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181-195
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-13 KUPARUK RIV UNIT 1A-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-13 50-029-20700-00-00 181-195-0 W SPT 5953 1811950 1500 1800 1800 1800 1800 220 360 360 360 4YRTST P Adam Earl 7/12/2023 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-13 Inspection Date: Tubing OA Packer Depth 500 2690 2560 2530IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714091240 BBL Pumped:2.6 BBL Returned:2.5 Friday, September 1, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg Q q q (i DATE: Wednesday, July 24, 2019 P.I. Supervisor l r 1 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. FROM: Matt Herrera 1A-13 KUPARUK RIV UNIT IA -13 Petroleum Inspector Ste: Inspector Reviewed By: � P.I. Supry Jk— NON-CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT IA -13 Insp Num: mitMFH190723094757 Rel Insp Num: API Well Number 50-029-20700-00-00 Inspector Name- Matt Herrera Permit Number: 181-195-0 Inspection Date: 7/21/2019 Packer Well - - IA -13 Type In,j Ir TVD PTD 1811950 ' Trpe Test si'r "Pest psi BBL Pumped: 06 BBL Returned: Interval) 4YRTST P/F Notes: MIT -IA pressure test to 1800 PSI Per Operator Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1953 Tubing] 2350 x:50 2350 2350 - ia10 - IA Ho 1795- 1760 - 1745 - 06 OA 218? 3'0 320 330 � r Wednesday, July 24, 2019 Page I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Monday, July 15, 2019 4:19 PM To: Wallace, Chris D (CED); Regg, James B (CED) Cc: CPA Wells Supt Subject: KUP Injector 1A-13 (PTD #181-195) Inconclusive AOGCC witnessed MIT -IA Attachments: 1A-13 90 Day TIO plot.PNG; MIT KRU 1A PAD (2of2) 07-14-19.xlsx; 1A-13.pdf Jim/Chris- Kuparuk Injector 1A-13 (PTD# 181-195) was reported with an inconclusive test result during yesterday's AOGCC witnessed mechanical integrity testing. At this point in time, the well does not display any indications of compromised barriers. CPAI suspects the inconclusive test result was the effect of the thermally impacted fluid used for testing. The AOGCC representative (Jeff Jones) noted on the 10-426 that the testing fluids were —80° F and the well head temperature was -142' F. CPAI intends to leave the well as "normal" status and re -schedule the test in conjunction with additional AOGCC witnessed testing that will soon be conducted. The results of the follow up test will be submitted on an additional 10-426 as required for the 4 -year UIC compliance testing. Please let me know if you disagree with the plan. Attached are copies of the 10-426, 90 day TIO plot and a well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM MEMORANDUM TO: Jim Regg P.I. Supervisor 2� �s�lti FROM: Jeff Jones Petroleum Inspector I Well Name KUPARUK RIV UNIT IA -13 IInsp Num: mitJJ190716092555 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 18, 2019 SUBJECT: Mechanical Integrity Tests CmccoPhillips Alaska, Inc. IA -13 KUPARUK RIV UNIT IA -13 Sre: Inspector Reviewed Bi7�,� P.I. Suprv. NON -CONFIDENTIAL Comm API Well Number 50-029-20700-00-00 Inspector Name: Jeff Jones Permit Number: 181-195-0 Inspection Date: 7/14/2019 Thursday, July 18, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA -13 Type Inj w 'TVD 5953 - Tubing 9300 _1'0 - 2300 zns - �7s PTD 1911950 Type Test SPT Test psi 1500 - IA 1170 1900 ' 1760 1-0 - 1725 BBL Pumped: -, os - BBL Returned: 0 .5 OA 380 '.,------ 400 -F-420 i10 4z0 -I_ - --- Interval - 4YRT9T P/F 1 -- -4-- Notes: Possible thermal expansion effect. well head temp. 142 deg. / test fluid 80 deg. 1 well inspected, no exceptions noted. Thursday, July 18, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,July 20,2015 TO: Jim Regg ; �l �j/tz-itS P.I.Supervisor �, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-13 FROM: Bob Noble KUPARUK RIV UNIT 1A-13 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry JP — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-13 API Well Number 50-029-20700-00-00 Inspector Name: Bob Noble Permit Number: 181-195-0 Inspection Date: 7/17/2015 Insp Num: mi1RCN150719140423 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-13 - Type Inj W iTVD 5953 ' Tubing 1150 - 1150 - 1150 ' 1150 - PTD 1811950 - Type Test SPT Test psi 1500 - IA 560 1990 - 1990 - 1880 - -II Interval 4YRTST PAF P ' OA 270 330 - 330 330 • Notes: SCANNED ,.51 ,,,, Monday,July 20,2015 Page 1 of 1 XHVZE Ima Project Well History File Cover{" 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. ./ ~' L- _,/__ ~_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) n Color items: [] Diskettes, No. [] Maps: [] Grayscale items: ~Er Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCEN~""~ARIA WINDY DATE:~_~{~.~,.> ~ ~;~/ Project Proofing BY: OBIN VINCENT SHERYL MARIA WINDY DATE',-'- .-- ~ - J.S/ Scanning Preparation' ~__~ x30= ~i~ + ~ = TOTAL PAG ES 7~~, Production Scanning Stage' l Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER I. SCANNING PREPARATION: ~YE~'-~ .O IF NO iN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO BEVER~,~VINCENT SHERYL MARIA WINDY I RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked 12/10/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg c i (( ( u P.I. Supervisor t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A -13 FROM: Chuck Scheve KUPARUK RIV UNIT 1A -13 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry x.1 - NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 13 API Well Number: 50 029 - 20700 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727070431 Permit Number: 181 - 195 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IA-13 - Type Inj. W. TVD 5953 - IA 500 2700 - 2640 2630 - P.T.D 1811950 TypeTest 1 SPT ' Test psi 1500 - O 240 320 T 320 � 320 Interval 4YRTST - P/F P - Tubing 2075 2100 2100 2100 Notes: t .1:4!'-'1,..' ,- r r I fk t ` j } 1 f i Wednesday, July 27, 2011 Page 1 of 1 ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16`Y', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~ V G~ ~u~ ,~ ~ ~~,j~ ~ d s~ cam. comrniµ,>,cu~ ci~ilrape I~11~ tq3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. 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 November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7~', 8~' 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 Klem ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7116/10 1 A.1 C.1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A 13 50029207000000 1811950 11" Na 11" Na 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" Na 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1 C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1 C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7/7/2010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 7/7/2010 1E-24A 50029208570100 1971870 2" Na 2" n/a 1.7 7/7/2010 1E-25 50029208440000 1821700 3" n/a 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/8/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1A-13 Run Date: 7/1/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 20700 -00 ,1:.N€ EE: NC 7 200 Injection Profile Log 1 Color Log 50- 029 20700 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. V r L, 1 t _�9,5 90(1 Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barre, leallp4rWok NOV 5 200 Date: Signed: �iaska Oil Gas :;pit. Gon,,riYsur: MEMORANDUM . TO: JpimI SRegg. Xe't'{;¿; 7/-:z,':h-¡ " u pervlsor !' ¡-"-'I 1... / FROM: Bob Noble Petroleum Inspector Well Name: KUPARUK RlV UNIT lA-13 Insp Num: mitRCN070719131534 Rei Insp Num: Well I lA-13 ¡Type Inj. ! N I E.Di 1811950 iTypeTest ! SPT Interval 4YRTST P/F Notes: ~~'. Friday, July 20, 2007 Packer TVD Test psi i pi./' State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-13 KUPARUKRIVUNIT 1A-13 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20700-00-00 Permit Number: 181-195-0 Depth Pretest 591j /' I IA I 0 ¡ I +--- , 1760 Vi OA I 0----L Tubing! 600 I ,\q5 ,C6 Reviewed By: P.I. Suprv 3&2- Comm Inspector Name: Bob Noble Inspection Date: 7/15/2007 Initial 15 Min. 30 Min. I 1730 I 1720 I 1760 o o o , ---+- I 600~~~ 600 P étd(er~pt~ (nb) &i.ê<'l.(.,ks Z)Cl4C I ~¿,\r, . \ . "" ell œcfz.c~ "Si..v"va Jv\.û* f€Cl~ SlVI(~J ~)"ttZ t .- .-1e<;J- PJt;S<;IiÎl~ òt:- ..-.,."....-. '---.. -.. , SCANNED AUG 0 6 2007 45 Min. 60 Min. i i I -: i ~ Page 1 of I MEMORANDUM ') State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg Q P .1. Supervisor K....~q 'BI ç / (¡Ç DATE: Thursday, August 04, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPillLLIPS ALASKA INC lA-13 KUPARUK RIV UNIT lA-13 \Cô\~\ erg- FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV UNIT lA-13 Insp Num: mitJCr050803080030 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20700-00-00 Permit Number: 181-195-0 Inspector Name: John Crisp Inspection Date: 8/2/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lA-13 Type Inj. w TVD 5913 IA 815 2510 2445 2420 P.T. 1811950 jTypeTest SPT I Test psi 1478.25 OA 560 660 660 660 I Interval OTI-ŒR P/F P Tubing 1110 1110 1110 1110 Notes: MIT after tubing patch installed. 1.8 bbl fluid pumped to achieve test pressure. ;)GI\NNE[: AUG 0 ~) 2005 Thursday, August 04, 2005 Page 1 of 1 KRU MIT lA-13 ) ~~~j~f~:~r.r~]~lA~13..·..·.................·..... ........... ........... ....... ..... . ..' .'. .... ... .... ........ .......... . .. ............. ..... .<>..... ·.....r 1Fr~~rN~K ·rr()b.l~t11Well§¥PY.<;111~1!@9011.R89J1l1i~~ip~·qpm?' . ..' ])ªte:Eti, ·OlJt¡1~.Q059S:38:?OsQ80Q...· ) qS Attached is an MIT form for Kuparuk we1l1A-13 (PTD 1811950). The well was recently patched but the MIT was performed again since the tubing and IA pressures appeared to be close «MIT KRU 1A-13 06-30-05.xls» . The test turned out fine. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 KRU lA-13 Content-Description: MIT KRU IA-13 06-30-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SCANNED JUL 2 2~ 2.005 1 of 1 7/13/2005 10:42 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;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 1A-13 06/30/05 Arend/Rogers AES , Packer Depth Pretest Initial 15 Min. 30 Min. We1l1A-13 Type Inj. S TVD 5,913' Tubing 1350 1350 1350 1350 Interval 0 PT.D. 1811950 Type test P T est psi 1500 Casing 860 2000 1925 1925 P/F P Notes: Follow-up MIT post patch Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0630_MIT _KRU_1 A-13.xls E= !J " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 ð 2005 REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing D Operat. ShutdownD em I~' D~ f11f"hfiì"1'" Time Extension Ò . "···'·L"., D Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 100' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Developm.~nt D Stratigraphic D Exploratory 0 Service 0 other Re-enter Suspended Well 5. Permit to Drill Number: 181-195 6. API Number: 50-029-20700-00 9. Well Name and Number: 1 A-13 10. Field/Pool{s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7144' feet true vertical 6589' feet measured feet true vertical 6276' feet Length Size MD 80' 16" 80' 2623' 10-3/4" 2723' 7015' 7" 7115' Plugs (measured) Junk (measured) TVD Burst" Collapse 80' 2658' 6560' Measured depth: 6592-6669,6693-6709,6844-6851,6860-6884 true vertical depth: 6041-6117,6141-6157,6291-6298,6307-6331 'SCÆ~NED JUN 1 4 2005 Tubing (size, grade, and measured depth) 3.5" 12-7/8", J-55, 6750' 1 6785' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1SP'; BAKER 'DB' WI 4.5 EXT. pkr= 6504'; 6753' SSSV= SSSV SSSV= 1826' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS 8Fl JUN 082005 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 2070 2000 15. Well Class after proposed work: Explorato~ D Development D Service 0 16. Well Status after proposed work: oilD GasD WAG0 GINJD WINJ 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: 303-135 Oil-Bbl Casinq Pressure 1525 1040 Tubinq Pressure 1130 -2500 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations _X Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name MJ Lov,el~ Signature ~I' 7/t Form 1 0-40L¡sed ~4/2004 WDSPLD Problem Wells Supervisor 907-659-7224 Date 06Sufl} a 6--- OJ R\/ I G· ¡ f\f Ll L t \.~. , [ t¡ t '\ Submit Original Only 1A-13 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary.. Pull and Re Run Retrievable Patch 5/1/2005 PULLED SLIP STOP @ 63971 WLM. SET SV IN PACKOFF, TBG TEST FAILED. SET HOLEFINDER ABOVE TBG PATCH @ 64261 RKB, GOOD TEST. RETURNED WELL TO INJECTION. 5/17/2005 PULLED 3" X 361 PATCH AND K-3 PACK OFF @ 6426' RKB. 5/2/2005 TEST 3.5" ECLIPSE PACKER. GOOD. TEST TUBING WI 31/2" D&D. TEST SOLID @ 64151 6/1/2005 SET WEATHERFORD UPPER PATCH ASSEMBLY WITH TOP PACKER MID ELEMENT AT 6426" TOP OF PKR AT 64221 6/S/200S MITIA passed (post patch set) Summary Pulled and Re Ran Retrievable Patch - mid elements from 6426'·6493' - Top of patch 64221 -.-- - - - -- -- .-' -'- KRU MIT's ) ") Subject: KRU MIT's From: NSK Problem Well Supv <n1617@conocophillips.com> Da1e: Mon, 06 Jun 2005 07:44:44 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim_regg@admin.state.ak.us>, bob _ fleckenstein@admin.state.ak.us Tom, Attached are diagnostic MITIA's on 1Y-10 (PTD 183-051) and 1A-13 (PTD 181-195). The MITIA on 1A-13 was completed post patch - we will also schedule a state witnessed MIT after the well is bra ught on line. The MITIA on 1Y-10 was completed for IAxOA diagnostics. Please let me know if you have any questions. «MIT KRU 1Y-10 06-05-05.xls» «MIT KRU 1A-13 06-05-05.xls» MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 Content-Description: MIT KRU 1 Y -10 06-05-05.xIs KRU IY-IO 06-05-05.xls Content-Type: application/vnd.ms-exceI Content-Encoding: base64 Content-Description: MIT KRU 1A-13 06-05-05.xIs KRU IA-13 06-05-05.xls Content-Type: appIication/vnd.ms-exceI Content-Encoding: base64 1 of 1 6/6/20057:52 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 1 1 A 06/05/05 Brakel Rogers - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 1A-13 Type Inj N T.V.D. 5913 Tubing 850 850 850 850 Interval 0 P.T.D. 1811950 Type Test P T est psi 1500 Casing 1040 2500 2500 2500 P/F P Notes: Pre Witnessed post patch MITIA Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: 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 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1A-13 06-05-05.xls 6/6/2005 Re: PWI IA-I3 (1811950) ) ) Subject: Re: PWI 1A-13 (1811950) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 23 May 2005 15:28:55 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: James Regg <jim_regg@admin.state.ak.us> Jerry , A patch has been approved previously for this well. You all reported the "renewed" communication and you plan to repair the equipment that is in the well. I do not believe that an additional sundry is required. Good luck with the repair. Keep us advised and file a 404 reporting the work. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Slickline diagnostics last week on injection well KRU 1A-13 confirmed the retrievable tbg patch set across a tbg leak at 6429' had failed. An MITT of the tbg above the top of the old patch passed. The patch top packer and spacer pipe was then pulled, and a CMIT passed with a plug set in the bottom patch packer, confirming tbg integrity below the tbg patch. The tbg patch was set under sundry approval #303-135, May 2003. A 10-404 was submitted in Oct 2003 reporting the tbg patch repair. The patch top is currently being redressed and repair could be made as early as 5/26/05, with a follow-up M ITIA. To reset this patch, is a new 10-403 required or is a 10-404 sufficient, assuming the MITIA passes? Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_ maunder@admin.state.ak.us] Sent: Monday, April 18, 2005 2:35 PM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: PWIs 1A-13 and CD2-51 C'('ANNED MA'{ "/, to {_GO'5 <':)\.... MJ, So long as there is no indication of any communication outside the casing, you request to keep these 2 wells in WATER ONL Y service is acceptable. Please add the wells to the monitoring list and submit the Administrative Relief paperwork as you indicate. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Any decision on allowing this two wells (1A-13 and CD2-51) to remain on line for a while? Just bringing it up in case the questions got buried in the dozens of emails I sent you this weekend. I can forward the original emails a questions if needed. MJ Loveland ConocoPhillips Problem Well Supervisor 1 of3 5/23/2005 3 :29 PM Re: PWI IA-13 (1811950) ) ) 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Saturday, April 16, 2005 6: 15 PM To: 'Thomas Maunder' Cc: 'James Regg'; NSK Problem Well Supv Subject: RE: Injection weIl1A-13 (PTD 181-195) Tom, The MITIA on 1 A -13 (PTD 181-195) failed today during the diagnostic MITIA. When pressuring up the IA for the MIT, an injection pressure of 1.750 psi at 7 gpm was stabiJized down the IA. I suspect the tubing retrievable patch has failed. ConocoPhillips requests approval to leave the well online until diagnostics and freeze protection can be coordinated ~~ approximately 2 weeks. I will send the MIT fonni.n a separate message. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Friday, April 15, 2005 11:33 AM To: 'Thomas Maunder' Cc: 'James Regg' Subject: Injection well 1A-13 (PTD 181-195) Tom, The DSO reported lA-B (PTD 181-195) IA would not bleed below 1550 psi after 2 hours of bleeding. DHD went out yesterday and did a similar bleed however were able to bleed the IA to 1400 psi - which came back to 1550 with in 5 minutes. Our original review of this well indicated that the problem was thermal (see the 6 month TIO plot) - however that may not be 20f3 5/23/2005 3 :29 PM Re: PWI IA-13 (1811950) ) ) the entire problem. This well has a retrievable tubing patch for a known leak. DHD will complete a MITIA later this week and I will report the results. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 30f3 5/23/2005 3 :29 PM RE: MIT KRU lA-13 04-16-05.xls ) -) S~þ~eçt:RE:i1>1I~~l.JIA-.l?Q~~r()~q?~l~.... .......................... ............ .......... . .......... . F~~D1:.·..N.~.~...~r()~].e~ .W.ell··.~.llP;.. .-<~1...()..1·.7@p.onQcophi.llip·s~cq111:;> :pª'~e:.:N1:qJ1~..··.l&Aprf095 O.8:5Q:04;QßPO· The OA pressure during the test was 850 psi. I added the well to May's failed MIT report MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: James Regg [mai lto: j .i..m :re~lS3@adrni:r:J.. state. a.l,:.. us] Sent: Monday, April 18, 2005 8:50 AM To: NSK Problem Well Supv Cc: Tom Maunder Subject: Re: MIT KRU 1A-13 04-16-05.xls Did they record pressures in OA while performing MIT? I noticed from TIO plot that the OA has recently seen a significant pressure increase also (to 940 psi). Given history of this well (tubing patches and now suspected failure of same, please add the well to the monthly injector monitoring list provided to Commission. Jim Regg AOGCC NSK Problem Well Supv wrote: «MIT KRU 1A-13 04-16-05.xls» Failing MITIA data. Let me know if you have any questions. Description and plans are under separate email. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 """'CJ1N" ~~Crj, ~ ·pn 9, 1. 2005 ~ ,,, .~~f,,;,~- j-ì r\ h 1 of 1 4/18/2005 9:03 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: ConocoPhillips Alaska Inc. ~\J\q{ FIELD I UNIT I PAD: Kuparuk I KRUI 1 A DATE: 04/16/05 OPERATOR REP: Arendl Brake AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1A-13 Type Inj S TV.D. 5953 Tubing 1100 1100 1100 1100 Interval 0 P.TD. 1811950 Type Test P T est psi 1500 Casing 1550 1750 P/F F Notes: Diagnostic MITIA Well Type Inj TV.D. Tubing Interval P.T.D. Type Test ,Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Test Details: Could not pressure up IA above 1750 psi - injecting in IA @ 7 gpm with triplex - liquid packed TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test SCANNED JUN 1 4 2005 MIT KRU 1A-13 04-16-05-1.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) 4/18/2005 ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 1,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED OCT 0 ,.: 200,1 a/a~kB Oil & Gas Cons. ¢on~n Dear Mr. Maunder: Enclosed please 'find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells IA-13 (PTD 181-195), IH-07 (PTD .182-084), and 30-04 (PTD 1.88-062). The Sundry Notices regard tubing patches run to fix tubing leaks in IA-13 and IH-07. IH-07's Sundry is a repeat notice as the patch was recently pulled and re run to access the C sand. 30-04 Sundry Notice is fbr an OA casing patch repair. Please call Nina Woods, Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, MJ ConocoPhillips Problem Well Supervisor Attachments STATE OF ALASKA A SKAOILAND GAS CONSERVATION COMMI ..~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r'-] Suspend E] Operation Shutdown ['"] Perforate E] variance E] Annular Disp. E~ Alter Casing E] Repair Well F~ Plug Perforations E] Stimulate E] Time Extension E] Other r'-] Change Approved Program E] Pull Tubing E] Perforate New Pool E] Re-enter Suspended Well E~] 2. operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E~] Exploratory F'] 181-195 / 3. Address: Stratigraphic E] Service ['~ 6. APl Number: P. O. Box 100360 50-029-20700-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-13 8. Property Designation: 10. Field/Pool(s): Kuparuk Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7144' feet true vertical 6589' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size M D TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SUR. CASING 2623' 10-3/4" 2723' 2658' PROD. CASING 7015' 7" 7115' 6560' Perforation depth: Measured depth: 6592-6669, 6693-6709, 6844-6851, 6860-6884 true vertical depth: 6041-6117, 6141-6157, 6291-6298, 6307-6331 '4~8'~'~ ~J("' / 0 Tubing (size, grade, and measured depth) 3.5"/2-7/8", J-55, 6750'/6785' MD. Packers& SSS V (type & measured depth) pkr= CAMCO 'HRP-1SP'; BAKER 'DB' W/4.5 EXT. pkr= 6504' · 6753' SSSV= SSSV SSSV= 1826' 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 OiI-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation Subsequent to operation 2140 1150 1318 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [] Development [~ Service ~'~ Daily Report of Well Operations _X 16. Well Status after proposed work: oilr-'~ Gas r-'~ WAG ~-~ GINJ[~ WINJ [] WDSPL[--'~ ,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I 303-135 Contact Printed Name MJ L0vela~d~ / ~ Problem Well Supervisor Sign ,tar ~.~~.~~,~_/~~ Phone t~ -~ --/~'- 7,,~ Forn~0-404 Revised 2/2003 · ~$ BFL OCT SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 1A-13 (PTD 1811950) SUNDRY NOTICE 10-404 TUBING REPAIR October 1, 2003 This Sundry is a report of completed well operations that repaired ConocoPhillips (CPA) Kupamk Well lA-13 with a tubing patch. On February 5, 2003 the AOGCC was notified of a failed MIT. Subsequent diagnostics indicated a hole in the tubing at 6429' MD. Sundry Notice 10-403//303-135 for a tubing patch was approved May 5, 2003. Subsequently a -37' retrievable eclipse tubing patch and a K3 packoff assembly was set from 6463-6426' on September 1, 2003, and September 20, 2003, respectively. A passing State Witnessed IA MIT to 2000 psi was completed on September 29, 2003. NSK Problem Well Supervisor MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: September 29, 2003 Commissioner,/,7 _ ' O/ ' SUBJECT: Mechanical Integrity Tests THRU: Jim Regg "~/--,¢~ Conoco/Phillips P.I. Supervisor~'~'~ Kuparuk River Field KRU 1A-13- 1H-07 FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. w~,,I ,,,.~ J Typ~,,j.JsJ T.V.D. I5953J Tubingl~=~0 I~0 I~0 I~0 I,,,~rva, I O P.T.D.J 1811950 JTypetestJ P JTestpsiJ 2000 J CasingJ 680 I 2000J 1950J 1930J P/F I -P Notes: Post patch MIT - 1.2 bbl. Pumped. OA 0 psi. vv~,,I ,.-o, I Typ~,,j.jsI T.V.D. I~ I Tubingl~00 I~e00 I~00 I~00 I,,t~rva, I O P.T.D.J 1820840 ITypetestJ P JTestpsiJ 2000 JCasingJ 800 I 2480J 2420J 2410J P/F J _.P Notes: Post patch MIT - 1.7 bbl. Pumped. OA 340 psi. to 400 psi during test. Well J P.T.D.J Notes: P.T.D. I Type test Notes: Well J I Typ~Inj. P.T.D. J Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Two MITIA's performed. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Number of Failures: 0 Attachments: ~ Total Time during tests: 4 hrs, cc: MIT report form 5/12/00 L.G. 2003-0929_M IT_KRU_I H-07_jc.xls 10/10/2003 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 30, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notice for ConocoPhillips Alaska, Inc., Well lA-13 (PTD 181.1950). The Sundry Notices regards a tubing patch to repair the well. Please call Nina Woods or me at 907-659-7224 if you have any questions. Sincerely, Con. ocoPhillips Problem Well Supervisor Attachments: Repair Plan Sche'matic 10-403 RECEIVED MAY 0 15 2003 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [] Operation Shutdown ['--] Perforate Repair well [] Plug Perforations [--'] Stimulate Pull Tubing ~ Perforate New Pool ~] r-'] Vadance r'-] I~ Time Extension [--] Re-enter Suspended Well I--I Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development [~ Exploratory [] Stratigraphic [] Service r'~ 5. Permit to Drill Number: 481-195 ,/ 6. APl Number: 50-029-20700-00 7. KB Elevation (ft): RKB 100' 8. Property Designation: Kuparuk Unit 9. Well Name and Number: 1A-13 10. Field/Pool(s): Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): 7144' Casing CONDUCTOR SUR. CASING PROD. CASING TotalDepthTVD(ft): 6589' Length 801 . 2623' 7015' Perforation Depth MD (ft): 6592-6669, 6693-6709, 6844-6851, 6860-6884 Effective Depth MD (ft): Size 16" 10-3/4" 11 ¸ Effective Depth TVD (ft): MD 80' 2723' 7115' Perforation Depth TVD (ft): 6041-6117, 6141-6157 6291-6298, 6307-6331 Plugs (measured): TVD 80 2658 6560 Tubing Size:' 3.5"/2-7/8" Junk (measured): Burst Tubing Grade: J-55 Collapse Tubing MD (ft): 6750'/6785' Packers and SSSV Type: pkr= CAMCO 'HRP-1SP' · BAKER 'DB' W/4.5 EXT. SSSV= SSSV 12. Attachments: Description Summary of Proposal Detailed Operations Program E~ BOP Sketch r'-'] 14. Estimated Date for Commencing Operations: When Approved 16. Verbal Approval: Date: Packers and SSSV MD (ft) pkr= 6504" 6753' SSSV= 1826' 13. Well Class after proposed work: Exploratory I---I Development r"-] 15. Well status after proposed work: Oil r--] Gas [] WAG r-~ GINJ [] Plugged I-"1 WINJ I--'] Service [-~ Abandoned WDSPL [~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name UJ Loveland ,¢ Signature .,~~"~' ~~~'"~'~~" ~ Commission Use Only Contact: MJ Loveland/Nina Woods 650-7224 Title: Problem Well Supervisor Phone Date ~7(/~ ~ ~_~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test [~] Mechanical Integrity Test 't~ Other: Subsequent Form Required: Approved by: .r~ .,,/~_~,~ ~ ~ .o m 2 03 ........... BY ORDER OF C O~l'l~l'ri'~-E[I-(~'NER THE COMMISSION ORIGINAL ConocoPhillips Alaska, Inc. Kuparuk Well 1A-13 (PTD 1811950) SUNDRY NOTICE 10-403 TUBING REPAIR 04/30/2003 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well lA-13 with a tubing patch. On February 5, 2003 the AOGCC was notified of a failed MIT. Subsequent diagnostics have identified a Tubing to IA leak through a pup joint at 6429'MD. Pending the results of Slickline diagnostics for additional leaks, the plan is to patch the tubing with a retrievable patch. The center-center patch element length is 35'. Following a successful MIT, the well will be returned to normal water injection. Should the pre-patch diagnostics indicate additional leaks above or below the identified hole, the AOGCC will be notified and an alternative plan discussed. REPAIR PLAN 1. Verify no additional leaks above and below identified hole. 2. Set 35' 3.5" retrievable patch from 6428' - 6463' with center of element at 6463'. 3. MIT as per AOGCC requirements (0.25 x TVD to packer) 4. Submit 10-404 post repair NSK Problem Well Supervisor (1826-1827, 0D:3.500) ConocoPhillips Alaska, Inc. ~ 1A-13 APl:1500292070000 SSSV Typo:ITRDP Annular Fluid:I Reference Log:J Last Tag:16970 Last Tag Date:J 10/14/2001 KRU 1A-13 Well Type:I INJ Orig 11/25/1982 Completion:I Last W/O: 18/28/1993 Ref Log Date:I TD:17144 ftKB Max Hole Angle:137 deg (~ 3400 Angle @ TS:I7 deg @ 6593 Angle @ TD:I7 deg @ 7144 I Rev Reason:I Re-set DMZ' Last Update14/1/2003 PBR (6492-6493, 0D:3.500) PKR (6504-6505, 0D:6.156) SLEEVE-C (6737-6738, 0D:2.750) SBR (6751-6752, 0D:2.875) NIP (6772-6773, 0D:2.875) TUBING (675O-6785, 0D:2.875, ID:2.441) Perf Pert (686O-6884) Casing String - ALL STRINGS Description Size Top Bottom I TVD I Wt Grade CONDUCTOR I 16.000 I 0 I 80 I 80 165.001 H4O SUR. CASING I 10.750 0 I 2723 I 2658 145.501 K-55 PROD. CASING I 7.000 O I 7115 I 6560 I 26.00 K-55 Tubing String -TUBING Size I Top 3.500 0 3.500 6486 2.875 6750 perforations Summary Interval TVD 6592-6669 6041-6117 , 6693-6709 6141-6157 6844-6851 6291-6298 6860-6884 6307-6331 Gas Lift Mandrels/Valves Thread Bottom TVD Wt Grade Thread 6486 5936 I 9.30 I J-55 I ABM-BTC 6750 6198 I 9'30 I L'80 I ABM-SUE 6785 6232 I 6.50 I J-55 I ABM-SUE · Zone I StatuslFt IspFI Date I Type I Comment UNIT/ 177 I 4 13/18/198211PERF 10degPhasing;Enerjet l'C'4'C'3'C'~ I I I I I C-1 / 116I 4 13/18/19821 ~PERFI0degPhas,..;Eneriet A-5 ! I 7 I 4 13/18/19821 IPERFI0degPhasing;Enerjet A~ / 1241l° 110~1~19931R~ER~10de~P"a~"n~:Sneriet:B"~ / I I I I I Hole cha St I MD I TVDI Man I Man I v Mfr Iv Type I v oo I Latchl Port I TRO I Date I V,v Mfr Type Run ~ I ~4ol ~-I I~ I~.~ I~ I o.ooo Io I~oo~l~mn~> 1. wle~ended packin9 Injection Mandrels/Valves stI MD I TVD I Man I Man I V Mfr ] V Type I V OD I Latchl Port I TRO I Date I Wv I I IMfr I Type I I I I I I I Run I Cmnt 2165511 60001Camcol MMG-2 I I DMY I 1.5 IRK IO.OOOl 0 18/28/19931Closed ,:.:JEWELRY...'. : .." .... '..:..~ : '. ' i. '.' · '.'.: ..: '. .... · Other· :(plugsi. equip.i: etciI Depth/TVD I Type 1826 118181 sssv 6492 159411 PER 6504 159531 PKR 6751 16199 I SBR 6753 162011 PER 6772 162191 NIP 6784 16231 SOS 6785 16232 TTL Description I D Camco TRDP-1A 2.812 Camco 'PBR-10' 2.937 Camco 'HRP-1SP' 2,937 Baker GBH-22 2.441 Baker 'DB' w/4.5 ext. 3.250 Camco 'D' Nipple NO GO Baker 2.250 2.441 2.441 Depth lTVD I Type Description ID 6737 6185 I SLEEVE-C AVA BPC SLEEVE w/one 5/16" port; set12/26/98, Set 2.31" AVA BPI sleeve 1.800 (Model No-Go) in the 2.75" BPC sleeve on 3/28/02 - CLOSED Note: Sleeve cannot be pulled w/braided wire; need CTU 6737 6185 I NIP AVABPL PORTED NIPPLE. 2.750 2003 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2734 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 04/03/03 Well Job # Log Description Date BL Color CD 3S-16 ~.2~-.C~.)'~/'"/' INJECTION PROFILE 03115/03 1 1A-13 ~ <~1-1 c~ ~, ./~... LEAK DETECTION LOG 03/16/03 1 1C-102 ~C)I-} I~ T~,"22067 RST 01/16/02 1 ~/ /~>.~C~-. . ,, , , , DATE: RECEIVED Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. APR 1 £00 0,, & Gas Cons. An~or~e Re: Failed MIT Kuparuk 1A-13 (181-195) Subject: Re: Failed MIT Kuparuk 1A-13 (181-195) Date: Thu, 06 Feb 2003 07:53:17 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> Hi M J, Another one?? Jerry had sent a note regarding 1H-07 the other day. What is the timing for your diagnostics?? Keeping the well in service is not unusual, however getting the CMIT as soon a practical would be appreciated. Please let us know of your schedule. If you have any pressure plots for say the last 6 months or so they would be appreciated as well. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom, > Yesterday (2/5/03) ConocoPhillips' Kuparuk Injection well 1A-13 failed an > MITIA. The well had been reported to have more then 2 bleeds per week to > keep within the well operating guidelines for IA pressure. A diagnostic MIT @ 3000 psi failed. Test pressures were (T/IlO): injecting 1800/2200/560 (well was pinched back), Initial MIT 1800/2850/560, 15 minutes 1800/2200/560. Repressured to 3000 psi, bleeds off 650 psi in 15 minutes. Our plan is to determine the leak path, setting plugs or running a leak detect logs as needed, and completing a combo MIT TxlA. We would like to keep the well on water injection service as needed during the evaluation process. Please let me know if you concur with our plans. We will report this well on the Monthly Failed MIT report until the problem is resolved. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska 659-7224 Tom Maunder <tom maunder~,admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission SCANNED FEB ! 0 2003 1 of 1 2/6/2003 7:55 AM ARCO Alaska, Inc. ~, Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1A-13 Stimulate 1 H- 17 Perforate 1H-10 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED N 0V - ?. 199;~ Alaska uu ~ u~s uons, uom~ssJOt3 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-600$-G ' ~ ~ STA~ ~ ~ ~r ~ OIL AND GAS ~VATIC~ ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing ___ Alter casing Repair well Other _ ~-'~_~, 2. Name of Operator I5. Type of Well: IO. Datum elevation (DF or KB) I Development _ I ARCO Alaska, 1110, I Exploratory _ I RKB 100 feet 3. Address I Stratigraphic _ I 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 I Sen4ce X Kuparuk River Unit 4. Location of well at surface 1049' FSL, 492' FWL, Sec 5, T11N, R10E, UM At top of productive interval 1373' FSL, 1397' FEL, Sec 6, T11N, R10E, UM At effective depth 1407' FSL, 1414' FEL, Sec 6, T11N, RIOE, UId At total depth 1434' FSL~ 1425' FELa Sec 6~ T11Na R10E~ UM 12. Present well condition summary Total Depth: measured 71 44 feet true vertical 6588 feet 8. Well number 1A-13 9. Permit number/approval number 81-195 10. APl number so-029-20700 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) Norte Effective depth: measured 7 0 2 6 feet true vertical 64 7 0 feet Junk (measured) None Casing Length Structural Conductor 8 O' Surface 2 7 2 3' Intermediate Production 71 1 5' Liner Perforation depth: measured 6592'-6669', true vertical 5940'-6015', Size Cemented 1 6" 222 SX PF I 0- 3/4" 1000 SX Fondu & 275 SX AS II 7" 1175 SX Class G 250 SX AS II 6693'-6709', 6844'-6851', 6040'-6058', 6190'-6195', Measured depth 80' 2723' 7115' 6860'-6884' 6205'-6230' True vertical depth 80' 2645" 6560' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6759' Packers and SSSV (type and measured depth) PKR: Brown HB ~ 6521' & Brown lB ~ 6751°; SSSV: Camco TRDP-1AENC @ 1803' 13. Stimulation or cement squeeze summary Fracture stimulation of "A" sands on10/10/93. Intervals treated (measured) 6844'-6851 ', 6860'-6884' Treatment description including volumes used and final pressure 14. 0V - 2 Gas Cons. C0ffil Anchorage Pumped 136 Mlbs of 16/20 & 12/18 ceramic proppant into formation~ fp was 4426 psi. Reoresentative Daily Averaae Production or Iniectiorl Dam OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 225 3300 Subsequent to operation 0 0 217 1600 2260 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil _ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~j ~. ~/~ Title Senior Engineer Form 10-404 Rev 06/15/88 16. Status of well classification as: Suspended Service MWAG Ini.. · SUBMIT IN DUPLICATE issi~ lA-13 DATE 10/10/93 DAY 1 ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company DESCRHrrION OF WORK KUP~UK "A" SAND REFRAC CONTR~OR ~ ~Y ~Z~ON DOWELL - GALLEGAS 7114' .[ , 701,8' -9/4/93 iiiii I Illl Illll I KUPARUK RIVER UNIT WELL SERVICE REPORT ' ' ~cicc# .... SCA# ' 9;8159 IFIE~D COST EST. "[ACCUMULATED CosT" , ! , $141,076 I $150,80,2 , isssv xYPz / SXA~S lC CO rv, , TIME 0700 0945 1008 , 1217 LOG ENTRY MIRU FRAC EQU!p.MENT, QC GEL, HOLD sAFETy MEE~G. PRIME AND P~ EQUI. PMENT TO 9120 pS!,.SET ISO TOOL AND CUPS... START PUMPING FRAC STAGES AS FOLLOWS: STAGE RATE VOLUME START/MID FLUID 7"ANN. PI/SD #1 / 25 BPM / 125 BBLS / 5617-4400 PSI / SLK WTR / 3325 PSI FWHTP4399,ISIP-2399,FG-.82,CP-5020 PI/SD g2/25 BPM / 25 BBLS / 4495-4390 PSI ! SLK WTR / 3525 FWHTP-4362,ISIP-2480,FG-.82,CP-5060 i ' pI~, SD, #3/,2,5 B,,PM'/~5'I BBLS/,44'!.5-4376 PSI / SLK WTR/33,75 ,PSI '., ~R_ E C. F ~V '~ U ' F'WHTP-4362,ISIP-2325,FG-.81,CP-5000 DF/25 BPM / 150 BBLS / 44404650 PSI / DXL-GW / 3475 · N()¥ ' DFF/25'BPM / 60 BBLS ) ~820-4~20 PSI/NXL]'GW ) 3484 PSi'" Alaska' ~',, II I I I Illl I I FWHTP-4426,ISIP-2560,FG-.85,CP-5250,MTR ERR-2%,FL.£FF.-36% PAD / 25 BPM / 175 BBLS / 45504740 / DXL-GW/3410 PSI 2pp~25BPM/ii'5 "- .... ~. · .._.... .... ,' · ...... BBLS ,/47~54320 / DXL-GW / 35 ,0~_ ~,~[~'UK ?1 tqOLt:U~ SNGtN.EER!NG 4~PA/25 BPMi 60 BBLS / 420242OO/DXL-GW / 3493~ ~ ! 1 ................. '-.,~ n -~ ~., ,ara 6PPA/25 BPM/70 BBLS / 4130-4060 / DXL-GW / 3425 PSI 8PPA/25 BPM/100 BBLS/4179-4250 / DXL-GW / 3415 PSI 10PPA/25 BPM / 130 BBLS / 42714400 / DXL-GW / 3365 PSI 12PPA/22 BPM/85 BBLS / 4491-4250 / DXL-GW / 3406 PSI I I I I II I I III I Ill I II I I al Itl I Ill I I ' I Iai _ II [ 14PPA/22 BPM / 25 BBLS / 4450-4570 / DXL-GW / 3479 PSI 16PPA/22 BPM/25 BBLS / 46104730 /DXL-GW / 3450 PSI FLUSH/22 BPM / 23 BBLS / 5090-5150 / DXL-GW / 3450 PSI FLUSH/22 BPM / 15 BBLS / 5240-4980 / NXL-GW / 3450 PSI i , ,, ,, ~ , , , , , ~ i ,, i i, [ , u , , , ,,,, FLUSI-I/21 BPM / 20 BBLS / 4980-4980 / 3450 PSI , , il ,i., i ., , i i , ,, 1252 SHUT-DOWN, FWHTP-4426 PSI, ISIP-2545 PSI. . , _ · I I . I ] I I I I I ii II I II [ I III I I I E IXlcm~c~ Tins .I~OC.~ iv sumumv is co.maj., o~ ~AC~ lXl COm'~ I ....... v ....... w v~ ......... i I I I'"" '" I ..po. l,, I . , I , m,U,~I , .phI ,,.. ~,9~ ,.7.t,,OO~',e ~ , -, , EFFE~ PROP: 138,558# (18,$00~ CP & 120,058# LWP) REMARKS CONTINUED: i TOTAL PROP PUMPED: 139,830 # CARBO-LITE & LWP PROP LEFT IN CASING: 1273 # 12/18 LWP SUMMARY: REFRACTUKED KUPARUK "A" SANDS USING YF-140 D GELLED SEAWATER AND 138,558 # OF CARBO-LITE & LWP PROPPANT. SECURED WELL FOR COIL TUBING CLEAN-OUT. SERVICE COMPANY DOWELL LRS SUPPORT EQUm. i PREVIOUS CHARGES · i Diesel TOTAL FIELD ESTIMATE i i ii Si~ed: i N O¥ - 2 199~ i Alaslqg 0il & Gas C;ons. ti0llitlli~-~ Anohorage DM~Y $134,616 $2,860 $3,~ i $141,076 I ACCUM. TOTAL $134,616 $2,860 $3,~ $9,726 ii I $150,802 ARCO Alaska, Inc. ,,,, Post Office B~,x 100360 October 27, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. ...WELL ACTION ~1'i~!5:1;' 1 A- 13 Perforate q~-o~ 1H-02 Perforate 1H-16 Stimulate c~;z-151 1H-16 Perforate 2~--~%'~ 1L-05 Perforate %~,~5 1Y-14 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering /'*RC© Aiaska Inc. is a Subsidiary of AtlanticRichfieldCompany ...... STATE OF ALASKA C~~ GL AND GAS CONSERVA~ REPORT OF SUNDRY WELL OPERATIONS ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Localion of well at surface 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator 15. I I Stimulate Repair well Type of Well: Development Exploratory _ Stratigraphic Service 1049' FSL, 492' FWL, Sec 5, T11N, R10E, UM At top of productive interval 1373' FSL, 1397' FEL, Sec 6, T11N, R10E, UM At effective depth 1407' FSL, 1414' FEL, Sec 6, T11N, R10E, UM At total depth 1434' FSL~ 1425' FEL~ Sec 6, T11N, R10E~ UM 12. Present well condition summary Total Depth: measured 71 44 feet true vertical 6588 feet Perforate X Other 6. Datum elevation (DF or KB) RKB 100 I 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-13 9. Permit number/approval number 81-195 10. APl number so-029-20700 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None -6) Effective depth: measured 7 0 2 6 feet true vertical 6470 feet Junk (measured) None Casing Length Size Cemented Structural Conductor 8 0' I 6" 222 SX PF Surface 2 7 23' 1 0 - 3 / 4" 1000 SX Fondu & Intermediate 275 SX AS II Production 71 1 5' 7" 1175 SX Class G Liner 250 SX AS II Perforation depth: measured 6592'-6669', 6693'-6709', 6844'-6851', true vertical 5940'-6015', 6040'-6058', 6190'-6195', Measured depth True vertical depth 80' 80' 2723' 2645' 71 1 5' 6560' 6860'-6884' 6205'-6230' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6759' Packers and SSSV (type and measured depth) PKR: Brown HB ~ 6521' & Brown lB @ 6751'; SSSV: Camco TRDP-1AENC ~ ~803',- t ~ v r" r~ 13. Stimulation or cement squeeze summary K E L. I'I VE Repedorated 'A4' Sand on 10/1/93. Intervals treated (measured) 6860'-6884' OCT ~ 8 1~J9~ 14. Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons. C0mmiSStO~ Representative Daily ,Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 225 3300 Subsequent to operation 0 0 217 1600 2260 15. Attachments ~ 16. Status of well classification as: I Copies of Logs and Surveys run m Daily Report of Well Operations X Oil ~ Gas Suspended~ 17. I hereby ~rtify that the foregoing is true and correct to the best of my knowledge. Signed~ i~/~ u.,.. ~' ~'~---~-- Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidla~/of Atlantic Richfield Company WELL IPBDT l/I-13 I"/ozs't CONTRACTOR REMARKS T P .' ~.~'c) o p 5; I FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT cc' 2-301)5 I0 ~1L E~+. Cos+: $ ~:3 IO. Sc A · E0223 ,,...,,, t:am~'tSS~0¢ ~,nghorage r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK , knot. ISigned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well O t h e r m 2. Name of Operator ARCO Alaska, I.nc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 1049' FSL, 492' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1373' FSL, 1397' FEL, Sec. 6, T11N, R10E, UM At effective depth 1407' FSL, 1414' FEL, Sec. 6, T11N, R10E, UM At total depth 1434' FSL, 1425' FEL, Sec.6, T11N, R10E, UM 7144' 6588' 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet 6. Datum elevation (DF or KB) 100' RKB, 66' PAD GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-13 9. Permit number/approval number 81-195(Conserv Order # 10. APl number 50-029-20700 11. Field/Pool Kuparuk River Oil Pool feet 261) Effective depth: measured 7025' true vertical 6470' feet Junk (measured) feet Casing Length Size Structural 8 0' 1 6" Conductor Surface 2723' 1 0-3/4" Cemented Measured depth True vertical depth 222 Sx PF 80' MD 80' TVD 1000 SX Fondu & 2723' 'MD 2645' TVD 275 SX AS II Intermediate Production 71 1 5' 7" 1175 SX Class G Liner 250 SX AS II 7115' MD 6560' TVD Perforation depth: measured 6592'-6669'. 6693'-6709', 6844'-6851', 6860'-6884' MD true vertical 5940'-6015', 6040'-6058', 6190'-6195', 6205'-6230' TVD Tubing (size, grade, and measured depth) 3-1/2" X 2-7/8", 9.3#/6.5#, L-80/J-55 @ 6785' MD Packers and SSSV (type and measured depth) Baker 'DB' Perm Pkr @ 6753', Camco HRP-1SP Ret Pkr @ 6506' MD, Camco "TRDP-1A" 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) S E P ,} 0 199, Treatment description including volumes used and final pressure ~laska 0Il & 6as Cons, Caren Representative Daily Average Production or Injection Data Anch0ra_qe OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 't"0-~4-04 Rev 05/17/89 Title Area Drilling Engineer Date SUBMIT IN~)UPLICATE ,sston ARCO ALASKA INC. DAILY OPERATIONS(~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: lA-13 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-20700 81-195 ACCEPT: 08/20/93 06:00 SPUD: RELEASE: 08/28/93 11:00 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 08/21/93 (1) TD: 7144 PB: 7025 08/22/93 (2) TD: 7144 PB: 7025 CIRC THRU CHOKE TO KILL WELL MW:12.8 NaCl/Br MOVE RIG F/ NORTH END OF lA PAD(WORK AREA USED FOR 3-3/4 DAYS OF ANNUAL RIG MAIN). SPOT RIG ON LINER & MOVE OVER WELL lA-13. ACCEPT RIG @ 1800 HRS 08/20/93 ON lA-13. PULL VR PLUG, PULL BPV USING LUBS. TRANSFER 218 BBLS MUD INTO PITS. RU HARD LINE. RU CIRC LINES. LOAD TIGER TANK W/SW. BREAK CIRC & LOAD TBG W/70 BBLS SW. MONITOR WELL. INJ 40 BBSL SW TO FLUSH OUT TAIL & 'C' & 'A' SAND PERS. MONITOR WELL. CIRC THRU CHOKE & FIN LOADING WELL W/SW @ 3-1/2 BPM. SI & MONITOR WELL AFTER SW RETURNS TO SURF. TRANSFER MUD F/OUTSIDE TANK TO PITS. TRANSFER 40 BBLS WATER FOR SPACER TO PILL PIT. COND MUD TO 12.0 PPG. CIRC THRU CHOKE: PMP 40 BBLS WATER SPACER FOLLOWED BY 12.0 PPG MUD TO KILL WELL. RIH W/FTA #i-PUDP MW:12.8 NaCl/Br CONT CIRC THRU CHOKE. MONITOR WELL UNTIL DEAD. SET BLANKING PLUG. ND TREE. NU BOPE. TEST ALL TO 3000 PSI. WITNESSING OF TEST WAIVED BY JOHN SPAULDING OF AOGCC. MU LANDING JT. BOLDS. PULL 3-1/2" HGR TO FLOOR. CBU. PMP SLUG. LDLJ & TBG HGR. POH STANDING BACK 3-1/2 "ABM-BTC TBG. LD JEWELRY, STAND BACK 103 STDS. RD TBG TOOLS. RU TO RUN DP. UNLOAD JEWELRY FROM RIG. LOAD BOT RETRIEVING TOOL, BUMPER SUB, OIL JARS, & 12-4-3/4" DC INTO SHED & STRAP SAME. SET WEARBUSHING. MU FTA #1: BOT RETRIEVING TOOL & BUMPER + JAR + 12 DC. RIH. PU 3-1/2" DP. RECEIVED SEP 3, 0 11993 Alaska Oil & Gas Cons. L, ummtsstO' Anchorage WELL: 1A-13 API: 50-029-20700 -PERMIT: 81-195 PAGE: 2 08/23/93 (3) TD: 7144 PB: 7025 08/24/93 (4) TD: 7144 PB: 7025 08/25/93 (5) TD: 7144 PB: 7025 CBU MW:12.8 NaCl/Br SERV RIG. CON RIH W/FTA #-PUDP. PU KELLY & CBU ABOVE FISH @ 6406', 3-3/4 BPM, 950 PSI. SINGLE IN W/KELLY & TAG TOP OF SLICK STICK @ 6483'. WASH & WORK OVER SLICK STICK & ENGAGE. J'S @ 6504'. BLED JARS OPEN & TRIED TO RELEASE PKR-UNABLE. TRIED ROTATING TO RELEASE PKR-NO GO. LAST ATTEMPT, JARRING PULLED RETRIEVER OF SLICK STICK, COULD NOT RE-ENGAGE. BELIEVE WE SHEARED RETRIEVING LUGS OFF SLICK STICK. CBU. PMP SLUG. TEST UPPER & LOWER KELLY COCKS TO 3000 PSI-OK. BLOWDOWN & STAND BACK KELLY. POH W/FTA #1. J'S IN RETRIEVER OK, STILL BELIEVE LUGS SHEARED OFF. PU TRISTATE TOOLS-STRAP & CALIPER SAME. MU GUIDE, OVERSHOT, EXTENSION, XO, BUMPER, OIL JAR-RIH 6 STDS DC. MU ACCEL JAR & PMP OUT SUB. RIH W/FTA #2. PU & SERVICE KELLY. BREAK CIRC. TAG TOP OF SLICK STICK @ 6484'. WORK DOWN ONTO SLICK STICK & SET GRAPPLE. WORK PIPE & PU TO 290K#-NO GO. JAR ON FISH @ 230K#, FISH GRAD JARRED FREE AFTER JARRING UP ABOUT 5'. PULLED FISH UP HOLE~30' & LET RUBBERS RELAX FOR ABOUT 15 MIN. CBU. VARYING RATE F/l-2 BPM & WORKING PIPE TO FREE UP PKR ELEMENTS-CIRC FAIRLY GOOD @ 1 BPM. POH W/BHA #1 MW:12.8 NaCl/Br CONT CBU @ 1 BPM-PACKING OFF. PMP SLUG. BLOWDN & STD BACK KELLY. POH W/FTA #2 & FISH. RECOVERED ALL FISH. LD ALL. FOUND FINE, DIRTY SAND PACKED ON ONE SIDE OF LOWER END OF BLAST JTS & EVIDENCE THAT LOWER 6'-7' OF 2-7/8" PUP ABOVE SEAL ASSY WAS PACKED IN SAND. BOT SEAL ASSY LOOKED GOOD. REMOVE FISHING TOOLS & FISH FROM PS. STRAP & CALIPER BIT & SCRAPER. MU BHA #i-BIT + SCRAPER + BIT SUB ON 4-3/4" DC. RIH ON 3-1/2" DP. KELLY UP. WASH & REAM SINGLES F/6416'-6736', CLEANING OUT SAND FILL ACROSS C SAND. TAG BOT 'lB' PKR @ 6736' CBU & CIRC HOLE CLEAN-RECOVERED FAIR AMT OF "TAR BALLS", 6ONT CIRC UNTIL CLEAN. PMP SLUG. BLOW DN & STAND BACK KELLY. POH W/BHA #1. MILLING PERM PKR MW:12.8 NaCl/Br CONT POH W/C/O BHA. BREAK OUT TOOLS. MU, RIH W/i-i/4" STINGER TO C/O PKR SEAL BORE. MU CIRC HEAD, WASH DN TO PKR. TAG PKR @ 6736'. ROTATE & WASH STINGER INTO & THROUGH PKR DN TO AVA NIPPLE REDUCER. CIRC PKR SEAL BORE CLEAN. POOH W/SEAL BORE C/O ASSY. LEFT 1" PIECE OF MULE SHOE F/I-I/4" STINGER IN HOLE. LD BHA. MU NEW BHA. EVAL 1-1/4" MULE SHOE & GO OVER OPTIONS. LESS TIME REQUIRED TO MILL PKR & RETRIEVE TAILPIPE ASSY. BRING IN COMPLETION JEWELRY WHILE WAITING ON TRI-STATE. PU, STRAP, MU TRI-STATE PKR MILLING TOOLS & RIH W/SAME. PU KELLY, BREAK CIRC, TAG UP ON PKR @ 6739'. MILL ON PERM PKR. AFTER MILLING APPROX 3', PKR STARTED SPINNING W/MILL. WORK MILL & PKR. RECEIVED S E P 0 1993 Alaska Oil & Gas Cons. L;ommissio,'~ Anchorage WELL: lA-13 API: 50-029-20700 -PERMIT: 81-195 PAGE: 3 08/26/93 (6) TD: 7144 PB: 7025 RIH W/CLEAN OUT ASSY MW:12.8 NaCl/Br CONT MILLING PKR F/6739'-6742'. CHASE PKR TO 6934' (TOP OF FISH), 6956' (TOP OF FILL). CBU. PMP SLUG. BLOW DN & STD BACK KELLY. RIG TO POH. POH W/MILLING ASSY. BREAK OUT, LD MILLING BHA. STRAP, MU FISHING ASSY. RIH W/BHA. RIH W/FISHING ASSY ON 3-1/2" DP. MU KELLY. TAG & ENGAGE FISH. CIRC & COND MUD. PMP SLUG. BLOW DN & S/B KELLY. BREAK & LD FISH. POH W/FISHING ASSY. MU BIT & SCRAPER & RIH. 08/27/93 (7) TD: 7144 PB: 7025 RUN COMPL ASSY MW:12.8 NaCl/Br CONT RIH W/BIT & SCRAPER. MU KELLY & BREAK CIRC. CIRC HOLE CLEAN. BLOW DN & S/B KELLY. POH, LD DP & BHA. SEND OUT BHA & ND FLOW RISER. RU SWS & PRESS TEST LUB. RIH TO 7800' W/GAUGE RING & JB. NO OBSTRUCTION. POH. JUNK BASKET EMPTY. RD JB & GAUGE RING. MU PKR/TAILPIPE ASSY OH PKR RUNNING TOOL. RIH W/PKR/TAILPIPE ASSY. CORRELATE ON DEPTH & SET PKR W/TOP @ 6740'. POH. RD SWS, NU FLOW RISER. RIG TO RUN COMPLETION. 08/28/93 (8) TD: 7144 PB: 7025 PREP TO ND BOP STACK MW:12.8 NaCl/Br RIH W/3-1/2" COMP ASSY. PMP SLUG. CONT RIH. MU SSSV & CONTROL LINE. MU TBG HGR W/CONTROL LINE. TEST CONTROL LINE TO 5000 PSI-WOULD NOT HOLD PRESS.' RIG TO POH. BREAK OUT & LD LANDING JT W/TBG HGR. POH W/5 STDS TBG, CHANGING OUT SEAL RINGS & DRIFTING. RE-TEST CONTROL LINE-OK. RIH W/ 5 STDS & MU TBG HGR. RE-TEST CONTROL LINE-WOULD NOT HOLD PRESS. INDICTIONS POINT TO PROBLEM @ SSSV. POH. BREAK OUT & LD LANDING JT/TBG HGR. CHANGE OUT SSSV & PUPS. MU NEW CONTROL LINE & TEST TO 5000 PSI-OK. RIH W/NEW SSSV, NEW CONTROL LINE & 3-1/2" TBG. PU TBG HGR & LANDING JT. TEST SSSV TO 5000 PSI-OK. LAND OUT COMP ASSY. RILDS. PRESS TBG TO 2500 PSI TO SET PKR. BLEED OFF & BOLDS. PU & SHEAR PBR W/1000 PSI ON TBG & 20M LBS OVER STRING WT. RE-LAND & RILDS. PRESS TEST CLOSED SSSV W/500 PSI FOR 15 MIN. PRESS TEST ANN & TBG TO 2500 PSI. PRESS TBG UP TO 3000 PSI. PRESS TBG TO 4200 PSI TO SHEAR SHEAR-OUT SUB. BACK OUT LANDING JT &' SET BPV. 08/29/93 (9) TD: 7144 PB: 7025 RIG RELEASED MW:12.8 NaCl/Br ND FLOW RISER & BOPE. NU MCEVOY GEN III 3-1/8", 5M TREE. TEST THA FLANGE. PULL BPV, SET TEST PLUG. TEST TREE TO 5000 PSI. PULL TEST PLUG. MU CIRC JT & HOSE. DISPLACE WELL TO SW. SI WELL TO STAB & MONITOR. RIG TO PMP DIESEL. DISPLACE WELL TO DIESEL BY PUMPING DOWN ANN & THROUGH CV @ 6440'. SECURE WELL & TRUCK FLUIDS F/RIG & LOC FOR DISPOSAL. INSTALL CELLAR WHEELS ON RIG WHILE CLEANING PITS. RELEASE RIG @ 2300 HRS 08/28/93. SIGNATURE: DATE: RECEIVED SEP ,5 0 Alaska Oil & Gas Cons. Commission Anchorage WELL N~ME ~M ~ FLUID ~ S~~DE S~ ~ ~S ~ ~ ~ P F ~o~ .... e~o zzoo ~zoo zz~ - ~-- ~0 IlO0 2 ioo *T~JBING 1NIRC'~ON FLUH): P = I~OIX)'CEDWATER]NI $ = SALT WATI~ INS M -- bl~CIBLE IN~CTION [ = IN.~CTING DI~EL SALT WATE~ DRILL~G MUD Orl'ig~ To ]~9. Blak W~tl (27~-7542} LTtle Initial __ 4-~ ~ Wo~kovcr __ Exptain: J U L 2 7 !992 Oil & Gas Cons. Commission 1. Type of Request: 2. Name of Operator STATE OF ALASKA ~ ~ . OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,, . Operation Shutdown ~ Stimulate m Plugging Perforate _ /~ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 '4. Location of well at surface 1049' FSL, 492' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1373' FSL, 1397' FEL, Sec. 6, T11N, R10E, UM At effective depth 1407' FSL, 1414' FEL, Sec.6, T11N, R10E, UM At total depth 1434' FSL~ 1425' FEL~ Sec. 6, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 71 4 4' true vertical 65 8 8' Effective depth: measured 7 02 5' true vertical 64 7 0' Pull tubing Alter casing Repair well " ~5. TyPe of Well: I Development Exploratory I Stratigraphic _ Service feet Plugs (measured) feet feet Junk (measured) feet None Pull tubing Othe.r' ..=_.X..- 6. Datum elevation (DF or KB) Casing Length Size Structural Conductor 8 0' I 6" Surface 2723' 10 3/4" Intermediate Production 71 1 5' 7" Liner Perforation depth: 100' RKB f~et 7. Unit or Property name Kuparuk River Unit _ 8. Well number 1A-13 9. Permit number/Approval number 9-822 10. APl number 5o-029-20700 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 200 Sx Perma 8 0' 8 0' 1000 Sx Fondu 2723' 2645' & 275 Sx AS II 1175 Sx Class "G" 71 1 5' 65 6 0' 250 Sx AS II measured 6592'-6669', 6693'-6709', true vertical 5940'-6015', 6040'-6058', Tubing (size, grade, and measured depth 3 1/2" J-55 set at 6776' Packers and SSSV (type and measured depth) Brown HB1 @ 6504' & Brown lB @ 6734', Camco TRDP-1AENC @ 1803' Stimulation or cement squeeze summary Intervals treated (measured) 6844'-6851' 6860'-6884' , 6190'-6195', 6205'-6230' Treatment description including volumes used and final pressure , ..Convert from water in. jector to WAG iniector. 14. Reoresentative Dailv Average Production or In!ection Data Prior to well operation (injecting) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X MD OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - 0 - 0 - 2000 700 2300 - 0 - 5600 - 0 - 0 - 3800 16. Status of well classification as: Water Injector__ WAG Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~--'~ ....... Title Senior Operati0,ns Engineer Signed ',~ - 05/17/89 Form ,, Date ,'~/Sy~'~' SUBMIT IN DUPLICATE W Z E A T L N A L E T 1 B SI o. A PR 3 B PR 4 B PR 5 B PR 6 A PR '='._. B TS 10 B PR TOTALS: W Z S E 0 T L N A L E T 7 B PW '.~ B PW 11 B SW 12 A PW 13 A OI 14 B PW 15 B G1 16 B PW KDGS MORNING WELL REPORT FOR 10118/89 DRILL:3ITE lA PRODUCTION WELL STATUS GA.'_--; L I FT STATUS 7" 10" TP TT WE: H25 CSG C:--;O F'SI CHK DEG % PF'M PSI PSI GA8 I Nd TEMP METER RATE DEO READINO MSCF 0 0 0 95 1050 1700 540 160 176 44 6 :2:6 1230 460 110 176 96:36 87 1110 790 125 176 36 5 30 870 475 190 176 134 86 183 1140 600 120 176 7:3 0 28 1290 740 180 176 110:39 25 1080 680 170 176 106 64 43 1210 750 0 ' 0 0 72 5893 804 67 4489 588 70 4795 291 62 1795 251 76 1295 317 80 7895 1094 68 5996 1618 4963 INdECTION WELL STATUS IN,JECTION RATE ALLOW I Nd PSI ACT 7" 10" I NJ T.T CSG CSG 'PS I DEG CHI<.: PS I PS I INd IN,J METER RATE RATE READING BPD MM$CFD 2500 1200 156 5 1450 300 2500 1950 142 15 1080 700 2500 1050 70 40 1420 20 2500 1:375 136 12 225 260 4000 3350 92 30 0 0 2500 1670 145 5 0 170 4000 2950 85 30 625 600 2500 1350 156 12 2010 910 :3621962 876 0.000 5442232 1360 0.000 3436859 76 0.000 4953385 1000 0.000 0 0 5.243 3988799 458 0.000 0 0 4.~87 2525505 2482 0.000 PAGE 1 S/I IMF'AE:T C H M 0 R I D EPL S N E BBL$ 2400 6::-: 17:3 000(~ 0 0 0000 0 0000 0 0 0000 0 O. 0000 0 0 0000 0 0 0000 0 0 178 S/I C H M 0 R'I D S N E 0000 · 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 TOTALS: SWI: 76 + PWI: 6176 = 6252 10.230 KDOS MORNING WELL REPORT FOR 10/14/89 DRILLSITE lA PRODUCTICIN WELL STATUS GAS LIFT STATUS W Z S E 0 T L N .A L E T 1 B SI 2 A PR 3 B PR 4 B PR 5 B PR 6 A PR 8 B TS 10 B PR TOTALS: 7" 10" TP TT WC H2S CSG C:SG PSI CHK DEG % PPM PSI PSI 0 0 0 95 1050 1680 540 175 176 45 6 36 1240 480 110 176 98 36 87 1090 775 130 176 36 5 30 875 450 200 176 132 86 183 1150 600 150 176 74 0 28 1300 740 210 176 112 36 25 1100 740 175 176 107 61 43 1200 770 INJECTION WELL STATUS GAS INd TEMP METER RATE DEG READING MSCF 0 0 0 76 5994 824 74 4493 611 77 4696 286 77 1886 225 80 4496 1160 87 7796 1073 73 6196 1645 5824 INdECTION RATE W Z S E 0 T. ALLOW L N A INd L E ~T PSI 7 B PW 9 B G1 11B SW 1) A PW 13 A PW 14 B PW 15 B GI 16 B PW TOTALS: ACT 7" 10" INd TT CSG CSG PSI DEG CHK PSI PSI INd INd METER RATE RATE READING BPD MMSCFD 2500 1290 160 5 1900 500 4000 3725 110 30 960 690 2500 1000 68 30 1390 20 2500 975 136 5 430 420 2500 1700 153 5 730 360 2500 1750 145 5 600 290 4000 3000 96 30 940 900 2500 1100 155 5 2080 1060 8617886 2966 '0.000 0 0 8.907 3432116 655 0.000 4,~", · ~...:,158 4029 0 000 7819199 1766 0.000 3985420 1939 0.000 0 0 4.812 2515908 2844 0.000 SWI: 655 + PWI: 13544 = 14199 13.719 PAGE 1 S/I IMPACT C H M 0 R I D EPL S N E BBLS 2400 63 178 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 178 S/I C H M 0 R I D S N E 0000 0 0000' 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 .... ~. ~SKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS _ sus. . _ w,.;-_ 1. Type of Request: Abandon Alter casing _ Repair well Change approved program ~ _ Plugging _ Time extension _ Stimulate_ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ,ARCO Alaska, Inc. !3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 1049' FSL, 492' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1373' FSL, 1397' FEL, Sec. 6, T11N, R10E, UM At effective depth 1407' FSL, 1414' FEL, Sec.6, T11N, R10E, UM At total depth 1434' FSL, 1425' FEL, Sec. 6, T11N, R10E, UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7144' true vertical 6 5 8 8' measured 70 2 5' true vertical 6 4 7 0' Length Size 80' 16" 2723' 10 3/4" 7115' 7" measured feet Plugs (measured) feet feet Junk (measured) feet None 8. Well number 1A.-13 //~J ~' ~--c T o/~.- 9. Permit number 81-195 10. APl number s0-029-20700 11. Field/Pool Kuparuk River Field ! Kuparuk River Oil Pool Cemented Measured depth True vertical depth 200 Sx Perma 80' 80' 1000 Sx Fondu 2723' 2 645' & 275 Sx AS II 1175 Sx Class "G" 71 1 5' 6 5 6 0' 250 Sx AS II 6592'-6669', 6693'-6709', 6844'-6851', 6860'-6884', ~ECEIV'Eg true vertical 5940'-6015', 6040'-6058', 6190'-6195', 6205'-6230', SEPI I 9 Tubing (size, grade, and measured depth -;.~l~,S~[ Di~ & GaS C0rJS. 3 1/2" J-55 set at 6776' Arich0rage Packers and SSSV (type and measured depth) Brown HB1 ~ 6504' & Brown 1B ~ 6734'~ Camco ,,TRDP-1AENC @ 1803' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch !Water injector to WAG injector 14. Estimated date for commencing operation October. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Suspended Service _Water I n!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' - ~7 FOR COMMISSION I[ISE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Date IApproval No. ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned C on'rrrll'~'~i6~e r Date SUBMIT IN TRIPLICATE 1A-13 Water Injector Conversion to WAG Injector No BOP's or workover fluids will be used during this work. The estimated B HP is 3400 psi at 6200' TVD. RECEIVED S EP 1 ~ 1989 Anchorage Procedure 1A-13- A Only SPFO/SRT. A Only Gas Iniection 1. Pull orifice valve at 6543' RKB. 2. Run dummy valve. 3. Allow well to stabilize at maximum water injection rate. 4. Operations Engineering to perform SPFO. 5. Operations Engineering to perform SRT after well has stabilized. 6. Convert well to A Sand only gas injection for 10 weeks. NC Gas In!ection. NC Water In!ection 1. Fill wellbore with liquid to avoid being blown uphole. 2. Pull dummy valve at 6543' RKB. 3. Run 1" FIo-thru MHHF orifice valve with a solid latch. (same valve as pulled in the above procedure) 4. Begin A/C gas injection. 5. Operation Engineering will communicate when to switch well to A/C water injection, based on gas injection rates. RECEIVED ! 1989 ,~i~ska OiJ & ~as Co~s. [;ommissio~: Anchorage ATTACHMENT 1 PAGE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY WELL ZONES COMPLETION TAKING WATER INJECTION BWPD '"'"~1A-13 20700 02/04/83 03/26/87 "'~1A-15 20711 03/01/83 03/25/87 'W--"IF-02 20881 10/15/85 01/13/87 1F-05 20807 10/28/85 03/08/87 ----W'"IF-IO 20984 08/13/84 01/27/87 ~IF-11 20993 08/12/84 03/09/87 ">~'lF-13 21020 08/16/84 03/19/87 SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C FOLLOWUP A&C SS A&C ~'" 1F-15 21025 08/16/84 03/24/87 SP NNER FOLLOWUP A&C SS A&C '~' 1G-09 21001 09/15/84 02/23/87 SPINNER FOLLOWUP ..~;':; 1G-14 21017 08/24/84 02/24/87 SURVEY FOLLOWUP A~C SS C 9100 ~lR-15 21387 11/10/86 02/25/87 SPINNER INITIAL A~C SS A~C Alaska Oil & Gas Cons. r,.~. ~. ~; _ ~choy~ge Mr. C. May 27, Page ? V. Chat' 1986 ton KUPARUK -EINITIAL RIVER UNIT INJECTI'O~ 'LOG~ INJECTION PROFILES Well Number Date of Initial Injection Date of Injection Profile lA-7 3/21/83 3/25/83 lA-9 3/1/83 3/22/83 lA-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 1A-13 2/4/83 10/17/83 1A-14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 1E-9 1E-13 1E-14 1E-t6 1E-19 1E-21 1£-23 1E-27 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Well Number Date of Initial Injection Date of Injection Profile 1F-10 1F-11 1F-13 1F-15 8/13/84 10/30/84 8/12/84 9/24/84 8/16/84 9/25/84 8/16/84 9/26/84 · Well Number Date of Initial Injection Date of Injection Profile 16-3 1G-6 1G-9 1G-i4 1G-16 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ARCO Alaska, Inc.j~k'~''= Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject' Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have an5 questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, B. B. Berg Operations Engineer BBB/SPT-pg:O069 Attachments Naska 0il & Gas Cons. CommisSion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '¢"~ STATE OF ALASKA t ALASKA ,6 AND GAS CONSERVATION C ISSION ~ d~.~ WELL COMPLETION OR RECOMPLETION REPORT AND Leo 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~X WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-195 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20700 4. Location of well at surface 9. Unit or Lease Name 1049' FSL, 492' FWL, Sec.5, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1373' FSL, 1397' FEL, Sec.6, T11N, R10E, UM lA-13 At Total ~epth 11. Field and Pool 1434'FSL, 1425' FEL, Sec.6, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I' 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15, Water Depth, if offshore 116. No. of Completions 01/07/82 01/20/82 01/25/82*I N/A feet MSL 17. Total Depth (MD+TVD) 18.PlugBack Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7144'MD,G588'TVD 7025 'ND ,6470 'TVD' YES ~; NO []I 1821 feetMD 1650' (approx) , 22. Type Electric or Other Logs Run . D IL/SP/GR, SFL/FDC/CNL/Cal, BHC/DIL/CR, FDC/CNL/Cal, CBL/CDL/CCL/GR, CCL/GR, Temp/Cradio/Spinner, Tracer, RFT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP. BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 65.0# ~ H-40 Surf 80' 24" 200 sx Permafrost . , 10-3/4" 45.5# ' "K'55 Surf' 2723' i3-1/2" 1000 sx Fondu & 275 sx AS I! 7" 26.0# K-55 Surf 7115' 8-3/4" 1175 sx Class G & 250 sx AS II :r 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) 6592' - 6669' ~ 3-1/2" 6776' 6521 ' & 6752 6693' - 6709' w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6844' - 6851' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6860' - 6884' 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 OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Dri l 1 i ng Hi story ~.,~ ~, ...... Form 10-407 * NOTE: Tubing was pulled & well recompleted 12/18/85. DAM/WC13 Submitin duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. Top Kuparuk Base Kuparuk Unable to obtain Each attempt was conditions. 6592' 6945' fluid sample. u~successful due 6391' :o hole 31. LIST OF ATTACHMENTS Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the TEST NO. 2 5 6 7 8 9 ( ~2 ~3 DEPTH PRESSURE 3024 3023 3608 3607 3024 3024 3023 3023 3022 3021 3020 3010 3009 3460 3458 3456 3454 3607 3640 3639 knowledge 3607 1407 psi 1 406 psi 1 641 psi 1 642 psi 1 406 psi 1 409 psi 1406 psi 1 408 psi 1 408 psi 1 408 pst 1405 psi 1 405 psi 1405 psi 1 584 psi 1583 pst 1 583 psi 1583 psi 1 649 .psi 1 656 psi 1656 p. si 1 642 psi Signed _ j Title Da~:e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ARCO Oil and Gas Company Well History - Initial Report,- Daily Inelructi~n~: Prepare and submit the "Initial R~t" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River ICounty, pariM1 or borouoh . North Slope Borough Lease or Unit ADL _ ~5647 Title Recompletio,~, State Alaska IWell no. 1A-13 ~/0 Auth. or W.O. no. AFE 603112 50-029-20700 Operator ARCO Alaska,. Inc~, Spudded or W.O~ begur~,..,: Workove~ - - - 12/11/85'd: ~ 12/12/85 12/13/85 12/I4/85 thru 12/16/85 9.6 ppg Acce OlO0::hre WRDE @SSSV;cu~ 7- 7 ":--:': .'.' :: ! ;.i.i: ....-, . 9.6 ppg NaCl/NaBr RestringWL, RIM', pull dumml~.t, vl;~@~636~:,-POM;t sly, set in SSSV; could not gecoff of slv~ Fin hard in & tst. Drop cutter bar, pull WL out of hole. RD. Kill well w/9.6 pp$ brine. ND tree, NI/& tst BOPE~. Shear Pull tbg to SSSV, Retry WL tls, LD SSS;;i~ RIH~'W/tb&~: Stab;- into pkr. 7" @ 7115' 7025' PBTD, TIH w/retrv'g tl 9.6 ppg NaC1/NaBr Spot kill pillacross perfs, observe well, POH.. Cbs collars to AB Mod.. RU to.,m:,:Dl~;- PU retrv..'g tt~, TIH, 7" @ 7115' 7025' PBTD, WO-' fSh'g tls 9.6 ppg NaC1/NaBr Fin TIH, rotate, out slick stick, cftc, POH, LD fsh. PU pkr retrv'g tls, TIH, mill pkr, CBU, POH w/pkr; hung Up ih~ DV ~' ~ ~ ~, .. collar. Jar on pkr, cont POH. Left pkr in hole, wait on fsh"~ ~,~ tls. 7" @ 7115' 7025' PBTD, POH 9.6 ppg NaC1/NaBr -- TIH w/spear, spear pkr hung in DY collar, jar on pkr, PO~;i~;~'g~O rec'd fsh. RIH w/6-i/8" tapered mill, m out DY collar, POH, LD mill. RIH w/bit i scrprs, tag fill @ 6769.', wsh & mn to 6841', gas bubble to surf, circ on choke, Cont wsh a rm. to 7025', CBU, attempt to POH, stuck @ 6995". Wrk free, CBU, PORt RIH w/OEDP, rev out. Stage in hole, rev circ tbg vol @ 6523', 6711', 6930'. RIH to 7016', rev cftc, POH.. PU EZSV, RIH, se~ @ 6547'. Tst to 2000 psi, POH. ND BOPE. Chg out tbghead, tst. NU & tst BOPE. Tst csg to 3500 psi. RIH, DO EZSV while. filtering brine. RIH to PBTD, CBU, POH, The above is correct For form p~p~'ratlon and dlstril~Jtlon, see Procedures Manual, Section' 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company ,~, 'F' Daily-Well History-Final Report Inetructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Rel~rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting State cost center code Alaska DistriCt ~County or Parish Alaska I Field Lease or Unit Kuparuk River Auth. or W.O. no. ITitle I AF~, 603112 WWS 1 Operator I A.R.Co. AECO Alaska, Inc. Spudded or W.O. begun IDate I Workover North Slope Borough ADL 25647 Recompletion IWell no. 1A-t3 W/O Date and depth as of 8:00 a.m. 12/17/85 12/18/85 Complete record for each day reported API50-O29-20700 W.I. rl'otal number of wells (active or inactive) on this I Icost center prior to plugging and I 56,24% labandonment of this well [Hour I Prlor etatue if a W.O. 12/10/85 ! 0100 hrs. I 7" @ 7115' 7025' PBTD, Rm'g Cbs 9.6 ppg NaCl/NaBr Fin POH. RIM w/scrp=s/JB, CBU @ PBTD, POH, LD DP. RU Schl, Cst lubr. Make gage ring/JB rn to 6840'. Pat BOT 1-B Pkr, set @ '6734' (WLM). RD Schl. RU to cn CA. 7" @ 7115' 7025' PBTD, RR 9.6 ppg NaCl/NaBr Rn 204 its, 3~", 9.2#, J-55 BTC AB MOD tbg w/SSSV @ 1821', HB-1 pkr @ 6521', 1-B Pkr @ 6752', HB-1 pkr @ 6521', "D" Nipple @ 6766', TT @ 6776'. Set pkr, cst tbg, shear SBR, re-lnd tbg. Tst SSSV, insCl BPV. h~ BOPE, NU & cst tree. Displ well w/diesel. Att Co Cst orifice vlv, failed. RU Camco, pull vlv @ 6457', insCl dummy, RD Camco. Tst tbg, set BPV. RR @ 0600 hrs, 12/18/85. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) 011 Produoing method Flowing Potential test data New TD Date 12/18/85 I PB Depth PBTD Kind of rig 7025 ' Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test timeProduction 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/~,~ For form preparation and dist~butlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITItle ! Drilling Superintendent ARCO Alaska, Inc. ( Post Office B~)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1A-13 Dear Mr. Chatterton. Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU13/L49 Enclosure If RECEIVED FEB 0 5 1S88 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION 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: 1049' FSL, 492' FWL, Sec.5, T11N, R10E, UH 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' 12. 7. Permit No. 81-195 8. APl Number 50-- 029-20700 9. Unit or Lease Name Kuparuk River Uni~ . 10. Well Number 1A-I~ 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool ADL 25647 ALK 46~ 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 ~ 0100 hrs, 12/10/85. Killed well. ND tree. NU BOPE & tested - ok. Pulled tubing. Fished & recovered pkr & tailpipe. Tstd csg to 3500 psi - ok. RIH & set lB pkr ~ 6734'WLM. Ran 3-1/2" completion assy w/tail ~ 6776', pkrs ~ 6752' & 6521', & SSSV ~ 1821'. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel. Tstd tbg to 1000 psi - ok. Set BPV. Secured well & released rig ~ 0600 hfs, 12/18/85. RECEIVED FEB 0 5 ~S~S Alaska 0ii & Gas Cons. C;0mm~ssi0n A~chorag~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ {~~ ,~~..~ Title Associate Engineer The space below~'zf/or Commission use Conditions of Approval, if any: Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU13/SN01 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office BOx 100360 January 14, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A~13 2H-7 3A-14 3F-13 3J-t2 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-t9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 LS-15 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 i986 Alaska Oil & Gas C~s. Uommis,s/on AF~CO Afc~skc Inc. ~.~; ,3 Subsidiary Of Atl,3nticF~ichfir. ld~.ompany ~i~u, STATE Of ALASKA O1[~ ALASKA AND GAS CONSERVATION C ,~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operatior~] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-195 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20700 4. Location of Well atsurface 1049' FSL, /+92' FWL, Sec.5, TllN, R10E, UPI 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 256/+7 ALK /+65 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1A-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of December ,19 85 12. Depthatend of month, footagedrilled, fishingjobs, directionaldrillingproblems, spud date, remarks ACcepted rig ~ 0100 hfs, 12/10/85. Killed well, ND tree. NU BOPE & tstd. Pulled tubing. Fished & recovered pkr & tailpipe. Ran 1-B pkr, tailpipe, & completion assy. ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured well & RR ~ 0600 hfs, 12/18/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 3-1/2" tbg. SSSV @ 1821', HB-1 pkr ~ 6521' 1-B pkr ~ 6752', TT ~ 6776' 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN 1 ~ 1986 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /j~ ~ ~~ TITLE Associate Engi neet DATE "-~-~L~ // NOTE--Report(~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ' Form 10-404 TEMP/MR07 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc./'[''~'' Post Office B(~X 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1A-13 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert well 1A-13 to a selective single completion. Since we expect to start this work on December 1, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4944 or Jeff Quintana at 263-4620. Si ncerely, J. Gruber Associate Engineer JG/tw SN/L074 Enclosure RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA L AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-1 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 COMPLETED WE LLxI~ OTHER [] 4. Location of Well Surface: 1049' FSL, 492' FWL, Sec.5, TI1N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' 6. Lease Designation and Serial No. ~_nL 25647 AL.K ~.65 7. Permit No. 81-19_~ 8. APl Number 50- 9. Unit or Lease Name 10. Well Number !A-!3 11. Field and Pool Kuparuk River Field Kuparuk River Oil 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 g 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 convert well 1A-13 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally t~ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: December 1, 1985 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED · NOV 91985 Alaska 0il & Gas Cons. Commission Title Associate Engineer Date Approved by COMMISSIONER ~®turned / By Order of the Commission Date Form 10403 (JLQ) SN/109 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.f~' Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 Ti{ANSMITTAL NO: 5285 ~.<ETURN TO: ARCO ALASKA, INC. KUPA~{UK OPERATIONS ENGINEEkING ~ECOKDS CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 £'KANSMITTED HI,.'RE~4ITH ARE THE FOLLOWING IT~/4S. ~ ACKNO~LEDG~ ~ECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS LISTINGS (ONE COPY OF EACH) ~C-11 06-23.-85 RUN %1 4427.5-8881.5 REF #70597 ~C-10~ 07-02-85 RUN ~1 1785.0-8987.5 ~EF #70620 ~C-9-' 07-10-85 RUN #1 3920.0-8332.5 REF #70642 ~C-7" 07-31-85 RUN #1 4617.5-8747.5 REF #70706 ~B-14- 03-20-85 RUN #2 3280.0-6803.5 R~F #70229 ~B-12-- 07-03-85 RUN #1 4021.5-8261.5 REF #70641 lB-11~ 06-26-85 RUN #1 2190.5-9257.0 ~{EF #70598 ~B-10* U6-17-85 RUN ~1 3273.0-7270.5 KEF #70555 IB-9---- 06-10-85 RUN #1 2092.0-8415.0 REF 970634 ~Z-15" 06-19-85 RUN #1 2658.0-6620.0 REF #70562 !Z-14/ 06-28-85 RUN #1 3876.0-8334.0 REF 970600 ',Z-13" 07-05-~5 RUN #1 4180.0-8538.5 R~F 970639 ',Z-12'- 07-20-85 RUN ~,1 4409.0-9412.5 KEF ~70661 ~Z-11,* 07-27-85 kUN 91 3531.5-7534.0 Rk'F 970704 N SOX 2 OF 2: P~/t..HOLE LIS TAPES PLUS LISTINGS (ONE COPY OF w-16~/ 01-28-85 }{UN #1 3116.0-7038.5 REF V-14'/ 05-16-85 RUN #1 3047.0-7086.5 V-12u/' 04-22-85 RUN #1 3960.0-9265.0 REF U-10~ 04-11-85 RUN #1 2972.0-7063.0 ~EF U- 7 ~F.~ '03-1-9-85 RUN 91 3594.5-8179.5 A-13~/' 07-16-85 RUN ~1 7649.5-8160.0 R-13'/ 07-27-85 kUN 91 3940.0-8578.0 REF R-12/''~ 07-20-85 RUN #1 3935.0-8277.5 REF K-11'~'' 07-13-85 RUN %1 3810.0-7213.5 R-10~'/ 07-06-~5 RUN 91 2991.0-8738.0' R-9'/ 06-28-85 RUN 91 399'1.5-8131.0 REF ~-7/ 06-04-~b RUN #1&3 0045.5-7103.0 kEF %70436---REVISED ~70614---REVISED #70613---kEVISED #70612---REVISED 970505---K~,'VlSED- 970645 #70702 #70660 #7U643 #70640 #70601 #70509 ~CEIPT ACKNO%~LEDGED: DISTRIBUTION: ~AE DRILLING W. PASHER CURRIER L. JOHNSTON EXXON {I.'VRON NOBIL PHILLIPS OIL M NSK CLERK J. RATHMELL DATE: ~_~ n,~_... ° ,-~.,~"~"'~ Cons. Corr~mission STATE OF ALASKA SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was ~,_/'/ transmitted via is hereby acknowledged: qUANTITY /~.~. DESCRIPTION -- #,¢,~,~/,~-/,~ - ~~~, ~' DATED: Copy YES sent to sender _ NO__~_~ ALASKA OzL AND GAS CONSERVATION CO ~SSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alaska Alas-~ Oil and Ca~ Consen'ation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DES CRI PTION - I/ ' , ' ' RECEIVED: DATED: Copy sent YES to sender KUPARUK ENGINEERING TRANSMITTAL" ,~ 2~ ~.~' TO'- ~ ~ ~~" FROM: D. Fay Allison DATE: WELL NAME-. Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY R~E'I PT ACKNOWLEDGED- DATE- '~PL EASE RETURN RECEIPT TO' ARCO ALASKA, INC. =~:~-~-~'"Oit&GasC~ns'.,~ '~ ATTN: D. FAY ALLISON - ATO/l115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 TO: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOF~EDGED: ~~LEASE RETURN RECEIPT TO: *. °. DATE: ,, ...... '..i:,:, }~' :" .......... ":' ARCO ALASKA, INC. ;~'" ..... ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office ~= $0 Anchorage.A.~,...,~a 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska 'Oil and Gas Conservation Con~n. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: · , Enclosed are well completion reports~ for ~KUparuk weI~s- - lA-10 through 1A-16A. Very truly yours, ~/J. S~ D~yton ~j~~~~ JSD/er cc: L. K. Blacker -AFA 330 w/o Attachment L. M. Sellers -ANO 332 w/Attachment E. A. Simonsen -AFA 311 w/Attachmant H. C. Vickers -AFA326 w/o Attachmant ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG -1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] sERvIcE [] ~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-195 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20700 4. Location of well at surface 1049'FSL, 492'FWL, Sec 5, T11N, R10E, UN 9. Unit or Lease Name Kuparuk Rlver Unit At Top Producing lnterval 1372'FSL, 13961FEL, Sec 6, T11N, R10E, UM 10. WellNumber 1A-13 At Total Depth 1434'FSL, 1425'FEL, Sec 6, T11N, R10E, UM ~.Fie~dandPoo~ Kuparuk River FieId 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. IO0'RKBI ADL 25647 ALK 465 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1/7/82 1/20/82 1/25/82 feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7144' 6588' 7025' 6470' YES[~ NO[] 1915' feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR SFL/FDC/CNL/Cal BHC/DIL/GR FDC/CNL/Cal CBL/CDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 SIIPf ~A ' ?A" ?0 fl.~w. 10 3/4" 45.5# K-55 S,,rf 2723' 13 1/2" lflflfl..w Fnnd,, & 775,.-w flq TT . 7" 26# K-55 SHrf .7115' R 3/4" 6fl?nw _P-!~ss G c.m.t _ l~nrl 53~w Clmn.~ R nmi- - i-m~ 1 24. RerforationsopentoRroduction (MD+TVO of Top and Bottom and ~ 25. TUBING RECORD interval,,size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6592-6669' ~ !/2" 6~99' 6/!25 ' 6693-6709 ' · · , '6844-6851 ' ' '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · 6860_6884, . w/4 SPF ..~ .. DEPTH.INTERVAL (MD) AMOUNT & KIND OF MATERIAL US.ED. N/.~. . , · ]'nt:erval perf"d, t~ice. . . 27. ' PRODUCTION TEST Date'First Production " I M~th0d of Operat, ion (.FI,gwing, gas lift, etc,:)... . . 3/19/82I Flowing ; Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ~ CHOKE SIZE GAS-OIL RATIO 3/19/82 12.0 TESTPERIOD'e 2591. !.26.7 -- ~ 4no Flow::Tubing . Casing Pressure CALCULATED i1~ OIL~BBL' ,GAS-MCF W~'I~ER-,BBL .OIL GRAVITY-APIT~o;r) Press'lB0 ' 24'HO'UR RATE-r' '" 51R2: 25~3 · --.'. 24.8° , .... 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gasorwater. Submit core chips. "'~*IV'E~ N/A "' '. ~'~' . . . , · " ~.,~.,,,l<a 0d & Gas Cons. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. 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 Kupa~'uk 6583' 6032 ' River Form. ,, Base Kuparuk 6945' 6391 ' River Form. .. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge $,gned ~,~_ , ~~/~ TitleRegiOn OpS' ERg~'' Date ")f/~Z-, , 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. ! ~',:?'~, :.i.~ ii: r~o cores taken, indicate "none", Form 10-407 , TRANSMITTAL NAME: Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE IPT ACKNOWLED DATE:jU[q i~ (38>! "'""-'k~ Oii ;~. (.]as Uons. Co,rz,~mWon LEASE RETURN RECEIPT TO: ARCO ALASKA, INC ~ ..... ' .... - P. O. BOX 360 ANCHOk%GE, AK 99510 KUPARUK ENGtNEER!NG TO: TP~.NSMITTAL .'-{ ~ D. W. Bose DATE: ~1~/~/0~.. WELL NA/~E: ! , Transmitted herewith are the following: PLEASE NOTE: BL - BLUELiNE, S - SEPIA, F - FILM,~ TAPE RECEIVED RECEIPT ACKNOWL, ED ':~ ~'~ ~.EO: j~,~a~ Alaska 0il & Gas Cons. Core.is.Sion ~.-SE RETURN RECEIPT TO: ARCO 'A~ASK~, 'lNG. .AO~horaffe ATTN ~O~,, L~. ~O~eO~ ' APA/3 t P. O. BOX 360 ANCHO~GE, AK 99510 ... ARCO Alaska, Inc. . '- .. Post Office ~3ox 3-~:, : Anchorage, Atr~sk~ ., May 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Consecvation Commission 3001 Porcupine Drive Anchocage, AK 99501 SUBJECT: Revised Well Completion Repocts Dea~ Mc. Chattecton: Enclosed ate revised well completion repocts and gytoscop~c sutveys fcc the Following wells: :~ 1A-13 B-1 B-8 1B-gGI Reports for the three B-pad wells ate being resubmitted due to an RKB change. The ociginal 1A-13 completion report lndzcated that certain items would be submitted at a later date; these items ate now included on the revised repott. P. A. Van Dusen PAV: JG/llm Enclosures GRU5/B15 Gas Cons. Commission Anchorage ~' STATEOF ALASKA ALASKA . .ND GAS CONSERVATION CO. ,...~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-195 3'. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20700 -- 4. Location of well at surface 9. Unit or Lease Name 1049' FSL, 492' FWL, Sec. 5, T11N, R10E, UN ~ Kuparuk River Field _ At Top Producing IntervalI~ 10. Well Number 1373' FSL,1397' FEL, Sec. 6, T11N, R10E, UH 1A-1~ _ At Total Depth 11. Field and Pool 1434' FSL, 1425' FEL, Sec. G, T11N, R10E,.UN.. ' ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 100'RKBI ADL 25647 ALK 465 I ' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01-07-82 101-20-82 01-25-82 feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7144'MD, 6588'TVD 7025'MD, 6470'TVD YESx~] NO[[] 1915' feetMD 1650' (approximate) 22. Type Electric or Other Logs Run DTL/SP/GR SFL/FDC/CNL/Cal BHC/DIL/GR FDC/CNL/Ca], CBL/CDL/CCL/GR 23, CASING, LINER AND CEMENTING RECORD , , 'SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED -, 16" 65# H-40 Surf so, ?a,, ?nn.,~ P~rrnn F~- n~i- ,10-3/4" ~45.5~ K-55 Surf ?7?3' 13-!./?" !O00s× rnna,, & 275sx A S II 533sx Ci~ss G emt - I , , 24. Perforatio. ns open to .Produc:tion (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, sizeand, number) . . SIZE.. DEPTH SET (MD) PACKER SET (MD) ,,. ' 3 !/2" 6499' 6/425' , N?A 26. ACID, FRACTURE, CEMENT'SQUEEZE, ETC. .. ... .. .... ..... E~'~P~-H..INTERVAL~ (MD) AMOUNT& KIND OF MA'I~ERIALUSED ., , · 27. pRoDucTION TEST ~. . Date F. rs~ Producdon · ..... .. Method of Operation {Flowing, gas lift, Otc.) N/A. , . .- , . .. Date of Test NoursTested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS-OILRATIO TEST PERIOD ~" :I . , Flow,Tubing. Casjng. P?essure CALCULATED ~ OIL:BBL' GAS.:MCF W. ATER-BBL OIL GRAVITY-APl (corr) 'Press.. : - .24-HODR RATE-- ' ' '.' .... , .. 28. ' CORE ~)ATA' ' I. Brief ~tescription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ... See O~illing History MAY1 8 i982 /U.~.ska 0il & Gas Cons. C0mrnissi0~. , Anch0ra~ ,. Form 10-407 submit in duplicate PDI II,/AOt O~' O'/ =r~u~+/t~/-~',/-'° ~C~t~ITINUED ON REVERSE SIDE Rev. 7-1-80 29. 30. 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 Kuparuk 6592' 6040' Base Kuparuk 6945 ' 6391' N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 .copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /7/~ /' /-~ _ ......... ~.. / I / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the prOducing intervals for only the interval reported in item 27. Submit a separate form for each additional interval' to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementin¢ too!. ARCO Alaska, InC. B~'~X Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Hand-carried SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Wm. VanAlen DATE' 'April 28, 1982 OPERATOR: Arco SAMPLE TYPE: SAMPLES SENT: core chips 6582 - 6640 6642 - 6756 6760 - 6816 6820 . 6875 6878 - ~ NAME' lA- 13 NUMBER OF BOXES: 12 at 1' intervals SHfl~PED BY: ~ ~~_~l.~_~l~.~~Paleo Lab Supervisor ON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 360 ANCHORAGE, ALASKA 99510 REr. EIVED Alaska Oil & Gas Cons. Commission Anchorage ':~RC© A!ask~ ~nc is ~ subsidiary of AtlanticRichfieldCompany ,. hO,,Tn SLOPE E~:GI,.~EERli:c Tran$mi;t-:d herev:ith are the following' J. J. Pawelek/Ann Simonsen S- -[,q~DiA,. F - FILM, T - TAPF /"/¢ RECEIVED APR 0 8 1982 ARCO ALAS~tA, INC. ATTIC: A;;N SI~.iO~iS£;! - AFA/311 P.O. BOX 360 A:;C}.{OIAC2, AK 99510 Alaska Oit & Gas C6ns. Commission ~choraga STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Arco Alaska, Inc. 81-195 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20700 4. Location of Well 9. Unit or Lease Name Surface Location' 1049' FSL, 492' FWL, Sec. 5 TllN, R10E Bottomhole Location' 1320' FSL, 1229' FEL, Sec. 6~ TllN, R10E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 61' GL~ 100' RKB I ADL 25647 ALK 465 Kuparuk 25647 10. Well Number lA-13 12. 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). Began perf. operations 3/8/82. Perforated Lower Sand at 6860-6884' and 6844-6851' MD with Schlumberger's 2-1/8 Enerjet at 4 SPF. Well did not flow. Reperforated Lower Sand on 3/11/82 using same gun and perforation intervals. Well still not flowing. On 3/14/82 pressured up on tubing from 1500-2720 psi, with only slight leak-off. Perforated Middle and Upper Sand at 6693-6~09', 6639-6669', 6609-6639', and. 6592-6609' with Schlumberger's 2-1/8 Enerjet at 4 SPF' Ran HP for static bottomhole pressure. Set HP at 6570' MD (5921' SS). BHP = 2909 psi. BHT = 152.3°~. Put well on production 3/19/82. Note' Based on Lower Sand perforating results, we decided to forego any attempts to perform a water injectivity test as stated in the original SundrY Notice. ... · RECEIVED MAR 2 '1987 Alaska 011 & Gas Cons. Comml~lt ~chorage 14. I hereby~v~certify that the~for~rue and correct to the best of my knowledge. Signed . ~ )~~-"- TitleArea Operations ti:n~,ineer The space e~w for Commission use /~ Conditions of Approval, if any: ~/ Date 3/23/82 By Order of Approved by. COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,Or.~r. ~LOPE E~',GIP, EERIi;G J. J. PaweleK/~nn Simansen Trans..qi:ted herewith are the following: ,r,~ SEPTA, PL~_E [~0? BLUEL~~ .. F - FILH, T - TAPP E ~.,ETUR;, f'IECE;?T TO: ARCO ALAS}tA, INC. ' P.O. BOX 360 ...... r.~ ' ~'?. ,.. ¢c.~lO RECEIVED DATE' MAR 2 2 Alaska Oil & Gas Cons. Commission Anchorage - AFA/311 NOP, TH ~LO?E EiiGI,~E~,,Ii;G J. J. Pawelek/Ann Simonsen DATE. ~- ~-' ~ 2_.. NELL,,,=,.,::"~"='- Transmitted here:.:ith are the following' ' ~'~' ~ SEP,~,, PL,.~.: iiOTE. BLU~L!;~,,~, " F - FILH, T - TAPF ;-.'- ,',~- ,_?-, t~E~'~:~?T TO' ARCO AL~S;~A, Ii~C. ATT~I: A~';~I SI:.iONSE~! P.O. gO:,: 360 ~" CcSlO DATE' - AFA/311 RECEIVED MAR 0 9 1982 Alaska Oil & Ga,., Cons. Commis,~ Anchorage NO,qTH ~LOPE EiiGIi'EER!i;G,L. -.. PLc'c-_.~_: i:OTE' BL --BLUEL].ilE, J. J. Pav:etek/Ann Simansen S - SEPIA, F - FILM, T - TAPE RE.£EIVED ' ]~AR 0 '5 ~982 Oil & Gas Cons. Anchoraga ("/ STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] OTHER [~ i'~~'..~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O.Box 360, Anchorage, 4. Location of Well Surface Location: Bottomhole Location: 5. Elevation in feet (indicate KB, DF, etc.) MAR ,3 2 !982 AK 9 9 5.~$ka nil & Anchorage 1049'FSL, 492'FWL, Sec 5, TllN, R10E 1320 'FSL, 1229 'FEL, Sec 6, TllN, R10E I6. Lease Designation and Serial No. ADL 25647 ALK 465 61' GL, 100' RKB 7. Permit No. 81-195 8. APl Number 50- 029-20700 9. Unit or Lease Name Kuparuk 25647 10. Well Number lA-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Poo~. 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ 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). In order to establish the ability to inject into the Lower Kuparuk Sands, ARCO Alaska, Inc. intends to perform a third water injecti- vity test. Previous test have'proven unsuccessful in establishing injection into the Lower Sand at pressures below fOrmation parting pressure. Because of the importance of this information to Incre- ment I Waterflood planning, we plan to attempt injection into the Lower Sand of Kuparuk lA-13. The well will be initially perforated from 6860'-6884' and 6844'-6851'. After perforating, the well will be allowed to flow to production for approximately one month to clean up the formation. A well test will then .be conducted to determine the extent of any formation damage present. Based on the well test, a decision will be made with regard to an acid stimula- tion. If no stimulation is required, or after the stimulation is performed, the injectivity test will be run.. We will inject water for 2-5 days, shut in for pressure falloff, perform a step rate test, and shut in for a final pressure falloff. After the test, we will attempt to flow the well back for 1-2 weeks, at which point we will perforate and test the Upper and Middle Sands at 6588'-6668' and 6692'-6708'. The well will then be flowed to the. CPF. Perforating of the Lower Sand will begin March 5, 1982. Injection testing is currently planned for mid-April and should last no longer than 10 days The spac~low for Commission us~/ Conditions of Approval, if any: 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ORIG!H~L SIGNED BY LOHN]E C. SMIT]~ Approved by Approved Copy Returned gv.5~equent Work ~epozt~ By Order of ~ ~--d --~~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-S0WMP B-27 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Ala,ska, Inc. Posl Office B ,0 Anchorage. Aias'~a 99.510 ¥: !,-..~.~t~.~,~ o97 February 22, 1982 Mr. C. F. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 5001 Porcupine Drive ~chorage, Alaska 99501 Subject- State Reports Dear Sir' Enclosed please find Well 'Completion Reports for the following drill sites- 11-6, 12-4A, 13~19, 14-9A, 14-26, 15-15 1A-12,ilA, 13, and B-11GI. ' Also included are Monthly Reports for January on drill sites- 13-20, 13-23, 14-30, 15-1, and lA-14. Sincerely, P. A. VanDusen District Drilling ~ngineer Enclosures PAV/GLA' sins ' ...... STATE OF ALASKA ALASKA ( i'--*ND'GAS CONSERVATION C .;AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ]~}(' GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-195 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50- 029-20700 4. Location of well at surface 9. Unit or Lease Name 1049' FSL, 492 FWL, Sec. 5, TllN, R10E, UM Kuparuk River Field At Top Producing Interval 10. Well Number To Be Submitted. lA-13 At Total Depth 11. Field and Pool To Be Submitted. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River Oil Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., BUBO. or Aband. 15. Water Depth, if offshore [ 16. No. of Completions 01/07/82 01/20/82 01/25/82 feetMSL] 1 · 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) t9. Directional Survey 20. Depth whereSSSV set 21. Thickness of PermafrOst 7144 ' 7025 ' YESX~C NO ~ 1915 ' feet MD 1650 ' (Approx.) 22. Type Electric or Other Logs Run DIL/SP/GR SFL/FDC/CNL/Cal BHC/DIL/GR FDC/CNL/Cal CBL/CDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD' CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf. 80' 24" ' 200sx P~ F. cmt 10,.3/4" 45.5# K-55 .Surf. 2723' 13½" .1000sx Fondu & 275s.x A.S. II 7" 26# K-55 Surf. 7115' .. 8 3/4,: 642sx Class "G" cmt - lead 533S× Class "G" cml - tail 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD , · inte(,val, size and number) · : SIZE DEPTH SET (MD) PACKER SET (MD) 3z 2 6499 ' 6425 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. " ,. · . · .. .. : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · N/A N/A ~.- · · · 27. ~ . PROOUCYIoNTEsT':'~' ~ : . Date Fi,rst Production .. Mb(hod of;Operation (FI.owing, gas,lift, etc.) . Date of. Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MC'F WATER-BBL CHOKE SIZE GAS-OIL RATIO ! ,~ .TEST PERIOD~I~ Flow Tubing - Casing Pressure CALCULATED· iiii'- OIL-BB, L GAS~MCF WATER:BBL OIL GRAVITY-APl (corr) : : ,24-HO'~'Ru RATE~r ': ' ' Press. 28. CORE DATA' · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' , See Drilling History · . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. .- '" 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. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title ])z'::i.l:~J. ng ~g:j.:P_eeTDate 7' K" -/ .... 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. I.tem 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 (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- in9 and the location of the cementinq too!. Form 10-407 ~AlanticRichfleldCom Core Description Report D~erato~T~-nd well name Page · ~)f ARCO Kuparuk A-13 1 ] 1 Location Date Section 5-TllN-RIOE January 15. 1985 ~ore number Ilnterval tCut Recovered - 1 I 6572.0' - 6582.0' , 10.0' .0' , Depth Thickness .Description ,, · · 6572.0-6582.0 10.0 No Recovery. --, , , . .... .:. , . . , , , . ,. . ~ , , . ,, . . RECE!VED, · Anchorag, , , ...... , ., AR3:~-2389 i Core number __Field Descri~ption by C. E. Paris 1 a~~ ~' ~ .... COre Description Report A!lanticRichfieldComp 'v' .. C;3er~tor and well name "~ Page Of ARCO Kuparuk A-13 1 ! 2 Location Date Section 5-TllN-RlOE January ]6; 1987 Core number Ilnterval lOut Recovered .... 2 I 6582.0' - 6642.0,, 60.0' 58.5, ... Depth Thickness Description 6582.0-6595.0 13.0 Shal'e, medium gray, siliceous. Pyritized'plant fragments and mica flakes on bedding surfaces. Small curved fracture with slickensides at 6593.0'. .. 6595.0-6603.0 8.0 TOP KUPARUK RIVER FORMATION, TOP D. Si ltstone, light . . 'gray,green, with shaly carbonaceous laminae. Small tubular burrows (0.5 cm. long), which are a dark gray color. ' ' ' , , Gradational upper and lower contacts. Floating white, ~ . well rounded, quartz grains .(.fine grained) and dark gray chert grains (granule size). 6603.0-6617.0 14.0 TOP C-4. Sandstone, light green-brown, .localized oil staining, upper fine to medium grained, quartzose, fair to. moderately .sorted~ subangular to subrounded, poor .to. · , fair porosity in cemented zones, excellent porosity i'n , · friable zones, top eight .feet is completely well cemente, d with Carbonate cement (siderite)., lower six feet has _ .patchy areas of friable sandstone., .irre.qular vertical fractures devel, oped in t'he well cemented 'sandstone. Fractures · and vuggy secondary porosity have an .amber cut and milky . white-yellow flUorescent cut. Glauconite co.ntent ranges . from 25-30%, increasing locally to 30-35% .......... , 6_617.0.-6640.5 23.5 TOP C-3. Sandstone, medium green-brown, excellent oil stain, fine grained, auartzose., fair to mo ~ d,. __ subangular to subr°unded~,, semi-friable, exc~(~'n~; p~§~i.ty ~i ~ C m~sm0n .... ~.~ permeability, G~auco,~e co,~en~ ~~' ~,_~ ~,~ ' ~.' the top to a~ound 10% at the base of core. Becomes sli. ght]y ,,. .. micac.eous near the base. No visible.sedimentary structure.~. ICore number Field Description by C. E. Paris 2 AR3B-2389 ARco Oil and Gas Company Operator and well name Location ARCO Kuparuk A-13 Section 5-T11N-RIOE Core number Depth 6640.5-6642.0 Thickness 1.5 Ilnterval 6582.0' - 6642.0' Icut 60. O' Description Core Description Report Page of Date January 16:1982 Recovered - 58.5' Good'odor, yellow fluorescence, dark amber cut, streaminq milky-green fluorescent cut, excellent show. Siderite zones at the following depths: 6625.0' (0.3' thick), 6627.0' (0.4' thick), 6630.5' (0.5' thick), 6636.0' (0.4' thick) and 6639.0' (0.5' thick). Thes~ zones have fractures which bleed oil. Grain size decreases from upper fine .grained at top to lower fine qrained at base of core. No Recovery. ~kLL, C I D 0Ci:1 1982 Alaska 0il & Gas Cons, Ccmmisaion ~ch0rage Field Description by C. E. Paris ICore number 2 AR3B-2389-A AtlanacRichfieldCo p Core Description Report Operator and well name Page of ARCO Kuparuk A-13 1 I 1 ~.ocation Date Section 5-TllN-RIOE January 16, 1982 ~:ore number Ilnterval lOut Recovered 3 I 6642.0' - 6700.0'I 58.0' 58.0' Depth Thickness Description 6642.0-6676.0 34.0 C-3'(continued). Sandstone, medium gray-brown, good oil -- . stain, fine grained, moderately sorted, subangular to subrounded, good.porosity and permeability, semi-friable, -,, good to excellent show. Gradational lower contact. Siderite - · zone at 6662.0' (0 7' thick). Glauconite content .ranges from 10% at top of core ·to trace amounts near basal contact. , , 6__676.0-6700.0 24.0 TOP C-2. Sandstone, light brown-green, with interfingers of light, gray silty sandstone. Sandstone,. good oil stain, fine grained, 'moderately sorted, subangular to subrounded, , good porosity and fair permeability, semi-friable,, contains zero to traCe amounts of glauconite Grain Size decreases from upper fine grained at top to lower fine grained at __ base. Silty sandstone, lower very fine grained, argillaceous and carbonaceous matrix~ zero to trace amounts of glauconite, . . fair porosity The amount of silty sandstone decreases _ downwards Siderite zone at 6682.·0' to 6683.0'. · , ,, · .. OCT 1 1982 Alaska 0i~ & Gas C0n~ · . . .,, iCore number Field Description by C. E. Paris 3 AR3B-2389 ·/~,RCO,'Oil and Gas Company ( Core Description Report Dpe'rator and well name -- ~' Page ~f ARCO Kuparuk A-13 1 ! 2 Eocation Date' Section 5-TllN-RIOE . ,lanHary 17 log Core number tlnterval ICut Recovered · 4 6700.0' - 6760.0' §0.O' 55.5' Depth Thickness Description 6700.0-6703.0 3.0 TOP'C-I' Sandstone, light §reen-brown, e~(cellent stain, upper very fine grained to lower fine grained, moderate to well sorted,, subangular to subrounded, good porosity and permeability, micaceous, trace to 5% glauconite, yellow fluorescence, dark amber cut, milky-green cut, good odo.r., . excellent Show. Sideri'te zone With Vuggy.'Poro§ity at 6702.5' to 6703.0'. 670.3.0-6710.0 7.0 Sandstone, l iqht green-brown, 'upper fine grained, glauconi.te . content 20-25%. 'Siderite zone at 6704.2' to 6704.8'.. 'Patchy carbonate cementation from 6705.0' to 6708.0' which has a · , , , similar appearance to C-4 unit. 6710.0-6719.8 9.8 Sandstone, upper fine grained to lower medium grained., 25% ........ §lauconite content, yellow...fluorescence, amber cut,· milky- . green fluorescent cut. Thin stringerS (t~__wo inches thick) of upper medium grained .sand occur sporadically in thi~ .~'P_ctinn. , . Small patches of pyrite (0.5 cm diameter).and cnal frRgmPnts · also occur in this interval. 6719.8-6720 5 0.7 Sandstone, lower coarse grained with rounded dark qray pebbles · at base, semi-friable, sha.r.p upper and basal contact. 6720.5-6735.0 14.5 TOP B- Interbedded sandstone (60%),.siltstone (10%) and .. mudstone (30%). Sandstone' li§ht brown, qood stain, very' fine ~qrained, well sorted,-suba.ngular to subF~)~{31~l ~l~,~od - 'porosity, fair to §ood permeability, semi-fr/~le, small · .scale cross laminations. Siltstone: ~l..~uj)),, ~ca~, mlc.aceous · . "" "~as cons C~,~_ ' . with small horizontal burrows. Mudstone:· dar~O~.~'~'~ion . . sandstone interheds are tentic~l~r in ~h~n~. tdhit~ fin~ . AR3B-2389-A Field Description by C. E. Paris Core number ARCO Oil and Gas Company (( ( Core Description Report Dperator and well name Page of I ARCO Kuparuk A-13 2 I 2 Location Date Section 5-TllN-RIOE January 17, 198; 4 6700.0' - 6760.0' 60.0' . 55.5' , Depth Thickness Description grai'ned 'sand-size specs occur sporadically throughout the section. Medium grained glauconitic sandstone bed (2-3" thick) occurs at 6722.0'. Thin siderite zones occur at 6722.0' and 6724.0'. Between 6730.0' and 6731.0' the sandstone content increases to 70-80%. This sandstone has a.gold .f. luorescence,.dark . . .... amber cut, milky-green fluorescent cai;. ~ ' 6735.0-6748.0 13.0 Interbedded sandstone (40-50%), siltstone (10%) and mudstone .r (40--50%). Lithologies same as above. Mudstone interval at · . .6740.0' (0.3' thick). ,, 6_748.0-6755.0 7.0 Interbedded sandstone (40%), siltstone (40%) and mu'dstone . (20%). Lithologies as above. 6755.0-6756.0 1.0 Interbedded sandstone (80%), siltsto'ne (10%) and mudstone (10%). Lithologies as above. 6756.0-6760.0 4.0 No recovery. . · . , · · . · . · , ,. .... ~j# ~ ,", -..., · "~'¢~,,,,L''~ ~,~m,~ ..... AR3B-2389-A Field Description by C. E. Paris lCore number 4 ARco,'~il and Gas Company ( .... Core Description Report ARCO Kuparuk A-13 1 Location Date Section 5-TllN-RIOE January 1.7; 198~ ~ore number .' Ilnterval [Cut Recovered 5 6760.0' - 6820.0' 60.0' 57,0' Depth Thickness Description ....... 6760.0-6761.0 1.0 Sandstone, light brown, good stain, lower very fine grained, well . sorted~ subangular to subrounded, semi-friable, yellow fluorescence, clear cut, clear to slightly milky fluores.cent - cut. -, 6761.0-6797.0 36.0 Interbedded sandstone (60'70%), siltstone (10%) and mudstone ... .... (20_30%). Sandsi~one.' l~ight'brow'n,"f'air to goOd stain, lower very fine grained, semi-friable. Siltstone' medium , gray with small horizontal burrows. Mudstone'. dark gray. This interval contains sedimentar.y structures and trace fossils typically seen in the B unit. The sandstone beds . thicker than an inch have. a good stain. Siderite zones at · ' 6785.5' to 6786.5' and 6794.0' (0.2' thick). . ......... 6797.0-6817.0 20.0 Interbedded sandstone (40-60%), siltstone (10%) and mudstone (30-50%). Lithologies as above except sandstone is finer .. .. , grained and si ltier. Large augen-shaped burrows at 6807.0'. Small lenses of white, fine Qrained sandstone at 6g09.0'. _ _ . may be storm lag deposit. · · . 6817.0-6820.0 3.0 No recovery.· . , , _ , , ICore number Field Description by C. E. Paris 5 AR3B-2389-A /~RCO :~il and Gas Company ~,l~ ( Core Description Report ~--i~erator and well name ' Page ~ of J I ARCO Kuparuk A-13 1 .~ 12 ['ocation Date Section 5-TllN-RlOE January 18, 1982 ~'ore .umbe~ I,.te~val[Cut Recovered 6 6820.0' - 6878..0' . 58.0' 55..5.' Depth Thickness Description ...... · 6820.0-6822.0 2.0 Interbedded sandstone (40-60%), siltstone (10%) and mudstone . (30.-50%). Sandstone' light brown, lower very fine grained, · . silty, semi-friable. Siltstone- medium qray. Mudstone' dark 9ray~ 6822.0-6830.0 8.0 Interbedded sandstone.(40%), mudstone (.50%) and siltstone ., (10%). Lithologies as above.. White, fine .qrained, calcareo..us sandstone lens.es at 6826.0' (3-4" thick). 6830.0-6850.0 20.'0 Interbedded mudsto, ne (70%), sandstone (20%) and siltstone .,, . (10%). Lithologies as above. Medium grained sand scattered ~ .~ through four foot interval at 6835.0'. .. 6850.0-6855.0 5.0 Interbedded mudStone (80-90%), sandstone (10-15%) and siltstone (0-5%). Lithologies same as above. Sandstone percentage decreases downward' Medium bro.wn claystone bed at 6852.0' to 6852.8'. · ~6855.0'6865.0 10.0 Interbedded mudstone (65%), sandstone (30%) and siltstone' · · (5%).. Basal one .f. oot is claystone. Lithologies as above, _ Sandstone percentage decreases downward. 6__865.0-6868.0 3.0 TOP A-3' Sandstone (90-100%) with n~udstone .partings (0-10%),. Sandsto.ne' 1.ight brown, excellent stain, very fine grained= quartzose, well sorted, subrounded; good porosity .and permeability: .-- semi-friable, abundant low.angle cross-bedding, gold fluorescence; · dark amber cut, excellent show. MudstOne- dark arav. occ. ur.s as wavy partings in sandstone. Top 0.5 foot is~.'~n~_~i~__~_~D >~' wi th c a 1 c i te. CIO.3', ~no,) 6868.0-6870_~5 2.5 Int~_rheddPH ~Rnd~t. nnm (6Ci_-R(l~) Rnrl ml~rlqfnr~~e/l~m~m~.~,inkim~_ln=imc ...................... ~, .... ~ v~l rl1,311S~0~j-~ as above. Anchorage , , I Core number Field Description by C. E. Paris 6 AR3B-2389-A AR.CO Oil and Gas Company Core Description Report Operator'and well name' " "'~ ]Page of I ARCO .. Kuparuk A-13 2 I 2. ~_ocation Date Section 5-TllN-RIOE ,lmn,tmrv 18 lClR2 ~;ore number Ilnterval lout Recovered"'*-- _ 6 ,. 6820.0' - 6878.0, .~R.(~' Depth Thickness Description ~ .. 6870.5-6875.5 5.0 Interbedded mudstone (60-80%) and sandstone (20-40%). Lithologies as above. ., 6875.5-6878.0 2.5 No recovery. -- .. · ., · ,.. , ., ,, , _ .. ,, ._ · , .... , , , .... · 'A]aska Oil'& Gas Cons, .. Anchorage ...... AR3B-2389-A ......... t Core number Field Description, by C. E. Paris 6 ARCO 'Oil and Gas Company Core Description Report 3p~rator and well name Page I ARCO Kuparuk A-13 1 I 1 Location Date Section 5-TllN-RlOE January 18. lgR; · Core number Ilnterval ICut Recovered ~ ' 7 , 6878.0' - 6937.0' 59,0' 61,0' Depth Thickness Description · .. 6878.0-6898.0 20.0 TOP ~-2: Sandstone, light brown, excellent stain, very fine graint . quartZose,.well sor. ted, subangular to subrounded= semi-friahlP, ... good porosity and Dermeability; abundant low angle crnss-bedding~ excellent show. Wavy, mudstone partings throughoUt lower 2/3 _ · of this interval. , , 6898.0-61902.0 4.0·- Interbedded sandstone (75-90%), siltstone (5%) and mudstone . (5-25%). Lithologies as above. . , 6902.0-6915.0 13.0 . Interbedded sandstone (50-75%) and mudstone (25-..50%).. Lith°lo§ies as above. Light gray, carbonate cemented sandstone bed at ..... 6907.0' (0.2' thick). 6915.0-6918.0 3,0' Interbedded sandstone (30-50%), mudstone (30-40%), and siltstone ' . ~. (10%)... L!thologi. es as above. . . . 6918..0-6924.0. 6.0 . Interbedded sandstone' (10.-30%), mudstone (70-90%) and sil.tstone ~ (0-5%). Lith. ologies as above. Pyrite nodule at.6923.0' (4" .... .long, 2" wide). , , 6_924'.0-6927.0. 3.0 Interbedded sandstone (30-50%), mudstone (50-70%) and. siltstone ... (0-5%). Lithologies as above. . . .. 6927.0-6939.0· 12.0 Interbedded sandstone (50-80%) and mudstone (20-50%). Li.thologies as above. Sandstone beds greater than 0..2 feet thick at 6935.0'- 6936.0'. , · END OF CORE ,. OCT 1 1982 ..... A)aska 0ii & Gas Cons. Anchorage AR3B-2389-A Field Description by C. E. Paris IICore number 7 lA-13 Drilling History NU hydril and diverter. Spudded well @ 1145 hrs, 01/07/82. Drilled 13~_" hole to 2750'. Ran 65 jts 10-3/4" 45.5#/ft K-55 BTC casing w/shoe @ 2723'. Cemented 10-3/4" csg w/ 1000sx Fondu and 275sx A.S. II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi. NU BOPE & tstd to 2500 psi - ok. Tstd 10-3/4" csg to 2000 psi. Drld FC and cmt to 2710'. Tstd 10-3/4" csg to 2000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 4847'. Ran DIL/SP/GR SFL/FDC/CNL/Cal. Ran RFT tool in Cretaceous Sands. Drld 8-3/4" hole to 6572'. Cut core #1 fr/6572 - 6582, core #2 fr/6582 - 6641, core #3 fr/6642' - 6700', core #4 fr/6700' - 6760', core #5 fr/6760' - 6820', core #6 fr/6859' - 6878' and core #7 fr/6878' - 6936'. Drld 8-3/4" hole to 7144'. Ran BHC/DIL/ GR and FDL/CNL/Cal. Ran 176 jts 7" 26# K-55 BTC csg to 7115'. Cmtd 7" csg w/ 642sx Class '%" cmt lead slurry followed by 533sx Class "G" cmt tail slurry. Set 7" packoff and test to 3000 psi - ok. Tstd 7" csg to 2000 psi - ok. Arctic Packed 7"x 10-3/4" annulus w/300 bbl H?O, 250sx A.S. II and 102 bbl Arctic Pack. Drld FC & cmt to 7025'. Displa~ed well to NaC1/NaBr brine. Tstd 7" csg to 2000 psi - ok. Ran gyro and CBL/VDL/CCL/GR. Ran 3~" completion assy W/tail @ 6499' and pkr @ 6425'. Tstd tbg hanger and packoff to 3000 psi - ok. Displaced brine w/284 bbl dies61. Dropped ball and set pkr. Pins... sheared in shear out sub @ 3000 psi. Press tbg to 3000 psi & csg to 45Opsi - ok. ND BOP£. Nil tree & test to 3000 psi - ok. Tstd tbg to 3000 psi and annulus to 500 psi - ok. Bled tbg to 500 psi - ok. Instld BPV. Secured tree & released rig @ 0430 hrs, 01/25/82. Mr. Bob Hines ARCO Alaska, Inc.. P. O. Box 360 Anchorage, Alaska 99510 January 26, 1982 Re: Our Boss Gyroscopic Survey Job No. Boss-16962 Well No. lA-13 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: 1-23-'~2 Operator: Marvin Milam Dear'Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional .Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures cc: Dave Rees - BP Alaska Exploration Co. Steve Lambert - Union Oil Company Donald James - Sohio Petroleum Company RECEIVED iV'lAY 1 8 1982 Abska Oil & Gas Cons. Commissior~ Anchorage SPERRY-SUN WELL 'SURVEYING COMPANY PAGE - 1 ANCHORAGE ALASKA ARCO ALASKA, INC DATE OF SURVEY dANUARY 23, 1'~'''''' · . ;Ii:,... KUPARUK :..- ~"..' :. : ..: ?::: ::.: ..:. ' :: .'. :: .::..' ApR I L...';' 12,:.~:~;~:i 982 ,_lOB NUMBER · " : ' ~ ~ ''.'" :~ :, : .:.-. ~':: '.' ':.i~:.:'::':.::~::::~'~-?h::.:~<:~:'::.k~F.:..:::-:.~..':.:~ '.' .>:.:<~: "?q:'..:,.::~:':~::-~:::: .. ~.':.' .T:.. ?: . ::~:":~ ::.~ .::>- ::::.'_:.' :: ': .:".'::~:~h:~F~F:'.:.- .'. :. .'. : ':. 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L .:,LRVEYING COMPANY PAGE ANCHORAGE ALASKA ARCO ALASKA,, INC. DATE FIF "".=,L RVEYI "' ,,...IANI IARY_ ,_.._,.z,.-..,, 1 "":'"".-.~',':,z .: ~.]A:.~I'3",fSECS::.TI~N-~'RI'OE): ..... .... ..~:::,::7:::::COMPLrr~T~]]ATE: :~ Er=SS'- L]-?~RCi~~S~~.::. .... : ~ERTZ6:~L 8ECTZON C~LCULATED ~LONG CLOSURE · , .... ., ,::-"-::::::=:::}':::"':::"':"'::::'TRUE-:::""~:::::: SUB~-SEA:::::":::: "ODURSE::::::'::C~iiiRSE:':-:-,-DO6-=bEG:::: : ~:: · rE~A~ .. :....:. ~: C :: :::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: :::: :::.:::::::: [ el 0? ::::::::::::::::::::::::::::::::: :::.ins, :::::::::::::::::::::::::::::::::::: ' '-' 372.95 W 350. · .:,~U u ...,=,o6'-"-"--'. 42 2786.42 3:4-...._, N . . 10 W 0 . 17 Z,=,, 46 .=,'-' 3100 2.968.14 28/:,8.14 35 28 N 82.30 W O. 74 71.13 S 430.11 W 407. .............. 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I]ATE OF SURVEY dANUARY 23, 1:-]82 = .-I-A-'I.5~--¢StEE;5-T-I-1-N.RiOE:)~.~ · ~ ~.:~ , : :. · ~ C:OMPUTA-TI~DN-DATE-'--~-----: 'En'=~!.]YROE;COP~I~JR~/EY~ ~!'~ ~ .... ~ :: .~' ': VERTICAL SECT iON C~LCUL~TED ~LONO CLOSURE .:.: MEA..,URED: :: VER.TI ~.AL:::i:i,VER~:I E. AL.::::tNL:LI:NA:TI:iUN:::i::i:i: ::Di R EE, TZ, 0N : :oEVER I T.Y::.::i: :RECTANuULAR . C00RDI NATEs.-,: DEFi~:~ :: i'i::=: !i DEPTH ii::i iil 0¢] :i;~:NORTH/S_r_~i ITH: ::. ::!:;::i::.EAST/WEST: I 6000 5455.81 5355.81 12 5 N 54.39 W 1.'P4 256.36 N 1826.11 W 1840.83 6100 5553.78 5453.78 11 2 N 50.80 W 1.27 268.51 N 1842.04 W 1858.8~ : ::': ':::: :': ::::::::::::::::::::::~'%6,-, ~' t). 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UMF ANY F'AGE._, ANCHORAGE ALA:=;KA ,..~ ." · : · ARCO ALA._kA, I NC DA'FE :KLIPARLll<:~ ~:]:~:i~ :' ~.:i~ ~]~:iAPRIL: 12ii)1982 '/~ ]:' INTERPOLATED VALUES FOR EVEN lc)0 FEET OF ._~LB-.=,EA DEPTH 500 500.00 400·00 2.80 S 3·72 E 0.04 0.03 600 600.00 500.00 5·21 S 6.63 E 0.11 0.07 .... :-: :: 700-,~-700700:-:--,,600-~-00 '..~r4-:$-"-'.'----,--,-¢~ ,~7"'~6-E- ................. :'::Cr;.'2~'-' 0'.--/~4- ': ::: ::::' ::::::.:::::: ( 0 :": :::: ~ -( ~': :: ::: ::::: ' :: ::::-:::::'::::::::::'::: ' ..... ~ ::: :: ;:::::::::: ::':::::' ::::::::::::::";" : ::: :": :: 'o :' ::: : : ::::::::::::::::::::::::: 8)~ ==============0 ====00 :::::::::::::::::::::::::::: 00. :I4, O6 :'~ ::' ::::::::::: ::14:~ O:; E : : O. 4; · 0:, 24 .:. :' :::::: .:::::::::: .:: ~ .:: .: :::::. :?:: :: _(~. · :... · ::::::: .::: :: .: ~: :::: · ::::::.:::'::::: :::: :: . .: ¢-~: .::.: :: .~.i-: ~*'~ ::: :: ::::: :~:::.: ,~ - : : : ~ ~i :. : :::::::::::::::::::::::: :~00: ::.:: .:::::.. :0~ 00:: :': :: 800, O0 :::.:'::..::: :.::.::: ~0:~:7o: : :::::::::::: :l,:,~Ty E O, 7.~ :::: O~ 30 ' :::::::::::::::::::::::::::::::::::::i Ol~' ~:~'i ::::' :':~::"::' '~:i :(:* '"J~-:-.. 00::'~ ':: ::::: ':~?~:)07,00 '"'' . i ': ::: ::::: ::' :: :":: ~','~;::~'-+. ~:.~:::::::::::::::::::::o: ~*'~- '-~,'-~... ¢.r:- I~ .... 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O0 110. 04 S 63.41 E 7 · 5:-? 1808 1800.00 1700.00 120.70 S 60.82 E 8.21 SPERRY-SUN WEI'L SURVEYING COMPANY PAGE -6 ANCHORAGE ALASKA ARCO ALASKA, INC. ~ DATE OF SURVEY dANUARY 23, 1982 :.. ~ - :'.. : : · :; -:.: ':'~.:::: :::.::'~: :~ ": :, · :... ::~ ::::: :::::::::::::::::::::::: -:::~ : ~. :~L~,_K~ :: ':': ':..,: '.-'.:::.:::.: : -::' .:_..:.....~_:::..=:. ........ .::_ :::::.: .=.. :: :: : ..... :._:'.:::.:=:::~:~_:~_: ~:-; :: ::.: ::: ..:...::: : : : .:. ::::~::.:::::::::::::::::::: : INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH --}DEPT. H:.::Z:~:"~:': :::..:LDE. PTH:=~Z::L.::::--DEPT+J..~oRTH:?SOI=tTH2~~)WES;T_~{ri:F-P~ENE:E-! .. c:ORRECT.ION::'.:.,, '..: ':, L':,.!'::':!~:::,-, ' :' : ' .' 1 '.-.?08' 1 '.-]00. O0 1800. 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': ' :::': ::.::-:: ::.~:tf, ~- '- , ': :::.: .::: :::: :::: .._~ ': .:~. ::::::::':.::::. "::"::~.:::::: :' ,- · .'~: . ,-,.~ . :: . :. ,.~ 6 .-', ':Z .. :: :: :'. ::.::.::: ,=,400, 00'.: . ::::.:..:..~,:~.~0. 00 :::::::::::.:::-::: :,: ..... :.:..~1.--~6::,.,. .... ::::::::::::::::::::::4: W : ::.::::: ,',=,:.~.46 . : :.:~o,44 :..:..:. ...:.:.:.::.:::.:.. · : ': "'" '::'~.., ..... 7'6,4 ::::..:::~::i:,=,._,~O(:~ .--0{:~' '~ ::':":::':::':":"~:._,400.~ '"- "":¢:)0~'-'' ' :' '::::::~:::"~'~~"'~'... ,~'-!~:~:._, ~~1-4-~-~::: :::"" ~: :' :::" :::: ' :::: ':::~'~;--2'8_,4' · ' ~"=: :". ,.,~ ': -:~'-- :' ~ ~ ':: ~.,.,'"'~. C~"k'~-'::' .... :"::: :'::':" :' .......... :" :: ":' :- :~' :: '" :388~ :3600. O0 3500. O0 2. '..=~4 N 8'~8.01 W 28'~. 76 24. '~4 4013 3700. O0 3600. O0 15.65 N :~70.41 W 313.87 24.11 SPERRY-SUN WELL SURVEYING COMPANY PAGE 7 ANCHORAGE ALASKA ARCO ALASKA, INC.. DATE OF SURVEY .JANLARY; ' ?'3,'- 1¢''-'~',-,_-,.~ IA ~ .. ~3Eb~ .~I~R~ · ... ::~.,.:-:..:. .... .: -....'. 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L' .j · KUPARUK::..:::~ ~:~A A~<~ :"::: ::::::::::::::::::::::::::::::::::::: === === ===================================== ===== :~' :::: " :':::::':::"' ~: :::::'::~:"::'"::::: :~'::'::': '' .................. -:::~::::::: .::::~;..~::::~::::~::::-.-::~:AF RI" ": ........... ~...:~:~::1~ ~. ............ ,.:,:::.~1:~F:8~....:.::==================================--..:.- .':': :: :... :..::::.::: :..:. -:.c:::::: ;: ::~ i :. :.~:; '::"' :":':~ ::: :::" ::::::::::::::::::::::::::::: ::::.dOB:.:.~, .~ NUMBER: ' I :s :.: Boo~,.-p ~ ~,.Fz&2...: ::.~::.:.::.::~:~;:~.:: .: :...... :.:... ~ ........ .~:......,.: .... :, .-, .... · L ,: ~, A ? :. ::: ::::::~:.: ~. ::: ;:~: ~:~:~::. ~:::::: :.<.:.. ~:~ ~:~:::-:~ ::~: ::::::; ::-:::.?: ....::~:: :: :;:: ...:: ::::..:: ::: ::. ::: ::::..:::: ::.: ~ .:.::.:.:. --: :: :-:::-.::-:~:::::-:::::-::.-.:::::-~:--.' ..-.' : ..... : '::: .:-c'::::: :... :: :.::--:: .': ..."-::-.':: .: .."-:: '~ :.'::::: :: .: :':-:.,::-:'-..: ~. E L L Y B, ~ H I N ~. EL E V, -=:: i 00 ,. ~ 0 '- FT..: :' .::,: ;. -:: ~--. . ...:... ........ :..: :....: .:.:...:. ::: :..::. O-PER.~~~M · . INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ' · : ' '~.,~ ' :'::'" ':";,.' .':i".: :: ':':...i ..;.:..:::i':..i:llllig,~' · .:.:.l.:....l';...'..:' .: :-".. '"' :.:.:l::::..:.. ': : .. .:.:. :..~:>~::..l:~ : : .. :..; .. ' '''"::' :i:,:' l. Z'l'l::'F'i':' ':?'i::C:E'iL.2~:;Z"il~'~;:i';';'::'Z ...... . .DE~ LII~I:.I L--"IL~TFI NI'~II~~.~ITF~ bR."---'; ! / 4137 3.'_.--.'00. O0 3700. O0 2,'3.92 N '1042. '15 14 337.68 2:3.7'.-"1 . .... :. 4.,..,'~0....,.. C~'(~:t.'~t~.:'=,,~,t~t~,.~ .... .. 4-.~~~...:: :~/1:.::'1.~, ..... ',d,l,,1 . . .., ,"_-,';O .--Zl:3 .. - . .. ...'2,:777 .... ..... .. . . ......... : :-. ~;-. ; .~.... : · ! ................. ~ .... ~.'' ...................... .... ...:: .:. · . ......... ;>. ~.:::...: :- ...... .................. .,-_,~ 'r. ~ :.:..' · ? .':::-:::: :::-.::::-.::' ::::::::::::::::::::::: ,~":.. ;": .... ';::. 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'..:.: ...:.::.::. :: · .~ 11',. {~.E:.~..:.....::'...:.::::.:.:: :"..:... :'::~;::~:~:::~::..:.:::.:::...: .:.::::::.. :: ~:.:.: ':'-, :.:-: "'::':. :.;:i:-.!i;!::'ii~i:i!;-.i!:' :'":~i. :~::;;~"~::i{';:::;;i'i;!:!i'i;i;::'~i'i~'!> :'::'~,~-" .~ ~t ~'~ ~ ' .>:::i::;:iii:~::.:>:.::i~i}::::..F!!;;!;.!;:.!~:;`::F~:~.::i~r~~~}.:.:```~.::.~. :: ';::;::'~ ';~.~::i:~.j !: '":::!'::::'-:!:-"i:::::;'i :;i:: :::::!!::<::: ;i.:::- 8:"::~'~:::i".~~~' :~:: --:: :;.:-:.:. ::::F :' ':'::::" ~:::::;:::'-:::::::: :.:-:-:'::':::': ::--"::':"~;~'~::::~:~:.::'~ ',-''. ":'.':-.:~'F:'.::-:': .F-:"'; !~::~.~ ~." ': &~~',:.L:;,..;:::..':'_~:~ .-~ ::'~ ~~~:~" .: "~. ..... :::.:': '::,': .": ......... :'":-:':~?P;":2~: ....:.:: ;~.~'..::..:.>2 ' · ' ' ': · ' 4740 4300.00 4200.00 104.81 N 136~?.88 W 440.51 17. 4856 4400.00 4300.00 11 ~. 82 N 1427.36 W 456.82 16.32 .:.:.. :..:....::~:.~¢.o,_. ~, .: ~....: ..:.. <.. 4 ~ 0 (~ :, O0 :..:.-:::..:: ~::..~ 45 o 0.,. 0 0:. :.:-: :: .~:: .-: ::::..~::.::..::..~ 4 ,. :., :~:o:.:::: N ...::~::: :~::: :~:';: I .~,.~,:~.: ~::~=. %:::.: W -:. ~-~:.:: .:'.~ -: ::..:.~..::.4 o ~,...:.., 7. :..... :.....:.: .. :. · · . .:. 13 ..: 74::: ::.....::... :.: .: ....:.....; .. :.:?::.::.:::~...~: . ..... : '- :':.;::~-';:::::~::::~:.~;:~. ' ' '~ ".....' 'L .';':.:'" :' ..... ::: ........... :2';:: :~.::: .... .'. ;':~ :::~'- ~ :'~ ~' :.:'.;]..:~:: ":~:~::::'.:. '/~h ;': .:'::~:'..': :;:.-: ;..~::;:h:7;<;:.. :-{~::: ;~;~"~::~..;:~;~.;;. - "... ;: ::.:.;..:: ? 3.':' ' ~t "' ~"<" ' .'" ' :':" ': ~' '"~ '" ,'.':..: ' ' ::C':;:;::'""'.:. '.. .::.::' ::::::::::51 .... 7.::..:. ~700.~ O0 .:..:.::-:.:: :-4~;00, :~.~e :.:.: ..:::::......~:~:~:~:.:::::..:.t.63,::.10..'.'..N.:.:::.~.::.:::.~::~'.'.- 1...,.~=,~-.~:.'..,o-: W :.. ..... ..'~ :-::: :4.. 7.87.. :. -::: . . · . 1 ~, ¢0.: ..:. ' ";' :: ',: ".:: :': ' :::% ':'~ .~:~i~":--,_, ':'-' '"':: '"~4,_,t.l~i(t' ::'::':":' ¢ :::"::' :' -:'"'"'"4~; ~' :'- ~LO(~.¢ '~ "'::":' :":'::' ...... ..... .: ..::.~=.::~)~:.....--. -.: n~::...:- - :.~,~.. ~~ .... 54 ~ 8 4¢/00. O0 4800. O0 ~ 'F~O. 34 N t ~72. ~ 4 ~ 5 ~ 8.34 '~. 52 5526 5000. O0 4¢00. O0 202.50 N ~ 7 t O. t 2 ~ 526.02 7.68 ...::...::.:.: 563-I--%~(~] :_:.:. :-':- '. ~:~r ;0(~ ~::'-:: ....:2-13; ~6*:b %.~'7~--7:'W 5::d-;. :~- 5: ~ 2' :::.:.. :-. 573~ :.;':-.5200:; :::::::::::::::::::::::::::::: 00:, O0 ... ':..:..:.:-:::....: .-.225~ .13 ..N. ::::::::::::::::::::::: 7:Y(~:.?~7 . -..:.:::::: ~j,~,' : :....:....~ :.:.:: · : ::..::::: :::::.: ': ~ ~..: . , '.........:.::'.:: ..... ; ~ . . ~ ~... - :...::-.: '.': . - ~...:::.:::,~ .: - . .:-.. ':c::.:....5,~,~?-.': :~.. :..:.. :5.~O0~:O0.:::::.:::..:::..::.::.:c,~O0.,O(J.: .::...:.-::::: ..:::::::-:... ........ ~7.:~ L~: N-.:.:::::::.'.. .... ..:.1Y.,..~..~.-.::.. ~, ~:-...: . o.=,~ ,:... 0 - "~, ~,..~ -:':'.c::':.:: '~,~"~._ ~(J' '~ J~:-~~~O(~': ::':~::: ~ ......... ": ::: ........ :': F"~ L'~:(~(:j- :-~..:::::-.::::~:: ::'~' ':,~:~ ~:: :':" .' :":-'::'. ":~ ~:':.. f:':' ....::'.:: j= ==== ======= = == = =============~~ ~045 5500. O0 5400. O0 2~,1.87 N 1833.75 N 545. i 8 2.32 614Y 5&O0. O0 5500. O0 27~. 1:~ N 18~8. '~4 SPERRY-SUN WELL "--'~ ' ~:I_IRVEY I NL~ COMPANY F'AL~E ANC:HORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY dANUARY 23,::°°c'~.~.-.-- 1.. ~ · · ~: ·, · C~Z~MI=~t-T~-I~ON~DA-TE-,- ~: ~. : ..,1 :-iKLiPARIJK. ~. :~ ~ :::l! ·l: ::~:' ?i~il ~ i:~i?:~l~!~: ::ii, i i?!~!: · l~ ii~ ~i~ i 'iiii:liii!i APRIIL i :.ii:2~i~.ii~i:.i!:-i~'-P,2~ ~ ii ~ · l:i~::I: :~:dOB~ NUMBERI BOSS~116.~62 i.ii i' ~l~'il~: l"iiI i:: '" .-.':: i~ ' ' ,-- ..~: : : .: !': ~ '.:: i. i".!: .!i .~:~ ~i -. ~:i-> .-:i::i: ~i'i::~i~! i'i~i! ~!{: ~!:i:ii!!:iii' ::: i:':'~': "i: i:i: :~:::'ii'/:.':.'i:: i'ii ::: ~ :: . ~./:. :~ :-::~:.:. '!':i ;~.~'.'ALAoKA .-. ~ ;~:; :~ -.':' :':: ::':;~ ~; .:: ::~..:-.;;:: ~ ===================================== ;~. ~:~:.~:. :~::~::::~:~:: '~ :- ::.. ~:-; ~:: ::;'. ~ ::;;: KELLY'.BU;:,HiNL~ ELEV,' ~.::100.~ O0' FT... '. · INTERPOLATED VALUEIq FOR EVEN 100 FEET OF ~,LB-oEA DEPTH '-' ~" P]~':' 55 6~4E, 5700 O0 ~A(~O O0 "':~= '~' .... ~._,.'~7 N 1,:,61 46 W 1 47 . : ~" ~71'''~ " }~:':.: ~,~, "::' :.: :':: ~ ;-,5 ¢i":- :.::': · '~':';:,~:':~ .~, ': : : :~- ~' :" :.: . .' :;~- :~ ':: .':::::":: .:'~:::~'::'.~ .~..' ' ': ':. : "~:~: . 64..,LI :. '. 5.. OU. O0 :: ':' :.::-5~CILI, L)O '~::~:-:::". : L~O~:.,:;'.~ N ::':::: J 8~;~i.6c~ : :. :: ...~ · .. ~ - - : ~::' .cz .... : , ,:: ~::~:::::: :. :'..:,. :.~. :~¢~ -'- ::: ::: : :¢,~;:":-. :: :. ~52~:.::::::::::~i. oo~<~o:~2~oeo~::oe-" :" .~.~,-a~:~i:~N~~~.C~e:~:::::::: ::552:~.8::.:: ::?::::'.::':~:...::' ~:O:~7,S:: ~'' ':.: :: .... :::::::::::::::::::::::::::::::::::::'.:. ':.:" .~' '.:. ':' '-' =;='-' 'P:~ O. 76 6752 /-,2[]0 O0 6100.00 341 07 N logo 19 W _ o~ ._. /-,:2c~r~ O0 A2AA. O0 :351 c,,=, ,~,,~ N 1903.36 ~ 0 71 ........... ~.z,. 7 ~ . -: 6954: ::'~-6400,:00-:":'":6300~'00 ..... :':.-':":~-:362~49":'N' '.--'1~08'~2~?'"N ..... . .::. :70._,5 :'C)O ~:~:~:::~:~.)~:.-~..: :..~-,5. ~ .... .. :. 0.~:84 :::~..: ~::::.::.:.::~:~:::: ..: .: ·: ..... 7144 ... 6~,,~,_,. 0.~. 64~,~,.C} ..... . ....· .~-,=,5.:~1 N ....... ~.t:~:..:.=,1. ~: ::: :: .... ,~.:,./7 ~ · .:..0.74 - ... ..... .. .... · :. . THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FRAM RADIUS OF CURVATURE) POINTS -. SPERRY-SUN WELL SURVEYING COMPANY F'A~3E 9 ANCHORAGE ALASKA ARCO__ __ALASKA' INC. -- DATE OF :-~LIRVEY' dANUARY 23, 1'~82 -~,.~, .. ,: : ' ':'" :.' "::',': :', : ':; :': '. · ':: ':'::: ' . ,' ":' / · L/" ~-:-':[~.':W[ :'::[:- :-[: Z,:.%.[ ." :[.: ..::/:::., [[~[~[ '::':' ')'i [~:..M[2)-..[~[::~:~.'.-~'' ' ' ' :: INTERPOLATED VALUES FOR ..FEL. IAL SURVEY POINTS ::: :::::::::: ::::::::: ~. R~ Di~:/.~;/::::.~>/:i:.:~;:~i~i::~E~ y~:;~.~-~:.:::~c~:::~::.~:.;::::~E~:y I;~' _ ~, r~ 6040.2~ .... ~l olo. 71 N 1888.83 W TOP OF KUPARUK ::'. ................. :-'::' ................. '::':::::' .-. ~ :'~..~::::~:.':-: ............. ~ ...... t~" .....~ ............. '::':' .~.:':'.' ::::':: ........ ::::::::::::::::::::::::::::::::: ................... '~ :' ::::~:::~ ~:.-':': ' :::'::::'.":'. ..... ' ': ~: -:' ...... '",-:~: ..... ::::::::::::::::::::: ...... ........... ::::::::':::'-:::. ....... .:: ::..':',:::'...." .::..~:' :':: .............. ',.:.'":'.::'.. ,..::..:'::'~':..:'". ....... ':':',.::: :.,:.: ,.: ......... : .............. ',:.:'.:.'::/: :' ::',:':. ...... ": ":... .... ·" ':.:':"-':.::::' .:': "~ ~":."~::~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '~::~"':' '::' ::":-::::: :~'" :' '~.": :'"'."- :: =========================================================== ':': ============================================================== '::':~.:?:~. ~--/ ~ '~ .... ~t' -- --' m .... MARKER---2--- MEA.:,_RED'-'II, DEPTH --TVD ........ THICKNESS WITH REF, TO WELLHEAD BKB BKB SUB-SEA VERT I CAL ( OR I O I N- 104 .gFSL 4'~2FWL ) · .~ . -:: TUi:: OF-..:: KUI: ARUK: :.: :.... :::/:..,.. ~. ::::.:~.: :: :' :::::.: .: ':~:::::: ======================== &04£) ~:~-'.:~:~:::~::~:~:~ ~, :.Y4£), .~.. :~ ~:: :. :..: ::.'.:: :.::::: '::.::. ::.: · ~'. :": ."..:~:Z~,: 7.1N ~:~.:: :::::~:~: 18~-~8, ,.~.:,W :.'...~ .ql ' - = ':":' 3~7, .92N 1 '~ 1 O, 4&W ~ JRVEY DEPTH 7000 Z: 44~,. ~:::4.=, ':":' · ' ...i _ _ # ~ PBTD ,.,..._-~n'-'.~, &470. A2 /=,370. A2 370. '-22N ! .~ 11. :,._,~ 1 ) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. .. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. '---D A TA-= C AL:C EII:A-T-I-t-'~N,A N ~N~E~R ~nerT-IOIxP=B~RA[.I U $~3 p,C~U Rk/A~t:IR E--~ · =:-:~ : . ~ " .: :..~. : . ' COHPUT~T~ON D~TE APR I L 12, lt~82 ,JOB NUMBER BOSS- 16t~,2 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16962 Well: lA-13 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: January 23, 1982 Operator: Marvin. Milam Scale: 1" = 500' TRUE NORTH 7144 -2o~o. oo -,sbo. oo -,oho oo-~'---'----~~~ --500.00 Surface Location (1049FSL 492MNL) HORIZONTAL PROJECT I ON ARCO Alaska, Inc. Our Boss Gyrosoopic Survey Job No. Boss-16962 Well: lA-13 (SEE5 TllN R10E) Kuparuk Field North Slope, Alaska Survey D~te: January 23, 1982 Operator: Marvin Milam Scale: 1" = 1500' 0.00 1500.00 3000.00 4500.00 6000.00 7500.00 1955.62' N78° 38'W 7144 15~0.00 30bO. O0 VER T I CI:::IL PROJE C T I ON Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, ~ell Nam~ knd Number Reports and Materials to be received by: ~--~. Date Required Date Received Remarks Completion Report . . Yes Well History Yes Samples K : . ,.¢/,d PI Registered Survey Plat .' ~ C, _f~ ,,, , ... . , - ..... Inclination Su~ey Drill St~ Tes~ Re~s ,¢0 ' Pr~u~ion Test Re, rte , t .... Dig~iz~ rata ALASKA OIL AND GAS CONSERVATION COMMISSION Commissioner January 12, 1982 Bobby Foster'~~ Petroleum Inspector ~itness BOPE Test on ARCO ' s 1A-4~ J ~ Sec. 5, TllN, R10W, UM Permit #81-195 S_unday, Ja~nuary!0,_~19_8_2 - i traveled to ARCO's 1Al6 after being contacted by Ken Jones, ARCO drilling foreman, concerning the upcoming BOPE test. The test began at 2:00 p.m. and was concluded at 3:30 p.m. As the attached BOPE inspection report shows there were no failures. In summary I witnessed the BOPE test on ARCO's lA-16. O&G 418o STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report . ! . I ns pec to r~~~, oPerator . ~/~J~ ' . Well .... / ~' !.. /,-~ ' Date' Location: Sec ~ T/:~JR/~7~)M / ~ /h~/~"as'ing s t @,...~. ~ ] ~f~. Drilling ContraCtor .~~)~J Rig Representa.t iv ~~' ACCUMU~TOR SYSTEM Location, General ,,ell Sign.. '.~v'~,~:~'- General Housek6 eping, ti~?,''~'''' .. Reserve pit Rig. BOPE Stack Well/'-~" /._~ ? . Re pr e se n t a rive Permit # Annular Preventer !:'" PiPe ' iRams. Blind Rams Choke Line Valves H.C.R. Valve 'Kill Line va'ives TeSt'Pressure Check Valve .... Full Charge Pressure r~:~ ps ig Pressure After Closure /'~'>/~ psig · .200 psig Above Precharge Attained: --- m±n~SeC Full Charge Pressure Attained: ~ mina'}sec Controls: Master' ~[%, ,,..,~ Remote Kelly 'and Floor Safety Valv, es Upper KellY'.: /' 'Tes., ,t Pres, sure Lower KelI~ / Test PressUre / Test Pressure Bal 1 Type. ..... Ins ide BOP / Test Pres sure /~' . Choke ManifOld ~~Test Pr'ensure -~ No. ValVes No. flanges Adj useable ChOkes. / ' Hydrauical'ly operated choke. Repair or-Replacement :of failed' equipment'to be made wi thinl, days and InsPector/COmm'ission office notified. Remarks: Pi s tr ibUt ion orig.~ - AO&GCC cc - Operator cc - Supervisor Inspector December 31, 1951 Me. D. 'S. Smiley Senior Drilling Engineer ARCO Alaska, Inc. P. O, Box 380 Anchorage, Alaska 99510 Re ~ I/up a ruk R ire r Fi · 1 d 1 A- 13 ARCO Alaska, Inc. Pemit No. 81-195 Sur. Loc.~ 1049*FSL, 492~FWL, Sec 5, TllI~, Itl0E, Bottomhole ~c.: I320~FSL, 1229~FEL, Sec 6, TiI~;, Ut/. Dear ~/r. ~iley: Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud log are not required. A continuous directional survey is requil'ed as per 20 AAC 25.050(b)(5). If available, a tape eontaintn/~ the digitized Icg information shall be submitted on all logs for copying except experimental IO~s, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anad~omous fish. Operations in these areas are subject to AS 16.50.870 and the re~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to comraencin~ operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control Act, as amended. Prior to ~ir. D. S. Smiley l~uparuk River l~ield 1A-13 -2- December 31, 1981 commencing operations you ~ay be contacted by a representative of the Department of ]~nviron~ental C~nservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is sl~udded. We ~ould also like to be notified so that a repre- sentative of the Co~ission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we way have a wi tness present. Ve~ truly yours, Il. Hamilton Ch&i~,m~n of BY ORDER OE _THE CO~IUl$$1ON Alaska Oil & Gas Conservation ~ission EdaO 10 sure ec~ Depart~nt of l~tsh & Game, Iiabitat Section w/o enel. ~partment of Envi~onn~ntal Conservation w/o/encl. HHH~be ARCO Alaska, Inc. Post Office B% 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 28, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk 1A-13 Dear Sir' Enclosed please find the following' 1. The application for Permit to Drill Kuparuk lA-13 and a $100.00 check for the application fee. 2. A diagram showing the proposed horizontal and vertical projections of ~the wellbore. 3. An as-built drawing of "A" pad indicating the proposed surface location. 4. A proximity map indicating the relative locations of Kuparuk wells lA-3, lA,4, lA-5, and lA-11. 5. A determination'of maximum pressure to which BOP equip- ment could be subjected. 6. A diagram~and description of the surface hole diverter system. 7. A diagram and description of the BOP equipment. In addition, please note that this well's bottom hole location will not require .letters of Non-Objection from BP Alaska Exploration Inc. and SOhio Alaska Petroleum Company. If yOu should have any questions, please do not hesitate to contact'~me at '263,4272. Sincerely' yours, D. S. Smiley Sr. Drilling Engineer DSS: TJB- 1 tc Enclosures ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany · ~, STATE OF ALASKA C~i. ALASKA -AND GAS CONSERVATION C ,vllSSION 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 J~E~VEBt. unit~ 4. Location of well at surface or lease name Kuparuk River Field 1049'FSL, 492'FWL, Sec. 5, TllN, RIOE, UM ~)EC2919,~ lO. We, number " At top of proposed producing interval ~ r lA-13 1320'FSL, 1229'FEL, Sec. 6, TllN, RIOE, UM ~askaojl&GasCons. Co~s~~ pool ' At total depth ~Chorage '] ' d and 1320'FSL, 1229'FEL, Sec. 6, TllN, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk Ri ver 0il P001 61'GL, 66'PD, 100'RKBIADL 25647 ALK 465 12. Bond information (see ~0 AAC 25.025) Type Statewide Surety and/or number Fed ]:ns. Co. #8088-26-27 Amount $500,000 1:~. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance t° nearest drilling or completed 30 Miles NW Deadhorse miles at TD 3671 feet 1A-4we"is 94'@ 1614'TVD feet . 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7354 'MD/6895' TVD feet 2469 1/7/82 19. If deviated (see 20 AAC 25.050) ]20. Anticipated pressures 2~[.}U psig@ bUOF Surface ' KICK OFF POINT 1 650 feet. MAXIMUM HOLE ANGLE39' 0~(see 20 AAC 25.035 (c) (2) 31 03 psig@ 5990 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER 1 SETTING DEPTH QUANTITY OF CEMENT ,. '1 Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 16" 65# 'H-40 Welded 80' Pad I 'Pad 114'~ 114' +_200 DF . 13~ ]0-3/4" 45,5# K-55 BTC 2727' Pad ~, Pad 2762'~2700' 1063sx FOndu + 250sx , . 8-3/4 7" 26# K-55 BTC 7319' Pad ~ Pad 7354'1 6895' 1539sx Class "G" ~ I I I 22. Describe proposed program: ARCO Alaska, Inc. proposes .to drill a Kuparuk R~ver Field, Kuparuk River Oil Pool devel- opment w~ll to approximately 7354'MD, 6895'TVD. Selected intervals will be cored and 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.BOP 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. Expected maximum surface pressure will be 2600 psig based on cooling of a bubble rising at constant volume. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left in uncemented annuli thru the permafrost interval ' Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ' .... SIGNED TITLE Sr. Drilline Eneineer DATE 12/28/81 The space below for C ~ " ' CONDITIONS OF APPROVAL - Samples required Mud log required I Directional Survey required APl number []]YES ~qO []]YES ~NO ,~YES i--INO 50-- O Z Permit number Approval date ~;r,_ /,~'~ _ 1~/3~/8~ , SEE COVER LETTER FOR OTHER REQUIREMENTS ,,, APPROVED BY ,COMMISSIONER DATE Deeaz~be~ 31. ].98! _, by order of the Commission Form 10~401 Submit in triplicate Rev. 7-1-80 'f · el, 05 I 'NC&~'4' AS Bbl t.' KUPARUK PROJECT [')RILL SITE "A'" ~,,L ATLANTIC RICHFIELD COMPANY .,~ NDRTH AMERICAN PRODUCING DIVISION q~l~ GENERAL ENGINEERING GROU DALLAS [ TEXAS "' BOMHOFF & ASSOCIATES , INC. "~'~"1''~' I r .~...,,.,,., ' ~' I~,"1~'' ~ ~ISK;~.G-I I~,,-, ~, ' ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3103 psig from RFT & pressure buildup date. This pressure @ 5890' SS : 5990'TVD will be balanced by 9.96 ppg mud wt. Normal drilling practice calls for 10.5 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 168'i psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2600 psig during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°F, 3103 psi), gas migration to the surface w/o expansion, and cooling to 60OF cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) Pi Vi' = PfVf Ti Tf Since Vi = Vf ie no expansion Ti Tf Then Pf = PiTf = (3118 psi.a)(6OOF + 460) Ti ' (160OF + 460") Pf = 2615 psia = 2600 psig '% Surface Div~K~-:r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapt:-r. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pi t. valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. DEC2 9 16" Conductor Maintenance & Operation ~- 1. Upon initial installation close annular I preventer and verify that ball valves ,I have opened properly. , . [ 2. Close annular preventer and blow air ~_ through diverter lines every 12 hours. 3. Close annularlpreventer 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___y_v circumstances. l) -. IRNNUL~R PR~VENTOR 9 . ) BLIND . P ! ?-Z R.".M ) £ 51 TOG HD C'SG fiI e l. 16" Bradenhead 2. 16" 2000 PSI x lO" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 13-5/$" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular ACCL?:ULATC~,~ CAP:Ct, TV TEST CHECK A~;D FILL ACCU:4ULATOR RE.:E?.VOIR TO PROPER LEVEL WIT:-( HY0?.AULIC FLUID. ASSURE THAT ACCL::ULATCR PRESSURE IS 2000 PSI WITH 1SO0 PSI COW;;STSE.:J.I OF THE REGULATOR. OBSERVE Ti:.IE THE,'.I CLOSE ALL UflITS SiMULTA:;E- OUSLY A~;D RECORD THE TIME AND PRESSU,~E RET-lAIN- PiG AFTE2 ALL LJ;iITS ARE CLOSED WITH CHARGi;;G PUMP OFF. RECORD Oil IADC 2EPORT. THE ACCEPTASLE LOt;ER LU.IIT iS 45 c ...... - -:'- .... S CLOSI::G ih,. A~;D 12C0 PSI REJ.IA~ N I,,~ PRESSGSE. 13-5/8" lOP STACK TEST _ . l. FILL BOP STACK A::O MA;IIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD OO',;N SCREWS ARE FULLY TRACTE~. PRECETE.:j. II,'~E DEPTH THAT TEST PLUG WILL SEAT A~;D SEAT I~! WELL:-:EAD. RU~( I~ LOC~ DOW;; SCF, EWS l~t ~EAD. 3. CLOSE X~;:;ULA2 P~EVENTER AND C:qGKES A~;D BYP~S VALVES O~( MA~IFCLD. 4, TEST ALL CCMPG:~E:;TS TO 2~0 PSI AND HOLD FOR lO MIl;UTES. ~. INCREASE PRESSURE TO 1800 PSI AND HOLD FO~ lO MD~UTES. BLEED TO ZERO PSI. 6. OPEN A~;~:ULAR PREVE~ITE2 AND CLOSE TOP SET RIPE 7. .INCEEASE PRESS~EE TO 3000'PSI AND HOLD FOR lo MI I;UTES. 8. CLOSE VALVES DIRECTLY UPSTEE~.I OF CHOKES. BLEE~ :C~;STEEA:.I PRESSURE TO ZERO PSI TO TEST VALVES. TEST~.IAI,h,G ....... UNTESTED MANIFOLD VALVES, I~ ANY, '~ITH 3000 PSI UPSTEE~'.I OF VALVE A~(D ZE~O PSI DO~;STEE~. BLEED SYST~ TO ZERO PSI. -. 9. 0PE~ TOP SET 0F PIPE ~4S A~;D CLOSE S~T OF PIPE lO. D(CREASE PRESSURE TO 3000 PSI AND HOLD FOR MI~UTES. BLEE~ TO ZEEO PSI. Il. OPE~ BOTTC:.I SET OF PIPE RA~IS. BACK OFF N[NG JOI;~T A~D PULL OUT OF HOLE. CLOSE ~.IS A~ID TEST TO 3000 PSI FO~ 10 IID;UT~S. BLEED TO ZERO PSI. 12. CPE:I BLI::D R~'.IS A~lO RECOVER TEST Pl~. SURE NANIFOLD AND LI~ES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET [N ORILLI~;G POS [ T I 13. TEST STANDPIPE VALVES T0 3QCO PSI. 14. TEST KELLY COCXS A~(D INSIDE BOP TO 30~0 PSI WITH KGC;:EY P~NP. - 1~. RECKED TEST I:;FO~.~TIO~( 0~ BtO:OUT P~EVE~ZTER Gas Co~s. Comm~ssb~,~ v~sc~. YblOhOrS',8.. ~ 16. PERFC?Jl C~PtIl! ~OPE TEST 0:;CE A ~EE~ A:;O FU;;CTIC;;ALLY OPERATE ~6PE ~AILY. ~I LAT = 7~)°19' 58. 741'~ LONG =_ 149°40'26.679'' ~ ...... ~ ~~' ~I ~ ~ X = 540,178.32 Z ~1 ~ ~ LAT : 70°19'57.557'' > ~ ~ 'f~3 ~ LONG = 149°40'26.693'' ~ - ; WELL A3 Y : 5 971 227 31 /- ~ ~ LAT : 70o19'56. 381" 313~ ~ LONG : 149°40'26.707'' > ~~Z~~ ~ WELL A~' Y : 5,971,gO6.83 ~. I ~ ~ X : 540,178,52 : ~1~' -~1 _ ~'~/ LAT : 70°19'55.196" - ". ~ ~ '1' ~ ' LONG = 149o40'26.725'' SII'-' ' ' AS' .... . ....... ~ - -b I ~ LAT : 7OO19'54.016'' '~ ~i~O~,~ , LONG = 149~40 26. 741 -'-- ....... ~~~ -I' ~ X = 540,178.71 ~ ~)F~Ato '~ 'LONG : 1~9°~0'26.757" ..... ~ ............ ~~' t'-- ~ , WELL A7 Y = 5,970,746 73 · . ~ ~ ~ = 54o ~78.55 ~.. _~ LAT = 70o~9' <, ~,~ · ~ WELL A8 Y :' 5,970,626.78 ~ x = 54o,]78 59 : : i LAT = 70°]9' 50. 475" ~ > ~. ~ ~ LOnG = 149040'26.798, " ~ ~ n z ~ .... ~ ..-,, I HEREBY CERTIFY THAT I AM · ..~,'~ PROPERLY REGISTERED AND LICENSED ,2 ..;:,' T0 PRACTICE LAND SURVEYING IN ~ . :'" .... ' THE STATE 0F ALASKA AND THAT .// / / / ~: ....... ~ ............. THIS PLAT REPRESENTS AN AS- ¢?g-¢~/~~~;-' BUILT SURVEY MADE BY ME AND ~ ,/. ~. , ..... :,;.'~, . ,- THAT ALL DIMENSIONS AND OT.HE~ ' .' ' .', . .,. -~ .' .'.,; 'DETAILS ARE CORRECT, ~S OF- i I I ii i iiii i I i i I i~i A'tlanticRichfieidCompany O DATE' DRAWING No: NORTH AMERICAN PRODUCING DIVISION IO.g-¢o ALASKA DISTRICT- KUPARUK ................ i ..... - ii iii i _ ii i CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ~o x (2 thru (3) Admin *~f~ (9 thru (4) Cas. g_ ~ [~/.~O/~t (12 thru 20) (5) BOPE (21 thru 24) Company Lease & Well No. YES NO 1. Is the permit fee attached ............................... 2. Is well to be located in a e ned p o .................. 3.. Is well located proper distance from property line ........ '' 4. Is well located proper distance from other wells ........ 5. Is sufficient'undedicated acreage available in this pool '' 6. Is well to be deviated and is well bore plat included ... 7. Is operator the only affected party ...~.' ................. 8. Can permit be approved before ten-day wait .............. 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. (6) Add: ~ 1~/~o}~11 25. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 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 ~oOO psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~ Additional Remarks: rev: 03/10/81 INITIAL i GEO. UNIT I'O'N/OFF POOL CLASS STATUSt AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ ,, No Special'effort has been made to chronologically organize this category of information. ** REEL HEADER ** SERVICE NAME :SERVIC DATE :821061 7 O~IGIN : REEL NAME :REEL ID CONTINUATION ~ PREVIOUS REEL : COMMENTS :REEL CO~ENTS ** TAPE HEADER SERVICE NAMF :SERVIC DATE :82/06/ 7 OPIGIN :FS1A TAPE NA~E CONTINUATION ~ :01 PREVIOUS TAPE ** FILE HEADER SERVICE NA~E VERSION 8 : DATE ~ Ma×I~I)~ LENGTH : 1024 FILE TYPE PREVIOUS FiLE ** INF~ATION RECORDS ** MNE~ CONTENTS ~m~m mm~m~m CN : ATLANTIC RICHFIELD COHPANY FN : PRUDHOE BAY RANG: RANGE TOWN: TOWNSHIP SECT: SECTION COUN: NORTH SLOPE STAT: ALASKA CTRY: U,S,A. MNEM CONTENTS PRES: DIbOO1E jOB # 10707 CONPANY NA~4~ WELL FIELD COUNTY 62514 DIL RUN #2, LOGGED BOTTO? LOG INTERVAL TOP LOG INTERVA6 CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY FLUID LOSS RM @ ~EA8. TENP, R~F 0 ~EA$, TEMP. Jg-J 7~.22 FT. 4000 FT, :' 10.75 ~ 75 IN. ~0,3 LB/G 41.0 ,S B 4~89604 70 em 64- 64;00 ~F. LVP 010.MOl. VERIFICATIO~~] LISTING RMC ~ .~EAS. TKf,'IP, = 3,340 R~ ~ BHT ~ 2,435 MATRIX SANDSTONE ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE 4 0 DATU~ SPEC!FICATIOM BLOCKS MNEM SERVICE SERVICE UNIT ID ORDER # DEPT SFLU DIL ILN DIL OHM~ ILD DIL SP DIL GR DIG GAPI NPHI FDN PU RHOB FI)N G/C3 GR FDN GAPI CALI FDN IN DRHO FDN G/C3 NRAT FDN NCNL FDN FCNL FDN DT BHC US/F GR BHC ~API API LOG 0 7 7 7 7 42 42 42 42 42 42 42 42 60 60 DATA DEPT !138 5000 MFLU SP -999:2500 GR GR 77,6250 CALI NCNL 24~0.0000 FCNL DEPT 7100,0000 SFLU SP -20 0313 GR GR 87:3750 CALI NCNL 2092,0000 FCNL -,999 7 ! e.: ~C,'66 D~' ' ....... ":99'~'~;'~5'~"~: O:R 99'9;'2'500 7. 54~. 000 LVP DEPT S? GR NCNL DEPT SP NCNL DEPT SP Gw NCNL DEPT SP NCNL D~PT SP G~ NCNL DEPT SP GR NCNL DEPT SP G~ NCNL DEPT SP GR NCNL DEPT SP NCNL DEPT SP NCNL DEPT SP NCNL 010.MO! VERIf'ICATION 7000,0000 SFLU i 24.0156 OR 01.3750 CALl 1 17,0000 FCNL 6900,0000 SFLU -25,4844 GR 76 6875 CALI 2526 ~ 0000 FCNL 6800.0000 SFLU -31.4688 GR 81.4375 CALl 2498.0000 FCNL 6700.0000 SFLU -R1.1250 GR 44 5313 CALI 2726[00u0 FCNL 6600.0000 SFLU -69,6250 OR 58.1562 CALI 2454.0000 FCNL 6500 0000 SFLU -29i3281 GR 93 9375 CALI 1506.0000 FCNL 6400.0000 SFLU -34 7813 GR 134~2500 CALI 1~88.0000 FCNL 6300,0000 SFLU -34.5625 GR 195 0000 CAbI 1800:0000 FCNL 6200,0000 SFLU ~26.8594 GR 35,0000 CALI 1993,0000 FCNL 6!30~'0000 SFLU .7813 GR 93,5000 CALI 2490. 0000 FCNL 6000,0000 SFLU -23,5469 GR 106.9375 CALl 1995,0000 FCNL LISTING 3.t25 --: NPHI ': .: ,'. -' ~ ~.. ~!4::2:::~ 5'8:.- ~8 :':.--~ ~:. 7422 DRHO O, 0645 NRAT 3. 5566 5060 DT.'": :~ :: ':: ':::: :~I::~'~:~ ~ :.,> .'~'. · >-.): :..~.~:79~1:'~ 5::Q: ':::.' ~:'J: : .~' 76.5000 ~qPH! .... : ~'~3'6; ~6'88 RHOB 2,414i 790:0000 D~ 96;3750 GR ' 7'6:5000 76 9375 NP:HI .:<'::- .,~ :... ,:'2 .... >~: ::~" :'..' 9:4844 D~H0 0.0220 NRAT 2.9082 781.0000 DT"- .:= - :::' C '~ y'.:'.:G~:-: ~ · :~; :::-:: :i 9J3~ .. <'~:: - : 11,3594 DRHO ': :':::.- s:~::i': >:: ~ !!~: !:? :" :i:~' ':5::' -- : 1- 356.2~00 ~t i'1'6;5'6'~5: ~ 96;5000 ' 1 ~ , 421 ~ bR'H~: ' ::"~-~':6"':0:'~'4"~ NR'A-T ' ...... 3:': 79'49 464. 0000 DT:' _~-.:.:V :.5:; :':::: ::~ :- . 3750' NPNi ...... 43 '~'5 7 0 .... R~'OB 2 10 · 94.53 DRH:O 443: ~50~ D'~ ....... f ~i~::: '~'~:2 ~ G~' 197 12.5 5'47 : BRH:0:'.~'.-:::' <':::: ii, q: ..:~;:.!i:-.>/!. :::! :'.-.:': :. 728. b 666 - b --:f'O~::':;7'~"O 0 .... "GR' 85'; i 875 t o. ~i ~ :" ~'~8 :~: ¢""~ "'"¢~'~"'0::6'0"i~-"'*:'c~AT 3-; 8633 462.2500 : DT ;.:~ ; :: ':::-: LVP DEPT NCNI, DEPT G~ DEPT NCNb DEPT SP GR NCNb DEPT NCNL DEPT SP GR NCNb DEPT SP GR NCNL DEPT SP G~ NCNb DEPT SP GR NCNb DEPT SP NCNb 0i0,H01 VERIFICATION 5900,0000 SFLU -26,4375 GR 138 6250 CALI 1919~0000 FCNL 5800 0000 SFLO -43~8125 GR 116,6875 CALl 2035.0000 FCNL 5700.0000 SFLU -21,3438 GR 172 2500 CAb! 2035:0000 FC~:b 5600.0000 $FLU -20,6719 GR 133,0000 CALl 1954.0000 FCNL 5500 0000 srbu -17:7500 GR 160,7500 CALI ~973.0000 FCNL 5400 0000 $FLU 20 !~406 GR T50 750 CALI 2016.0000 FCNL 6719 GR 92,1250 CALI 2194.0000 FCNL 5200.0000 SFLU -25 3438 GR ~o:oooo CAbI 2414,0000 FCNL 51.~,0000 SFLU ,8594 GR 89 8750 C&LI 2574:~000 FCNL 5000.0000 SFLU -35.1250 GR 92.4375 CALl 2458,0000 FCNL DEPT 4900 0000 SFLU SP -31;9219 ~R o~ 71,0000 CAbI 97,33 ILMi: ::_ _':: : ~:...: ..::'::I 1~2'5900- NPMi 41,6016 'RHOB 2,3496 11 · 7578 DR'~O::/ :::_. :: :: ~::~:.'~0 ~ '~::: 5tO,O000 DT 117~3750 GR 122;5000 3.4844 14. 0078 D'RHO O ;'0376 NRAT 3';2~39 0 3,9668~: IBM': :~' '.: :~:1:~: ~ :~'5~' ->~ '> >:.~ ~::'I: 9-.;:.;: '. '~' ':: 170.8750 ~PH~ 32'~ 95'90 RHOB 2~ ~71, i 603,5000 OT i'04;0'000 'GR 170,87'50 i 1,4688 D IqFi',0 ..... 0; 03'42 N'R AT ......... 3,81'64 76. 2500 -:<:!' :::'? 5~. :3 ::: :_ _:.i:; - · · 1,2080 bmr:4.:'::::: :.::.: ::ff. ::: !:::::: :.:-::::.- .: 55 , 2500 NPHI ......... 44", 2"8"71 R~Ci8 2';; 26'56 12.2,.. ~' 96g ".:D'RHO :;: ::: "~: O':'....:.: :::': :: :::~: - 432:75005?23 12.9766 DRHO 0~02'34 NRAT 3"'3848 8 8- O q~:~I'25 NPHI ..... ..... . 2;.~_2~_2_:- : . 2. 164 12 , ~ 641 ' 18.5000 .- PT :.:::;:-:-:~:-~;.:~ ::,:;~ <:.~G ':;:~:::~U ~":t. :~ =============================== : :'.:- ' ~. 8 2:6 2 12. 4688 31 ;5000 0T f0'2';O'OO0 .... ~ 8'0'~'I'25 ~ 5352 iL, g 2.~0~9 ILD 2,4~92 9 4, 50:00 .4648 IbM~, :':~. ~ ': D:..'..'::::'..:~': :::: .::<:~:~: 3: 0::. ':: '< :: - 12,5 LVP NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP G~ NCNb DEPT SP NCNb DEPT SP GR NCNb DEPT SP NCNL DEPT SP GR NCNb DEPT SP GR NCNL DEPT SP OIO,H01 VERIFICATION 23P6.0000 FCNL 4800.0000 SFLU -36 53~ 3 GR 71 ~ 93.5 CALl 2304.0000 FCN5 4700 0000 SFLU -45~9687 GR 96.2500 CALf 2180.0000 FCNI, 4600.0000 SFI,U -45.9375 GR 9'4.4375 CALl 2440.0000 FCNL 4500.0000 SFLU -46.8437 GR 86.6875 CALI 2516.0000 FCNL 4400.0000 SFLU -49 7188 GR 106:6250 CALl 2052.0000 FCNL 4~00 0000 SFLU 40~6250 GR 91.3125 CALl 2164.0000 FCNL 4200.0000 SFLU -52.0000 GR 98.5000 CALI 2008.0000 FCNL 4100,0000 SFLU -53.7188 GR 77,8125 CAbI 2294.0000 FCNL 4.000.0000 SFLU $3. 50 CALl 2412.0000 FCNL 3900 0000 SFLU -53'.9687 GR 73.02500 CALI 2464. 000 FCNL 3800.0000 SFLU -5B.6563 GR LISTING 672.0000 DT t03.3750~''"RG 72.6250 2,18 95' 4~-75 NPMI: ~ <' '"i~ :': 'i~,~ .=' ~:.~RM : 580.5000: I 0 b' i 250~' 0391 .~LM~.~ ~H' I "; ::: ' ..... ~:':~ h~:~ :~ 40 ;'~ 7-6' 2 L~:: ~IRHoB /~22; 2969 1 ). 2344 DRM'O ~ '~ -':~-:' :::< :..~/~ ~ 5S~. 500~ D~ fO'7; i875 GR 95', 5625 -~]~-." :.;:' '~.:~ ............. >.:. ' ~}5~' ~.. .........~' ~:: ::J" -~::~':: '~" 955 644. 50 O0 7 7 6875 NPHI 3i'~'~'9 ~ 8 R'~OB 2, )6']3 12.7 422 13i 8203 DRN'~ ~:,-'~0'3'66 ....... N~'AT 568,5000 :;:::: :.~:~:;~:. 94.3750 NPHi 38,0'859 'RH'OB 2 109.1875 ~. 0469 <~ .:~:~::~;--~::. :>.: ~:': ~ ~:' :: L~:.~ .::.;:;~':-:~.:'~ ~, ]. 006'0 :~ ~9'~= f'O~ ~ ....... ~'~ : .... 4. 2 69 641. 7 9.5781-''DRM 658.0600 'ST ....... "~'g9'";~2~'00 ...... ~- ~ 25'00 4. o LVP GP NCNL DEPT SP NCNL DEPT SP NCN5 DEPT SP NCNL DEPT G~ NCN5 DEPT SP GR NCNL DEPT SP NCNL DEPT SP NCgL 0EPT NCNL DEPT SP GR NCNL DEPT SP NCNL DKPT . 010 H01 VL. 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