · 2 ;:.:, 2; 2 5S4.-.0~0C, :2.2550 .2 . 5164 :.~3. C t 7,5 5:~ i i. O0 0 O ~ o 19~ ~5'3.t'()Oq 2 .. 25 ~ i 54:50,0O00 l. ,46. 2.500 2 . ~t i 2, 0 4.1i~59 119.!375 5, 7 Z i ,5 1J(}. 12::;0 -"3 9 9, ~5 0 0 -' '3 :~ :3 , :_: c' 0 -9 ~: 9.25 00 ilO.tS'T:: -9 :¢ ?, ~ 2 5 0 0 .. l: P F: 7 ,.~ ,< i L l: T "'2 ~ ":,, .4 ',:. ~) 5 Z ~i ' T "N ~ T f ~'q S 'T' '= N 5 ~, 2 L 2:' "~ ~:,~: ~ ", k,,. .... ' iL ;i T i f{ S 2~ ? ~-{ ,2, I ' ..... 3'4 '- ',... :." -:3 L; :3 . 2:330 r :: L 2.2L£L 13.3 730 ,",;'iNL ~, · ~,,,., , .,:.. .... 565i ~ C N L -':.:; 3 ~. 2. ": ,3 T :: '4 S 2. :~ ,44 4:. 'r - .~ i.. i"! 5 ~::: l 2. C. 9 ,:30 G R S. 0371 f.,: R ,,:: T 4.0 'i' 49 i L 0. C 2 L 5 r',,~R a T .::: _'!,.. ,!3528' N C !",': L - '.¢" :-~. ':'~.. 2 !30 r'~, T ::: :"{,,, 54 O ~.. 0:3 ,,3 O G ;~ "e, 30 ',,, i~t ,-',, T L,4 o C 7 1L NC:'4L -'fi "3 9,2. 5 0,, ~ 'T 5 f..~ S ":, 4 4. '''~ ': ~ L M .... , -, ?: .~ fl ,":, $ q! ~ ,5 ',...; O · .~ ,_, ~ ',.., -9 i) $. 25 .") 0 ,k, R ~ T :)') 9. Z 5,30 NCNL -'599 . ~ 5 ,") ,3 'I' :::: f,2 :,:¢ · ....~ ~, ,~ ¢' ,~ -:33 9.25 '3 itl) f, .'~ ~, T -~ 99. ~ 3S 9 T ~:N S "3 n r:. R ~ ',~, 2 ,'-3, O .......... - 999 ,~ 250 8 !,1 q ,-I l ! . ~'? 50 3.52' .;5 - 9:33 · 2 5 :l 9 2.2227 2,.a355 : ,' 7 S .,~' 0 0 0 - S'39 . 25,03 3.2373 1 ?,S .,5250 ! 757.03'30 2. g ~ 67 ,14.9.9030 3.3915 ~795.00~0 -999.2 5 L~O 269.0090 ~. 936, Z 1696.0020 ~,-. 2 h. 33 3 · 4004 '~ :3 } ~ 0030 :3,35 S 8 ,,,~ -999 . 25 u 9 5,0 :? 91 -979. ..... '~ 5 n. 0 -':? 99,25 r30 -9:79,2 ~ 90 ,-,~ '59 l 5 'J '''~ ; P - Z 3 · 4. :544 ,$ ;~ · ALi -99'9.2500 Ed33 IN R A -9 ~ 9.2 "02 !.,~ o,-i i i E P'f ,5730. 0000 S ~LU ; P - 38. I i: 75 ',3 R ' A L. i -9 '5 ~ o 2. 15 O 0 '.q r,: S" !i0. !,24. 123. _ (:',, :) ,) ,, -' ~.71 5126 2 ':;, C 2 £:'~ 3.2' 2i53 7!:?E 4 "' 55 {~a4 1.!50 . fl ,.. C: 2~00 14 ,?; (~ 3756 .,.503 5 ':;' :3 £ ..i.':700 2503 5:,'75 2:500 2 !50 S i,_% C' R r' 3 3R 2 q r~ :3 i L C T a ~',i S ii. D T::N3 C R H 0 .~ ! L 3 -9 S 9.2 .=. 0 2 N R .:', T .: S ?. 25 O O T'!!~q S -'?'5' 9.2 5 0 9 TE klS 5054.0008 G -':-3 "'.4,' ~ · 2 5 O 0 ~",.i C 7t L iL:,'I TENS 47 7 2,0 0 C, 0 G ? '-9 '? "}. 2 }!~ [], 0!,: ;!: .:','.'. T -.:-~ q F;.~ ~ f 0 ,'5" -97}.25J0 "'" 0 3.90,27 "~ Q ~ 7, L:; - 999.25, 0.3 -999.2500 -3'79.2530 - 99 ~'. 250 0 :2 , ~. ,,... -'99 S'. 2 5'30 I, 744? -'} ?'~. ;2500 -99',F. 2503 -"/~ :;, ~':. 2 ::0f 9.21 SO 4,. I ~,~- 46 :,. 7: 5 -99 9. ! 59 0 "P . }ALi ~,N,~ A -999.25..03 ,N P h 'Z ,.5200 · '3000 S~LO - ")99 · 2500 ;:,; ,~ 2 t -- 99S. 2 JO 0 N F'H l - 9 ~ .... :' "":. S 0 ,-.,'~ T ,_c/.,,,; !; 1.7.~!; ltd ! 33,. ':',': 7 S 0 T ' :',,~ S --;,99.2500 [,'- '~C -9'J~ '" q O O ;3R !, :',:,:.b i 6 iL2 11 a,. ,, 8 .'5 ,..":' ~; T ,f fq S _ c: ~ .:-~. 2 5 0 0 :: ;?-i ,: -S9::}, 2500 O 129. 6250 -9 ':,',': cf . ,2 :: 0 C' -S' 9 ,.4.. 2. 50 O -'S :) ?,. 2 ::: 03 i. :488 iLO i t 9. ::' '? 5 '3 T ':' ?,,15 -. 9 :.:,~ 9,2500 5 ~ ? 0 -:? ~';. 2' '3 3 T: ',; f ~.. 4:5 l 5 l t 47 l". 032,3 'S.{ - ::~ 9 '.-3:. 25:33 NCht . ~. >., 3 T = I",: S ',_'. 9' .: O i iL~-' ..... ~ -999 · '3 3 % ~ ,,' · ,:~; :3 4 ,-': 52. ;'3 '3 O 0 5 R -9 ) 9.2 S 00 N ,~! .,z. T - 999.2 500 I,,' C N ', - 9-~'9.250 $ 'T S :; S 45 ,~, O · O 9 O ~'3 O r:,.,,, -"? 3, 9 ,. 2 d C, C t'.~ :R A ir -'}'99.:2503 T5N: ~.4527 -:,9?. 25 2 O -'} 9. '.-' ? .5 i'~ ." ~.'~37~ -~99.2500 -~'9S.:25~,'0 2.5005 -'}99. 2500 a "' S O O '~gq 2_'5,'.00 -99 '!.7,. ? ,5 ,,1 ri -!,:;, ~ q,. ,7:.500 !. 9917 -999.2500 ,-9 :'99.2. :5,3 0 ','. E P T :} 30,3.2333 S "L d ;P -23. ~?,~4 · A L Z -99 ~'. £ .5, 30 ':t ;m .... :C N L -9 ~ 9.2 S 03 T LN 3 ) E,:~ T !.:. ~ 30 .. GO03 S::LU ' P - 25. 23, 3, i L,, ,::< ' AL" -9 :~ 9. L' ~0 $ R h'-'3 )b PT F 300.00 O0 S FL.U ' '~ L.,." -- -~ 9-). 2:50 ;"",... ,::{ H 2 ( N 2 ,a -:l,~, '9 '5 . .,..:~ .5 C 0 ;',; P r'~ ! : C N L - 999. ?. 500 'T "' ;',', S .i' E ~' T 9200.0000 $::LJ ~,.P -26.7:.500 G~:'' :~ N ,.;,: ,,.; -~ 9 '5.2. 50 ,.) ',,~ r:,, ",,.-,i i : C ;',,i L --9 '.~ 9.250 O T ! P,; S 3:,£ ? T 49 O O. 0'300 5 FL U ~ P -,29.734~ ,:J 2 .l. :3 t '.A iL-'. !ll.i.:'Ts -:? .~ ?. ,:' 500 l' ,: ," i -'? :, ;~. 2 !: 0,3 ,3 q i . 63, .20 ':2 i._ f', g !. ~, 750 'T .::! ')4 S - ~' :} 9 . ,! 50 O !5 ;: fi i '::,:;~ 9. '?~ . .2 0 u, L. ,< 3 ,. 3746 I L 2,' ,.:i ::) :'~, . 2 ."5 "";,., 3 :! ~ hi. ,., ''~ 2.5 ::,- tO * ! L a 2 ;, a. C '33' C: C., -'} 99.2 5 ..'_', 0 :'4 C ~,i L -'..) ) ~. 2 '5 C :3 T E :',! S ,2. ~ 75 T ! L M ,~172,. O30O 5~ - 95 ?. 25 {),'.) i',! R ,:,, T -? ,:)9.2 500 N C ?,: L - ~ .-? ~-. 2 5 O .'.3r ~ ~,,~ S - 'a 99..2:530 ,N ::~ 5 T -9 ::.:,, 5'. 2.503 !'..! C t,.! L -99a.250,3 -~ q :':~ '); :2, r'-, ¢',1 ':,", -~ T -9 Y 9 · 2 5 3'3 2 · '} .5 4 '7 - 5 }9.25 ,} 0 -P .4 9 . 2 3 ,.,, -"~ 9 ~. 2533 -9q9. -99~,.25J0 -999 . '2503, 2. ~075 -'~' :,~ ?,. 2500 - ~99.25'30 -999 . 2500 -999.2500 -"?, 99..i 5 L", 0 3.0554 -?':? { .2500 - 999.25:30 ::":~9 ,2:00 - 99 9 . 25 0 O 3.56 '74. -'a99 ,.2.500 - ~? 9 '~.. ,2 '!~ ,.,,"' 0 -999.!500 .... :.; 9g. 2 ~,3 0 ':. 36 98 - q c 9 "~' 0 ,->,, N ,::,' :CNL ~ N R A :CNL } E P T ;ALI :CNL } "~ P T ' A L i 9 i "' · ,-t 3 ,Z V .7 ?' ':' ,' '" ,... T :L :,,, ,.. 'r .CO00 ":F' U .7931 · 203 i ?: :"i L 5 .... 57B kF:~l · 5 O ~ 0 T E N i 4400. u -23.7 521.5 03'...,'" .: :: l_ J i::,4 ,..L: C' 0 T ','-k' :S '-46 3 ,;3O .67 · O0 00 S 6 ~:- "~ r'i '"'" 5~ NPHi 0 O I: :~,i S 4 :.':' 0 0 '? 34 . 00 °03 · 08 25 O0 FLU P F! ! 0o "'~, -S£. 5 9.7 2.7 903.5 90,: ,5 0 ;3 i 0 9 030 SFLU :2, i7 N P H l TE X.' S 3, 03.0 -7!. :~, 9 ~ q 'u u :] 3 '? 5 S F L U ,;:' ~,: (,'.: 5 i1'!.'750 -955.2530 -9~:¢.25,3(3 -$~5.2.500 ! ,, 0,59' i:' l L 2 ~ 5.4.?. 75 T E N.S " 2:5 ~ 7 [3 ,.: :'-~ .... :i l:. 4573 3 ~ H l :!: '5, :5 6 2. 5 T i::: k' S 2. i 3 36 [:: :.,: d ' 44.2S71 DP.hi 29:5C.0000 6R 78.5i35 iLO 4 a.. · '7 ,..,r':' O 0 T: >,1 $ _. ' ~' R 'H .:~ .... '~:. 20 31 .... P i",', "' ',.:: 074-. 0 O O 0 330, !.357 IL.:) 43 · 21. 8 7 1% :"',: 2 . i '2 ,S 9 [.'"~ :k '~ 75 29n6 C:'Pr -':' '~ .., G ~ , ...... 3$,n:;itO'3 ,a I. C 525 'i" 5 "q S 3. ~.:,!7 iL _ ..:~ r; ?..? :-.. 0 ~ N C ~.,2 L. 3 . E' i 8 '~ ! L 3-', L': ,-. · b'UUw - 9 $9.2, 30 O :'.~R ,i T -'..; ~ .9 ,, 25 ',} 0 I'..; C .",4 L -':i 9 9. 2:5 ~,.,: ',3 T,: ?',; 3 3. ,i i ~ S l L I',.1 "" ? 9 -R ..:. .... i '::" ,,, 0 3 3 ~.:, 0 ." ~' !"xl" ' ,.. i. $ ~ :,', a T 23. 5398 NCNL - ':.:: '.-)S . 2:5 C 9 T E :'{ S ?.227~ -9SS.,15~,0 -9~'?.2530 }. 1:567 - 97'} . 25 0 C - 9"? 9.2500 · - S :~ '9. ,l 5,3 v 3.42.13 9~.43v5 18'B'i.oorjo -'S99.1500 55.209 Ii i 99 £ o 9090 -9 S 9.25 9 0 7,'7824 39,5625 3,537! 1791.0000 -9':~$.2500 <5 I. 1.77 15 ,~ 9 ,., 7500 ~. 266 · O O :_:, 0 - 999. 250,3 !35.34'70 '43.2!S7 2.5371 2450.0000 -599.2500 0094 0 ~ 2 S 39 ~<'J 4 ]~Li :CNL 3EPT .~P :.AL1 :C.NL -C N L :CNL : '",3 N L 3 i:.: p T :CNL :ALI ::C 3 E ? T' SP "AL,'.,. -37.021: .... ],. I · '3 'l 55 % "" C, - 9 ::l. q.. 25:3 O "~". ::' ''~ i -99~.' 500 ~thS 33, .3 '3 · C 0 '3 C.;S != L U - 4. 0.5.303 G ~,~ -999.25010 - -~ '~ '3 · :,-" .50 ':,) T -' ": S -4. 9 · 2. 5 ! "3, C-, - :~ ¢ q.. 7 .,-:, O ;,3 :.,"" ,~ - ' -9 '-~ ',9.2 } 00 i "N S 3,50'3 . 0:3 O 3 S': L J -34.73,.13, .52 -99!3.2500 3500,,,0000 ,5. F L d -99 '} · :2 5 ,'.30 N P ""I, l -999. :2 ,'500 T ~ f,i .5 3300.0000 5FLj -9 :} :9. Z 50:3 G R - 9 ,q 9. Z 500 k, F' !"-i l - 999.2500 T ii',i }~ - 999. ?_ !50 J G ;':, - 9q 9,. 2. 509 R HC !- -:) 9 '). 2 .:500 ,:",,,J :' >i i -5'99.2 5 O0 T ' N S 3103.C'300 $i=:i U - ~' 99 . 2 :.'3 C,':. 0 3 ;:; -:29 '~, 25 ~,30 ,:~ m i: .!5 3. :5 ':3' l 7 i L 2 i 0 '::", .., g 375 T L ,"., S - g. '-~,.., 9 · 2" _:13 ,", r,_ e ? - 9 99. Z5 J C C F'~' i -g 29. 2503 :,-,4 ~,:: 5 .~164 !L5 '35 ,, 0625 T ,~'! :',,~ S -~ 99. 2 :'500 [} R .""', C -9 '? ':,,~., 2 . ~': 00 .'r L :J.. - 9 Y 9.2_ 5,30 T E f',,,i 5., -9 'ii "~. ,7590 5 <:: ,"; l -9 i! 5'. 25 ,'3, 0 .'_'. F." ~ l -9 59.2 5 0 0 {.: :~ -'999.25 ":3 C, 5 F,: ~ C, - :~ :) 9 · 25 ;3 C '?' .;',' d" _ c;,, a. 9.2 ,S ..,, ''~ 0 (.:,:, -5 ) ~r,. 2:i00 -. 'i.; 5 ':ii ,., 2 ¢ O O T ;!i f,,: S -i} 59 ,, ';' ':~ 00 fl: F' ?'i -999. 2500 Gq 0,3127 -' "~.25'?..., '~ ,.5,. 0 S ''~ 0 i L 2794-.00,30 -999, 2590 !'.,,;RAT - ..99 9.. :Z 5,3 0 ',I C t'.,.; L 90 · 62 5 O T'!h/S - 999. '2 :.5, '30 i L M -95' '9 ,,,, 250 '3 G, R '-999 ,,, 2 ,...4 .':2, 0 N R ,~ T :~" :} · 2500 'v - ,, ,, C t,; L ,:59 · 3750 'T E i'.,i S - 9 t:., 9.25, ,'.3 O t L -5;' ",} 9 ,,, 2 530 G R 54..,,4375 'TENS - !ii' '-~' 9 ,o 2!i 5 !} 0 ! L, - ~ 35 · 2500 'S R - P ') 9. ?r.." 0 "3' ?,.i C ,N L 5 !,5, ,, 95, ,:5; 7 T :{:"', S" 97.1875 3.7537 -9~9.2530 -'~99.2500 5.76,5 '} -97'a .25,00 -'} :~ ~. '.250 C' -~? ~. 25,. 00 3.5927 - }9'9. 25.," 0 -g99.'~qgn -099.250,2, 5. - ? 99 o 250 0 - ? :9 a,:..~? "' 0 .,, ~, ,a ,'::, ? · 2. ,50 ? ,Z78~,. 000,3 -979.2'5 O0 - 9'99.250 O -999. ,25:} 0 -9 :a .'::.. 250 "' 26, 20.000 O -999,,2500 -:~ '} '7 . 25 ,'30 -99'3 · 250,0 -'997 . Z,500 258 O . !3 O O 0 9a'9..>- '~ -- .,,, _DOid ~:' ~'::~ 5', 25 ? 0 'AL" :CNL ~,? :CNL 1) E PT b I-' -,., N r,, A :CN ,L ~F~ q N R ,a :'CNL D,'} PT CAL..7. R I'",~ R A F C },;i L ;D i',[: F T S P C .,:~ L ..~ :' ') 0 0 . '3003' 5. ~':L U -99 }'. 2: ,3 '0 C-< -99 '9.250 ;} ,':', ~ 2S;30 ~.n30 ,3 =Lb -999 · 2, 5 ,':' 3, G R -99 '~ · £ ~ 0 ,..,' .:,: --i :] 5 -99 '~ · .25, 03 N P h .,. :'70;3 '3990 qFLiJ - 99. :2 ~ t,,"' 3 r, ,.? - 99 '~., . 2.': 5 u"" } ~",~ ? H l - :) ~ 5'. ;2503 I :: ¢,; .5 26'3;3,23,00 -99 '9. ;;.: :,:; 03 - 9'~ 9.2500 -:'-) 9 9. 2,500 .2413 O. 0 C'O:J SFLJ _ ci ,': ::~ 2 5 "" ' ...... ,,., 0 '] R '-9 :)9.2 :!53 "3 k "? O 5 230'3 - 9 ':.")9 - ~ 99 -999 2200.00,90 -9 :-} 9, E 5 O 0 ;4: ,~ i ,(!::, -?. ) 5 ,, '2 -300 l L L, - :J, ':)9 . ':'5 ,,5 O T :: :"4 S -'::;, '} ~. 253 0 6 :i -":' ) '~ ,, 2 .... ~:: ",,, ,..,n - k ~,..t "':, -:9 '} }. 2 5 0 O %R -9 '.)9 ,.. 2 ;~ ',30 -r. L C, -9 ,,:~ 9 . 2500 T :: :,',i 5 -93- 9.2 .50 C, ;.} R H '3 _ c; ::~ '.4: . E 5 "'" '''~ 5 ~ ,.4 '"' ~ :~ 9.25 0 0 T ~ i,.,l S -99 '~ o 25, 00 ,:7 ~: ,-49 - :? ..J ~. 2 f: 00 9P H l .... ",e ":" ~) _c, aq, ,.-.500 G . "' O t L ?' :,} :'.4 $. 2 '5 ,,,,, .... - ":2 ':~ 9. f 50 () T ~i t{ 5 -999.25 t':, O ':) :> i-'t, 'i - 9 :?, 9. ,:: 5 0 0 G ~,i: - 9 } 9. ? 50,3 '::R :4:3 _ o ~; c,. 25.-,,.; -':' '~ 9.250 ' 'S r.:.; -}9:).2' 39 :,".~,q:T - .:'. -:,, q. 2S"9 X C"' k ~.l:..73.75 T-t,'S - 9 '99.25 ',3 '3 r.' ~1 - 9 :)'9. ,_': 5 L:; O:..' ,,::; a, 7' -'9 9 ~.. 2 5, 0 0 ', C N L q. 7.3125 T L:. ~'.~ S - :} ':., 9 · ,25 !:,', 0 i L ..,r., -p,':i .':~,. £-; 3 v" 2-' q "'?' a., · 2 ~ 30 ~',;.s, ..::. T - :~ ,:J 9 · 2 5 C: 9 I',, C N L 5 ! · 4 O ? ,~ T:!~N S _ c,, 99 .o ,2 :': ,..,' ,3 l ' .,'""~, -':'7' '99, :2530 :3 - ~5:;'. 250'3 N A'. A T - 9 9 9 · 25 0 O NC.:'4 L :52. C :5 ,'.,_" 5 T ~ ?~ $ -999. 2500 ELM -9c0 "5 '''~0 -q .... . ,, .::t v L: -9 -)9 · 2, 50:3 i'( ~", ,~ 'T - a :} ':}, 25 "' ~'i k, C t',; t .54.8 1,25 T E !,.~ ,5 -999.2 f':';3 O ! L -? ? 9 . 2503 G R - S9 % . 2500 N;,:: ~'a,T - ':} 9 }. 2 50 3 h C !',~ L 59. '7,513 T ;': '>,i S -9 ~; 9 · ,;2 !-500 i' :",! -S':}'5.' 5,}3 -9 ~' 9 . Z i' ,3.? - :} 9 :~ .2530 - :} -~ ? · £ 5,30 1;' '~' *,. -q. , 0 ' a" -) 9 ':~ ·15,3, 9 -'} '::, ? . 25 ,3 O -}')9. 2500' · 4-C =. 30,?, 3 -'999.2 5 3:3 -?,, 'i-} 9. £ "00 - 99 "..:.. 25 ,'3 O -999. 2500 *:~,74 OhO0 -995.2500 -99~.2500 -gq9. :)z,~ .'23~0.0000 -'9 }'9.2 50 O -999.25, 00 _ aS :: · 25 n v - '? 99. '":' --999.250? - 99':;'~, 2.500 -9 '9 ':-". £ 5 00 ':' ? n 4 ooon -999 - 9 c~ :9 226 a "; E P T : '3 '3 0 · $ ", 0 '3 S F' L ~ :: t.,~ ;~ ,.:, -) ~' ",~ · L .¢ 0.3 ,'.; ';: ~ :: . ~ ', T : C ?',J L -':~ 9 ,') 2 5 '.., 3E ? T l 7 O O. O O, 03 S ~LU S P - ~ 99. 23, 0 "",..., r:,.,,, r,~ ,,.~., N R ,a, - :;. ,.} '-} ,.. Z '5 ,..,"'" O i',,i ?' ~','~., i F: C ',.t L - 999 o ;."' ~ 0 O T E .,'*,~ 3 3'E F T l 50 O. 000,3 5 P L,J q p _ c.~ 9 ~.,:_: 150 '3 & ;~ i',,J R A - 99 ":'} ,. Z !5:30 t',.i ,o H' I '] E ? 'T 1 4 L') O. 0 0 I..,3 O,S =' ij S P -:)':):?. '2 5 0 0 G ,q C A L l -'~.-) 5', ;! .5 00 R i.~ '32 R N R A - 9 9 9,2 5 0 '3 ':',,~ ~ '?i Z ;CNL -:.~'.) q >5,'3,3 "' N C ~ L i - $ 9. ;::', ,, ;': .,.': 0 ,~,."' ,.-,~" !.4 i; ~ - f.) -,-., ':i,:,, 2. ,'..5 ,,."" 0 Z L 2') -?.' '} 3.2: fi{ 00 T :. ;'.,! .q -9 9 :} .,, '2 5 0 0 ~; ;~ !-", ,3 - f ?.' ~. :" :~ 'l' :} "i C, '% L. -99 '-}..>' 50 "" "L -.~ "} 9.2 .-3 '23 3 ;,. - 9 '~ 3.230 '3 :'..: ~: .i T ":3 · £ l ': 7 T ' ~.,:S -95'9..'.'_*590 .T. L t.'1 -'} ':J 9. ,25 ,] 9 ,3. q -:} ,} 9,2.530 p,, ',:.t: .,.; T -9 }' 9.2 :::. 2 '3 t',~ C X ~ 4 9 o '4. 6 :} 6! T -",i S - 9 ')' '~. · 2 - n. ,.,n N 2 ~' T - % f;' 9 · 2,.: ~, O 3 I',4 C t,...! L 2 ,?.. · 7 'a '5 } 'T ,! iX '5 -99 ,q · 2'533 _'~ '.c, 7.250 O -997'..2500 -99'}. 2503 _uS?;.OO C, -S ':. '}. ''~ 5 ,] C -999.2. ~ 00 -9 9 '".,¢'. 253 0 ,il 1'3. O 00 O ~ ,,2 -.-)99. ?590 -F,'. 9 '-;,. 2 5 O O 2O73,,OO:30 -999' . 25 O0 -999 -99 ',q. 25 't', 0 .-"}99 11050.00'30 -999.2~00 i*'t 0 ~r q "~ 9 o -999 · - %'9 9 .. 2 1590. gO00 '- ? 99 . ~ :5 0 0 '"} 'i-'" 9 2 5 r~ -97}9.2530 ;':: P T 1 l 33.0 C ;30 _~ ::t'.; , ,,-, -'3 ~; :}. $ ~, 'L, 3':3' 'At ;- -}~$.i 3,3 ' ' h,, q' A -~$5.2 53,.: -~ :, c, . 25 :"," -9'59 . 2 ~ 00 3':'h i -'~'~ 2 ~:r'''' 6q' -95, 9 · 2500 2 ?: r,3 -999.2,500 '2, P ~ Z -':)S9,.i50'3 ',59,}.00'30 -'} 9'9.2520 -'}99 ,. 2 .:,. S S -9}9.2530 -'99 ,-3..'2 500 ';,':,23 q3'3 ! ¢ 5:3. n 0'30 -'~ 99. £ 33,3 -999.2303 ~ =,20,()09u'
