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183-165
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2V-04 KUPARUK RIV UNIT 2V-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2V-04 50-029-21041-00-00 183-165-0 W SPT 5603 1831650 1500 1800 1800 1800 1800 360 580 580 580 4YRTST P Bob Noble 6/14/2024 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 2V-04 Inspection Date: Tubing OA Packer Depth 500 2610 2545 2530IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240616141109 BBL Pumped:1.6 BBL Returned:1.5 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 12:40:53 -08'00' ORIGINATED TRANSMITTAL DATE: 7/16/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4884 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4884 2V-04 500292104100 Injection Profile (IPROF) 17-Jun-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 183-165 T39213 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 11:48:49 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-27_15914_KRU_2V-04_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15914 KRU 2V-04 50-029-21041-00 Coil Flag 27-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:183-165 T37582 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.06 13:44:13 -08'00' Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 907383247 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-21 0 12 2M-19 50-103-20158-00 907335394 Kuparuk River Multi Finger Caliper Field & Processed 19-Aug-21 0 13 2M-19 50-103-20158-00 907335394 Kuparuk River Plug Setting Record Field- Final 20-Aug-21 0 14 2M-27 50-103-20175-00 907335397 Kuparuk River Plug Setting Record Field- Final 18-Aug-21 0 15 2M-33 50-103-2024-00 907316545 Kuparuk River Packer Setting Record Field- Final 8-Aug-21 0 16 2N-333 50-103-20525-00 907331967 Kuparuk River Radial Bond Record Field- Final 17-Aug-21 0 17 2N-333 50-103-20525-00 907383501 Kuparuk River String Shot Record Field- Final 13-Sep-21 0 18 2T-207 50-103-20287-00 907326322 Kuparuk River Packer Setting Record Field- Final 15-Aug-21 0 19 2V-04 50-029-21041-00 907398078 Kuparuk River Correlation Record Field- Final 20-Sep-21 0 110 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 1-Sep-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϭϴϯϭϲϱϬ Ͳ^Ğƚ͗ϯϱϳϬϳBy Abby Bell at 10:25 am, Sep 23, 2021 MEMORANDUM TO: Jun Regg P.I. Supervisor n �--Ajpk L2( , FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2V-04 KUPARUK RIV UNIT 2V-04 Ste: Inspector Reviewed By: P.I. Supry �7 bl Comm Well Name KUPARUK RIV UNIT 2V-04 API Well Number 50-029-21041-00-00 Inspector Name: Adam Earl Permit Number: 183-165-0 Inspection Date: 6/14/2020 Insp Num: mitAGE200617113856 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2V-04 lType Inj w TVD 5603 Tubing 2340 2340 - 2340 - 2340 " PTD 1831650 IType Test SPT Test psi 1500 IA 360 1820 1760 t760 - BBL Pumped: BBL Interval 4YRTST Returned: OA 80 - 90. P/F P 85 RS ' Notes: MIT IA Wednesday, June 17, 2020 Page 1 of 1 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: n AOGCC ..t ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 'eft Anchorage, AK 99501 183155 30 50 2 ' • r • 27 -Mar -19 TRANSMITTAL# _W27ommMar :02 WELL NAME 1E-104 API # 50-029.23234.00 ORDERSERVICE # EA77-00006 FIELD NAME DESCRIPTION KUPARUK RIVER DELIVERABLE WL DESCRIPTION ]PROF DATA TYPE FINAL FIELD Color DATELOGGED Prints 20 -Feb -19 r 1 1A-05 1H1A-07 -118 2A-17 2V-04 1H-114 3C -15A 50-029-20627.00 50-029-20658-00 50-029-23578-00 50.103-20193-00 50-029-21041-00 50-029.23584-00 50.029.21426-01 EOSH-00028 EOSH-00029 EOSH-00030 EA77-00009 EA77-00010 EOSH-00031 EA77-00011 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL1 WL WL1 WL IPROF (PROF IPROF Caliper IPROF IPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 16 -Mar -19 17 -Mar -19 18 -Mar -19 18 -Mar -19 19 -Mar -19 19 -Mar -19 20 -Mar -19 1 1 1 t 1 8 Transmittal Rec�ai t A Transmittal Receipt signature confirms that a package (box, l� envelope, etc.) has been received and the contents of the X C' l package have been verified to match the media noted above. The rint Nam Signature Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy t chlumber er and CPAI. not have been verified for correctness or quality level at this g point. Alaska PTSPrintCenrerna clh r., r,..., Schlumberger -Private STATE OF ALASKA • RECEIVED ALARA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 0 6 2017 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ dirhicti s. tdown ❑ Performed: Suspend ❑ Perforate LI Stimulate I=1 Alter Casing CI -gram ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MARCIT GELTRTMT 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 183-165 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-21041-00 7.Property Designation(Lease Number): 8.Well Name and Number: KR 2V-04 ADL 25644 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,675 feet Plugs measured None feet true vertical 6,203 feet Junk measured None feet Effective Depth measured 7,571 feet Packer measured 6927, 6997 feet true vertical 6,109 feet true vertical 5544, 5603 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 feet 16 " 110' MD 110 TVD SURFACE 3,085 feet 9 5/8" 3,121' MD 2668 TVD PRODUCTION 7,626 feet 7 " 7,662' MD 6192 TVD Perforation depth Measured depth 6947-6949,7188-7240,7327-7335,7344-7373 feet True Vertical depth 5561-5562,5768-5814,5891-5898,5906-5931 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,308' MD 5,874'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER F-1 PRODUCTION PACKER 6,927' MD 5,544'TVD PACKER-BAKER F-1 PRODUCTION PACKER 6,997' MD 5,603'ND SSSV- NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Sat* DEtt 2 22017, Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: o e 2900 250 833 Subsequent to operation: 0 0 350 200 1188 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-320 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer /� Contact Phone: (907)265-6097 Authorized Signatur4111r -•� — Date: V TI.- /-7./ //77— RBDMS Lt NOV - 7 7017 Form 10-404 Revised 4/2017 , (Wili7 Submit Original Only KUP I •ConocoPhillips41lip5Well Attribute Max Angle&MD TD Aldska,Inc, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConocWriilhps 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-04,11/2/201712:00:0 PM SSSV:NONE Last WO: 1/2/1988 41.49 12/17/1983 Vertical schematic tactual) Annotation Depth - Date Annotation Last Mod By End Date Last Tag-RKB 1 1 1 Rev Reason:TAG 8 MARCIT GEL JOB SEE pproven 10/19/2017 HANGER;35.2 /.0?.. NOTES )1 II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(fIKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread d : 4 CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H-40 WELDED ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 36.7 3,121.2 2,668.1 36.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 36.7 7,662.2 6,191.8 26.00 J-55 BTC Tubing Strings �^-CONDUCTOR;37.0-170.0^ Tubing Description String Ma...ID(in To ftKB Set Depth ft..{{Set Depth NO Wt Ib/k (IGrade Top Connection 1 1 Completion Details 31/21 )2.9921 p( 35.2 6,939.01 p (5,554.0-UPPER 1 ( 9.301 L-80 EUE 8rd Mod f Nominal ID SURFACE;36.7-3,121.2 [ Top(ftKB) Top(ND)(ftKB) Top Inc!C) Item Des Com (in) 35.2 35.2 0.05 HANGER VETCO TUBING HANGER 2.992 CASING PATCH-WLM;4,010.0 6,918.7 5,536.8 32.26 LOCATOR GBH-22 LOCATOR 3.000 -4,030.0 6,919.5 5,537.5 32.25 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 Si Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;6,864.4 TUBING-WO-2015- 31/2 2.992 6,926.6 7,013.21 5,617.2 9.30 L-80 EUE 8rd Mod SQUEEZE PERF ISO PCKR-4.75"x3.5" Completion Details Nominal ID LOCATOR;6,918.7 Top(ftKB) Top(NO)(ftKB) Top Incl(") Item Des Com (in) ".�,' 6,926.6 5,543.5 32.16 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER;6,926.6 _ _ PACKER SEAL ASSY;6,919.5 '_` ■ e"c 6,929.9 5,546.3 32.12 SBE 80-40 SEAL BORE EXTENSION 4.000 SBE;6,929.9 6,949.3 5,562.7 31.87 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 CMT SOZ;6,947.0-8,949.0-i i 6,992.9 5,599.9 31.31 LOCATOR GBH-22 LOCATOR 3.000 6,993.8 5,600.6 31.30 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 4 Tubing Description String Ma...ID(in) Top IRKS) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/t) Grade Top Connection 411 TUBING-WO-2015-C 31/2 2.9921 6,996.7 7,262.21 5,833.3 9.30 L-80 EUE 8rd Mod SAND ISO PACKER- 1 4.75"x 3.5" LOCATOR;6,9929 ,;�, Completion Details PACKER;6,996.7._ ' I Top(ftKB) Top(TVD)(ftKB) Top Inci('I Item Des Com Nominal ID SEAL ASSY;6,993.8 SBE;7,000.0 II 6,996.7 5,603.1 31.26 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 va, PACKER ;'Mf 7,000.0 5,606.0 31.22 SBE 80-40 SEAL BORE EXTENSION 4.000 11 7,019.4 5,622.5 31.02 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 11 7,181.7 5,762.8 29.34 BLAST JOINT BLAST JOINT 2.992 AIE 7,201.4 5,780.0 29.13 BLAST JOINT BLAST JOINT 2.992 GAS LIFT,7044.6 FAt _ 7,255.2 5,827.2 28.42 LOCATOR GBH-22 LOCATOR 2.990 7,256.5 5,828.3 28.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt Ib/k) Grade Top Connection GAS LIFT;7,102.7 TUBING-WO-2015-A 31/2 2.980 7,257.5 7,288.11 5,856.2 SAND ISO PACKER- 4.75"x 3.5" 11 Completion Details Top(ftKB) Top(ND Nominal ID BLAST JOINT;7,181 7 )(ftKB) Top Mein Item Des Com (in) IPERF;7,188.0-7,2400 : 7,257.5 5,829.2 28.39 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 BLAST JOINT;7,201.4^ PACKER ,a 7,260.8 5,832.1 28.35 SBE 80-40 SEAL BORE EXTENSION 4.000 7,265.2 5,836.0 28.29 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.970 LOCATOR;7,256.2 31A 7,269.8 5,840.0 28.23 NIPPLE DS NIPPLE 2.812 _- 7,277.3 5,846.6 28.13 LOCATOR GBH-22 LOCATOR 2.980 PACKER;7,257.5 SEAL ASSY;7,256.5s :`:a 7,278.0 5,847.3 28.12 SEAL ASSY 80-40 GBH-22 BONDED SEAL ASSEMBLY 2.980 a- Tubing Description 'String Ma...IID(in) 'Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...I Wt(Ibkt) 'Grade 'Top Connection SBE;7,260.8 `-; '� TUBING-WO-1988 31/2 2.992 7,279.0 7,308.9 5,874.6 9.30 J-55 EUE8rdABMOD +llr Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) NIPPLE;7,2698 - 7279.0 5,848.2 28.11 PACKER BAKER'FB-1'PERMANENT PACKER 4.000 . 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION 4.000 7,301.6 5,868.1 27.81 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 LOCATOR;7,277.3 7,308.1 5,873.8 27.75 SOS BAKER SHEAR OUT SUB.ELMD @ 7292'per SWS 3.000 IPROF on 5/19/1999 PACKER;7,279.0 SEAL ASSY;7,278.0 l-FF SBE;7,281.5 'f; Perforations&Slots ghot 11/ Top(ftKB) 13bn(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com NIPPLE;7,301.6 " 1 •1 .1 Squeeze 1 CMT Gun size and phasing ll SOS;7,308.1 i • Z not documented. 1it 1 7,240.0 1 IPERF 120 2V-04 CSG Gun I 7,335.0 5,890.61 1 IPERF 90 IPERF;7,327.0-7,335.0--. I TT IPERF;7,344.0-7,373.0 I TT PRODUCTION;36.7-7,662.1 V;k KUP I. 0 2V-04 ConocoPh llips z.y . Alaska,Inc - Cor oCchhil4ps .. ••• 2V-04,11/2/20171200:10 PM... ... Weigel schematc(actual) ... ._. HANGER 35.2 Mandrel Inserts se oni li ' Top(TVD) Valve Latch Port Size TRO Run ..,,.......e..e.....,....,.e...............e y... N Top(5KB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Coin I . .. 1 6,864.4 5,491.0 CAMCO KBMG 5.39 GAS LIFT DMY BK 0.000 0.0 4/12/2015 DCK- 2 2 7,044.6 5,644.1 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000 0.0 3/26/2015 -,,-ti CONDUCTOR;37.0-110.0- 1 3 7,102.7 5,694.3 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000 0.0 Notes:General&Safety End Date Annotation 5/7/2010 NOTE:Confirmed Packer leak or behind pipe channel up from TTL to C-Sand w/WFL 8 PPROF 10/9/2017 NOTE:PUMPING FULLBORE MARCIT GEL TREATMENT,PUMPED A TOTAL OF 33,253 BBLS OF MARCIT SURFACE;36.7-3,121.2 GEL CASING PATCH-W LM;4,010 0 -4,0300 GAS LIFT',6864.4 itt It in LOCATOR 6,918.7 5. PACKER,6,926.6 SEAL ASSY,6,919.5 I '. I SBE;6,929.9 CMT SOZ,6,947.0-,949.0— Via,t Ir St LOCATOR,6,992.9 PACKER;6,996.7 SEAL ASSY,6,993.8, SSE;7000.0 1.. • V 12 4 II GAS LIFT;7,044.6 w 1 i GAS LIFT;7,102.7 BLAST 7,1400 — I ,1880 IPERF; 7,240.0�— BLASTJOINT; 7,201.4 it it LOCATOR;7,255.2 ME PACKER;7,257.5 SEAL ASSY;7,256.5 -I 'T '- SBE',7,260.8 � " It wr NIPPLE;7,269.8 LOCATOR;7,277.3 IL Z PACKER,7,279.0 SEAL ASSY;7,278 0, SBE,7,2815 t Oi at I I NIPPLE,7,301.6 I SOS,7,308.1 ii- IPERF;7,327.0-7,335.0—.1 . IPERF;7,344.0-7,373.0—. PRODUCTION,36.7-7,662.1 • • • 2V-04 MARCIT GEL TREATMENT DTTMSTI JOBTYP SUMMARYOPS 10/5/17 MISC RES PUMPING MARCIT GEL TREATMENT, INCREASED CONCENTRATION SURV TO 8000 PPM, AS OF 17:00, 3128 BBLS OF 8000 PPM GEL HAVE BEEN PUMPED AND WHP = 1661 PSI, IN PROGRESS. 10/5/17 MISC RES PUMPING MARCIT GEL TREATMENT. INCREASED CONCENTRATION SURV TO 10,000 PPM AND DROPPED RATE TO 2.1 BPM, CURRENT WHP = 1580 PSI AND APPEARS FAIRLY STABLE, WILL SWITCH TO 12,000 PPM CONCENTRATION IN THE MORNING, IN PROGRESS. 10/6/17 MISC RES SWAPPED TO PUMPING 12,000 PPM CONCENTRATION MARCIT GEL SURV AT 09:15 AND HAVE PUMPED 989/3000 BBLS FOR THIS LAST STAGE, INJECTING AT 2.2 BPM AND WHP = 1759 PSI AND REMAINING FAIRLY STABLE AFTER AN INITIAL INCREASE AFTER SWITCHING TO A HIGHER CONCENTRATION GEL, IN PROGRESS. 10/7/17 MISC RES COMPLETED PUMPING FULLBORE MARCIT GEL TREATMENT, SURV PUMPED A TOTAL OF 33,253 BBLS OF MARCIT GEL WITH AN ESTIMATED NET PRESSURE INCREASE OF 790 PSI, JOB COMPLETE. 10/22/17 MISC RIH WITH DJN, TAG AT 7309' RKB, CLEAN OUT WITH SLICK DIESEL RES AND DIESEL GEL DOWN TO 7440' RKB. JOB COMPLETE SURV y of Tk .\\\1//, �� THE STATE Alaska I'M and Gas fir Conservation Commission .lt .i,t _ ._ 333 West Seventh Avenue C GOVERNOR BILL WALKERvielYNwM Anchorage, Alaska 99501-3572 OF _ Main: 907.279.1433 ALA�J1l�e' Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer SCANNED JUL 2 02017 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2V-04 Permit to Drill Number: 183-165 Sundry Number: 317-320 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (4)2 ( Hollis S. French 4`• Chair kg DATED this day of July, 2017. RBDMS L JUL 1 7 2017 • 0 • RECEIVED • STATE OF ALASKA JUL 1 12017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL TRTMT2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development El 183-165 3.Address: Stratigraphic ❑ Service 0 . 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21041-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' KRU 2V-04 . Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25644 • Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,675' 6,203' . 7571 . 6109 , 2290 7302 NONE Casing Length Size MD TVD - Burst Collapse - Structural Conductor 73' 16" 110' 110' Surface 3,085' 10" 3,121' 2,668' Intermediate Production 7,626' 7" 7,662' 6,192' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6947-6949,7188-7240,7327- 5561-5562,5768-5814,5891- 3.500" J-55 7,308' 7335.73.44-7373 • 5898,5906-5931 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 85-40 F-1 PERMANENT PRODUCTION PACKER - MD=6927 TVD=5544 PACKER-BAKER 85-40 F-1 PERMANENT PRODUCTION PACKER ' MD=6997 TVD=5603 SSSV; NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development❑ Service U 14.Estimated Date for 8/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com 1/e1//7 Contact Phone: (907)265-6097 Authorized Signature: Date: COM ISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31-7 - 3 2.c) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No l RBDMS I,(./JUL 1 7 2017 Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: /D —I.0!� APPROVED BY ' hit I Approved by: ip• di, - COMMISSIONER THE COMMISSION Date: p_n� � 'e 740- OW, '' , A rt- q/J /, Submit Form and V A 1 Form 10-403 Revised 4/217 ' ` v . .. ' a'. - valid for 12 months from the date of approval. Attachments in Duplicate At 00/77 • Proposed 2V-04 MARCIT Gel Treatment 2V-04 is a slant, dual selective injector in both A & C sands. The well had a packer leak and therefore,the C sand could not be shut-in.A rig workover was completed in 2015.However,high injection rates were observed even after the rig workover. The TMD3D log indicated that all fluids were still going into C sand and the 2015 injection profile indicated that there was crossflow from A sand to C sand at low flow rates.2V-04 is a high injectivity well(-4.6 bpd/psi)with low injection pressure (1240 psi). Since injection is overwhelmingly going into C sand, this well is not supporting the A sand in the area. The well potentially connects to the adjacent conductive fault. Offset 2V-16 producer strongly connects to 2V-04,but has been on A sand production since 2007. 2V-04 also has connections to 2T-13, but this well has been a long-term shut-in well due to subsidence issues. The objective of the conformance treatment is to reduce injectivity into C sand and improve injectivity into A sand/A potential difficulty is mitigating crossflow from A sand to C sand. Procedure 1. Perform MIT-T and MIT-IA on tubing and inner annulus to confirm integrity. 2. Sand back to isolate the entire A sand and place graded calcium carbonate on top. 3. Conduct a step rate injection test to set a baseline before job execution to compare against the job rates and pressure. a. Start at an injection rate of--2000 BPD or— 1.39 BPM and establish stable conditions for 4hrs. b. Step injection rate up to - 3000 BPD or—2.08 BPM and establish stable conditions for 4hrs. c. Step injection rate up to —4000 BPD or—2.78 BPM and establish stable conditions for 4hrs. d. Step injection rate up to — 5000 BPD or— 3.47 BPM and establish stable conditions for 4hrs. 4. Pressure up inner annulus to 500 psi. 5. Start injecting produced water until gel is mixed. 6. Once a stable rate and pressure has been reached and the gel is ready for pumping, start gel pumping as shown below at the desired concentrations and rates in stages. Final two stages (7,000 ppm and 10,000 ppm polymer concentrations) of polymer injection will need to be with seawater. Keep polymer concentrations as stable as possible and provide pump rate and pressure data. Monitor changes in pressure as this may be an indication regarding the nature of the void space conduit. Target Concentration Design Volume Treatment Rate Total Treatment Rate Target Polymer PU24 Polymer Concentration (ppm) (bbl) (bpd) (bpm) (#/day) (ppm) Days 3000 12000 4500 3.13 4720 5400 2.7 5000 9000 4500 3.13 7867 9000 2.0 7000 6000 2500 1.74 6119 7000 2.4 10000 3000 2500 1.74 8741 10000 1.2 Total 30000 8.3 i 7. Evaluate pressure changes over time to target final pump rate and pressure 8. After pumping the gel, inject 39 bbls of produced water and then 22 bbls of diesel for surface freeze protection. 9. Once gel has been displaced, monitor the pressure for— 1 hour. 10. Leave the well shut-in and wait for gel to cure—4 days to allow the polymer to cross link. 11. Perform a fill cleanout to remove sand back. 12. Bring the well online (start from 25%of target rate) and gradually increase the rate. KUP • 2V-04 Ct)nocophidip5 Well Attributes Max Angle MD TD • Alaska Inc . - Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(kKB) ,6amcoNHIips 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 ..° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2V-04,7/6/2017 11:55:04 AM SSSV:NONE Last WO: 1/2/1988 41.49 12/17/1983 Vortical scnemanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,331.0 4/18/2015 Rev Reason:TAG,GLV C/O,PULL RHC PLUG, hipshkf 8/24/2015 HANGER;35.27ilti- PULL CATCHER/PLUG Casing Strings Camng Description OD(in) ID(in) Top(ftKB) Set Depth WEB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J_ CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread uw,,,,,,„,i,•i,,,,,,,,,,,,mi.„„i,,,^m I ens SURFACE 9 5/8 8.921 36.7 3,121.2 2,668.1 36.00 J-55 BUTT I I ICaning Description PRODUCTION OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 7 6.276 36.7 7,662.2 6,191.8 26.00 J-55 BTC Tubing Strings -,1,-ti CONDUCTOR',37.o-1100 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING-WO-2015 31/2 2.992 35.2 6,939.0 5,554.0 9.30 L-80 EUE 8rd Mod -UPPER Completion Details • Nominal ID Top(/k(B) Top(TVD)(5KB) Top Mel(°) Item Des Corn (in) SURFACE;36.73,121.2 35.2 35.2 0.05 HANGER VETCO TUBING HANGER 2.992 • CASING PATCH-WLM;4,010.0 6,918.7 5,536.8 32.26 LOCATOR GBH-22 LOCATOR 3.000 -4,030.0 6,919.5 5,537.5 32.25 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 • El Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS UFT;6,864.4 TUBING-WO-2015- 31/2 2.992 6,926.6 7,013.2 5,617.2 9.30 L-80 EUE 8rd Mod al SQUEEZE PERF ISO PCKR-4.75"x3.5" Completion Details Nominal ID LOCATOR;8,918.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) . :, 6,926.6 5,543.5' 32.16 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER;6,928.8.E �_ PACKER SEAL ASSY;6,919.5I 's F: 6,929.9 5,546.3 32.12 SBE 80-40 SEAL BORE EXTENSION 4.000 SBE;6,029.9 6,949.3 5,562.7 31.87 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 CMT SGZ,6,947.08,949.0 r 6,992.9 5,599.9 31.31 LOCATOR GBH-22 LOCATOR 3.000 '*' 6,993.8 5,600.6' 31.30 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 IFTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(NO)(...Wt(lb/ft) Grade Top Connection IS TUBING-WO-2015-C 31/2 2.992 6,996.7 7,262.2 5,833.3 9.30 L-80 EUE 8rd Mod SAND ISO PACKER- 4.75"x 3 5" LOCATOR,6,992.9 Completion Details S. Nominal ID PACKER;6,996.7 Top(kKB) Top(NO)(ftKB) Top Incl TI Item Des Corn (in) SEAL ASSY;0,993.8- -. 6,996.7 5,603.1 31.26 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 SEE,7,000.0 PACKER i8 `MI 7,000.0 5,606.0 31.22 SBE 80-40 SEAL BORE EXTENSION 4.000 §=f 7,019.4 5,622.5 31.02 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 7,181.7 5,762.8 29.34 BLAST JOINT BLAST JOINT 2.992 ° 7,201.4 5,780.0 29.13 BLAST JOINT BLAST JOINT 2.992 GAS LIFT,7,044.6 : 7,255.2 5,827.2 28.42 LOCATOR GBH-22 LOCATOR 2.990 7,256.5 5,828.3 28.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.990 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(113M) Grade Top Connection TUBING-WO-2015-A 31/2 2.980 7,257.5 7288.1 5,856.2 GAS LIFT;7,102.7 l SAND ISO PACKER- 4.75"x 3.5" Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) BLAST JOINT;7,181.7 Y 7,257.5 5,829.2 28.39 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 IPERF,7,1000-7,240.0^ I .1.,..-,. II PACKER BLAST JOINT;7,201.4 7,260.8 5,832.1- 28.35 SBE 80-40 SEAL BORE EXTENSION 4.000 7,265.2 5,836.0 28.29 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.970 7,269.8 5,840.0' 28.23 NIPPLE DS NIPPLE 2.812 LOCATOR;7,255.21.1 7,277.3 5,846.6 28.13 LOCATOR GBH-22 LOCATOR 2.980 PACKER;7,257s 7,278.0 5,847.3 28.12 SEAL ASSY 80-40 GBH-22 BONDED SEAL ASSEMBLY 2.980 SEAL ASSY;7,256 5, "''. a I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lbkt) Grade Top Connection 7,11' TUBING-WO-1988 31/2 2.992 7,279.0 7,308.9 5,874.6 9.30 J-55 EUE8rdABMOD seE;7,263.0 '" Completion Details W- Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl TI Item Des co. (In) NIPPLE;7,269.8 7,279.0 5,848.2 28.11 PACKER BAKER'FB-1'PERMANENT PACKER 4.000 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION 4.000 7,301.6 5,868.1 27.81 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 LOCATOR;7,277.3 L;. 7,308.1 5,873.8 27.75'SOS BAKER SHEAR OUT SUB.ELMD @ 7292'per SWS 3.000 IPROF on 5/19/1999 g PACKER;7,279.0 SEAL ASSY;7,276.0 Perforations&Slots SBE;7,287.5 • Z Shot Tar it Dens Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 6,947.0 6,949.0 5,560.8 5,562.5 Squeeze 12/27/1987 4.0 CMT Gun size and phasing • NIPPLE;7,307.6 Perforations, SQZ not documented. 2V-04 sos;7,308.1 - 7,188.0 7,240.0 5,768.3 5,813.8 C-4,UNIT B, 4/3/1984 12.0 IPERF 120 deg.phasing;5 1/2" 2V-04 CSG Gun 7,327.0 7,335.0 5,890.6 5,897.7 A-4,2V-04 4/3/1984 4.0 (PERF 90 deg.phasing;2 1/8" TT IPERF;7,327.0-7,335.0- 7,344.0 7,373.0 5,905.7 5,931.5 A-3,2V-04 4/3/1984 4.0 (PERF 90 deg.phasing;2 1/8" _ TT � IPERF;7,344.0-7,373.0 � . PRODUCTION;38.7-7,862.1 • KUP • 2V-04 ConocoPhilli• ps W Itr CarwoaPhilllps 2V-04,7/6/2017 11:55:04 AM Verlt ai sWramanc.(actual) HANGER;35.2 Mandrel Inserts N� Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 6,864.4 5,491.0 CAMCO KBMG 5.39 GAS LIFT DMY BK 0.000 0.0 4/12/2015 DCK- II 2 2 7,044.6 5,644.1 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000+ 0.0 3/26/2015 M CONDUCTOR;37.0-110.0• 3 7,102.7 5,694.3 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000 0.0 Notes:General&Safety End Date Annotation 5/7/2010 NOTE Confirmed Packer leak or behind pipe channel up from TTL to C-Sand w/WFL&PPROF SURFACE;38.7-3,121.2 CASING PATCH-WLM;4,010.0 -4,030.0 111 GAS LIFT;6,864.4 111 LOCATOR,8,918.7 PACKER;6,928.6 PA' SEAL ASSY;6,919.5 S SBE;6,929.9 CMT SOZ;6,947.0-6,949.0— V LOCATOR,6,992.9 PACKER,6,996.7 6.66 SEAL ASSY,6,993.8— ITE SBE;7,000.0 f GAS LIFT;7,044.6 GAS LIFT;7,102.7 BLAST JOINT;7,181.7 �: IPERF;7,188.0-7,240.0^ II=. BLAST JOINT;7,201.4 ■■■■ LOCATOR;7,255.2 -O PACKER;7,257.5 SEAL ASSY;7,256.5 6 SBE;7,280.8 w NIPPLE;7,268.8 LOCATOR;7,277.3 PACKER;7,279.0 SEAL ASSY;7,278.0. L SBE;7,281.5 • SIRM NIPPLE;7,301.6 SOS;7,308.1 IPERF;7,327.0-7,335.0 IPERF;7,344.0-7,373.0----. PRODUCTION;36.7-7,862.1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Rper \'- eSUBJECT:Mechanical Integrity Tests P.I.Supervisor jc (4l 3i 4=2 ( � CONOCOPHILLIPS ALASKA INC 2V-04 FROM: Jeff Jones KUPARUK RIV UNIT 2V-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2V-04 API Well Number 50-029-21041-00-00 Inspector Name: Jeff Jones Permit Number: 183-165-0 Inspection Date: 6/3/2016 Insp Num: mitJJ160608071919 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, 2V-04 - Type Inj W' TVD 5603 - Tubing 1700 1700 1700 . 1750 . — PTD 1831650 - Type Test SPT Test psi 1500 - IA 500 2400 2350 , 2350 Interval4'RTST PAF P / OA 50 70 • 60 - 60 . Notes: 1 well inspected,no exceptions noted. sJJNNEO DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 vt-s-k G5 • 2-G149 WELL LOG TRANSMITTAL#902963899 To: Alaska Oil and Gas Conservation Comm. January 22, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 �g RECEIVED ® DATA LOGGED -1 `/ ^ 2/lts(2 i Cs Anchorage, Alaska 99501 Ld K BENDER JAN 2 6 2D,3 AOGCC RE: Water Flow Log with TMD3D: 2V-04 Run Date: 12/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2V-04 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-21041-00 SCANNED Water Flow Log with TMD3D (Field print) 1 Color Log 50-029-21041-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' ✓Qgw / _E:+4:e ' • • . 5� WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 9, 2015 Attn.: Makana Bender DATA LOGGED 1.o�.%/2O15 333 West 7th Avenue, Suite 100 K.BENDER Anchorage, Alaska 99501 RECEIVED O C T 1 4 2015 RE: Injection Profile : 2V-04 AOGCC Run Date: 8/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2V-04 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21041-00 iCANNEfi Injection Profile Log 1 Color Log 50-029-21041-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Mxtga.fredxj,_dgeoceat MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,June 05,2015 P.I.Supervisor y„..,0_,19b(5 I I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2V-04 FROM: Matt Herrera KUPARUK RIV UNIT 2V-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2V-04 API Well Number 50-029-21041-00-00 Inspector Name: Matt Herrera Permit Number: 183-165-0 Inspection Date: 5/9/2015 Insp Num: mitMFH150511130412 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2v-o4 Type I41 v' -TVD 5603 Tubing 910 910 - 910 . 910 - 910 PTD 1 1831650 Type Test SPT Test psi 1500 - IA 360 1800 - 1760 - 1770 - 1760. - Interval 1N1TAL P/F P " OA 242 377 375 380 377 . Notes: Slight temp flucuation.IA pressure showed stabilization. 1 2 BBL'S Diesel to bring IA to test pressure _ SCANNED ,JUL 1 3 ZUlb Friday,June 05,2015 Page 1 of 1 1 Keck 2111-oq Regg, James B (DOA) Prb tb3 r Syc From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, May 13, 2015 12:59 PMQiq To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Senden, R.Tyler Subject: RE: KRU MIT forms Attachments: MIT KRU 1G-05 05-8-15.xls; MIT KRU 2W PAD 05-09-15.xls; 2V-04 schematic.pdf q,3 [ (.9 5- �..i o Attached are corrected forms and an updated schematic following the workover on 2V-04. The packer used was @ 6997' MD, 5603'TVD as that is the one closest to the top set of perfs. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 SCMINED JUN 0 82015 OWELLS TEAM comaphinips From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, May 13, 2015 11:23 AM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA) Subject: [EXTERNAL]RE: KRU MIT forms KRU 1G-05 (PTD 1830200)-Packer TVD should be 6114 ft KRY 2V-04 (PTD 1831650)-Packer TVD should be 5563 ft KRU 2W-02 (PTD 1850160)-Notes for 1 hr test are confusing; replace with "First attempt"; What were initial pressures for 2nd attempt (add to notes this test was 1 hour after first attempt) Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggCilalaska.gov. From: NSK Problem Well Supv [mailto:n1617Ca�conocophillips.com] Sent: Tuesday, May 12, 2015 7:56 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Senden, R. Tyler Subject: KRU MIT forms 1 Attached are copies of the forms for the recent MIT's performed at Kuparuk. Please let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 4LWELLS TEAM conaai Lapps 2 ") ALIBI&..` ' (titi;rfr Y„ KUP INJ 2V-04 ConocoPhillips 1 Well Attributes Max Angle&MD TD Alaska,inc. /I Wellbore API/UWI Field Name Wellbore Status Incl(°) MO(ftKB( Act Btm(ftKB) 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2V-04,4/27/20152:08.20 PM SSSV:NONE Last WO' 1/2/1988 41.49 12/17/1983 Verucal schematic(actual) Annotation Depth(908) End Date Annotation Last Mod By End Dale Last Tag:RKB 7,379.0 1/21/2014 Rev Reason:WORKOVER smsmlth 5/3/2013 HANGER.35.2 rtlinf Casing Strings jCasing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 8-40 WELDED Casing Description OD(In) ID(In) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...WULen(I...Grade Top Thread Nu. ,,,,,,i,All,SURFACE 9 5/8 8,921 36.7 3,121.2 2,868.1 36.00 J-55 BUTT Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'WULen(I...Grade Top Thread PRODUCTION 7 6.276 36.7 7,662.2 6,191.8 26.00 J-55 BTC -M,CONDUCTOR;37.0-110A ..�Tubing Strings Tubing Description String Ma...113(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/rt) Grade Top Connection TUBING-WO-2015 3 1/2 2.992 35.2 6,939.0 5,554.0 9.30 L-80 EUE 8rd Mod -UPPER Completion Details Nominal ID SURFACE:36.73121.2 Top(ftKB) Top(TVD)(kKB( Top Inol(') Item Des Com (in) 35.2 35.2 - In0.05 HANGER 'VETCO TUBING HANGER 2.992 CASING PATCH-WLM: 6,918.7' 5,536.8 32.26 LOCATOR 'GBH-22 LOCATOR 3.000 4,010.0-4,030.0 6,919.5• 5,537.5 32.25 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 GAS LIFT;6,864ATubing Description String Ma...ID(In) -Top(ftKB) -Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection '� TUBING-WO-2015- 3 1/2 2.992 6,926.6 7,013.2 5,617.2 9.30 L-80 EUE 8rd Mod I SQUEEZE PERF ISO PCKR-4.75"x3.5" Completion Details LOCATOR;6,918.7 -i Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl(°) Item Des Com (in) PACKER;6,926.81DID 6,926.6 5,543.5 32.16'PACKER 'BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 SEAL ASSY;6,919.5 -_I PACKER SBE;8,928.9 6,929.9 5,546.3 32.12 SBE 80-40 SEAL BORE EXTENSION 4.000 r 6,949.3 5,562.7 31.87 X0 Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 CMT 502:6.947.0-6,949.0- 6,992.9 5,599.9 31.31 LOCATOR GBH-22 LOCATOR 3.000 6,993.8 5,600.6 31.30 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(in) Top(kKB) Bet Depth(ft...Set Depth(TVD)(...Wi(Ib/ft) Grade Top Connection TUBING-WO-2015-C 3 1/2 2.992 6,996.7 7,262.2 5,833.3 9.30 L-80 EUE 8rd Mod SAND ISO PACKER- LOCATOR:8.092.4) : 4.75"x 3.5" _' Completion Details PACKER;6,996.7 = Nominal ID SEAL ASSY;5993.8-. -- Top(ROB) Top(TVD)(ftKB) Top Incl I") Item Des Corn (in) SBE;7,000.0am 6,996.7 5,603.1 31.26 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER II 7,000.0 5,606.0 31.22 SBE 80-40 SEAL BORE EXTENSION 4.000 III 7,019.4 5,622.5 31.02 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 7,181.7 5,762.8 29.34 BLAST JOINT BLAST JOINT 2.992 GAS LIFT;7044 67,201.4 5,780.0 29.13 BLAST JOINT BLAST JOINT 2.992 7,255.2 5,827.2 28.42 LOCATOR GBH-22 LOCATOR 2.990 I - 7,256.5 5,828.3 28.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.990 GAS LIFT:7,102.7 Tubing Description Stang Ma...ID(In) -Top(ftKB) -Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-WO-2015-A 31/2 2.980 7,257.5 7,288.1 5,856.2 SAND ISO PACKER- 4.75"x3.5" Completion Details BLAST JOINT: Nominal ID (BLS JOINT;7201.0, Top(ftKB) Top(TVD)(ftKB) Top Intl(') Item Das Com (in) BLAST JOINT:7,201.4 7,257.5 5,829.2 28.39 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER 7,260.8 5,832.1 28.35 SBE 80-40 SEAL BORE EXTENSION 4.000 LOCATOR;7,255.2 7,265.2 5,836.0 28.29 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.970 7,269.8 5,840.0° 28.23°NIPPLE DS NIPPLE W/RHC PLUG 2.812 1I PACKER;7,257.5 SEAL Assv;7,256.51 7,277.3 5,846.6 28.13 LOCATOR GBH-22 LOCATOR 2.980 7,278.0 5,847.3' 28.12 SEAL ASSY 80-40 GBH-22 BONDED SEAL ASSEMBLY 2.980 SBE:7.260.6 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibkt) Grade Top Connection TUBING-WO-1988 31/2 2.992 7,279.0 7,308.9 5,874.6 9.30 J-55 EUE8rdABMOD Completion Details NIPPLE;7,2898 Nominal ID Top(kKB) Top(ND)(ftKB) Top Intl I") Item Des Com (in) 7,279.0 5,848.2 28.11 PACKER BAKER'FB-1'PERMANENT PACKER 4.000 • LOCATOR;1,277.3 7,281.5 5,850.4 28.07'SBE BAKER SEAL BORE EXTENSION 4.000 7,301.6 5,868.1 27.81'NIPPLE •CAMCO'D'NIPPLE NO GO 2.750 .. PACKER;7,279.0-, 'In _'. 7,308.1 5,873.8 27.75"SOS BAKER SHEAR OUT SUB.ELMD @ 7292'per SWS 3.000 SEAL ASSY;7,276.0 -- !PROF on 5/19/1999 SBE:7,261.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) CATCHER;74298.0 II Top(TVD) Top ncl' Top(RKB) (ftKB) (°) Des Com Run Dale ID(in) CATCHER;7,298.0 I7,298.0 5,864.9 27.86 CATCHER 2.79 CATCHER GAL 48" 1/22/2015 1/2 7,302.0- 5,1368.5 27.81'PLUG CA-2 PLUG OAL 27" 1/2015 NIPPLE;7,301.6 PLUG;7,3020' r��/,; Perforations&Slots Shot Dens SOS;7,308.1 Top(ftKB) Btm(RKB) Top(TVD) B (ftKB) (K B U) _ Zone Dab (sht) Typo Cent 6,947.0 6,949.0' 5,560.8 5,562.5 Squeeze 12/27/1987' 4.0"CMT "Gun size and phasing Perforations, SQZ not documented. (PERF;7,327.0-7,335.0-.. 2V-04 7,188.0 7,240.0' 5,768.3 5,813.8 C-4,UNIT B, 4/3/1984 - 12.0..IPERF 120 deg.phasing;5 1/2" •• .-.A 2V-04 CSG Gun • IPERF;7,344.0-7.373.0 1 PRODUCTION;36.7-7,662.1 s ,, KUP INJ 2V-04 • ConocoPhillipsr, Alaska,Iris. ca,ocriatrupc 2V-04,4/27/2015 298:22 PM Vertical schematic(actual HANGER',35.21��d1 Perforations&Slots Shot Dans Top(TVD) Bt(f(TVD) (shota/f >vu411 uua Top(ttKB) Btm(ftKe) (ftKB) (ftKB) Zone Date t) Type Corn 7,327.0 7,335.0 5,890.6 5,897.7 A-4,2V-04 4/3/1984 4.0 IPERF 90 deg.phasing;2 1/8" TT -M/CONDUCTOR',37.0.110.0•' 7,344.0 7,373.0 5,905.7 5,931.5 A-3,2V-04 4/3/1984 4.0 IPERF 90 deg.phasing;2 1/8" TT Mandrel Inserts St t0 on Top(TVD) Valve Latch Port Size TRO Run SURFACE',36.7-3,121.2 • N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn r 6,864,4 5,491.0-CAMCO KBMG 5.39 GAS LIFT SOV BEK- 1.000 0.0 3/28/2015 DCK-2 2C1 CASING PATCH-W LM; 4.010.0-4,030.0 2 7,044.6 5,644.1 CAMCO KBMG 5.39 GAS LIFT DMV BK-5 0.000 0.0 3/26/2015 3 7,102.7 5,694.3 CAMCO KBMG 5.39 GAS LIFT DMV BK-5 0.000 0.0 GAS LIFT;6,864.4 - Notes:General&Safety End Date Annotation 1111 5/7/2010 NOTE:Confirmed Packer leak or behind pipe channel up from TTL to C-Sand w/WFL&PPROF 111 LOCATOR:6,918.7 -p. PACKER.6926.6- _ SEAL ASSY,6,919 5 '!< . SBE;6,929.9 it - CMTSOZ',6,947.0.6,9490 a 1 1111 LOCATOR:6,992 9 PACKER',6 996 7 SEAL ASSY,6,993.8-- SBE.7,000 0 SBE.70000 ®f V N GAS LIFT.7,044.6 GAS LIFT;7,102.7 BLAST JOINT',7,1817_ --'' - IPERF',7,188.0-7.240.0, — -. BLAST JOINT',7201 4 N LOCATOR;7.255.2 /1111 PACKER.7.25]5 - — - i SEAL ASSY:7256.5, •-j SBE:7260.8 NIPPLE;7.269.8 LOCATOR,7.277.3 PACKER:7.279.8 SEAL ASSY;7,278.8 SBE,7,2815 CATCHER',7298.0II 1 ISI NIPPLE',7.302.0 1/(////; PLUG:7.302.0 t/(((/' SOS;]308.1 IPERF;7,327.0-7 335.0— I PERF:7,344 0.7,373 0--- PRODUCTION.36.7-7,662.1 STATE OF ALASKA RECEIVED AL,- KA OIL AND GAS CONSERVATION COM,.,,SSION APR 3 0 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Plug Perforations r Perforate r OthAOG CC Aker Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-165 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 1 ' 50-029-21041-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25644 KRU 2V-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7675 feet Plugs(measured) 7302 true vertical 6203 feet Junk(measured) none Effective Depth measured 7571 feet Packer(measured) 6927,6997, 7258, 7279 true vertical 6109 feet (true vertical) 5544,5603, 5829, 5848 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110 110 SURFACE 3085 9.625 3121 2668 PRODUCTION 7626 7 7662 6192 SCANNED MAY 1 8 2015 Perforation depth: Measured depth: cement squeeze perfs from 6947-6949 only, 7188-7240, 7327-7335,7344-7373 True Vertical Depth: cement squeeze perfs from 5561-5563 only, 5768-5814, 5891-5898,5906-5932 Tubing(size,grade,MD,and TVD) 3.5, L-80,7309 MD, 5874 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER'F-1' PERMANENT PACKER @ 6927 MD and 5544 TVD PACKER-BAKER'F-1' PERMANENT PACKER @ 6997 MD and 5603 TVD PACKER-BAKER'F-1' PERMANENT PACKER @ 7258 MD and 5829 TVD PACKER-BAKER'F-1'PERMANENT PACKER @ 7279 MD and 5848 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F' Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG F' GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 315-027 Contact Janelle Nesvold Cad 263-4641 Email Janelle.R.Nesvold@conocophillips.com Printed Name Janelle Nesvold Title Sr. Wells Engineer Signature �ll ue�.�/ c /, Phone:263-4641 Date Li /Z P6�G�a """ -/►►► 0 li y L 57(+115— Form 10-404 Revised 10/2012 Submit 9 iginal Only ���``� RBDMSJ APR 3 0 2015 • KUP INJ 2V-04 • ConocoPhillips 4 I Well Attributes Max Angle&MD TD Ala ka.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) cee,oe wa,pe 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2V-04,4/27/20152'0820 PM SSSV:NONE Last WO: 1/2/1988 41.49 12/17/1983 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -.........................................................._.__.... _._.... Last Tag:RKB 7,379.0 1/21/2014 Rev Reason:WORKOVER smsmith 5/3/2013 HANGER;352 ',(It;: Casing Strings CCC��� Casing Description OD(in) ID(in) Top(ftKB) Sat Depth OMB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1I CONDUCTOR 16 15.062 37.0 110.0 1100 62.50 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)...WVLen(I...Grade Top Thread .. :., .... :. . are.SURFACE 9 5/8 8.921 36.7 3,121.2 2,668.1 36.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftK8) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread _ PRODUCTION 7 6.276 36.7 7,662.2 6,191.8 26.00 J-55 BTC .-,-,-/CONDUCTOR,37.0-110.0• II Tubing Strings Tubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TOD)(...Wt(Ib/ft) Grade Top Connection TUBING-WO-2015 31/2 2.992 35.2 6,939.0 5,554.0 9.30 L-80 EUE 8rd Mod -UPPER Completion Details 11, Nominal ID SURFACE;38.7-3.121.2 4 Top(kKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 35.2 35.2 0.05 HANGER 'VETCO TUBING HANGER 2.992 CASING PATCH-WLM: 6,918.7 5536.8 32.26 LOCATOR GBH-22 LOCATOR 3.000 4,010.0-4,030.0 _ 6,919.5 5,537.5 32.25 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 GAS LIFT;6 064 a �r Tubing Description Stdna Ma...ID(in) Top(MB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection r' TUBING-WO-2015- 3 1/2 2.992 6,926.6 7,013.2 5,617.2 9.30 L-80 EUE 8rd Mod I SQUEEZE PERF ISO PCKR-4.75"x3.5" Completion Details LOCATOR;6,918.] Nominal ID Top(MB) Top(ND)(ftKB) Top Incl("I Item Des Com (in) 5926.6 5,543.5 32.16 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER;8,926.61 SEAL ASSY;8,919.5 1 i i PACKER SBE;6,929.9 I ! 6,929.9 5,546.3 32.12 SBE 80-40 SEAL BORE EXTENSION 4.000 6,949.3 5,562.7 31.87 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 CMT SQZ;8,947.0-8,949.0-- 6,992.9 5,599.9 31.31 LOCATOR GBH-22 LOCATOR 3.000 6,993.8 5,600.6 31.30 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 3.000 Tubing Description String Ma...ID(In) Top(ftKB) 'Set Depth(ft..Set Depth(NO)(...Wt(lb/ft) Grade Top Connection U TUBING-WO-2015-C SAND ISO PACKER- 3 1/2 2.992 6,996.7 7,262.2 5,833.3 9.30 L-80 EUE 8rd Mod LOCATOR;6,992.9 : 4.75"x 3.5" a Completion Details PACKER;6,996.7 - Nominal ID SEAL ASSY;8,993.8, s Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) S8E;7000.0 ,ter 6,996.7 5,603.1 31.26 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER ' 7,000.0 5,606.0 31.22 SBE 80-40 SEAL BORE EXTENSION 4.000 7,019.4 5,622.5 31.02 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.950 7,181.7 5,762.8 29.34 BLAST JOINT BLAST JOINT 2.992 GAS LIFT;7,044.6 7,201.4 5,780.0 29.13 BLAST JOINT BLAST JOINT 2.992 7,2552 5,827.2 28.42 LOCATOR GBH-22 LOCATOR 2.990 • 7,256.5 5,828.3 28.40 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.990 GAS LIFT;7,102.7 Tubing Description String Ma...ID(in) Top(ftKB) at Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Tap Connection TUBING-WO-2015-A 31/2 2.980 7,257.5 7,288.1 5,856.2, • SAND ISO PACKER- 4.75"x3.5" i Completion Details BLAST JOINT;7,181.7 -- Nominal ID' !PERF;7,188.0-7,240.0- = t Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) BLAST JOINT;7,201.4 7,257.5 5,829.2 28.39 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 4.000 PACKER 7,260.8 5,832.1 28.35 SBE 80-40 SEAL BORE EXTENSION 4.000 LOCATOR;7,255.2 7,2652 5,836.0 28.29 XO Reducing Crossover,4-3/4"Stub Acme x 3-1/2"EUE 8rd 2.970 .N., 7,269.8 5,840.0 28.23 NIPPLE DS NIPPLE W/RHC PLUG 2.812 PACKER;77,2255.73,55-\._ = SEAL ASSY; •=I 7,277.3 5,846.6 28.13 LOCATOR GBH-22 LOCATOR 2.980 '• 7,278.0 5,847.3 28.12 SEAL ASSY 80-40 GBH-22 BONDED SEAL ASSEMBLY 2.980 SBE;7,260.8 Tubing Description Ma... ) Top(ftKB) Set Depth(ft..Sat Depth(ND)(...Wt(Ib/ft) !Grade Top Connection II a TUBING-WO-1988 'String 3 1/2 1ID(In)2.9921 7,279.0 7,308.9 5,874.61 9.30J-55 I EUE8rdABMOD Completion Details NIPPLE;7,269.8 Nominal ID 111 Tap(k1413) Top(ND)(ftKB) Top Incl(') Item Des Com (!n) 7,279.0 5,848.2 28.11 PACKER BAKER'FB-!'PERMANENT PACKER 4.000 LOCATOR;7,277.3 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION 4.000 a 7,301.6 5,868.1 27.81 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 s PACKER;7,279.0 or 7,308.1 5,873.8 27.75 SOS BAKER SHEAR OUT SUB.ELMD @ 7292'per SWS 3.000 SEAL ASSY;7,278.0 l g SBE;72815 I. !PROF on 5/19/1999 11 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) CATCHER;7,29857.298.0 5,864.9 27.86 CATCHER 2.79 CATCHER DAL 48" 1/22/2015 1T6 7,302.0 5,868.5 27,81 PLUG CA-2 PLUG OAL 27" 1/21/2015 NIPPLE;7,301.6 Perforations&Slots PLUG;7,302.0 �. Shot Dens SOS;7,308.1 i Top(ND) Btm(TVD) (shotslf Top(ftKB) etm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,947.0 6,949.0 5,560.8 5,562.5 Squeeze 12/27/1987 4.0 CMT Gun size and phasing Perforations, SQZ not documented. 2V-04 IPERF;7,327.0-7,335.0 7,188.0 7,240.0 5,768.3 5,813.8 C-4,UNIT B, 4/3/1984 12.0 IPERF '120 deg.phasing;5 1/2" 1PERF;7,344.0-7,373.0- 2V-04 CSG Gun PRODUCTION;36.7-7582.1 KUP INJ 2V-04 ConocoPhillips of Alaska.Inc. Cmoco t l 2V-04,4/27/2015 2'0822 PM Vertical schematic(actual) __. ... .;. ......_..........._ HANGER;35.2IMF Perforations&Slots :1IIF Dens ' —- Top(TVD) Btm(TVD) (shots/1 Top MED) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com �.,.. 7,327.0 7,335.0 5,890.6 5,897.7 A-4,2V-04 4/3/1984 4.0 IPERF 90 deg.phasing;2 1/8" TT 7,344.0 7,373.0 5,905.7 5,931.5 A-3,2V-04 4/3(1984 4.0 IPERF 90 deg.phasing;2 1/8" ./�NCONDUCTOR;37.0-110.0• II..; TT Mandrel Inserts st • • ati on Top(TVD( Valve Latch Port Size TRO Run N Top(SOB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Data Com SURFACE;36.7-3,1212 1 6,864.4 5,491.0 CAMCO KBMG 5.39 GAS LIFT SOV BEK- 1.000 0.0 3/28/2015 DCK-2 2C1 CASING PATCH-Wilk • 4,010.6I,030.0 • 2 7,044.6 5,644.1 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000 0.0 3/26/2015 • 3 7.102.7 5,694.3 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 0.000 0.0 GAS LIFT;6,864.4 Notes:General&Safety End Date Annotation 5/7/2010 NOTE:Confirmed Packer leak or behind pipe channel up from TTL to C-Sand w/WFL&PPROF • LOCATOR;6,918.7 :Q. PACKER;6,926.81 '-_-- SEAL ASSY;6,919.5 =r SBE;6,929.9 CMT SOZ;6,947.0.8,949.0— I I 8 LOCATOR;6,992.9 SE PACKER;6,996.7 _ SEAL ASSY;8,993.8- SBE;7,000.0 a 9 r GAS LIFT;7,0440 GAS LIFT;7,102.7 r BLAST JOINT;7,181.7.. — I ` (PERF;7,188.0-7,240.0 BLAST JOINT;7,201.4 LOCATOR;7,2552 at PACKER;7,257.5 '_ SEAL ASSY;7,258.5 =a SBE;7,260.8 I NIPPLE;7,2698 LOCATOR;7.277.3 i, PACKER;7,279.0.. .. SEAL ASSY;7,278.0 OBE;7,281.5 i. I CATCHER;7,298.0 NIPPLE;7,301.6 PLUG;7,302.0 I SOS;7,308.1 lb (PERF;7,327.0-7,335.0— (PERF;7,344.0-7,373.0 -4 - PRODUCTION;36.7-7,662.1 k 2V-04 PRE-RIG SUMMARY DATE SUMMARY 3/19/2014 (PRE-RWO): FUNCTION TEST T & IC LDS-ALL FUNCTIONED PROPERLY. T POT-PASSED. T PPPOT-PASSED. IC POT-PASSED. IC PPPOT-PASSED. MITIA& MITOA PENDING. 3/20/2014 (PRE-RWO) MITIA- PASSED; MITOA- PASSED 3/21/2014 DRIFTED TBG TO 7302' RKB WITH 36' GYRO DUMMY. READY FOR E/L. 7/2/2014 LOG GYRODATA SURVEY FROM SURFACE TO 7330. MAKE STOPS AT 50, 700, 900, 1300, 1900, 4100, 6300, 7330. 1/16/2015 (PRE-RWO) FUNCTION T AND IC GN AND LDS ALL GOOD 1/18/2015 (PRE-RWO): T POT-PASSED. T PPPOT-PASSED. IC POT-PASSED. IC PPPOT-PASSED. 1/21/2015 TAG TD @ 7379' RKB, PERFORM 30min STOP SBHPS @ 7350' RKB (2675.9psi, 131.6 degF), 15min GRADIENT STOP @ 7237' RKB (2645.8psi, 130.7 degF), BRUSH & FLUSH TBG W/20 BBLS, SET 2.75" CA-2 PLUG @ 7302' RKB, PASSING MIT-T TO 3000psi. IN PROGRESS 1/22/2015 SET 2.79" CATCHER @ 7302' RKB, PULL DV @ 6897' RKB, SHOOT STRINGSHOT FROM 6915'- 6923' RKB, IN PROGRESS 1/23/2015 LRS LOADS TBG W/40 BBLS OF SEAWATER & 30 BBLS OF DIESEL TAKING RETURNS TO A TIGER TANK, CUT TBG @ 6919' RKB W/2-3/8" CHEM CUTTER, LRS LOADS ADDITIONAL 40 BBLS OF DIESEL & U-TUBED FOR FREEZE PROTECT....JOB DONE. ConocoPhillips Time Log & Summary WeUview Web Reporting Report Well Name: 2V-04 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 3/10/2015 12:00:00 AM Rig Release: 3/30/2015 2:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/08/2015 24 hr summary Road sub to 2V pad from Moraine 1 00:00 02:00 2.00 MIRU MOVE MOB P Install Jeep, pits on the road to 2V pad. 02:00 05:00 3.00 MIRU MOVE MOB P Clean around Sub,wood and herculite. Jack up Sub and pull matting boards. Pull Sub ahead and clean location. 05:00 12:00 7.00 MIRU MOVE MOB P Move Rig off of Moraine#1 ice pad. On the ice road @ 06:00 hrs. 12:00 00:00 12.00 MIRU MOVE MOB P Sub at CPF 3 @ 17:00 hrs,wait for crew change. Continue moving @19:00 hrs to 2C pad. Arrived at 2C pad 23:00 hrs. Pits are at 2V pad waiting for Rig. 33/09/2015 Continue to Road rig to 2V pad from Moraine 1. MIRU. Rig accepted @ 23:59.59 hrs 00:00 06:00 6.00 MIRU MOVE MOB P Continue to move the Rig to 2V pad. Arrived at 2V pad 06:00 hrs. 06:00 09:00 3.00 MIRU MOVE MOB P Line up Rig on Well 2V-04. 09:00 12:00 3.00 MIRU MOVE MOB P PJSM, raise the derrick, spool tugger lines and man rider lines. Spool up bridal line tuggers and install cattle shoot. R/U blocks on the TD. 12:00 18:00 6.00 MIRU MOVE MOB P PJSM, hang back bridal lines, Remove jeep from the pits and spot rig over 2V-04. Set the pits in place _ and install interconnect. 18:00 00:00 6.00 MIRU MOVE RURD P R/U electrical power to the pits and swap power to the Sub. Spot Kill tank, cuttings tank and R/U berming. Prep mud pumps with 5" liners. Prep rig floor and spot LEPD fuel tank. Rig accepted @ 23:59 hrs 3/10/2015. 33/10/2015 Continue to R/U/Install Sheer Hopper, change liners in pumps, R/U on tree to reverse circulate. R/U Choke manifolyd house and kill lines to Tiger tank. Pull BPV, UD lubricator and ready kill system for test with brine water. 00:00 07:30 7.50 0 0 MIRU MOVE RURD P Install new Sheer Hopper. Swap over equipment to 4"&change pumps _over to 5" liners 07:30 08:30 1.00 0 0 MIRU MOVE SVRG P Service rig. Page 1 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 12:00 3.50 10 0 MIRU WELCTI KLWL P Rig up on Tree to reverse circulate. Test gas detection system.Warm up manifold in choke house. 12:00 21:00 9.00 0 0 MIRU WELCTI MPSP T Pull BPV/P/U lubricator and test. Pull BPV, TBG 500 PSI, IA 420 psi. Close master wing valves and tempt to pull lubricator. Trapped gas, close SSV and attempt to bleed pressure off.Valves on Tree leaking, call for valve service crew. Bleed down TBG IA to 500 psi via Kill tank. L/D lubricator and install tree cap. 21:00 00:00 3.00 0 0 MIRU WELCTI RURD T R/U choke manifold house. Replace ported 90's on choke manifold. Test manifold and kill line to Tiger tank with air. Repaired all leaks, blew down all lines to Tiger tank. Ready kill system for test with brine water. Valve service crew serviced Tree and choke house manifold. 03/11/2015 Kill the well, set the BPV, N/D the Tree, set Blanking plug, and N/U BOPE. 00:00 01:00 1.00 0 0 MIRU WELCTI SEQP P Pressure test choke manifold and kill lines to 3500 psi. High pressure discharge line on mud pumped leaked. 01:00 04:30 3.50 0 0 MIRU WELCTI RGRP T Called out Nabors welder, repair the high pressure pump discharge line/ Stand Pipe. 04:30 07:00 2.50 0 0 MIRU WELCTI SEQP T Perform 5000 psi Integrity test on pump discharge line. Test kill lines and choke maniforld at choke house. 07:00 09:30 2.50 0 0 MIRU WELCTI KLWL P Kill well/pump 60 bbls 9.1 ppg brine down the annulus, 40 SPM, 347 psi, to the Kill Tank. Pump 190 bbls of brine down the tubing. Pump 363 bbls(1 1/2 X Well volume) Lost 36 bbls due to possible casing patch leak, Bleed 1000 psi OA pressure to 0. 09:30 14:00 4.50 0 0 MIRU WELCTI CIRC P Pump 363 bbls of brine(1 1/2"X Well volume)down the tubing taking returns out the IA through the choke maniforld @ 1 bpm/80 psi. Lost 6.5 bbls, shut down,well on Vac. 14:00 15:00 1.00 0 0 MIRU WHDBO MPSP P Set F type BPV with dry rod. 15:00 19:30 4.50 0 0 MIRU WHDBO NUND P Leave IA open, N/D Tree. Well on Vac, DHD shot fluid level at 198'. Install blanking plug and Head adaptor. Pump down control line to verify SSSV is open 19:30 00:00 4.50 0 0 MIRU WHDBO NUND P N/U BOPE, N/U Riser, choke and kill lines. 03/12/2015 Start BOP test, shut down and change LPR's. Continue testing BOP's,Annulare preventer failed test. Change out Annular preventer. Page 2 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Fill stack with brine water and start BOPE. Test 250 psi low and 3000 psi high. Test blind rams, choke valves, kill DEMCO, manual chokes and Super choke. 03:00 06:00 3.00 0 0 MIRU WHDBO RURD P Drain stack and Change 3"X 6" _lower VBR's to 2 7/8"X 5"VBR's. 06:00 08:30 2.50 0 0 MIRU WHDBO BOPE P Fill stack and continue to finish BOP test.Test LPR's, Dart valve, TIW valve, and XO's, 08:30 10:00 1.50 0 0 MIRU WHDBO RURD P P/U 3 1/2"test joint, Drain stack and verify Donut on test joint is below LPR's. 10:00 17:00 7.00 0 0 MIRU WHDBO BOPE P Continue testing BOPE. Test UPR's, Choke valves, LPR's, IBOP TD, Manual TD TIW valve, Dart valve, Annular preventer failed. 17:00 00:00 7.00 0 0 MIRU WHDBO RGRP T Replace Annular preventer/remove air boot, pull riser, remove Dutch riser, install potato masher, remove cap, remove element, check seals, install new element, M/U preventer cap and re-install circulating equipment. 03/13/2015 Replace Annular preventer, finish testing BOP's. P/U equipment to pull Hanger and 3 1/2"tubing. Pull Blanking plug and bleed pressure off behind the BPV. 00:00 02:45 2.75 0 0 MIRU WHDBO RGRP T Install Riser and Flow Line, lay down Annular head removal tool. 02:45 08:30 5.75 0 0 MIRU WHDBO RGRP T Function Annular element several times and increase pressure to 800 psi operating pressure w/3-1/2 test joint in place.Attempt to pressure test, multiple times-unable to seal with element. Steam element to warm up and make ply able. 08:30 15:30 7.00 0 0 MIRU WHDBO BOPE T Test with 3-1/2 Test joint, lay down test joint and pick up 4"Test jt. Found out when switching test from Kill line to test stump that the hose was frozen. Thaw out test hose and test the Annular, UPR's and LPR's- Good Test. Lay down and 4"test joint and pick up the 3-1/2 test and retest. Good Test. Conduct CPAI Koomey Draw down test. Starting Accumulator PSI =2,950 psi Function rams, Pressure gain of 200 psi =23 seconds Final pressure =72 Seconds AVE N2 6 Bottles=2,267 psi 15:30 16:30 1.00 0 0 MIRU WHDBO RURD P PJSM, L/D test tool ,tools and B/D lines. 16:30 18:00 1.50 0 0 COMPZ RPCOM RURD P P/U tubing equipment to pull tubing and SSV control line. Page 3 of 19 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 COMPZ RPCOM SFTY P Pre Spud meeting with crew and service hands. 19:00 21:00 2.00 0 0 COMPZ RPCOM RURD P Continue to R/U to pull Hanger, SSV control line and 3 1/2"tubing. 21:00 21:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM, pulling Hanger and 3/1'2" tubing. 21:30 22:30 1.00 0 0 COMPZ RPCOM SEQP P Pull Blanking plug with T bar. (VETCO service hand) 22:30 00:00 1.50 0 0 COMPZ RPCOM OWFF P Screw into BPV and open pop-it 1/4" turn, bled pressure off until pop-it was completely open. Pressure 0 well static)observe for 30 minutes. 03/14/2015 Pull BPV, pressure behind BPV, circulate and kill well with 9.1 ppg Brine. Pull Hanger, L/D 3 1/2"tubing and control line. 00:00 00:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well for 30 minutes with pop-it open,well static. 00:30 01:00 0.50 0 0 COMPZ RPCOM MPSP T Pull GRAY LOC TYPE F BPV. Trapped pressure behind the BPV, blew brine water from the tubing. Shut the Blind rams and took pressure readings. 200 psi on the tubing and 0 on the IA. Called Fred Herbert and AOGCC,well was shut in with the Blind rams. No Brine water on the outside of the rig. CPAI Near Miss report has been put into First Report. 01:00 03:30 2.50 0 0 MIRU WELCTI KLWL T Monitor shut in pressures. Intial shut in tubing pressure 200 psi / IA pressure 0. R/U choke house kill manifold and Tiger tank to kill well. 03:30 06:45 3.25 0 0 MIRU WELCTI KLWL T Bring pumps up to 22 spm/1.5 bpm, circulate to the Tiger tank. ICP 373 psi at1 -2 bpm/FCP 815 psi at 4 bpm. Started seeing returns to the Tiger tank at 13 bbls. Shut well in annulus volume 242 bbls. Shut in the well, 50 psi on the IA. 06:45 10:45 4.00 0 0 MIRU WELCTI OWFF T Observe well, monitor Tiger tank for returns. 10:45 11:15 0.50 0 0 MIRU WELCTI OWFF T Bleed off IA pressure/35 psi to Tiger tank. B/D line to Tiger tank,Verify pressure on tubing and IA. Open Blind rams and observe well for 30 minutes. 11:15 12:30 1.25 6,919 6,919 COMPZ RPCOM PULL P M/U one 8'pup joint on top of two 10' pup joints for landing joint. M/U landing joint into Hanger. Pull Hanger at 95K/SOW 73K. 12:30 14:00 1.50 6,919 6,919 COMPZ RPCOM CIRC P Circulate 1.5 X Volume of the hole. Pump at 3 bpm/226 psi/130 gpm. Pump 4 bpm/338 psi/170 gpm. Pump 5 bpm/524 psi/214 gpm. 14:00 14:15 0.25 6,919 6,919 COMPZ RPCOM RURD P Blow down TD. 14:15 15:00 0.75 6,919 6,919 COMPZ RPCOM PULL P L/D pup joints and Hanger Page 4 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:30 3.50 6,919 5,087 COMPZ RPCOM PULL P L/D 3 1/2", 9.3#, EUE tubing with SSV control line. From 6919'to 5087. PUW 85K/SOW 73K. Strap tubing as it was L/D. 18:30 19:15 0.75 5,087 5,087 COMPZ RPCOM RURD P R/D control line spooling unit and tool box. 34 control line bands were recovered. (control line and bands NORM tested) 19:15 00:00 4.75 5,087 1,081 COMPZ RPCOM PULL P Continue POOH with 3 1/2"tubing sideways. From 5087'to 1081'/ PUW 41K/SOW 40K. 33/15/2015 L/D 3 1/2"tubing. Vent gas and fill hole. Test Blind rams and HCR's. P/U BHA#1, RIH and P/U 4"DP. Slip and cut drilling line. Circulate B/U. 00:00 03:30 3.50 1,081 0 COMPZ RPCOM PULL P L/D 3 1/2"tubing from 1081'to Cut Off joint. Recovered 222 joints of 3 1/2"tubing. SSV and control line, GLM and 34 bands. Clear floor and prep for Blind ram test. 03:30 03:45 0.25 0 0 COMPZ RPCOM SFTY T PJSM,testing Blind rams and HCR's. Opened HCR kil prior to opening Blind rams. Observed 30 psi under Blind rams, closed HCR kill. 03:45 06:30 2.75 0 0 COMPZ WELCTI RURD T Gas pressure under Blind rams. R/U Kill lines and Choke house to Kill Tank. Test and strap Kill tank. Prep to load and kill well. 06:30 07:30 1.00 0 0 COMPZ WELCTI KLWL T Opne IA to Kill tank, bleed pressure off to 0 psi. Observed well at Kill tank to verify 0 pressure and 0 pressure on the IA. Open Blind rams. 07:30 08:00 0.50 0 0 COMPZ RPCOM CIRC T Fill the hole with 9.1 ppg Brine. Fluid level was at 521', 21 bbls to fill. 08:00 09:00 1.00 0 0 COMPZ RPCOM BOPE T Set the test plug and test the Blind rams, HCR Kill and Choke. Test to 250 psi low and 3000 psi high. Pull test plug. 09:00 09:30 0.50 0 0 COMPZ RPCOM RURD P Install Ware bushing per VETCO/GRAY. 6.25' ID-7"OD. 09:30 12:00 2.50 0 300 COMPZ RPCOM BHAH P PJSM, Pick up BHA#1 as per BAKER Rep. PUW 44K/SOW 42K. 12:00 13:15 1.25 300 438 COMPZ RPCOM BHAH P Continue picking up BHA#1. Length 437.82'. PUW 50K/SOW 48K. 13:15 18:00 4.75 438 4,279 COMPZ RPCOM PULD P P/U 4"DP from 438'to 4279'. PUW 108K/SOW 82K. Casing Patch at 4025', saw 10K, slack off, pick up and rotate a half turn, broke over 2-10K at 4049'. 18:00 21:00 3.00 4,279 6,845 COMPZ RPCOM PULD P Continue to P/U 4"DP from 4279'to 6845'. PUW 155/SOW 98K. 21:00 22:15 1.25 6,845 6,845 COMPZ RPCOM SLPC P Slip and cut drilling line, 83', 13 wraps. 22:15 22:45 0.50 6,845 6,845 COMPZ RPCOM SVRG P Service rig, TD, Drawworks and Crown. 22:45 23:00 0.25 6,845 6,896 COMPZ RPCOM PULD P Continue to P/U DP 6845'to 6896'. P/U 15'and a 5'pup joints and place them between DP joints 203 and 204. PUW 157K/SOW 99K. Page 5 of 19 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 6,896 6,896 COMPZ RPCOM CIRC P Circulate B/U, Gas and oil breaking out of Brine. Pump 5 bpm, 574 psi. 33/16/2015 L/D BHA#1 with fish. P/U BHA#2/Retrievamatic Packer. RIH and pressure test upper casing, IA above the casing patch, below the casing patch and pressure test up the work string. POOH with test packer. 00:00 01:00 1.00 6,896 6,896 COMPZ RPCOM CIRC P Circulate B/U @ 5 bpm/574 psi/ 209 gpm. 01:00 01:15 0.25 6,896 6,918 COMPZ RPCOM FISH P Engage Fish at 6912', latch at 6918'. Pump 1 bpm/334 psi.Verified latch-up 20K over pull. Set 25K down for PT. 01:15 01:30 0.25 6,918 6,918 COMPZ RPCOM PRTS P Pump down DP and pressure test to 3000 psi for 15 minutes. 01:30 01:45 0.25 6,918 6,918 COMPZ RPCOM FISH P Pull Seals at 200K PUW. Pump 1 bpm/82 psi/43 gpm.Verify Seals pulled free. 01:45 02:00 0.25 6,918 6,918 COMPZ RPCOM CIRC P B/D TD, L/D pup joints. 02:00 10:30 8.50 6,918 0 COMPZ RPCOM TRIP P POOH with Fish. PUW 150K/SOW 100K. Fill hole with normal pipe displacement to BHA.6918'to 0'. Calc,Disp. 37 bbls,Actual 43 bbls. 10:30 15:00 4.50 0 3,362 COMPZ RPCOM TRIP X P/U Retrievamatic Model "L",27.85. RIH to 3362'/PUW 46K/SOW 45K. 15:00 15:15 0.25 3,362 3,362 COMPZ RPCOM PRTS X Pressure test Retrievamatic, 1000 psi, PUW 84K/SOW 68K. 15:15 15:45 0.50 3,362 3,930 COMPZ RPCOM TRIP X RIH to 3930', PUW 93K/SOW 80K. 15:45 16:15 0.50 3,930 3,362 COMPZ RPCOM PRTS X Set test packer at 3362'and test above the casing patch to 3000 psi. 16:15 16:30 0.25 3,362 4,122 COMPZ RPCOM TRIP X RIH to 4122', PUW 95K/SOW 75K. 16:30 17:00 0.50 4,122 4,122 COMPZ RPCOM PRTS X Pressure test casing below the casing patch at 4122'. Test to 2500 psi for 15 minutes. (Test good) 17:00 18:00 1.00 4,122 5,454 COMPZ RPCOM TRIP X RIH to 5454', PUW 120K/SOW 85K. 18:00 18:30 0.50 5,454 5,454 COMPZ RPCOM PRTS X Pressure test casing at 5454'to 2500 psi for 15 minutes. (Test good) 18:30 19:00 0.50 5,454 5,454 COMPZ RPCOM PRTS X Pressure test casing below the test packer and above the FB-1 Packer. Test to 2500 psi for 15 minutes. Test bled off 40 psi. 19:00 20:00 1.00 5,454 6,498 COMPZ RPCOM TRIP X RIH to 6498', PUW 137K/SOW 92K. 20:00 20:30 0.50 6,498 6,911 COMPZ RPCOM PULD X P/U 4"DP to 6911'. PUW 145K/ 96K. 20:30 21:00 0.50 6,911 6,911 COMPZ RPCOM PRTS X Pressure test casing at 6911'to 3000 psi for 15 minutes. (Test good) 21:00 22:00 1.00 6,911 6,911 COMPZ RPCOM PRTS X Pressure test 25'above FB-1 Packer through the DP.Test to 3000 psi for 15 minutes. (Test failed) 22:00 22:30 0.50 6,911 6,911 COMPZ RPCOM SVRG X Service rig. 22:30 22:45 0.25 6,911 6,879 COMPZ RPCOM PULD X L/D single joint of DP 6879'. PUW 145K/SOW 96K. 22:45 00:00 1.25 6,879 5,360 COMPZ RPCOM TRIP X TOOH from 6879'to 5360'. PUW 120K/SOW 80K. Page 6 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment D3/17/2015 24 hr summary Continue to TOOH with test packer from 5360'to surface and lay down BHA. PU and MU packer milling assembly and TIH to the top of the FB-1 packer at 6929'. Mill FB-1 packer from 6929'to 6932'and circulate bottoms up. 00:00 05:00 5.00 5,360 0 COMPZ RPCOM TRIP X POOH w/BHA#2, (Baker Model L Retrievamatic(RH)from 5,360-ft to Surface. 05:00 06:00 1.00 0 32 COMPZ RPCOM BHAH P P/U, MU 32-ft of BHA#3 06:00 06:30 0.50 0 0 COMPZ RPCOM OTHR P Service crew 06:30 08:30 2.00 32 422 COMPZ RPCOM BHAH P MU and RIH w/BHA#3, (5.9"OD Packer Milling Assembly)to 421.76-ft. 08:30 13:30 5.00 422 6,929 COMPZ RPCOM TRIP P RIH w/BHA#3 from 421-ft to 6,929-ft 13:30 23:30 10.00 6,929 6,932 COMPZ RPCOM MILL P Obtain milling parameter: PU= 153K, SO=95K, ROT= 118K, RPM 80,torque on= 10K,torque off=9K, 3 BPM = 1100 psi. Mill packer from 6929'to 6932'with 6-10K down. Fluid vis is 88. Lost about 65 bbls during milling operation. 23:30 00:00 0.50 6,932 6,922 COMPZ RPCOM CIRC P PU to 6922'and circulate bottoms up at 5 BPM= 1191 psi. 33/18/2015 Circulate bottoms up at 5 BPM and observer the well for flow(well static). Attempt to TOOH on elevators but the well is swabbing due to the hi-visc brine. Trip back in hole to 6892'to condition the brine and lower the viscosity of the brine. Lower the visc in the well from 210 visc to 45 visc while rotating and reciprocating at 3 BPM. Attempt to TOOH on elevators but the well is swabbing. Observe the well for flow(well static)and pump out of the hole from 6892'to 2328'at midnight. 00:00 00:15 0.25 6,922 6,922 COMPZ RPCOM CIRC P Continue to circulate bottoms up at 5 BPM= 1191 psi. 00:15 00:30 0.25 6,922 6,922 COMPZ RPCOM OWFF P Observe the well for flow for 10 minutes. Well static. 00:30 01:30 1.00 6,922 6,922 COMPZ RPCOM RURD P Blow down top drive and RU air slips to TOOH with DP. 01:30 01:45 0.25 6,922 6,643 COMPZ RPCOM TRIP P TOOH with BHA#3-packer milling assembly. Pulled 3 stands 01:45 02:15 0.50 6,643 6,643 COMPZ RPCOM RURD T Air slips not getting a bite on the DP. RD air slips 02:15 02:30 0.25 6,643 6,364 COMPZ RPCOM TRIP P Pulled 3 more stands and the BHA appears to be swabbing. 02:30 03:00 0.50 6,364 6,364 COMPZ RPCOM OWFF T Pull the stripping rubber and observer the well for flow. Well static. PU on DP and the BHA is swabbing. SO on the DP and the fluid level drops 03:00 04:00 1.00 6,364 6,364 COMPZ RPCOM CIRC T Circulate bottoms at 2.5 BPM=784 psi. 04:00 04:15 0.25 6,364 6,364 COMPZ RPCOM OWFF T Monitor the well for flow. Well static. 04:15 04:30 0.25 6,364 6,364 COMPZ RPCOM RURD P Blow down top drive 04:30 06:15 1.75 6,364 5,400 COMPZ RPCOM TRIP P Continue to TOOH with BHA#3- packer milling assembly but well is still swabbing due to hi-visc fluid. 06:15 06:45 0.50 5,400 5,400 COMPZ RPCOM OTHR P Service Crew Page 7 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:30 1.75 5,400 6,892 COMPZ RPCOM TRIP T Trip back to 6,892-ft to condition the fluid and bring the visc down. 118k Up wt, 110kDnwt. 08:30 11:00 2.50 6,892 6,892 COMPZ RPCOM CIRC T Lower visc in well from 210 sec Funnel visc.to 45 visc. while rotating at 50 rpm,3 bpm @ 594 psi. 11:00 13:15 2.25 6,892 6,892 COMPZ RPCOM TRIP T Attempt to TOOH f/6,892-ft to 6,133-ft 151k Up wt, 100k Dn wt. Had a 10 bbl gain, MU top drive and pump back to bottom due to swabbing 6,892-ft. 145k Up wt, 98k Dn wt. 13:15 13:45 0.50 6,892 6,892 COMPZ RPCOM SVRG P Service Top drive and grease wash pipe 13:45 14:00 0.25 6,892 6,892 COMPZ RPCOM OWFF P Observe the well for flow for 10 minutes. Well static. 14:00 18:00 4.00 6,892 4,802 COMPZ RPCOM PMPO P Pump out of the hole at 3 BPM = 450 psi from 6892'-4802'. 18:00 19:30 1.50 4,802 4,136 COMPZ RPCOM PMPO P Continue to pump out of the hole at 2 BPM=299 psi from 4802'-4136'. 19:30 19:45 0.25 4,136 4,136 COMPZ RPCOM OWFF P Blow down top drive and observe the well for flow for 10 minutes. Well static. 19:45 20:00 0.25 4,136 3,946 COMPZ RPCOM TRIP P Pull two stands with pumps off while pulling through casing patch. Well still swabbing. 20:00 00:00 4.00 3,946 2,328 COMPZ RPCOM PMPO P Continue to pump out of the hole at 2 BPM=220 psi from 3946'-2328'at midnight. 03/19/2015 Pump out of the hole at 2 BPM from 2328'to 411'. While monitoring the well and prepping to TOOH with the DC's the well started to flow slightly. Trip back in the hole to 1947'and circulate surface to surface with new 9.1 ppg brine. Continue to TIH from 1947'to 3945'and circulate surface to surface with new 9.1 ppg brine. Continue to TIH form 3945'to 6924', clean the pits, and load with clean 9.1 ppg brine. Circulate clean brine taking returns to the slop tank until clean 9.1 ppg brine is at surface. Continue to circulate 1.5 hole volume of clean 9.1 ppg brine at 2 BPM= 180psi. Shut down pumps. Well is slightly flowing. Lost 8 bbls during circulation. Shut in the well and RU to monitor the well pressures. Stabilized SIDPP=25 psi and SICP=20 psi. Calculated new KWF with 125 psi safety factor=9.6 ppg. 00:00 04:15 4.25 2,328 525 COMPZ RPCOM PMPO P Continue to pump out of the hole at 2 BPM=220 psi from 2328'-525'. 04:15 04:30 0.25 525 525 COMPZ RPCOM OWFF P Observe the well for flow for 10 minutes is static 04:30 05:15 0.75 525 525 COMPZ RPCOM RURD P Blow down the TD. PU and MU well control safety joint for pulling collars. 05:15 05:30 0.25 525 411 COMPZ RPCOM PMPO P Pump out of hole with the last stand of DP. 05:30 06:15 0.75 411 411 COMPZ RPCOM RURD P Blow down top drive and prepare to change elevators from 4"DP to 3-1/2"DP. Well slightly flowing. 06:15 07:30 1.25 411 1,947 COMPZ RPCOM TRIP T RIH w/BHA#3 from 411-ft to 1,947-ft 75k up wt,65k do wt 07:30 08:30 1.00 1,947 1,947 COMPZ RPCOM CIRC T Circulate surface to surface @ 2 bpm @110 psi 08:30 10:00 1.50 1,947 3,945 COMPZ RPCOM TRIP T TIH from 1947'-3945', PU= 100k, SO=80k. 10:00 11:00 1.00 3,945 3,945 COMPZ RPCOM CIRC T Circulate surface to surface at 2 BPM=238 psi Page 8 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 3,945 3,945 COMPZ RPCOM OWFF T Blow down top drive. Monitor the well for flow. Well slightly flowing. 11:30 13:30 2.00 3,945 6,924 COMPZ RPCOM TRIP T TIH from 3945'-6924', PU= 155k, SO= 102k. 13:30 17:30 4.00 6,924 6,924 COMPZ RPCOM COND T Clean pits and load with 9.1 ppg NaCI brine. RU to the kill tank, blow down lines, and test to 2500 psi. 17:30 22:30 5.00 6,924 6,924 COMPZ RPCOM CIRC T Circulate clean brine taking returns to the slop tank until clean 9.1 ppg brine is at surface. Continue to circulate 1.5 hole volume of clean 9.1 ppg brine at 2 BPM = 180psi. Shut down pumps. Well is slightly flowing. Lost 8 bbls during circulation. 22:30 00:00 1.50 6,924 6,924 COMPZ RPCOM OWFF T Shut in the well and RU up to monitor the well pressures. Stabilized SIDPP=25 psi and SICP =20 psi. Calculated new KWF with 125 psi safety factor=9.6 ppg. 03/20/2015 Weighted up the pits from 9.1 ppg to 9.6 ppg NaCl brine for the new KWF and circulate the well over to 9.6 ppg brine(lost 28 bbls to the formation while circulating). Monitored the well for flow and the well is taking approximately 18 BPH. TOOH with milling assembly and laid it down. Started the weekly BOPE test to 250/3000 psi and annular to 250/2500 psi with 3-1/2"and 4"test joints. States right to witness was waived by AOGCC inspector Jeff Jones on 3/19/15 at 21:46 hours. `Filling the IA every hour* 00:00 04:30 4.50 6,924 6,924 COMPZ RPCOM COND T Weight up the pits from 9.1 ppg to 9.6 ppg for new KWF and continue to monitor the well. 04:30 04:45 0.25 6,924 6,924 COMPZ RPCOM SFTY T PJSM for circulating new KWF 9.6 ppg NaCI brine. 04:45 05:00 0.25 6,924 6,924 COMPZ RPCOM RURD T RD pressure monitoring equipment and RU circulating equipment. Blow down top drive and line to kill tank to ensure they are clear. 05:00 07:45 2.75 6,924 6,924 COMPZ RPCOM CIRC T Circulate at 2 bpm at 200 psi and change well over from 9.1 ppg NaCl Brine to new KWF of 9.6 ppg NaCI brine. Pump 299 bbls of 9.6 ppg NaCI Brine and returned 271 bbls to the kill tank for a loss of 28 bbls to formation during circulation. 07:45 08:45 1.00 6,924 6,924 COMPZ RPCOM OWFF T Monitor well for flow on trip tank circulating across the top-establish static losses of 18 BPH. 08:45 09:00 0.25 6,924 6,924 COMPZ RPCOM RURD T Blow down line to the kill tank and blow down the top drive. 09:00 12:00 3.00 6,924 6,924 COMPZ RPCOM COND T Load the pits with 9.1 ppg NaCI brine and weight up to 9.6 ppg brine. 12:00 16:00 4.00 6,924 421 COMPZ RPCOM TRIP T TOOH from 6924'-421'. Losing -17 BPH. 16:00 17:30 1.50 421 0 COMPZ RPCOM BHAH P Lay down BHA#3-packer milling assembly and clean out boot baskets. Recovered 15 lbs of metal debris. 17:30 18:00 0.50 0 0 COMPZ WHDBO WWWH P Jet the BOPE stack of metal debris in preparation for the weekly BOPE test. Page 9 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 0 0 COMPZ WHDBO RURD P Pull wear ring and install test plug per Vetco rep. 18:45 20:00 1.25 0 0 COMPZ WHDBO RURD P RU TIW valve, Dart valve, and 4-1/2" IF x 3-1/2" IF crossover. Fill the stack. Purge lines and choke manifold. Shell test the BOPE stack to 3000 psi(passed). 20:00 00:00 4.00 0 0 COMPZ WHDBO BOPE P Weekly BOPE test to 250/3000 psi and annular to 250/2500 psi with 3-1/2"and 4"test joints. States right to witness was waived by AOGCC inspector Jeff Jones on 3/19/15 at 21:46 hours. *Filling the IA every hour` Tests: #1) Blinds; Chokes 1, 2, 3, & 16; Kill Demco(Passed) #2) Chokes 4, 5, &6; HCR Kill (Passed) #3) Chokes 7, 8, &9; Manual Kill (Passed) #4) Manual and Hydraulic Choke (Passed) #5) Chokes 10& 11 (Passed) #6) Chokes 12, 13, &14(Passed) #7) Choke 15; Dart Valve;Annular with 4"Test Joint(Passed) #8) TIW; HCR Choke; Upper Pipe Rams with 4"Test Joint(Passed) 03/21/2015 Finished the weekly BOPE test to 250/3000 psi and annular to 250/2500 psi with 3-1/2"and 4"test joints(all tests passed). States right to witness was waived by AOGCC inspector Jeff Jones on 3/19/15 at 21:46 hours. Filling the IA every hour. PU, MU, and TIH with spear assembly to 6383'. Engage fish, pulled seals assembly free at 190K(40K over), circulated bottoms up, TOOH to 4030', but were unable to get fish past the bottom of the casing patch. Tripped back in hole to 6932', released the spear from the fish, circulated bottoms up, and TOOH to 4689' at midnight. Page 10 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 0 0 COMPZ WHDBO BOPE P Continue weekly BOPE test to 250/3000 psi and annular to 250/2500 psi with 3-1/2"and 4"test joints. States right to witness was waived by AOGCC inspector Jeff Jones on 3/19/15 at 21:46 hours. *Filling the IA every hour' Tests: #9) Manual Choke(Passed) #10) Lower Pipe Rams with 4"Test Joint(Passed) #11) Upper Top Drive IBOP and Outer Test Spool(Passed) #12) Lower Top Drive manual IBOP and Inner Test Spool (Passed) #13) Lower Pipe Rams with 3-1/2" Test Joint and TIW(Passed) #14) Upper Pipe Rams with 3-1/2" Test Joint and TIW(Passed) #15) Annular with 3-1/2"Test Joint and TIW(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2850 psi Accumulator Pressure After Closer= 1600 psi Pressure Gain of 200 psi =31 seconds Full System = 164 Seconds Average N2(6 Bottles)=2053 psi 03:30 04:45 1.25 0 0 COMPZ WHDBO RURD P Break off TIW from test joint. Pull test plug, blow down line, RD testing equipment, install wear ring and lay down test joint. 04:45 05:00 0.25 0 0 COMPZ RPCOM RURD P Clean and clear the floor. 05:00 05:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up BHA. 05:15 06:30 1.25 0 406 COMPZ RPCOM BHAH P PU and MU BHA#4-spear assembly. 06:30 09:45 3.25 406 6,877 COMPZ RPCOM TRIP P RIH w/4" HT40, 14. lb/ft, S-135 DP from 406'to 6,877', PU= 150K, SO = 105K. 09:45 10:00 0.25 6,877 6,877 COMPZ RPCOM OWFF P Observe the well for flow, static losses= 16 BPH. 10:00 10:30 0.50 6,877 6,905 COMPZ RPCOM FISH P Establish fishing parameters. Engage SBE at 6938', PU, and pull seals free at 190K(40K over). PU to 6905',free PU = 160K 10:30 11:30 1.00 6,905 6,905 COMPZ RPCOM CIRC P Circulate bottoms up at 5 BPM = 1140 psi. Small amount of gas seen at surface; circulated until clean. Blow down the top drive. 11:30 17:00 5.50 6,905 4,030 COMPZ RPCOM TRIP P TOOH with BHA#4 from 6905'to 4030' (bottom of casing patch)but unable to get through the casing patch. Page 11 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 4,030 4,030 COMPZ RPCOM RGRP T Change out saver sub on the top drive and pressure test to 250/5000 psi. 18:00 21:00 3.00 4,030 6,932 COMPZ RPCOM TRIP T Trip back in hole from 4030'to 6932'. 21:00 21:30 0.50 6,932 6,932 COMPZ RPCOM FISH T Roll the pumps at 1 BPM= 102 psi, see seals engage, and release the spear from the fish. 21:30 22:30 1.00 6,932 6,932 COMPZ RPCOM CIRC T Circulate bottoms up at 2 BPM= 225 psi. 22:30 00:00 1.50 6,932 4,689 COMPZ RPCOM TRIP T TOOH from 6932'to 4689'at midnight. PU= 114K and SO= 84K. 03/22/2015 Continue to TOOH from 4689'to 500'. Observe the well for flow, static losses= 17 BPH. Lay down spear assembly and PU centralized spear assembly. TIH to top of fish, engage spear into SBE at 6932', pull free, and circulate bottoms up at 5 BPM. TOOH with fish; had to work fish through casing patch from 4039'— 4015'. Lay down centralized spear assembly and POOH laying down the SBE with pup joint, 7 joints of 3-1/2"tubing, 3 GLM's, and 1 blast joint. The connection between the first and second blast joint was galled when backing out the connection and were unable to get a lift sub to make up. Wait for overshot grapple to arrive. Engage overshot onto top of blast joint and POOH laying down blast joints, 2 pup joints, and seal assembly. 00:00 01:30 1.50 4,689 500 COMPZ RPCOM TRIP T Continue to TOOH from 4689'to 500'. 01:30 01:45 0.25 500 500 COMPZ RPCOM OWFF T Observe the well for flow,static losses= 17 BPH. 01:45 02:15 0.50 500 500 COMPZ RPCOM SFTY T Kick while tripping drill followed by AAR. PJSM for laying down BHA. 02:15 03:30 1.25 500 0 COMPZ RPCOM BHAH T Lay down BHA#4-spear assembly. 03:30 04:30 1.00 0 402 COMPZ RPCOM BHAH T PU, MU and RIH w/BHA#5- centralized spear assembly to 402-ft. 04:30 08:00 3.50 402 6,872 COMPZ RPCOM TRIP T TIH with BHA#5-centralized spear assembly from 402-ft to 6,872-ft 150k up wt, 105k do wt. work thru patch multiple times with 5.9"OD drift from 4,015-ft to 4,039-ft. 08:00 08:30 0.50 6,872 6,908 COMPZ RPCOM FISH T Establish fishing parameters. Wash down to top of fish at 1 BPM=90 psi. Engage fish at 6932'and PU to 6908'. PU= 155K. 08:30 10:00 1.50 6,908 6,908 COMPZ RPCOM CIRC T Circulate bottoms up at 5 BPM= 975 psi. Blow down top drive. 10:00 13:00 3.00 6,908 4,030 COMPZ RPCOM TRIP T TOOH with fish from 6908'to 4030'. Had to work the fish several time to get top of fish into the patch and had to work locator through the patch with 10-20K drag. 13:00 16:00 3.00 4,030 412 COMPZ RPCOM TRIP P Continue to TOOH from 4030'to 412' 16:00 17:45 1.75 412 0 COMPZ RPCOM BHAH P Lay down BHA#5-centralized spear assembly. 17:45 18:15 0.50 0 0 COMPZ RPCOM RURD P RU GBR for pulling 3-1/2"tubing. Page 12 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:15 21:00 2.75 345 63 COMPZ RPCOM PULL P POOH laying down the SBE with pup joint, 7 joints of 3-1/2"tubing, 3 GLM's, and 1 blast joint. The connection between the first and second blast joint was galled when backing out the connection and were unable to get a lift sub to make up. 21:00 23:00 2.00 63 63 COMPZ RPCOM WAIT T Wait for overshot grapple to arrive from Deadhorse while monitoring the well on the trip tank. 23:00 23:15 0.25 63 63 COMPZ RPCOM BHAH T Install grapple, PU, and MU overshot. Engage top overshot onto top of blast joint. 23:15 23:30 0.25 63 0 COMPZ RPCOM PULL P Lay down both blast joints,2 pup joints,and seal assembly. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P RD GBR and change elevators from 3-12"tubing to 4" DP. 03/23/2015 PU, MU, and TIH with cleanout assembly. Sting into F-1 packer, set 10K down, PU, and pump hi-visc sweep at 5 BPM=605 psi. PU to 7278'and spot 23 bbls corrosion inhibited(Conqor 303A)pill. TOOH to 5082', slip&cut drilling line, continue to TOOH to 412', and lay down cleanout assembly. PU F-1 packer assembly and MU setting tool. The pin threads on the pup joint on the bottom of the packer assembly and the box threads on the nipple were galled during make. Wait for packer assembly to get new pup joint and nipple bucked-up. 00:00 00:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM for picking up BHA. 00:15 01:30 1.25 0 402 COMPZ WELLPF BHAH P PU and MU BHA#6-cleanout assembly. 01:30 05:30 4.00 402 7,264 COMPZ WELLPF TRIP P TIH with BHA#6 to 7264'above top of F-1 packer. 05:30 08:30 3.00 7,264 7,285 COMPZ WELLPF CIRC P Wash down from 7,264'to 7,278', sting into packer, and set 10k down on packer top. PU and Pump Hi visc sweep from surface to surface @ 5 bpm @ 605 psi. 08:30 09:00 0.50 7,285 7,285 COMPZ WELLPF CRIH P Spot a 23 bbl CI 9.6 ppg pill on bottom from 7,278-ft to 6,678-ft. 09:00 11:00 2.00 7,285 5,082 COMPZ WELLPF TRIP P POOH to 5,082-ft 120k up wt, 80k do wt. 11:00 13:30 2.50 5,082 5,082 COMPZ WELLPF SLPC P Slip and Cut 103-ft of 1-1/8" Drill line. Service draw works, Top drive and brakes. 13:30 16:00 2.50 5,082 412 COMPZ WELLPF TRIP P POOH from 5,082-ft to 412-ft. 16:00 17:30 1.50 412 0 COMPZ WELLPF BHAH P POOH laying down drill collars and BHA#6-cleanout assembly. Clean and clear the floor. 17:30 18:00 0.50 0 0 COMPZ RPCOM RURD P RU GBR tubing running equipment and organized the pipe shed for running lower completion. 18:00 20:00 2.00 0 0 COMPZ RPCOM WAIT T Wait for wireline adaptor kit with setting sleeve and B-2 adapter nut with setting sleeve to arrive. 20:00 21:45 1.75 0 0 COMPZ RPCOM PUTB P PU F-1 packer assembly and MU setting tool. The pin threads on the pup joint on the bottom of the packer assembly and the box threads on the nipple were galled during make. Page 13 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 0 0 COMPZ RPCOM WAIT T Call for new nipple and 4'pup joint. Send nipple,4'pup, and packer assembly back to Baker to remove galled pup and buck up new pup and nipple. Monitoring the well on the trip tank. 33/24/2015 Wait for new packer assembly with nipple to arrive due to galled threads during MU. PU and MU setting tool to packer assembly with nipple. MU setting tool with packer assembly to seal assembly. TIH with lower F-1 packer assembly on DP to 7278'. Spaced out and dropped 1-7/16"steel bal. PU to up weight plus 1', packer at 7257 ft MD. Set packer per Baker rep, pressure up to 2150 psi and hold for 5 minutes(initial shear at 1000 psi). Release setting tool with 17 K over pull. TOOH with J-Hydraulic setting tool to 3961'. Repair draw works clutch. Continue to TOOH with setting tool from 3961'to surface and lay down setting tool. PU and MU test packer assembly. 00:00 07:00 7.00 0 0 COMPZ RPCOM WAIT T Continue to wait for new packer assembly with nipple to arrive due to galled threads during MU. Monitoring the well on the trip tank. SIMOPS: Perform general house keeping and maintenance on the rig. 07:00 08:30 1.50 0 47 COMPZ RPCOM PUTB P PJSM. PU and MU setting tool to packer assembly with nipple. MU setting tool with packer assembly to seal assembly. 08:30 14:30 6.00 47 7,278 COMPZ RPCOM RCST P TIH with lower F-1 packer assembly on DP to 7278'. 14:30 15:00 0.50 7,278 7,257 COMPZ RPCOM PACK P Spaced out and dropped 1-7/16" steel bal. PU to up weight plus 1', packer at 7257 ft MD. Set packer per Baker rep, pressure up to 2150 psi and hold for 5 minutes(initial shear at 1000 psi). Release setting tool with 17 K over pull. 15:00 18:00 3.00 7,257 3,961 COMPZ RPCOM TRIP P TOOH with Baker J Hydraulic setting assembly to 3961'. 18:00 19:00 1.00 3,961 3,961 COMPZ RPCOM SVRG P Service draw works 19:00 20:30 1.50 3,961 3,961 COMPZ RPCOM RGRP T Repair draw works. Insufficient air supply to high clutch causing the clutch to slip. Replace air supply swivel, clutch plates,and bladder. Function test,everything working properly. 20:30 22:00 1.50 3,961 18 COMPZ RPCOM TRIP P Continue to TOOH with setting tool from 3961'to 18' 22:00 23:00 1.00 18 0 COMPZ RPCOM BHAH P Lay down J-hydraulic setting tool. Clean and clear the floor. 23:00 00:00 1.00 0 26 COMPZ RPCOM BHAH P PU and MU BHA#7-test packer assembly. 03/25/2015 TIH with test packer to the top of the F-1 packer at 7257'and engage seals into packer/SBE pressured up on the DP to 3000 psi for 15 minutes(good test). Un-stung seals and set test packer but unable to get a test. Released test packer tagged F-1 packer seal bore top with seals picked up 1 ft set packer PT F-1 packer to 3000 psi for 30 minutes(good test). TOOH with test packer assembly from 7256'to 6307', set test packer, and PT IA to 2500 psi for 15 minutes to validate patch was holding(good test). Continue to TOOH with test packer assembly and lay down. PU, MU, and TIH with selective completion assembly on drill pipe from 291' to 4292'at midnight. Page 14 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:30 5.50 26 7,257 COMPZ RPCOM TRIP P TIH with BHA#7-test packer assembly to top of F-1 packer at 7257'. 05:30 10:00 4.50 7,257 7,256 COMPZ RPCOM PRTS P Engage seals into packer/SBE pressured up on the DP to 3000 psi for 15 minutes(good test). Un-stung seals and set test packer but unable to get a test. Released test packer tagged F-1 packer seal bore top with seals picked up 1 ft set packer, PT F-1 packer to 3000 psi for 30 minutes(good test). Released test packer. 10:00 11:00 1.00 7,256 6,307 COMPZ RPCOM TRIP P TOOH with test packer assembly from 7256'to 6307'. 11:00 12:00 1.00 6,307 6,307 COMPZ RPCOM PRTS P Set test packer and PT IA to 2500 psi for 15 minutes to validate patch was holding(good test). 12:00 12:30 0.50 6,307 6,307 COMPZ RPCOM SVRG P Grease crown,top drive, and draw works 12:30 16:00 3.50 6,307 26 COMPZ RPCOM TRIP P Continue to TOOH with BHA#7- test packer assembly 16:00 17:30 1.50 26 0 COMPZ RPCOM BHAH P Lay down BHA#7-test packer assembly. Clean and clear the floor. 17:30 21:00 3.50 0 291 COMPZ RPCOM PUTB P PU and MU selective completion: seal assembly, 3 blast joints,2 GLM's, F-1 permanent packer and B-2 setting tool with bumper sub. 21:00 00:00 3.00 291 4,292 COMPZ RPCOM RCST P TIH with selective completion assembly on drill pipe from 291'to 4292'at midnight. 03/26/2015 Continue to TIH with selective completion to top of packer at 7257'. Space out,drop 1-7/16"ball,and pump to ball seat. Set F-1 packer per Baker rep. Attempt to pressure test IA to 3000 psi but unsuccessful. A PT of the IA to 2500 psi for 30 minutes passed but unable to get a 3000 psi to pass. Discuss with town engineer,discovered cement squeezed perforations from 6947'to 6949'from RWO in 1988 which is above the packer that was just set. Release B-2 Hydraulic setting tool from packer,TOOH, and lay down. Wait of new packer assembly to arrive. PU, MU,and TIH with upper packer assembly on drill pipe to 5348'at midnight. 00:00 02:00 2.00 4,292 7,257 COMPZ RPCOM RCST P Continue to TIH with selective completion assembly on drill pipe from 4292' to top of packer at 7257'; PU= 140K and SO= 100K. 02:00 03:30 1.50 7,257 6,998 COMPZ RPCOM PACK P Space out, drop 1-7/16"ball, and pump to ball seat. Set F-1 packer per Baker rep. Pressure up to 2200 psi, hold for 5 minutes, bleed pressure off, PU 35K over, and SO 35K down. Pressure back up to 2200 psi, PU 40K over, and SO 35K down. 03:30 06:00 2.50 6,998 6,998 COMPZ RPCOM PRTS T Close the upper pipe rams and pressure up on the IA to 3000 psi. Test failed retest multiple times bleeding off, Function rams, pull 50k over pull to reset packer, retest same leaking,test t/2500 psi held f/5 min pressure up to 3000 psi leaking. Consult baker engineer for max pull. Page 15 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 6,998 6,998 COMPZ RPCOM PRTS T Continue U Attempt to pressure test packer U 2500 psi work string pul 95k over, retest U 2500 psi f/30 min good test attempt to pressure test U 3000 psi test failed. Blow down lines, release from packer, and shear ball seat. Discuss with town engineer, discovered cement squeezed perfs from 6947'to 6949'from RWO in 1988 which is above the packer that was just set. 09:00 13:00 4.00 7,257 25 COMPZ RPCOM TRIP P TOOH with B-2 hydraulic setting tool. 13:00 13:30 0.50 25 0 COMPZ RPCOM BHAH P Lay down B-2 Hydraulic setting tool and bumper sub. Clean and clear the floor 13:30 14:00 0.50 0 COMPZ RPCOM SVRG P Service draw works, iron roughnick handling equipment. 14:00 18:30 4.50 0 0 COMPZ RPCOM WAIT T Wait on New F-1 Packer from Baker Completions 18:30 20:30 2.00 0 111 COMPZ RPCOM PUTB T Load and strap new completion equipment. Redress B-2 adapter kit. PU and MU seal assembly, 1 joint, packer assembly, B-2 hydraulic setting tool and bumper sub. 20:30 00:00 3.50 111 5,348 COMPZ RPCOM RCST T TIH with upper packer assembly on drill pipe from 111'to 5348'at midnight. PU= 112K and SO= 84K. 03/27/2015 RIH with upper packer assembly to top of selective packer at 6697',space out,drop 1-7/16"ball, pump ball to seat, and set F-1 packer per Baker rep. Pressure test the IA to 3000 psi for 30 minutes(good test). Release from the B-2 setting tool from the packer, shear out the ball seat, POOH laying down drill pipe and lay down B-2 hydraulic setting tool. Perform weekly BOPE test to 250/3000 psi and annular to 250/2500 psi with 3-1/2"test joint(all tests passed); BOPE test witnessed by AOGCC inspector Louis Grimaldi. Attempted to pull test plug but were unsuccessful. ND BOPE and set back on stump. ND DSA and ND tubing head. 00:00 01:15 1.25 5,348 6,997 COMPZ RPCOM RCST T Continue to TIH with upper packer assembly on drill pipe from 5348'to top of selective packer at 6997' 01:15 02:30 1.25 6,997 6,997 COMPZ RPCOM PACK T Space out, drop 1-7/16"ball, and pump to ball seat. Set F-1 packer per Baker rep. Pressure up to 2000 psi, hold for 5 minutes, bleed pressure off, PU 40K over, and SO 30K down. Pressure back up to 2200 psi, PU 45K over,and SO 35K down. 02:30 03:45 1.25 6,997 6,927 COMPZ RPCOM PRTS T Close the upper pipe rams and pressure up on the IA to 3000 psi to test the packer for 30 minutes(good test). Release B-2 setting tool from packer. Pressure up and shear ball seat at 2400 psi. 03:45 04:00 0.25 6,927 6,927 COMPZ RPCOM RURD P Blow down top drive and lines. 04:00 04:15 0.25 6,927 6,927 COMPZ RPCOM SFTY P PJSM for POOH laying down drill pipe. 04:15 06:00 1.75 6,927 4,460 COMPZ RPCOM PULD P POOH laying down drill pipe from 6926'to 4460'. Page 16 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 4,460 4,460 COMPZ RPCOM SLPC P Slip and cut drilling line. 07:00 07:30 0.50 4,460 4,460 COMPZ RPCOM SVRG P Service rig and top drive, draw works. 07:30 08:00 0.50 4,460 4,861 COMPZ RPCOM TRIP P TIH with remaining drill pipe from derrick V 4861' 08:00 13:30 5.50 4,861 0 COMPZ RPCOM PULD P Continue POOH L/D 4" DP. Lay down B-2 Hydraulic setting tool. 13:30 15:30 2.00 0 0 COMPZ WHDBO RURD P Prep for BOPE test, pull wear ring, install test plug, and RU BOPE testing equipment. 15:30 19:30 4.00 0 0 COMPZ WHDBO BOPE P Weekly BOPE test: 250/3000 psi and annular to 250/2500 psi with 3-1/2"test joint. Test witnessed by AOGCC inspector Louis Grimaldi. Tests: 1) Blind Rams, choke 1,2,3,16, KMF Demco: Passed 2) Choke 4,5,6, kill HCR: Passed 3)Choke 7,8,9, Man kill: Passed 4)Man/HCR choke: Flow check Passed with inspection required 5)Choke 10,11: Passed 6) Choke 12,13,14, annular,4"HT dart: Passed 7)Choke 15, TIW, upper pipe rams with 3-1/2"Test Joint: Passed 8) HCR Choke, Upper Top Drive IBOP, Lower Pipe Rams with 3-1/2" Test Joint: Passed 9)Manual Choke, Lower Top Drive Manual IBOP: Passed 10)Outer Test Spool: Passed 11)Inner Test Spool: Passed Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2950 psi Accumulator Pressure After Closer= 1625 psi Pressure Gain of 200 psi=42 seconds Full System = 159 Seconds Average N2(6 Bottles)=2050 psi 19:30 21:00 1.50 0 0 COMPZ WHDBO RURD T Attempt to pull test pull but unable to unseat the test plug. Use the top drive and PU 50K but still unable to get test plug to move. 21:00 00:00 3.00 0 0 COMPZ RPCOM NUND T ND BOPE and set back on stump. ND DSA and ND tubing head. Remove old tubing head from cellar and bring new tubing head into the cellar. Page 17 of 19 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 33/28/2015 24 hr Summary NU new tubing head, PT the void to 2800 psi for 10 minutes(good test), NU DS, NU BOPE,and shell test the BOPE to 250/3000 psi(passed). Single in the hole with upper completion on 3-1/2"9.3#L-80 EUE 8rd tubing to top of packer at 6926'. Circulate well over to corrosion inhibited seawater; land the tubing hanger and RILDS. PT the tubing to 3500 psi for 30 minutes, PT the IA to 3000 psi for 30 minutes, shear SOV, install TWC,and PT to 1000 psi from below(good test). ND the BOPE, ND the DSA, NU the tubing head adapter, NU 3-1/8"tree, and RU tree testing equipment. 00:00 00:30 0.50 0 0 COMPZ WHDBO NUND T NU new tubing head. 00:30 01:00 0.50 0 0 COMPZ WHDBO PRTS T Pressure test tubing head void to 2800 psi for 10 minutes per Vetco rep. 01:00 03:30 2.50 0 0 COMPZ WHDBO NUND T NU DSA and NU BOPE. 03:30 04:00 0.50 0 0 COMPZ WHDBO RURD T MU tubing hanger to landing joint, land tubing hanger,and RILDS(using the tubing hanger as a test plug to shell test BOPE). Fill the BOPE stack. 04:00 04:15 0.25 0 0 COMPZ WHDBO RURD T Shell test BOPE to 250/3000 psi (passed). 04:15 04:30 0.25 0 0 COMPZ WHDBO RURD T BOLDS, pull landing joint, lay down tubing hanger, and lay down landing joint. 04:30 05:00 0.50 0 0 COMPZ RPCOM RURD P RU GBR tubing running equipment. 05:00 05:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up tubing 05:15 14:15 9.00 0 6,926 COMPZ RPCOM PUTB P PU seal assembly, 1 joint, GLM assembly,and single in the hole with 3-1/2"tubing. 14:15 14:45 0.50 6,926 6,926 COMPZ RPCOM HOSO P Locate on NoGo, L/D 3 jts of tubing space out, M/U Hanger 14:45 15:45 1.00 6,926 6,900 COMPZ RPCOM CRIH P Displace well w/200 bbls of corrosion inhibited seawater at 5 BPM=600 psi 15:45 16:15 0.50 6,900 0 COMPZ RPCOM THGR P Land tubing hanger and RILDS 16:15 16:45 0.50 0 0 COMPZ RPCOM RURD P R/U t/Test Tubing and Annulus 16:45 18:00 1.25 0 0 COMPZ RPCOM PRTS P Test tubing to 3500 for 30 minutes (good test)bleed off tubing to 2000 psi shut in tubing pressure up on annulus to 3000 psi test for 30 minutes(good test), Bleed the IA to 0 psi and bleed the tubing to 0 psi; pressure up on the IA quickly to shear SOV in GLM(sheared at 2400 psi). 18:00 18:30 0.50 0 0 COMPZ WHDBO MPSP P Install two-way check(TWC)per Vetco rep. Pressure up on the IA to 1000 psi for 5 minutes to test TWC from below(good test). 18:30 19:00 0.50 0 0 COMPZ WHDBO RURD P Blown down all line and RD testng equipment. Clean and clear the cellar 19:00 21:00 2.00 0 0 COMPZ WHDBO NUND P ND BOPE and set back on stump. ND DSA. Page 18 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:45 1.75 0 0 COMPZ WHDBO NUND P NU new tubing head adapter and NU new 3-1/8"tree. Tree orientation verified by 2V DSO Jon Fennie. 22:45 23:30 0.75 0 0 COMPZ WHDBO PRTS P Pressure test void to 250/5000 psi for _15 minutes(good test). 23:30 00:00 0.50 0 0 COMPZ WHDBO RURD P RU flange on wing valve to test the tree. RU tree testing equipment. Bring lubricator to the rig floor for pulling TWC. 03/29/2015 PT tree to 250/5000 psi(good test, pull TWC with lubricator, freeze protect the well with diesel, and install BPV with the lubricator. Secure the tree and cell; prep for rig move. 00:00 00:30 0.50 0 0 COMPZ WHDBO OTHR P Continue RU tree testing equipment and fill the tree with water. 00:30 01:15 0.75 0 0 COMPZ WHDBO PRTS P Pressure test the tree to 250/5000 psi for 5 minutes(good test). 01:15 02:00 0.75 0 0 COMPZ WHDBO OTHR P RD tree testing equipment and RU lubricator. 02:00 03:00 1.00 0 0 COMPZ WHDBO OTHR P Pull TWC with lubricator. 03:00 03:15 0.25 0 0 COMPZ WHDBOOTHR P RD lubricator. 03:15 04:15 1.00 0 0 COMPZ WHDBO FRZP P RU Little Red Services(LRS)to pump freeze protect diesel. PJSM. 04:15 06:15 2.00 0 0 COMPZ WHDBO FRZP P Pressure test lines to 2500 psi.. Pump 53 bbls of diesel down the IA taking returns up the tubing at 2 BPM = 1050 psi. Place tubing and IA in communication, allow the well to u-tube, and for diesel to equalize between the tubing and IA to freeze protect the well down to 1500' MD. 06:15 10:00 3.75 0 0 COMPZ WHDBO MPSP T RU lubricator and test to 1000 psi set H BPV in profile, trouble setting plug in profile not wanting to seat all the way, Pull and clean threads good seat, RD lubricator. -Simops Clean Pits 10:00 12:00 2.00 0 0 MIRU MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Final well pressures: tubing = 0 psi, IA=0 psi, and OA= 110 psi. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Continue Cleaning pits, flushing lines, and preparing for rig move. 03/30/2015 Move satellite office, shops, and pits to 1E pad entrance. Rig Release 02:00 hours. 00:00 02:00 2.00 0 0 DEMOB MOVE DMOB P Stage shops, satellite office at 2V pad entrance. `Rig Release 02:00 hours* Page 19 of 19 Sharon, Below is the approval we received from the state to set our packer high on 2V-04.This needs to be attached to the Sundry on this well post-RWO. Thanks, Janelle From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, March 26, 2015 10:31 AM To: Nesvold, Janelle R Subject: [EXTERNAL]RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Janelle, A variance is granted to set the upper packer approximately 280'above the top perforation as outlined below per 20 AAC 25.412(b). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria Loeoot talaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victorialoem@alaska.gov From: Nesvold, Janelle R mailto:Janelle.R.Nesvold@conoco hill) s.com [ P P ] Sent: Thursday, March 26, 2015 10:21 AM To: Loepp, Victoria T(DOA) Subject: RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Victoria, I would like to request a variance for 2V-04 to set the upper packer at approximately 6910'.There are downhole perfs in the casing in this well from 6955'—6965'that were cement squeezed back in 1988 but are leaking and will not hold a pressure test to 3,000 psi. I need to set a packer above these perfs in order to obtain a passing 3,000 psi pressure test on my 7" casing.There is currently a packer set below those perforations at—6980'. The top perf depth in this well is 7188' which would put our new packer 278' above that. The CBL is attached and the top of cement is at approximately 5625'. Please let me know if you have any questions. Thank you, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907) 263-4641 Cell: (281) 352-2927 From: Loepp, Victoria T(DOA) [mailto:victoria.loePP@alaska. ov] Sent: Thursday, March 26, 2015 9:44 AM To: Nesvold, Janelle R Subject: [EXTERNAL]RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Janelle, Please outline your variance request in an email. Include requested packer depth, top perf depth and CBL interpretation and reason for variance request and I will respond. Thanx, Victoria From: Nesvold, Janelle R [mailto:Janelle.R.Nesvold@conocophillips.com] Sent: Thursday, March 26, 2015 9:31 AM To: Loepp, Victoria T(DOA) Subject: 2V-04 Schematic Victoria, Attached below is the most recent proposed well schematic for 2V-04. Thanks, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907) 263-4641 Cell: (281) 352-2927 Pro / 3 - /65 Loepp, Victoria T (DOA) From: Nesvold,Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Thursday, March 26, 2015 10:39 AM To: Loepp,Victoria T(DOA) Subject: RE:2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Follow Up Flag: Follow up Flag Status: Flagged Thank you, Victoria. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent: Thursday, March 26, 2015 10:31 AM To: Nesvold, Janelle R Subject: [EXTERNAL]RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Janelle, A variance is granted to set the upper packer approximately 280' above the top perforation as outlined below per 20 AAC 25.412(b). Thanx, Victoria SCANNED +1 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Nesvold, Janelle R [mailto:Janelle.R.Nesvold@)conocophill[ps.com] Sent: Thursday, March 26, 2015 10:21 AM To: Loepp, Victoria T(DOA) Subject: RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Victoria, I would like to request a variance for 2V-04 to set the upper packer at approximately 6910'.There are downhole perfs in the casing in this well from 6955'—6965'that were cement squeezed back in 1988 but are leaking and will not hold a pressure test to 3,000 psi. I need to set a packer above these perfs in order to obtain a passing 3,000 psi pressure test on my 7"casing.There is currently a packer set below those perforations at 6980'. 1 The top perf depth in this well is 7188'which would put our new packer 278' above that. The CBL is attached and the top of cement is at approximately 5625'. Please let me know if you have any questions. Thank you, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907)263-4641 Cell:(281) 352-2927 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, March 26, 2015 9:44 AM To: Nesvold, Janelle R Subject: [EXTERNAL]RE: 2V-04(PTD 183-165, Sundry 315-027) Packer Depth Variance Request Janelle, Please outline your variance request in an email. Include requested packer depth, top perf depth and CBL interpretation and reason for variance request and I will respond. Thanx, Victoria From: Nesvold, Janelle R [mailto:Janelle.R.Nesvold@conocophillips.com] Sent:Thursday, March 26, 2015 9:31 AM To: Loepp,Victoria T(DOA) Subject: 2V-04 Schematic Victoria, Attached below is the most recent proposed well schematic for 2V-04. Thanks, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907)263-4641 Cell: (281)352-2927 2 Kuparuk Producer 2V-04 Proposed Well Schematic 1/14/2015 Janelle Nesvold 16"62.5 ppf 11-40 welded conductor from 37'-110'MD r.+ Homco Casing Patch(4010-4030') ID=5.976" 3-1/2"9.3 ppf 180 EUE 8rd 9-5/8"36 ppf J-55 BTC surface casing ADAM production tubing(ID:2.992") from 36.7-3121.2'MD(ID:8.921") . _ IMIIEINNNNII BAKER F packer @ 6950' Max.inclination 44.7°@ 4,700'MD Max.DIS 4.S°/100'@ 1,300'MD ** "C'sand from 7188'-7240' Blast Joints a BAKER F Packer @ 7270' BAKER seal assembly @ 7,277 MD F _ BAKER FB-1 packer @ 7,279'MD 2.75"CAMCO'0'nipple no go @ 7,302'MD CAMCO shear out sub @ 7,308'MD "A"sand from 7327-7,335',7344'-7373' 7'26 ppf J-55 BTC production casing from surface-7,662.1'MD tKAit zti,-04 Ill, I�j31ro5U ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 20,2015 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, I am following up the verbal notification of BOPE usage on Nabors 9ES with a written report. Time of BOPE Use: 3/19/2015 at 22:30 hours Well Location:2V-04 - API Number: 50-029-21041-00 PTD Number: 183-165 ' Rig Name:Nabors 9ES - Operator Contact: Theresa Lee 907-263-4837 Theresa.M.Lee(aconocophillips.com for Janelle Nesvold Operations Summary: Circulated hole volume of 9.1 ppg brine then started pulling out of the hole from 6,935'to 3,945' and stopped to monitor, saw slight flow. Tripped back in to 6,924 and circulated 1.5 hole volumes with 8 bbl losses. Shut in VBRs to monitor the well pressures when we observed well building to SIDP 25 psi, SICP 20 psi. , BOPE Used: Upper Rams 2 7/8"x 5"VBR Reason for BOPE Use: Control flow of fluids from the wellbore. Actions To Be Taken: Calculated new kill weight fluid with 125 psi over balance to be 9.6 ppg. We circulated the hole over to 9.6 ppg NaCl Brine and monitored the well for flow, losses of 12-18 bbls/hr.Plan going forward is to Trip out of hole with packer milling assembly from 6,924-ft to surface and conduct weekly BOP test that was submitted at 18:00 hrs on Thursday March 19,2015. If any changes occur during this purposed operation we notify immediately. If you have any questions or require any further information,please contact me at 263-4837. Sincerely, Theresa Lee RWO Engineer CPAI Drilling and Wells OF T4 THE STATE Alaska Oil and Gas ofALASKA Conservation Commission - IEiitx_,_ 333 West Seventh Avenue ---- � GOVERNOR BILL WALKER Anchorage.e. Alaska 99501-3572 Main: 907.279.1433 fALASY ire r�C`l�� Fax: 907 276.7542 a l www.aogcc.alaska.gov Janelle Nesvold - 1 66- Senior Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 2V-04 Sundry Number: 315-027 Dear Ms. Nesvold: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair 2/404 DATED this 2.3 day of January, 2015 Encl. I STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI__.ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r� Change Approved Program r Suspend r Rug Ferforations r Perforate r Pull Tubing Fo Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development r 183-165 ' 3.Address: 6.API Number: Stratigraphic r Service r , P.O. Box 100360,Anchorage,Alaska 99510 50-029-21041-00 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception", Yes r No J KRU 2V-04 • 9.Property Designation(Lease Number): p/y? 10.Field/Pool(s): ADL 15044• as(or{y Kuparuk River Field/Kuparuk River Oil Pool ' 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft)• Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7675 • 6203 • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110' 110' SURFACE 3085 9.625 3121' 2668' RECEIVED PRODUCTION 7626 7 7662' 6192' 1�► JAN 152015 A0000 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7188-7240,7327-7335,7344-7373 * 5768-5814,5891-5898,5906-5932 3.5 J-55 7309 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER'FB-1'PERMANENT PACKER MD=6936 TVD=5552 • PACKER-BAKER'FB-1'PERMANENT PACKER MD=7279 TVD=5848 • SAFETY VLV-CAMCO TRDP-1A SSSV MD=1832 TVD=1714 • 12.Attachments: Description Summary of Proposal J 13 Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r, 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 2/15/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r• Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Janelle Nesvold @ 263-4641 Email: Janelle.R.Nesvold@conocophillips.com Printed Name Janell- Nesvold / Title: Sr. Wells Engineer Signature " • , ' / Phone:263-4641 Date 04-0 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\5-021 Plug Integrity r BOP Test VMechanical Integrity Test r Location Clearance r Other: Bop tc5f 1`o 3,000p5, `/,/pSP 8- ,2 73$ pSr 4pnvlar) -i �« Fz 2500 i)5 1 his yv , Fort5$ d 4'1tVil l't4,v1v / �tFF-cr 1- 17ii%I3 rd ij te.fi�'I Spacing Exception Required? Yes ❑ No Subsequent Form Required: Go-4a4 2—/e APPROVED BY / / Approved by• COMMISSIONER THE COMMISSION Date' -23 -/ 7 - pprp�e¢�ppl tlpr►Is�v V for 12 months Tom the date of approval. p Form 10-403(Revised 10/2012) U K I I N//"1\ L ,/i /1� Submit Form and Attachments in Duplicate V rL //22/i RBDMS,3 JAN 2 6 2015# '/ / .1i /4_2-is • RECEIVED JAN 152015 AOGCC ConocoPhulhps January 12, 2015 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Foerster: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Preduccr 2V-04(PTD: 183-165). Well 2V-04 was originally completed in 1984 as a selective completion and was put on production in both the A and C sands. In 1985 the well was converted to an A&C sand selective injector. In 2010, a leak was detected at the lower packer causing uncontrolled injection into the C-sand. The well was shut in in 2013 after attempts to plug off the C-sand were unsuccessful. The objective of this workover is to pull the existing selective completion across the C-sand and replace with a new 3 '/2" selective stacked packer gas lift completion to return the well to an A- sand injection with an option of C-sand injection. If you have any questions or require any further information,please contact me at 263-4641 or Janelle.R.Nesvold@conocophillips.com. Sincerely, Janelle Nesvold Wells Engineer CPAI Drilling and Wells KUP 2V-04 • ConocoPhillips i Well Attributes Max Angle&MD TD A','0 Int;. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftK8) Act Btm(RKB) 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 """ Comment - H2S(ppm) Date Annotation End Date - KB-Grd(ft) Rig Release Date Well comp -20.04 5i3i2013 1210 08 PM SSSV:LOCKED OUT Last WO: 1/2/1988 41.49 12/17/1983 -- Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,425.0 4/27/2013 Rev Reason:TAG haggea 5/3/2013 - Casing Strings @ c,'" Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 11-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd HANGER,35 SURFACE 95/8 8.921 36.7 3,121.2 ' 2,668.1 36.00 J-55 BUTT Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd PRODUCTION 7 6.276 36.7 7,662.1 6,191.8 26.00 J-55 ETC Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING WO 31/2 2.992 35.2 7,308.9 5,875.2 9.30 J-55 EUE8rdABMOD Completion Details CONDUCTOR,_ Top Depth 37-110 (TVD) Top Incl Nomi... __ Top(RKB) (RKB) (°) gem Description Comment ID(In) 35.2 35.2 0.16 HANGER GRAY TUBING HANGER 3.500 RL L._._� 1,831.9 1,714.0 39.46 SAFETY VLV CAMCO TRDP-1A(USED)SSSV-LOCKED OUT LOWER SLEEVE 2.812 SAFETY VLV, V V 924/1993 1,832 6,935.2 5,550.8 32.05 SEAL ASSY BAKER LOCATOR/SEAL ASSEMBLY(10'SEALS) 4.000 '• 6,936.2 5,551.7 32.04 PACKER BAKER'FB-1'PERMANENT PACKER 4.000 k,... 6,939.5 5,554.5 31.99 SBE BAKER SEAL BORE EXTENSION 4.000 7,201.8 5,780.4 29.13 BLAST CAMCO STEEL BLAST JOINTS-3(NOT RINGS) 2.867 JOINTS 7277.2 5,846.6 28.13 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY(5'SEALS) 4.000 7,279.0 5,848.2 28.11 PACKER BAKER'FB-1'PERMANENT PACKER 4.000 SURFACE, A ' 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION 4.000 37-3,121 7,301.6 5,868.8 28.24 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 F, 7,308.1 5,874.5 28.14 SOS BAKER SHEAR OUT SUB.ELMD @ 7292'per SWS(PROF on 3.000 GAS 6LI.89T7 5/19/1999 tr Perforations 8,Slots SEAL ASSY, Shot 6.935 '�i"'''-/ Top(TVD) Btm(TVD) Dens r= Top(RKB)Btm(RKB) (RKB) (MB) Zone Date (oh-- Type Comment PACKER,6,936 7,188.0 7,240.0 5,768.3 5,813.9 C-4,UNIT B, 4/3/1984 12.0 IPERF 120 deg.phasing;5 1/2"CSG Gun ' 2V-O4 seE,6.940 7,327.0 7,335.0 5,891.0 5,898.0 A-4,2V-04 4/3/1984 4.0 IPERF 90 deg.phasing;2 1/8"TT 7,344.0 7,373.0 5,905.91 5,931.5 A-3,2V-04 4/3/1984 4.0 IPERF 90 deg.phasing;2 1/8"TT Notes:General&Safety End Date Annotation PRODUCTION, 5/7/201 O NOTE:Confirmed Packer leak or behind pipe channel up from TTL to C-Sand wM/FL 8 PPROF 7,027 PRODUCTION, t 7.096 PRODUCTION, 7.164N, E. 7,188- IP7,24ERF0, l SEAL ASSY, _ 7,277 PACKER.7,279 r SBE,7282 \I ( NIPPLE,7,302 as- II. SOS,7,308 TS-,'; Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run PE N...Top(RKB) MIME* CI Make Model (in) Sery Type Type (in) (psi) Run Date Com... z3na,RF,33s 1 6,897.4 5,518.8 32.53 CAMCO KBUG 1 GAS LIFT DMY RK 0.000 0.0 1/3/1998 2 7,026.6 5,630.9 31.44 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26/2010 (PERE, r-74 3 7,094.7 5,688.1 30.54 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4262010 7.3447.373 4 7,164.1 5,747.6 29.62 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26/2010 PRODUCTION, 37-7,662 A 4. TO,7,675 • 2V-04 Rig Workover, Selective Stacked Packer (PTD #: 183-165) Current Status: The well is currently shut in. It has a leak in the lower packer. Scope of Work: Pull the existing selective completion across the C-sand and replace with a new 3 '/2"selective stacked packer completion. General Well info: MPSP: 2,738 psi(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Kuparuk A/C-Sands—2,960 psi/5,822' TVD(9.7 ppg EMW)measured 4/27/2013.Requested an updated SBHP. Wellhead type/pressure rating: Gray/McEvroy Gen III,7 1/16"5M Top x 11"3M Bottom Nabors 7ES BOP Config: Annular/Variable Pipe Rams/Blind Rams/Mud Cross/Variable Pipe Ram MIT results: MITxIA—Passed 03/20/2014,MIT-T—Passed 04/27/13 Well Type: Injector Estimated Start Date: October,30,2014 Production Engineers: Deanna van Dam/Mike Balog Workover Engineer: Janelle Nesvold(263-4641 /Janelle.R.Nesvold@conocophillips.com) Proposed Pre-Rig Work: 1. RU Digital Slickline.Obtain updated SBHP. 2. Set CA-2 plug in 2.75"Camco `D' nipple profile.PT and DDT.RD E-line.Ensure SSSV has been locked out. 3. Set catcher sub on top of CA-2 plug. 4. Pull DV from GLM#1 at 6,897'RKB and leave open. 5. RIH and cut tubing at mid joint of the first full joint above the upper seal assembly. 6. RDMO Digital Slickline. 7. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,PT from below,ND tree,NU BOPE&test to 3,000 psi. 4. Pull blanking plug&BPV,screw in landing jt,BOLDS's,unland tbg hgr. 5. POOH laying down 3-1/2"tbg. a. If tbg will not pull free,RU E-line: Fire a string shot and cut the tbg in the middle of the second full joint above the Seal Assembly. 6. MU Packer Mill and single in on drillpipe. • • 2V-04 Rig Workover, Selective Stacked Packer (PTD #: 183-165) a. If tubing was cut, MU overshot assembly to pull Seal Assembly free from upper permanent packer and TOOH in stands to lay down same. 7. Mill upper permanent packer until able to pull free.POOH. 8. RIH with spear to fish packer and upper selective. 9. POOH standing back drillpipe and laying down Baker FB-1 packer and selective assembly. 10. MU overshot assembly to pull Seal Assembly free from upper Baker FB-1 permanent packer and TOOH in stands to lay down same. 11. MU Tandem String Mill Assembly and Cleanout to the lower packer. 12. TOOH laying down 3-1/2"DP and Cleanout assembly. 13. MU&TIH w/3-1/2" L-80 injector selective completion with a lower 3-1/2"x 7"Baker FHL retrievable packer located at—7,260'MD and an upper 3-1/2"x 7"Baker FHL packer located at—6,895'MD. 14. Space out. Drop ball/rod to set both Baker FHL packers. Shear upper PBR. 15. Space out w/pups. Stab seal assembly into PBR and land tubing hanger. 16. PT the tbg to 3,500 psi,bleed tbg to 2,500 psi, PT the 1A to 3,000 psi for 30 min and record. Bleed the IA to zero,then the tbg. Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing jt,install BPV. PT BPV from below. 18. ND BOPE. 19. NU tree. Pull BPV&install tree test plug. Test tree. Pull test plug. 20. Freeze protect well w/diesel. 21. Set BPV. 22. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells 2. Pull BPV 3. RU Slickline: a. Pull ball and rod b. Pull SOV and replace w/DV c. Pull RHC plug body d. Pull catcher and CA-2 plug e. Ensure well is freeze protected and RDMO 4. Turn well over to Ops. • Kuparuk Producer 2V-04 Pro•osed Well Schematic r"---1 1/14/2015 Janelle Nesvold :.,> _'. M f cr+crclriviY 16"62.5 ppf H-40 welded conductor from 37'-110'MD g3t4 it * 001.1 TRDP-1A 055V-locked out @ 1,832'MD t544 WV R.4 VR4 rif,.° *: 3-1/2"9.3 ppf L80 EUE 8rd 9-5/8"36 ppf 1-55 BTC surface casing ABMOD production tubing(ID:2.992") from 36.7'-3121.2'MD(ID:8.9211 0 c« Baker P8R @ 6,965'MD/5721.8'TVD(ID:3") .. BAKER FHL packer@`7,000'MD N ll Max.inclination 44.7°@ 4,700'MD v'v Max.DLS 4.5°/100'@ 1,300'MD I S' farF 404: m IV ?l`d elF::,?: s "C"sand from 7188'-7240' #rte Baker PBR @ 7,029'MD BAKER FHL packer@ 7,260'MD ARP iitlfil 2.813""D"nipple @+/-7509' at f Rai ? BAKER seal assembly @ 7,277'MD 140 �Y BAKER FB-1 packer @ 7,279'MD ;3;4: rilef ; 44' oW v, 2.75"CAMCO'D'nipple no go @ 7,302'MD Ism WA, CAMCO shear out sub @ 7,308'MD rc A S: �. �. "A"sand from 7327'-7,335',7344'-7373' 7"26 ppf J-55 BTC production casing from surface-7,662.1'MD V. ect Well History File C~ e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- ~,_.~ - I ~.~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scanne hie by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: ~ NOTES: [] Logs of-various kinds [] Other BY: (~~REN VINCENT SHERiYL MARIA LOWELl. Project Proofing = TOTAL PAGES ~_~- BY: BEVERLY BREN~ SHERYL MARIA Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 LOWELL PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~(~' YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERLY BREN VINCEN~ER_~MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIOUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wl:x:l ew �\\ I% % THE STATE Alaska 011 and as ofALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op .- Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Sc�NNEp 1 12013 Tyson Wiese Sr. Wells Engineer ConocoPhillips Alaska, Inc. 3 _ (p 5 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2V -04 Sundry Number: 313 -262 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED thi0 day of June, 2013. Encl. STATE OF ALASKA itk ly ACA OIL AND GAS CONSERVATION COM ION 10' IUD` APPLICATION FOR SUNDRY APPR�VALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill 1` Perforate New Pool fl Repair w ell [°° Change Approved Program [- Suspend r Plug Perforations E Perforate 1 Pull Tubing E Time Extension E Operational Shutdow n E Re -enter Susp. Well 1"'"" Stimulate E Alter casing C Other:Crystal Seal /Packer Repair W. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory [_' 183 -165. 3. Address: Stratigraphic 1 Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21041 - 00, 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes E No 14 2V - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25644. Kuparuk River Field / Kuparuk River Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7675. 6203* none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110' 110' SURFACE 3085 9.625 3121' 2668' PRODUCTION 7625 7 7662' 6192' MAY 2 9 20 , A0t ,oC Perforation Depth MD (ft1: Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7188 -7240, 7327 -7335, 7344-7373 5768 -5814, 5891 -5898, 5906 -5932 3.5 J - 7309 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'FB -1' PERMANENT PACKER MD= 6936 TVD= 5552' PACKER - BAKER'FB -1' PERMANENT PACKER MD= 7279 TVD= 5848." SSSV - CAMCO TRDP -1A MD =1832 TVD= 1714• 12. Attachments: Description Summary of Proposal [.i • 13. Well Class after proposed work: Detailed Operations Program ( BOP Sketch r Exploratory ° Stratigraphic E Development r Service I 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/20/2013 Oil 1 Gas r WDSPL E Suspended r 16. Verbal Approval: Date: WINJ 1✓ ✓ GINJ r WAG E Abandoned E Commission Representative: GSTOR r SPLUG 1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tvson.M.WieseCci).conocoohillios.com Printed Name Tyson ese Title: Sr. Wells Engineer Signature /` Phone: 263 -4259 Date S —' —'l-t)rS Commission Use Only /► Sundry Number: ).. / , j Z Conditions of approval: Notify Commission so that a representative may witness v Plug Integrity 1 BOP Test F Mechanical Integrity Test r Location Clearance [— Other: Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: / _- 4, D t Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: vi /C Approved application is valid tor 12 months trom the date of approval. 47,, Form 10 -403 (Revised 1 � 1 ORIGINA! RB ®t�s JUN 1 i ' 101 And Attachments / Duplicate \ \* • • • 2V -04 Crystal Seal Packer Leak Treatment Permit to Drill #: 183 -165 The objective of the proposed 2V -04 Crystal Seal treatment is to squeeze Crystal Seal through the packer leak and into the C -sand perforations to plug the packer leak, and restrict future injectivity into the C- sands. If C -sand injectivity is not inhibited, a small volume cement plug will be placed across the packer leak. Increase A -sand injectivity and overall A -sand support in an area that has been limited since the packer leak was found in 1995. Proposed Crystal Seal Procedure: // Slick Line / Little Red: 1. RIH and tag top of cement cap @ 7,318' KB, approx. 10' below T.T. 2. B &F pup at retainer set depth. DMY drift for cement retainer assembly. Halliburton Pumping Services: (Fullbore Crystal Seal Treatment) 1. Ensure that the 10 -403 Sundry has been approved by AOGCC. 2. Perform step rate injectivity test to confirm rates required for Crystal Seal placement. 3. Design Crystal Seal stage concentrations based on injectivity results. 4. Pump the Crystal Seal treatment in 5 stages, ramping concentration from 0.05 ppg — 0.25 ppg, using clean seawater as base fluid. Final stage volumes to be determined based on treating pressure response seen during pumping. 5. After treatment is completed, displace Crystal Seal with 40 bbls of clean seawater, and 20 bbls of Diesel for freeze protect. No not over displace Crystal Seal treatment. Schlumberger Coil Tubing: (FCO and Post Treatment Inj. Test) 1. RIH and perform a Crystal Seal FCO down to the previous cement cap, removing any excess product from the well, using a seawater base fluid. 2. Perform a 10 bbl injectivity test using clean seawater, to determine if C -sand injection was inhibited, or if a cement packer repair will be needed to allow for A -sand support. 3. POOH laying in seawater to 2,300' KB and diesel F.P. to surface. E -Line: (If C -sand injection rate is adequate to place cement plug across packer leak) 1. RIH and set HAL squeeze packer in 5' pup below T.T. @ 7,306' KB. Schlumberger Coil Tubing: (cement plug across lower packer leak) 1. RIH, sting into squeeze packer, ensure pump rates required for cementing, and pump the 5 bbl cement plug around the T.T., and up through the packer leak. 2. POOH and Freeze Protect. WOC to develop 2,000 psi C.S. prior to milling. Schlumberger Coil Tubing: (Milling / Injection Test / Under - reaming) 1. RIH and mill up the squeeze packer and cement down to approx. 7,314' KB. 2. Perform Injection test to ensure the cement plug is holding, and C -sand is isolated. 3. Mill through remaining cement and down into the sand plug below. Under -ream 7" from sand top to T.T. and perform FCO to clear A -sand perfs of sand plug. 4. RDMO. Turn well over to operations to perform A -sand injection testing. With C -sand packer leak repaired, A -sand should take a split and this well should provide increased injection support to the area. TW III • • TW 5-23 -2013 2V -04 PTD #: 183 -165 Crystal Seal / Cement Plug Current Completion Proposed Treatment Al " 16 "" 62.50# H -40 Casing @ 110' KB Camco TRDP SSSV @ 1,832' KB AI 9 518" 36# J -55 Casing @ 3,121' KB 1 1...2„ pump Fullbore II I Crystal Seal treatment down tubing, past the packer leak and into the C -sand perfs Perform CTU Clean out to remove excess Crystal Seal DMY @ 6,897' KB from tubing. 3.) Perform 10 bbl injectivity test to - - � gather data on «�- Crystal Seal impact. Baker FB -1 Perm Packer @ 6,936' KB i i 4.) Set Squeeze IM's: Packer profile in tubing ir below the nipple DMY (ca 7,027 KB DMY (@ 7,095' KB 5.) Perform 5 BBL DMY @ 7,164' KB CTU cement job using squeeze packer. C Sand Perfs: - • 7,188' - 7,240' KB Crystal Seal Treatment �� 6) Mill out squeeze packer and cement plug to 7.314' KB. 1 i '. Baker FB -1 Perm Packer Q 7.) Perform Injection 7.279' KB wi large leak p S m Test to confirm the ce ment plug is 68' Cement holding and C -sand Plug is isolated Camco D Nipple @ 7,302' KB LA 8.} Mi11 a rd d cement nt un and under ream 7" casing from 7.322' to T.T. 2.68" HAl Squeeze Packer @ 7,306' KB aa'�` 9.) pen up A -sand to Baker SOS @ 7.3 KB p erfs for injection. 10.) Turn well over to Pre Treatment 4' ,, = '. #*•„ cement cap to k x >.. operations to BOO 7,318' KB for A-sand Injection. A -Sand Perfs: _ 7,327' — 7,335' KB '` :i ' 7,344' - 7,373' KB Pre Treatment Sand Plug back to 7,322' KB, covering A -sand perfs .41::: : . : - 7" 26# J -55 Casing @ 7.662' KB • TW KU P 2V -04 - ConocoPhillips 01 Well Attributes Max Angle & MD TD III FV <t5ka, Itx;. Wel!bore APUUWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm MB) 500292104100 KUPARUK RIVER UNIT INJ 44.70 4,700.00 7,675.0 "" ' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 1/2/1988 41.49 12/17/1983 Well Conf9: - 2V-04, 5/3/2013 12:10'08 PM - .- Schematic - Actual Annotation Depth (1166) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,425.0 4/27/2013 Rev Reason: TAG haggea 5/3/2013 -- -- Casing Strings Casing Description String 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (t.. Set Depth (ND) ... String Wt.. String ... String Top Thrd HANGER, 35 SURFACE 95/8 8.921 36.7 3,121.2 2,668.1 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String .. String Top Thrd 1�1-13 PRODUCTION 7 6.276 36.7 7,662.1 6,191.8 26.00 J -55 BTC Tubing Strings S- Tubing Description String 0... String ID ... Top (RKB) 501 Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO I 3 1/2 2.992 I 35.2 I 7,308.9 I 5,875.2 9.30 J -55 EUE8rdABMOD Completion Details CONDUCTOR, Top Depth 37 -110 - (TVD) Top Inc! Nomi... Top (ftKB) ("KB) ( °) Item Description Comment ID (in) ill 35.2 35.2 0.16 HANGER GRAY TUBING HANGER 3.500 1 ,831.9 1,714.0 39.46 SAFETY VLV CAMCO TRDP -1A (USED) SSSV - LOCKED OUT LOWER SLEEVE 2.812 SAFETY VLV, 9/24/1993 1,832 6,9352 5,550.8 32.05 SEAL ASSY BAKER LOCATOR/SEAL ASSEMBLY (10' SEALS) 4.000 6,9362 5,551.7 32.04 PACKER BAKER 'FB-l' PERMANENT PACKER 4.000 6,939.5 5,554.5 31.99 SBE BAKER SEAL BORE EXTENSION 4.000 7,201.8 5,780.4 29.13 BLAST CAMCO STEEL BLAST JOINTS - 3 (NOT RINGS) 2.867 JOINTS 7,277.2 5,846.6 28.13 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY (5' SEALS) 4.000 7,279.0 5,848.2 28.11 PACKER BAKER'FB -1' PERMANENT PACKER 4.000 su RFACE, I ■ 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION 4.000 37 - 3,121 7,301.6 5,868.8 28.24 NIPPLE CAMCO 'D' NIPPLE NO GO 2.750 VW GAB LIFT, 7,308.1 5,874.5 28.14 SOS BAKER SHEAR OUT SUB. ELMD @ 7292' per SWS IPROF on 3.000 6,897 5/19/1999 Perforations & Slots Shot SEAL ASSY, lop (ND) Btm (TVD) Dens 6,935 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh ... Type Comment PACKER, 6,936 7,188.0 7,240.0 5,768.3 5,813.9 C-4, UNIT B, 4/3/1984 12.0 IPERF 120 deg. phasing; 5 1/2" CSG Gun 2V-04 SBE, 6,940 - 7,327.0 7,335.0 5,891.0 5,898.0 . A-4, 2V-04 4/3/1984 4.0 IPERF 90 deg. phasing; 21/8" TT 7,344.0 7,373.0 5,905.9 5,931.5 A -3, 2V -04 4/3/1984 4.0 IPERF 90 deg. phasing; 2 1/8" TT Notes: General & Safety End Date Annotation PRODUCTION, _ 5/7/2010 NOTE: Confirmed Packer leak or behind pipe channel up from TTL to C - Sand wNJFL 8 PPROF 7,027 F E:- PRODUCTION, 1. IMI 7,095 P RODUCTION, f 7,164 IPERF, 7,188 -7,240 a' SEAL ASSY, 7,277 P ACKER, 7,278 _ SSE,7,282 l 2 NIPPLE, 7,302 SOS. 7.308 Mandrel Details Top Depth Top Port (TVD) Intl 00 Valve Latch Size TRO Run IPERF, N... Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 7,327 -7,335 1 6,897.4 5,518.8 32.53 CAMCO KBUG 1 GAS LIFT DMY RK 0.000 0.0 1/3/1998 2 7,026.6 5,630.9 31.44 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26/2010 3 7 5,688.1 30.54 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26/2010 PERF, 7,3447,373 4 7 5,747.6 29.62 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26Y2010 -\\. ! i P RODUCTION, 37 -7,675 TD, 7,675 �, OF T� • • �w ������yys THE STATE Alaska Oil and Gas 7 ofALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue FA LaS�� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese b5- Wells Engineer 3 ConocoPhillips Alaska, Inc. k P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2V -04 Sundry Number: 312 -416 SCANNED JAN 11 2013 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. • cer: y, 4' ,, ommissioner DATED this v day of November, 2012. Encl. STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMM1OON I APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request: Abandon f Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Flug Perforations r Perforate r Pull Tubing r Time Extension f Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Crystal Seal Treatment F;: • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183 -165 . 3. Address: Stratigraphic r Service p' 6. API Numb - P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21041 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes J No J 2V - 04 f 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25644 . Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7675 . 6203 • 7571' 6109' Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110' 110' SURFACE 3085 9.625 3121' 2668' PRODUCTION 7625 7 7662' 6192' RECEIVED OCT 302012 AOGGG Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7186- 7240', 7327'- 7335', 7344' -7373' 5768'- 5814', 5891'- 5898', 5906-5932' 3.5 J -55 7309 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER'FB -1' PERMANENT PACKER MD= 6936 TVD= 5552 PACKER - BAKER 'FB -1' PERMANENT PACKER MD= 7279 TVD= 5848 SSSV - CAMCO TRDP -1A SSSV MD =1832 TVD =1714 12. Attachments: Description Summary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17 • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/29/2012 Oil r Gas 1 WDSPL r Suspended r 16. Verbal Approval: Date: WIND r . GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tyson .M.WieseCa?conocoohiliips.com Printed Name Tyso Wiese Title: Wells Engineer Signature � ` \ Phone: 263 -4250 Date ID — 1 - 1:\ — 1 1017, Commission Use Only Sundry Number:5 I Z - iik „ Conditions of approval: Notify Commission so that a representative may witness w Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No 3/4 Subsequent Form Required: /0 Y 0 ilf 1/ APPROVED BY // /�—// Approved by: • ' SSIONER THE COMMISSION Date: !/ 4 / I ,. t�[fr -. n ) . • • • rove; - • lc ion is vali tor 1 montns trom the date of a pproval. �r) AL ...,IG riegM 40 w ( e 1. Submit Form and Attach ents in Duplicate P-curci)F-«lzirivY 0100-*/#‘ • • 2V -04 Crystal Seal Packer Leak Treatment Permit to Drill #: 183 -165 The objective of the proposed 2V -04 Crystal Seal treatment is to squeeze Crystal Seal through the packer leak and into the C -sand perforations to plug the packer leak, and restrict future injectivity into the C- sands. Increase A -sand injectivity and overall A -sand support in an area that has been limited since the packer leak was found in 1995. Proposed Crystal Seal Procedure: Slick Line / Little Red: 1. RIH and tag fill in 7" casing to determine if A -sand perfs are covered. 2. RIH and obtain updated SBHP data. 3. Set CA -2 plug in nipple @ 7,302' KB and perform MIT -T to 2,500 psi. Pull CA -2 plug. 4. Using Diesel, perform MIT -OA to 1,500 psi. Schlumberger Coil Tubing: 1. RIH and confirm fill tag in 7" casing. 2. Pump a sand plug to isolate the A -sand perfs from the Crystal Seal treatment. Attempt to place top of sand to within 10' of tubing tail. Slick Line / Little Red: 1. Allow sand plug to settle out for at least 12 hours. 2. RIH with bailer and tag top of sand at approx. 7,322' KB. 3. Use bailers to adjust the top of sand to within desired window (10 -15' outside tubing tail). 4. Pump an injectivity test, ramping from 1 -4 bpm, in 1 bpm increments. Record Results. Halliburton Pumping Services: 1. Ensure that the 10 -403 Sundry has been approved by AOGCC. 2. Perform step rate injectivity test to confirm rates required for Crystal Seal placement. 3. Design Crystal Seal stage concentrations based on injectivity results. 4. Pump the Crystal Seal treatment in 5 stages, ramping concentration from 0.05 ppg — 0.25 ppg, using clean seawater as base fluid. Final stage volumes to be determined based on treating pressure response during pumping. 5. After treatment is completed, displace Crystal Seal with 40 bbls of clean seawater, and 20 bbls of Diesel for freeze protect. No not over displace Crystal Seal treatment. 6. RDMO Schlumberger Coil Tubing: 1. RIH and perform a Crystal Seal FCO, removing any excess product from the well, using a seawater base fluid. Do not clean out sand plug covering A -sand perfs below. 2. Lay in 20 bbls diesel for freeze protect following the clean out. Little Red: 1. Perform Post Crystal Seal injectivity test, limiting injection pressure to 2,000 psi. 2. This test is to measure the success of the treatment, and to ensure that the well can take the minimum injectivity to prevent the formation of ice plugs. 3. Report injection data to CPF -2 Prod. Engineer to determine if it should be brought back online. If injection rate is still very high, other packer leak treatments may be designed. TW __. KUP 2V-04 ConocoPhiflip$ , ".a Well Attributes Max-Angle-8. MD Alaska, Inc. Wellbore API/11W1 Field Name Well Status !note) MD (ftKB) Act Btm (ftKB) °-` 500292104100 KUPARUKRIVERUNIT INJ 44.70 4,700.00 7,675.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date wan coeea: - 2004,1DanDez 9:1a:2D AM SSSV: LOCKED OUT Last WO: 1/2/1988 41.49 12/17/1983 Schematic -A6W6I Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,452.0 4/26/2010 Rev Reason: DRILL DATES osborl 10/4/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) _. String Wt.. String ... String Top Thrd l CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H-40 WELDED • Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 36 SURFACE 95/8 8.921 36.7 3,121.2 2,668.1 36.00 J -55 BUTT " w Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6276 36.7 7,662.1 6,191.8 26.00 J-55 BTC Tubing Strings " Tubing Description String 0... IString ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) _. String Wt.. String ... String Top Thrd TUBING WO 31/2 I 2.992 I 35.2 7,308.9 5,875.2 I 9.30 I J -55 EUE8rdABMOD Completion Details " CONDUCTOR, Top Depth 37.110 i (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) rwu 35.2 35.2 0.16 HANGER GRAY TUBING HANGER 3.500 1,831.9 1,714.0 39.46 SAFETY VLV CAMCO TRDP -1A (USED) SSSV - LOCKED OUT LOWER SLEEVE 2.812 SAFETY VLV, - 9/24/1993 1,832 6,935.2 5,550.8 32.05 SEAL ASSY BAKER LOCATOR/SEAL ASSEMBLY (10' SEALS) 4.000 6,9362 5,551.7 32.04 PACKER BAKER'FB -1' PERMANENT PACKER 4.000 6,939.5 5,554.5 31.99 SBE BAKER SEAL BORE EXTENSION 4.000 7,201.8 5,780.4 29.13 BLAST CAMCO STEEL BLAST JOINTS -3 (NOT RINGS) 2.867 JOINTS 7,277.2 5,846.6 28.13 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY (5' SEALS) 4.000 7,279.0 5,8482 28.11 PACKER BAKER'FB -1' PERMANENT PACKER 4.000 SU37 -3,121 RFACE. I 7,281.5 5,850.4 28.07 SBE BAKER SEAL BORE EXTENSION - 4.000 7,301.6 5,868.8 2824 NIPPLE CAMCO 'D' NIPPLE NO GO 2.750 GAS LIFT, 7,308.1 5,874.5 28.14 SOS BAKER SHEAR OUT SUB. ELMD @ 7292' per SWS (PROF on 3.000 6,897 5/19/1999 Perforations & Slots Shot SEALASSY, J Top(TVD) Btm(TVD) Dens 8,935 { Top (ftKB) Bt7 (ftKB) (ftKB) (ftKB) Zone D9 ( sh Type Comment PACKER, 6,836 7,188.0 7,240.0 5,768.3 5,813.9 C-4, UNIT 8, 4/3/1988 4 12.0 IPERF 120 deg. phasing; 5 1/2' CSG Gun 2V-04 SBE, 8,940 7,327.0 7,335.0 5,891.0 5,898.0 A-4, 2V-04 4/3/1984 4.0 IPERF 90 deg. phasing; 21/8" TT 7,344.01 7,373.0 5,905.9 5,931.5 A -3, 2V -04 4/3/1984 4.0 IPERF 90 deg. phasing; 2 1/8" TT Notes: General &' Safety 1�'w. End Date Annotation PRODUCTION, 5/72010 INOTE: Confirmed Packer leak or behind pipe channel up from TTL to C-Sand w/WFL & PPROF 7,027 PRODUCTION, 7,095 PRODUCTION, 4 7,16 IPERF, 7,188 -7,240 SEAL ASSY, 7,277 PACKER, 7,279 C SBE,7,282 NIPPLE,7,302 i 505,7,308 Mandrel Details . Top Depth Top Port (TVD) 1691 OD Valve Latch Sion TRO Run IPERF, Stn Top(RKB) (ftKB) (1 Mak Model (in) 5ery Type Type (in) (p s i) Ron Dote Com... 7,327 -7,336 1 6,897.4 5,518.8 32.53 CAM KBUG 1 GAS LIFT DMY RK 0.000 0.0 1/3/1998 2 7,026.6 5,630.9 31.44 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4262010 IPERF, 3 7,094.7 5,688.1 30.54 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4262010 7,34x- 7,373 -1 4 7,164.1 5,747.6 29.62 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/26/2010 PRODUCTION, 37- 7,662 • rD, 7,67s Page 1 of 1 • • • Schwartz, Guy L (DOA) From: Wiese, Tyson M [ Tyson .M.Wiese ©conocophillips.com] Sent: Wednesday, October 31, 2012 3:44 PM To: Schwartz, Guy L (DOA) Subject: RE: 2V -04 Crystal seal. ( PTD 183 -165) Guy, The packer leak is at the lower packer, allowing a high volume of injection up through the packer leak and into the C -sands above. We would like to restrict/eliminate that flow to the C -sands and redirect that support to the A- sands. We are hoping that the swelling Crystal Seal product will help achieve the goal and allow for better A -sand support. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 CeI1:1- 907 - 230 -5388 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, October 31, 2012 11:34 AM To: Wiese, Tyson M Subject: [EXfERNAL]2V -04 Crystal seal. ( PTD 183 -165) Tyson, Can you elaborate on the packer leak that is mentioned in the sundry procedure. Upper or lower , etc. The well passed its last MIT —IA in 2008. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 10/31/2012 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~~ ~ j RE: Injection Profile /Water Flow Log: 2V-04 Run Date: 5/7/2010 May 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V-04 Digital Data in DLIS/LAS format, Digital Log file, Interpretation Report 50-029-21041-00 Water Flow Log 50-029-21041-00 Injection Profile Log 50-029-21041-00 1 CD Rom 1 Color Log 1 Color Log PLEASE ACKNOWLEDGE RECEII'T BY SIGNING. AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 Uy C rafael.barretc?all_ibu~tpn.com 4~, Date: _~ t; ` ~j ', ~3 ,~~5~ ,~~~~ Signed: _~,~ ~ ~^ ~ ~' g~"~~a moo. - ',_ °:~°1 ~~~~~~~ ~~~-- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ., - , - t~,, ~~r riF_, ;~ ~~; -~ Log Description ~/ NO. 5056 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /23/09 16-05 ANHY-0030 INJECTION PROFILE () 01/09/09 1 1 2L-325 ANHY-00031 LDL 01/10/09 1 1 3M-03A AZJZ-00011 SFRT - ~~ 01/11/09 1 1 2T-10 ANHY-00033 INJECTION PROFILE - - 01/11/09 1 1 2L-301 AZJZ-00013 USIT 01/12/09 1 1 2A-26 AZJZ-00010 SONIC SCANNER 01/15/09 1 1 2A-26 AZJZ-00010 SFRT Cj / 01/17/09 1 1 f 1R-18 ANHY-00039 INJECTION PROFILE (~ 01/19/09 1 _ ` 2V-04 ANHY-00040 INJECTION PROFILE 01!20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • l~ • • ConocoPhillips a~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission , A 333 West 7~' Avenue, Suite 100 ~ ~~~ ~ ~ ~~~~ /_ L Anchorage, AK 99501 ~ $ 'j " ~ (f~`'~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, Julyl0,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 1l~IElYI®~ZANI)~TM Ta~ Jim Regg j P.I. Supervisor ? ~'f ~ ~/l l?~~~ FROM: Jeff Jones Petroleum Inspector State of ~ilaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June l 1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2 V-04 KUPARUK RIV UNIT 2V-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv %~ Comm Well Name• KUPARUK RIV UNIT 2V-04 API Well Number s0-029-2 1 04 1-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ080610172548 Permit Number: 183-165-0 Inspection Date: 6~2~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zv-oa TYPe Inj. ~ I TVD ss3s IA o ~ z~3o z6ao z6zo ! ~ p.T i 1831650 TypeTest ' sPT I Test psi ~ Isoo pA izo ! Iao i tag j Iao I ~ 4YRTST P "'~ Tubin 3400 ~ 3400 ~ Interval P/F __ g i ~ I 3400 ! 3400 J Notes• 6.2 BBLS diesel pumped; two exception noted. The tubing adapter nuts are not fully engaged _ ____ _ on some of the bolts and the SSV is leaking ;/ hydraulic fluid; operator will initiate repairs. ~~. ~°`''`~~E~ JUL ~. ~ 2008 Wednesday, June 1 1, 2008 Page 1 of i RECEI\/ED 10/13/06 Scblulnbepgep OCT 1 6 2006 AIa!å()i1 & Gas (:kIm.. C~~W7 Änclmragf!J Schlumberger -DCS. ". " . ~'1t\iEP. 2525 Gambell Street, SUite 400 <;J¡ç,þ"t,·. . Anchorage, AK 99503-2838 ATTN: Beth (;) ". (;~i ...s US~ I ~3 -/05 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20106 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T -39 11296724 PROD PROFILE W/DEFT 09/20106 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE WID EFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10103/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10106/06 1 2V -08A 11216327 USIT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Kt111(13jr4 Email to:Tom_Maunder@admin.stateak.us;Bob_Fleckenstein@adminstate.ak.us; and Jim_Re69@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2V DATE: 06/28/04 OPERATOR REP: Sauvageau I Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2V-01 Type Inj S TV.D. 5778 Tubing 1500 1500 1500 1500 Interval 4 P.TD. 1831580 Type Test P Test psi 1500 Casing 1150 2200 2200 2200 P/F P Notes: Well 2V-02 Type Inj S TV.D. 5705 Tubing 2150 2150 2150 2150 Interval 4 P.TD. 1831610 Type Test P Test psi 1500 Casing 1150 2700 2660 2640 P/F P Notes: Well 2V-03 Type Inj S TV.D. 5689 Tubing 1150 1150 1150 1150 Interval 4 P.T.D. 1831640 Type Test P Test psi 1500 Casing 850 1920 1900 1900 P/F P Notes: Well 2V-04 Type Inj S TV.D. 5538 Tubing 950 950 950 950 Interval 4 P.T.D. 1831650 Type Test P Test psi 1500 Casing 150 1900 1890 1880 P/F P Notes: Well 2V-05 Type Inj S T.V.D. 5672 Tubing 2300 2300 2300 2300 Interval 4 P.TD. 1831760 Type Test P Test psi 1500 Casing 950 1750 1720 1710 P/F P Notes: Well 2V-06 Type Inj G T.V.D. 5636 Tubing 2550 2550 2550 2550 Interval 4 P.TD. 1831790 Type Test P Test psi 1500 Casing 900 1700 1690 1690 P/F P Notes: Well 2V-07 Type Inj S TV.D. 5692 Tubing 2500 2550 2550 2550 Interval 4 P.T.D. 1831800 Type Test P Test psi 1500 Casing 900 1750 1720 1710 P/F P Notes: Well 2V-08A Type Inj S TV.D. 5725 Tubing 2450 2450 2450 2450 Interval 4 P.T.D. 1840910 Type Test P Test psi 1500 Casing 1550 2980 2900 2880 P/F P Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test dunng Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2V 06-28-04.xls 7/13/2004 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3002 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1F-01 t ~'~l_°j. SILICON ACTIVATION LOG-RST 10101/03 2U-03 ~<~-C-~/~ STATIC SURVEY 10/02/03 2U-09 I~TD,~. " STATIC SURVEY 10102103 2V-04 I'~-i~--)l STATIC SURVEY 10102/03 10/21/03 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thar~:i~!~'~~:~I'I ~;;: :'ii,:';;:.'~ ,...: .............. ::.i~;!,~.' .~"'.i~.~,i~,J~ ;~ ._ ARCO Alaska, Inc. Date: ' December 8, 1988 Transmittal Ct: 7365 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 1G-01 ~3Q-02 ~3K-06 ~ 2V-04 ~ 2V-04 Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report I 2 - 0 5 - 8 8 Casing 1 1 - 2 9 - 8 8 Casing 1 I - 2 7 - 8 8 Casing 1 1 - 1 6 - 8 8 Sand 'A' 11-19-88 Sand 'A' Receipt Acknowledged- DIST .R. I~.UTION: D&M State of Alaska Chevron Mobil Unocal SAPC STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION CO,~,'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND I. OG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~] WAG INJECTOR 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 83-165 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21041 4. Location of well at surface 9. Unit or Lease Name 2253' FSL, 166' FEL, Sec. 7, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 3854' FSL, 3767' FEL, Sec. 7, TllN, R9E, UM 2V-4 At Total Depth 11. Field and Pool 3954' FSL, 3962' FEL, Sec. 7, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 114'I ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I16. No. of Completions 12/10/83 1 2/15/83 04/03/84*I N/A feet MSL] 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7675'MD, 6203'TVD 7571 'MD, 6109'TVD YES ~ NO []I 1832 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, RFT, GR/CBL/CCL, Gyro, CCL/GR/Temp, CET, Temp/Noise log, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SE'I-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 220 sx CS II 9-5/8" 36/47# J-55/L-80 Surf 3121' 12-1/4" 900 sx PF E & 250 sx ~F C 7" 26.0# J-55 Surf 7662' 8-1/2" 280 sx Class G & 250 ~x PFC 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf 3-1/2'' 7309' 6936' & 7279' 7188'-7240'MD 5769'-5814'TVD 26. ACID~ FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 90° phasing . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7327'-7335'MD 5891'-5898'TVD . 7394'-7396' 100 sx Class G 7344'-7373'MD 5906'-5931'TVD 7292'-7294' 100 sx Class G Leak (~ 4014' 200 sx Class G 6947'-6949' 7.5 ~X Class G 27. N/A PRODUCTION TEST See attached Addendum for fracture data. Date First Production I Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED 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 None °il' gas °r water' Submit c°re chip~~' ~/~I~I~ ~ · Note: Drilled RR 12/17/83. Perforated well & tubing run 4/3/84. Perforations added 5/8/84. Fractured well 6/1/84 & 8/13/84. Workovers performed 12/1/87 & 1/2/88. Form 10-407 Rev. 7-1-80 WC4/OZ :DAN I CONTINUED ON REVERSE SIDE Submit in duplicate ~ EO G M V'..", i ',-:i-' :-'!,"' · ~: :" RIVI~TI N TESTS G LO ~ ARKERS ' " ' ' --' . · :~ -: ' :'i - ' '~' · ' ~-- .. ~-. ¥ ' .. '. ;'~'~ .'~' ,~-" - , ~., " - ' - ', ,. ~ , :' · : ; . - ;. . . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. :..~ ~ ~ .':~-. Top Upper Sand ~-' 7187~ 5767~ RFT results attached to Well Completion ' Base Upper Sand 72/+0~ 581/+~ report dated Z~/19/8b,. Top Lower Sand 7309~ 5875 ~ Base Lower Sand 7/~68~ 6017~ · . . . 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~0~/~~ .~.~C~ Title Associate Engineer Date ~-~'i~ 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 1/06/84 1/97/84 1/08/84 5/08/84 6/02/84 6/03/84 - 6/06/84 6/11/84 ADDENDUM 7571 ' PBTD & Gyro Rem adaptor flange & vlv. Move f/2V-3. RU. RIH w/GR/CBL/CCL. Log f/PBTD- 3100'. POOH. RIH w/gyro to 7571'. POOH. 7571'PBTD Ops Susp Ck gyro @ 3000 '-3500' & was inconsist w/SS. Susp ope f/24 hr to ck gyro. Instl adaptor flange & vlv. 7571'PBTD Cc~pl Rem adaptor flange & vlv. Rn gyro to PBTD. Gyro showed 165', BHL was to left of SS. RD. Instl adaptor flange & vlv. Move equip to 2-F. CBL showed no cmt across sar~. 7571'PBTD Flowing Well for Perf Cln Up MIRU Gearhart WL units. NU WL BOP & tst to 3000 psi, ok. MU RU Perf Gun #1, NU ccmb. Lub & tst to 3000 psi, ok. RIH w/Gun #1-2-1/8" tornado link jts, 4 SPF @ 90© phasing. Rn into jnk in tbg @ +6555'. Chased out of tbg tail. Rn tie in & correl w/DIL/GR 12/16/83 & G~CBL 1/05/84, both"on same depth. Open well for flow, perf interv 7358'-7373' (15'). Flow well 5 min. RIH to ck PBTD, PU tension @ +7535'--& pulled tite, wkd free @ 7520'..Orig PBTD was 7556' WIM on GR/CBL.--POH. SITP 400, all shots fired ok. MU PU Gun #2-RIH SITP 500, tie in. Flow well 5 min. Perf interv 7344'-58' [14'). Gun did not fire. POH. SITP 500 psi. Ck & tst equip. MU PU Gun #2A-RIH. SITP 500, tie in, flow well 5 min. Perf interv 7344'-58' (14'). All shots fired, ok. SITP 500. No surf press noted during flow period. MU PU Gun ~3- RIH, tie in, flow well 5 min. Perf interv 7327'-35' (8'). Flow well 5 min. No flow press noted. POH. All shots fired ok. SITP 600 psi. RD Gearhart WL. NU tree cap & tst to 3000 psi, ok. SITP 600 psi. Open well & flow thru choke manif. Sep stock tk w/flare in vlv 1/2 to full open for perf 'd we~l clnup. Total fluid flowed 25 bbls in 4 hrs. FTP 0 psi, flow in temp 23-F begin, 26OF end. Est flow rate 150 BFPD. Cont to flow for clnup. 7563'PBTD Prep f/DataFrac Ops Trane & schedof personnel & equip. Plan to start spotting tks & rel equip @ well site 0700 hrs 6/02/84. 7563 ' PBTD Prep f/Data Frac Ope ~'~'~ Move BJ tks f/2-B pad to 2-V pad. 7563 ' PBTD · Gas C0~' i]l]!f~f!]$$iu%'~ RU to Data Frac ~.,~~ 24 hr SITP 850# psi. WO Ops/Prod to rel E in uni ~nc.~elled 700 bbl diesl. RU Camco. Tst lub 2700#. RIH w/CCL/GR/Temp. Correl w/Gearhart CBL 1/05/84. Rn CCL/Gem~ f/7470 '-7100'. POOH, rem GR. PU H~. RZH w/CCL/HP. Let HP st_~bil. RU BJ ins, W/~P WHT rec. Tst ins 5000#, ok. Ann 1500#, ok. (Cont. next pg. ) 2V-4 Cont. 6/12/84 7563 ' PBTD Prep to Rn CCL/Temp Log Tst BJ lns 5000#, ann 1500#. Bullhd 70 bbl diesl dwn tbg @ 2 BPM. 2650 psi, ISIP 18009 psi. Pmpd 125 bbl gel diesl @ 10 BPM, SD ~x~ps, ISIP 2010. Begin ~p in/flow bk. Pmpd 40 bbl gel diesl @ 10 BPM @ 2860 psi. ISIP 1640 ~bs. Flow bk 1/4 BPM f/3 min. Prop 40 bbl gel diesl @ 10 BPM @ 2940#, ISIP 1850# psi 1/4 BPM f/20 min, flow bk. Pmp 40 bbl gel diesl @ 10 BPM @ 2950# ISIP 18609 psi, flow bk 1/4 BPM f/20 min. Pmp 40 bbl gel diesl @ 10 BPM 2790# ISIP 2000# psi. Flow bk @ 1/4 BPM 14 min. Mini frac w/fluid loss & brkr 190 bbl gel @ 15 BPM @ 3020# psi, flush w/67 bbl gel diesl @ 15 BPM @ 2860# psi. ISIP 2000#. Job cc~pl @ 12:03 6/01/84. RD BJ. Rn CCL/Gemp log f/7500 '-7100 '. RIH to 7500 '. BH press bldup. Rn CCL/G~p logs f/7500 '-7100 '. RIH to 7500'. BH press bldup. 6/13/84 8/13/84 7563 'PBTD Ops Susp Rn CCL/T~zp log f/7500 '-7100'. BHP t~p bldup. POOH. RD Camco. RU to flow tst well. Open up well on 28/64 choke SITP 950# psi. Flowed 30 bbl in 30 min @ 4009 W/4P. Pinch choke to 02/64. Flow 164 bbl. SI well. Prep 7563'PBTD MIRU Camco. Raise BOP's & lub. Tst ea @ 2500 psi, ok. Rn pre frac t~mp log f/7450'-6990'. POOH. RD Camco.. RU Dowell. Tst lns@ 5300 psi, ok. Press 3-1/2"~ x 7" ann to 1500-Psi. Dowell ~ 155 bbl gel wtr w/900# 100 mesh SN & i'2~;~700# 12/20 SN @ air 12 BPM @ 2650 psi. Displ w/36 bbl gel diesl & scrned out @ 5000 psi. Left 29 bbl 7 ppg SN in tbg w/23 bbl 7 ppg SN in form. Frac grad calc 0.71. Press bled to 4000 psi in 15 min. RD Dowell. Turn well over to Prod, WO plan to clnout. 8/16/84 7563 ' PBTD Ops Susp MIRU Otis slickln pickup 2.45 gauge ring, tst lub 3500. Trip in tag fill @ 6170' (sand). RU to flow, no flow. 8/17/84 7553'PBTD Flowir~ Well M~ve Nowsco CTU on loc & RU for sand clr~ut. Press tst BOP's to 3000 psi, ok. Start in hole @ 1/4 bbl diesl per min to 5000' w/2.25 clnout tool. Start gel diesl w/rate of 1 bbl per min. Start sand wsh @ 6150' w/rate of 1 bbl gel diesl per min. Pull tbg up to 5000' & stop wshg. Start dwn hole f/5000', wshg @ 1 BPM w/heavier gel diesl, tag sand @ 6170'. SI well. 8/19/84 7563 ' PBTD Rel to Prod. MI RU Baker WL unit pickup 2.625 bullnosed gauge ring. Tst lub to 2500 psi, ok. Trip in stopped @ SBR, trip out, flow well. Trip bk in, wk tools f/ 6950'-7400'. Trip out, wkd tools bk up to 6820'. Trip out, RD Baker. Note* Ann 7:' x 3-1/2" hard to bleed dwn, tstd to 1500 psi. Prep to 1000 psi in 15 min @ end of 30 min, tst still 1000 psi (gas). STATE OF ALASKA '-'-': ALAS, , OIL AND GAS CONSERVATION COMI., ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Alter Casing ~ Other Stimulate ~ Plugging ~ Perforate C Pull tubing WORK0VER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 114' Feet 3. Adpd.re.SSBox 100360, Anchorage, AK 99510-0360 6. U. nit or .Pro~@erty name r~uparuK r~ver Unit 4. Location of well at surface 2253' FSL, 166' FEL, Sec. 7, T11N, R9E, UM At top of productive interval 3854' FSL, 3767' FEL, Sec. 7, T11N, R9E, UM At effective depth 3933' FSL, 3923' FEL, Sec. 7, T11N, R9E, UM At total depth 3954' FSL, 3962' FEL, Sec. 7~ T11N~ R9E~ UM 11. Present well condition summary Total depth: measured 7675 'MD true vertical 6203 'TVD 7. Well number 2V-4 8. Approval number 7-879 9. APl number 50-- 029-21041 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 7571 'MD feet Junk (measured) true vertical 6109 'TVD feet Fill ~ 7413' Casing Length Size Cemented Conductor 80' 16" 220 sx CS II Surface 3085' 9-5/8" 900 sx PF E & 250 s× PFC Production 7625' 7" 280 sx Class C & 250 sx PFC Measured depth ll0'MD 3121'MD 7662'MD True Vertical depth 110'TVD 2668 ' TVD 6191 'TVD Perforation depth: measured 7188'-7240' 7327'-7335' 7344'-7373' true vertical 5769'-5814', 5891 '-5898', 5906'-5931 ' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7309' Packers and SSSV (type and measured depth) FR-1 nl~r~ ~ ¢,cIR¢-,, ,t, 7979'. Tpnp-!A $$$V ~ 183:2' 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) Leak (~ 4014 ', 6947 ' -6949 ' Treatment description including volumes used and final pressure 200 sx Class G~ 75 sx Class G N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Workover Well History, Daily Report of Well Operations w/Addendum, dated 12/30/87) Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/37 Date Submit in Duplicate~¢~ '."..' ...... '.' ~UPV:JE 11/~/e7 TD: 7675 PB: 7571 SUPV: JE 11/26/87 ( TD: 7675 ?B: 7571 SUPV:DJ 11/27/87 ( TD: 7675 PB: 7571 SUPV:DJ 11/28/87 ( TD: 7675 PB: 7571 SUPV:DJ .. -r a well Is spudded or worl(ovar °pe~a~;on~ ere inclusive dates only. .,- SLOPE NOIq~;~R ~!'!':! ;~:';? "~.:':*.;~=~,"J:~"' ~Z: ' 50-029-21041 - ' ' " . ~.~ :.. ;,; '-', ,,,., , .. . ,. . :... .... ... .-.::~,. , ...... · .. ~ J~.~":~!~'.. ~: ~,,, :'.' · . ~: L".% :' :~.~:~, ] , ', ...... · ........ ¥" .¥ ~n?':?_.~4..' -:~' ~ ',~ :' .;: ' ~,..::~ .,~%~ ....~ ; .. ., ,.. . . . ..~:,.~:~. .....:.: .. ~.:,. ~ .... ,.M ~ .,.'. . · . .., . ,:~%:,. - .. . ~ ..~ .....,, ,;. .... . " . POOH· N~TH 3 1/2 =BZ~G ~:10~~T*''· %..:' [:,.... '. PU TO 10.3 PPG. POOH WITH 3-1/2" TBG. C~GE SE~ RINGS. . DAILY:S41,399 CUM: $98,064 ETD: $98,064 EFC:$424,000 POOH WITH R3 PACKER MW:10.3 NaCl/NaBr POOH WITH COMPLETION STRING. STAND BACK 3=1/2" TUBING. RIH AND CIRCULATE @ 6986'. TESTED PACKER OK. FOUND 7" CASING LEAK BETWEEN 4019'-4021'. POOH SLM. MONITOR WELL FOR GAS/OIL FLOW. DAILY:S38,500 CUM:$136,564 ETD:S136,564 EFC:$424,000 POH MW:10.6 NaCl/NaBr POH-WELL KICKED. WT UP BRINE TO 10.5 PPG. TIH TO 6985', CIRC. ATTEMPTED TO POH, WELL FLOWED. WEIGHT BRINE TO 10.6 PPG. CIRC. KILL-WT BRINE, POH. DAILY:$41,2~O CUM:$177,834 ETD:S177,834 EFC:$424,000 HOLDING PRESSURE ON SQUEE MW:10.6 NaCl/NaBr FINISHED POH. TIH W/RETRIEVABLE BP AND SET @ 4076' TESTED CASING TO CONFIRM LEAK. CBU. SPOTTED SAND ON TOP OF Bp (CALC. TOP OF SAND @ 4050'). SLIP & CUT DRLG LINE. FINISHED TOH. RIH W/CHAMP PKR TO 4025'. TEST AND ISOLATED LEAK @ 4014'. RUN CCL/GR INSIDE DP. CIRC. OUT GAS. PULLED 5 STDS AND SET PKR @ 3622'. ESTABLISHED INJ. RATE AND SQUEEZED 50 SX CLASS G CMT. BLED ANN..AND DP, UNSEAT PKR. PRESSURED UP DP TO 400 PSI AND CASING TO 200 PSI. WOC. DAILY:S56,690 CUM:$234,524 ETD:S234,524 EFC:$424,000 DRILLING CMT MW:10.6 NaCl/NaBr WOC. RELEASED PRESSURE. UNSEAT PKR. CBU. POH. LD CHAMP PKR. TIH AND TAGGED CMT STRINGER @ 3763' WASHED AND REAMED TO 3931' CIRC. AND RECIP. WASHED AND REAMED SOFT CMT TO 4044'. DAILY:S42,300 CUM:$276,824 ETD:S276,824 EFC:$424,000 The above is correc; For form preparation ar~ di,tributlon, 8ee Procedure~ Manualg~ectlon 10, Drillbtg, :P~ 86 and Data ITitle Associate Engineer ~tlanticRichfieldCompany Dai,y Well History-Interim Illetl~lcll~lla: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pedorrned. Number all drill stem tests sequentially. Attach descriDtion of all cores. Work performed by Producing Section will be reported on "Interim' sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. ICounty or Parish JStal~K NORTH S~.OPE Lease or Unit ~Well no. ADL: 25644 2V-4 I KUPARUK RIVER UNIT Date and depttt as of 8:0~ a.m. 11/29/87 ( TD: 7675 PB: 7571 SUPV:DJ 11/30/87 ( TD~ 7675 PB: 7571 SUPV:DJ 12/01/87 ( TD: 7675 PB: 7571 SUPV:DJ/JE Complete record for each day while drilling or workover in progress NORDIC I CIRC. WELL ON CHOKE MW:12.0 NaBr CIRC. OUT CMT CUTTINGS. TESTED CSG TO 800 PSI - OK. DRILLED SOFT CMT TO 4066'. POH, TOOK KICK, CIRC, RAISED BRINE WT TO 10.7 PPG. TIH, CIRC. ON CHOKE, RAISED BRINE WT PPG. CIRC WELL ON CHOKE. DAILY:S25,800 CUM:$302,624 ETD:S302,624 EFC:$424,000 TIH WITH BHA MW:12.0 NaBr FINISHED KILLING WELL. POH. TIH, CBU. SPOTTED 150 SX CLASS G BALANCED PLUG. PRESSURED UP ON SQUEEZE. WOC. POH. RIH WITH BHA. DAILY:S162,246 CUM:$464,870 ETD:S464,870 EFC:$424,000 NU MCEVOY TREE MW:12.0 NaBr FINISHED RIH. CIRC., POH AND LD EXCESS DP. RIH, CIRC. & WOC. RIH & DRILLED SOFT CMT TO 3340' & FIRM CMT TO 3359'. CBU. TESTED CSG TO 500 PSI-OK. LD DP. RIH W/3-1/2" KILL STRING. LANDED TUBING, SET BPV, LD LANDING JT. ND BOPE. NU TREE. (BOTTOM OF KILL STRING @ 3326.95') DAILY:S30,470 CUM:$495,340 ETD:S495,340 EFC:$424,000 The above is correct Signature For form preparation and ,~strib~Jtion see Procedures Manual F~¥:tion 10, Drilling, Pages 86 and 87~' IDate ITitle Associate Engineer and Gas Company Daily We,I History-Final Report Inst~i,~tiollt: Prepare and submit the "Final R~,~t" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold. "Fl.aI.R~rt" 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. I Accountlng coat center code District I StatL /~CO Alaska, Inc. Field ICounty or Parish - NORTH SLOPE Lease or Unit Title ~DL: 25644 R~I: 50-029-21041 2V-4 IWell no. Auth. or W.O. no, IA.R.Co. W.I. 56.0000 Date 11/23/87 COmplete re~ord for each day reported RELEAS~ RIG Iotal number of wells (aCtive or Inactive) on thl~, cst center prior to plugging and / bandonment of this well our . IPrlor ~t~ul If · W.O, 1215 I MW: 12.0 FINISmaD NU MCEVOY, 5000 PSI TREE AND TESTED TO 3500 FREEZE PROTECT WITH 9 BBLS DIESEL. SITP-0 PS.I. SET BEV. SECURED WELL AND RELEASED RIG @ 0930 HRS, DAILY:S7,000 CUM: $502,340 ETD:S502, 340 EEC; $424,000 Old TD New TD Released rig Date PB Depth Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) 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 date corrected The above is correct For form preparation and distJ~ution, see Procedures Manual, Sectr~n 10, Drilling, Pages 86 and 87. Date [Title Associate Engineer ADDENDUM WELL' 2V-4 8/13/84 MIRU Camco. Raise BOPs and lubricator. Test each at 2500 psi. Ran pre-frac temp log f/7450'-6990'. POOH. RD Camco. RU Dowell. Safety meeting. Tested lines at 5300 psi, ok. Pressure 3-1/2" x 7" annulus to 1500 psi. Displaced w/36 bbls gelled diesel and screened out at 5000 psi. (Left 29 bbls 7 ppg SN in tubing w/23 bbls 7 ppg SN in formation). Frac gradient 0.71. Pressure bled to 4000~psi in 15 min. RD Dowell. Turned well over to Production. Wait on plan to cleanout. D ri.~n9 Supe~or G [Yate / ' ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday afte~ a well is spudded or workover operations ara started. Daily work prior to sPudding should be summarized on the form giving Inclusive dates only. District ]County, parish or borough ARCO Alaska, Inc. I NORTH SLOPE Field ILeal, or Unit KOPARUK RIVER UNIT I ADL: 25644 Auth. or W.O, no. ITitle I WORKOVER API: 50-029-21041 Operator 2V-4 ~Nell no. ARCO Spudded or W.O. begun IDate IHour ACCEPT J 12/16/87 ]1800 HRS Dste and depth as of 8:00 a.m. 12/16/87 ( 1] TD: 7675 PB: 3359 SUPV:SS/DJ 12/17/87 TD: 7675 PB: 3359 SUPV:HE/JE 12/18/87 TD: 7675 PB: 3359 SUPV:HE/JE 12/19/87 ( 14 TD: 7675 PB: 7413 FIL! SUPV:HE/JE 12/20/87 ( 15 TD: 7675 PB: 7413 FILI SUPV:HE/JE 12/21/87 ( 1( TD: 7675 PB: 7413 FILI SUPV:HE/JE 12/22/87 ( 17 TD: 7675 PB: 7413 FILL SUPV:HE/JE The above is correct For form preparat~n and distribution, see Procedures Iv[;~nual,_Section 10, 'Complete record for each day reported NORDIC I tARCO W.I. 56.0000 Prior status if a w.o. MOVING RIG TO LOCATION MOVING RIG FROM 3H PAD TO 2V PAD. MW:12.0 NaBr DAILY:SO CUM:$502,340 ETD:S502,340 EFC:$424,000 LOADING PIPE SHED WITH DP MW:12.0 NaBr MOVE RIG FROM 3H PAD TO 2V PAD. ACCEPT RIG @ 1800 HRS 12/16/87. NU BOPE. POOH WITH 3-1/2" TUBING. LOAD PIPE SHED WITH 3 1/2' DRILL PIPE. DAILY:S54,370 CUM:$556,710 DRILLING CMT @ 3965' DRILL CEMENT FROM 3359'- 3965'. DAILY:S32,710 CUM:$589,420 ETD:S556,710 EFC:$424,000 MW:12.0 NaBr ETD:S589,420 EFC:$424,000 RIH W/RBP ON 3-1/2" DP MW:12.0 NaBr DRILLED CLV~ F/3965'-4048'. TAGGED SAND & WASHED TO 4059'. POH. MU OVERSHOT ASSY. RIH. WASHED SAND F/4052'-4074'. UNABLE TO WASH TO RBP @ 4076'. SUSPECT THAT RBP UNSET, CBU, POH, LD RBP & OVERSHOT. RU RBP & RIH. DAILY:S51,178 CUM:$640,598 ETD:$640,598 EFC:$424,000 RIH W/CET LOG MW:11.3 NaBr/NaCl RIH W/RBP ON 3-1/2# DP. SET @ 6985'. CIRC. FILTER BRINE, MIX 11.3 PPG BRINE. CIRC. HOLE W/11.3 PPG. POH. RU SCHLUMBERGER. RU LUB. RIH W/CET LOG. DAILY:S36,594 CUM:$677,192 ETD:S677,192 EFC:$424,000 RIH W/3-1/2" TUBING MW:11.3 NaBr/NaCl RUN CET/TEMP/NOISE LOGS. IDENTIFY CHANNEL. RIH & PULLED RBP @ 6985'. CIRC. POH. NO RBP. RIH & FOUND RBP @ 120'. POH & LD RBP. RU & RUN BAKER 'PBR' SEAL ASSY & 3-1/2', 9.3~, J-55, EUE, 8RD, AB-MOD TUBING. (NOT INTERNALLY COATED) DAILY:S59,425 CUM:$736,617 ETD:S736,617 EFC:$424,000 INJ. SEAWATER INTO 'C' SAND MW: 8.5 SEAWATER FINISHED RIH W/222 JTS 3-1/2#, 9.3~, J-55, EUE, 8RD, AB-MOD TUBING W/TAIL @ 7301', BAKER 'FHL' RET PKR @ 7013', BAKER 'FB-I' PERM. PKR @ 7271'. TESTED TUBING TO 2000 PSI-OK. PU OUT OF 'PBR'. CIRC. 11.3 PPG FOLLOWED WITH 60 BBLS 10.0 PPG BRINE. LOCATED IN 'PBR'. SET SLIPS, CLOSED PIPE RAMS. RU WL. RIH & PULL 3 DV'S ACROSS 'C' SAND. RU HARDLINE TO SEAWATER SOURCE & INJECT SEAWATER IN 2V-4 'C' SAND. STARTED 12/21/07 .... ~5 ~. I Data I Title /45-~ Associate Engineer 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 Iormalion name in describing work pedormed. Number ell drill stem tests sequentially. Attach description of ell cores. Work performed by Producing Secfion will be reported on "lnfarlm" sheets until final completion. Report official or representative teat on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently Ihan 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 strln0 unlll completion. District ~County or Parish Stat ARCO Alaska, Inc. I NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25644 2V-4 Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress NORDIC 1 BPM, 1400 PSI. TOTAL AWAY=2153 BBLS. no. 12/23/87 ( 1 ) TD: 7675 PB: 7413 FIL SUPV:HE/JE 12/24/87 ( 1 TD: 7675 PB: 7413 FI SUPV:DJ/ML 12/25/87 ( 2 ) TD: 7675 PB: 7413 SUPV:DJ/ML 12/26/87 (2[) TD: 7675 PB: 7413 SUPV:DJ/ML 12/27/87 ( 2 TD: 7675 PB: 7413 SUPV:DJ/ML 12/28/87 ( 2: TD: 7675 PB: 7413 FI] SUPV:DJ/ML DAILY:S41,174 CUM:$777,791 ETD:S777,791 EFC:$424,000 INJ. SEAWATER INTO 'C' SAND MW: 8.5 SEAWATER INJECTING SEAWATER INTO 'C' SAND PERFS 7188'-7240' (12 SPF). TOTAL VOLUMN AWAY = 7411BBLS. DAILY:S26,300 CUM:$804,091 ETD:S804,091 EFC:$424,000 POOH WITH WL MW:10.0 NaCl/NaBr CONTINUED INJECTING FILTERED SEAWATER INTO 'C' SAND @ 1450 PSI, 3.4 BPM. 10,000 BBLS SEAWATER INJECTED. SWITCHED TO 10.0 PPG NaCl/NaBr BRINE & INJECTED 1000 BBLS OF SAME. RU OTIS WL UNIT AND SET DUMMIES IN GLV'S @ 7059', 7129', & 7262'MD. POOH. DAILY:S25,300 CUM:$829,391 ETD:SS29,391 EFC:$424,000 RUNNING TIE-IN LOG MW:10.0 NaCl/NaBr SET DUMMY IN GLM @ 7262'. POOH. TEST TBG TO 2000 PSI. STING OUT OF PBR. REVERSE CIRC HOLE TO 11.3 BRINE. SET RBP @ 6977'. SPOT 50 BBL SAND ON TOP RBP. PRESSURE TEST LUBRICATOR TO 2000 PSI. RIH WITH TIE-IN LOG. DAILY:S35,254 CUM:$864,645 ETD:S8,646,645 EFC:$-7,358,000 TIH WITH BIT AND SCRAPPER MW:ll.3 NaCl/NaBr PERFORATE 7" CASING @ 6947'-6949'. RIH TAG SAND @ 6920'. SPOT 75 SX CLASS G 15.8 PPG CEMENT BALANCED PLUG. SQUEEZE AWAY 10 BBL. HOLD 1000 PSI FOR 4 HRS. BLEED PRESSURE. POOH. LD PKR. RIH WITH BIT AND SCRAPPER. DAILY:$55,386 CUM:$920,031 ETD:S920,031 EFC:$424,000 RIH WITH BIT AND SCRAPPER MW:11.3 NaCl/NaBr TAG CEMENT @ 6844'. DRILL CMT TO 6958'. CBU. SET PKR @ 4062'. TEST CASING BELOW PKR TO 1600 PSI FOR 30 MIN. PULL ONE STAND. DISPLACE DP TO PKR WITH 9.9 PPG BRINE. SET PKR @ 3990'. OPEN DP. NO FLOW IN 30 MIN. REV OUT DP WITH 11.3 BRINE. RIH WITH BIT AND SCRAPPER. DAILY:S36,616 CUM:$956,647 ETD:S956,647 EFC:$424,000 RIH WITH CHEMICAL CUTTER MW:10.0 NaCl/NaBr WASH SAND OFF RBP. CIRCULATE. DISPLACE TO 10.0 PPG BRINE. FISH OUT RBP. RIH WITH CHEMICAL CUTTER. DAILY:S34,770 CUM:$991,417 ETD:$991,417 EFC:$424,000 The above is correct For lorrn prepara~6 and distribution - see Procedures ~,~anual Section 10, Drilling, Pages 8~' and 87 IDate f -I~"-~ JTille Associate Eh§inset ARCO Oil and Gas Company Daily Well History--Interim Instructions: Th s form is used during drilling or wo.rk.o, ver operations. If test ng, coring, or ped. or.ating_, s.h.ow fo.r..m.atlon name In descrlbln~ work performed. Number all drill stem tests sequentially. Attach descr .pt!on of all cores. Work perfo.rmed by Pronuclng ~ectlon will ne reported on "Interim' sheets until final corn etlon Re ort official or represe.ntative test o.n ~'~.lna.!" fo .r~n.. 1.) Subm. it "lnten.m:' .s. hee. ts whe.n filled .o. ut.b, ut not !.ess fre.qu.e, ntly than every 30 days, or (2) on ~dnes~lay oPf the week in which oil string is set. ~uoml! weekly ~'or worKovers eno lOllOwlng setting ot ou slrlng until completion. District Field ARCO Alaska, Inc. KUPARUK RIVER UNIT County or Parish NORTH SLOPE Lease or Unit 2V-4 Date and depth as of 8:00 a.m. 12/29/87 ( 2 TD: 7675 PB: 7413 FIL SUPV:DJ/ML 12/30/87 ( 2 TD: 7675 PB: 7413 FIL SUPV:DJ/ML 12/31/87 ( 2 TD: 7675 PB: 7413 FILl SUPV:HE/SC 01/01/88 ( 2' TD: 7675 PB:7413 FILL SUPV:HE/SC 01/02/88 ( 2~ TD: 7675 ?B: 3359 SUPV:HE/SC Complete record for each day while drilling or workover in progress NORDIC 1 FISHING MW:10.0 NaCl/NaBr CUT TUBING @ 7150'. LOST RETURNS. RIH. LATCH PBR. WORK PBR FREE. PUMP AND SQUEEZE HEC PILL. CBU. POOH. RECOVER 144.97' OF FISH. MU OVERSHOT. RIH ON 3-1/2" TUBING. DAILY:S44,193 CUM:$1,035,610 ETD:S1,035,610 EFC:$424,000 MU COMPLETION ASSEMBLY MW:10.0 NaCl/NaBr FINISH TIH. TAG AND LATCH FISH. WORK FREE. POOH. RECOVERED FISH IN TOTAL. LD SAME. RU LOGGERS. RUN CET FROM 7260' TO 6000'. RUN TEMP LOG FROM 3250' TO 7260'. RUN NOISE LOG FROM 7260' TO 3900'. POOH. RD LOGGERS. START RUNNING COMPLETION ASSEMBLY. DAILY:S27,300 CUM:$1,062,910 ETD:S1,062,910 EFC:$424,000 RIH WITH CASING PATCH MW:10.0 NaCl/NaBr MU BAKER SEAL/LOCATORASSEMBLYAND JEWELRY AND BAKER FB-1 PERMENANT PACKER. RIH WITH SAME ON 3-1/2" DP. SET PAKER @ 6920' DPM. POOH. MU 6-1/8" SWEDGE. RIH ON DP TO 4106'. POOH. MU 7" CASING PATCH. RIH ON DP. FB-1PKR @ 6935' & 7278', TAIL @ 7308' (WIRELINE MEASUREMENTS). DAILY:S84,832 CUM:$1,147,742 ETD:S1,147,742 EFC:$424,000 RU TO RIH W/ 3-1/2" DP MW:10.0 NaCl/NaBr FIN RIH W/ 20' HOWCO CSG PATCH. RU WL. RUN GR/CCL F/ 3990' TO 3100'. CORRELATED W/ CBL DATED 1/5/84 AND GR/CCL DATED 11/26/87. POSITION MIDDLE OF PATCH AT 4020' WLM. SET PATCH FROM 4010' TO 4030' WLM. POOH AND LD 3-1/2" DP AND SETTING TOOL. RIH W/ 8 STD 2-1/8" TBG. LD SAME. RIH W/ 56 STDS OF 3-1/2" TBG. LD SAME. RD TBG EQUIPMENT. RU TO LD 3-1/2" TBG. DAILY:S35,250 CUM:$1,182,992 ETD:S1,182,992 EFC:$424,000 ND BOPE STACK MW:10.0 NaCl/NaBr FIN LD 3-1/2" DP. ATTEMPT TO PULL WEAR BUSHING - WON'T LATCH. TEST 7" CSG (HOWCO PATCH) TO 1700 PSI. OK. ND BOPE STACK. PULL WEAR BUSHING (DAMAGED "J" SLOT). NU BOPE AND TEST TO 3000 PSI. STRAP/CLEAN TBG. RU AND RUN 3-1/2" 9.5~, J55 EUE 8RD AB MOD IPC TBG COMPLETION. MU SSSV, TEST CONTROL LINE TO 5000 PSI. FIN RUN TBG. LOCATE IN FB-1 PKR. SPACE OUT. PU HANGER. LAND TBG. TEST TBG TO 2500 PSI. OK. TEST ANNULUS TO 1750 PSI. OK. TEST SSSV. OK. SET BPV. ND BOPE STACK. (SSSV @ 1832', FB-1PKRS @ 6936', 7279', & TAIL @ 7309'. DAILY:S91,180 CUM:$1,274,172 ETD:S1,274,172 EFC:$424,000 IWell no. The above is correct IDate Signature (~ ~./~ .,' ~/~1~ For form preparation and dis~bution - - -- see Procedures Manual Sec~,~n 10, Drilling, Pages 86 and 87 Associate Engineer 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 nol 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 ARCO Alaska, Inc. ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 25644 WORKOVE R IAccounting Sla~ cost center code Field KUPARUK RIVER UNIT 2V-4 J Well no. Auth. or W.O. no. Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. Old TD Released rig API: 50-029-21041 IA.R.Co. W.I. 56.0000 IDate 12/26/87 01/03/88 ( 29 TD: 7675 PB: 7413 SUPV:HE/SC Complete record for each day reported NORDIC 1 I otal number of wells (active or inactive) on this ost center prior to plugging end bandonment of this well our J Prior stelus If a W.O. I 1800 HRS Classifications (oil, gas, etc.) Producing method Potential test data RIG RELEASED MW:6.9 DIESEL ND BOPE STACK. MU MCEVOY 3-1/2" 5000 PSI TREE. TEST SAME. OK. DISPLACE W/ DIESEL. SITP = O. SICP = O. TEST TBG TO 1000 PSI. CV - OK. BLEED TBG PRESSURE. SET BPV. SECURE WELL. RIG RELEASED AT 1330 HRS, 1/2/88. DAILY:S22,123 CUM:$1,296,295 ETD:S1,296,295 EFC:$424,000 New TD Date JPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) 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 di~libution, see Procedures Manual, Se;l~on 10, Drilling, Pages 86 and 87. IDate . ITitle /-/5-~ Associate Engineer Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1988 Transmittal # 7056 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~"~~ Cement Evaluation Log 12-29-87 5987-7253 ~ '"~3H-6 Cement Bond Log 11-27-87 5300-7866 ~-°3H-7 Cement Bond Log 11-28-87 6000-8516 -.0 ~-~3H-5 Cement Bond Log 11-25-87 4900-7020 ~3H-8 Cement Bond Log 12-3-87 4600-6756' ~'~'~3H-10 Cement Bond Log 12-9-87 5128-6633 ~ ~3H-1 Cement Bond Log 12-3-87 5700-7978 ~'~ x'~'3H-2 Cement Bond Log 11-23-87 6100-8184 '~ ~'~3H-4 Pulse Echo Log 11-25-87 5600-7986 "~ ~'~3H-9 Cement Bond Log 12-8-87 5550-7162 ~-~'~ 3H-3 Pulse Echo Log 11-26-87 4400-9354 Receipt Acknowledged: DISTRIBUTION: Date: Alaska Oil & Gas Con~. Anchorage NSK Drilling State of Alaska(+sepia) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Completion -- Workover Log- Daily ARCO Alaska, Inc. ~-_ Post Offic,~- '00360 Anchorage, .-.,a~ka 99510-0360 Telephone 907 276 1215 Date: December 31, 1987 Transmittal # 7054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2V-4 Cement Evaluation Log 12-20-87 2893-6981 HAPPY NEW YEARS Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska (+sepia) ska & Sas Cons. C0mmissi0~ 0il Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc~;...--~--_ Post Offic, .)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 25, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7019 Transmitted herewith are-the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2X-15 Kuparuk Well Pressure Report(Otis) 10-1-87 2V-4 Kupaurk Well Pressure Report(Otis) 11-16-87 2X-13 Kuparuk Well Pressure Report(Otis) 10-1-87 2X-16 Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand 'C' Sand PBU 'A' Sand PBU 'A' Sand n~',~'~.~,~'.~ ..... -;~0~~-'~E' Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA "-'~ t.. AL,,_,KA OIL AND GAS CONSERVATION CO,,,,dlSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well m Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing .~,.Amend order ~ Perforate C Otherx 2. Name of Operator ARCO Alaska, lnc 3. Address P. 0. Box 100:360 Anchorage, AK 99510-0:360 4. Location of well at surface 225:3' FSL, 166' FEL, Sec. 7, T11N, R9E, UM At top of productive interval :3854' FSL, :3767' FEL, Sec. 7, TllN, R9E, UM At effective depth 393:3' FSL, 392:3' FEL, Sec. 7, T11N, R9E, UM At total depth :3954' FSL, :3962' FEL, Sec. 7, T11N, R9E, UM 11. Present well condition summary Total depth: measured true vertical 7675 'MD feet 620:3 ' TVD feet Effective depth: measured 7571 'MD feet true vertical feet 6109 'TVD Casing Length Size Conductor 80 ' 1 6" Surface 3085 ' 9-5/8" Production 7625' 7" Plugs (measured) Junk (measured) Cemented 220 sx CS Ii 900 sx PF E & 250 sx PFC 280 sx Class G & 250 sx PFC 5. Datum elevation (DF or KB) RKB 114' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2V-4 8. Permit number 83 - 1 65 9. APl number 50-- 0~-21gbrl 10. Pool Kuparuk River Oil Pool None ~'~~~ O~-, No.e pt ~.'~&-~ ~'~ r Measured depth True Vertical depth 110 'MD 110 'TVD :31 21 'MD 2668'TVD 7662'MD 6191 'TVD Perforation depth: measured 7188'-7240', 7:327'-7335' true vertical 5769'-5814', 5891 '-5898' Tubing (size, grade and measured depth) :3-1/2", 9.3#, J-55, 8rd, AB-Mod tubing w/tail @ 7:308' Packers and SSSV (type and measured depth) Baker FB-1 pkr (~ 7278', Baker BHL pkr (~ 7020'; Camco , 5906'-59:31' [~()V ./_ 2 Alas~ Oil & Gas Cons. commi~lor~ ~chorago TRDP-1A SSSV ~ 1907' 12.Attachments Description summaw of proposal..,~ Anticipated bottomhole pressure 2900 13. Estimated dateforcommencing operation November 15, 1987 Detailed operations program workov BOP sketch 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 '/,~' ~,Oq.~l ,.- O/~/..~,q_..)L../ Title Associate Enqi near Date JI¢iZ-~7 Commission Use Only (JG) SA:3/1:3 approval Notify commission so representative may witness I Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceI /-- ~/7/ i_ :..! -::; - ~ · · -' "~L _ '~P'----. / _./ Approved by ~/, (/V/. Commissioner Form 10-403 Rev 12-1-85 by order of , | the commission Date II/IZ;/~" J Submit in triplicate 2V-4 Preliminary Workover Procedure ~ye-Rig Operations 1. MIRU slickline unit, set blanking plug in "D" nipple. Test tubing 2000 psi. 2. Pull dummy valve from GLM @ 6960'. Set dummy valves in all other GLM's. 3. RD slickline unit. 4. Load tubing and annulus with diesel. 5. RU E-line unit. 6. Cut tubing below retrievable packer and above blast rings. RD E-line. 7. Set BPV. Rig Operations 1. MIRU workover rig. 2. Pull BPV. 3. Circulate kill weight fluid down tubing taking returns through the annulus. 4. Set BPV. 5. ND tree. NU and test BOPE. 6. Pull tubing string. 7. RIH with drill pipe and packer retrieving tool. 8. Latch onto packer and release same. CBU. Monitor fluid loss. Pump pill if fluid loss is excessive. 9. POOH. LD packer. 10. RIH and retrieve FL4S tubing with blast rings. 11. Make clean out run to top of permanent packer. Filter brine clean. oo. . -. .~ ,... -, · ,., ~s~ Oil & 6as Cons. Anchomge 12. RIH with retrievable bridgeplug, set above 'C' sand perfs. Test casing to 3500 psi. Pull retrievable bridge plug. 13. Re-run completion assembly with GLM's, steel blast joints, packer, and SSSV. 14. ND BOPE. NU tree and test. 15. Displace well to diesel. 16. Set BPV. Secure well. 17. Release workover rig. 2VPAD/2V-4d ih ANNULAR PREVENTER PIPE RAI'IS 4 BLIND RAFIS 5 TUBING HEAD 2 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PS1 STARTING HEAD $, 11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS S. 7-1/t6" - 5000 PSI BLIND RAMS 6. 7-1/16" - $000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 , CHECK AND FILL ACCUMULATOP RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 4S SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1, FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI 'AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11. TEST STANDPIPE VALVES TO 3000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14, PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. JO JULY 28, 1986 (NORDIC RIO 9-$/8") ARCO Alaska, Inc. Post Office B, ~0360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 January 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed on the 2V-1 Convers 2V-4 Convers 2V-5 Convers 2V-6 Convers 2V-8 Convers 3B-2 .- Convers 3B-5 Convers 3B-10 Convers 3B-16' Convers 3C-2 Convers 3C-5 Convers 3C-7 Con~ers 3C-12 Convers on 12/18/85 on 12/19/85 on 12/19/85 on 12/19/85 on 1 2/1 8/85 on 1 2/29/85 on 12/29/85 on 12/29/85 'on 12/29/85 on 12/30/85 'on 12/30/85 'on 12/30/85 'on 12/30/85 If you have any quest ions, please cai I · J. M. Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) me at 263-4212. RECEIVED 2 7 1986 .~,~ '~ch0rage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 1~3-165 3. Address 8. APl Number P. O, BOX 100360, ANCHORAGE, ALASKA 99510 50- 0:29-21 041 9. Unit or Lease Name 166' Sec. KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION- 2253' FSL, FEL, 7, T11N, RDE, UM 5. Elevation in feet (indicate KB, DF, etc.) 78' (RKB)114' I 6 . Lease Designation and Serial No. ADL25644 ALK 2575 10. Well Number 2V-4 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December to a water conversion "C" sands. 19, 1985 Kuparuk well 2V-4 was converted from a producer injector well as part of the full field waterflood effort. Water is being iniected into both the "A" and 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ /~' (~,-~'~- ~ Title KUPARUK Date The space below for Commission use OPERAT IONS COORD I NATOR 1/73/86 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post O~--;ox 100360 Ancho~ _ . Alaska 99510-0360 Telephone 907 276 1215 December 10, 1985 Mr. C. V. Alaska Oil 30.01 Porcupine Drive Anchorage, AK 99501 Chatterton, Chairman and Gas Conservation Commission Dear Mr. Chatterton: Attached are our notices of intention to convert field well 2V-1 and 2V-4 to water injection wells. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD.ps'File Attachment (In Triplicate) Kuparuk RECEIVEb AnChorago' C°rnmisslor~ ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUN_ RY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P, O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 2253' FSL, 166' FEL, T11N, R9E, tJM Sec. 7, 7. Permit No. 83-165 8. APl Number 50- 029-210ql 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2V-4 5. Elevation in feet (indicate KB, DF, etc.) 78' (RKB)114' 12. 11. Field and Pool KUPARUK RIVER FIELD b6. Lease Designation and Serial No. KUPARUK R I VER O I L DL256qq ALK 2575 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: Perforate Stimulate Repair Well (Submit in Triplicate) [] Alter Casing [] Perforations [] Abandon [] Stimulation [] Change Plans [] Repairs Made (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to increased gas capacity well 2V-4 was not converted from a gas injection to a producer well. "A" sand It is proposed that 2V-4 be converted from an gas to an "A" sand water injection well. This conversion process of the Phase ! water-alternating gas injection project. anticipated the injection will be routinely alternated from water injection in 3 month and 9 month cycles. Conversion of 2V-4 is expected by 12/15/85. injection is part It is gas to 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed FJi~ Title KUPAR[JK The space below for Commission use OPERAT IONS COORD I NATOR Date 1 ? / ! 0 / 85 Conditions of Approval, if any: ,._. Approved by COMMISSIONER Approved Copy Returned /~-~ ?-o~ ~..~ the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate r-~_.. ~-t o¢I, ARCO Alaska, Irt~--' Post Offic .... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working.with ARCO Alaska, Inc. in this area. If you have.any questions .please call me at 263-4212. Sincerely, T. }4. Drumm Kuparuk Operations Coordinator _cc: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED S E P 2 0 O. ~ Gas Co.s. Comrnissio~ Anchora~ge STATE OF ALASKA ~--. ALASF~-"OILAND GAS CONSERVATION )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska. 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. Perforate Stimulate Repair Well 99510 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached Pull Tubing t61 Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [~ Repairs Made [] Other [] [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe PropoSed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of/^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approxirnatel~v 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. 2 0 19".,5 Oil & Gas ConS. commission Anchorage 14. hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ;:~, /~.~ ~.~r~.~.-~ Title Kuparuk Operations Coordinator pa,e The space below for Commission use 9/18/85 Conditions of Approval, if any: Approvedby (~~ ~~ Form 10-403 Rev, 7-1-80 Approved Cof~y J~,eturnecl / By Order of COMMISSIONER the Commission Date __ Submi! "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 -176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 2'1062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 I! 25658 25658 25657 !! 25656 I! 25644 25643 25655 25644 25655 25642 !! 2580 12/15/85 !' 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 I, 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 ~, 115/85 ECEIV ~laska Oil a Gas Cons-Commlss~or~ PHASE I-A 3UILT WELLS I thru 8 oF A, · OAVl D LUC( 5276 - 8 RECEI,,,- Vel. LOCATED IN PROTRACTED SECTIONS '7 & 8 TOWNSHIP lIN.., RANGE 9 E.,UMIAT MER. DRU--~' SITE 2-V CONDUCTORS Ab-BUILT LOCATIONS REV. I: CHANGE WELL NUMBERING PER NSK DRILLING, REMOVE PROPOSED LOCATION 1,2,11 8 12. REMOVE NOTE RE: ORIGINAL LOCATIONS 7 ~8; SHOW AS' BUILT LOCATIONS FOR CONDUCTORS 5 I~ 6. REV. 2:1 ADD CONDUCTOR 8.A. I' Y:5,966,598.45 LAT. 70° 19' I 1.8641" X: 508,47-1.81 LONG. 149° 55' 54. ZI5" 168' FEL 189:5'FSL 2' Y: 5,966, 718.54 LAT. 70° 19' 1:5.045Z'' 'X= 508,421.75 LONG. 149° 55' 54.?-I :5" 16?'FEL 201:3' FSL Y:5,966,838.5Z LAT. 70° 19'14 2254" X: 508,47-1.94 LONG. 149°55'54 204" 166' FEL ?-133' FSL Y:5,966,958.61 . LAT. 70° 19"15.4065" X: 508,42:1.81 LONG. 149° 55' 54.203" 166' FEL 2?-53' FSL Y=5,966,958.46 LAT. 70° 19'15.4020" X: 508,701 .94 LONG. 149055'46.028'' 114' FWL 2253'FSL" Y= 5,966,838.50 LAT. 70°19'14.2221" X: 508,701 .92 LONG, 149°55'46.035'' 114' FWL 215:5' FSL 7 Y:5,966,718.55 LAT. 70° 19' 1:5.0420" LONG. 149° 55'46.0:57" 2.015' FSL ? ':)/2.? ~, Z~ ,fOrA X: 508,701.89 II 3' FWL Ataska 0il & Gas Cons. Com[ ~aio =5,966,598.58 . Anchorage ~ ~: 508,701.86 ~ 112~ FWL SA Y= 5~966~590.19 X= 508~701.89 112~ FW L NOTE, BASIS OF LOCATION IS MONUMENT :52-1 8~ 2X 30bTH; BASIS OF ELEVATION IS TBM 8:5-4:5-2.5 AS SET BY LHD E~ ASSOC. LA'T. 70° 19'11 .8623" LONG. 149° 55'4 6.047-" 189:5' FSL LAT. 70° 19'11.7798'' LONG. 149°55'46.042:" 1884' FSL 2-V~ RVEY-- liN, V.'AT MER. I HEREBY CERTIFY THAT' I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE · LAND-SURVEYING IN THE STATE OF ~LASKA BSSOE AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT 'SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCT. 20~ 198:5. CONDUCTORS 5 E~ 6 SURVEYED NOV. 5 ,198:5i 8-A SURVEYED JULY 11,1984. ARCO Alaska, Inc. Kuparuk Project North Slope Drilling DRILL SITE ?_.-V AS- BUILT CONDUCTOR LOCATIONS date: NOV. 9 , 1983 scale: I": 400 drawn by' E.W. dwg. no.' 9.05.222.11d2 rev. Z ARCO Alaska, Inc. ? -Post Office E,. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 'ir' i:;t,q N 5" H _T 'I"F A L N (3 ·_~'~ t o ''~ '? ::E:TURN T0' AI:(CO AL..ASI<A, INC, Al'l'i',l' RECORI),9 CLE"F(I< ATO-i t '1 F:'.[). I)OX .100360 AHCHORA(~E, Al< 9'5~tO 1' I:;~ ,*, N..? H I l' TIE I) ' H Iii: I:(E 141 T I--I A I:;~ [.'-. T H [.'] I:: [)I_. I... (] 14 1 iq [~ I:< Iii: C E: :[ F' l' I~ N I) I:;: E T U I? H D i,11"'" ,? :1: G N IE P C (] F:' Y [] F' I..JSF(/,S'E(~UEEi',ICE 01::' EVlii:NI'S ((]i',ll:~. C[)I::'Y OF EACH) ~'i.~1-.11:' (HISC. ACI'IVII'Y) ,S'Ii-:l-.ll::' (HIS,'C, ACI'IVITY) .C, 3-2(')-r:~5 I:;:lJl'd.. -. 'C" ,?¢'li',lI) []NL.Y ]3HF:' ¢;3-,=-,.,-")'z .p,:~.,.., TLJRi'~¢,F;:C)UNI) '"" "' ]: N ,J ["' C ]' · 4-''~ ..... L-,-,.-~ ,.: I [] i'-,I C) ,.. 0 -" P, ':'~; I) ]: E,.VEI... BF;,'.EAI< DOWN F:'I'.".LJ '[.:' ,.S'ANi) ONL. Y 04-22-'85 I ! . .") F'Z-~I.J C 5'Ai',~D [)NI...Y 04--,=.'I -"85 'A ' SAND F'BU ¢.4-2':~-'[']'::; ENI) I::'E{U/TCL F' B tJ 04. --':.) .1 ..... i:':t':.~U C[)HF'LET I Oi',l 04-22-'85 [)'F I $' [) 1' I [) T I $ B, ,J, I..I U G I"I.E [)I']:.S' (]TI,S' [: ,A M C (:) ARCO Alaska, Post Ollice Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to stimulate Kuparuk Field well 1F-6 and to convert the following wells: 1Y-2, 1Y-8, 1Y-12, 1Y-15 2A-l, 2A-2, 2A-3, 2A-4, 2A-5, 2A-6, 2A-7 2V-1,.2V-2, 2V-3, 2V-4 If you have any questions, please Call me at 263-4253. .o Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JAN 0 4 1985 Alaska Oil & Gas Cons. Con]miss[on Anchorage ARCO Alaska, Inc. Is a subsidiary o! AtlanflcRlchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL ]~ 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCATION: TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 78 ' (RKB) 114' 12. 2253' FSL, 166' FEL, Sec. 7, 7. Permit No. 83-165 8. APl Number 50- 029-21041 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2V-4 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER OIL ~DL25644 ALK 2575 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2V-4 be converted from a gas injection well to a producer. The well originally was a producer in the "A" and "C" sands. It was converted to a "C" sand injection in November, 1984, and now will return to production ("A" sand only). ANTICIPATED START DATE: February 4, 1985. RECEIVED .IAN 0 1985 Alaska 0il & Gas Cons. O0mmissi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDINATOR The space below for Commission use Date 1/3/85 Conditions of Approval, if any: BY lOt~lE §. SMITlt By Order of Approved by. COIVlMISSIONER the Commission Approved Returned Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir, Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 December 18, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action ~ Date Performed 1E-5 Fracture 11/15/84 1E-8 Stressfrac 12/3/84 1G-2 Stressfrac 11/22/84 1G-4 Acidize 12/4/84 1L-3 Fracture 10/28/84 2A-4 Stressfrac 12/8/84 2C-3~ Perforate 10/27/84 2D-4 Perforate 12/5/84 2V-1 Conversion 11/8/84 2V-2 Conversion 11/8/84 2V-3 Conversion 11/8/84 2V-4 Conversion 12/8/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk ~Operations Coordinator MLL / kmc Attachment (Duplicate) R F.. C rt.. V F.. D OEC 2 ~t!!~ Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a subsidiary of AflanflcRichtieldCompany ~"-"" STATE OF ALASKA -'"' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-165 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-21041 4. Location of Well 9. Unit or Lease Name SURFACE LOCATION: 2253' FSL, 166' FEL, Sec. 7, KUPARUK RIVER UNIT T11N, R9E, UM 10. Well Number 2V-4 11. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. KU PAR U K R f V E R 0 ! L 78' (RKB)114' ~DL25644 ALK 2575 POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X[] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December 8, 1984, to an injector. The the "C" sand only. Kuparuk well 2V-4 was converted from a producer "A" sand was blanked off and injection will be in RECEIVED OEC 2 Alaska 0ii & Gas Cons. C0mmlssi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ Title OPERATIONS COORDINATOR The space below for Commission use 12/18/84 D a t e~,~) _~/ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date .__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of intention to convert Kuparuk Field well 2V-4 to a gas injection well and to perform a Stressfrac treatment on 2A-4. if you/~b~e any questions, please call / \ ~~ike L. Laue ' Kuparuk Operations Coordinator me at 263-4253. MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, COMPLETED WELL OTHER [] 4. Location of Well SURFACE LOC~TION: 2253' T11N, RgE, UM FSL, 5. Elevation in feet (indicate KB, DF, etc.) 7. Permit No. 83-165 8. APl Number ALASKA 99510 s0- 029-21 041 9. Unit or Lease Name 166' FEL, Sec. 7, KUPARUK RIVER UNIT 10. Well Number 2V-4 1 1. Field and Pool KUPARUK RIVER FIELD [~ 6. Lease Designation and Serial No. KUPARUK R I VER O I L 78' fRKB)114' AD 25644 ALK 2575 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 2V-4 be converted from a producer to a gas injection wel I. The. wel I has produced from both the "A" and "C" sands. For injection however, the :A' sand will be blanked off and injection will be in the "C" sand only. ANTlCl PATED START DATE: November 16, 1984 14. I her~at the foregoing is true and correct to the best of my knowledge. KU PARU K ~j~,~-- ~' ~'~l~. ~J,t.-, ~O ~- Title ' OPERAT IONS COORD I NATOR Signed The space b~low for Commission use Date 11/15/84 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Form 10-403 Submit "Intentions" in Triplicate ARCO Alaska, In:-~-''' Post Office ~(~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2V Pad Wells 1-8, 8A Dear Elaine: 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 JG/tw GRU1/L20 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany WELLS :5 thru ~_--,~.,~%-.~,-.,,~- .... ,,t,o f ~ 8 5276- S &r~ . LOCATED IN PROTRACTED SECTIONS TOWNSHIP I1~, RANGE 9 E.~UMIATMER. NOTE:BASIS OF LOCATION IS MONUMENT 32-1 ~ 2X SOUTH; BASIS OF ELEVATION IS TBM 8;.'.'5-43-25 AS SET BY LHD I~ ASSOC. 8 9 24 2-V' FHIS' / JRVEY. 7 lIN, R 9 E, rJM:AT MER. ,l,.= I M.~LE REV. I: .. WEL NUI~BERING PER NSK DRILLING, ,,r2MOVE PROPOSED LOCATION I, 2_, I1 ~ 12. REMOVE NOTE RE: ORIGINAL LOCATIONS 7 ~ 8; SHOW AS-BUILT LOCATIONS FOR CONDUCTORS 5 ~ 6. Y=5,966,598.4.5 LAT. 70° 19' I 1.8641 X: 508,421.8 I '~ LONG. 149°5'5'54.2-.15" 168' FEL 1893' FSL 2_.. Y= 5,gGG, 718.54 'X: 508,421.75 IG7' FEL Y: 5,966,838.52_ X= 508,421.94 166' FEL ¥=5,966,95B.$ I X: 50B,42_1.81 166' FEL ¥=5,966,95B.46 X= 508,701 .94 114' FWL ¥=5,966,838.50 X= 508,701 .92 114' FWL ¥=5,96G,718 ×= 508~701.89 Ii 3' FWL 8 . Y= 5,966, 598.58 X= 508,701.86 IIZ' FWL LAT. 70° 19' 13.0452" LONG. 149° 55'54.213" 2013' FSL LAT. 70° 19'14 .27_54" LONG. 149°55'54 204~ 2153' FSL LAT. 70° 19' 15 . 4065" LONG. 149°55'54.203" 2253' F S L LAT. 70° 19' 15.4 020" LONG. 149°55'46.028" 2253' FS L - LAT. 70°!9'14.2221" LONG. 149°55'46.033" 2135' FSL LAT. 70° 19' 13.0420' LONG. 149° 55'4G.037" 2013' FSL LAT. 70° 19'11.8623' LONG. 149° 55'46.042." 1893' FSL I HEREg¥ CERTIFY .REGISTERED AND LAND -SURVEYING TH AT' i AM PRO LICENSED TO PR IN THE STATE OF AND THAT THIS PLAT REPRESENTS MADE UNDER MY DIRECT SUPERV1SIO PERLY -- ACTICE ALASKA A SURVE N AND THAT ALL DETAILS ARE CORRE OCT. 20, 1983. CONDUCTORS 5 ~ 6 NOV. 5 ~ 1983. CT AS OF SURVEYED Kup-ruk ARCO Alaska, Inc. Project North Slope Drillln DRILL SITE 2.-V AS- BUILT CONDUCTOR LOCATIONS i NOV. 9 , 1983 J ~cal.' I"= 400 dr~wn b7' E.W. I dwg. no.' 9.05.222.1: I rev. I ARCO Alaska, Inc. {. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 7, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2V-4 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to fracture 2V-4. Since we expect to start this work on August 8, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Arda/Dril 1 ing Engineer JBK/JG/tw GRU8/L86 Enclosures RECEIVED AUGO Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany '-'- STATE OF ALASKA ~-- ALASKA~.,,L AND GAS CONSERVATION CC ivllSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I~x OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well Surface: 99510 2253' FSL, 166' FWL, Sec. 7, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 114' I 6. Lease Designation and Serial No. ADL 25644 ALK 2575 7. Permit No. 83-165 8. APl Number 50- 029-210/+1 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2V-4 12. 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to fracture this well. This work will be done as follows: 1. MIRU E-line unit. Run Temp/CCL log. 2. RU frac equipment and pump frac. 3. Run post-frac logs. 4. RD E-line unit. Estimated Start: August 8, 1984 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. i hereby certif~_l;hat the foregoing is true and correct to the best of my knowledge. ////~_--_/"~/L~, ~ Area Drilling Engineer Signed Title The space sion use Conditio~ of Apprc{~rr, if any: Date Approved Copy Returned IONMIE 1:. SMITIt By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU8/SN27 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALA$t~A OIL A#D GAS CO#SERVATIOfi C0~,~15S/0~ Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~~-/~-~~ · Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please'submit the above missing material. Sincerely, Chairman ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2V-4 Dear Mr. Chatterton' Enclosed are the Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG:tw GRU7/L07 Enclosure RECEIVED APR 2 4 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' ~--~---- STATE OF ALASKA '"-----. ~-___ ALASKa.. ~_ AND GAS CONSERVATION ~ MISSION ' WELL COMPLETION OR RECOMPLETION'REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,,,.~,,~/ 2. Name of Operator 7. Permit Number i/~, ~// ARCO Alaska, Inc. 83-165 / 3. Address 8. AP1 Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21041 4. Location of well at surface 9. Unit or Lease Name 2253' FSL, 166' FEL, Sec. 7, TllN, R9E, UM T~oc,A?~i-,,.~.F Kuparuk River Unit At Top_ Producinglnterval /EJ~JF!~:~ ! 10. Well Number 385z~' FSL, 3767' FEL, Sec. 7, TllN, R9E, UN ]Surf._~;~' ! 2V-4 At Total Depth lB. IH ~j l l. Field and Pool 3954' FSL, 3962' FEL, Sec. 7, TllN, RgE, UM ....... Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 114' RKBI ADL 25644, ALK 2575 12~ Date Spudded2/10/83 13. Date T.D. R eachedl 2/15/83 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/03/84 N/A feet MSL 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7675'MD,6203'TVD 7571 'MD,6109'TVD YES [~ NO [] 1906 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, RFT, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: 62.~ H-40 Surf 110' 24" 220 sx CS II 9-5/8" 36.0#/47.0:~ J-55/L-Sl) Surf 3121' 12-1/4" 900 sx Permafrost E & 250 sx Permafrost C 7" 26.0# J-55 Surf 7662' 8-1/2" 280 sx Class G & 250 sx Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD) 7188' - 7240' W/ 12 spf 3-1/2" 7308' 7278' & 7020' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. ' DEPTH INTERVAL (MD-) AMOUNT& KIND OF MATERIAL USED 7394' - 739G' 100 sx Class G 7292' - 7294' 100 sx C~ass G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD I~ FIowTubing Casing Pressure CALCULATEDI~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Briefde~cripti~n~f~ith~~~gy~p~r~~ity~fractures~apparentdipsandpresence~f~i~~gas~rwater.submitc~rechiRENONE CEJV E D APR 2 1984 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 GRU6/WC13 CONTINUED ON REVERSE SIDE ...._ . . ..~, ::. .... ~ ..:.~--~: GEOLOGIC~MA'RKERS :-:. ~: ,'~-.~ :~, ,~::, :, ~. ~. .... -~ ,~,~, --~ ,~,-,,~,_,. ;~ "'-,,- ,, -~:~ ,. ,. : .~ : ..... ..~ ,. ., :,.~.~ .. · . . , NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS, DEPTH TRUE VERT. DEPTH GOR;and time 0f each phase. .', . . . . - . Top Upper Sand 7187.~ 5767~ , Base Upper Sand 72~0~- - : ' 581~~ See RFT results . . . Top Lower Sand: / 7309~ 5875~ Base-Lower Sand 7~68~ . 6017~ . .. . · · -. .~ - ;. · · .. . . . . · . . . . .; . 31. LIST OF ATTACHMENTS . Drilling History~ RFT results, ComPletion Summary, Gyroscopic Survey (2 copies)· 32. I hereby certify that the foregoing is l~rue and cOrrect to the best of my' knowledge '- . Signed Title Area Drilling Enqr. Date INSTRUCTIONS General: This form is designed [or submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ~ : -, '*"l ~--~. ,'l 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 v~heth~r from ground level (G L)' 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". 2V-4 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0515 hrs, 12/10/83. Drld 12-1/4" hole to 3140'. Circ & cond hole. Ran 76 jts 9-5/8" csg 36# J-55 HFERW & 47" L-80 BTC csg w/shoe @ 3121'. Cmtd 9-5/8" csg w/900 sxs Permafrost "E" & 250 sxs Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Instld 9-5/8" packoff. NU BOPE & tstd same. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10 new form. Tstd form to 11.5 ppg - EMW - ok. Drlg 82"2 hole to 7675 TD as of 12/15/83. Ran logs DIL/SFL/SP/GR/FDC/CNL/CAL f/7662 to 3121. Ran RFT's. Ran 17665 its 7" 26# J-55 HFERW BTC csg w/shoe @ 7662. Cmtd 7" csg w/280 sxs- class "G". Bumped plug w/3000 psi - floats held - ok. ND BOPE. Installed 7" packoff & tstd same - ok. Leave top of 7" csg void for freeze protection. Performed arctic pack using 250 sxs Permafrost "C" & 62 bbls arctic pack. Secured well and released rig @ 1530 hfs on 12/17/83. HILL/DH76 1/12/84 RECEIVED APR 2 4 19tM Alaska Oil & Gas Cons. Commission Anchorage 2V-Z~ COMPLETION SUMMARY RU GO/Eastman. Ran GR/CBL/CCL f/PBTD - 3100'. Ran Gyro. RD GO/Eastman. Secured well. Accepted rig @ 1900 hrs, 03/27/84. ND tree. NU BOPE & tstd - ok. Ran gauge ring/JB to 7560'WLM. Perforated 7394' - 7396' w/4 spf. RIH & set EZ Drill retainer @ 7310'WLM. Pumped & squeezed 100 sx Class "G" cmt. Perforated 7292' - 7294' w/4 spf. RIH & set EZ Drill retainer @ 7140'. Pumped & squeezed 100 sx Class "G" cmt. RIH & tagged retainer @ 7140'. Drld retainer f/7140' - 7143'. Drld cmt below retainer. Tagged bottom retainer @ 7314'DPM. Tstd upper squeeze perfs to 1500 psi; bled off to 800 psi in 15 minutes. Retested squeeze job by isolating f/pump & standpipe. Repressured to 1500 psi; bled to 1250 psi after 15 min. Pumped pill. Drld btm retainer & cmt f/7314' - 7563' CBU. Tstd csg to 1500 psi - ok. Pumped pill. Spotted balanced Brid~esal pill (30 bbls) f/7300' - 6515'. RIH & perforated the following intervals w/12 spf: 7240' - 7220' 7220' - 7203' 7203' - 7188' Set top of FB-1 pkr @ 7263'WLM. Ran 3 1/2" completion assy w/tail @ 7308', FB-1 pkr @ 7278', FHL pkr @ 7020', &SSSV@ 1906'. ND BOPE. NU tree & tstd to 5000 psi - ok. Pressured tbg & set pkr. Disp well w/30 bbls diesel & 215 bbls crude oil. Set BPV. Opened SSSV. Secured well & released rig @ 2400 hrs, 04/03/84. GRU6/CSOg-tw RECEIVED APR 2 4 1984 Alaska Oil & Gas Cons. Commission Anchorage 2V-~ RFT Results Depth Hydro. Pressure Shut-in Pressure 7192 7198 7214 7232 7330 7356 7362 7370' 3142 psi 3137 psi 3141 psi 3153 psi 3212 psi 3221 psi 3219 psi 3217 psi 2997 psi 2997 psi 2997 psi 3002 psi 3043 psi 3048 psi 3050 psi 3060 psi JG/O3:rb RECEIVED APR2 41984 Alaska 0il & Gas Cons. Commission Anchorage A R F: 0 A L A :'-";K A, I N E:. PAD 2V~ WELL NO: 4 SIGMA-GYRO ,JOB NFl: A¢~1F:4Z0224 KUF'ARL~K FIELD, NORTH '.:LFIPE, ALASI<A '.i!i:IGMA-GYRO, 0-7..5.._~6 P'ID, '.:_:URVEYOR: ,JAHN/CORAM, DATE RUN: O/:..-,JAN-E:4 :=;IGMA 175 NO: 662,. F'ROBE NO: I::ORE'.-_; I (3FIT: '._:;O¢~W SIJRVEY 'rAKEN FROM WELLHEAD VERTIF:AL .'=_;EC"rI("IN F:ALC:ULATED IN PLANE OF PROPOSAL DIRECTION: N 64 flEG, 6 MIN. I,~1 RECORD RF SLIRVEY RADILIS F~F L.I_RVATLIRE METHOD ARCO AI...A:z;I:::A, ] NC:,, COMF'UTAT!ON F'AGE NO. F'AD 2V, WELL NFt: 4 ::;IGMA-E~YRF~ ._lL]f'~ NO: A(:D1:::4Z0224 'FINE DATE KUPAF..'UK FIELD, NORTH '.:;LC)F'E: ALA~E;KA I 1: 27: 2:s: 25-.JAN-:E::3 TRUE MEA'._:;URED DRIFT DRIFT F:OURSE VERTICAL VERTIF:AL SI_IB'.-]EA R E C T A N F~ I_1 L A R C L O :-_-: I_1 R E DOGLE,]; DEF'TI4 ANGLE DIRECTION LENGTH DEPTH .'E;ECTION TVD F: ~-~ 0 R D I N A T E ::: DI'.E;TANCE DIRECTION :s;EVERIT' FEET D M D M FEET FEET FEET FEE]' FEET FEET l: M DG/1 ()OF l('Dc"~ ('D ':' S 8:9 ~'2 W lOPeD, lCDO C'DC'D 0 1('~ --14 00 (') C'~I c. ('D 1 i W (') 1'-' S 8:3 52 W ('D. 1:3 ..... ~m - ~, · . . u · .' . · i_,, _. ~m . . . '--' - 200. 0 5 S :2:2 :_::2 W 100. 2(')(,). 0(] 0-' 20 :36 · 00 0. 11 '.--; 0. :..-'_'7 W 0.29 '.9 68 I W 0. 10 ::300, 0 'F..' S 5O 6 E 100,, :-_-:00,00 0.08 186,00 0·:31 S 0,24 W O,:"::"F.' '.E; 38 12 W 0,17 4(')FD. (iD 7 N 6/:, 4() W 100. 400.00 0. 10 2:=:6.00 O, 45 S 0.3:3 W 0.5/_', S :':::/_', 11 W 0, :.37 5F)0. 0 46. 'E; :=:Fi ..... :::6 W 100 . ~¢D(')_.. · (')('). c:D · ,_,':'M... :3:36 .00 0 . ._'::'--'.,.. S i . 1¢)_ W 1 . 15 ._,c- 7:':-: 4.(] W 0 · 6::: /:,00. 2 2'.-.'-' S 7'.-.-,' 4 W 100, )5'.T,".:;'. ,? 5 :3.2:3 485, 'F,'5 0,70 S 3, 'F.' 3 W :3.99' S 7'.-.-.' 52 W 1,71 700. 5 19 S 84 23 W 100. /:,99.71 :::.87 585·71 1.6:E: S 10./:..7 W 10.80 '.:; 81 4 W 2.::: :9c)0. ::: 20 N :92 48 W lc)0. 798.99 19.62 6:::4.'P'F.' 1.50 '.9 22.54 W 22.5'.P S 86 11 W :::.35 'P00. 11 :]-:2. N 77 4..9 W 100. :::97.47 :2:6.19 7:::3.47 1.40 N :39.55 W 39.5:E: N :::7 58 W 3.:31 lc)00. 14 59 N 74 52 W lc)O-' 994.79 58~61 880.79 6,81 N /.':,1.84 W 62.22 N 8:3 4.:3 W 3.52 :1100. 18 59 N 71 6 W 100. 10'.P0.41 87.47 .cY76.41 15.36 N . 89.78 W 91.08 N 80 17 W 4.14 1200. 21 36 N 7:.2 29 W 100. 11:94.19 121.85 1070.19 26.20 N 122.73 W 125.50 N 77 57 W 2.6./:, :1.:300. 2.5 44 N 76 41 W 100. 1275.75 161.31 1161.75 36.86 N 161.42 W 165.58 N 77 8 W 4.45 140c). 29 9 hi 74 4-8 W lc)0. 1364.48 206.44 1250.48 48,20 N 206.08 W 211.65 N 76 50 W 3.5:3 1500, :3:3 10 N 73 18 W 1CDC). 1450.0:z: 257.40 1336.0:3 62.4.1. N 255.84 W 2/_-.3.:34 N 76 17 W 4.10 1600., 3/_-, 49 N 7c) 42 W 100. 1531.'.T¢4 :314.'.'?CD 1.417.94 80. 13 N :310.:']7 W :.:!:20.55 N 75 31 W :3.9:::': :1.70F!,. :}.':8 '2'F..' N 68 1:':: W 1()(), 1/.',,11 ,, 11 .":-:7.=';_ _. 0I 1497.11 101 . F,/.,_. N :'::,"_-,7 . .5;7 W ._,':"='1, :'::4,., N 74 :':::":-: W 2. '":' ~..,.. ._ 1 ::": (')0 ,, :38 40 N 68 .1. 0 W 1. 0c). 168'.-}. 2'? 43'7.22 1575.2'!') 124.7:3 Iq 4. 215.47 W 4.43. :37 N 7:3 40 W O. 19 1900. 40 17 N 67 49 W 100. 1766.48 500.64 1652.48 148,,55 N 484.41 W 506.67 N 72 57 W 1./_-,:3 20c"D0. 4.:l 29 N 6'7 18 W 100. 1842.()8 565.':T.'7 17:28.c) 8 173.!54 N 544.90 W 571.87 N 72 20 W 1.25 2100. 41 24 N 67 2.0 W 1()0. 1'~ 17.04 632.01 1803.04. 1 '.--.*'FT. 06 N 605.92 W 6:-_-:7.78 N 71 49 W 0.0'.'} :;'::":2:0c).41 0 Iq 6..5 ..52 W 10(). ], '.-.-¢',,7~2.28 697.81 18'78.28 225.22 N 666. :37 W 70:3.40 N 71 -'.,-::0 W 1.05 :;;ir:300. 4.1 24 N 65 7 W 100. 2()67.52 763.66 1953.52 252.. 54 N 726.3 () W 76, E: . '.~ 5 N 70 50 W 0. 6' 4 '"? 40 (). 42 14 N 64 27 W I 0 (). 2 .1. 4:2. C"~ 5 830.'--0''."~' ,~":' ¢)..~.'? :q... 0'.5 2 :=: 0 .94 N 786. 62 W '--''--''~'=' '~' 5..--'29. N 70 2 I W C: . ',~ 4 · ;::'.":;0o, ....... 4.2 .54. N 6:7;: ::56 W 100. '~'"~Zl~;. ................... 7(] ::!:77 9'7 21(:).1. 70 :31c) .':-:9 N :=:47 .'-";'-,' W 'P02..57 N 69 .=;'-':, W 0.7.5 :260(') .... ,, 4.::::1.'7 N A":'....., 45 W 100 . .,."::" .'.' q '::'.,.. ,_ ,_,. 72 "TM, l-, .... . ":"=',:.,.., 2.1.74 .7'2 :340 .51 N 'pF)F.::.. _. 8:3 W 'r.">70 '=,':'....., N 69 28 W 0, 4() 270,r'), 4:3 5 N /_-,::":: 4'7 W 100. ':::.: :3 ./:, 1,64 1034,7 .1. 224.'7,64 :37('D, 76 N ?70.21 W 1038.64 N /.:-,'Fy 5 W 0, '.';:0 :2 ::::00 ,, 4.:3 1:2 N 6:::: :34 W 't()O. :24:34,61 11 ('):3,09 2320.61 401.0:3, hi 10:31..5C) W 1106.74 N 68 45 W (). 1 '.':-:' 2'.:.:.'0('D,'1.:3 :;32 N 6::::: ::;:6 W 100. ':?507,40 117.1., 64 ';?.:3'.:;':3.4() 4:2:1 · 68 N' 1('.)'.-.-¢:2.':, ,;.::5 N 1175.02 N /.6-.:_--: 27 W 0. 19 AF,:CO ALASK A, I NI-': F::' A l.'.[ 2 V .: W E L L. N 0: 4 '.:_'; T f-.i FI A- r--i y R Ci KLIPARUI< FTELD., I',IFIRTH SLr]F'E-, ,J f'll B N rll: A 01 :=: 4 Z 0224 F: Cl M F' I_1T A T I 0 N T I ME DATE 1 I: 27: 28 '--'. ' 5-,_1A N- 8:3 PAGE NO. 2 TRUE MEA'.:;URED rIR IFT f)RIFT CAURF:E VERTICAL VERTICAL SUBC-;EA R E C T A N G U L A R C L 0 S U R E rIOGLEG DEF'TH ANGL. E DIREC'rlnN LENGTH 1]EPTH SEC]'ION TVD C 0 0 R D I N A T E S DI'STANCE DIRECTION SEVERI T' FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F' :l:,:")'[) 0 ,, 4:l: 2'.'.-" N 6::: 6 W .......':,'1(1)0. 4.:E', :=:C)_. N '6,:':: 1.'q,_ W :3200. 4:3 6 N 6:3 9 W :3:::00. 4-2 39 N 6::: 21 W :.':-:4 (')(]:, .4-:2:3:3 N /-, '-''"'.,.:.:7 W :35'[),:."). 4.:2:1 ¢) N '6,::: 2:5 W · :'.::6'[)(') 41 ._ = N 6:3::34 W :37,[;)0. 4.2:15 N ,6,4. :3 W ::: :E: ¢) '[] . 4':.2 4''[]' N 64 :3 W ::3'.:;" ¢). '[':'... 4.':;:' '='...,._'"'~ N 6/i. 14 W 100. 2580.03 124A. 38 2466. '[)3 100. 2'6.52.57 130.9.21 25:-.:8.57 100. 2725.35 1377.7:9 2611.35 1 £)0. 2798.6:2: 1445. :_-:2 2'6,84.63 1 ¢)0. '.:".872.24 1513.49 2758.24 100. ;2 °.=.* 46. 1:3 1580.8'6, 28:32. 13 1. 00. :3020.4:3 1647.80 2906.43 100 ,, :3094.67 I'714.78 2980.67 100. 3168.45 1782.29 3054.45 100 :3242 03 1 '-'~" 0:2' 3 z.,:, . . ,=,._,t). . 1 '-"-'. 03 462.60 N 1154.2',5 W 1243.50 N 68 10 W 49:3.66 N 1215.'6,:=_: W 1:312.09 N 67 54 W 524.59 N 1276· 90 W 138£).46 N 67 4'[) W 555.21 N 1337.'6,5 W 1448.:=:0 N ,6.7 28 W 585.43 N 1378.72 W 1515.83 N 67 17 W 615.4:F..: N 145:E:. 52 W 158:2:. 06 N 67 7 W 645.35 N 1518.42 W 1649.87 N 66 5:E: W .. _ ~ "".5:3 _ , 674 'P2 N 1._7o W 1716.7/:, N /-,6 51 W 704.46 N 1/=,39.23 W 1784.19 N 66 45 W 7:33.99 N 1700.18 W 1:::51.85 N 66:39 W 0.26 0.10 0.41 0.47 0.21 0.41 '[]. :32 0.50 (}. 42 0. 15 4.()00. 4.'.=.' 14 N 64 23 W 410¢). 42 45 N 64 38 W 4200. 4:} 2 N 64 41 W Zl300. 4::: :3A N '6,4 ._? W 44(')'[). 4:3 41 N '6, 5 6 W 100. :3:315.87 1.917.46 3201.87 100 ":'":' '=''=',' ."'F..' 85. ..:, ~ / ._,. 60 ....... ,_ ..... 60 I 01 '-'"'-' = 100. :::4'6,2 ,, :37 :20:=]:3.06 :3:'-:4.8.87 100 c,~,:.,~ '6,9 2121 59 342.1 69 10("~. :3608, 11 2190.54 :_":494. I 1 76:3.24 N 1760.':.75 W 1919.24 N 66 34 W 792.31 N 1821.92 W 1986.74 N 66 30 W 821.43 N 1883.44 W 2054.77 N 66 26 W 850.60 N 1945.4.6 W 212:3.28 N '6,6 23 W :.::_ 7'-.'~.. '71 N... t. 0 7.9 7 W 21 '-.?. 2.....~.'-"'"' N 6/.,.. :2 A W · ::/. C) ...... 0.54 0.29 0.50 0.2 :L 4. 5'["),F). 4.:3 ...58 N '6,5 1/=. W 4600,. 4. 4. 1:3 N 65 :;.24 W 4,700. 4.4 42 N 6:5 40 W 4. ',:: '[) ¢) . 44 21. N '6,5:39 W 4700. 4.4 19 N '6, .',5:7:: 6 W 1¢)0. :3'6,80.26 2259.77 35'6,6.26 '.-)08.78 N 2070.81 W 22'6,1.45 N 6'6, 18 W 100. :F:752.0:3 2329.4q 3638.03 '.P37.84 N 21:34.10 W 2331.08 N 66 17 W 10 () .:, c:,.-=,.=, .:, 5 2 :=:'.=; 9 46 " :~ ':' 5 - .... =: 70'.-., .. .... ':'.¢ /-, /-, , 8'6, Iq ',:: 197 ,'=: 9 W 2401 16 Pi 6'6, 1. 5 W ~ ,..~ ,~.1 .% ._1 ~ ...1 .... · -- .. ~ - . 100. :3::::'.-}4.65 24/:,9.56 :3780.65 95)5· 78 N 22/. 1.7:3 W 2471.28 N 6/:, 14 W 100 '.:: ".'¢ /-, /', . 1 :E: ~'= ~":¢ 4. 0 ~"'-'=;'-' - .. 2.:2:25 ¢'~; ' . ...... · ':.....,.: .....-'.,,:,.. z.. 18 1024. '6,1 N .42 W z.-- 4.1 14 N 6,6, 1:3 W 0, 31 0. :-.:5 0.44 ("). O. 05 50()C). 4. 4. :2 N 6!5 46 W 51C)0. 4:3 19 N /=,5 50 W 5:.T:'.00, 4. 2:35 N 65 57 W 5:300. 41 57 N /-'.'6, 17 W 5.4.00. 41 18 N 66 2. 8 W 100. 4037.90 260'.:.~. 05 35)2:3. '.-.70 1053. :30 Iq 238:_',. '.-} 1 W 2610.82 N 66 1 ::.2 W 100. 4.11 (). 23 2678.08 3'.=.,96. 2:3 10:]: 1. '6,2 N 2451.90 W 2677.87 N 66 12 W 1'[)0. 41:.:.:3.4.2 2,746.1::: 40'6,':7¢. 42 1109.4:3 N 2514. 10 W 274.8.'01 N 66 1 I W 100 4.,'...7 4.2 :Z :::: i .:, . 40 4143.42 11 '="57."'5 '6, '='"=' 5 3./..:,.64 N 1 W 1 .2'6, N /'=,6 11 W 1¢')0. 43312.17 2879.78 4-218. 17 1163.26 N 2636.48 W 2881.70 N 66 12 W 0.3 :!. (). 72: ¢). 74 (3.6'6, 0 ,, 6.6 ....... :(.)(J. 4.0:3'.:.) bi 6,/.-:, :32 W 5/=,0'[:) ,, 4, 0 :3 Iq 66 ::ii:O W 5700. :39:2:'.:) N 6'6, :3:3 W 5800. :39 :})4 N '6, 6 4.:2 W !5'.-:/C)¢),,:38 4:3 N 66 :.3.4 W 100,. 4407.67 2945.28 429:=:.67 1'18'P.41 N 2'6,96.5'P W 2947.26 N '6,6 12 W 100. 44 :.,=.: ::-: .88 ::: .... A 0'-.-¢ .9. ':>.. 4 ,_"::/-,..'~ . :'=: :.'3 1""..' 1 '";._. 2 c). N .,~'-' 7 ~.... 6.0 A. W .:,""¢J 1 ,..'=' 02. N '6, 6 1 ';:" W · -, "! /.c', 100. 4. 560 ,, '6,5 :3074.01 444 6.65 1 .' 4,[ ....... :, N 2 :=: 14 ,, :=-:¢) W :3076.10 N '6,6 1:3 W 100. 4./.::,:=:7.7(.'):31:37,, 6'.:,:' 452:':2:, 7,[) 12/-",5.94 N 287:3, :3:3 W :313':.'-/. 84. N /.'.',6 1 :'::: W 100 ............... 4.71 .~ ?....'./:, 3:;::0C) 74 4601 2.5.5 :L'-"... ...... ':,0 97 N ~,9.'=: .1. ,.=.,'-',~ W :::202_, c¢'=' .... I',! 66 14-W 0. '6.5 0.6'[.') 0.4:1. O. 09 0, ~"=' ~ ._1 ARCO AI._AF'i;KA. INC. PAD 2V. WELL NO: 4 '.E:IGMA-GYRO KUF'ARUK FIELD. NORTH SLOPE. ALASKA ,_IDB NO: 40184Z0224 COMF'UTAT I ON TI ME lqATE 11: 27:..'~- '=',_, 25-,..IAN-8:_--: F'AGE NO. 3 · TRUE MEA'.--:URED DRIFT DRIFT COURSE VERTICAL VERTICAL '.::UBSEA R E C T A N G U L A R C L 0 S U R E I]OGLEG DEF'TH AFIGLE DIRECTION LENGTH DEPTH :=;ECTION TVD C 0 0 R D I N A T E S DI:E:TANCE DIRECTION '.SEVERIT' FEET D . M D M FEET FEET FEET FEET FEET FEET D M DG/100F 6100. 37 50 N /_-,/.. :'::2 W 6:2<:i0. 37:2:9 N 66 7 W /::,:3('~0. 2:7 1.5 N /.,5 4-2 W 6400. :--:_/-._ 40 Ixl ,:, ~. ._, '= ...'""','--~.. W 100. 4793.62 3262.8:3 4/.,79.62 1315.71 N 298:3.27 W :2:265. 10 N /-:,6 14 W 100. 4872.45 3.324.31 475:=:. 45 1:2:40.22 N 3044,, 71 W :2:3:76.6:2: N /.,6 15 W 100. 4951.53 :3:2::=:5.48 4837.5:3 1364.80 N 310~]1.78 W :3387.84 N 6/., 15 W 100. 50:2:0.92 :2:446.25 491/... 92 13:89.62 N 3:15/... 2:=: W 3:44:3./..5 N /.,/., 14 W 100. 5110.83 3506. :35 49'76.83 1414.39 N 3211.07 W :3508.77 N 66 14 W 0.62 0.27 0.31 0.47 0.58 6500. :2:.5 51 N /.,5:34 W 6600. :2:5 2:3 N 65 22 W ,"_-'~70(]. :34 4.5 N 64 25 W 6:30(11. :3:3 46 I',1 64 1.2 W 69('~0. :2::2 3() N 6:2:45 W 100. 5191.4-/-, '._::5/.,5.48 5077.46 1438.82 N 3264.94 W :2:5/.,7.92 N 6/., 13 W 100. 5:272. '71 :3623.76 515:::. 71 14/-,:}. 02 N :3317. '.---~7 W :3626.21 N 66 1:2 W 100. 5:2:54.52: :})6:=:1.27 5240.52 14,87.42 N :2::370.05 W :3/.,83.70 N 66 11 W 100. 5437.17 :37:37.56 5:32:2:.17 1511.83 N :3420.7:3 W 3739.97 N /.,6 9 W 100. 5520. '.-} 1 3792.2.':2 5406.91 15:2:5.81 N 3469,, 90 W :2:794.59 N 66 8 W 0. :=:2 0.40 0.90 O. 9'? 1.29 7000. :31 1:3 N 6:3 43 W '7200. 29 9 N 63 35 W 7:2:00,, 27 50 N 6:3 1'7 W 7400. 2.'!:6 49 N 62 51 W 75()~:1, :2.5 2:3 N 62:2:4 W 100. 5605.84 3845.02 5491.84 1559.18 N 3517.25 W :3:_:47. :2:4 N 66 6 W 200. 5778.72 3945, 55 56~..4.72 1603.80 N 8607. :2:4 W 3947.79 N 6/., 2 W 100. 58/.,6.60 3993.25 5752.60 1625.13 N 3650.00 W 3995.44 N 66 0 W 100. 5955.44 4039.15 5841.44 1645.92 N 3690.93 W 4041.29 N 65 58 W 100. 6045.25 4083.13 5.931.25 1666.15 N 3730.00 W 4085.21 N 65 5./:, W 1.28 1.. 0::3 1.04 1.45 F'RO,_IE:CTED ]"0 F'B'i"D ,.-' R 0,...I E C T [":- [) T 0 T D 7.1.. 6109.3:9 411:3,, 5..=.,; 5995.3:9 1680.25 N :3756.9'7 W 4.115.59 N 65 54, W 0.00 7/..:,75. 25 ':.?.:F: N /.,2 2:4 W .1.04. 620:'::. 35 4158.11 6089.35 1700.91 N 3796.48 W 4160.09 N 65 5:2 W 0.00 F I NAI._ CLOSLIRE - D I RECT 101',1: D I S T A N C E: N 65 DEGS 52 M IN'.:: 0 SECS W 4160.09 FEET ARCO AI..A~E~KA [:'A.[I 2V~ WELL NO: 4 E~IGMA-GYRO ,_lOB NO: AO184Z0224 KUF'ARLIK FIEL. D~ NORTH SLOPE~ ALASKA '.E-:IGP1A-GYRO~ 0-7556 MD~ SURVEYOR: ,_IAHN/CORAM~ [;ATE RUN: 06-,_1AN-84 SIGMA 175 NO: 662~ PROBE NO: 064 ~'-ORESIGHT: S00W SURVEY TAKEN FROM WELLHEAD RECORD OF: INTERPOLATED SURVEY ARCO ALA::;KA, INC. F'AD 2V, WELL NO: 4 SIGMA-GYRO KUPARUK FIELD, NORTH F;LOPE, ALASKA ._lOB NO: A0184Z0224 COMF'UTAT I ON TIME DATE - .-.o ~ 1 I: 2::~: 44 ,._-JAN-8:3 F'AGE NO. 1 MARKER ............. C:ODE NAME TRUE .'_--;UBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G LI L A R C: L 0 S I_l R E VERTICAL DEPTH DEF'TH DIFF DEPTH C 0 0 R D I N A T E S DISTANC'E DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOF' UPPER !--;AND BASE UF'F'ER '._--;AND TOP LOWER SAND BASE L. OWER SAND 7187.00 5767.48 1.417.5 5653.48 1600.85 N 3601.43 W 7240.0 ('~ 581 :--:. ::: 7 1426. i 56'.-}'?. 87 161 '2.2'.-} N ::: 624.36 W 7309.00 5874.60 1434.4 5760.60 1626,96 N 365:}. 64 W 7468.00 6016.51 1451.5 5'."-.~02.51 1657.6:} N 3717.45 W 3941.20 N 66 2 W 3966.79 N 66 1 W 3999.51 N 66 O, W 4071.09 N 65 57 W Su~ges~"~"'form to be inserted in each "A~E'ive" well folder to d~.eck for timoly compliance with our rc~julations. ' - O~e~ator, ~1 ~ Name and N'u~Ser '. Reports and Materials to be received by: ~_~ ~, ~--~¢ Date Required Date Received Remarks _ Completion Report Yes · , __ · . · Samples . -- Core Chips Core Descr±ption ...... "-%..- .Inclination Survey //~,/~ ....... DireCtional Survey Ve:~,C''''P Drill Stem Test Reports ./~/d~_~ ..~ · Prod~cti0n Test Reports y,~,~,. ,~ ¢'"'".,~,~, ,,..,,~¢ ¢/'~ Logs Run. Yes ARCO Alaska, In' Post Office aox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Subsequent Sundry Reports - Various Wells Dear Hr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' 2F-6 2V-4 2F-10 2V-6 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG' rb GRU7/L02 Enclosures · ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,,---~ STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION SUNDRY NOTICES AND REPORTS ON WEL ._S 83-165 8. APl Number ~o- 029-71~1 9. Unit or Lease Name ~k R~ver 1, 2. Name of Operator ARCO/l. laska, Inc. 3. Address P. O. Box 100360, gnchora~,/~ 99510 4. Location of Well Surface: 2253' FSL, 166' FEL, Sec. 7, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 114' RKB 6. Lease Designation and Serial No. ADL 25644 ALK 2575 10. Well Number 2V-4 11. Field and Pool Kuparuk River Field I<uparuk River 0il P0ol 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ]~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU ~/Eastm]n. Ran GR/CBL/CCL f/PBTD-3100'. Ran Gyro. RD GO/Eastman. Secured well. Accepted rig @ 1900 hrs, 03/27/84. ND tree. NU []OPE & tstd - ok. Ran gauge ring/JB to 7560'WLM. Perf'd 7394' - 7396' w/4 spf. RIH & set EZ Drill retainer @ 7310'WLM. Pumped & squeezed 100 sx Class "G" cmt. , , · · , "G" Perforated 7292 - 7294 w/4 spf. RIH & set EZ Drill retainer @ 7140 . Pumped & squeezed 100 sx Class cmt. RIH & tagged retainer @ 7140'. Drld retainer f/7140' - 7143'. Drld cmt below retainer. T~a,gge? ,bottc~ retainer @ 7314'DPM. Tstd upper squeeze perfs to 1500 psi; bled off to 800 psi in 15 minutes. Ke~s~eo j squeeze job by isolating f/pu~p & standpipe. Repressured to 1500 psi; bled to 1250 psi a, fte..r. 15 ~n:. ,Puq~ pill. Drld btm retainer & cmt f/7314' - 7563'. CBU. Tstd csg to 1500 psi - ok. Pumped pl/w..~po~e~ balanced Bridgesal pill (30 bbls) f/7300' - 6515'. RIH & perforated the following intervals w/12 spf: 7240' - 7220' 7220' - 7203' 7203' - 7188' Set top of FB-1 pkr @ 7263'WLM. Ran 3-1/2" completion assy w/tail @ 7308', FB-1 pkr ¢ 7278', FHL pkr @ 7020' & SSSV @ 1906'. FD BOPE. NU tree & tstd to 5000 psi - ok. Pressured tbg & set pkr. Disp well w/30 bbls diesel & 215 bbls crude oil. Set BPV. Opened SSSV. Secured well & released rig @ 2400 hrs, 04/03/84. 14. I hereby certify,.,that the foregoing is true and correct to the best of my knowledge. . Area Dri l ling Engineer Signed Title T.e us. Conditions/of Appr v~, if any: Approved by] COMMISSIONER By Order of the Commission Date ........ Submit "Intentions" in Triplicate Form 10403 GE~/SN43 Rev. 7-1-80 and "Subsequent RepQrts" in Duplicate KUPARUK ENGINEERING TRANSMITTAL # ~¢ TO: " FROM: D. Fay Allison see below Transmitted herewith are the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well De s ~ ript,ion Date ,~ V-$ /¢Yn,~.ls~z-/~,,~ (z,. I~ '_) /z.l, 71g~ / RECEIPT ACKNOWLEDGED' PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON. - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. '99510 DATE: KUPARUK ENGINEERING TRANSMITTAL TO' FROM: D. Fay Allison DATE' WELL NAME- Transmitted herewith are the i~ollowing· see below PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Descript ion Date RECEIPT ACKNOWLEDGED' PLEASE RETURN RECEIPT TO: ARCO ALASKA, 'INC. A1-FN: D. FAY ALLISON. - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. '99510 TO' F ROM: D. Fay Allison DATE'- ~_ ~ "-/- OF/ I.~-ZLL HAME' Transmitted herewith are the following' PLEASE HOTE'~- BLUELINE,G SEPIA, F-FILM, t- TAPE, PC- PHOTOCOPY RE, F..EIPT ACKIIOWLEDGED' EASE RETURN RECEIPT TO' ARCO~"iLr.---~:~l~"' ~. ~,~,.,F~ , I I~C i ATTH' D. :FAY ALLISON - ATO/1115-B P. O. BOX 100350 ~,~.,r~.,r,~]e~ A,,. 99510 ,J"~ l I ~,.~ / I v i N/' '~'.';- ) Oil "' Gas Cons. Comm?,r, io~ KUPARUK ENGINEERING TRAHSMITTAL # ~,~_~2 .- TO: _~.'~...:c_ FROM- D. Fay Allison see below Transmitted herewith are the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Description Date Run RE/E~IPT ACKNOWLEDGED' ~/~LEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 - ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-14 2V-3 WSP #2 2F-15 2V-4 WSP #13 2F-16 2V-5 2F-1 2V-6 Thank you. Sincerely, ~ District ri ing Engineer JBK/SH1: ih ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompany "~ ' ' STATE OFALASKA ~ ALASKA LAND GAS CONSERVATION C( MISSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-165 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21041 4. Location of Well atsurface 2253' FSL, 166' FEL, Sec. 7, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. PAB 78' 114' RKB ADL 25644 ALK2575 -- : For the Month of December 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2V-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool ,19__ 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks %_ Spudded well @ 0515 hrs, 12/10/83. Drld 12-1/4" hole to 3140'. Ran, cmtd & tstd 9-5/8" csg. Drlg 8~"2 hole to 7675TD. Ran logs. Ran RFT. Ran, cmtd & tstd 7" csg. Leave top of 7" csg void for freeze protection. Performed arctic pack. Secured well and released rig @ 1530 hrs 12-17-83. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HFERW & 47# L-80 BTL csg w/shoe @ 3121'. Cmtd w/900 sxs Permafrost "E" & 250 sxs Permafrost "C". 7" 26# J-55 HFERW BTC csg w/shoe @ 7662. Cmtd w/280 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/CAL f/7662 to 3121'. Ran RFT's (results not available at this time). 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED . TITLE .... a D='~i~- NOTE--Repor/on~hrs~ is req;ired for each calendar month, rega~l%; of the%tatus o~ oper~ions, and must b~ file~n duplicate with the Alaska Oil and Gas~nserva~Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 ..... ~TT.T./~eR Submit in duplicate 2V-4 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0515 hrs, 12/10/83. Drld 12-1/4" hole to 3140'. Circ & cond hole. Ran 76 jts 9-5/8" csg 36# J-55 HFERW & 47" L-80 BTC csg w/shoe @ 3121'. Cmtd 9-5/8" csg w/900 sxs Permafrost "E" & 250 sxs Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20" hydril & diverter. Instld 9-5/8" packoff. NU BOPE & tstd same. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10 new form. Tstd form to 11.5 ppg - EMW - ok. Drlg 8½" hole to 7675 TD as of 12/15/83. Ran logs DIL/SFL/SP/GR/FDC/CNL/CAL f/7662 to 3121. Ran RFT's. Ran 176 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 7662. Cmtd 7" csg w/280 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND BOPE. Installed 7" packoff & tstd same - ok. Leave top of 7" csg void for freeze protection. Performed arctic, pack using 250 sxs Permafrost "C" & 62 bbls arctic pack. Secured well and released rig @ 1530 hrs on 12/17/83. HILL/DH76 1/12/84 M 'EMORANDUM State of Alaska TO: C. y/. ~ton DATE: December 19, 1983 ~'C~-:-';t-~ FILE NO: 11 6 /! · THRU: Lonnie C- Smith Commis s loner ~ ~__/ TELEPHONE NO: FROM' Ben LeNOrman SUSJECT: Witness BOPE Tests on Petroleum Inspector ARCO's Kuparuk 2V-4, Sec. 7, TllN,R9E,UM, Kuparuk River Unit. .g_~,rdmy;_.Dmmamhar 10: 1983: I departed my home at 6:00 am for a 6:30 am showup and 7:30 am departure via Alaska Airlines, Flt. #55 for Deadhorse arriving at 9:10 am. Weather: -22°F, fair, light wind. BOPE tests on ARCO's Kuparuk 2F-15 were completed, the subject of a separate report. Sunday, December 11~ 1983: Standing by on ARCO' s 2V-4. Monday, December 12, 1983: BOPE tests on ARCO's 2V-4 began at 7:40 ~-m and were completed at-10:00 am. BOPE inspection report is attached. Testing of low pilots, SSV's, SSSV's and 'recording of annulus pressures on 83 Sohio Prudhoe Bay Unit wells began at 1:00 pm... Thursday, DeCember 15, 1983:...and was completed at 6:00 pm, the ~bj~Ct Of a Sepa'rate report. Friday, December 16, 1983: I departed Deadhorse via Alaska Airline's-~Fit'o TM #66 a~ 9:50 am arriving in Anchorage at 11:30 am and at my home at 12:00 noou. In summary, I witnessed successful BOPE tests on ARCO's Kuparuk 2V-4. Attachment 02-00IA(Rev. 10179) OaG #4 4/81 q'~' STATE OF ALASKA ALASKA OIL & GAS OONSERVATION CCMMISSION B.O.P.E. Inspection Report ~InsDector Operator Well ._ ~tion: Sec ~ TII~R~ 'M.M~ ~il linq ~n~a~or Representative Permit # ~9~ ~~asing Set @ ~ I :~ ~ ft. Representat ive ~~ ~~~/ location, General Well Sign C~neral Housekeeping ~/~ Reserve pit ~)~ Rig · ~BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves,__ H.C.R. Valve Kill L~ne Valves- ~ Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure, ~~ psig Pressure After Closure /~ ~-O psig Pump incr. clos. pres. 200 psig, Full Ch~a~.e Pressure Attained: N2 ~ ~ A ~.. ~ &-~_ ! psig Controls: Master ~9/~ Remote ..~9~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Ixm~r Kelly Ball Type Ins ide BOP Choke Manifold No. valves. /_~7~ No. flanges 9/~ ~djustable Chokes / Hydrauically operated choke mind.sec. min~_sec. Test Pressure Test Pressure Test Pressure Test ~es ~e Test ~essure Test Results: Failures ~ Test Time- -~ hrs. Repair or Replacement of failed 'equipment to be made Within , days and Inspector/Ccmmi.ssion office notified. Remarks: ~7~_j~. ~'~-.~u/ ,~ F; T~Z~ ~ /~5 Z,j ~.~' Distribution orig. - AO&6CC cc - Operator cc - Supervisor Inspector~ ~ ARCO Alaska, Inc. Post Office b,..,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 30, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2V-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to change our original plan to reduce problems associated with high-angle holes. Since we expect to start this work on December 10, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, :~:~er JBK/JG5L49'tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C~,,'IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I.. 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 COMPLETED WELL [] 4. Location of Well Surface: 2253' FSL, 166' FEL, Sec.7, T11N, RgE, UN Top of Producing Interval: 3920' FSL, 3602' FEL, Sec.7, T11N, RgE, UH At Total Depth: 4056' FSL, 3881' FEL, Sec.7, T11N, RgE, UN 5. Elevationinfeet(indicate KB, DF, etc.) ] 6. LeaseDesignationandSerialNo. 114' RKB, Pad 78' / ADL 25644 ALK 2575 12. 7. Permit No. 83-165 8. APl Number 50- 029-21041 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2V-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stim u lation [] Aba ndo nment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date ofstarting any proposed work, for Abandonmentsee20 AAC 25.105-170). To reduce the problems associated with higher angle holes~ i.e., reciprocating pipe and getting open hole logs to bottom, we have elected to decrease the kick off point from 1400' TVD to 500' TVD. This will reduce the hole angle from 47° to 40°. The location of the well at surface and the location of the well at the target center remains the same. Due to the decrease in angle, the location at the top of the producing interval and at TD change as indicated above. As indicated on the attached directional plots, the well will be drilled to approximately 7609' MD or 6178' TVD. Estimated Start: December 10, 1983 14. I hereby cerJd4f¥ that the foregoing is true and correct to the best of my k,.owledge. ~.~///--/*J~/~' ~ Area Drilling Engineer Signed Title ission use The space b Conditions~f A~pr~l, if any: ' / Approved by COMMISSIONER Approved Cop)' Returned / 2. ,g'. 8.':~ By Order of the Commission Date /2.-3 Form 10-403 GRU5/SN27 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~'' Post Office b~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 29, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2V-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on January 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU5L45-tw Enclosures Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA, tLAND GAS CONSERVATION C,_ AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-165 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21041 9. Unit or Lease Name Kuparuk River Unit OTHER E~X ~,, 4. Location of Well Surface: 2253' FSL, 166' FEL, Sec.7, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 114' RKB 12. I 6. Lease Designation and Serial No. ADL 25644 ALK 2575 10. Well Number 2V-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ]~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon - [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: January 15, 1984 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer Signed Title The spac e~o~r~/m i~si o n' u se icond .... it,~'ns of A~,oKral, if any: Date Approved by B~ LBHHIE G. Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 GRUS/SN22 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Movember 17, I983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCD Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2V-4 ARCO Alaska, Inc. Pemit No. 83-165 Sur. Loc. 2253'FSL, 166'FEL, Sec. 7, TllN, R9E, UM. Btmhole Loc. 4198'FSL, 4175'FEL, Sec. 7, TllN, R9E, b~. Dear Mr. Kewin: Enclosed is the approved application for perr~it to drill the above referenced 'well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey ~Js required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage system~ have been classified aS important for the spawning or migration of anadro~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). ~rior to co~nmencing operations you may be contacted by the ~labitat Coordinator's Office, Department of Fish and Pollution of any waters of th~ State i~ prohibited by AS 46, Chapter 3, Article 7 and the regulations pr~ulgated thereunder (Title 18, Alaska Administrative Code,-Chapter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to com~.~ncing operations, you may be contacted by a representative of the Depart~_ent of Envirovanental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to co~mencing installation of the blowout Jeffrey B. K~.~in Kuparuk River Unit 2V-4 -2- l'tovember 17, 1983 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. ~_-ere a diverter system is required, please also notify this office 24 hours prior to com~-~encing equipm~ent installation so that the Com~.ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a ~itne~s present. Very truly, yours, C. V. Chatterton Alaska Oil and Cas Conservation Commisoion be,6:H/A Enclosure cc: Department of Fish & Game, ~{abitat Section w/o encl. Department of Environmental Conservation w/o enc1. ARCO Alaska, Inc. "~' Post Office Bo.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 7, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2V-4 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2V-4, along with a $100 application fee. Diagrams showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. A diagram and description of the surface hole diverter system. ° A diagram and description of the BOP equipment. Since we estimate spudding this well on December 3, 1983, your earliest approval will be appreciated. If you have any questions, please call' me at 263-4970. rely, Engineer JBK/JG5L30'tw Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~' ALASKA O,- AND GAS CONSERVATION CO~v, MISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. Address P. 0. Box 100:360, Anchorage, Alaska 99510 4. Location of well at surface 2253' FSL, 166' FEL, $ec.7, T11N, RgE, UH At top of proposed producing interval 3909' FSL, ~5J~Q'. F.F_J_,S¢~. 7, T11'N, P. gE, At total depth 4198' FSL, 4175' FEL, Sec. 7, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. RKB 114', PAD 78' I ADL 25644 ALK 2575 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 2V-4 '?~.:, 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 736 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8258' MD, 6429' TV• feet 2467+ 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1400 feet. MAXIMUM HOLE ANGLE 47 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 2V-3 well 120' ~ surface feet 18. Approximate spud date 1 2/03/83 2711 psig@J0°F Surface 3115 _psig@ 6024 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program ! SIZE SETTING DEPTH QUANTITY OF CEMENT Hole ~24" il 2-1/4" i2-1/4" B-l/2,, Casing 16" 9-5/8" Weight 65.5# 36. O# 9-5/8" 47.0# 7" 26.0# 22. Describe proposed program CASING AND LINER Grade I Coupling H-40 / Weld J-55 HF-FRW BTC L-80 / BTC J-55 HF-IRW BTC Length 80'I 1768'! 1027 8225 MD TOP TVD 36' I 36' 35' I 35' 1803' ~1800' 33' I I 33' MD BOTTOM TVD 116' 116' 1803'11800' 2830'12700' 8258'16429' I I (include stage data) ± 200 cf 1160 sx Permafrost E 250 sx Permafrost C 391 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8258' MD (6429' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2711 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an une_q_q~_xpe~ted gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 2V-3 will be 120' away from 2V-4 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions TITLE Area Drilling Engineer DATE in the di'spos~.~rocess. SIGNED The space belo/0r/~/i;c~/ionuse / /,/' CONDITIONS OF APPROVAL Samplesre~ [ Mud Iogrequired I Directional Survey required APl number DYES ' Permit number ~ I SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 17, 1983 ~- ~ / I by order of the Commission Form 10401 --GRU5/PD08 Submit in triplicate ' ..3pO0 I. t · 6000 5000 , 't O,Ob, ,'% 200.0 1 000 _ -. 10.OO ........ TVD-~91.4 TI'ID,,.7,500 t DEP-~3g:I 0 VEST 22S3 FT. I ' ' I 17, soo ~oo - ~oo' - ~_o0' - ~oo 0 ..... ~oo · 200 ...... soo ....... I , , , !' :: !AR:CO .......... l ......... :-' ........... :PAm]?--v ~ . KUPARUK ~I. ELD,~-NO~H SLOPE. ALASKA ;- -~ .... ~0 ................ ~ --~ - ~ - '~ i--~- ': ~--~-~--~ ..... ~ ......................... . ....... ............... ~:, ., .... i : . ' ..... i ~ ~ ~ . ............. = .~ ........ ~ ........... ? ....... ~ .................................. . .............. N ...... T:': ;TFTT-;_:Z~ -!_--2_.t_:~[-_ :.' :-~ ._'__:-':_-~_.::'~":: 2_'_.' .~: ' ~_.'::,'_.'/M~: F .- - :~ - :-: -:--:':;' :-~-~~~~.__.__:_:~ ~-- '-~.-:-~7;~ -.i~ . -:-~_ - . '~,~:.:~'? ~:'; . ~'~. ~ .... '(9. Surface Diverter Si/stem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3, 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~nipple. 16" Conductor that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. Maintenance & Operation ~- , 1. Upon initial installation close annular I preventer and verify that ball valves I - have opened properly. · i 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3' Close annul ar preventer in the event 13-5/8" 5000 PSI 'RSRRA BOP sTACK t~NNUL~R PREVENTOR _ . . PIPE RaHS [,) 7 · ~DR'ILLING PiP£ RRNS TBG i - - o 1. 16" Bradenhaad 2. 16" 2000 PSI x lO" 3. lO" 3000 PST tubing head 4. 10" 3000 PST × 13-5/3= 5000 PSI , > 5. 6. 7. 8. adapter spool 13-5/8" 5000 PS! 13-5/8" 5000 PSI and kill lines 13-5/8" 5000 PS! 13-5/8" 5000 pST 13-5/8" 5000 ?SI FSI casing head w/choke ACCI3-1ULATO~ C.-Lv,t~ITT TFqT ~-IECIC ~,'D FILL ACCI~-%rLA.TOR I_E'VE1] WITH HYD?AULIC FLUID. ASSUPJE THAT A~-F~_ATOP. PP~L~..E IS ~ PSI WITH 1'500 PSI C~J~TP-~ O~SEP, YE TIHE Th?.N CLIiSE ALL trb.;iTS SL'~TA~'~- ~..'SLY ;,qD RECOP, D THE TL~'~ A-q9 ?RESSt.~..E .:~".Alli- I,~ ~R ALL L~/ITS J.~ P'~4P OFF. R~COs:~D ON IA~g¢ REPORT. L~IIT IS 45 SE~XDS CI_OSIN~ T~,E ~'O 12C~O PSI P~-vJ~INIh~ PP-~ESSUP~. - r - 13-5/$' BOP ST,LC.( TEST FILL BOP STACK ~ F~t_.~(ZFOLD WIi",-I X~C DE.EL. ~E~ THAT ~ HO~ ~ S~ ~ ~.A~D. P~D~E~I)~ DEPT~ TF~T ~ h'IE S~T A)~ S~T I~ ~U~D. ~ I~ LO~ ~N SCOWS IN H~. ~E ~C'tU~3, PR~;~R ~D C~O~ ~ ~P~S Y~V~ 0:( ~qIFOLD. ~JT ALL C~:E~S TO ~ ~Z ~0 ~D FeR IIiC~E PRESS~ TO I~ ~I ~'(D F~ ~P, lO MIIiUTES. B~ED TO ~0 ~I. PIPE I);~E-PRSSU~ TO ~ 5I' A';D H~ ~2 lO H!~J. ~E V~V~ DI~T ~~q OF B~ED ~.';(ST~( PP~%~ ~ ZERO VAiV~. T~T P~-L~)I!)~ UI~j~ F.~qIFO~ Y~VE ~;D Z~O PSI ~~~. B~ TO ~RO PSI. - ~ TOP S~ OF PiPE ~ ~ ~ I~,~E PRESSU?~ TO 3~ ~ ~J;D X~ ~D~ lO ~!!~T~. B~ED TO Z~ PSI, ~J( BOSOM S~ OF PIPE P~J. 5~ ~ .~)O TEST TO 3~ ~t F~ lO ~I~. B~ED TO ZERO PSI. ~ ~qIFOLD ~'~D LI~ ~ ~u"~ ~ DI~ ~;D ~L YALY~ ~ ~ ~( ~I~I~ T~T ~'(DPIPE Y~Y~ TO ~ ~I. T~ ~Y ~ ~D I~I~ ~ TO P~ TEST I~(F~lI~l ~ ~ T~T FO&N SIG:( ~(D S~2 TO ~I~ ~P~- YI~R. · - CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc , ................... I /"," ~ ':,:,:, (2 thru 8) (3) Admin , (9 ,'" thru 11) (4) Casg ////~/~' _ (12 thru 20) ( 5 ) B 0 PE ,/j~l'/~/ //-//~' (21 tkiru 24) (6) Add: 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line . . 4. Is well located proper distance from other wells 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore ~]?~ included 7. Is operator the only affected party ................ 8. Can permit be approved before ten-day wait ......................... o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS Does operator have a bond in force ................................. Is a conservation order needed ..................................... Is administrative approval needed .................................. Is Is Wil Wil Wil Wil Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~ · conductor string provided ........................................ enough cement used to circulate on conductor and surface ......... 1 cement tie in surface and intermediate or production strings ... 1 cement cover all known productive horizons ..................... 1 surface casing protect fresh water zones ....................... 1 all casing give adequate safety in collapse, tension and burst.. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating- Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: ~4 0 Geology: Engi~e,~,$~ing: HWK ~_ LCS !~ BE~ / rev: 12/06/82 ,- INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE '~ ~ i.. 'i., o I ',' (5 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effod has been made to chronologically organize this category of information. ,VP 010,W0P VERIFICATION LISTIMG PA(;E 1 :* RP~.!, "Mb. DER ** ~EEI~ ~'~M~ :1352~2 ~O~~S :SCHLU~RERGFR WML~., SERVICES CIISTO~ER FIEt,~ TAPE ~, Tamp WEAOER ** ~ERVTCE ~A~E : 3ATE :83/12/16 .3!~ IGT N :CSt!. r~PE ~ME :~35252 ~O~MENTS :SCWLUMREP~ER w~[~[., SERVICES CUST0~R FIELD TAPE *****~**** EOF' ********** ALLO TS 2554,5562 ( TE.T$ - ?EN~ * EXO0 DTSA. 0,0000 EX01.. DISA 0,0000 ~0~ DISA 0,0000 ~X03 D~S~ 0.0000 ,Vp 0!.0.~{09. VEPIFICATIO~' LTS?ING PAGE E~04 ~T$~ 0,0000 ZFDm l.l,.,b~ 0.0000 ZERO = 0 mm~#mm~m~mmmmmmmmm~m~ TS~tbm TS .A~m ZERO w~00 DT$~ ZFRO .AND ZERO 3~76~ ~LAR OFF 0 w~O1 DTSA Z~RO .~ND Z~m 32767 AL~R OFF 0 ~AO~ DTSA Z~RO .~ND ZERO 3?767 ALAR OFF 0 w~0] ~ISA z~Pn .A~$D Z~RO 3~767 AT.,A~ OFF 0 LCON EXP2 BEL!, V~Lt! CSlZ I~VD FNU~ FE×P FPH! RPU. $~SO AOFF RFTT ~D~P TP~ PrOD TO~T TPT UNAL IN IN 0.0000 UNAI., 1 UNAb F ~ 819~.0000 UNA~., 1.0000 UNAL P$IG UNAL 1 OK UNAI, LOG UNAL BOTH iI.,b~ I., EG~ DEG~ 140,0000 UNit., vT FT 7203,950~ I..I~!~L PST~ PSla 1,4,7000 I,,J~A5 DEGF DEGF 1,44.0000 IJNA[~ SING UNIt S S 23,9090 t.!NAt, $ S 23,3999 YP OIO.HO~ ..... vE~I.VICA?IO~'~ [,,IeTINGo. P~.~:.. ~" 3 HOaN . TOOL'. STICK ! · .AbARM. , .ALARM.OFF. VP 01. O.~40P VF. RIFICA?!OM LISTING PAC, E 4 R 'I. UNA L P 2 U ~,!'A L FT, U~ T., !! L U ~,'. A L D~F ii,AL L ~ F U ~, P I ~ U N' ~ L 082 OS 3 U ~,~ A I., 084 U,,taL 085 086 TC8 Tt~2 U~tAL T ~ 5 U ~' ~ L T~6 T ~ 7 U ~ A L TNO T~' 1 ~ $~7CT TPw~T UNAL VP 01.0.N02 V~RIFICA?IQN L.ISTI'Nf~ P~GE COUNTY 0 0 0 4:40 0,o000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 O.O00O 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0.0000 0,0000 0 0000 o~ooon o.oooo o.oooo o.oooo 0,0000 0.0000 0 0000 0~0000 0,0000 0,0000 * PgTn ~n~?~T RECO~n ** TYPE 2 SIZ~ 1 2 66 66 70 66 ENTRY 0 0 aO 1 ID or, DER ~ !~O(; TYPE CI,ASS ~QD NO. ENS RFT LB 9~ 635 ~1 0 !05 ~ SPE ~FT RPS q~ 970 Ol 0 105 2 ~P RFT PS'I'G 9~ ~.4, 0(') 0 105 4 RES PF~ PS!G og gl4 O0 0 105 ~ P~F,: ~F· PS!~ 9~ 914 00 0 105 ~ ~)1,0 ~FT O~ ~1,4 O0 0 ~.05 2 ~0 ~FT 98 ~14 O0 0 105 ~ ONE PFm qm 814 O0 0 105 2 'T~N PFT 9~ ~.4 O0 0 ~05 2 ~O ~PT 9~ ~1~ 00 0 105 2 :~ ~FT CAPI 98 310 O0 0 ~ 05 ~ P~O .,,,ESS CODE (OCT~b) 6~ 10000000000000 49 10000000000000 49 10000000000000 6~ lOlO0000000000 49 10000000000000 49 10000000000000 ~g lO000OO0000000 ~9 10000000000000 ~9 10200000000000 49 10200000000000 49 10200000000000 49 10200000000000 49 1.0000000000000 * DATA FOR~.AT RECOItD ** TYP~ STZE REPR CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 3o 4 1 66 1 5 1. 66 6 4 73 19! 7 4 65 INCH ~ 4 73 60 9 4 65 ,lIN ~.a 4 65 .lin ~5 ! 6~ 73 !6 ! 66 0 1 66 ,aT~}~ 8PVCIFTCST?ON mLOCKS I:4F~ SFRVICM SERVICE I!NTT API API APl APl FILE SIZE SPb REP~ PROCESS It) ~DER ~ ~,nG TYPF C[.,~SS ~OD ~0. CODE (OCTAL) ~TT~ ~FT ~ g~ 636 ~1 0 105 4, 1 6R 10000000000000 'E~$ PF? 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LISTTN(:~ PAGE '7 T~O ~F? 0~ 81.4 00 0 ~05 2 814 00 0 ~05 2 al4 00 0 ~05 2 al~ 00 0 105 2 ~!:a O0 0 105 ~ ~a O0 0 105 2 8~ O0 0 105 ~ ~1,4 O0 0 105 ~ tl, O O0 0 105 ~ TT~ ~.9,30.30 ~ENS RES -67fl~.0000 ~P~ ONF 7.0000 VTEa ~ 99,1875 ******** DEPTH ******** 2~10 0000 ~SPE 29,0375 -678~o0000 PD10 0.0659 7,0000 PHUN 9,0000 TI~ 241.~744 TENS RES -6560,0(}00 ~P~E 124.6~75 ******** DEDT~i FEET 7169.5000 2790.0000 MSPF 40,1250 7.0000 PHI.I~ 9.0000 ArE :~3/10/15 aXI~l,l~ GE~GTq 11024 ILE TYPF : P~ EOF ********** I 49 10000000000000 1 49 ~,0000000000000 1 49 lO000000000000 1 49 10000000000000 1 ~9 10~00000000000 1 49 ~0200000000000 1 49 10200000000000 ! 49 10200000000000 1 ~O 10000000000000 gGP 3000"0000 PP20 0,0659 PT{tO 2.0000 SGP 3000,0000 PD20 0.0659 PTHO 2,0000 ILE NA~IF j~FT E~VICF ~ :PLAY~ AtE :~3/10/!5 ~XI~T{~ T.,E~GTg 11074 IT,E TYP~ P~VloI~S FTT.,~' TS abhO 27a0 ~856 ( TENS - TMMa , 0~0000 ~XO~ OI$~ 0,0000 ~03 OlSa, 0.0000 EXO~ OTSA 0.0000 Z~O ~I,,1,0 0,0000 TYPE ZERO = 0 MNE~ STAT EXP1 LcON EXP2 TS ~,t,~ TS .A~D Z~RO 5 WTSM OFF 0 wA00 O,lS~ ZRRO .~'~t~ ZFPO 32767 ALAR OFF 0 WAO1 D,~S~ ZK~O .AND ZERO 3~767 ALAR OFF 0 3~767 AL~R OFF 0 TYPE :TDOI., Al, LO 214 708 0 ALLO 6O 87 214 ~E~ ST~T P!.I~I TUNI VA[,U ~$ U~ AT, CSIZ I~VO R L ~ PVTT TP~ P~OD TOFT TDT CVOb PLOT l,CO 1 LCO~ LCO 3 t..,COa LC05 L C 07 LCIO Lei? LC14 bet5 LCd6 LC!7 LC1 8 LC19 [,,C~O LC23 WTS~ IN IN ¥ F D~GF D~GF PSIA psta PSIG P$IG $ S S 0,0000 ! 81.92,000n ,000 PHI, IOK '140,0000 7192,0498 14,7000 144,0000 0 0000 4169g SING 4 ~000 20~ 000 PRaT HORN ,TOOI,.STICKIWg* STAT PUN ! T|JU I VP 01..O.HO~ V};.:~IVIOA?ION I,.,!S'!'I:N~ pA~[,I JO T PUNT, : TUNI VAi, U L L ~P 01,0.MO~ V~]~IFICRTIf]N L,TSTING PA.~ ,l~ F F F F F L,B/F F LB/~' F F F IjB/F F F F P, .F, GF DEGF STATE COUNTY INCL 0 0 0 440 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0.0000 0,0000 0,0000 0,0000 O.O000 0.0000 0 0000 0:0000 0,0000 0,0000 0,0000 0,0000 0,0000 ~PH Uu.AL ~ ~F,~ UN4[, OHN~ OH~M ~S tin A L 0~'~ ~H ~ ~ M S T U N ~ L 9 ~ ~ ~ D ~ G F ~ FSI l,I~ A [,, D~F D~GF ~CST ~]~,~AL DKG~ DKGF O,O00n 0,0000 0,0000 0 0000 0,0000 O,nO00 0,0000 0.0000 0,0000 0,0000 NTRY BLOCKS TYPE SIZE, PEP~ C(DL ENTRY 1 ~, 66 0 2 1 66 0 3 2 79 ~0 4 ! 66 255 5 1 66 0 6 4 73 31I 7 4 65 INCH 8 4 73 12 9 4, 65 .1~ 11 1 66 33 1. 3 i 66 !,! 4 65 ,lIN 16 1 66 9 1 66 0 ITUP SPF,.,CIFIC.ITION RbOCF$ NE~,I SERVICE SERVICE UNTT iPI iPI APl AP1 FILE SIZE SPL REPR ID OPDF~ N LOG TYPE CI,,.~8$ ~OD TIP ~FT $ g~ 636 ~! 0 106 4 ~p OFT PSIC a8 ~14 00 0 106 4 nES ~FT ~SIG 98 8~ 00 0 ~06 PRE PFT PSTG 98 81,~ 00 0 106 ~10 PFT 98 814 00 0 106 9~0 ~F~ ~a 81a 00 0 ~06 O~E FF? a~ 8i4 O0 0 106 2 T~M RFT g~ ~1~ 00 0 106 HHN ~F~ ~ ~la O0 0 ~06 2 TWO PF~ 9P C!4 O0 0 ~06 p~OcEss OCT~ r, ) 1. 68 04000000000000 I 49 04000000000000 1 49 04000000000000 1 6~ 04100000000000 1 49 04000000000000 1 49 04000000000000 1 49 04000000000000 ! 49 04000000000000 1 49 04200000000000 1 49 04200000000000 1. 49 04200000000000 1 49 04200000000000 1 49 04000000000000 * DATA FOPgAT ~FC~R~ ** :NTPV RLnCwS TYPE 3 SIZE PEP~ CODE ~ 66 1. 66 EN TP Y 0 SP~ ~FT RPS GP ~FT PSIG RES RF'T PSIG P~E ~FT PSIG D~0 OM~ PET ~!JN RFT T~n ,API ~PI APi APT FILE LOG TYPE CLASS MOD 98 636 ~1 0 1,06 98 635 ~1 0 106 9~ 970 O1 0 106 98 81.4 O0 0 9~ 814 O0 0 106 O~ ~14 00 0 !06 9~ Ri4 O0 0 106 98 ~14 O0 0 106 98 8t4 O0 0 106 9~ ~14 O0 0 106 98 81~ O0 0 !06 98 ~14 O0 0 106 9~ 310 00 0 ~06 SiZE SPL RLPR PROCLS~, 4 1 68 04000000000000 ~ 1 49 0~000000000000 2 1 49 04000000000000 4, ~,, 68 04100000000000 ~ 1 4,9 04000000000000 ~ I 49 04000000000000 ~ 1 49 04000000000000 ~ t 49 0~000000000000 2 1 49 04200000000000 ~ 1 49 04200000000000 ~ 1 49 04200000000000 2 1 49 04200000000000 2 1 49 04000000000000 * D,AT5 ** TT~ 259.4042 T~$ ~E$ 3056.0000 ~PNE ONE 9.0000 PTWM ~ 1.67.1250 ******** DEPTI,( ******** FEET ~ETEPS 65510.0000 !.9967,4492 ~534,0000 MSPF 46,1.56~ 3066.0000 PDlO 0.0669 2.0000 P~IIN 1.0000 ******** DEPTH ******** FEET METERS 6MSqS.!016 19991.2539 2460.~000 ~SP~ 59,6563 3056.0000 PD10 0.0669 1.0000 PHI{N 1.0000 SGP 3152,0000 DP20 0,0669 PTHO 3.0000 SGP 3~42.0000 PO20 0,0659 uTHO 3.0000 * FILE T~AII,E~ ** EPVTC~ WA~E E~STC~i ~ : 24.~ A~E :~3/10/15 FILE H~AD~R ** ED,SION ~: ~ AXI~U~ I..,E~CTH :1,024 R, EvToUS ~ll.~ l NF~R~ATj.[:IN RECORDS M~IE" STAT OUTP DCON . 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TI STA~' PDAT t~$2 OS 5 TLA~ T~ 7 TkO9 TOWN RaN~ NAT~ CSNT ST:AR ~I,A~ ~LD r)PEP l.,~C Tf,! STATE COUNTY I NC[, 0 0 0 44O 0,0000 0,0000 0,0000 0,0000 F. 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CODE M~!TRY 1, 1 66 0 P 1, 66 0 3 ~ 79 30 4 1. 66 255 5 l, 66 0 6 4 73 7 4 65 I~CH 9 4 65 .1..I~ !1 1 66 33 ~4 4 65 ,lin ~5 1. 66 73 o I 66 o hTt,I~ MPMCTFICIT!ON BLOCKS ~}E~ SERVICE SERVICE 1!NIT APl AP! g, PI APT WlI, E SIZ~ SPL REPP ID O~DER e Lra(; TYPE CLASS ~OD NO. :wl~ FUS ~FT SPE Gm PET PSIG 9R ~1.4 O0 0 ~07 'RFS PFT PETG On P~E Din PET 'D~O 'm~E 'TEN '~U~ P~? 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Ho2 VEn.T.F.T..CATIO~ lbT$'t'Tlv~ Pg.C,E !~ ST~T . ~ U N A b ~ ,1, R. 2 U~~ ~L C~~ U~ Uw W Y TN DPT L~TI pm~ UN~.L A~TM 0S2 084 OS6 UN TN 2 W~3 UNAI, T~.TM UN~5 · ~'5 t~ ~t.., T~*6 UN~I.., Tw7 T~'~ U~'A~, W~'lO Tw ~ 2 Uk'~5 SFC~ UNAt, Pt.]~I TUNI VAhU ST~T~ I~CL 0 0 440 0 000o 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0o0000 0,0000 0,0000 0,0000 0.0000 0,0000 0.0000 0,0000 * DATa FOR~T RECORn ** PiThY RT,OCKS TYPE SIZE ~EPP CODE 66 M ~,IT R Y 0 VP 0,0.~02 VERIFICATION LISTING ~TII~ SP~CI'FICATION BLOCKS Ir) ORDER # LOG TYPE CLASS MOD MO. TIM PFT S 98 636 ~1. 0 10g 4 SPE RFT RPS 9~ 970 01 0 108 2 gP ~FT PSIG ~ ~14 O0 O !08 4 D10 RFT 98 ~1:4 O0 0 10~ 2 020 PrW 98 ~l.a O0 0 108 2 ONE ~FT 98 814 O0 0 108 2 T~N ~rT 99 ~14 O0 0 108 2 Ht!~~ PFT 98 81~ O0 0 108 2 · uO ~F~ 98 81, a. O0 0 1.0~ 2 PROCMTS CODE I~CTAL) 1, 68 0400000 00000 I 49 0~000000000000 1 49 040000000000OO 1 62 04,00000000000 ! 49 04000000000000 1 49 04000000000000 1 49 04000000000000 I 49 04000000000000 1 49 04200000000000 1 49 04200000000000 1 49 0~200000000000 ! a9 04200000000000 l, ~9 04000000000000 * DaTa F~}~AT REC~D ** NT~Y TYPE SIZE ~MPP CODE ENTRY !. 1 66 0 2 ~. 66 0 3 2 79 30 4 1 66 255 5 1 66 0 6 4 73 311 ~ 4 73 1,2 9 4 65 ,lin 11 1 66 33 13 ! 66 1 ~a, 4 6~ ,lin ~.5 1 66 73 16 1 66 1 fl 1 66 0 ATUM TPECTFIC5TYOM RI.OC~S NF~ TFPVICF SERVICE U~TT APT ~PI API ~.P! FIT,F SIZM SPL REFR ID C~DER ~ LOG TYPE CI,ASS MOD Nfl. CODE PROCESS 1 68 oaOOOOOnO00000 VP 0...10.~';0.,? VE~IFICATIrtN !~,I.$T!NG PAC, E ~6 ps~ 90 ~4 oo o ~o~ 9~ ~4 oo o oe el4 oo o to~ o~ 01~ oo o 98 814 O0 0 98 ~14 O0 0 CAPI ~g ~10 O0 0 105 * DAT~ ** 0.~166 ******** D.EPTN ******** 65510,0000 19967,449~ 2~o oooo ~sp~ ~o~4:0ooo P~lo 2.0000 ~uu~ 0 .. 0669 1.0000 ******** DEPTH . EET ~ETERM 65580.11,?~ 19991,56~5 2404.0ooo ~,,s,~ sl.37So ]os4:oooO p~'~o 0.0660 1,0000 P~Us! 1,0000 1 49 04000000000000 1 49 04000000000000 ! 6§ 04100000000000 I 40 04000000000000 1 49 04000000000000 i 49 04000000000000 49 04000000000000 1 49 04200000000000 1 49 04200000000000 1 49 04200000000000 ! 49 04~00000000000 1 49 0~000000000000 SGP 3128,0000 PD20 0,0669 PTEO 3,0000 SGP PD20 PTHO 31~0 oo°o o:o6 ,o 3,0000 F~SION ~ aTE ~3/10/15 AXI~IIW LENGT~ :!024 I I..,E TYPE E~SlC)~ t : 2a.2 ATE ILK TYPF TYPE ~'AV'~R ST~'r EXP1 LCON EXP2 F~EO ACTI BEDb VA[~U Al, LO TS ,AND ZERO 5 WTSM OFF 0 39767 AI,~D OFF 0 32767 AL~ O~F 0 D?Sa Z~PO .AND ZERO 377~7 ~LAR OFF 0 3~767 ALA~ OFF 0 TYPE :TOOL ............................ . ......... ;----...--- ...... ,--..--.........,---...-. DTT A,[ [jO , RFT ~l,[.,O 2~4 708 0 ,qC .'r ~' AY,bO 60 87 ~14 ~BI,F TYD~ :CC, NS ~P 010.WO~ V,ERIFICATIOt~ LISTING P.t~GE 28 BNS U~t ~T, SD UMAL F~XP UMR!, ~ P I,.~ ,, UN AL S~,$O UNAL PL~ UN 11.., ~OFF U~AL ATE~ UN~L TP~ I..!N AL P~OD Ut, AL TOFT UNAL T P T U ~' .~ L fiVOL !J~~ ~ L P l, 0 T U M ~ 'L [.,COl UN II., l,.., C 0 ~ UM A L 1.,.~ C 0 ! U M A 1, LC04 UNAL LCO5 I,C 0 ~ U~ ~ L LC 0 0 LIN A L LC 10 UN IjC ~, ~ [.INA[, be ! 3 UW ~t., LC ! 4 UN L C 16 U t, ~ t, I.,C1 o UNAL LC20 5C2 ! bC23 bC24 UKtfiL AI_,~R Xt~O0 DIS~ X"Oi IN IN 0,0000 1 F F ~lg2,0000 ,0000 p, t°°°° P$IG 10K FTES BOTH DEGF DEGF 140,,0000 FT FT 7232.0996 PSIA. PSIA 14,7000 D~GF DKGF 144,0000 PSI~ PST~ 0 0000 4169§ SING 8 $ 53,0909 s s 23 lOOl HORN .TOOL.STICKING* .ALARM. .~[.,ARm.OFF. PUNI Tt!NI V~LU i~l IN 8,5000 OH~M OHMM . 1.0000 ~EET FEET F~ET SHOR ~6 STAT .... PUN! TUNI VALU SON RI R2 UNAb UNA[., w ~ U CN F L U K~ A ~,, W I T ~,~ U N A L DFT b O N G U STAT UH C 0 U N U LWF U~AL a P l N I.T ~ A L 0~2 UNAT, 083 086 VP F LR/F ? F F F F F F F F F F F F F F COUN?Y I NCL 0 0 0 440 0,'0000 0,0000 0.0000 0.0000 0.0000 0.0000 0,0000 0,0000 0,0000 0.0000 0.0000 0,0000 O,O000 O,O00n 0,0000 O.O000 0.0000 0.0000 0 0000 0~0000 VP 010,}~02 VEPiFICRTI~)~! LISTING PAGE 31 N'r~Y I~LOCKS Typ a.T[~ SPMCTFICaTTON BLOCKS ~M,~ SERVICE SW. RV!CE U~TT * D~T~ FO~T PFCO~O ** 'NT~Y mL, nC~S CODE 66 6~ 79 66 65 65 66 66 6~ 66 I .~PI ~PI FILE E CI.,aSS ~OD NO. 6 21 0 !09 5 21 0 109 0 o~ 0 ~09 4 O0 0 4 O0 0 ~09 ~ O0 0 ~09 ~ O0 0 ~09 ~: O0 0 ~0~ ~ O0 0 ~09 4 no o lo9 4 O0 0 109 4 O0 0 0 O0 0 109 SIZE CODE E N 'T P Y 0 0 0 ,I~N 1 SIZE SPb 4 1 ENTI~y 0,0000 0,0000 0,0000 0.0000 0,0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 REP~ PROCESS CODE (OCTALJ 68 04000000000000 49 04000000000000 49 04000000000000 6~ 04100000000000 49 04000000000000 49 04000000000000 a9 04000000000000 49 04000000000000 ~9 04200000000000 49 04200000000000 49 04200000000000 49 04200000000000 ~.o 04000000000000 ,~TU'5~ SPECIFICAT,,T,'ON BLOCKS ID O~D~ ~ [,OG TYPE CLASS MOD SPF PF'm PPS O~ 970 O1 0 GP ~F~ PS!C 9~ ~I, 4 O0 0 R~$ ~FT PSIG 98 ~1~. O0 0 P~E ~FT PSIG q8 814 O0 0 OlO P~T 9~ 814 O0 0 D~O PFT 98 ~ 14 O0 0 ONE ~FT 98 81,4 00 0 ~]~ PF~ 98 ~14 O0 0 T~O P~T 98 ~14 O0 0 R ~FT G4PI 98 ]),O O0 0 NO, 1,09 109 109 109 !09 ~og tOq 109 109 109 ~09 !09 109 REPR PROCESS CODE (OCTII~) 6B 04000000000000 49 04000000000000 49 04000000000000 6~ 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04~00000000000 49 04200000000000 49 04000000000000 ******** DEPTH TT~ J~.7050 TE~$ 2494.0000 RES 3072,0000 ~PPE 3072,0000 ONE 4.0000 ~T~ 3.0000 R 1.7051 iTTq 178.9058 T~NS 'RFS 3064.0000 RPRE 'ONE 7.no00 DTPN :R 151.0000 M~TERS 19967.449~ POlO 0.4990 0.0669 1,0000 6~564.2344 19983.9785 ~630.0000 ~SPF 49.9~75 ~064,0000 PDIO 0.0669 ?.0o00 P~[~, !.0000 S(;P 3157,0000 PD20 0.0669 PTHO 3.0000 SC, P 3150 0000 PD20 0",06'~9 PTHO 3,0000 LISTING PACK 33 EOF KXO ~.:X 0 STAT V~I..,U EXPR DISA 0,0000 r)TSA 0,0000 !:)T$~ 0,0000 ~S~ 0.0000 D!Sa 0.0000 aLk, n 0,0000 ZERO : 0 ABLE TYPE STAT EXP1 LCON aI, r,n ~$ .AND 5 WTS~ OFF 0 DTSA ZERn .RND ZERO 3~767 AL~ OFF 0 MODEM STAT L~NG WFIG HEIG DTT A~,50 0 0 0 ~FT Al, LO 2~ 4 708 0 SCT~ ~!.,,I, 0 60 ~7 214 CST, Z ! ~V D S~ PFTT FDEP SCSi' P~OD TOFT ~V~L PLOT ~:C01 LC0~ b('03 LC04 LCO5 LC06 LC07 bC9~ LC1O STAT PUN! 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",¥ E ~; .S T a T Pf~ %~ ~ TUN I V a LH PW ~;NAL OWMM OH~ 1 0008 Q~DU UNAL F~T Y~P Uw~U ~ VP 010.;~02 VEPlMICATIDN LTSTING PAGE 42 ~ ¥ TYPE ~HE~ ST~T PlJNI TtJfl~ VALU SON U ~ A T, ~ R ~1. U WN I)N~L F~ UNAL FL U~ F L l U N A L L, UL UN AL WTTN DFT UN~L ~,,O~n UNAL L ~ TI STAT CO[]N UN~L Pr)~w APIN UN'AL 081 U 082 UNA[, OS 3 0$4 085 UNA[, 086 U~AL TL.aB TCS UN~L TN2 UNAL T~'4 T~,~5 U~AL TN6 UNAL W~'7 UNAL TN~8 UNAL TN 11 UNAL TN 1 ~ UNAL SFCT TOW~ VP 010.HO2 VERIFICATION LIS?lNG PAGE F F F F F LB/F F F LB/F F F I,,B/F D~GF $ C3 OHM~ D~gF D~GF F F F F F LBtF F F F F F F DECF LB/~ C3 OH~M OH~ DFGF STATE COUNTY INCh 0 0 0 440 0 O000 0 0000 0 0000 0 0000 0 0000 O 0000 0 0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0 0000 O:OOOn 0,0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 VP OJ[O,HOP,, YE~ITICI'~IclN LI$?INC,, PlG~ 44 ATIt~ SPEC.T,.FTC 4T ! O{~i T]~ PFT GP ~Fm ~FT ~FT ~FT HU~ ~ ~FT 1 2 4 ? 11 0 PSIG ! 66 i 66 ~ 66 4 65 66 4 65 ~ 66 66 LOG TYPE g~ ~70 9~ 814 O0 0 q~ ~14 O0 0 98 ~4 O0 0 Ill q~ ~1,4 O0 0 111 9~ ~la O0 0 ~1~ * DATa FOR~T RMCO~D * ~ITRY BI,OCKS TYP ~Z~TI)~, SPMCTFTCnTTrD~,! 9 11 13 1,6 SIZE REPP CODE 1 66 1 66 2 79 ! 66 1 66 4 73 4 65 4 73 ~ 66 1 4 65 ~ 66 ! 66 ENTRY 0 c) 30 0 311. ,lin '73 1 0 SIZE SPL REPR CODE 4 1 6a 9~ I 49 ?.. 1 49 P I 49 2 1 49 ~ 1 49 ~ 1 B:MTRY 0 0 3O 255 0 INCII , 1I~1 33 1 1 0 PROCESS (OCTAL) 04000000000000 04000000000000 04000000900000 04100000000000 04000000000000 04000000000000 04000000000000 04000000000000 04200000000000 49 04200000000000 04200000000000 49 04200000000000 49 04000000000000 VP O~l. 0,~(}2 V~:}]F]'C4T!0N Y.,!]STING PAGE 45 T~ SPE ~T ~P ~F? PSIG 9~ RES ~FT PSI~ 98 PnE ~FT P$IG ONE ~FT 98 T~N RF THO R ~F'T GAPi 98 Apl lPI A TYPE CI~IS$ 636 635 970 01 ~1~ OO 914 O0 81~ O0 ~14 O0 81~. O0 ~14 O0 814 O0 ~4 O0 ~,4 O0 310 O0 PI F l 1,,,, E SIZE [.) 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CATIO~'~I [,ISTI~G P~E 46 ~X03 DI~A 0,0000 E×04 D~SA 0,0000 ~!E~ ~TaT EXP1 LCON EXP2 rR~O aCTI BELL VALI,! 5 WTS~ OFF 0 ~AO0 D~S~ Z~PO .A~D Z~O 37767 AL~R OFF 0 waOl DTS~ Z~PO .~D Z~O 3~7'67 AL~ OF~ 0 wAO~ ~YS~ Z~R~ ,~D ZE~O 3~767 ALAP OFF 0 3~767 ~L~P OFF O ABI,~ TYPF :TOOl, nTT, ~T,LO o. 0 n PFT ~I,,LO 214 70n 0 S~T~ A!,L~ 60 P7 214 VP OlO.H()2 VERIFICATION LTS~'ING PAGF, 47 ~ S 1'. NVD RFTT TPR~ SCS~ TOFT TPT CV~L PLOT LC01. l, C 0 ~ LC03 LC04 LC05 L C 06 LCO7 LeO0 ~,ClO LC1 ~ LC 16 LC!7 LC 1 ~ LC 1 ~ LC20 LC22 LC2~ !,C24 WTS~ ao~,~ U N A L U ~! A L U~AL U ~,! A L UNAL {.I M A U M l L U ~,t A L UNAL UN ~L U N l L U N A L U N A t, UNAb UNAL UNAL UN~b UNAI, [INA[, UWAL UNAL U~a!, U~'AL UNAL ,n l,bO OPMM I'N IN 0,0000 1 F F 819~,0000 ,0000 2,0000 10K FTE$ BOTM DEGF [..EGF 140,0000 WT FT 7362,0000 Pgll PS,IA 14,7000 D~GF DEGF 144,0000 DSlC PSIG O 0000 ' 4!69~' S S ~8 0210 S S 2)'0909 HORN .TOOL.STICKING* .At, ARM. .hLAR~.OFF. X~O0 r)Is~ PUNT TUNI vhbg TN I~ B, 5000 1+oooo F~K ,,. F~ET FEET ~2 STAT [ I,,~ i'1111 Ill,Iq i_,. [:~ i .. VP 0!0 HO2 VE~IFICA?IO~T I.lI¢--'Dl.~I(; P~gE 49 · ~ · 0S6 TLA~ ?.C.~ TN9 T~?IO CS2 ~S 3 HLD L U ~ I, cC aLI TLI CBD1 C~L ~. CW 2 CPO2 F F F F K F F F F F F LB/F F LBtF F BT.ATE cOUNTY 0 0 0 440 0.0000 0,0000 0,OO00 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 O.OO00 0,0000 0,0000 0.0000 0.0000 0,0000 0,O000 ifP O~.O,HO~ VER,!,:W~C~TION I, TST~N~ PA~E 50 NT,~Y Bt.,OCK 8 1, 1 66 ~ t 66 5 ! 66 6 4 73 7 4 65 8 4 73 9 4 65 11. 1 66 13 1 66 14 4 6~ ~5 ~ 66 ),6 ~ 66 ~T{!U SPECTFIC[TyON BLOCKS ID O~DFR # GP PFT 'R~S PFT PSYG 'ONE ~FT 'TFN PFT 'HUN ~FT 'TUO AP! gPI ~Pl APl LOG TYP~ CLASS 98 636 ~1 0 98 635 21 0 9R 970 O~ 0 9~ ¢14 O0 0 98 814 O0 0 08 8!4 O0 0 98 ~14 O0 0 ~ ~14 O0 0 g~ 814 O0 0 98 ~1a O0 0 98 ¢la O0 0 98 8~a O0 0 O~ 3~n O0 0 ENTRY 0 0 30 255 0 311 INCH ,lIN ! .lin 0 FILE SIZE 112 4 ~12 2 1 112 2 1 112 2 1 112 2 1 ~17 2 1 112 ~ 1 !17 112 2 0,0000 0,0000 0,0000 0,0000 0 0000 0~0000 0,0000 g,O000 ,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 REPR PROCESS CODE (OCTAL~ 68 0400000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 O&O00000000000 49 04000000000000 49 04000000000000 4:0 04000000000000 49 04200000000000 49 04200000000000 49 04~0000~000000 04200000000000 49 04000000000000 , IJaT~ F0~M~T RECORD ** ~TwY BLOCKS TYPE 2 5 6 7 9 !.]. 15 ~6 0 CODE 66 66 79 66 ~6 7~ 65 7~ 65 66 69 65 66 6~ 66 l~l]~ SP~CIFTCATIOM BL~CKS TI~ ~FT S E~!S PF· LB 'RFS ~FT PSIG P~E PFT PSIG 'D~0 ~FT 'D~0 PF~ 'T~N RFT 'HUN ~FT '~uO ~F· API API ~PI TYPE CLASS 9R 97O g~ ~14 o0 9~ ~ O0 9~ ~14 O0 98 8~4 O0 ~8 814 00 98 814 9n 81~ O0 g$ 814 00 g~ ~1~ O0 9~ 3!0 O0 AP1 FILE MOD NO. 0 0 112 0 112 0 0 ~12 0 0 11~ 0 112 0 ~,1~ 0 ENTRY 0 0 ~0 255 0 311 INCH ~2 33 1 .lIN ! 0 SIZE 4 2 2 2 2 49 49 6P 49 49 PROCESS OCTAI,~ 0400000,~00000 04000000000000 04000000000000 04100000000000 04000000000000 04000000000000 49 04000000000000 49 04000000000000 49 04.200000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04000000000000 DATA ** ITI~ 16.~460 TEB~S ,RES 3{4n.0000 ~P~E 'ONE 9.0000 PTEN IR 1.o679 181.24S9 3132.n000 5.0000 1.67.3750 ******** DEPTH FEET 65510.0000 ~590.0000 3~40.0000 9.0000 ******** ~ETERS ~9967.4492 PP~O 0.5928 0.0669 1.0000 ******** DEPTH ******** FEET ~ETERS 65565.6563 1,9984.412! 2544.0000 ~SPE 48.9687 313~.0000 PD10 0,0669 a.oooo P~ll~ 1.0000 SGP 3222.0000 PD20 0.0669 PTMO 3.0000 SGP 3218.0000 pn20 0.0669 OTEO 3.0000 ILE TYPE A, RI,,.W TYPE TYPIC : XPF uNM~ STAT VSLI.! 5:XPR TS at,t,n 2544,5.4~ 7 ( TFNT~NS - . ~. * FXO0 [)ISA 0.0000 ~01 DTSA 0,0000 ~XO? DTS~ 0,0000 ~wn3 r~!8~ 0,0000 ~%0~ 97SA 0,0000 zFRn ~I,bO O.O~OO ZERO = o !~00 D~S~ Z~RO ,~D ZE~O 3~767 ~L~ OFF 0 W~0! D.Y$~ ZERn .,AND ZERO 32767 AL.~R OFF 0 w~09 DIS~ ZERO .~n ZEgO 3~767 AI,~R OFF 0 WA03 D?S~ ZERO .AND ZERO 32767 Al, AR OFF 0 TYPE ~FT AL[.~ ~14 708 0 $CT~ A[,.,L~ 60 87 214 C$1.7., YJNAL IN ! N 0,0000 I~VD UNAL 1 SD UNAY., F F 8192,0000 FMI, I~ UNIL 1,0000 F~YP I.I~AY, 2.0000 RPU ,JNAL PSlG ,SGSO UNAL 10K ~ I.,~' UNAL FTES ~OFF UNAL BOTH ~FTT A !,,LO DEGW DFGF 140 0000 rDEP ~NIL FT FT 7370~ 049n AT~" UNAL DEGF DFGF 144 0000 TPRF LI ~ l l., PSIG PSIG 0 0000 SGS~ UNAL 4169~' TOFT U~'AL S S 21. 3450 TDT UMA[, S S 23,09gq cvor, UNAL PRET PLOT UNAt, HORN [,C 0 ] UNAL LC02 UNAL l,r03 U~AI, L, C04 UNAL LCO~ UWAL Lc06 UNAL LC07 T,~ng UNAI., .a~lw 'r¥'PE :CONS · TOOI,.STICKING* . A I.~AR ~. · aI,AR~..OFF. T PUNT TUNI T PUNI TUNT VALU l., IN IN R,5000 [., O~ OH~M 1 0000 %, F~ L FRET t, F~ET !,, $~OR L ~3 L 12 T.., 16 STAT PUNT TUNI VALU UNAL U~AL STAT PD,~T TLAB TCS T~ 3 TW4 T~ 5 TN6 T~37 ?~ 9 TNIO SFCT T~WN ~JATI ~FSS ~T ~ ~]L Ll.i N STI%TE INCL 0 ii:-] i[~ [;-1 ~ YP Ol.O.H02 VERIFICATION LISTING PAGE 56 L C C U N A b B L I U ~ A L F F TL 1 U~ A L F F ~PD U~ A l,,., F F EKB UNAb F F ECL UN.I!., F F T P D U N A ~., F F T D L U ~ a ~., F F CW 1 UN A L LBI F I,,Bt F B~D ~, UM ~L F F C~91 UN AI,, F F C~I,~ l UNAL F F CW~ UNAL LB/F LB/F ~8D~ U~'AL 'F F CRL2 U~At, ~ F Cw ~ UNA[, [.., B / F" ~,S D ~ UN ~ I,, F C~ D 3 {,~ AL F STE~ UN~?., DEGF DEGF ~R'r UN ~L DEGF DEGF DFV UNAL S S R~S UNAL [)HMM t~ST UNA!, O~GF DEGV ~CST UK'AL DWG~ DEGF 0 0 0 0 0 0 ,0000 ,0000 ,0000 ,0000 ,0000 0,0000 0,,0000 O,gO00 O. 000 0 '0000 O, 0000 0,0000 0'0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 g:ggOOoo 0,0000 0,0000 0.0000 0,0000 0,0000 0,0000 0,0000 0,0000 0,0000 0.0000 0,0000 0,0000 * DATa FORMAT RMcnRD ** NTPY ~LOCKS TyPM 2 5 7 ~4 !5 16 SIZE 1 ! 4 1. 1 REPR CODE 66 66 79 66 66 73 65 73 65 66 65 6.6 66 ENTRY 0 0 ~0 255 0 INCH ,~IN 33 ,~IN 7] VP OlO.~O~ V'KRTtrI:CATTON LT, STIN'G PACE 57 0 I 66 0 ID SPF', ~ES O~O PFT O~O OMF~ ~FT T~N PFT HUN THO ~FT ORDER UNIT API LOG PSIG g8 9~ TYPE CLASS MOD MO. ~lal O0 0 ~13 ~14 O0 0 11] ~14, O0 0 1.13 8i~ O0 0 113 914 oo o 113 ~1,4 oo o 1,13 ~1,4 O0 0 914' O0 0 ]l,O O0 0 Tn O~D~R # PST~ ~STC almI AP1 API APl APT I,oG TYPE CLASS ~OD OS 636 21 0 9~ 635 ?1 0 9~ 97O O1 0 O~ ~14 O0 0 9~ o!4 O0 0 O~ hi4 O0 0 O~ ~14 ~n 0 On n!4 nO 0 q~ 814 O0 0 q~ old O0 0 98 ~14 OO 0 9~ 814 oO 0 98 3~0 00 0 ~TTM 'ENS PFT SPE PFT '010 'D20 'O~E 'T~' '~I.JN PFT 1!3 ~13 t. 13 .!13 113 SlZ E SPI, 4 4 4 1 2 2 ,4 2 1 ENTRY 0 3O 0 31.1 INCH 1 , lIN 1 0 SPL ! 1 !. .~. ! ! 1 1 ! ! 1 REPR PROCESS CODE COCTAb) 68 04000000000000 49 04000000000000 49 04000000000000 68 041.00000000000 49 0400000000~000 49 0400000000 49 04000000000000 a, 9 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 4:9 04200000000000 4,9 04000000000000 REPR PROCESS CODE (OCTAL) 6B 04000000000000 49 04000000000000 49 04000000000000 68 04100000000000 40 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 40 04200000000000 49 04000000000000 L~l~ i!lli! ~I:-I }l'= [:4 i 'TIM 225.7187 TENS ~,~Es 3~,~9. oooo ,o,~ ~,:oooo ~T~ ~,~ 16~.3750 ******** D~lPTH FRET METERS 655~0 0000 1, g967.44~ ~54.0000 MSPE .... 0.3740 3~ 40:. O()O0 POlO 0.0669 0.0000 PHU~ 2.0000 ******** D~PTH FEET 655~n.9922 19989.0859 , 2560.0000 ~ISP~ 45.3750 ~130.,,0000 PBIO 0.0669 0,0000 PHIIN 1.0000 SGP PTUO 3226.0000 0,0669 3,0000 4,0000 3210.0669 3.0000 'ERSION ~ ~,~TE :83/10/15 'II, E TYPE ~EXT FILE U.A~E VP OIO*T~O~ VE';P~iFIC~TI~N LISTING PAGE 35252 * T~PF HEADER ** ERVICF Nh~E :FDIT ATE :~/01t10 RIGIN :0000 REVTO~$ TAPE O~N~NTS :LIBRARY T,~PE ********** EOF ********** * FILE ~E~DMR ** ~T~ ~ AXI~I,.I~ LCN~TH t 1024 ILE TYP~ N : ~RCO AT.,ASK~ N : ~V-4 N ~ Kt!P~RUK ()WN: ECT~ 7 OUN: NoSLOP~ TATt aLaSKa TPY: lisa U~!IT TYPE C~,TE SIZ~ Ci]DE oho 000 016 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 OhO 002 065 000 000 008 065 000 000 006 065 000 000 004 065 VP 0~O.HO~ VERIFIC,~,TION [,!ST,tMG P,~C~F 2 AL~SK~ CO~P!JT ~' ************************************************************************************** OMP~NY ~ ,~TI,~,MTiC RICHFI~bD COMPANY ~LL = 2V-4 T ,~ T ~7 = A [,, A, S K A DP: S. ~ARSH,ALB AMING = 0,625" 9 311,8' - git SIZe% = 8.5" TO 76~2' YP~ FLUTD = Kwsl'rY = lo,~ ~,,[:I~ ~ = 3,6 a 7~,o DF ISCOSITY = 40,0 S R~F = 3,9 O 73.0 DF H = 1~.0 ~C = 2.7 S 73.0 DF LUID t.,~}S8 = 5,9 C3 R'~ AT }%HT = I, ,. 907 ¢ 144,0 DF ****************************************************************************** VP OlO 1'~O~ VE~.I, ICSTIOM' LISTING P~.GF 3 is, O(., ~NC[,.,I]DED WITW T[tiS ~aGNETIC TAPE,* * S C ~:~ L U ~ B ~ G L R S DI.I~L !MDUCTI~N SP~ERIC~.LLY FOCUSED LOG (DIL) * FO~ATION DENSITY CO~PENS.ATED LOG (FDN) * COMPENSATED NEUTRON LOG (FDN) , MT~Y ML~CK$ TYPE SIZM PEP~ CODE MMTRY 4 1 66 1 ~ 4 73 60 9 4 65 ,lI~ 0 ! 66 0 SpeCYFYC T ON nOCKs EpT ID ORDER # FT LOGO TYPEo CI.,~SSo ~ODO MO.O 4 [.,EYELO ~ CODE 60 FLU DIL OH~E 7 0 0 0 0 4 0 1. 68 LD DIL O[q~g 7 1~ 46 0 0 4 0 1 6~ vp 010.HO2 VERIFICATt0~ LISTING PAGE 4 P DI L 'MV 7 R D I L G ,h P I 7 PHI FD~t P{,l 42 CML FDM CPS 42 CM[~ FDN CPS 4~ ALI ~DM I~ 4~ RAT FDN 42 R FD~,~ GAPl. 42 * DATB, ** ~PT 7701.. o000 SFLL! P... ",26, ~81. 3 ~t~ HOB 1. ,9443 NC~5 R~T 3.06~5 EPT 7700. 0000 P, -26 5469 NOB ~,: 9443 MCML s:p 7600. oooo p .16,.sooo HOB 2.47~7 7 oo, oooo P. 20.5000 P, -26:oooo qOB ~. 3906 ~T 3.1699 ~iPT 7300.0000 SFLU P, -32.~000 ~R NOB ~.. 414 l NCNL ~T ~. ~359 EPT 7~On,OOnO P -6~.0000 RaT ?.R633 EPT 7100 . nO00 SFI,[.I P -3~.7500 HOR ~, a063 ~CNL ~: 0 0 0 31 32 0 0 68 2 0 0 44 0 0 0 35 1 0 0 34 92 0 0 34 g] 0 0 2~ 3 0 0 42 I 0 0 0 .0 0 0 31. 32 0 0 2,98O5 35.2500 3 ,. 50O0 653,3359 ~.. 9805 35, ~500 ~;53 .. 5000 3.3359 3,502O 104,,6875 24.42, 3,181.6 3.0176 1,10.81,25 2086. 0000 3.9355 3.8223 J09.7500 2158.0000 3,5664 3.8457 99.81~5 2570.0000 3.0!~5 .~ 43.~750 5~.4375 pal?.OOOO 3.1816 ~.4'707 1.4.'1,0000 11~9~.0000 3.96~9 ~tPH I IbM NPHI FCNL NPHI FCNL IbM NPHI FCNI., NP~! FCNL NPHI FCNL GR . 35. 195. 35' 2. 37. 195. 35. 767, 104. 2. 45. 530. 11.0. 3. 37. 605. ~.09. 3. 3~. 851. 99. 70. 31. 75R. 5~. 46. 47~. 143. 502O 5957 875O 2500 5020 1094 8750 2500 3965 5000 6875 4063 5078 0000 81.25 2500 2559 0000 7500 5371 ~5~ 0000 8 !..~5 onoo 44'~3 0000 4375 16~1 4355 750O 0000 CAL! CALl I LO DRMO C~bI ILD,, DRHO CaLl ILD DR~O CAl,.,I CALX l 1.,~ DRHO CaLI I I 68 1 68 1 68 I 68 1,, 68 1 68 1 68 ! 68 1 68 8.5000 .2'4102 -0.2827 7,3594 3,1,797 0.0244 ~.539~ 0.05~ 0.0{95 8.6953 3.5273 0.0~8! 8.73~4 59.8750 0.00~8 8.83~9 2.1465 0.0278 9.3203 .... c .... .C, P~Gg 5 :P OiO,H02 V~;PTFTCAq'IO~~ l,!,;,TIt," ~P'r 7000. 0000 > -45.5000 :'~OB 2.3809 ~: A'I.' 3.68.16 ~N~A ~,, 40,. ~500 -~99. 2500 -999. ~500 ~;P~ 6~00. 0000 gF[,U P,~, 51.0000 -999. 9500 NCNb -990. ~500 .~;PT 6700. 0000 SF[,U P 53.7500 FlOR -OOO,, ~500 R~T -999.~500 -s,... soo ~PT 6500' 0000 SFt, tI p -53,5000 NOB -099, ~500 RAT -990.2500 RNRA EPT 6400'0000 S~I.,[! HOB -999.~500 ~CNb RAT -~99.~500 EPT 6300,. 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OOOn p -73,0000 HOB -~99.9500 4. ~ 477 224,3750 NPH'! 41os47 .... 4,3750 ~'JPHI ~99~.~500 '999.~500 ,. 3, 1367 188, 0000 -999, ~500 "999,~500 GR 3.7734 -999.9~00 FC~I, -999,2500 GR 3,81 ~5 '090.2500 FCNb -999.~500 !0~.~750 -ggg,2500 FC~II, -~gg.~500 '147.. 5000 NPHI -99~.~500 -999.~500 3.05~7 I 1,,,~ 1 49.. ~750 -999,~500 FCNI, -99~,~500 2.9844 ~ 05. 8750 ~PHI '999. ~500 FCN!., '999.9500 4.4648 9~.a375 '999.2500 FCN[, -~99.~500 3.550a ll~U 130.7500 -gOq,~500 FCN[, 3"06~4 45.,8984 454.000O 224.3750 1.~..6436 -999,2500 '999.,2500 214,3750 2,9629 -g99,,2500 -999..2500 1,88.0000 3.1934 -999,2500 -999.2500 !,30.3750 , 3"5977 999,.:~500 -099.2500 1.11.3125 3.5059 -999.2500 -999.2500 10~.3750 3.3!,05 -999,2500 -999,2500 147,5000 2.8633 -~99,7500 -999,~500 ]~9,8750 3.2539 -999,2500 105.8750 4.~47~ -999.2500 -999.2500 99,4375 3.2~13 -~99.~500 -999.250n ! CALl I I,,,P CALl I LD,,. DRHO OReO CAbI D R H 0 C A [, I DRHO CALl IbD. DD I,t[3 C~bI DRHO CA[,I 1 I,,.!9 DRHO CALl T DRHO C~[,I ,3,.1.055 0.0203 9.06~5 1.4963 -099'2500 9.1:0t6 2,9863 -999'2500 9,5391 3.2207 -999.2500 9,9844 3,6.406 -099',~500 9.9609 3.,3~09 -999,2500 9.8281, 3 3633 -9992~500 9,3984 2,8867 -999,~500 10,351.6 3.3125 -999.2500 9.921.9 4.2422 -999,2500 9,7656 3.29R~ -~99,2500 -999.7500 -09.9,2500 .F.;P T 5900. 0000 ~FLU P - 65 ,. 0000 RAT -999.~500 ~PT 580o.o000 ,$FL!J P., -76.5000 -~99.~500 5700. 0000 SFLU -990.2500 NCNL EPT 5600,.0000 P., - 65 ,. 1875 ~,tOB -999, ~500 ~ICN 1,, ~AT -999,2500 ssoo'.oooo P. -70. 7500 ~.t 0 B - o 9 O, 2500 ,t7. -99g.~500 PNRA EPT 5300.0000 p., -74. ~500 qR ~PT 5200. O000 P .... 7~.5000 HO~ -999. ~500 ~ICNI, ~T -99~. ~500 5!00.0000 S Fl,l.J -74.~500 -999. 9500 NCN[, -~99.~500 P~RA p -76.0000 ~OB -099.~500 PAT -099.~500 -76.7500 -909"2500 2.6@55 l, 49.,7500 - O 99.2500 '099, ~500 3. 5938 :goo. soo .ooo. 2soo -999. 2500 2:.2168 ~ 20.. ] 750 :990,2500 goO' ~$oo -gg9, ¢500 -999,~500 2' 7656 ~. 07,6250 -999. 2500 -~99,2500 , 143,7500 -9oo,2500 2'.7734 I 1 ~. 3750 9. 5469 J a~. 3750 -999.~500 ?"4531 i ~7.1250 -00~.25o0 ~.64~4 J. 25.25o0 -999.2500 - 9 9 9 . 25 0 0 D R l'.~ 0 -999.~500 C~LI -099,2500 -999,2500 I:)R k~O -999,2500 CALl -999,2500 3 .. 6 83 6, :T L D. -999,2500 DRHO -999'2500 CALl -999,2500 1,9990 -999,2500 -999., 2500 . 999.5500 ~,7520 ILO, '999°2500 DRI40 "'999. ~.500 CALI -999°2500 2.72~7 -999. 2500 DRHO -999,2500 CALl -999.2500 2.6.172 -goO. 2500 DR}~O -999.,~500 CALl -999.2500 2,61.52 -099.~500 DRFIO -999 . 2500 C.t~ [, I -999.2500 2.6387 ~LD -099 · 2500 -999.2500 CALl -099.2500 2.5273 -999. 2500 DRUO -990.7500 C~I,I -gggo~500 ~..7441 -099. 2500 DRHO 2.51t7 -999.25on -999,25oo 9.99 · zsoo -999.25oo 3, 8965 999, 500 2.0840 -999..2500 '990,2500 2.84,1.8 999.2500 2999.2500 -999. ~500 -990.2500 2.7422 -999~2500 -999.2500 2.690? -999.2500 -999.2500 2.7559 -999.2500 -~99.2500 2 6270 -99012500 -999,2500 2.9160 -909.2500 :'~ ill iii il:-] D-ti Vp 01.0.HO~ VF..PIFIiCATIf}N LTSTING PAGE 7 !.! i,,I B -999' ~500 NCNb RAT -999. ~500: 480o'. 0000 -77,5000 -999. ~500 SPT 4700.. 0000 P -7~.5000 GR HO~ -999.9500 RAT -999.~500 RNRA EPT 4600~. 0000 P. -20.~500 ~OB -99~.. ~500 NCNL RAT -999.~500 RNRA EPT 4500. 0000 SFI,,U P,. -I9,5000 GR HOB ~999, ~500 MCML R~T -099.~500 EDT 4400.. 000() SFLU HO~ -999. ~500 MCML RAT -999.~500 RNRA EPT 4300' 0000 P., -23. 5000 GR HOB -999.~500 NCML RAT -999,2500 RI~R l EPT a~00,0000 P. -24,5000 GR H~B -099. PSO0 ~C~'b RAT -999. ~500 EPI' 4iO0.OOnO SFLU P -27.0000 ~ -999.2500 NCNL R~T -99g.~500 a000. n0n0 HOR -999.~500 RAT -99~, 2500 -~3.2500 -Og~. ~500 ~DT 3~00.0000 -egO. 2500 '999,2500 OR 2,544'9 1,06.5000 '999,2500 FCML '999, ~500 GR 106..3750 NP~I -999.~500 -999.~500 ', ~ ~ ... -999~500 5'C51 -999.~500 105.4375 ~PHT 'q99,. ~500 FCNL -~90.~500 110.. 6875 -999, ~500 -999 . ~500 105,, 5000 NPHI 3' 7246 85.56~5 NPHI' -99~.~S00 -999. ~500 -999. ~500 3,13~ 99.6~50 -99q. 9500 FCM[, -999.~5o0 3.791 0 -999.~500 3.O41 0 l[.,~ -999.2500 -999.2500 -999.2500 -999,.2500 -090,2500 3'0996 -999.~500 -999,2500 -999,~500 . 2,..4043 -999.~500 -999.~500 -999,2500 2.6387 -909.~500 -~99'2500 . 2'.6250 999,2500 -g99,~500 -999.~500 ~,9375 -999,2500 -099,2500 -99g.2500 3.9043 -990,~500 -~99.2500 -999.~500 4.1~9 -999,2500 -999,~500 -999,2500 3.1172 -~99,2500 -999.2500 -999.2500 3.1660 -999.2500 -q99.~500 3.0137 CA5I I ORHO C~bI ORHO CALl I bO DR}lO CALl t OReO C,A i.,, I DRHO IL, D ORHO II, D DRHO C4I, I lbo DRHO C~[.,T I LO DRHO CALl I I,,O -999,2500 . 2,63~7 -999.,2500 -999,2500 3,1172 999.2500 2 99. soo 2,5332 -999,2500 -999,2500 . 2.,79~B .999,~500 999.~500 2'.eo~6 :999 2500 99922500 3.1328 -999,2500 -999,2500 ].glgg -999.~500 -999,25o0 4.6563 -999 ~500 -99 2 $oo 3.4043 -999.2500 -9q9,~500 3.5273 -999,~500 -999.2500 3,31R4 ....IP O.IO',HO~ VERIF!C~TI[)N I.,ICT~SG,.~ PAGE ~PT ~00. 0000 SFLU -999, ~500 3600, nO00 -999. ~500 ~,!CN L 3500.0000 SFI,,U -31. ,7500 -999. ~500 NCNL -999,~5~0 3400' 0000 -999.~500 NCNL -999.~500 3,300'. 0000 -26.7500 -ggg, 2500 NCNL -999.2500 EPT 3~00 0000 .... FLU HOB -999. 2500 ~!CNL RAT -999.2500 ~PT 3100. 0000 8FLU P 23.4844 GR ~PT 3076.00o0 P 26.51.56 gOB -999. 2500 RIT =999. 2500 -999. 2500 FCN !., -999.2500 115.4375 NPHI .10t.5000 NPHI ~99.. ~500 FCNL -999.2500 . 99.0000 999. ~500 FCNL -g99.~500 GR 4, 0156 8~:31~5 NPHI -999. 2500 FCNL -999.2500 7.1719 7~.B125 ~PHI -999. ~500 FCNI, -999,~500 47., 96~7 ~iPHI -~99,2500 FCNI. 2000,0000 50.~750 -g9~.~500 ~C~IL -ggg.~500 -999,~500 -999.~500 4,0~34 -999,2500 ~g99.2500 '999.2500 '999 2500 '999'2500 ~999,~500 ~,,4844 '999,~500 '999,~500 '999,~500 , 5,1680 -999,2500 -999,2500 -999.~500 -99~.4648 . ,~500 ~999,~500 -99~,2500 7,6680 ~99~.~500 -999.2500 -999,~500 2000.0000 -999,2500 -999.2500 -999,2500 2000.0000 -999,2500 -999.2500 -999.2500 CALl ILD. D R H 0 C A L ! I LD, OReO CAI,,! CA5i DRHO CAI,,! D~HO DRHO ILO, DRHO CAbI IL~ DRHO CALl -999,2500 -999,2500 4,5352 :099,~500 999,~500 4,3750 -999,~500 -999,~500 8.~1,.41 '999, 500 '999,2500 5.8281 -999,~500 -999,~500 5.23~3 :999.2500 999,2500 8 492~ -~9922$00 -999.2500 10,5234 99~2500 32.7813 -999.2500 ~.91.41 ., :84101110 ~I(;iM 10000 3NTI'NUAT~ON ~ :01, ~RV,.T CE ~,t A ~,~ E :MOLT EF, T.., N'~,~: ,, : 135252 3NTINI. IAT~ON ~ ~MENTS :[,,I~RARY TaPE ********** EOF ********** ********** EOF **********
