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Home My WebLink About182-116MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-17 KUPARUK RIV UNIT 1E-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 1E-17 50-029-20793-00-00 182-116-0 W SPT 5966 1821160 3000 1985 1992 1969 1984 280 430 430 430 REQVAR P Sully Sullivan 6/3/2024 MIT-IA to 3000 psi per AIO 2c.047 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 1E-17 Inspection Date: Tubing OA Packer Depth 910 3310 3200 3195IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604103817 BBL Pumped:2.2 BBL Returned:2.1 Monday, July 22, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 99 9 9 9 AIO 2c.047MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2024.07.22 15:06:39 -08'00' 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 _1E-17 50-029-20793-00 182116_1E-17_IPROF_16Jan2023 _1E-20 50-029-20895-00 183005_1E-20_LDL_10Jan2023 183005_1E- 20_PlugSettingRecord_20Aug2023 183005_1E-20_PPROF_29Sep2022 183008_1E-20_RBP_25Feb2023 1F-06 50-029-20820-00 182145_1F-06_Perf_11Jul2022 182145_1F-06_TubingCut_20Feb2022 1G-09 50-029-21001-00 183124_1G-09_IPROF_01Jun2022 1G-103 50-029-20824-00 219110_1G-103_RSTWFL_09Nov2022 1G-11 50-029-21008-00 183131_1G-11_LDL_31May2022 1G-13 50-029-21016-00 183140_1G-13_LDL_09Jul2022 1H-102 50-029-23580-00 217097_1H-102_PPROF_02May2022 1H-103 50-029-23593-00 218003_1H-103_PPROF_06May2022 1H-109 50-029-23595-00 218013_1H-119_IPROF_02JUL2023 3of 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 T38329 T38330 T38331 T38332 T38333 T38334 T38335 T38336 T38337 T38338 2/29/2024 _1E-17 50-029-20793-00 182116_1E-17_IPROF_16Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:29:27 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-17 KUPARUK RIV UNIT 1E-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-17 50-029-20793-00-00 182-116-0 W SPT 5966 1821160 3000 2506 2507 2483 2463 150 300 300 300 REQVAR P Austin McLeod 6/4/2022 MITIA to MAIP. AIO 2C.047. 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 1E-17 Inspection Date: Tubing OA Packer Depth 970 3300 3200 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605184254 BBL Pumped:2.3 BBL Returned:2.1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9AIO 2C.047. James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:26:29 -08'00' MEMORANDUM State of Alaska Permit Number: 182-116-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg --) I /1 1<1 �1, DATE: Monday, June 8, 2020 P.I. Supervisor X21 iY SUBJECT: Mechanical Integrity Tests t/( 1 Conowl?bi8ips Alaska, Inc. Well 1E-17 FROM: Austin McLeod KUPARUK Rry UNrr IE -17 Petroleum Inspector 5966 'Tubing Src: Inspector 2573 ' Reviewed By: 2566 PX Supry1�jb NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IE -17 API Well Number 50-029-20793-00-00 Inspector Name: Austin McLeod Permit Number: 182-116-0 Inspection Date: 6/72020 Insp Num: mitSAM200607204243 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Ea7 Type Inj W 'TVD 5966 'Tubing 2570 ' 2573 ' 2565 • 2566 TD I 1821160 'Type Test SPT Test psi ao0o IA 790 3310 3220 3190 ' BL Pumped: 2s - BBL Returned: a OA 300 390 390 - 385 nterval IREQVAR PIF P Notes: 2 year MIT -IA to MAIP as per A10 2C.047. Monday, June 8, 2020 Page I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 17, 2019 4:21 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1 E-17 (182-116) Update and return of well to normal operating status Attachments: 1E-17 90 day TIO trend 9.17.19.pdf, MIT KRU 1 E-17 Diagnostic MITIA 07-23-19.xlsx Chris, KRU WAG injector 1E-17 (PTD 182-116) (AID 2C.047) was previously reported for suspect IA pressure decrease. Investigation found a small leak from the IA valve jewelry, which was re -taped and tightened. DHD performed a passing MITIA and passing pack off tests. The well was placed on a 60 -day monitor period and no signs off annular communication were exhibited. The well is being returned to its'normal' waivered status (under AID 2C.047). A 90 day TIO trend and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM CaioodNiNps Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Monday, July 22, 2019 8:40 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1 E-17 (PTD 182-116) Report of suspect IA pressure decrease Attachments: 1 E-17.pdf,, 1 E-17 90 day TIO trend 7.22.19.pdf Chris, KRU WAG injector 1E-17 (PTD 182-116) (AID 2C.047) is being reported for exhibiting suspect IA pressure decrease. The plan is to mobilize DHD to the well to perform diagnostic testing to include an MITIA and pack off tests. The IA pressure will be charged and the well will be placed on a monitor period for 60 days to confirm or disprove the suspect annular communication. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) WELLS TEAM MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: �i � / DATE: Tuesday,June 12,2018 Jim Regg / 1 P.I.Supervisor I l l b!i s I I' SUBJECT: Mechanical Integrity Tests {{ CONOCOPHILLIPS ALASKA,INC. 1E-17 FROM: Adam Earl KUPARUK RIV UNIT 1E-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ I�IZ- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-17 API Well Number 50-029-20793-00-00 Inspector Name: Adam Earl Permit Number: 182-116-0 Inspection Date: 6/10/2018 Insp Num: mitAGE180611093025 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1821160 Type Inj 1E-17 T e w 'TVD i 5966 Tubing 2665 2665 � 2675 2675 Well PTD ;Type Test SPT ;Test 580 3000 • IA 3300 ' 3240 3230 YP psi --- --- --BBL Pumped: 2.4 ' BBL Returned: 2.3 • OA 80 100 100 - 100 IntervalT REQVAR P/F P ✓' Notes: MIT-IA tested as per AIO 2C.047 to max ant.Inj.Pressure JUN 2 2 LuA Tuesday,June 12,2018 Page 1 of 1 iEcERlEb STATE OF ALASKA Al"OIL AND GAS CONSERVATION COMMIE/IN N REPORT OF SUNDRY WELL OPERATIONS t`''�A ' c 1 2018 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ ❑ Performed: Suspend III ❑ Other Stimulate 111 Alter Casing 111 Chan e 1put �/piroved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: Tubing Patch 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 182-116 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-20793-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-17 ADL 25651 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 7,885 feet Plugs measured None feet true vertical 6,567 feet Junk measured None feet Effective Depth measured 7,785 feet Packer measured 7230,7265,7283,7498 feet true vertical 6,456 feet true vertical 5966,5997,6014,6210 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 feet 16 " 78' MD 78'TVD SURFACE 2,279 feet 10 3/4" 2,313' MD 2162'TVD PRODUCTION 7,835 feet 7II7,866' MD 6550'TVD SCANNED JUN 1 12018 Perforation depth: Measured depth: 7373-7441, 7587-7596, 7613-7636 feet True Vertical depth: 6095-6158,6292-6300,6316-6337 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,522' MD 6,232'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FHL RETRIEVABLE 7,230' MD 5,966'TVD UPPER PACKER-2.73"QUADCO PAC 7,265' MD 5,997'TVD LOWER PACKER-2.73"QUADCO PAS 7,283' MD 6,014'TVD PACKER-BAKER FB-1 PERMANENT 7,498' MD6,210'TVD SAFETY VLV-CAMCO TRDP-1 SAFEI 1,922' MD 1,859'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: - - 2141 - 2122 Subsequent to operation: - - 209 - 2149 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations g Exploratory 0 Development ❑ Service Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL L] Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG 0 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: 318-130 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer ,/ 1,-,--1]'. - - Si ,I Contact Phone: (907)265-6471 f Authorized Signature: "7:4 c.. '" - ` Date: ! 1/18 �►J� Form 10-404 Rylrised 4/2017 - ABoms,\(/MAY 0 1 20 ,bmit Original Only • • 1 E- 1 7 TUBING PATCH DTTMSTEJOBTYP SUMMARYOPS 4/27/18 ANN BRUSH AND FLUSH FROM 7220-7295' RKB. RUN 2.73"OD X COMM 20' DUMMY PATCH DRIFT TO 7300' RKB. PATCH INJECTION MANDREL AT 7269' RKB. SET LOWER PARAGON PACKER @ 7283' RKB. SET UPPER PARAGON PATCH ASSEMBLY AT 7265' RKB. TEST TOP OF PATCH TO 2500 PSI FOR 30 MINS (PASS). PULL TEST TOOL. JOB COMPLETE. READY FOR INJECTION. KUP 4J 1 E-17 Conoc©Phillips ' &wells Well Attri Max An D TD Wellbore API/U Field Name WM Wellbore Status ncl(") Act Btm(ttKB) AIiiSk,,01C. ConocaPfalkps „v 500292079300 KUPARUK RIVER UNIT INJ 44.72 4,000.00 7,885 0 Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) Rig Release Date -.. SSSV:TRDP Last WO: 11/15/1984 I 40.71 8/26/1982 1 E-17,4/30/2018 10.37.08 AM Last Tag Vertical schematic(actual) Annotation Depth(RKB) End Date Last Mod By _ Last Tag:RKB(EST.10'OF RAT HOLE) 7,646.0 1/8/2018 pproven HANGER;278 ---1-' 'm: Last Rev Reason Annotation End Date Last Mod By Rev Reason:SET C-SAND PATCH 4/27/2018 condijw lull Casing Strings 1 ] Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 CONDUCTOR 16 15.250 34.0 78.0 78.0 65.00 H-40 WELDED 7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread - SURFACE 103/4 9.950 33.8 2,313.1 2,162.0 45.50 K-55 BTC jj Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread rr '^ns,,,,,,noon. ^^ us ^^..^^�^r^nnsism.Wio o` PRODUCTION 7 6.276; 31.5 7,866.0 6,549.8 26.00 K-55 BTC n.CONDUCTOR;34.0-78.0- ' 0 Tubing Strings _ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection SAFETY VLV;1,921,8 ^^ TUBING 31/2 2.992 27.8 7,522.9 6,233.0 9.20 J-55 BTC AB-MOD Completion Details Top(ND) Top Incl Nominal Top(ftKB) (RKB) C) Item Des Com ID(in) GAS LIFT;1,964.9 . 27.8 27.8' 0.06 HANGER FMC GEN I HANGER 3.500 1,921.8' 1,858.6 34.92 SAFETY VLV CAMCO TRDP-1 SAFETY VALVE 2.813 7,205.0 5,943.2 25.75 SBR BAKER SBR 3.000 7,229.7 5,965.6 25.52 PACKER BAKER FHL RETRIEVABLE PACKER 4.000 7,379.8 6,101.9 24.03 BLAST RINGS BLAST RINGS(3) 2.992 SURFACE;33.7-2,313.1 • 7,497.2 6,209.4 23.33 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,497.7 6,209.8 23.33 PACKER BAKER FB-1 PERMANENT PACKER 3.000 GAS LIFT;3,795.2 - 7,513.3 6,224.1 23.25 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,522.1 6,232.3 23.20 SOS BAKER SHEAR OUT SUB 3.015 • GAS LIFT;4,902.7 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;5,723.8 aTop(ftKB) (RKB) C) Des Com Run Date ID(in) 7,265.0 5,997.4 25.18 UPPER 2.73"QUADCO PACKER(CPP35149) 4/26/2018 1.625 PACKER GAS LIFT;6,179.3 ® 7,269.0 6,001.1 ' 25.14 SPACER PIE+ 14.32'SPACER PIPE,SNAP LATCH(CPAL35082) 4/26/2018 1.600 III SNAP LATCH GAB LIFT;6,541.2 7,278.0 6,009.2 25.06 LEAK IDENTIFY LEAK BETWEEN 7254'8 7324'RKB 6)22/2017 1.000 (KNOWN LEAK SINCE 1994) 7,283.0 6,013.7 25.01 LOWER 2.73"QUADCO PACKER(CPP35096) 4/27/2018 1.625 GAS LIFT;6,908.2 PACKER Perforations&Slots GAS LIFT;7,158.8 Shot 1111 Dens Top(ND) Btm(ND) (shots/ft • a Top(ftKB) Btm(ftKB) (ftKB) (ttKB) Zone Date ) Type con 7,373.0 7,441.0 6,095.6 6,157.8 C-4,C-3,1E-17 8/26/1982 8.0 (PERF • MEM SBR;7,209,0rimmi 7,587.0 7,596.0 6,292.0 6,300.3 A-5,1E-17 8/26/1982 8.0 (PERF PACKER;7.229.7 _ 7,613.0 7,636.0 6,315.9 6,337.2.A-4,1E-17 8/26/1982 8.0 IPERF ', Mandrel Inserts UPPER PACKER;7,265.0 - St I INJECTION;7,269.2 - Mt SPACER PIE 0 SNAP LATCH;, on Top(ND) Valve Latch Port Size TRO Run 7,289.0 , Top(RKB) (ftKB) Make Model OD(in) Sere TypeRun Date Com Type (in) (psi) 1 1,964.9 1,893.4 CAMCO KBUG ' 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 LEAK;7,276.0 • 2 3,795.2 3,260.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 3 4,902.7 4,070.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 11/15/1984 LOWER PACKER;7,283.0 - 'I. 4 5,723.9 4,693.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/12/1990 5 6,179.3 5,062.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1015/1984 INJECTION;7,338.8 6 6,541.2' 5,362.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/12/1990 1 7 6,908.2 5,679.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 11/5/1990 r8 7,158.8 5,901.8 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 5/11/2012 (PERF;7,373.0-7.441.0-. L g 7,269.2 6,001.2 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 1/8/2018 EXT PKG 1 7,339.6 6,065.1 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 08/2018 III 0 INJECTION;7,4701 1 7,4781 6,191.8 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 1/9/2018 aNotes:General&Safety SEAL ASSY;7,4972 = End Date Annotation PACKER;7,4977 -e 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 - I 10/17/2017 NOTE:WAIVER FOR WATER INJECTION ONLY WITH KNOWN TXOA COMMUNICATION ON GAS NIPPLE;7,513.3 'I IN N SOS;7,522.1 ss�� IPERF;7,587.0-7,598.0-. IPERF;7,613.0-7,638.0 • PRODUCTION;31.6-7,888.0-. • •V OF T� 44,-,1//7„ is), THE STATE Alaska Oil and Gas ti � A of Conservation Commission LAsKA. - 333 West Seventh Avenue --"r11". -1.16-1*'. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Pierce Sr. Wells Engineer ConocoPhillips Alaska, Inc. CONE P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-17 Permit to Drill Number: 182-116 Sundry Number: 318-130 Dear Mr. Pierce: 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, st4DOC- - Hollis S. French Chair DATED this 36 day of March,2018. • RECEIVEli • STATE OF ALASKA MAR 2 7 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION ,p 'S 3 /)o r� APPLICATION FOR SUNDRY APPROVALS , GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations LI Fracture Stimulate ❑ Repair Well y''f`"V Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Patch Cl. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillios Alaska, Inc. Exploratory E Development ❑ 182-116 " 3.Address: Stratigraphic ❑ Service E. 6.API Number: P. O. Box 100360, Anchorage,Alaska 99510 50-029-20793-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ KRU 1E-17 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 • 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 ND: MPSP(psi): Plugs(MD): Junk(MD): 7,885' • 6,567' . 7765• 6456 ' 2300psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 44' 16" 78' 78' Surface 2,279' 10 3/4 2,313' 2,162' Production 7,835' 7" 7,866' 6,550' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7373.7441,7587.7596,7613.7676 • 6096.6158,6292.6300,6316.6337 3.500" J-55 7,523' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER FHL RETRIEVABLE PACKER MD=7230 ND=5966 • PACKER-BAKER FB-1 PERMANENT PACKER MD=7498 TVD=6210 ' SAFETY VLV-CAMCO TRDP-1 MD=1922 TVD=1859 • 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ❑ Service El • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/1/2018 OIL ❑ WINJ n ' WDSPL ❑ Suspended Ell 16.Verbal Approval: Date: GAS ❑ WAG l GSTOR ❑ SPLUG ElCommission Representative: GINJ n Op Shutdown n 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: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com ,� Contact Phone: (907)265-6471 Authorized Signature: °° s --, , .,', Date:3/2(x,/j ( COMMISSION USE ONLY Conditions of approva: Notify Corn ission so that a representative may witness Sundry Number: c.J l _I c]O Plug Integrity (l BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 41 PI 3 91016 Post Initial Injection MIT Req'd? Yes n No ReDM Spacing Exception Required? Yes n No Subsequent Form Required: /0 - '3 0¢ APPROVED BY IApproved by: HOCLC} . COMMISSIONER THE COMMISSION Date: 3 131, ke- c � ), ; _i/250T� rT� 3/29/{ ORIGINAL lei Submit Form and 'J Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate a ~,� KUP 10 1 E-17 •ConocoPhddhlps 4 Well Attributes Max Angle& D TD ALaak- Ire, Wellborn API/UWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(ftKB) Can0Cai119ipe 500292079300 KUPARUK RIVER UNIT INJ44.72 4,000.00 7,885.0 ... ,. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-17,1/1520189:5:47 AM ,_,_SSSV:TRDP Last WO: 11/15/1984 40.71 8/26/1982 Vernal schamabclactua0_ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,660.0 12/27/2014 Rev Reason:SEE NOTE-WAIVER FOR pproven 10/17/2017 HANGER;27.8 WATER INJECTION ONLY WITH KNOWN 11. as Casing Strings d Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) ;Set Depth(ND)... WULen(I...Grade Top Thread JJ CONDUCTOR 16 15.250 34.0_ 78.0 78.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1-I I fl SURFACE 103/4 9.950 33.8 2,313.1 2,162.0 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread `' f_ PRODUCTION 7 6.276 31.5 7,866.0 6,549.8 26.00 K-55 BTC [ 1 Tubing Strings : Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibttt) Grade Top Connection ,, ,TUBING 3 1/2 2.992 27.8 7,522.9 6,233.0 9.20 J-55 BTC AB-MOD -"-".-1 CONDUCTOR;34.0-78.0' ' �P Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) SAFETY VLV;1,9218 rrr%• 27.8 27.8 0.06 HANGER FMC GEN I HANGER 3.500 la 1,921.8' 1,858.6 34.92 SAFETY VLV CAMCO TRDP-1 SAFETY VALVE 2.813 7,205.0 5,943.2 25.75 SBR BAKER SBR 3.000 7,229.7 5,965.6 25.52 PACKER BAKER FHL RETRIEVABLE PACKER 4.000 GAS LIFT;1,964.9 7,379.8 6,101.9 24.03 BLAST BLAST RINGS(3) 2.992 I RINGS • 7,4972 6,209.4 23.33 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,497.7 6,209.8 23.33 PACKER BAKER FB-1 PERMANENT PACKER 3.000 7,513.3 6,224.1 23.25 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE;33.7-2,313.1- 7,522.1 6,232.3 23.20 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT;3,795.2 Perforations&Slots Shot fili Dens Top(ND) Btm(ND) (shots/ GAS LIFT;4,902.7 Top(ftKB) Btm(ftKB) (ftKB) (MB) Zone Date ft) Type Corn 7,373.0 7,441.0 6,095.6 6,157.8 C-4,C-3,1E- 8/26/1982 8.0 IPERF 17 GAS LIFT;5,723.9 7,587.0 7,596.0 6,292.0 6,300.3 A-5,1E-17 8/26/1982 8.0 IPERF 7,613.0 7,636.0 6,315.9 6,337.2 A-4,1E-17 8/26/1982 8.0 (PERF GAS LIFT;6,179.3 Mandrel Inserts a GAS LIFT;8,541.2 In iii: in N Top(ND) Valve Latch Pod Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sets Type Type (in) (psi) Run Date Corn -.1 1,964.9 1,893.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 GAS LIFT;6,908.2 2 3,795.2 3,260.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 3 4,902.7 4,070.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 11/15/1984 GAS LIFT;7,158.8 4 5,723.9 4,693.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/12/1990 II5 6,179.3 5,062.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/15/1984 6 6,541.2 5,362.6 CAMCO KBUG 1GAS LIFT DMY BK 0.000 0.0 5/12/1990 7 6,908.2 5,679.6 CAMCO KBUG 1 GAS LIFT DMY 8K2 0.000 0.0 11/5/1990 SBR;7,zo5.o g 7,158.8 5,901.8 OTIS LBX 1 1%2 GAS LIFT DMY RM 0.000 0.0 5/11/2012 PACKER;7,229.7 7269.2 6,001.2 OTIS LBX 1 1/2 INJ HFCV RM 0.000 0.0 12/29/2014 e 1 7,339.6 6,065.1 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 12/29/2014 INJECTION;7,289.2111 0 1 7,478.1 6,191.8 OTIS LBX 11/2 INJ HFCV 'RM 0.000 0.0 12/29/2014 INJECTION,7,339.6 .- Notes:General&Safety End Date Annotation III „. 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/17/2017 NOTE:WAIVER FOR WATER INJECTION ONLY WITH KNOWN TXOA COMMUNICATION ON GAS IPERF;7,373.0-7,441.0 INJECTION;7,478.1 - SEAL ASSY;7,497.2 PACKER;7,497.7 it NIPPLE;7,513.3 I SOS;7,522.1 . g (PERF;7,587.0-7,596.0 $ (PERF;7,613.0-7,836.0-4 PRODUCTION;319-7,866.0-r- 1E-17 Retrievable Tubing Patch Installation On 6/16/94, a Pony Tail log found a large leak at the upper C Sand GLM #9 with a DV set at 7269' RKB. LLR -1 bpm at -2200 psi. 1E-17 was returned to injection with a large split to C Sand through this leak since it was diagnosed. On 1/9/18, an injection test using hole finder sets verified the leak at 7269' RKB still existed after the DV was swapped out to a new DV with extended packing (LLR = 1 bpm at 2300 psi), which indicates that the pocket is likely eroded. On 3/16/18, a Pump-In LDL with a TT Plug set at 7513' RKB verified that the leak at 7269' RKB was the only C Sand leak. Per the proposed procedure below, the leak at 7269' RKB will be patched with a retrievable tubing patch to convert 1E-17 to 'A Sand only' injection Procedure: Digital Slickline: 1. RIH to Brush & Flush the 3.5" tubing at 7220 - 7295' RKB around the tubing patch set area. 2. RIH with a -20' OAL Dummy Patch drift BHA consisting of a 2.72" OD x 4' OAL (top section) and 2.06" OD x -16' OAL (bottom section) to mimic the approximate dimensions of the upper run of the planned tubing patch. Run the top of the drift BHA to -7268' RKB where the tubing patch is targeted for set. POOH with drift BHA. 3. RIH & set a 2.72" OD retrievable lower Straddle Packer at 7283' RKB in tubing. This set location sets the packer 5' from top of a full joint just below GLM #9. POOH. 4. RIH with -19' OAL run #2 assembly consisting from bottom to top of an Anchor-Latch assembly, -14' of 2.06" OD Spacer Pipe, and upper retrievable 2.72" OD Straddle Packer (top). Latch into lower Packer at 7283' RKB and then set the upper Straddle Packer at 7265' RKB in tubing to complete Tubing Patch at 7265 - 7283' RKB (seal to seal). This sets the upper Packer near the bottom of a full joint just above GLM #9 to isolate the leak at 7269' RKB. POOH. 5. RIH with test plug and set it in the top Packer of tubing patch at 7265' RKB. MITT to 2500 psi to verify good set integrity of the upper straddle Packer and the tubing above the Tubing Patch. POOH with test Plug. RD. Return 1 E-17 to 'A Sand only' injection service & obtain valid injection rate. JWP 3/26/2018 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, October 1, 2017 10:56 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1E-17 (PTD 182-116) update 10-1-17 Attachments: 1E-17 AA justification packet 10-1-17.pdf; MIT KRU 1E-17 Diagnostic 7-7-17.xlsx Chris, The monitor on water injection was extended out and pressures demonstrated stabilization. We WAG'ed the well to gas injection on September 1 and the 30 day gas monitor is coming to an end today. Although the IA had stabilized at "1250psi, a couple of days ago we bled the IA down to 500psi to confirm communication was no longer present. Unfortunately the pressure returned to that "1250psi within a day and a half. It is believed the"1250psi pressure is its equalization point and there is in fact communication on gas present. Therefore I've put together an AA application for your consideration. CPAI intends to WAG the well back to water injection as soon as possible, keeping the well online while the AA is processing. Please let us know if you disagree with this. Attached is an electronic copy for your reference. The physical copy is in the mail. I've also attached form 10-426 for the recent diagnostic MIT performed in July, which was referenced in the application. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907)943-0170 scone : NSK Well Integrity Supv CPF1 and 2 Sent: -dnesday,July 19, 2017 8:21 AM To:Wallac-, hris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R. ' -r<R.Tyler.Senden@conocophillips.com> Subject: RE: Report o a pressure anomaly 1E-17(PTD 182-116) update 7-19-17 Chris, During the monitor on water injectio or 1E-17, and since this previous note to you a couple of weeks ago,there has been a slow increase in both the IA and O a essures. The choke was opened around the time both annuli began seeing the increase so it is suspected this is a thermal re :•nse. The 30 day monitor will be coming to an end in a couple of days. To ensure that this is in fact a thermal reaction an. •of the presence of slow communication,we plan to bleed the IA and OA again and extend the monitor on water injection ou . • additional 30 days. Please let us know if you disagree with plan forward. Attached is an updated TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 1 N • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, July 19, 2017 8:21 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1E-17 (PTD 182-116) update 7-19-17 Attachments: 1E-17 90 day TIO 7-19-17jpg Chris, During the monitor on water injection for 1E-17, and since this previous note to you a couple of weeks ago,there has been a slow increase in both the IA and OA pressures. The choke was opened around the time both annuli began seeing the increase so it is suspected this is a thermal response. The 30 day monitor will be coming to an end in a couple of days. To ensure that this is in fact a thermal reaction and not the presence of slow communication, we plan to bleed the IA and OA again and extend the monitor on water injection out an additional 30 days. Please let us know if you disagree with plan forward. Attached is an updated TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED AUG 0 7 2017, Mobile Phone (907) 943-0170 From: NSK Well Integrity Supv CPF1 and 2 • :Thursday,July 06, 2017 4:48 PM To: Wa .,e, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, '. ler<R.Tyler.Senden@conocophillips.com> Subject: RE: Repor 2 IA pressure anomaly 1E-17 (PTD 182-116) update 7-16-17 Chris, 1E-17 was returned to water injectio in 6-22-17 in anticipation of running a leak detect log, as per the email below. However, there no longer appears • be active communication present. The initial reporting of suspected TxIA communication while on water injection is nowlb.e eved to be a gas-only leak. An extended bleed of the IA was performed on 6-26-17 where charged fluid was obse• ed. Since that time, very minimal pressure build up has occurred (^'30psi). This small build up is suspected to be due to re `"ual gas breakout. Although the initial report, made in 2016, was while the well was on water injection, it had been shut in .r several months prior and previous to that shut-in, the well had been on gas injection for several weeks. CPAI intends to obtain an updated MITIA(the last one was performe. '. October 2016) and then extend the current monitor on water injection out an additional 2 weeks for a sum total of 31 .ys on water. We will then WAG the well to gas injection for 30 days to confirm or deny the presence of the gas-only leak. the gas leak is confirmed, an AA application will be submitted for your consideration. An update will be provided a he conclusion of the monitor periods. Please let us know if you disagree with the plan forward. Attached is an updated 90 day TIO plot. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. 1 • • dweDajoil 0 o o 0 ,r ,1 lit ,r ,1 . +r-- R 1 1 _ R o .. .....,„ C -- r , .. .. . .....„....4._ 1 _ i r R I r r- ) \\ C W � 1 r - r \ - _ r o Q. y, O \ Z I"" \ - ok CV R _ _ r 1 - Ri \\\1\1 Zi GIG► e•- ) - r 1 65 R 1 W _.. 4' 4 '4 i 4 4' .1 I I+ 41 4 'I I I, 4" I i''.4 4' f 'i .P.• F- LI CS If_ < 0 0 o �, !_ C CD a .7 0 O 0 C) t. r r ISd I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday,July 6, 2017 4:48 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1E-17 (PTD 182-116) update 7-16-17 Attachments: 1E-17 90 day TIO 7-6-17 jpg Chris, 1E-17 was returned to water injection on 6-22-17 in anticipation of running a leak detect log,as per the email below. However,there no longer appears to be active communication present. The initial reporting of suspected TxIA communication while on water injection is now believed to be a gas-only leak. An extended bleed of the IA was performed on 6-26-17 where charged fluid was observed. Since that time,very minimal pressure build up has occurred (^'30psi). This small build up is suspected to be due to residual gas breakout. Although the initial report, made in 2016, was while the well was on water injection, it had been shut in for several months prior and previous to that shut-in,the well had been on gas injection for several weeks. CPAI intends to obtain an updated MITIA(the last one was performed in October 2016)and then extend the current monitor on water injection out an additional 2 weeks for a sum total of 30 days on water. We will then WAG the well to gas injection for 30 days to confirm or deny the presence of the gas-only leak. If the gas leak is confirmed,an AA application will be submitted for your consideration. An update will be provided at the conclusion of the monitor periods. Please let us know if you disagree with the plan forward. Attached is an updated 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907) 943-0170 SCANNED AUG 0 8 ZQL.'. From: Well Integrity Supv CPF1 and 2 Sent: Friday, • ° - 16, 2017 1:17 PM To:Wallace, Chris D a <chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler. - ••en@conocophillips.com> Subject: RE: Report of IA pressure an• .ly 1E-17(PTD 182-116) update 6-16-17 Chris, 1E-17 has been shut in since April 2016 because of the pr- '•usly reported suspected TxIA communication. Pressure manipulations,with and without a tubing plug set, have been a z pted. But due to the very slow nature of the varying build up rates while shut in, we believe that identification of the leak •..tion will only be obtained when the well is online. Therefore ConocoPhillips intends to return the well to water injectio •r a period no longer than 14 days in order to log the well with an E-line deployed acoustic LDL toolstring. A path forwa ill be established based on the results of the logging and appropriate paperwork will be filed prior to returning the wel : 'njection. Please let us know if you disagree with the path forward. Attached is an updated"'14 month TIO plot. Kelly Lyons/Brent Rogers 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,June 16, 2017 1:17 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1E-17 (PTD 182-116) update 6-16-17 Attachments: 1E-17 14 month TIO plot 6-16-17.jpg Chris, 1E-17 has been shut in since April 2016 because of the previously reported suspected TxIA communication. Pressure manipulations,with and without a tubing plug set, have been attempted. But due to the very slow nature of the varying build up rates while shut in, we believe that identification of the leak location will only be obtained when the well is online. Therefore ConocoPhillips intends to return the well to water injection for a period no longer than 14 days in order to log the well with an E-line deployed acoustic LDL toolstring. A path forward will be established based on the results of the logging and appropriate paperwork will be filed prior to returning the well to injection. Please let us know if you disagree with the path forward. Attached is an updated^'14 month TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor SCANS JUN 2 3 201 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone(907)943-0170 From: NSK Problem Well Supv Sent: Friday,April 22, 2016 3:13 PM To: ' . - Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R. <R.Tyler.Senden@conocophillips.com> Subject: RE: Report of • : -ssure anomaly 1E-17 (PTD 182-116)4-15-16 Chris, The MITIA and T&IC packoff tests passed on 4- • •. The IA was bled down to 1000psi (with WHP of"1800psi). Initially the IA pressure looked to be holding a good dP for seve .ays. However,the pressure increased again back up to —wellhead pressure. The well was shut in and freeze protecte• • 4-21-16 and will remain so until further notice. We will now begin diagnostics utilizing slickline/Eline as appropriate to ho• - Ily identify the leak point. Appropriate paperwork will be filed once a path forward is identified in returning the we _ 'njection. Attached is the MIT and updated 90 day TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. 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Tyler Subject: RE: Report of IA pressure anomaly 1E-17 (PTD 182-116)4-15-16 Attachments: MIT KRU 1E-17 non-witnessed 04-16-16.xls; 1E-17 90 day TIO 4-22-16.PNG Chris, The MITIA and T&IC packoff tests passed on 4-16-16. The IA was bled down to 1000psi (with WHP of^'1800psi). Initially the IA pressure looked to be holding a good dP for several days. However, the pressure increased again back up to wellhead pressure. The well was shut in and freeze protected on 4-21-16 and will remain so until further notice. We will now begin diagnostics utilizing slickline/Eline as appropriate to hopefully identify the leak point. Appropriate paperwork will be filed once a path forward is identified in returning the well to injection. Attached is the MIT and updated 90 day TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: NSK Problem Well Supv Sent: Friday Aril 15, 2016 12:32 PM To: Wallace, Chris.D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R;Tyler.Senden@conocophillips.com> Subject: Report of IA pressure nnoomaly 1E-17 (PTD 182-116)4-15-16 Chris, Kuparuk injector 1E-17 (PTD 182-116) is experiencing an IA pressure anomaly. It was returned to water injection on March 14, 2016, after having been shut in for hea r repair work since December 4, 2015. Initially the repeated buildup in IA pressure was believed to be thermally-induced. Al intends to begin initial diagnostics with DHD as soon as possible. The tests will include an MITIA, packoff testing and drawdown. There has been an extended period of bad weather on the slope and we are still in the process of removi the snowdrifts so there may be a small delay in initiating the testing. If the MITIA fails,the well will be shut in and freeze protected as soon s possible. If the MITIA passes,the well will go on a 30 day monitor clock. A follow-up email will be provided at the conclusion of the test/monitor period. Please let us know if you disagree. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. 1 W (} 4111 411111 , i s 5 y • crc rn vi [n twin CD R (I LY LY -y w w w w V — — — N wU U Cr 4 Cl_ tJ V 9 r1 VU) ✓. r r 6 L ' i7 N W = cc (, U U U a. c..) o o r a a, co 2^ u', o n w d, h 01 0, ((3) CC r r r 1- N EEE ,;, w w W o 0 o 0 SVP.'..!f_ .7 w i3 O � c F. r- r- J r r ,- yW r1 r1 r 1$) V ,•''7 G( O 4813 (A Cl(0 (ri tV I 1 I I 1 I r •-4 Q 1 Q ri...,................................ tu [w� Q • (o (i, 03 03 U C ea f 1 co m S co • C r • a O 03 05 :I..i d RI O E o 1 40 KLA R a7 Q $ i IL LL' CD It' C • C to to a3 tti r W M V' , ,,r N q g02 9 i : 1 i" C6 i LII I 1 R CO d O u O o O u R; it k Y It k K 1, , Z O (D o 0 0 0 0 H CJ CJ m CO T.'o Isd 5gnow` • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, April 15, 2016 12:32 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly 1E-17 (PTD 182-116)4-15-16 Attachments: 1E-17 90 day TIO 4-15-16.PNG; 1E-17 schematic.pdf Chris, Kuparuk injector 1E-17 (PTD 182-116) is experiencing an IA pressure anomaly. It was returned to water injection on March 14, 2016, after having been shut in for header repair work since December 4, 2015. Initially the repeated buildup in IA pressure was believed to be thermally-induced. CPAI intends to begin initial diagnostics with DHD as soon as possible. The tests will include an MITIA, packoff testing and drawdown. There has been an extended period of bad weather on the slope and we are still in the process of removing the snowdrifts so there may be a small delay in initiating the testing. If the MITIA fails,the well will be shut in and freeze protected as soon as possible. If the MITIA passes, the well will go on a 30 day monitor clock. A follow-up email will be provided at the conclusion of the test/monitor period. Please let us know if you disagree. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. E� APR 1 �� Desk Phone (907) 659-7224 SCAN Mobile Phone (907) 943-0170 1 o % j § j • 0 @a as $ §§ u _ . zt / § i § [ 4/4 . F 2 13 414 alt Era _ , . A. a8 $ § 0) 0) _ _ y « § \ § § p I 0 I t- w I . ] 333 § - - - 4'P S I I 2 I I I - \ . \ ` L........_._.,........,, L_ ) cn$ \ to ) 4 143 43 IJI _cu \ k e go J 2 'M c @ to e RI 112 u '$ '} ) O2 E E 10 0 / U 2 10 J `'t • -\ U. e CO to to 4 : n / \ � / • § - - skE . ! | ! | 0 1 WI $ , 6 • , , _? 21 I§ 8 8 D4 | | | ; ; r � § c. 411 Im ° gm. k -0 |s ~ 6,0�a STATE OF ALASKA • AliKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well r` Other:WINJ to WAG rN 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory r 182-116 3.Address: 6.API Number: Stratigraphic r Service For P.O. Box 100360,Anchorage,Alaska 99510 50-029-20793-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,ALK 469 KRU 1E-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7885 feet Plugs(measured) None true vertical 6567 feet Junk(measured) None Effective Depth measured 7765 feet Packer(measured) 7230,7498 true vertical 6456 feet (true vertical) 5966,6210 Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 78 78 0 0 SURFACE 2279 13 2313 2162 0 0 PRODUCTION 7835 10 7866 6550 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7377-7441,7587-7596,7613-7636 True Vertical Depth: 6099-6158,6292-6300,6316-6337 '-r- 099 6158,6292-6300,6316 63371 I-C r; RECEIVED Tubing(size,grade,MD,and TVD) 3.5,J-55,7523 MD,6233 TVD DEC 0 9 2015 Packers&SSSV(type,MD,and TVD) SBR-BAKER SBR @ 7205 MD and 5943 TVD AOGCV PACKER-BAKER FHL RETRIEVABLE PACKER @ 7230 MD and 5966 TVD SEAL ASSY-BAKER LOCATOR SEAL ASSEMBLY @ 7497 MD and 6209 TVD PACKER-BAKER FB-1 PERMANENT PACKER @ 7498 MD and 6210 TVD NIPPLE-CAMCO D NIPPLE NO GO @ 7513 MD and 6224 TVD SOS-BAKER SHEAR OUT SUB @ 7522 MD and 6232 TVD SAFETY VLV-CAMCO TRDP-1 SAFETY VALVE @ 1922 MD and 1859 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1934 548 1482 Subsequent to operation 0 5769 0 1470 2992 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations a Exploratory r Development r Service r.7 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r 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: N/A Contact Darrell Humphrey/Bob Christensen Email n1139(aconocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone:659-7535 Date Form 10-404 Revised 5/2015 Submit Original Only �� L-44 / � RBDMS, DEC 0 9 2015 S • 1 E-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/24/15 Open Well Return to Service 11/22/15 Convert to MI Injection KUP INJ • 1E-17 ConocoPhillips Well Attributes Max Angle&MD TD Alaska.I;k., Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(16413) rr,nr,c„fhilhln 500292079300 KUPARUK RIVER UNIT INJ 44.72 4,000.00 7,885.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-17,1P/20159:46:27 AM SSSV:TRDP Last WO: 11/15/1984 40.71 8/26/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,660.0 12/23/2012 Rev Reason:GLV C/O,TAG,PULLED WRP lehallf 1/7/2015 HANGER;27.8 ' I Casing Strings E., I._. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread f CONDUCTOR 16 15.250 34.0 78.0 78.0 65.0011-40 WELDED �.,z Casing Description OD(In) ID(in) Top(ftKB) Set Depth IRKS) Set Depth(ND)...'Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 33.8 2,313.1 2,162.0 45.50 K-55 BTC It I Casing Description OD(in) ID(in) Top OMB) 'Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I PRODUCTION 7 6.276 31.5 7,866.0 6,549.8 26.00 K-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 27.8 7,522.9 6,233.0 9.20 3-55 BTC AB-MOD ,�I nyr, l)1 Completion Details AA.A CONDUCTOR,34.0-780• Nominal ID ��'.� Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLV;1,921.8 If ,.. 27.8 27.8 0.06 HANGER FMC GEN I HANGER 3.500 1,921.8 1,858.6 34.92 SAFETY VLV CAMCO TRDP-1 SAFETY VALVE 2.813 7,205.0 5,943.2 25.75 SBR BAKER SBR 3.000 7,229.7 5,965.6 25.52 PACKER BAKER FHL RETRIEVABLE PACKER 4.000 GAS LIFT;1.964.9 7,379.8 6,101.9 24.03 BLAST RINGS BLAST RINGS(3) 2.992 7,497.2 6,209.4 23.33 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,497.7 6,209.8 23.33 PACKER BAKER FB-1 PERMANENT PACKER 3.000 7,513.3 6,224.1 23.25 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE;33.7-2.313.1- 4. 7,522.1 6,232.3 23.20 SOS BAKER SHEAR OUT SUB 3.015 Perforations&Slots GAS LIFT;3,795.2 Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;4,902.7 7,373.0 7,441.0 6,095.6 6,157.8 C-4,C-3,1E- 8/26/1982 8.0 IPERF 17 7,587.0 7,596.0 6,292.0 6,300.3 A-5,1E-17 8/26/1982 8.0 (PERF GAS LIFT;5,723.9- 7,613.0 7,636.0 6,315.9 6,337.2 A-4,1E-17 8/26/1982 8.0 (PERF Mandrel Inserts GAS LIFT;6,179.3 111 St - enl N Top(ND) Valve Latch Port Size TRO Run GAS LIFT;6,541.2Top(ftKB) (ftKB) Make Model OD(in) Se" Type Type (in) (psi) Run Date Com '1‘. 1,964.9 1,893.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 2 3,795.2 3260.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/23/1990 GAS LIFT;6,908.2 3 4,902.7 4,070.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 11/150984 4 5,723.9 4,693.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/12/1990 GAS UFT;7,158.a 5 6,179.3 5,062.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/15/1984 6 6,541.2 5,362.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/12/1990 7 6,908.2 5,679.6 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 11/5/1990 8 7,158.8 5,901.8 OTIS LBX - 1 1/2•GAS LIFT DMY RM 0.000 0.0 5/11/2012 SBR;7,205.0 9 7,269.2 6,001.2 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 12/29/2014 PACKER 7,229.7 1 7,339.6 6,065.1 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 12/29/2014 0 INJECTION;7,269.2 1 7,478.1 6,191.8 OTIS LBX 11/2 INJ HFCV RM 0.000 0.0 12/29/2014 1 a. Notes:General&Safety INJECTION;7,339.6Ig End Date Annotation • 825/2010 NOTE:View Schematic w/Alaska Schemetic9.0 - - ac- s ` (PERF;7,373.0.7,441.0= - = INJECTION;7,476.1 SEAL ASSY;7,497.2 PACKER;7,497.7 -• NIPPLE;7.5133e I SOS;7,522.1 - ` ERF;7.597.0.7,596.0- PERE; IPERF;7,813.0.7,636.0 PRODUCTION;31.8-7,866.0-- - MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 03,2015 TO: Jim Regg ��g 614'16 P.1.Supervisor _( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-17 FROM: Jeff Jones KUPARUK RIV UNIT 1E-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JriE — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-17 API Well Number 50-029-20793-00-00 Inspector Name: Jeff Jones Permit Number: 182-116-0 Inspection Date: 5/2/2015 Insp Num: mitJJ150505152450 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-17 Type Inj W'ITVD 5966 - Tubing 1100 1100 noo 1100 - PTD 1821160 - Type Test SPT Test psi 1500 IA 60 2000 - 1950 " 1940 Interval 4YRTST P/F P OA 570 720 720 - 720 - Notes: 1 well inspected;one exceptions noted;the allemite fitting on the surface casing packoff is leaking hydraulic oil into the cellar 2 4 BBLS diesel pumped. ANNE© JUL 1 3201 Wednesday,June 03,2015 Page 1 of I Ima ect Well History File CoverWge 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. Organizing .~o,,~ RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) Color items: Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERY~ WINDY Project Proofing .. Scanning Preparation c-~ x30: /~_ + /~/' Is~ = TOTAL PAGES BY: Production Scanning ~ Stage I PAGE COUNT FROM SCANNED FILE: '~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~' YES NO IF NO IN STAGE '!, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: Stage 2 (sCANNING IS COMPLETE AT THIE POINT UNLE8~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVt DUAL PAGE BASIS DUE TO QUALITY, GRAySCALE OR COLOR IMAGES) RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; IS~ General Notes or Comments about this file: Quality Checked Idone~ 12/lO/02Rev3NOTScanned.wpcl • • Nov ConocoPhillips Alaska ta 4.4, .�, , � P.O. BOX 100360 � � ;; ANCHORAGE, ALASKA 99510 -0360 SAN 0 4 101- December 30 2010 ` tv.r%p! Pi; R, at cora, - ':';Sion ancnertige Commissioner Dan Seamount Alaska Oil & Gas. Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 4° Commissioner Dan Seamount: 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 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 September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23rd, •rn , 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein l' 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 12/30/2010 1C, 1E, 1 F, 1G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1C-07A 50029205690100 2090290 3'2" n/a 3'2" n/a 4.3 12/23/2010 1E-09 50029207200000 , 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" n/a 3'9" n/a 11.6 12/22/2010 1 E -16 50029207770000 1821100 4' n/a 4' n/a 13.7 12/22/2010 1E - 17 50029207930000 1821160 3'11" n/a 3'11" n/a 8.5 12/24/2010 1F -13 50029210200000 1 831440 6" n/a 6" n/a 3 12/23/2010 1F-17 50029226570000 1960470 SF n/a 18" n/a 7.65 12/23/2010 1F-20 50029226610000 1960530 6" n/a 20" n/a 6.1 12/23/2010 1G-13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y-01 50029209330000 1830500 SF n/a 6" n/a 1.9 12/21/2010 1Y -03 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF n/a 6" n/a 1.7 12/21/2010 1Y-11 50029209260000 1830410 9" n/a 9" n/a 2.6 12/21/2010 1Y-12 50029209130000 1830260 4' n/a 4' n/a 8 12/21 /2010 1Y-13 50029209030000 1830150 15" n/a 15" n/a 1.7 12/21/2010 1Y-14 50029209100000 1830230 24" n/a 24" n/a 1.7 12/21/2010 1Y-16 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21/2010 • ~ ~ MEMORANDUM TO: Jim Regg ~ 7~~1 as P.I. Supervisor ~%~/ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-17 KUPARUK RIV iTNIT 1E-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV UNIT 1E-17 Insp Num: mitRCN100627135057 Rel Insp Num: API Well Number: 50-029-20793-00-00 Permit Number: 182-116-0 Inspector Name: Bob Noble Inspection Date: 6/24/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IE-I T ype Inj. N TVD 5966 IA 400 1760 ~ 1760 ~ 1760 P.T.D Is2I I6o' TypeTest sPT Test psi ~ I76o ~ OA i o 0 0 0 Interval axRTST p~ P ~ Tubing 600 600 600 600 Notes: ,~~. ~`!- ~ lad i~GC~~r,; '"~;; ~~i~;~ ~f,l)~; rid{~i, _w Wednesday, June 30, 2010 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim ReggK//;. llC{i~( P .1. Supervisor ~ 11 1 (" ~ DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-I? KUPARUK RIV UNIT IE-I? Src: Inspector ~\\lP \~Ô- FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~Ti3¡Z-- Comm Well Name: KUPARUK RIV UNIT IE-I 7 API Well Number 50-029-20793-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605100701 Permit Number: 182-116-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IE-I? ,--- -,---- ¡Type Inj. IN! TVD 5966 I IA 500 2380 2360 2360 i P. T. I 182II60 ¡TypeTest i SPT ! Test psi 1500 lOA 350 420 420 420 i Interval 4YRTST P/F p Tubing 625 625 625 625 I Notes Well temporarily shut in for common line repair. ~C"NNE~) ,JUN .. B ZODS Wednesday, June 07, 2006 Page I of I IE-17 MIT data ) ) Subject: lE-17 MIT data From: NSK Problem Well Supv <nI617@conocophillips.com> D~te: ~on,19 Sep 200516:35:33-0800,. ¡'" " .' ". , '. ,"", ", ' ~q:;;T~om~'lV1áunder <tom ~ mat1Ilder@adu1in:s~ate.ak.~s?;: Jiin: R~gg <jim _regg@a~n~st"te.ak:~s>,· RqJ)e~:Fleckenstein·<bob~:µ.êc~~nsteiri@adri1i11:.~t~t~:*~~~?"~i . .. .... n" _.~ .'. ._ Tom, Bob, Jim, ¡ Attached is a passing MITT and MITIA data for 1 E-17 (PTO 1821160). This was diagnostic testing to verify integrity for a possible CTO sidetrack, similar to testing completed last week on 1 E-16. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1 E-17 09-17-05.xls» ! II Content-Description: MIT KRU lE-17 09-17-05.xls ,; MIT KRU IE-17 09-I7-05.xls,¡ Content-Type: application/vnd.ms-excel 'i Content-Encoding: base64 ... .........,..."..."..........""""..,,,,,,,.;:,,,,..,,...,, .......... ............."....."..... . ........... ............ ",,,.. ..."......"."........"...."......."...."............."j ... ....................................." SCANNED NO\f 0 9 2005 I of I 10/4/2005 8:04 AM ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 11 E 09/17/05 Rogers 1 Sauvageau - ASRC Packer Depth Well 1E-17 Type Inj N T.V.D. 5966 Tubing P.T.D. 1821160 Type Test P Test psi 1500 Casing Notes: Diagnostic MITT with the A sand and C sand isolated. OA TTP set above A sand, DVs installed in C sand straddle. Well 1 E-17 Type Inj N T.V.D. 5966 Tubing P.T.D. 1821160 Type Test P Test psi 1500 Casing Notes: Pre-CTD integrity verification. Possible 8T candiate. OA Well Type Inj TV.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: OA Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: OA Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: OA Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas I nj 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 MIT Report Form Revised: 05/19/02 Pretest Initial 15 Min. 30 Min. 0 2550 2440 2400 Interval 0 180 180 180 180 P/F P 380 380 380 380 350 750 750 750 Interval 0 180 2520 2480 2480 P/F P 380 380 380 380 Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0= Other (describe in notes) MIT KRU 1E-17 09-17-05.xls 10/4/2005 1. Type of Request: Pull tubing STATE OF N.ASKA ~ /~LASKA OILAND GAS CONSERVATION C(.~MISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate ~ Plugging Perforate Alter casing Repair well Other ~ . 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development -)~ Exploratory _ Stratigraphic Service 4. Location of well at surface 203' FSL, 817' FEL, Sec. 16, T11N, At top of productive interval 1440' FNL, 1196' FWL, Sec. 21, T1 At effective depth 1522' FNL, 1088' FWL, Sec. 21, T1 At total depth 1546' FNL, 1027' FWL, Sec. 21r T1 12. Present well condition summary Total Depth: measured true vertical R10E, UM 1N, R10E, UM 1N, R10E, UM 1Nr R10E~ UM 7855' feet 6 5 6 7' feet' Plugs (measured) None RKB 106' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1E-17 9. Permit number/approval number 82-11 6/90-307 10. APl number 50-029-20793 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 765' true vertical 6456' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 78' 1 6" 296 Sx AS I 2313' 10 3/4" 1175SXAS III & 250 Sx AS I Measured depth 78' 2313' 7866' 7" 650SxClassG 250 Sx AS I measured 7613'-7636'4 SPF, 7587'-7596', 7373'-7441' true vertical 6315'-6336', 6291 '-6300, 6095'-6157' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 tubing at 7523' Packers and SSSV (type and measured depth) True vertical depth 78' 2162' 7866' 8 SPF 6549' R'E'¢EIVED NOV 2 8 1990 0il & Gas Cons. C0mmis,' chorage Baker FHL @ 7210', Baker FB,1 @ 7478', Camco TRDP-1A SSSV ~ 1902' 13. Stimulation or cement squeeze summary Converted to Water Injector Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure See Attachment 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 400 2500 2000 1400 150 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 2OOO 1000 16. Status of well classification as: Water Injector ~ Oil ~ Gas Suspended Service 2OOO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned~~~} ~ ,, ~~"' Form 10-404 Rev 09/12/90 ~,~ Date SUBMIT IN DUPLICATE on /,% rl t,/ i,/ Plli;i~,~RII! lel¥~ Subsidiary of Atlantic Richfield Complny WELL ? : /,~ -/? CONTI~TOR .EMARKS ~ ~ _ /,.5- O V IPBDT iFIELD-DISTRICT-ST' y,. u, ,o.~,,a ~ K. IOPERATION~AT REPORT TIME -/2- 5o /5'5'0 /~,~5" //..7_0 / 7/o /~ iL31,E H ,O I-/' P/.L ,. P - P/.,L~.i p ~ 0 "-' ['"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report 'F 'F mil. knot · . Sul~ldtlry of Atlantic Richfield/~mny ' WELL .... ~ ~ 'IPBDT /£ -/7 I CONTRACTOR 07'/5' ,"r-,~ FIELD- DISTRICT- STA OPERATION AT REPORT TIME C.o/~ P/.. ~ '7"F._. WI=I.I., ~P..I'iVI~51" HI"YUH I IDAT~ iDATE .~-7' .,,IT ~z ;'f ' -,S~T ~OV ~ 8 1990 Alaska uil &.~as. Cons. Commission ~u~crtorage r"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Chill STATE OF ALASKA Aw-~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ORIGIN 1. Type of Request.: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~X Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address 5. Type of Well: Development X Exploratory _ Stratigraphic _ RKB 106' feet 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 203' FSL, 817' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1440' FNL, 1196' FWL, Sec. 21, T11N, R10E, UM At effective depth 1522' FNL, 1088' FWL, Sec. 21, T11N, R10E, UM At total depth 1546' FNL, 1027' FWL, Sec. 21, T11N, R10E, UM 12. Present well condition summary Total Depth: measured Service 7855' true vertical 65 6 7' Effective depth: measured 77 6 5' feet true vertical 6 4 5 6' feet Casing Length Size Structural Conductor 7 8' 1 6" Surface 2313' 10 3/4" Intermediate Production 7 8 6 6' 7" Liner Perforation depth: measured feet Plugs (measured) feet None Junk (measured) None Kuparuk River Unit 8. Well number 1E-17 9. Permit number 82-116 10. APl number so-029-20793 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 296 Sx AS I 7 8' 7 8' 1175 Sx AS III & 2313' 21 62 250 Sx AS I 650 Sx Class G 7 8 6 6' 6 5 4 9' 250 Sx AS I 7613'-7636' 4 SPF, 7587'-7596', 7373'-7441' true vertical 6315'-6336', 6291 '-6300, 6095'-6157' Tubing (size, grade, and measured depth 3 1/2", 9.3#, J-55 tubing at 7523' Packers and SSSV (type and measured depth) Baker FHL @ 7210', Baker FB-1 @ 7478; Camco TRDP-1A SSSV @ 1902' 13. Attachments Description summary of proposal _ Convert to water injection. 14. Estimated date for commencing operation 15. May 1990 16. If proposal was verbally approved Name of approver ~)v~t~,,- ~,.~,,~ Date approved S e r vi ce RECEIVE£,, ~::~laska Oil & Gas Cons. Commissio[ Anchorage Detailed operation program Status of well classification as: Oil X Gas m BOP sketch Suspended _ 17. I herebt;¥ertify~ Sic,;Ined th~t~the ~is true and correct to the best of my knowledge. ·~ Title Senior Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test '~ Subsequent form require Approved by the order Commission 0RI(~INAL 81{3NED BY LONNtE C. SMITH IAppro aLNo. 10- ~-rP L) ~...,,~d C0{3~ ~ 0 ~ c/ Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 1E-17 Convert to Injector Charge COde 230DS10EL · J · e · Pull GVL's at 1945', 3776', 5704', and 6522'. Replace with DV's. Pull OV at 7139'. Load annulus with 190 bbls diesel. Run DY to GLM at 7139'. Perform MIT by pressuring 3 1/2"' x 7" annulus to 1500 psi. minutes without changing by more than 10%. Place well on injection. This must hold for 30 1. ~)000 PSI ?" W£LLHr. A~ GONNCCTC)R £LANG[ 2. 5000 PSI WIR£LIN£ RAIDS (VARIABL£ SIZ£) .3.~000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ P^CK-orr bl]RELZNE BOP. EOUZPHENT Attachment I I Page Z Drill Site 1H Well No. ~1H-3 '~lH-4 ~1H-7 '"1H-8 _Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site 1E Well No. .Log Date 1E-lA N)/lg/81 1E-2 ~8/17/81"7 _'~'1/17/84/ 1E-3 '"10/18/81'N, "'.1117181/ 1E-5 ~10/27/81~ 1E-6 ~10/21/81~ ~11/12/82/ ~1E-7 ~/28/81~ 1E-8 ~8/28/8}~ ~11/1/8 ~ 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/82 ~ ~ ~6/13/83 1E-29 ~10/18/8~ ~7/18/83 / / 1E-30 ~0/16/82 Drill Site 1G Well No. 'N1G_1 'NIG_2 "~lG-3 '~1G-4 '~1G-8 Log Date 9/7/82 -9125/8zN 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No.. Log Date 1F IF-1 2/19/83 1F-2 2/3/83 NIF-3 1/31/83 "1F-4 5/29/83 %1F-5 · 10/25/82 ",.1F-6 10/28/82' "- 1F-7 11/19/82%, ~ 517183,./ RECEiVi "/ FEB 21 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska. Inc./"'%~ Post Office ~. ~x 100360 Anchorage. Alaska 9951 ~-0360 Telephone 907 276 1215 June 24, 1985 ~4r. C. 'V. Chatterton, Chairman Alaska Oi'l and Gas Conservation Commission 3001 POrcupine Drive Anchorage, AK 99501 Dear Mr. ChattertOn: Atta foil Wel ! 1A-3 1A-4 1C-5 1E-3 1E-3 1E-4 1E-4 1E-16 1E-17 1E-29 1F-16 1F-16 1G-1 1L-15 1L-16 1Q-1 1Q-4 1Q-4 1Q-5 1Q-6 1Q-7 1Q-7 2C-10 2D-3 2W-1 3 2X-12 ched in duplicate are subsequent not ices owing wells at the Kuparuk River Field: Act ion Date Performed Fracture 5/30/85 Fracture 6/1/85 Perforate 4/27 / 85 Perforate 3/28/85 Fracture 4/3/85 Perforate 4/20/85 Fracture 5/7/85 Fracture 4/14/85 Fracture 3/26/85 Fracture 4/12/85 Perforate 4/11/85 Fracture 4/15/85 Fracture 4/1/85 Fracture 3/31/85 Fracture 3/31/85 Fracture 5/31/85 Acidize 5/17/85 Fracture 5/31/85 Fracture 5/1/85 Fracture 4/19/85 Fracture 4/27/85 Acidize 5/26/85 Perforate 4/21/85 Acidi ze 5/11/85 Acidize . 5/20/85 Acidize 5/1 2/85 on the If you have any questions, please call T. M. Drurnm Kuparuk Operations Coordinator TMDlkmc Attachment (Duplicate) me at 263-4212. RECEIVED JUN 2 ~ ]~£~ Alaska 0il & Ua$ Cons. '- · ' Anchorage ARCO Alaska, Inc. is a Subsidiary o¢ '--.:anticRichlieldCompany STATE OF ALASKA ALASKA L)~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX' 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 203' FSL, 817' FEL, SEC. 16, TllN, R10E, UM OTHER [] 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB) 12. 7. Permit No. 82-116 8. APl Number 50- 029-20793 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-17 11. Field and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RIVER OIL ADL 25651, ALK 469 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 [] [] Other [] Pulling Tubing [] Pull 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 March 26, 1985, the "A" sands of Kuparuk well 1E-17 were hydraulically fractured and propped to improve production. The treatment consisted of 260 BBLS of gelled water as pad and carrying fluid and 14,910 LBS of 100 mesh and 12/20 sand as proppant. 69 BBLS of gelled water and diesel was used as a flush. Prior to pumping, equipment and lines were tested to 6000 psi. RECEIVED JUN 2 6 ]985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ,.~, ~ ~_.~,,~-.~ Title OPERATIONS COORDINATOR The space below for Commission use 6/18/85 Conditions of Approval, if any Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Offic/'~'~x 100360 Anchorage, ~laska 99510°0360 Telephone 907 276 1215 DATE: APRIL 2'2, TRAN.?HITTAL NO: i ~8S 5 i 48 R E 1' U R N '1" O' A'RCO AL..A,?I<A, INC. A'FTN. RI:-.COR'DS CI...ERI< ATO--i i i p ('! r, rlY i 0'336£) AN['.I-.J[..'),RA(.-i-I.-E,-Al< o,~.r '.:'..¢ i ('.'). 'f'RANSHI'FTET':' I.-1ERrrI.4T. TH ..-,kS THE F'OI...L01,...I];N.G Il'EH,;, F'I_[i;ASE ACI<NOWLED(;E AND F.:ETL.~F..'.N ONE .%I[;N, ED COPY OF THIS 'FRANSHI'FTAL, YOE SO:F../F'ROD I..0[.; & L,'OE,/F'BU ( T. NITIAL S'. OE/PBU £OE/F'BU ,.e, OE/PF~U ,?L'}.E/' C' ',.?AND PBU /INI'I:T. RHITTIENT LIFT F F', ,:.,> ,.. ~r',E 'A' SAND F'BLJ F F.E.~ ~ LJF, E ) 'C' SANDS SOE/$BHF' - 'A' & STATIC BHF' DATA STATIC BHF' DATA STATIC BI'iF' DATA STATIC BFIP DATA STATIC BI-iF' DATA STATIC BHF' DATA STATIC BHF' DATA STATIC BFIF' DATA STATIC BHP DATA STATIC ~"iF DA IA ~TATIC ~"" . ~,rlF DATA STATIC BHF' DATA ,?TATIC BHP DATA ~T~-~,IC BHF' DATA ~TATIC BHP DATA ~TAT!C BHP DATA ~T~,T~.C BHP DATA ~TATIC BHP DATA STATIC BHP ~ATA ~TATIC BHF' DATA ~'"'ATIC BI'IF' DATA STATIC BHP DATA Z,'URVEY .",,::. C E l i":"T AF':'/-'"JOI'LEDGED '_ ,,,, ..F,r' ,, ROd ", :.,'ISTRIBU'FiON: · ~, i (-I ~ 'lI DRILLING W FA~I-IER ! I'~- t 'r'~.l L. ..JO,",~ a TOI. E,.~vv,, O N' MOBIL F'HILLIF'S OIL NSK CLERK J~ RATHMELL ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichlleldCompany 416-7/85 3/f t/85 ,. 2126/85 ,i,, 3/2/85 Z/Z/85 314185 3118185 J/24/85 J/24/8~, 313185 ~/2/85 3/2/85 S/t 9/85 f/2t/o~ ~..~ ~.. ~ ~ ,.. ~/~/~:~ 3/26/e3 ~ ,/~4/~ 1125185 f/26/85 t/25/85 t/$i/~$o I ,/~ / P,.,'¢ ' t/f t/8~ t/24-/85 .. t/24/85 . t e;,, ~ .. RECEIVED APR 2 5 1985 AlasRa 0il & G~s~_~Cans. Commission U N l 0 N I< . TNI_ I N/V~UL T ARco Alaska, inc. Post'Office~ 100360 .Anchorage, ~m.~ka 99510-0360 Telephone 907 276 1215 r:L.r ...... .... I -.IX .':'7 L.I I:;: V E: Y/' F' ?',' U ., , F:'I.. !..[ 7[ L:' ': ...... ~.: i,... [:'I ...... f:' (..~," "'", 5' T t'.,L ~.~""¢ ..... :~ F 1:< 1! C ,='TR~:Z~'Z.:., FF..',::~C COH'F:'L. ETE F:'OST F,r;..'.¢iC· LOG ,.:.i:"T'AT.T.P.. ......... 9!"IF'/T",'HT Z- I IF..'~t:Y,, ,_ F'R E"- F: F;.'.t-~ C / F', "[', "f' I.J If:.]: f'4G S'T,::-, T .T.' C ).'-~ t.-I F'/i? I-.! T ,..~ ~"~ F' F.: Ii.': -' Fl' I':: A C.: / F:'. T. l" LJ ]:: ]: N G ' A ' ~ ;::i N [:'.' Fl' F;-'. (:'~ Ct F'Z:':U ' .C' ,~.~.'.",ND T[.~.,'.'.;T ' El' ' 5.' ~.-'..~ i"-] D ~1" E,7 T F')3 L! ', T',, [ I · -' ,~",r', '-..-. r-'l-:.',,-.':-; C:: r..,~ .~, ~ .. ,... 5'~. .. I'" ~:'.1 * ]: ~::' "..t.,:... :":-.:. (:'-i ."F : T ".." t::',' L. VI:.":2 ... , [:'ATE' _ .................~.:~s. Gomm'~ss~'OB ~,Tf,,.'T'~:' g~:r ,::., ~'.~..., -. ,~ ~ ~ ~" .,,. '~ ,~, : , · ~ ~ ,..... ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 26, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive A-nchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of following Kuparuk Field wells' ~and 1E-29 If you have any questions, Commission intention to please call me Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) fracture the at 263-4253. RECEIVED Alaska 0~1 & Lias Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ? STATE OF ALASKA , ALASKA L,,~L AND GAS CONSERVATION CO,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-116 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20793 OTHER [] 4. Location of Well SURFACE LOCATION' 203' FSL, 817' FEL, SEC. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB) 12. 6. Lease Designation and Serial No. ADL 25651, ALK 469 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-17 11. Field and Pool KUPARUK KUPARUK POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data RIVER FIELD RIVER OIL 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 i~] (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 al'l 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 the "A" sand in Kuparuk well 1E-17 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid: Gelled Water 282 BBLS Gelled Diesel 69 BBLS Proppant' 12/20 Sand 13,230 LBS :~ ANTICIPATED START DATE' March 26, 1985 Subsequent Work Bcported on F~ No./~ ~ RECEIVED MAR 2 6 1985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use 3/26/85 COORDINATOR Date Conditions of Approval, if any: Approved by Approved Copy ,Returne~ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office BU.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-17 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L97 Enclosures If RECEIVED F E B 0 6 ]985 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA~ ' AND GAS CONSERVATION CO ~ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] - 2. Name of Operator 7. Permit NUmber ARCO Alaska, Inc. 82-116 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20793 4. Location of well at surface 9. Unit or Lease Name 203' FSL, 817' FEL, Sec.16, TllN, RIOE, UM Kuparuk River Unit .,. At Top Producing Interval 10. Well NUmber 1440' FNL, 1196' FWL, See.21, TllN, RIOE, UM 1E-17 At Total Depth 11. Field and Pool 1546' FNL, 1027' FWL, Sec.21, TllN, R10E, UM Kuparuk River Field 5.' Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB] ADL 25651 ALK 469 12' Date SPudded08/15/82 13. Date T.D. Reached08/23/82 14' Date C°mp" Susp' or Aband' i 15' Water Depth' if °ffsh°re 116' No' °f C°mpletions08/26/82 N/A feet MSL 1 17. Total Depth (MD+TVD) 18: Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20' Depth where SSSV set !21:Thickness Of PermafrOst 7885'MD,6567'TVD 7765'MD,6456'TVD YES I~ NO [] 1922 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal/FDC/CNL/BGT, CBL/GR/CCL 23. cASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 296 sx AS II 10-3/4" '45.5# K-55 Surf 2313' 13-1/2" 1175 sx AS Ill & 250 s) AS I ...... 7" 26.0# K-55 Surf 7866' 8-3/4" 650 sx Class G & 250 s) AS I 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) 7613' - 7636' 3-1/2" 7523' 72~3' & 7/~9~' 7587' - 7596' w/8 spf 7373' - 7381 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7381 ' - 7411 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,, 7411' - 7441' N/A , , ,. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ,. Date of Test Hours Tested pRoDUCTION FOR OI L-BBL GAs-MCF WATER-BBL CHOKE SIZE I GAS-OI L RATIO TEST PERIOD I~ I : Flow Tubing Casing Pressure !CALCULATED I~! OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c°rr) Press. : 24-HOUR RATE 28. CORE DATA , . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submitco~c~ E i V ED. NONE FEB 0 6 ]985 AlasK~ Oil & Gas Cons. Commission Anchorage Form 10-407 GRU3/WC55 Submit in duplicate Rev. 7'1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS " ' FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7372' 6094' N/A Base Upper Sand 7440' 6156' Top Lower Sand 7573' 6278' Base Lower Sand 7689' 6386' 31. LIST OF ATTACHMENTS W~rkov~.r W~.I] Hi 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on · . all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. .... Item 16 and 24: If this well is completed for separate production from more-than one interval (multiple completion), so state in item 16, and in item 24.show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate Whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. !rem 28: If no cores taken, indicate "none". Form 'i0~,07 "~" ARCO 011 and Gas Company Well History - Initial Report - Dally I~lnmtleaa: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Dally worR prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE Exp 304875 ICoun~, parish or ~rough North Slope Borough Lease or Unit Title ADL 25651 Re-Completion IState Alaska IWell no. 1E-17 W/O POOL 102 API: 50-029-20793 O~rator ARCO Alaska, Inc. Spudded or W.O. begun Workover IDate IHour 11/15/84 Date and depth as of 8:00 a.m. 11/o5/84 11/06/84 11/07/84 11/o8/84 11/o9/84 Complete record for each day reported 1800 Hrs. l^RCO w.,. 56.24% Prior status if a W,O, 7" @ 7866' Tbg @ 7291', 7765' PBTD, Pull BPV Wtr back brine to 9.6# Move rig f/1E-15 to 1E-17. Accept rig @ 0400 hfs, 11/5/84. Pull BPV. 7" @ 7866' 7765' PBTD, RU to set BPV Wtr back brine to 9.6 ppg Pull BPV, pull GLM dummy @ 7219'. RU tank & kill lns. Pmp 10 bbls, 9.6 NaCl dn tbg, followed by 40 bbl, 10.6#/gal BridgeSal. Displ BridgeSal w/9.6#/gal NaC1; no rtns (ann frozen or plugged. Displ pill to perfs. Open ann & att to circ w/650 psi @ pmp, 0 psi on ann. Pmp press dropped to 0 psi. Shut dh, SI ann. Open ann, start pmp'g ann full w/9.6 ppg NaC1; rtns = badly oil cut NaC1. Wait f/add'l NaC1. Circ well, some crude in rtns. RU to set BPV. 7" @ 7866' 7765' PBTD, POOH, chg colrs on tbg Wt. 9.6 NaC1 Set BPV. ND tree, NU BOPE stack. Tst pipe rams, blind rams to 3000 psi, annular to 1800 psi. Pull on SBR @ 125,000#, sheared out. Fill hole - 9 bbls. Fluid loss 11 bbls/hr. Pmp 15 bbls 10#/gal NaC1, followed by'50 bbl lO.6#/gal BridgeSal, followed by 15 bbls 10#/gal NaC1. Sqz to perfs. Start POOH & chg out butt colts. 7" .@ 7866' 7765' PBTD, POOH, RD csg crews Wt. 9.6 NaC1 POOH, chg colts, fluid loss inc'd f/4 BPH to 20 BPH. WO kill pill. Rec'd CaCO~ pill, spot 50 bbls to tbg, displ'd . £D perfs, POOH & chg out colts, 7765' PBTD, POOH, RD csg crews Wt. 9.6 NaCi Alaska Oil & Gas Cons RIH w/pkr retrv'g tl, pull Bkr pkr loose by releasing w/rightA~ . ' COITiltlJSs[OI1 ~ Cnora hand rotation. Circ out gas bubble, POOH. RIH w/Baker Mod ~ ge bridge plug, set @ 7268', test casing to 2500 psi. POOH. The above Is correct Signature For form preparation and di~Jbution, see Proceduree Manual, SectlBn 10, Drilling, Pagee 86 and 87. Date I Title 11/20/84 Drilling Superintendent ARCO Oil and Gas Company O Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Alaska I County or Parish IState North Slope Borough ILease ADL 25651 or Unit Complete record for each day while drilling or workover in progress Alaska Kuparuk River Date and deptll as of 8:00 a.m. 11/10/84 thru [1/12/84 11/13/84 [[/14/84 11/15/84 The above is correct For form preparation and di~ribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IWell no, 1E-17 W/O 7" @ 7866' 7765' PBTD, Redress tools for attempt @ fish Wt. 9.6 NaC1 ND BOPE, change out well head equipment to 5000#. NU & tst BOPE. RIH w/retrvg tl, wrk on releasing BP. Bridge plug parted @ top of mandrel. MU fsh string #1, RIH, tag fish @ 7292'; kept slipping off, POH. Chg to 2-5/8" OS, RIH, latch fsh; unable to release BP, POH. RIH w/2-1/2" OS; unable to catch fish, POH. RIH w/2-7/8" grapple, latch fsh, rel'd BP, POH; no rec'y. RIH, chase fsh to 7704', POH; did not retrv fsh. 7" @ 7866' 7765' PBTD Prep to run R-3 pkr and retest csg Redress OS w/2-3/4" grapple, RIH, tag fsh @ 7704', POH, LD complete BP & fsh'g string. PU csg scrprs/boot bskts, RIH to PBTD, circ, POH. 7" @ 7866' 7765' PBTD, Rn 3-1/2" compl string PU R-3 prk, RIH, set pkr @ 7294'. Press ann to 3500 psi; OK. Release R-3, POH, LD DP. Rn 6.125" gauge ring/JB; OK. PU FB-1 perm pkr, RIH, set @ 7478'. 7" @ 7866' 7765' PBTD Displace well to crude RIH w/3½" completion tbg, set pkr, shear out of PBR @ 128,000K. Set BPV, ND BOPE, NU tree & tst to 250/5000 psi. Tst pack off to 5000#. Open SSSV & test annulus to 2500#. Displ well to diesel/crude. SSSV @ 1921.87' - Baker FHL Retrv pkr @ 7229.69' Baker FB-1 perm pkr @ 7497.70' - FB-1 pkr @ 7478' WLM TT @ 7523' Date JTitle 11/20/84 "~ AI~CO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit I Well no~ Kuparuk River ADL 25651 I IE-17 W/O Auth. oF W.O. no. T t e AFE 304875 Completion Pool 102 API 50-029-20793 Operator A,R.Co. W.I, ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date 11/5/84 Date and depth Complete record for each day reported as of 8:00 a.m. I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O, I 0400 hrs 7" @ 7866' 7765' PBTD RR, Displace well to crude. Pressure tst tbg to 4800 psi, ball did not shear. Set BPV. RR @ 1800 hr, 11/15/84. Did TD 11/16/84 11/19/84 Released rig 1800 hrs Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 7" @ 7866' RU, pmp pressured 7" X 3 1/2" annulus to 2000 psi. Load tbg w/diesel & slowly pressured up to 5200 psi. Shear sub 500 psi pressure on released. Bled pressUre off tubing. annulus. Secure well. INew TD I PB Depth Date l Kind of rig 1/15/84 I Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7765 ' ~°z'a~e ['°mmJgSjoa Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. !C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date ITitle /~)j/ ~_ _ _] 11120/84 For form preparation and distribu~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Ataska, thC. post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 january 29, 1985 Mr. C. V. chatterton commissioner state of Alaska Alaska Oil & Gas ConservatiOn commission 3001 ?orcupine Drive Anchorage, AK 99501 SUBJECT' 1E-17 Dear Mr. ChattertOn' Report for the subject well. Enclose~ is a Subsequent Sun~rYcall me at 263-4944. you have anY questions, please Sincerely, Gruber Associate Engineer aG/tW GRu3/LB8 J~ncl osure$ RECEIVED F' E 8 0 4 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a SubSidiary ct AtianticRichtietdC°mpan¥ STATE OF ALASKA '-' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Narc~ Ql:lera~:or /~1 asKa ~ Inc. 3'Ad~r. esD. Box 100360, Anchorage, AK 99510 4. Location of Well 5~Jrface: 203' FSL, 817' FEL, Sec.16, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 12. I6. Lease Designation and Serial No. ADL 25651 ALK 469 7. Permit No. 82-116 8. APl Number 50- 029-20793 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-17 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). Accepted rig ~ 0400 hfs, 11/05/84. Killed well. ND tree. NU BOPE & tstd - ok. Pulled tbg & pkr. Set bridge plug @ 7268'; tstd csg to 2500 psi - ok. Bridge plug parted while attempting to reset it. Fished and recovered bridge plug. Set FB-1 pkr @ 7478'WLM. Ran 3-1/2" completion assy w/tail @ 7523', FHL pkr @ 7230', & SSSV @ 1922'. Dropped ball & set pkr. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel and crude oil. Set BPV. Secured well and released rig @ 1800 hfs, 11/15/84. RECEIVED F E B 0 ]985 Aiasl(a 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~ ~j'~j~J/[_? ,~(_~ Title Associate Engineer The space belfp for Commission use , ConditiOns of'Approval, if any: Approved by_ Form 10-403 GRU3/SNi 5 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Ir~'~ Post Offic= Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 17, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 1E-17 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-17 to a selective single completion. Since we expect to start this work on October 27, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG/tw GRU2/L16 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ' ALASKA OIL AND GAS CONSERVATION uOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 203' FSL, 817' FEL, Sec.16, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' 12. Perforate Stimulate Repair Well 7. Permit No. 82-116 8. APl Number 50- 029-20793 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-17 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0il Pool ADL 25651 ALK 469 Check Appropriate Box To Indicate Nature of Notice. Report. or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) [] Alter Casing [] Perforations [] ~ Abandon [] Stimulation r-I [] Change Plans [] Repairs Made [] Pulling Tubing (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other Pull Tubing ,~ Other (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 convert well 1E-17 to a selective single completion. fol lows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 500~psi, SRRA BOP stack will be used on well work. BOP equipment will be 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. RECEIVED Estimated Start: October 27, 1984 OCT 2 21 , 5~bseque~'~t Work Reported on Fo~m- No/~Dat~J L~~5a~gska 0il & Gas cons. c0mmissi - Anchorage 14. I hereby ce~fy that the foregoing is true and correct t° the best of my knowledge. The ,,,c~/el~fo~r~//~miss'on" Conditions of AppC'6val. if any: Date Approved by Submit "Intentions" in Triplicate Form 10-403 Rev 7-1-~O GRU2/SN18 and "Subsequent Reports" in Duplicate ARC° Alaska, Inc. ,- ...-.; :; ,.~-~ 3£~. ,' '. '.: ':' "- , ,-':. :-. L :: 9~f, iC' ".: · ~. ~;c'r',~ 9'.'- 277 5~37 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco 1C-5 " " 4/13/84 " 1C-6 Gas Disp. 5/16/84 Otis 1C-7 PBU 4/20a21 Camco 1C-9C~alloff Test 4/29/84 " lC-lO.~-q~_ " " 5/06/84 " 1D-1 Static BHP 4/19/84 " 1D-5 Falloff Test 4/29/84 Otis 1E-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 '~ 2F-13 " " 5/14/84 Otis 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat Receipt Acknowledged: B. Adams Camco DISTRIBUTION Date W.V. Pasher C.R. Smith F.G. Baker P. Baxter BPAE Dz illing Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska · Sohio Union Chevron NSK Operations R&D Well Files STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COIv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-116 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20793 4. Location of Well SURFACE LOCATION' 203' SEC. 16, TllN, R10E FSL & 817' FEL, BOTTOM HOLE LOCATION' SEC. 21, T11N. R10E 5. Elevation in feet (indicate KB, DF, etc.) 105 ' (KB) 12. 1522' FNL, 1066' FWL, I 6 . Lease Designation and Serial No. ADL 25651 9, Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-17 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). On January 5, 1983, Kuparuk River Unit Well 1E-17 was stimulated with 96% bbls of 12% HC1. All surface lines and BOP's were. pressure tested to 4000 psig and treating pressures were kept below this value. Following the acid treatment 75MCF of nitrogen was injected via the coiled tubing to aid in the cleanup process. Following cleanup the well was switched to the CPF. The post acid oil rate for this well was 2952 BOPD as compared to the pre-acid rate of approximately 300 BOPD. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERAI IONS The space below for Commission use COORDINATOR Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "lnterttions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK 'ENG I NEERI'NG TRANSMITTAL # 70?,/,o TO' Wi'lliam Van Allen DATE' ,.~)-' ~,~-.- FROM' D.W. Bos'e/ShelbS J. Matthews WELL NAME' .,<~__~_ ~NC~-/(3~,~,? Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F- F.ILM, T-'TAPE, C~-"~ ? .- R~E I PT. ACKNOWLEDGED' //~LEASE-RETURN RECEIPT TO: · ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/311 o P O. BOX 360 ANCHORAGE, AK. 99510 : i ',- .:i' f~ DATE: [,,.~, ' ~': ~'~:.; TO: william VanAlen FRCM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the follc~ing: /k~sY,~ 0~ & Sas euo~s, commissm~ At'Iii: IDtL13~. T.. JOI~qSO~ - ~A/311 1:'. O. BO× 360 A1~01~_(~, l~. 99510 TO: William VanAlen FROM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.~ASE NOTE: ~~F- FILM, T- TAPE, PC-PHOTOCOPY ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Bo/"--,~ ) Post Office ~ Anchorage, AlasKa 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager October 28, 1982 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Attached are notices of our intent wells 1E-14, 1E-17 and 1E-16. If you have any questions, please R. L. Stramp Kuparuk Operations Coordinator call RLS/b xc' D. J. Caffrey - AFA 350 L. M. Sellers - ANO 332 E. A. Simonsen - AFA 331 H. C. Vickers - AFA 326 to stimulate Kuparuk me at 263-4528. RECEIVEI] OCT 2 8 ]982 Alaska 0il & Gas Cons. Cummission Anchorage ARCO Alaska. inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION C(J,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator ~'~#~1 7. Permit No. ARCO ALASKA, INC. ~j~82-116 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 9 n,, ~]On_ 50-029-20793 4. Location of Well %~ ~'~' 9. Unit or Lease Name SURFACE LOCATION: 203' FSL & 817' FEL, ~b~Oho~°?~.~ KUPARUK RIVER UNIT SEC. 16, TllN, R10E '~70a'~'°~¢,,__.-1'~.~ 1E-17 BOTTOM HOLE LOCATION: 1522' FNL, 1066' FWL, /11. Field and Pool SEC. 21, T11No R10E / KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. ! KUPARUK R I VE R 0 1 L 105' (KB) I ADL 25651 ~ POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' (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.) 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). ARCO Alaska, Inc. proposes to stimulate Kuparuk well 1E-17 with a coiled tubing acid treatment to improve productivity, Well tests indicate that this well currently produces approximately 300 BOPDo We feel that this rate can be substantially improved by acid stimulation. The treatment will consist of 96 bbls. of 12% HCl with mud and silt I remover and iron sequestering agent. Coiled tubing will be used to spotI acid across the perforations and to squeeze the acid into the formation. Treating pressures will be' kept below 1300 psig (tubing pressure) to prevent fracturing the formation. Nitrogen injection via the coiled tubing will be used, if needed, to accelerate the cleanup process. The well will be cleaned up through a portable test separator, then switched to the CPF for a production test. ANTICIPATED START DATE' 11-1-82 r~ Subsequent Work Beported on Form No. '"2-*{~ Dated 14. I hereby ~rtif~/ tha; the forego,ng ,s tru'e'and c~3rrect tO the best of my knowledge. KUPARUK Signed~~'t C. ~~ Title OPF_RA_T_~ONS COORDINATOR The space t~ow for Commission use Conditions of Approval, if any: Approved ~.{p~)~'owd Copy' ISSIONER COMM ~ommission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCo .~laska, I~nc. Post Office Bd~''~1 Anchorage, Alaska 99510 TelePhone 907 277 5637 October 14, 1982 Mr. C. V. 'Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. ChattertOn. Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1-G-2 1G-3 WSW-3 WSW-4 A1 so enclosed are well completion reports for- 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG-11m Enclosures GRU2/L15 ARCO Alaska, Inc, is a subsidiary of AtlanlicRichlieldCompany STATE OF 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 ARCO Alaska, Inc. 82-116 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o-029-20793 4. Location of well at surface ~~ 9. Unit or Lease Name 203'FSL, 817'FEL, Sec. 16, T11N, R10E, UN I WmF~ED ii Kuparuk River Unit At Top Producing Interval 1440'FNL, l196'FWL, Sec 21, TllN, RIOE, UN ilSurf' ~...,. lO. WellNumber · ~ 1E-17 At Total Depth 11. Field and Pool 1546'FNL, 1027'FNL, Sec. 21, T11N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106'RKB[ADL 25651, ALK 469 .Kuparuk River 0il Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. [15. Water Depth, ifoffshore {16. No. of Completions 8/15/82 8/23/82 8/26/82 .] ]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 I 21. Thickness of Permafrost 7885'MD, 6567'TVD 7765'MD, 6456'TVl)YESJi(] NO[]11896' feetMDI 1450' (appr0x) 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal/FDC/CNL/BGT, CBL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 296-~x AS II 10-3/4" 45.5# K-55 Surf 2313' 13-1/2" 1175sx AS III & 250~.x AS I 7" 26.0# K-55 SUrf 7866' 8-3/4" 650sx Class G & 250_~x AS I 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) 7613' - 7636' 3-1/2" .7291' 7262' 7587' - 7596' 7373' - 7381' w/8 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7381 ' - 7411 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7411' - 7441' N/A · ,, .... ~I.A " PRODUCTI°N TEST Date First Production I Method of operation (F[0wing, gas lift, etc.) '"Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD "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 oil, gas or water. Submit core chips. None OCT I 1982 Ab.:.~.(a 0ii & Gas C.gns. 6cmm~s.:;i:m Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 7372' 7440' 7573' 7689' TRUE VERT. DEPTH 6094' 6156' 6278' 6386' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drillinq History, Gyroscgpic Survey _(2 copies) I hereby certify that the foregoing is true and correct to the best of my knowledge Sr. Drilling Fngm¢ , 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- ~ .~..~... ,,,~:~,~- C~s ln}ection,. , Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". I::¢-,rm 1 i'1-4f/7 : i 1E-17 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1230 hrs, 08/15/82. Drld 13-1/2" hole to 2337'. Ran 57 jts 10-3/4" 45.5#/ft, K-55 BTC csg w/shoe @ 2313'. Cmtd 10-3/4" csg w/1175 AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7885'TD (8/23/82). Ran DIL/SFL/GR/Cal/FDC/CNL/BGT. Ran 171 jts 7" 26#/ft K-55 BTC csg w/shoe @ 7866'. Cmtd 7" csg w/650 sx Class G cmt. Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/200 bbls H20, 250 sx AS I, & 97 bbls Arctic Pack. Ran gyro. Ran CBL/GR/CCL f/7690'. PBTD @ 7765'. Perf'd 7613'-7633', 7587'-7596', 7373'-7381', 7381'-7411', 7411'-7441' w/8 spf. Ran 3-1/2" perf completion assy w/tail @ 7291' & pkr @ 7262'. Tstd tbg hanger to 5000 psi - ok. Tstd packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Displaced well to diesel. Dropped ball & set pkr w/2500 psi. Pressured ann to 100 psi. Closed SSSV @ 1896'. Bled tbg to 100 psi - held for 20 min - ok. Opened SSSV - sheared out @ 3400 psi. Bled tbg to 750 psi, pressured ann to 2000 psi; held for 20 min - ok. Closed SSSV. Bled tbg & ann to 0 psi. Set BPV. Secured well & released rig @ 2300 hrs, 08/26/82. 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O0 -~5000. O0 -2500. O0 -2000. O0 -! 500. O0 -!000. O0 -500. O0 HORIZONTRL PBOJECT ON ARCO Alaska, Inc. Our Boss ~yroscopic Survey Job No. Boss-16105 Well: ~lE-17 (S~C16 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: August 24, 1982 Operator: John Coogle Scale: 1" = 500' NORTH 'Surface Location (203NSL 817WEL) ~-500.00 --1000.00 --1500.00 --2000.00 0.00 ~000.00 2000.00 3000.00 4000. O0 5000.00 6000. O0 3855.45' ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16105 Well: ~lE-17 (SEC16 TllN R10E) Kuparuk Field North Slope, Alaska Survey C~te: August 24, 1982 Operator: John Coogle Scsle: 1" = 1000' @ S63° I'W \ \ \ \ ..~7885 7000.00 I 1000.00 2000.00 3000.00 I 4000. O0 VERT;[CFIL PROJECTION Suggested form to be inserted in ~each "Active" well folder to check for timely compliance with our regulations. '-' Operat6~, ~ell' N~' and Number . Reports .and Materials to be received by: ~ -' ~- Date -Requ~.' red Date Received Remarks. Completion Report - Yes / Wel 1 .History Yes , , ,, . ~ ~ , Core ~Scription ~~ W-e~ ,,,, ,, , , ., Registered ~ey Plat. y.~. Inclination Su~ey ~./~ Drill St~ Test RemUs ~~ ~"~ ~u~on T~t Ro~s ' ~~ /~ ~/-~--_ ~./'~ C, . ,,. ,. Digitiz~ ~ta Y,~,, r /~- ..... W~ ~ ~ '~.. i , , . ., . ,,,. ARCO Alaska, Inc. Post Office B, Anchorage, AlaSka 99510 Telephone 907 277 5637 September 10, 1982 Mr. C·. V. Chatterton CommisSioner · State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK ' 99501 SUBJECT' State Repor~ts Dear Mr~ Chatterton' Enclosed are monthly reports for August on these drill sites' 1-19 13-32 1E-30 2,23 13-34 1G-1 2-26 14-21 1G-2 6-19 18-3 1F-5 6-20 18-6· WSW-2 6-21 -t!7~ii~? Also enclosed is a well completion report for Kuparuk 1E-16. SurVeys for 2-22 and .6-18 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A' VanDusen District Drilling Engineer PAV/JG:llm Enclosures GRU1/L93 S E'P 1i, g2 Gas Cons. C0rnrni~,~i~n ARCO Alaska, Inc. is a'subsidiary of AtlanticRichfieldCompahy STATE OF ALASKA ALAsK L AND GAS CONSERVATION C/-%IMISSION MONTHLY REPORT OF DRILLING AND WOFIKOVER OPERATIONS · Drilling we~( J~ Workover operation [] :2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-116 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20793 4. Location of Well atsurface 203' FSL, 817' FEL, 'Sec. 16, T11N, RIoE, UN 9. Unit or Lease Name Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' RKBI ADL 25651 ALK 469 10. Well No. 1E-17 11. Field and Pool Kuparuk River Fie]d Kuparuk River Oi] Poe] For the Month of August ,1982 q 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~ Spudded we]] ~ 1230 hrs, 08/15/82. Drld 13-1/2" hole to 2337';ran, cmtd and tstd 10-3/4" csg. Drld 8-3/4" hole to 7885'; ran open hole logs; ran, cmtd and tstd 7" csg. Ran logs. Perf'd well. Ran 3-1/2" completion assemb]¥. Secured well and re]eased rig ~ 2300 hrs, 08/26/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/fi, U-40 conductor set @ 78' Cmtd w/296 sx AS II , · · · :.10-3/4" 45 5#/ft K-55 BTC csg w/shoe ~ 2313' Cmtd w/1175 sx AS III 7" 26 O#/ft, K-55, BTC csg w/shoe ~ 7866' Cmtd w/650 sx Class G , · · · & 250 sx AS I. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/Cal/FDC/CNL/BCT CBL/GR/CCL f/7690'. DST data, perforating data, shows of H2S, miscellaneous data N/A SEP i 4 ]~82 0il & Gas Cons. Commissior~ l~,nch0ra.q~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~.~.~Ul~~~// _ ,-- _ TITLESt' Drilling Engineer_ .............. DATE ~//~.~' NOTE--Repor/1/'on/his for~n is required for each calendar month, regardless of the status of operations, and must be fi ed in duplicate with the Alaska Oil and Gas C~onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form -10-404 Submit in duplicate 1E-17 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1230 hrs, 08/15/82· Drld 13-1/2" hole to 2337'· Ran 57 jts 10-3/4" 45.5#/ft, K-55, BTC csg w/shoe @ 2313'· Cmtd 10-3/4" csg w/1175 AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC, cmt, FS & 10' new form· Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7885' TD (08/23/82). Ran DIL/SFL/GR/Cal/FDC/CNL/BCT. Ran 171 jts 7" 26#/ft K-55 BTC csg w/shoe @ 7866' Cmtd 7" csg w/650 sx Class G cmt ~ ~ ~ · · Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" ann w/200 bbls H20, 250 sx AS I, & 97 bbls Arctic Pack. Ran gryo. Ran CBL/GR/CCL f/7690' PBTD @ 7765' Perf'd 7613'-7633' 7587'-7596' 7373'-7381', 7381'-7411', 7411'-7441' w/8 spf. Ran 3-1/2" perf completion assy w/tail @ 7291' & pkr @ '7Z~2_~. Tstd tbg hanger to 5000 psi - ok. Tstd packoff to 3000 psi - ok. NU BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr w/2500 psi. Pressured ann to 100 psi. Closed SSSV @ /~L,~ . Bled tbg to 100 psi - held for 20 min - ok. Opened SSSV - sheared out @ 3400 psi. Bled tbg to 750 psi, pressured ann to 2000 psi; held for 20 min - ok. Closed SSSV. Bled tbg & ann to 0 psi. Set BPV. Secured well & released rig @ 2300 hrs, 08/26/82. JG:sm 09/07/82 GRU/DH45 SEP Z 4 Alaska Oil & Gas Cons. Comrnissior~ ant,borage MEMOR^NDUM Stale of Alaska TO: THRU: FROM: ALAS~ ~ AND C~%S CONSERVATION COMMISSION C. ~. ~%t~ton . DATE: August 18, ~ - ~()/ ~,~E .O: [08~/A Commi ssioner TELEPHONE NO: Bobby ~'oster ~trole~ Ins~ctor 1982 SUBJECT: Witness BOPE Test on ARCO ' s 1E- 17 Sec. 16, TllN, R10E, U~J Permit #82-116 Tuesday, .ADgUSt.!7,__!982 - The BOPE test began at 2:30 p.m. and ~as concluded at 4:00 p.m. As the BOPE Inspection Report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 1E-17. 4/80 z~-~ ,~-~ , ~ STATE OF ;d,ASKA ALaSKa% OIL & GAS CO;;SERVATIO;I COM~']~SSION B.O.P.E. Insl;ection Report Location.: Sec /~ Drilling Contractor Location, General Well Sign General Housekeeping Reserve-pit . Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure Test Results: Failures ACCU~'IULATO R SYSTEM Full Charge Pres sure ,~iP O,QO ps ig Pressure After Closure /~OO psig 200 psig Above Precharge Attained: -- mind'se. Full Charge Pressure Attained: ~ min /~ se Controls: Master ~. ,. Remote tg.~k Blinds swi.t=ch coy__e_~ Kelly and Floor Safety Valves Upper Kelly. / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure !! Choke Manifold ~_~ Test Pressure II Values / I! NO. flanges ~3 ~ ilAdjustable Chokes / l Hydrauically operated choke Test Time~L"~s .. Repair or Replacement of failed equipment to be made within ---' days and Inspector/Commission office notified. Rem'arks Distribution orig'~ - AO&GCC cc - Operator cc - Supervisor Inspec ' '~. ~r. Jeffrey B. Kewin Senior Dri I Ii'rig Bngineer ARCO Alaska, Inc. Po O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk ltiver Unit 1E-l? ARCO Alaska, Inc. Permit No. 82-116 Sur. Lee. $I?*FBL, 203'FSL, Sec. 16, TX1N, R10E, UM. Btmhole Lee. II05*FWL, 14Z¢'F~L, Sec. 21, TIlN, R10E, UM. Enclosed is the approved application for permit to drill the above re fereneed we I 1. Well samples and a mud log are not required.. A continuous directional survey is 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 systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.8'/0 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the 5tare is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control Art, as amended. Prior to co~n~enctng operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Co~mission may be present to witness M~. Jeffrey B. Iiewin Kuparuk River Unit 11~-17 -2- August 6, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event .of suspension or abandoranent, please give this office adequate advaaee notifieatton so that we may have a wi these present. Vet,./ tl'uly y~urs, Chairman of BY ORDER OF THE Alaska Oil and Oas ~nservation ~tsaion Ene!osure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enel. C'VC.' be ARCO Alaska, Inc. r~ Post Office E,~ . 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 4, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-17/1E-4 Well Crossing Dear Mr. Chatterton: Reference is made to our application for Permit to Dirill'~Kuparuk River Unit Well 1F~-17, which was sub- mitted for your review on July 14, 1982. As noted, well 1F~-4 crosses under the subject proposed well path a distance of 86 feet at 1763' TVD. This distance was calculated utilizing the completion gyro survey~ on 1F~-4 and the straight-line projected well path for 1F~-17. According to surveying company data, the rated accuracy of the type of tool utilized to survey IE-4 would result in an ellipse of uncertainty at the crossing interval-of appro×imatelY 67' x 14'. In addition, utilizing the expected standard deviations of the magnetic single shot survey data for well 1E-17, its ellipse of uncertainty would be 89' x 18'. Even assuming the worst case situation,'the ellipses will not intersect. Please note that all of these calculations are based upon a straight-line projection of the well path from surface to total depth for the proposed 1E-17. In reality, the well will be led to the left 6-8° to allow for normal right-hand walk, which will increase the Closest crossing distance, further reducing the chances of collision. It is our intention to analyze all future corssings closer than the 200' minimum, as stipulated in Section 20 AAC 25.050. of the current regulations, and include ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany RECEIVED AUG - i982 0ii & Gas Cons. Commission Anchorage Mr. C. V. Chatterton August 4, 1982 Page 2 a statement with our applications for Permit to Drill regarding our analysis and precautionary measures that will be taken to avoid a collision. Hopefully, this will aid in expediting the review and approval process of future permits. As we anticipate spudding well 1F.-17 on or before August 19, 1982, any efforts to expedite the review and approval process would be greatly appreciated. Sincerely, S .~~. ~~~~neer JBK:llm cc: Well File, 1E-17 K.6,5 RE£EIVED AUG - 5 1982 Alaska Oil & Gas Cons, Commission ARCO Alaska, Inc. Post Office Bo. 50 Anchorage, Alaska 99510 Telephone 907 277 5637 August 4, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1R-17/1E-4 Well Crossing Dear Mr. Chatterton' Reference is made to our application for Permit to Drill.Kuparuk River Unit Well 1E-17, which was sub- mitted for your review on July 14, 1982. As noted, well lB-4 crosses' under the subject proposed well path a distance of 86 ~feet at 1763' TVD. This distance was calculated utilizing the completion gyro survey~ on 1E-4 and the straight-line projected well path for lB-17. According to surveying company data, the rated accuracy of the type of tool utilized to survey 1E-4 would result in an' ellipse of uncertainty at the crossing interval of approximately 67' x 14'. In addition, utilizing the expected standard deviations of the magnetic single shot survey data for well 1E-17, its ellipse of uncertainty would be 89' × 18'. Even assuming the worst case situation, the ellipses will not intersect. Please note that all of these calculations are based upon a straight-line projection of the well path from surface to total depth for the proposed 1F~-17. In reality, the well will be led to the left 6-8° to allow for normal rightZhand walk, which will increase the closest crossing distance, further reducing the chances of collision. It is our intention to analyze all future corssings closer than the 200' minimum, as stipulated in Section 20 AAC 25.050. of the current regulations, and include RECEIVED' ARCO Alasl~a, Inc. is a subsidiary of AtlanticRichfieldCompany ;Alaska Oil & Gas Cons. Comrnissior~ Anchorage . Mr. C. V. Chatterton August 4, 1982 Page 2 a statement with our applications for Permit to Drill regarding our analysis and precautionary measures that will be taken to avoid a collision. Hopef. ully, this will aid in expediting the review and approval process of future permits. As we anticipate spudding well 1F.-17 on or before August 19, 1982, any efforts to expedite the review and approval process would be greatly appreciated. Sincerely, S~~n. ~~~~neer JBK: 1 lm .. cc: Well File, 1E-17 K.6.5 AUG - 5 i982 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Bo,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-17 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1E-17, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating~the relative location of Kuparuk wells 1E-1, 1E-2, 1E-3, 1E-4, 1E-15, 1E-16. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/JG: 1 lm Enclosures GRU1/L47 EL'EiVED JUL 1 51982 Oil & Gas Cons. Commission /{nchorag9 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany /"'~. STATE OF ALASKA ALASKA O,L'~ND GAS CONSERVATION CO~-,,v'ilSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~[~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC REDRILL [] DEVELOPMENT OIL~]( SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface RE[EiYED 9. Unit or lease name 817' FEL and 203' FSL, Sec. 16, T11N, R10E, UM Kuparuk River Unit At top of proposed producing interval 10. Well number 1320' FWL and 1320' FNL, Sec. 21, T11N, R10E, UM JUL 1 5 1982 1E-17 At total depth 11. Field and pool 1105' FWL and 1424' FNL, Sec. 2'r, T11N, R10E,~, nl~lq2Skauil&GasOons. O0rnm[ssi0n Ap. chor2,q9 Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk River 0i 1 Pool 106' RKBI ALK 469 ADL 25651 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14,. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 Miles NW Deadhorse miles 1105 feet 1E-4 well is 86' away ~ 1763' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease i8. Approximate spud date 7787' MD, 6581 ' TVD feet 2560 09/18/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2764 psig@__~0°F Surface KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 37 o] (see 20 AAC 25.035 (c) (2) 3140 .... psig@ 6106 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZe- CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ., I 115' ±250 cf ~. 4"' 16- 65# H-40 Welded 80' 35, I 35, 115'I 13-1/2" 10-3/4" 45.5# K-55 BTC 2640' 33' I 33' 2297' 2200' lO00sx AS III + I I i I 250sx AS II 8-3/4" 7" 26# 31' I 31' 7787' 16581' 1180sx Class G K-55 BTC 7756' I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7787' MD, (6581'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2764 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The well will be completed with 3-1/2", 9.2# J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space belo~/fo~J~r'~missj~ US~-- ~' /,- / CONDITIONS OF APPROVAL DATE 7./~.~ L Samples required Mud log required Directional Survey required APl number []YES ~-N.O [-]YES ~4Xl O [~ES []]NO 50_ ~ ~L.~ - %.,~ 7¢..? Permit number ~~ ~t,-- j,,~, SEE COVER LETTER FOR OTHER REQUIREMENTS - APPROVED BY__ ~, ,COMMISSIONER DATE ,/¥~'~,~'~t ~, 1.98~- ~ V " ~ "' ~; 7- /' by order of the Commission Form 10-401 GRU1/PD6 Submit in triplicate D ...................... ........ t .JUl_ A~sska ()il & Gas Cons. -®. O. . Surface Diver~. System 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. Maintenance & Operation ~- l. Upon initial installation close annular I ~reventer and verify that ball valves ) . have opened properly. ' · ~ 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3~ Close annular preventer in the event 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 an~. circumst~nc~'s. --~ 16" Conductor JUL ! S Oil & Qr~s~, .D°rls.. Commission 13-5/8" 5000 PSI RSRRA DOP STACK ' PIPE RRMS . . ') :--- .... .. -_:-:.-.. .'.-. ' L~'E[ WITH HYD~ULIC FLUID; 2. ~SURE ~T ACC~.i~TOR PRESSURE IS ~ PSI WITH. 1500 PSI D~I~ OF ~E RECTOR. -. 3. OBSERVE TIRE IHEN CLUE ALL D~;ITS SI~LYANE- OUSLY ~;D RECORD ~E TI~Z AND PRESSD~ '- ING ~R ALL UNITS ARE CLOSED WI~H ~GING _ P~ OFF. 4. RECORD ON IADC REPORT. ~E ACCEPT~ LIMIT IS 45 SECO~;~ CLUING ~IME AND 12~ PSI R~INI~ BR~SURE. - . · - DRILLING F, t .... ) _ , P i PE' RRHS . : -_ 'i --- - :- 15. 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI-drilling spool w/choke and kill lines .. .- - , 13-5/8" 5000 PSI pipe rams- .. 13-5/8" 5000 PSI. blind rams 13-5/8" 5000 PSI annular- .. ) -.::.:.; ..... . '. . ....- t ' 13-5/8" BOP STACK TEST l. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK I"~.AT ALL HOLD D(Z,~N SCRE14S ARE FULLY RE- IR. ACTED. PREDEiE~,INE DEPTH IHAI TEST PLUG · . WILL SEAT AIID SEAi Ih' WELLHEAD. RUtt Iii LOCK D(7~N SCR~,IS IN HEAD. CLOSE A~;:(ULAR PREVENTER AND C~tOKES /~ BYPASS VALVES 0;( MA}IIFOLD. TEST ALL CONPO,~;ENTS TO 250 PSI AND I40LD FOR lO MINUTES. · INCREASE PRESSURE TO 1800 PSI AND MOlD FOR 10 MINUTES. BLEED IO ZERO PSI. OPEJX AIiiiULAR PREVBXTER AND CLOSE TOP' .~[' OF PIPE INCREASE 'PRESSURE TO 3000 P$I AND HOLD FOR l0 MI N:IJTES. CLOSE VALVES DIRECTLY UPSTREA:! OF C]40KES. ' BLEED Dg~NS.TREgJ~ PRESSUPJE ~0 ZERO PSI YO lEST VALVES. TEST RB-LAINING UNTESTED M/tN[FOLD VALVES, IF ANY, WITH 3000 PSI UPSTRF~4 OF VA~LVE ~d(D ZERO PSI DC~NSTRF_~. BLEED SYSTE~('.)~ TO ZE 0 PSI. - . OPEN TOP SET OF PIPE RARS AND CLOSE BOI-~OR SET OF PIPE INCREASE PRE~SURF TO 3000 PSI AND MOLD FOR l0 RI)~UIES.. BLEED TO ~£RO OPEN BOTIOM SET OF PIPE RAMS. BACK OFF RUN- I(I)(G JOINT AND.PULL OUT OF HOLE. CLOSE BLIND RA~,LS AND TEST TO 3000 PSI FOR lO HI);UTES. BLEED 'TO ZERO PSI. OPER BLII(D PJkHS AND RECOVER TEST PLUG. RAKE SURE H~'IIFOLD /UiD LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET 'IN DRELLIliG POSITI~I. · - - TEST STAZiDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS A~;D I);SIDE BOP TO 3000 PSI RECORD TEST I)IFO?J4ATION ON BLOWOUT E'REYE~ITER lEST FOPJ4 SIGht A~ID SEND TO DRILLI~iG SUPER- VISOR. - · . - ~ . - '" ' PERFOPJ-I CO1PLETE BOPE TEST O;~CE A WEEK FU~CTIOt~ALLY OPERATE BOPE DALLY. . -:. .. -' I I WELL #8 Y 5,960,~00o2]0 X = .. 549 889.825 70°I 8111. z83" LAT ,-- LONG = 149°35~45o185'' :LL #1 #7 ' Y = 5,960.,480.368 X = 549,889.~6 LAT = 70918"10.104" LONG = 149°35: 45.219" .. · #6 y ' 5,~60936~;207' X = " 49 889.2'55' LAT = .70~18108-923'' LONG = 149°35745°249''' #5 Y = 5,960,240.410 · ' X =' 549:,889.039 LAT = 70°18'107o744'' LONG = 149°35145-z78'' :LL #4 Y = '5,9601,120'-155 x = 549,889.818 LAT ' 70°18~06-561''' LONG = 149°35~45-279'!. #3. Y = 5',960,000o596 X =. 549,889.506 LAT =. 70°18'05-386'' LONG = .149°35.t45-311'' #2 X = 5,959,880.504 y = 549,889.996 LAT = '70°18~04-204'' LONG TM 149,35'45.320" X = '5,959,760.244 y ' ' 549,889.514 LAT = 70°~8~03-022'' LONG'= 149°35145-358'' ~-~.~ OF,a./., ~:'~... ~::' ~ '.... _ · ;.. '..:~,,_ ~;~ i;.i;[[" ;:,' .;'i;' ~1[ CERTIFY . =-~"~'~" ....... ' I ,,!,:.'.;i::':i::.:.PRoPERLy' REGISTERED AND LICENSED ~ ~"::" ": 'To PRACTICE LAND.SURVEYING IN ' , · ~- ,A~': ~-~ ~' '~ ' ... ..'.:':.'..'." :".THE. STATE OF ALASKA AND THAT .~,[EIV~ ':i' '.-: THIS PLAT REPRESENTS AN AS' '~ ' --:.:::!.,_L.-..' 'BU I LT-' SURVEY MADE BY ME, AND : ..... o' .~. ,~C,o"~ "~":.'.'.-:';.ji'.'..THAT ALL.DIMENSIONS AND OTHER jUN~ ,~.jLmo~- ... .. ; ~:'?'" 'DETAILS'ARE CORRECT, AS OF: ' ' ." , .o~ v,,, 'f~ -., . ,-' .,-,,-~ . 0il:.&'.,. :,, ~.,~.,.~,~;~ . ~ ~ ~,. ~'~;ilrSSl~ ,~ ~. ~.;. ~.f,:-~ . · --.'" DATE '~'/'1~/~ "-! '_.;'. ' AInsk~ '" G~sC0ns ~' ' "~'.'~."'~Z"-':'"' . . ~., : · , .. ,'....' .'' - . , · . , , · l").G. E:: WEL'LG 1-]-7 Loo^TIOi,-l · AtlanticRichfieldCompany '0 NORTH AMERICAN PRODUCING DIVISION ASKA DisTRICT ~KUPARUK CHECK LIST FOK NEW WELL PERMITS IT~'M APPROVE DATE ~. (2) Loc ,,P"4f:: ~ thru. 8) (3) Admin(.,~thru 11) asg (12 thru 20) Company (5) .roPE (21 thru 24) (6) Add: %~ oAg- ~--~Z.- 1 Is the permit fee attached ............................ 2] Is well to be located in a defined pool .... , ......... iii ]] 3. Is wel'l 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 plat included ... 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait ............... 9. Does operator have a bond in force .............. ' ........ 10. Is a conservation order needed ..... ......... , ........... 11. Is administrative approval needed ....................... 12o 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Lease & Well No. 25. YES NO Is conductor string provided ........... '.' ........................... Is enough cement used to circulate on Conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst, Is this well to be kicked off from an eXisting wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating -Test to 3o~ psig ../7~, Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: IE- ~ ;~ oaa~/~,~,;a,, 0;! ~o~)1 ~,~ ,Yo~o ~ d~OPI3.. , J Geology: Engineering: 'dVA ~ JK~z"~ RAD ~ / rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 6'50/0o0~" t-~,'1 g~o 1i/~o ~u Well Histo.ry File APPENDIX Information of detailed nature ,that is not particulady 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'specialeffort has been made to chronologically organize this category of information. bVP OlO,HO1 V~.iRIFICATIO~ [,ISTI~G ** REEL HEADER ** SERVICE NAME :$ERVIC DATE {82109/ 3 ORIGIN : REEL NA~E :REEL CONTINUATION # PREVIOUS REEL COMMENT8 :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE 182/09/ 3 ORIGXN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS EOF FILE HEADER ** I~E N, ~E ~$ERVIC,O0! ERVICE NAME ~ PR~VIOU~ F:IhB ~ :**: !NFORMATION RECO:RD8 ** ~NEM CONTENTS U'MIT: TYPE 'CATE :::S-I:ZE' CO:D:~: bVP 010,H01 VERIFICATION t,£STIN(; ** RECORD TYP~; 04,7 ** RECORD TYPf3 047 ** COMPANY = ATLANTIC RICHFIELD COMPANY WEb[, COUNTY = NORTH SLOPE B~R~t!GH STATE = ALASKA JOB NUMBER AT ACC: 10707,65501 RUN #1, DATE LOGGED: 22 AUG 82 b'DP: RIK BOTTOM. DEPTH = 7822 OPDEPTH ASXN~ bVP OlO,HOl VERIFICA'rlDN LISTI~:G PAGE DENSITY = g,7 LB/G VISCOSITY = 40 S PM = 10,3 FLUID bOSS = 5,8 C3 RM m 3~190 ~ 65 DF RMF = 3,190 ~ 65 DF RMC = 2,160 ~ 65 DF RM AT BHT = 1,417 ~ 155 DF MATRIX SANDSTONE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 ! 66 I 8 4 7~ 6O 9 4 65 ,1I~ 0 I 66 0 DATUM SPECIFICATION BLOCKS ~NE~ SERVICE SERVICE UNiT API AP1 APi API FILE SIZE PROCES'S SAMPLE REP~. GTYPE ID ORDER# FT LO0 DEPT bVP OIO,HOI YERIF!CaTIO~4 LISTIaG PAG[C ~ Ci BGT I~ 0 0 0 0 0 4 ** DAT~ DEPT NCNb DEPT SP NCNL DEPT SP GR NCNb DEPT CNL DE:PT GR NCNb 7839 -999: -999, '999, 7800 , -16, 308, 5480, 77,00, 10 2028, 7.600, 22, 7500 -38 8O 2682 740:0, "75 ' 5000 SF[,U -999.2500 ILM 2500 GR -999,2500 NPHI 2500 CALl '99q.2500 DRHO 2500 FCNL -999.2500 C2 0000 SFLU 2,453! Ibm 8594 GP 308,0000 NPHI 0000 CALl 8,0000 DRHO 0000 FCNL 1994.0000 C2 0000 SFL{J 2 4629 II:~ 3125 CALl 9,02 34 DRHO 0000 FCNL 550,5000 C2 0000 SFLU 5,5352 ILM 9375 GR 93'6250 ~PHI 6250 CALl 749'04697 DRMO 0000 FCNL '0000 C2 0000 SFLU 7 500 CALl 0000. FCNb 920 .2070 ,7500 ,0.000:: C2 -999 -999 -999 5 .2500 ILD .25o0 MRAT .6055 C! 20508 30~1758 RHO5 O,Ob05 NRAT 8.5781 C1 2.0176 ILD 43 ~547 R~O~ O~ ~40 NR~T 9,1406 CI 3~.,6445 ILD ;914'1 5.5977 ILD 3X0,0059 RH~.~ 005'9 N'R . '~. 6953 C:I -999.2500 -99 25.0.0 5,9,~14 2,0254 2.3S87 7129 2.2.344 2,4805 5469 ,7188 ~.40(>4 , 0645 ;203I 5.4375 21 ~ 5605 2, bVP 010,MO! VERIFICATION LISTING .4102 !L~ 2.3340 ILD 2.3301 ,1875 NPHI 43,6523 RHOO 2.4043 .6094 ORHC 0.0576 NRAT 3.5996 ,0000 C2 9.7188 CI 8,6691 DEPT 6800,0000 SFDU 3 SP -7,5313 GR 122 GR 122,4375 CALl 9 NCNL 1889.0000 FCNL 492 3711 IbM !,9795 IbD 1 8154 :4375 NPHI 50,2930 RHOB 2;3105 ,0859 DRHO 0,0229 NRAT 3.9258 .7500 C2 9.]406 C1 8,5625 DEPT 6700 0000 SFLU 3 SP -38,2813 GR 144 GR 144,8750 CibI 9 NCNb 2192,0000 FCNb 638 ,4414 IL~ 2.8223 ILD 2.7891 8750 NPHI 39,0137 RHOB 2,4570 '-0000 C2 9,4922 C1 8' 5234 DEPT 6600,0000 SFLU 3 Sp -33,0313 GR 161 GR 161,5000 CALl 10 NCNb 1938,0000 FCNL 476 ,3574 IbM 2,7988 ILO 2,7480 ,5000 ,~PHI 46.72~5 RHOB 2'3809 0547 ORMO 0,0229 NRAT 3'8086 '2500 C2 9 9766 C1 8.3750 DEPT 6500,0000 SFLU $P "'15,5313 GR GR 143;7500 ClbI NCNb 2570,0000 FCNL 2,0684 IL~ I .8203 TLD 1.6973 , 4 ,2.832 RHOB 14 , ,0107 ~{RAT ~3516 773,0000 C2 9,0313 C1 8~b094 DEPT 6400,0000 ~FLU 8~ 'i0,0313 GR GR NCNL 2196~000'0 FCi~ DEPT 6300 NCNb 2 0000' SFLU 3,039I" 2500 C~'iil 0000 C.;2 5VP OlO,B01 VE~!~ICATION LISTING NCNL 2140,0000 FCNL DEPT 5~00,0000 SFLU SP 36,2813 GR GR 98,0000 CALl NCNL 2020,0000 FCNL DEPT 5700,0000 SFLU SP -44,5313 GR GR 106.8750 CALl NCNL 2146,0000 FCNL DEPT 5.60010000 SFLU SP 51 03!3 GR GR 88 3125 CALI NCNL 2278 0000 FCNL DEPT 5500 P -44 R g8 NCNL 1898 663.5000 C2 9,8569 DEPT 5400, SP '47, GR 102, NCNL 2268. DEPT 5200 SP GR 97 NCNb 2166: 1,7432 Ib~ 1.8506 IGD .5293 RHOB 98,0000 NPHI d2 10,0000 DRHO 0.0347 NRAT 57g.5000 C2 !~0.289! C1 1,9980 ILM 2,0527 ILD I06,8750 NPH! 37,9395 RHOB 10,6172 DRHO 0,O664 NRAT 570.0000 C2 10.2714 C1 2 0840 Ib~ 2,1992 88~3125 ~PHl 37,5977 RHOB 10,3516 DRHD 0,0181 NRAT 66B.0000 C2 10.2344 CI 0000 SFLU 1 03i3 GR 88 5000 CALl g 0000 FCNL 593 9756 ILM 2.0859 ILO 5000 NPHI 4i0,71480 RHOB 4922 DRHO , 006 NRAT 0000 C2 9.9375 313 GR 9375 CAbI 10, 0000 FCNL 554, O0 C:2 ~.0, 195 ILD 06]RHOB · ~ 033,2 5313 C1 8,7891 1,8525 2.330! 5703 2,0938 2,3223 3,3652 @.5078 2,1953 2,3574 3,3242 8.66.41 2.1660 ,2813 ,4~63 8.i641 , 742 .2910 ,5371 16719 2,24'22 8,85t::::0 LVP OIO,HO1 VERIFIC.AT!Ot~ LISTING PAGe: ? GR 95,9375 CALl 11 b094 NCNL 2088,0000 FCNL 606:0000 C2 0.0352 1 1.0781 2,4805 ILD 4O 2344 RHOB 0~0562 NRAT 10,8594 C1 3,5918 36.6699 RHOB 0,0688 NRAT ]0.~906 4,210q 36,2305 RHO~ 0.0649 ~RAT 9,9687 3 ~000 44~ ~95 ~HOR 0,0762 9.8750 C! DEPT 4700 0000 SFLU 2,4727 I5~ 8P -16:2656 GR 83,5000 NPMI G~ 83i 5000 C~LI 11,093~ DRHO NCNL 1991 0000 FCN~ 549,0000 C2 DEPT 4600,0000 SFLU 3 2793 I5~ SP -27,7969 G~ 100:0000 ~PHI GR 100,0000 CALl 11,3828 DRHO NCNL 2222,0000 FCNL 673.5000 C2 DEPT 4400,0000 SFLU 3,164~ Ib~ SP '~5,2969 GR 75.500 ~P}.~ GR 75,5000 CAbI ~,9531 O~aO NCNL 2027,0000 FCN[, 53 .5000 C2 DEPT 4300 SP -~4 NCNL 2266 0000 SFLU 6,6680 !bM : 0313 GR 82,8750 .8750 CALl 1I. 0391. · 0000 FCNh 755,5000 C2 6,996I ILD ]~,8398 RHOB *0352 NRAT 1i,3125 CI D~PT 4200 SP '31 ,O00O :: SFb. O 437 GR 750 CASI: 00'00 F'CN'L ~4; 3750 NPHi 39'27.49 RHOB 1:I, !4:84, :DR:HO :0,04:25: 'N:RAT 537';500'0 ..... C:2 10'~8"2~: C1 DEPT 4100' GE 8'0; N CN h 19:8:8, ' 6 ,'2~8'1:3 ::' 'ILD 37,0 t I:':7'::, ~0~. 'C:'i 3~ 2, 3, 8, 3, 2. 3 4. 2, 3, 9, 3, . 5352 3516 62'70 3252 50qB 5547 6359 3359 3203 6016 3164 2422 8867 25?0 6582 703i !'523 2266 263'7' 8,789 t ~. 066:~ ' 3itq 83, 4 8 8:3 ..ii 28~i bVP 010,HO1 VER'IFICATIO~i LISTING PAGE 8 SP -53 7813 GR GR 36i7813 CALI NCNb 2472 0000 FCNL DEPT 3600 0000 SFLU Sp '58,0313 GR GR 75,8750 CALl NCNb 2230,0000 FCNL DEPT 3500 0000 SFLU SP '51' GR 66,8125 GR ,4375 CALI NCNb 2036.0000 FCNb DEPT 3.4~0,0000 SFL{J SP 8,8125 GR GR 44,50000 CALl NCNL 2434. 000 FCNL DEPT 3300 0000 SFLU SP '57~8750 GR GR 64.1875 CAbI NCNb 2144,0000 FCNb NCNb 21'96 ,0000 $~bU ,2187 G ,4375 CA~Ib ,0000 FC DEPT 3100,0000SFLU SP -6:0,~7500 OR:! NC:Nb 2:456,0:000i ':FCN[, SP '62 NCN:L 3b.7813 gPHI i0,7344 DRHO 662,5000 C2 0 10 14,8359 IbM 13,1662 75.8750 ,~PHI 44.3359 9,5469 DRHO -0 0010 581.5000 C2 9~757q 13,1953 66 4375 NPHI 9~5703 DRHO 630,0000 C2 ,o898 RHOB 2,31'72 ,O145 NRAT 3.6055 ,5000 CI 11,0703 ILD 13,0797 RHO!'% 2.!309 NRA~ 3,~328 C~ 8,6719 14, 3 9,b172 DRHO 677.0000 C2 11.R516 IbM 64,1875 NPHI 9,3125 DRHO 611,0000 C2 10.3281 ibp 11.~672 40,13bl RH06 2,1504 0,0205 NRAT 3'4023 9.9766 C1 8.9219 15 3203 ILD i6,1.562 41:6992 RHOB 2,1035 0,0107 NRAT 3.4902 9,6406 C! 8.7500 10,9453 ILD 12.1484 4~,6270 RNOB 2,1855 .0107 NRAT 3,52t. 5 9.5313 CI 8.5625 65,4375 NPHi 5 '5000 , , 6'56 DRHO 7:09, O00'0' 'C2". lbo 112,4453 R ~:! 0 [3 ' 1 g 7 3 ; 53 6 O16 I LD 1'0,08S'9 : ~{~i:P,~T , 49'8'0: 5:313' :, ..... :.1: 8,6:6&~1 · 0000: G 51':'59'3B :~PM] 4'~,94:3~ RF{OB ,0g:59 ,0000 D£PT 2'900 00:00 'BFLU 8 6:i72 ILN{ 8 ,'8'359""YLD 9:';;'8906 PAG~ 9 bVP 010,~01 VERIFICATIO~ DEPT 2600,0000 SFbU 7, SP '53,2187 GR 59, GR 59,6875 CALl 10, NCNL 2064,0000 FCNL 536. DEPT 2500,0000 SFLU 13, SP '69,0000 GR 55, GR 55~9062 CALI 10, NCNL 2442,0000 FCNL 652, oooo SP -64;7500 G}~ 5 GR 54~ 2500 CALl 12, NCNL 2432,0000 FCNL 638. DEPT 2300,0000 SFLU 2000, SP -27,1875 GR 42, GR 42,2187 CAI, I 9, NCNL 1587,0000 FCNL 309, DEPT 2263 0000 SFLU :999, SP -999:2500 GR 999, GR -999,2500 CALl ~999, NCNL -999.2500 FCNL 999. 6484 DRHO -0,0054 NRAT 3' 8652 r)O00 C2 g,5313 CI 10,156~ 4922 ILM 13,9141 ILD 15.2500 9062 NPHi 42,1875 RHOB 2,0996 578~ DRHO 0,005~ N~AT 3.5977 oooo o.aas9 ct 3750 ~bM 8,0938 ILD 9,9922 0625 DRHO ~1'9766 9.3750 5000 C2 .... . Cl. 000 ILM 2000oO000 ILD 20,3125 8750 [)R~O '0 o62V0 ~T 4.9883 0000 C2 10.0938 C1 10.0938 2500 lh~ -999,2500 iLO -999,2500 2500 t~P~I -999.2500 RHOB -999,2500 e- ' 0 250 l')~O -999,2500 NRAT 999,2500 2500 C2 10.0938 C1 !0.0938 bYP OIO,H01 VERIF!CAT,I[(.}~q LISTING NEXT REEL NAME : COMMENTS :REEL COMMENTS