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Home My WebLink About186-178MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-15 KUPARUK RIV UNIT 3Q-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-15 50-029-21666-00-00 186-178-0 W SPT 6505 1861780 3000 2750 2784 2784 2784 160 190 190 190 REQVAR P Josh Hunt 8/28/2024 This is a 2 year MIT-IA required by AIO 02B.042. This well was tested to a starrting pressure of 3440 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-15 Inspection Date: Tubing OA Packer Depth 350 3440 3350 3330IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828163255 BBL Pumped:2.8 BBL Returned:2.8 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:24:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-15 KUPARUK RIV UNIT 3Q-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3Q-15 50-029-21666-00-00 186-178-0 W SPT 6505 1861780 3000 2870 2870 2867 2869 25 30 30 30 REQVAR P Bob Noble 8/13/2022 MITIA as per AIO 2B.042 to max injection pressure. 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 3Q-15 Inspection Date: Tubing OA Packer Depth 540 3500 3410 3390IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814154922 BBL Pumped:2.7 BBL Returned:2.4 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:37:57 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � DATE: Tuesday, August 18, 2020 P.I. Supervisor '��C 5{ SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3Q-15 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-15 Petroleum Inspector Src: Inspector Reviewed By P.I. Suprv� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-15 Insp Num: mitBDB200816080742 Rel Insp Num: API Well Number 50-029-21666-00-00 Inspector Name: Brian Bixby Permit Number: 186-178-0 Inspection Date: 8/15/2020 11 Packer Depth Well – 3Q-15-- - Type Inj w ''TVD bsos PTD 1861780 Type Testl SPT iTest psi 3000 BBL Pumped— 2.BL Returned: 2.4 Intervale REQVAR p/F P Notes: MITIA as per AIO 213.042 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 'i 2880 2880 - 2880- 2880 ' IA 670 3480- 3420- 3400 - OA 50 - 60 - 60 60 Tuesday, August 18, 2020 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ( DATE: Monday,August 08,2016 Jim Re TO: P.I.Supervisor I `� 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-15 FROM: Bob Noble KUPARUK RIV UNIT 3Q-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-15 API Well Number 50-029-21666-00-00 Inspector Name: Bob Noble Permit Number: 186-178-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804104417 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-15 Type Inj w' TVD 6505 - Tubing! 2880 2880 - 2880 - 2880 - ---' ---- PTD 1861780 Type Test SPT Test psi 3000 IA 1 980 3600 0 - 3560 - 3550 - ---------------- Interval REQVAR P/F P OA 660 940_ 940 ' 940 - Notes: MIT-IA per 2B.042 to max anticipated injection pressure. stole V`!AY 9,101?, Monday,August 08,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,July 01,2015 Jim Regg P.I.Supervisor (7 7 + l S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-15 FROM: Johnnie Hill KUPARUK RIV UNIT 3Q-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .LCL NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-15 API Well Number 50-029-21666-00-00 Inspector Name: Johnnie Hill Permit Number: 186-178-0 Inspection Date: 6/27/2015 Insp Num: mitJWH150630143538 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-I5 jType Inj I W TVD 6505 Tubing 2540 .I 2575 - 2590 - 2590 - PTD 1861780 Type Test SPT Test psi 3000 IA 830 3450 3380 - 3365 Interval REQVAR PAF P - OA 490 660 - 665 665 Notes: 3 2 bbls diesel usd test psi was 3400 AIO 26.042 SCANNED l �� Wednesday,July 01,2015 Page 1 of 1 • COI'10C ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~~_ .'G~'. . ......_~. . ~. -' ~~J'.; Dear Mr. Maunder: ~ Iwi ~ ~~ 1~V t ~ ~' 3~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 3G 3H 3K & 3Q P d ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor a Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8l10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" - n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 3H-20 50103200950000 50103200930000 1880090 1871340 SF 16' n/a 3.75 77" 16" n/a 7/30/2009 5.52 2.25 8/9/2009 8/9/2009 3H-22 3H-25 50103200970000 50103202030000 1880110 1990400 27'6" 30" 4.25 n/a 21" 30" 7/30/2009 n/a 8.5 7.65 8/9/2009 8/9/2009 3H-26 3H-28A 3H-32 50103202080000 50103202360100 50103203220000 1940290 1960370 2000010 SF SF 10" n/a n/a n/a 9" 18" 10" n/a n/a n/a 2.12 5.1 1.27 8/9/2009 8/9/2009 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 3Q-02 3Q-04 3Q-07 3Q-12 3Q-13 3Q-15 3Q-16 50029222200000 50029216880000 50029222190000 5U029216820000 50029216770000 50029216640000 50029216660000 50029216670000 1911250 1870040 1911240 1861940 1861890 1861760 1861780 1861790 15'7" 41' 4'10" 6" 7" 44'6" 49'5" 46' 2.00 4.75 1.50 n/a n/a 5.00 4.50 S.25 17" 21" 16" 6" 7" 21" 20" 30" 7/30l2009 7/30/2009 7/30/2009 n/a n/a 7/30/2009 7J30/2009 7/30/2009 4.25 5.52 4.25 1.7 2.97 8.92 9.35 8.5 8/8/2009 8!8/2009 818/2009 8/9/2009 8/8/2009 8/8/2009 8/8/2009 8/8/2009 Page l~~;f~ Regg, James B (DOA) From: NSK Weil Integrity Proj [N1878@conocophillips.com) t~ /~,lc~~( Sent: Tuesday, April 07, 2009 4:48 PM i~~~~ _'t v To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: KRU 30-15 Attachments: 30-15 TIO.jpg; 3Q-15 10-403 & waiver.PDF ~~ 1 ~~ ~ 17~© Jim, We started 30-15 (PTD 186-178) on its AOGCC approved 10 week MI test on 3/10/09. We will be applying for a shorted MI cycle or water only AA pen ina e results of the test. The internal waiver is documenting Sundry 301-200 approval -the well must have a sleeve (a dummy WRDP) in ~- the SSSV profile during operations to patch a control line leak that causes TXIA communication. Additionally the well is on a 2 year MITIA cycle to ensure the sleeve remains competent. I have attached a copy of the Sundry 301-200 and a TIO. '~ The AA application will be submitted around the end of May 2009. '~ Please let me know if you need additional details. MJ Loveland ~~~b. I4 V .' :' . ,°.~ y;.~,i~3~,,, i~ k Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, April 07, 2009 3:46 PM To: NSK Well Integrity Proj Subject: KRU 3Q-15 Inspector witnessed SVS test at KRU 30-15 (WAGIN) on 3/29/09 -report attached. He notes that the well has a waiver for TxIA communication. This was one of the wells that we considered for the shortened WAG cycle back in 2007-2008 but it was delayed because well was shut in for reservoir pressure management - I do not find that we wrote an admin approval as was done for 30-12 (AIO 26.027). Looks like the well has remained on water only since being put back on injection in April 2008. Please provide an update of well's status and basis for (internal?)waiver. Also attached the last email correspondence I have regarding 30-15. Thank you. Jim Regg AOGCC 4/8/2009 KRU 3Q-15 PTD 186-178 r r 4/7/2009 ~',7~ z~ i ~,~ -~e~d- __ __ _• _ _ __ a __ _ _ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS r ' . Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well ~ Plugging _ Time extension _ Stimulate _ , Change approved program _ Pull tubing _ Variance _ Pertorete _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) PhiNips Alaska, inc. Deveiopment_ RKB 60 feet 3. Address Exploratory 7. Unit or Property rtarrte P. O. Box 100360 stratigmphlc_ Anchora e, AK 99510-0360 service x Kuparuk Unit 4. Locatlon of well at surface B. Well number 2294' FNL, 1988' FEL, Sec. 17, T13N, R9E , UM {asp's 516348, 6025777) 3Q-15 At top of productive interval 9. Permit number /approval number ' 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM 186-178 At effective depth 10. APl number 50-029-21666 At total depth 11, Field /Pool 408' FNL, 684' FEL, Sec. 17, T13N, R9E , UM rasps 517643, so27sss1 __ _ _._Kuparuk Oil Pool 12. Present well condition summer Total depth: measured 7480 feel Plugs {measured) true vertical 6858 feet Effective depth: measured 7367 feet Junk (measured) ', true vertical 6763'. fast Casing Length Size Cemented CONDUCTOR 115' 16' 1850# Poleset SURF.CASINt3 3785' 9-5/8" 10~o sx As Iv, 250 sx claas o PROD. CASING 7392' 7" 330 sx Class Q 175 sx AS f Perforation depth: measured 7174'-7204', 7212'-7252' Measured Depth True vertical Depth 115' 115' 3845' 3777 7452' 8835' RECEIVED JUL 1 7 2001 true vertk:al 6600'-6626', 6633'-6666` Al~ka Oil & Gas Cons. Commission Tubing (size, grad, and measured depth 2-7/8•,6.5#, L-so Tng ®7osr MD. Anchorage Packers & SSSV {type & measured depth) CAMCO'HRP-I-SP' as 7os2' MD. BAKER'FVL' 7/10/89 - LOCI~D Ot1T. 1/20/95 • WRDP PULLED. ~ 1786' MD: 13. Attachments Description summary of proposal ~C Detailed operations proSlram _ BOP sketch July 2, 2001 16. If proposal was verbaNy approved Oil _ Qas _ Suspended _ Name of approver Date a roved Service WAG 17. I hereby certify that the loregoing is,hueDand marred to the best of my imowledge. Ouestlons? CaR Peter Nezaticky 659-7224 Signed / ~/ /' K~ `'"`" Tide: Problem Weft Supervisor Dale Jury 12, 2001 PotuNezaY Pra edb SharonNtJsn Wake26'3~4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity _ BOP Test _ Location ciea-ance ~ ~ r - ~(} Mechan~ai Integrity Test p ~ Subsequent form required 10- a ~c Sr` CJ~`fc ' rovedb order of the Commission • ~ /~.~ ~-ec.~tf~~' Commissioner Date '~ ~~olf.~i Forrnl0-403 Rev06/15/8B• ~~~~~vl• 1~~ SUBMIT IN TRIPLICATE J '" Phillips Alaska, Inc. '~ Kuparuk Well 3Q-15 SUNDRY NOTICE 10-403 & 10-404 REPAIR REQUEST 07/12/01 The purpose of this Sundry Notice is to notify the AOGCC of Phillips Alaska, Inc., intent to repair the tubing on Kuparuk well 3Q-15 injector. The AOGCC was notified of a failed MIT on 03/20/01. Diagnostics showed the failed MTT was due to a leak in the tubing. A leak detect log was run and identified a leak in the SSSV nipple and further diagnostics indicated a parted control line. An isolation sleeve was run across the SSSV nipple to verify the leak location. After the isolation sleeve installation the well passed a state witnessed MIT on 07/06/01. Near-term plans for this well include conversion from water to gas injection {WAG service). PROPOSED ACTION PLAN Phillips proposes to use the following action plan for operation of this injector:. 1. The well maybe used for either gas or water injection (WAG); ~ - 2. Tubing /casing integrity must be maintained by leaving and maintaining the isolation sleeve across the SSSV to meet AOGCC MTT criteria; 3. Perform an MIT every 2-years subject to standard test criteria (0.25 x tvd @ packer. or 1500 psi minimum, whichever is higher); 4. Notify the AOGCC should MIT's or injection rates and pressures indicate further problems. R~~~I C ~`~ a~a~k , Jul' 1 ~ ?Opl a ~d & echo ~ ~0mmtssi~ NSK Problem Well Supervisor 06/23/01 DUP~.IC~TE ~~t _ _ _ _ _ ~ _ _ ,-°'.: ~~ LJ Notice of Kuparuk Waivered Well WELL: 3Q- ~ 5 WELL TYPE: WAG Injector DATE: 12-09-01 Infection Data: RIR 1200 BWPD Pressures: Tubing IA OA InJ; 2850 psi 1200 psi 850 psi Shut-In: 1800 psi 1000 psi A00 psi REASON FOR NOTICE: Tubing x Production casing communication (T x IA) TUBING x IA COMMUNICATION? YES XX NO • History of SSSV problems suggested damaged control line may be source of communication; • Leak Detect Log on 5/27/Oi verified T x IA communication at SSSV nipple; • Nipple Isolation sleeve effectively stops T x IA communication; • MITIA Passed @ 1950 psi {State witnessed) on 07/06/01 with Isolation sleeve in place; / • AOGCC approved WAG service for Weil if SSSV nipple sleeve Is maintained !n good condition. IA x OA COMMUNICATION? YES NO XX • Weii history does not indicate IA x OA communication Is present. • The well has shown T x IA communication problems since 1987; • T x IA communication Is documented at SSSV nipple'and can be effectively plugged with a sleeve installed; • SSSV sleeve must be maintained In good condition to meet conditions of AOGCC approval for WAG service; • AOGCC approval for WAG infection was signed 07/20/01. PLAN OF ACTION: XX ___~___. Grant waiver to continue operations • WAG injection is allowed; • IA pressure is subject to standard limits of 3000 psi on gas and 2000 psi on water; • SSSV isolation sleeve must be replaced as needed to stop T x lA communication; • Record all bleed events in Setcim (as per standard operating procedure) #or monitoring; • Monitor well head pressures daily and log weekly into 5etcim; • Perform the #oliowing waiver compliance testing: • MITIA every 2 years as per AOGCC requirements; • Shut-in and secure well if MIT #ails or pressures indicate further communication problems. O /' ~~_ \ti12~1~I oa etT~. T-' Send Original to: pefhiefs J Nezaflcky, us Operator CPF PE Wells Flle and schematic Central Fees ATO Central Files Kuparuk MEMORANDUM • TO: Jim Regg / P.I. Supervisor ~ t ~~l i ~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-IS KUPARUK RIV UNIT 3Q-15 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~ ~'~ Comm Well Name: KUPARUK RN UNIT 3Q-15 API Well Number: 50-029-21666-00-00 Inspector Name Bob Noble Insp Num: mitRCN0 80927 1 83 024 Permit Number: 186-178-0 % Inspection Date: 9~25~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Nlin. 60 Min. Well ~ 3Qas Type Inj. W ~ TVD ~ 6505 ~ IA I 1400 2930 ~ 2920 2920 1861780 P.T. j SPT , TypeTesti Test psi 2930 QA j 470 640 ~ 640 640 Interval 4YRTST P~ P ~ Tubmg ~ 2300 I 2300 2300 I 2300 Notes: Wednesday, October 01, 2008 Page 1 of l 3Q-15 (PTD 186-178) Suspected~A communication to MI Page 1 of 2 Re , James B DOA • J9 ( ) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, January 28, 2008 2:49 PM ~r~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~'~ ~ ( ~ Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 3Q-15 (PTD 186-178) Suspected TxIA communication to MI Jim, There will be a delay in the results from a test on M9 injection as this well, 3Q-15, is shut in for reservoir pressure management and is expected to remain shut in until late March, at which time the test cycle could begin. The AOGCC will be notified of the results once the test has been conducted and the appropriate paperwork will be submitted at that time. Currently the other two wells; 30-10 and 30-12 are online for the approved test cycles. Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, January 08, 2008 10:28 AM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 3Q-15 (PTD 186-178) Suspected TxIA communication to MI I believe this is best handled just as done with KRU 30-12; swap to water and reenergize tubing packoffs and seals before submitting the AA fior continued operating the well. Refer to our 9/4/2007 email correspondence regarding KRU 30-12 (attached}. Request for administrative approval should be provided at completion of MI injection cycle {March 2008?}. We do not consider this a "normaP' well that would be exempt from the AA requirement. 1 am not following the issue regarding Pioneer development concerns. if there is something in writing, please provide. KRU 3Q-15 should be added to the monthly injector well integrity repart you submit. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, December 24, 2007 5:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 3Q-15 (PTD 186-178) Suspected TxIA communication to MI 1 /31 /2008 3Q-15 (PTD 186-178) Suspected~A communication to MI Page 2 of 2 Jim, Injector 3Q-15 (PTD 186-178) is showing signs of TxIA communication by a steady increase in IA pressure as noted on the TIO trend. The well has been on MI injection since June 2007 and has a similar trend pattern as previously reported 30-12 (188-041) where the communication was caused from the MI drying out the threads and seals after a few months of MI injection. So far 30-12 TxIA communication has been successfully mitigated with a shorter MI cycle --results will follow under separate email. In addition, 3Q-15 exhibited this very behavior once before after a similar length of MI injection and was reported and repaired in March of 2007. It is our belief that we can repair the 3Q-15 TxIA communication again by reenergizing the tubing packoffs and seals after the well has been on water for a few days. After which I would like to recommend an MI cycle length of no greater than 12 weeks followed by a water cycle. To complicate matters this is one of the 3 wells that the AOGCC has requested that we leave on MI through January to monitor for Pioneer development issues. ConocoPhillips requests approval to wag 3Q-15 (PTD 186-178) to water, reenergize the seals, and then test a shortened Ml cycle. If the shorter MI cycle is NOT successful in mitigating the TxIA communication we will apply for an AA for water only injection. If the shortened cycle is successful our intention would be to leave 3Q-15 classified as a normal well, however would add it to the monthly injector TIO reporting fist if requested by the Commission. Please let us know if the plan is acceptable. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 «30-15 18 Month TlO.jpg» «30-15 3 Month TIO.jpg» «3Q-15.pdf» 1/31(2008 3Q-15 (PTD 186-178} Suspected xIA communication to MI Page 1 of 2 • Regg, James B (DOA) From: Regg, James B (DOA) ~ [ ~ ~~~~ Sent: Tuesday, January 08, 2008 10:28 AM ~~~ `~ To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 3Q-15 (PTD 186-178) Suspected 7xIA communication to MI Attachments: KRU_30-12_wellbore_2007-0904.pdf I believe this is best handled just as done with KRU 30-12; swap to water and reenergize tubing packoffs and seals before submitting the AA for continued operating the well. Refer to our 9/4!2007 email correspondence regarding KRU 30-12 (attached). Request for administrative approval should be provided at completion of MI injection cycle (March 2008?). We do not consider this a "normal" well that would be exempt from the AA requirement. I am nat following the issue regarding Pioneer development concerns. if there is something in writing, please provide. KRU 3Q-15 should be added to the monthly injector well integrity report you submit. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, December 24, 2007 5:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 3Q-15 (PTD 186-178) Suspected TxIA communication to MI Jim, Injector 3Q-15 (PTD 186-178) is showing signs of TxIA communication by a steady increase in IA pressure as noted on the TIO trend. The well has been on MI injection since June 2007 and has a similar trend pattern as previously reported 30-12 (188-041) where the communication was caused from the MI drying out the threads and seals after a few months of MI injection. So far 30-12 TxIA communication has been successfully mitigated with a shorter MI cycle --results will follow under separate email. In addition, 3Q-15 exhibited this very behavior once before after a similar length of MI injection and was reported and repaired in March of 2007. It is our belief that we can repair the 30-15 Tx1A communication again by reenergizing the tubing packoffs and seals after the well has been on water for a few days. After which 1 would like to recommend an MI cycle length of no greater than 12 weeks followed by a water cycle. To complicate matters this is one of the 3 wells that the AOGCC has requested that we leave on MI through January to monitor for Pioneer development issues. ConocoPhillips requests approval to wag 3Q-15 (PTD 186-178) to water, reenergize the seals, and then test a shortened MI cycle. If the shorter MI cycle is NOT successful in mitigating the TxIA communication we will apply for an AA for water only injection. If the shortened cycle is successful our intention would be to leave 3Q-15 classified as a normal well, however would add it to the monthly injector TIO reporting list if requested by the Commission. 1 /8/2008 3Q-15 (PTD 186-178) Suspected IA communication to MI Please let us know if the plan is accble. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska; Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 «3Q-15 18 Month TIO.jpg» «3Q-15 3 Month TIO.jpg» «3Q-15.pdf» Page 2 of 2 1 /8/2008 ~"'~; RHILLIP Alaska, Inc. ~ubsidia.rr oP PHILLIPS PETP,QLEIJP~t COt~,hP?~.Pdl' 3Q-15 SLEEVE (1786-1787, ! ;~ OD:2.312) • KRU 3Q-15 _ APL SSSV Tyke 50U[az1eti600 ~ well I ype: , INJ LOCKED OUT ~ Orig Com IeUon: 11/26/1986 _ An91e w T5: An le TD: 52 de N 7170 33 de 7480 Annular Fluid. _ _ i Last W/O: 8/13/1987 Rev Reason: Reset ISO Sleeve _ l __-___-- ____ r by Imo Reference Lo Ref Log Date Last U date: 1/18/2002 Last Ta : 7230 ~ TD: ! 748.0 ftK6 Last T~ Date: _ _ 4/13/2001 -~ Max Hole Angle . 33 deg @ 6200 `~' °` ~! Casing String -ALL STRINGS _ ~, . `-3 Descri tion Size To Bottom TVD ; Wt Grade Thread CONDUCTOR _ 16.000 0 _ '115 115 62.50 H-40 _ SURF.CASING __ 9.625 0 ___i 3845 3777 36.00 J-55 PROD. CASING .7.000 0 i 7452 6835 260)~J-55 ~__ i ~~ Tuhing String_ TUBING - - _ - - ~` ~ Size Top Bottom TVD __~ Wt ( Grade { Thread 2.875 0 7092 6531 i 6.50 L-80 _ _ EUE 8RD AB MOD Perforations Summa _ - _ _ __ - ry __ _ . Interval _ TVD 7174 - 7194 (__6600 - 6617 7194 - 7195 6617 - 6618 _ Zone C-4,A-3,A-2 A-2 Status _ _ _ , Ft 20 1 ISPF j 6 7 ~ I Date 5/31/1991 5/31/1991 ~~ RPERF j RPERF Comment 2-1/8" EJ II; 0 de h 2-1/8" EJ II; 0 de h 7195 - 7196 6618 - 6619 I A-2 . ~ 6 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7196 - 7197 ! 6619 - 6620 A-2 __ 1 7 5/31/1991 RPERF 2-1/8" EJ fl; 0 de h 7197 - 7199 6620 - 6622 _ _ A-2 2 i 6 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7199 - 7200 ' 6622 - 6622 A-2 1 7 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7200 - 7201 6622 - 6623 A-2 1 ~ 6 5/31!1991 RPERF 2-1/8" EJ II; 0 de h 7201 - 7202 6623 - 6624 A-2 _ 1 _ 7 j 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7202 - 7204 6624 - 6626 j A-2 ! _ 2 __ 6 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7212 - 7222 6633 - 6641 j A-1 10 _ _ 6 _ 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7222 - 7223 6641 - 6642 A-1 I 1 7 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7223 - 7224 _ i _ 6642 - 6643 __ A-1 1 I _ 6 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7224 - 7225 i -- 6643 - 6644 _ _ A-1 1 7 1 _ 5/31/1991 RPERF 2-1/8" EJ IP 0 de h 7225 - 7226 - 6644 - 6644 _ A-1 1 6 ` _ 5131/1991 ' RPERF 2-1/8" EJ IP 0 de h 7226 - 7227 - 6644 - 6645 _ _i - A-1 1 -_ _7 - _5/31/1991 - RPERF 2-1/8" EJ II; 0 de h 7227 - 7228 --- 6645 - 6646 j A-1 ± 1 - - 6 5!31/1991 RPERF 2-1/8" EJ II; 0 de h 7228 - 7229 _- 7229 - 7230 i ---- 6646 - 6647 - 6647 - 6648 _ A-1 ----- A-1 r ___ 1 ! ~ _ _ ', 1 _ __ 7 ~ 6 5!31!1991_ 5/31%1991 RPERF RPERF 2-1/8" EJ II; 0 de h 2-1/8" EJ II; 0 de h 7230 7231 ~ 6648 - 6649 _ A-1 ~=_ 1 _ 7 ! 5%31%1991 RPERF 2-1/8" EJ II; 0 de h 72_31 7232 ! 6649 - 6649 A-1 1 ~ 6 5/31/1991 RPERF 2-1/8" EJ II; O de h 7232 - 7233 6649 - 6650 A-1 I ! 1 { 7 5/31/1991 RPERF 2-1/8" EJ II; 0 de h 7233 - 7234 7234 - 7252 6650 - 6651 6651 - 6666 ! A-1 D_1 _ ~ 1 _ 1R 1 _ 6 7 5/31/1991 5/Z1/1001 RPERF RRFRF 2-1/8" EJ II; 0 de h 7.1 /R" F i II n Aon nh Gas Lift MandrelsNalves II PBR I (7042-7043, OD:2.875) j I St 1 MD , __ ; 2557 TVD 2557 Man Mfr MMH Man ~ T e FMHO V Mfr V T e ~ yp DMY V OD ~ .0 Latch ~ M Port .000 TRO i _._ 0 -__ Date Run 3/25/2000 - Vlv Cmnt _ 2 i 4402 4253 _ MMH FMHO _ _ _ _ _ DMY i 1.0 BK-2 0.000 0 3/23/2000 3 5611 5281 MMH FMHO _ _ _ ____ '' DMY 1.0 BK-2 0.000 0 3/23/2000 4 6282 5846 MMH __ FMHO ___ DMY 1.0 BK-2 0.000 0 3!24!2000 5 6636 6144 MMH FMHO _ _ I DMY 1.0 BK-2 0.000 0 ; 3/24/2000 6 6991 6445 Otis LB i _ _ DMY 1.5 T-2 0.000 0 3/24/2000 I PKR .. - Other (plugs, equip., etc.) -JEWELRY (7062-7063, ~~~,~_ ~' OD:6.151) I NIP ya (7079-7080, OD:2.875) TUBING (a7os2, OD:2.875, _ ID:2.441) Perl (7174-7204) Pert (7194-7195) Pert Q199-7200) Depth TVDD i Type Description fD 1786 1786 SSSV Baker'FVL' 7/10/89 -Locked Out -SLEEVE REQUIRED 2.300 1786 1786 __SLEEVE I __ ISO SLEEVE R ESET_ACROSS SSSV 12' X 2.312" 10/18/01 , 1.812 7042 6489_ PBR _ Camco OEJ' _ ( 2.312 7062 ~ _7079 7091 7092 6505 _ 6520 6530 6531 PKR . NIP _SOS TTL Camco'HRP-1-SP' - - --- Camco'D' Nipple NO G_O__ _ Camco _ _ 2.347 2.250 2441 General Notes - _ I - __ I Perf (7222-7223) - KRU 3Q-15 (3-month TIO pressures) PTD 186-178 T; 1.. t7 Plot - 3Q-15 3000 v, 2000 1000 200 150 as 100 y a v 50 0 p -}-+++ 24-Sep-07 07-Oct-07 20-Oct-07 02-Nov-07 15-Nov-07 28-Nov-07 11-Dec-U! Date • ,] KRU 3Q-15 (18-month TIO pressures) PTD 186-178 T,'I,~O Plot - 3Q-15 3000 a 2000 1000 0 .,I ~ ~ ~ ~.... ; ~ ~ , ~ ~. ~n 01-Jan-07 ^ate 200 150 a. d 100 50 O • • 3Q-15 PTD # 186-178 Suspect T X IA comm. a . Jim, 30-15 PTO # 186-178 MI injector is showing signs of T x IA communication. Current T/I/O = 3700/2975/240 psi. / Immediate plans are to bleed and monitor the lA, WAG the well back to produced water to flush the gas out of the well bore and perform leak diagnostics. /" Let me know if you have any questions. Sincerely, l ......-r::: c µ:o F 10+ ctpp&rs to I ~{Gk :5~ðJ= 09M.~"~ ~~ Jë~ cZW7 l..1/\ Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 3CANNED APR 0 5 2007 «30-15.pdf» «30-015 90 day TIO.gif» ,. .... ,..- Content-Description: 3Q-15.pdf 3Q-15.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 3Q-015 90 day TIO.gif 3Q-015 90 day TIO.gif Content-Type: image/gif Content-Encoding: base64 1 of 1 4/2/2007 11 :47 AM 590 1267x779 of 4/2/2007 AM . . KRU 3Q-15 Well Type: IINJ Oria Completion: ,11/26/1986 Last W/O: 8/13/1987 Angle @ TS: 132 deg @ 7170 Anale @ TD: i 33 dea @ 7480 Rev Reasòn: Reset ISO Sleeve bvlmO Last Update: 1/18/2002 API:J500292166600 SSSV Tvpe:llOCKED OUT Annular Fluid: I i _~~Reterenee Log: I Last T aa: 7230 ~Date:14/13/2001 Description CONDL OR SLEEVE (1786-1787, 00:2.312) -~_.._- cc ______c._ _~R¡¡f.~()g()i1t.e: _________~____ ____ TD: 7480llKB MaXHol~~O I Size I ~I TVD I Wt I G 1 16.000 1 0 i 115 I 115 1 62.50 I I 9.625 0 3845 3777 36ßO 1 ! 7. 1 0 1 7452 I 6835 1 26m- Top ! Bottom I TVD I Wt I Grade I o I 7092 6531 ~ L-80 TVD Zone Status! Ft SP:) Date Type 6600 - 66_1I- C-4,A-3,A-2 I 20 ~ 5/31/1991 RPERF 6617 - 6618 A-2 ------~1 7 '5/31/1991' RPERF ·6618 - 6619 A-2 1 6 5/31/1991 RPERF 6619 - 6620 A-2 1 7 5/31/1991 RPERF 6620 - 6622 A-2 2 6 5/31/1991 RPERF 6622 - 6622 A-2 1 7 5/31/1991 RPERF 6622 - 6623 A-2 1 6 5/31/1991 RPERF 6623 - 6624 A-2 1 1 7 5/31/1991 RPERF 6624 - 6626 A-2 2 6 5/31/1991 RPERF 6633 - 6641 A-1 10 , 6 i 5/31/1991 RPERF 6641 - 6642 A-1 1 7 5/31/1991 RPERF -- -- 6642 - 6643 A-1 i 1 6 5/31/1991 RPERF 6643 - 6644 A-1 1 7 5/31/1991 RPERF 6644 - 6644 Ä~1·T-6-- 5/31/1991 RPERF 6644 - 6645 A-1 1 7 5/31/1991 RPERF 6645 - 6646 A-1 1 6 5/31/1991 RPERF 6646 - 6647 A-1 1 7 5/31/1991 RPERF 6647 -"6648 A-1 i 1 6 5/31/1991 RPERF 6648 - 6649 A-1 : 1 7 I 5/31/1991 RPERF 6649 - 6649 A-1 I 1 6 5/31/1991 i RPERF 6649 - 6650 A-1 1---.L-Z_ 5/31/1991 , RPERF 6650" 6651 A-1 1 i 6 5/31/1991 RPERF 6651 - 6666 A-1 ~--- 1s'T-y-- 5/3171991 RPERF Ie Thread DRrm Ie"",. Size 2.875 Thread EUE 8RD AB MOD Interval 7174 - 7194 .. 7194 - 7195 7195 - 7196 7196 - 7197 7197 - 7199 7199 - 7200 7200 - 7201 ~J202__ 7202 - 7204 7212 - 7222 7222 - 7223 7223 - 7224 7224 - 7225 ~_- 7226 7226 - 7227 7227 - 7228 7228 - 7229 7229 - 7230 7230 - 7231 7231 - 7232 7232 - 7233 7233 - 7234 ----m-4~252 . Comment 2-1/8" EJ II; 0 dea ph 2-1/8" EJ II; 0 dea ph 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 dea ph 2-1/8" EJ 0 dea ph 2-1/8" EJ 0 dea ph 2-1/8" EJ 0 deg ph 2-1/8" EJ 0 deg ph 2-118" EJ 0 dea ph 2-1/8" EJ 0 dea ph 2-1/8" EJ 0 deg ph 2-1/8" EJ 0 dea oh 2-1/8" EJ . 0 dea ph 2-1/8" EJ II' 0 deg ph 2-1/8" EJ II' 0 deg ph 2-1/8" EJ II; 0 dea ph 2-1/8" EJ II; 0 dea ph 2-118" EJ II; 0 dea ph 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 dea ph 2-1/8" EJ II; 0 dea ph 2-1/8" EJ II; O. Man I V Mfr I V Type V OD Latch II Port TRO Date Type I Run FMHC{_ -----J DMY'- 1.0 RM ,.0.000 0 3/25/2000 FMHQ~ .. +- DMY 1.0 BK-2 I 0.000 i 0 3/23/2000 FMHÖ' --. -I"_~n.o BK-20.000 0 3/23/2000 ~~~g ----=f-=-!~f·l=U=Pl;F· g:ggg' g : ~iHi~ggg I)) ______ .____ Des,C?':Ïption __._. Baker 'FVL' 7/10/89 - Locked Out - SLEEVE REQUIRED ISO SLEEVE RESET ÄCROSSSSS\liZX 2.312" 10/18/01 Cameo 'OËy----- .--.---~------ -~----"-----_._----~,_._-------_. I Cameo 'HRP-1-SP' I Cameo 'D' Nipple NO GO 1 Cameo I --- .-- ---- St I MD TVD Man Mfr 1 __I 2557 2557 MMH IT 4402 4253 MMH 3 5611 5281 MMH -41-6282 5846 MMH 5 I 6636 6144 MMH 6 ' 6991 6445 Otis Vlv Cmnt PBR (7042-7043, 00:2.875) PKR (7062-7063, 00:6.151) ~~_ TVD ~J 1786 ~_1.1J:86 ~~_L 6489 . 7062 -r 6505 7079 1 6520 7091 1 6530 7092 6531 Type SSSV SLEEVE PBR PKR NIP SOS TTL ID 2.300 1.812 2.312 2.347 2.250 2.441 2.441 NIP (7079-7080, 00:2.875) Date I Note 12/9/20011 WAIVERED WELL: CONFIRMED CONTROL LINE LEAK - ISO sleeve (2.312" OD x 1.812" ID) must r-- 1 remain across SSSV to maintain tubing IA isolation. 1 i TUBI NG (0-7092, 00:2.875, 10:2.441) mmm ......... Ii ,I m.m " Ii --- --- ii = - m .:::;I Ii :eI:::::: II " ~ II - - - - II __m.m mm. m m.m.. II - - I' - - II "----- -- - ----- :........... ::::::.. : ~ Ii i , Ii " Î! --~- JJ Perf (7174-7204) Perf (7194-7195) Perf (7199-7200) Perf (7222-7223) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: JCr Petroleum Inspector DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA lNC 3Q-15 KUPARUK RIV UNIT 3Q-15 TO: JimRegg 0 Ðl. J P.I. Supervisor f\~ <> Z¿. (ù4 Src: Inspector Reviewed By: P.I. Suprv .::r &-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-15 API Well Number: 50-029-21666-00-00 Inspector Name: JCr Insp Num: mitJCrO40810 181851 Permit Number: 186-178-0 Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-15 Type Inj. N TVD 6858 IA 400 3200 3150 3150 P.T. 1861780 TypeTest SPT Test psi 1626.25 OA 150 170 170 170 Interval 4YRTST PIF P Tubing 450 500 500 500 Notes: Wednesday, August 11,2004 Page I of I ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 2, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Sundry Notice for ConocoPhillips Alaska, Inc., well 3Q-15 (PTD 1861780). The Sundry Notice 'regards returning the well to a 4-yr MIT cycle after a successful repair for a failed MIT with two subsequent passing State witnessed 2-yr MITs. Please call Nina Woods or me at 907-659-7224 if you have any questions. Sincerely, MJ Loveland Co'nocoPhillips Problem Well Supervisor Attachments ~OANNED AUG ~ 1 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon BI Suspend F'] Operation Shutdown BI Pedorate BI Variance E~] Annular Disp. BI Alter Casing F'] Repair Well BI Plug Perforations BI stimulate BI Time Extension E] Other Change Approved Program F0-] Pull Tubing F~ Perforate New Pool BI Re-enter Suspended Well BI 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory r-1 186-178 / 3. Address: Stratigraphic D Service [] 6. APl Number: P. O. Box 100360 50-029-21666-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 60' 3Q-15 8. Property Designation: 10. Field/Pool(s): Kuparuk Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7480' feet true vertical 6858' feet Plugs (measured) Effective Depth measured 7367' feet Junk (measured) true vertical 6763' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURF.CASING 3785' 9-5/8" 3845' 3777' PROD. CASING 7392' 7" 7452' 6835' Perforation depth: Measured depth: 7174'-7204', 7212'-7252' true vertical depth: 6600'-6626', 6633'-6666' Tubing (size, grade, and measured depth) 2-7/8", L-80, 7092' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-I-SP' pkr= 7062' BAKER 'FVL' 7/10/89 - LOCKED OUT. 1/20/95 - WRDP SET PULLED. @ 1786' MD, Frac Sleeve installed @ 1786' 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-Mcf Water-Bbl Casing Pressure Tubin,q Pressure Prior to well operation 700 2800 2800 Subsequent to operation 700 1150 2800 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory F'~ Development r-'] Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oi1["-1 Gas r--~ WAGr~ GINJ~] WINJ r-'l 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: 301-200 I Contact MJ Loveland/Nina Woods Printed Name MJ Lo.y/eland/. / . Title Problem Well Supervisor Signature ,~~'~.~ /~..~~ Phone 659-7224 Date A m n~t Prepared bi/Sharon ~ll~up-~rake 2,63-4612 / Form 10-4(¢4 Revised 2/2003 · SUBMIT IN DUPLICATE Phillips Alaska, Inc. Kuparuk Well 3Q-15 (PTD# 1861780) SUNDRY NOTICE 10-404 08/02/03 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska's, intent to retum WAG injection well, 3Q-15 (PTD# 1861780), to a 4 year MIT cycle. Successful tubing repairs were completed in July 2001, for a leak discovered by a failed MIT. The failed MIT was reported to the AOGCC on 3/20/01. It was subsequently diagnosed and repaired per Sundry Notice 10-403/404 #301-200. Since the repair (a sleeve across the SSSV for a parted control line) was completed, the well has passed two State witnessed MIT's on 07/06/01 and 6/27/03. After the two successful 2-yr cycle MIT's, it is ConocoPhillips Alaska's intent to return the well to a normal 4-yr MIT cycle. PROPOSED ACTION PLAN ConocoPhillips Alaska proposes to use the following action plan for operation of this injector: 1. The well may be used for either gas or water injection (WAG); 2. Tubing / casing integrity must be maintained by leaving and maintaining the isolation sleeve across the SSSV to meet AOGCC MIT criteria; 3. Perform an MIT every 4-years, subject to standard test criteria (0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 4. Notify the AOGCC should M1T's or injection rates and pressures indicate further problems. NSK Problem Well Supervisor 06/23/01 , PHILLIPS Alas ka, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY SLEEVE -- (1786-1787, 0D:2.312) PBR -- (7042.7043, 0D:2.875) PKR -- (7062-7063, 0D;6,151) NIP (7079-7O80, 0D:2,875) TUBING (O-7092, 0D:2,875, ID:2.441) Ped (7174-7204) Ped (7194-7195) Perf (7199-7200) Peri (7222-7223) KRU 3Q-15 Reference Lo~:l Last Tag: 7230 LastTag Date: 4/13/2001 Well Type: IINJ ' Angle {~ TS: 132 deg @ 7170 Orig Completion:111/26/1986 Angle @ TD: 33 deg @ 7480 Rev Reason: ReSet ISO Sleeve Last W/O:18/13/1987 I by ImO Ref Log Date:J J Last Update: 1/18/2002 TD:J 7480 ftKB I Max Hole Angle: J 33 deg @ 6200 Bottom 115 115 3777 3845 7452 Casing'String - ALL STRINGS. Description Size i Top I CONDUCTOR 16.000 I 0 I SURF.CASING 9.625 0 I PROD. CASING 7.000 0 TVD I Wt GradeI Thread I 62.50 I H-40 I J 36.00 J J-55 6835 I 26.00 I J-55 Size I Top 2.875 0 Perforations Summary. Interval TVD 7174-7194 6600-6617 7194-7195 6617-6618 7195-7196 6618-6619 7196-7197 6619-6620 7197-7199 6620-6622 7199-7200 7200-7201 6622-6622 6622~6623 7201-7202 6623-6624 7202-7204 6624-6626 7212- 7222 6633-6641 7222-7223 7223-7224 6641- 6642 6642 - 6643 7224-7225 6643-6644 7225- 7226 6644-6644 7226-7227 6644-6645 7227- 7228 6645-6646 7228-7229 6646-6647 7229- 7230 6647-6648 7230-7231 6648-6649 7231-7232 6649- 6649 7232- 7233 6649-6650 7233-7234 6650-6651 7234- 7252 6651-6666 Gas LiE Mandrels/Valves Bottom I 'rVD Wt Grade Thread 7092 6531 6.50 L-80 EUE 8RD AB MOD ~PF Zone Status Ft Date Type C-4,A-3,A-2 20 6 5/31/1991 I RPERF 2-118" EJ II; 0 deg ph A-2 I 7 5/31/1991 ) RPERF 2-1/8" EJ II; 0 deg ph A-2 I 6 5/31/1991 I RPERF 2-118" EJ II; 0 deg ph A-2 I I I 7 5/31/19911RPERFI2-1/8"EJII;0degph A-2 2 6 5/31/1991 I RPERF .2-1/8" EJ II; 0 deg ph A-2 I 7 5/3111991 I RPERF 2-1/8" EJ II; 0 deg ph A-2 I I 1 I 6 I 5/3111991 ~ RPERF 12-1/8" EJ II; 0 deg ph A-2 I I I I 7 15/31/19911RPERFI2-1/S"EJII;0degph A-2 I I 2 I 6 I 5/3111991 I RPERF 12-1/8" EJ II; 0 deg ph A-1 I I 10 [ 6 15/31/1991iRPERFI2-1/8"EJII;0degph A-1 I I I I 7 15/31/19911RPERFJ2-11a"EJII;0degph A-1 I I 1 I 6 15/31/1991/RPERFI2-1/8"EJII;0degph A-1 I I I I 7 I 5/3111991 I RPERF 12-1/8" EJ II; 0 deg ph A-1 I I I I6 15/31/19911RPERFI2-1/8"EJII;0degph A-1 I I I I 7 I 5/31/1991 I RPERF 12-1/8" EJ II; 0 deg ph A-1 I / 1 6 15/31/19911RPERFI2-1/8"EJII;0degph A-1 ! I 1 I 7 15/31/1991JRPERFI2-118"EJII;0degph A-1 I I I 16 15/31/19911RPERFI2-1/S"EJII;0degph A-1 I I 1 7 5/31/1991 / RPERFI2-1/8"EJII;0degph A-1 I i 1 I 6 15/31/1991/RPERFI2-1/8"EJII;0degph --- A-1 ! I 7 5/31/1991 ~ RPERF 12-1/8" EJ II; 0 deg ph A-1 I I I I6 15/31/1991/RPERFI2'1/S"EJII;0degph A-1 I 1181 7 15/31/1991/RPERFI2-1/8"EJII;0deg_ph I Sti MD IT VD1 Man I Man I Mfr Type I '"4 6282 5846 MMH FMHO ' 151 6636 61441 aaH I FMHO 6991 6445 Ots I LB V Mfr - JEWELRY· VType VOD Latch Port DMY 1.0 RM I 0.000 DMY I 1.0 BK-2 0.000 DMY 1.0 . BK-2 0.000 DMY I 1.0 ] BE-2 0.000 DMY 1.0 BK-2 0.000 DMY 1.5 T-2 0.000 .. Description sssv Baker'FVL' 7/10/89- Locked Out - SLEEVE REQUIRED TRO DateRun 0 3/25/2000 0 ' 3/2312000 0 3/23/2000 0 3/2412000 0 3/2412000 0 3/24/2000 Vlv Cmnt ID 2.300 1.812 SLEEVE ISO SLEEVE RESET ACROSS SSSV 12' X 2.312" 10/18/01 PBR Camco 'OEJ' PKR Camco 'HRP-1-SP' I 2.312 · 2.347 · 2.250 NIP I Camco 'D' Nipple NO GO SOS Camco 2.441 TTL Note 2.441 WAIVERED WELL: CONFIRMED CONTROL LINE LEAK - ISO sleeve (2.312" OD x 1.812" ID) must remain across SSSV to maintain tubing IA isolation. MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Tom Maunder P.I. Supervisor FROM- Chuck Scheve State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 27, 2003 SUBJECT: Mechanical Integrity Tests Conoco Phillips 3Q-15 KRU Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. .':.I s I VI ,..P.T.D.I 186-178 ITypetestl P ITestpsil 162S I Ca$~ngl 250 I 20001 20001 2000I P/F I P I Notes: P.T.D.I Notes: We,I [ Type Inj. , .P.T.D. I Type test Notes: "WellI P.T.D.I Notes: .... P.T.D. I Type test ,Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3Q Pad in the Kupamk River Field and witnessed the semi-aunual MIT on well 3Q-15 as required by variance. It appears that the tubing by inner anulus comunication on this well has been repaired and the vafiance__~ty nn lcm..~{~1' b..~e needed~: The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with this well demonstrating good mechanical integrity. M.I.T.'s performed: '1 Number of Failures: 0 Attachments: Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. 2003-0627_M IT_KRU_3Q- t 5_cs.xls 7/11/2003 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX :[00360 ANCHORAGE, ALASKA 99510-0360 July 13,2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application and 10-404 for Sundry Approval for Phillips Alaska, Inc., well 3Q-15. Also attached is a discussion to support the request and a well schematic diagram. Please call Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, Peter Nezaticky Phillips Problem Well Supervisor Attachment ORIGINAL RECEIVED JUL 1 7 ~001 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2294' FNL, 1988' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth At total depth 408' FNL, 684' FEL, Sec. 17, T13N, R9E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic _ Service__X (asp's 516348, 6025777) (asp's 517643, 6027666) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-15 9. Permit number / approval number ' 186-178 10. APl number 50-029-21666 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF.CASING 3785' PROD. CASING 7392' 748O 6858 7367 6763' Size 16" 9-5/8" ,1 feet Plugs (measured) feet feet Junk (measured) feet Cemented 185o# Poleset 1070 sxAS IV, 250 sx Class G 330 sx Class G, 175 sx AS I Measured Depth TrueverticalDepth 115' 115' 3845' 3777' 7452' 6835' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7174'-7204', 7212'-7252' RECEIVED 6600'-6626', 6633'-6666' 2-7/8",6.5#, L-80 Tbg @ 7092' MD. CAMCO 'HRP-I-SP' @ 7062' MD. BAKER 'FVL' JUL 1 7 Alaska 0il & Gas Cons. Commission Anchorage 7/10/89- LOCKED OUT. 1/20/95- WRDP PULLED. @ 1786' MD. 13. Attachments Description summary of proposal _~X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation July 2, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed peter Nizaticky - ~¢~,// Title: Problem Well Supervisor FOR COMMISSION USE ONLY Questions? Call Peter Nezaticky 659-7224 Date July 12, 2001 Prepared by Sharon Aris up-Drake 263-4612 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance _ Mechanical Integrity Test __~ Subsequent form required 10- App..r..oved by order of the Commission J, IMi. Heusser ORIGINAL Commissioner ..... Approval no. Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3Q-15 SUNDRY NOTICE 10-403 & 10-404 REPAIR REQUEST 07/12/01 The purpose of this Sundry Notice is to notify the AOGCC of Phillips Alaska, Inc., intent to repair the tubing on Kuparuk well 3Q-15 injector. The AOGCC was notified of a failed MIT on 03/20/01. Diagnostics showed the failed MIT was due to a leak in the tubing. A leak detect log was run and identified a leak in the SSSV nipple and further diagnostics indicated a parted control line. An isolation sleeve was run across the SSSV nipple to verify the leak location. After the isolation sleeve installation the well passed a state witnessed MIT on 07/06/01. Near-term plans for this well include conversion from water to gas injection (WAG service). PROPOSED ACTION PLAN Phillips proposes to use the following action plan for operation of this injector: 1. The well may be used for either gas or water injection (WAG); 2. Tubing / casing integrity must be maintained by leaving and maintaining the isolation sleeve across the SSSV to meet AOGCC MIT criteria; 3. Perform an MIT every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 4. Notify the AOGCC should MIT's or injection rates and pressures indicate further problems. RECEIVED JUL 1 7 2001 Alaska Oil & Gas Cons. Commission Anchorage NSK Problem Well Supervisor 06/23/01 PHILLIPS Alaska, Inc. · A Subsidiary of PHILLIPS PETROLEUM COMPANY SLEEVE (1786-1787, OD:2.312) PBR (7042-7043, OD:2.875) PKR (7062-7063, OD:6.151) NIP (7079-7O8O, OD:2.875) TUBING (O-7O92, OD:2.875, ID:2.441) Perf (7174-7204) Perf (7194-7195) Perf 99-72oo) Perf (7222-7223) 3Q-15 i3Q-15 APl: 1500292166600 SSSV Type: I LOCKED OUT Annular Fluid: Reference Log: Last Tag: 7230 Last Tag Date: 4/13/2001 Casing. String - ALL STRINGS Description CONDUCTOR SURF.CASING PROD. CASING Tubing String - TUBING Size I T°P I 2.875 0 perforatiOns SUmmary TVD Interval 7174 - 7194 7194 - 7195 6600 - 6617 6617 - 6618 7195 - 7196 6618 - 6619 7196 - 7197 6619 - 6620 7197 - 7199 6620 - 6622 7199 - 7200 6622 - 6622 7200 - 7201 6622 - 6623 7201 - 7202 6623 - 6624 7202 - 7204 6624 - 6626 7212 - 7222 6633 - 6641 7222 - 7223 6641 - 6642 7223 - 7224 6642 - 6643 7224 - 7225 6643 - 6644 7225 - 7226 6644 - 6644 7226 - 7227 6644 - 6645 7227 - 7228 6645 - 6646 7228 - 7229 6646 - 6647 7229 - 7230 6647 - 6648 7230 - 7231 6648 - 6649 7231 - 7232 6649 - 6649 7232 - 7233 6649 - 6650 7233 - 7234 6650 - 6651 7234 - 7252 6651 - 6666 Well Type: I INJ Odg Completion: Last W/O: Ref Log Date: TD: 11/26/1986 8/13/1987 7480 ftKB 33 deg @ 6200 Max Hole Angle: Size Top 16.000 0 9.625 7.000 Bottom 115 3845 7452 Bottom I 'I'VD 7092 6531 Angle @ TS: 132 deg @ 7170 Angle @ TD:I33 deg @ 7480 Rev Reason: Tag, set Sleeve by ImO Last Update: 7/4/2001 TVD Wt Grade Thread 115 62.50 H-40 3777 36.00 J-55 6835 26.00 J-55 Wt Grade Thread 6.50 L-80 EUE 8RD AB MOD Comment 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 deg Dh 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 deg Dh 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 deg ph 2-1/8" EJ II; 0 de§ ph EJ II; 0 deg Dh 2-1/8" EJ II; 0 deg ph EJ II; 0 dog ph EJ II; 0 dog ph EJ II; 2-1/8" EJ II; 12-1/8" EJ II; EJ II; 2-1/8" EJ II; 2-1/8" EJ II; 2-1/8" EJ II; 2-1/8" EJ II; 2-1/8" EJ II; 2-1/8" EJ II; Gas Lift Mandrels/Valves StI MD IT VD I Man I Man I V Mfr I V Type I V OD I LatchI Port I Mfr Type 1 2557 2557 MMH FMHO DMY 1.0 RM 0.000 2 4402 4253 MMH FMHO DMY 1.0 BK-2 0.000 3 5611 5281 MMH FMHO DMY 1.0 BK-2 0.000I 4 6282 5846 MMH FMHO DMY 1.0 BK-2 I 0.000 I 5 6636 6144 MMH FMHO DMY 1.0 BK-2 0.000 6 6991 6445 Otis LB DMY 1.5 T-2 0.000 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 1786 1786 SSSV Baker'FVL' 7/10/89- Locked Out. 1/20/95- WRDP Pulled. 1786 1786 SLEEVE ISO SLEEVE SET ACROSS SSSV 12' X 2.312" 6/2/01 7042 6489 PBR Camco 'OEJ' 7062 6505 PKR Camco 'HRP-1-SP' 7079 6520 NIP Camco 'D' Nipple NO GO 7091 6530 SOS Camco 7092 6531 TTL EJ II; 0 dog ph 0 deg )h 0 deg ,h 0 dog ph 0 deg ph 0 deg ph 0 deg ph 0 deg ph 0 deg ph 0 deg ph 0 de ph EJ II; 0 deg )h TRO; Date Vlv i Run Cmnt 0 ! 3/25/2000 0 13/23/2000 0 ! 3/23/2000 0 ~ 3/24/2000 0 13/24/2000 0 i 3/24/2000 ID 2.300 1.812 2.312 2.347 2.250 2.441 2.441 General Notes Date Note 7/2/2001 Conflrmedt control line leak. ISO sleeve 2.312" OD x 1.812" ID) must remain across SSSV to maintain tubing A isolation. RECEIVED JUL 1 ? 2001 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2294' FNL, 1988' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth At total depth 408' FNL, 684' FEL, Sec. 17, T13N, R9E, UM Perforate _ Other_ ESP Jet Pump 5. Type of Well: Development __ Exploratory __ St rat ig rap h ic __ Service__X (asp's 516348, 6025777) (asp's 517643, 6027666) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-15 9. Permit number / approval number 186-178 / 10. APl number 50-029-21666 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 7480 feet 6858 feet Effective depth: measured 7367 feet true vertical 6763' feet Casing Length Size CONDUCTOR 115' 16" S U RF. CAS I N G 3785' 9-5/8" PROD. CASING 7392' 7" Plugs (measured) Junk (measured) Cemented 1850# Poleset lO7O sxAS IV, 250 sx Class G 330 sx Class G, 175 sx AS I Measured Depth 115' 3845' 7452' TrueverticalDepth 115' 3777' 6835' Perforation depth: measu red 7174'-7204', 7212'-7252' true vertical 6600'-6626', 6633'-6666' Tubing (size, grade, and measured depth) 2-7/8",6.5#, L-80 Tbg @ 7092' MD. Packers & SSSV (type & measured depth) CAMCO 'HRP-I-SP' @ 7062' MD. RECEIVED JUL 2' ZOO! 0//,~ G~s Cons, AnChorage Commission BAKER 'FVL' 7/10/89 - LOCKED OUT. 1/20/95 - WRDP PULLED. @ 1786' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 1317 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 3862 7590 1919 2859 4615 Casing Pressure Tubing Pressure 302 260 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Questions? Call Peter Nezaticky 659-7224 Title Problem Well Supervisor Date Prepared by Sharon AIIsup-Drake 263-4612 ORIGINAL SUBMIT IN DUPLICATE MEMORANDUM TO: Julie Heusser Commissioner ' q' ~'~' THRU: Tom Maunder .~VAu~ P.I. Supervisor'~'' ,v , FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 3Q Pad 3Q-15, 3Q-21 KRU Kuparuk River Field NON,,- CONFIDENTIAL Packer Depth Pre~est Initial 15 Min. 30Mi~. '" ' w,,,I ~-~s I~'r~.! S I~-v-o- ! ~ '1 ZuU., I' ~z~ I" =r, O I ~?"01 ~ I'~/ W' P.T.O.I 1~17~ ITy~t~l P IT=~I '~ I~! 2~ !'~=1 ~ I'~! ~ I ~ ~: MIT ~ ~V ni~e ~ve w/~i~ ~r (~ ~ li~) ..... W~I 3Q'21 I Tymi~j.I s'. I T.V.D. ! ~"l'Tuangl 2~ I 2~i 2~5 I 2~ I,~-,I w , ~-T-D-I,,~!~ IT~,t~l P, I~~1 ~ I caa~'l ~7~1 =~1 ~1 ~i,~~ I ~ ~: MIT ~ ~ tubi~ liar i~llafi~ ' wa~! I T~lnj.! !T'V'D;! :! TuU~l ' i '1 ' "! I~ail ' ,"J-O-I , , l~t~l, I~=~1'Ic"a~l , I , ~1 I I "~-!.. Weil~, P.T.D.~ Notes: w,",! P.I.D.I Notes: ITY,e'.j.! I T.v.D. I ' I Tubing]I I' I I'nte~aq ' ITypetestl , ITest ~.'1 ,' "1 cas~n~ I " I .I ' I.. I e/F I . . I T,,e,nj.! ' I I ! Tu n,I 'I I ' I ' Typetest! ITest ~iI I Ca~ng I I I ' I' ,, I P/F I ,', Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Worko~r O= Other (describe in notes) Test's Details Friday~ Jul_v 6, 2001: I traveled to Phillips Alaska Inc.'s 3Q Pad and witnessed MIT's on wells 3Q-15 and 3Q-21 following repair operations on these two wells. The pretest robing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with both wells passing the MIT's. Su, mmary: I witnessed successful MIT's on PAI's wells 3Q-15 and 3Q-21 in the Kupamk River Field / KRU, M.I.T.'s performed: 2 Attachments: Number of Failures: 0 Total Time during tests: 1 hr. c,c: MIT report form 5t12/00 L.G. MIT 3Q Pad KRU 7-6-01 JJ.xls 7/16/01 1' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO Alaska,/nc. FIELD /UNIT /PAD: Kuparuk/3Q DATE: 12/?/97 3Q-15 ~ F P SW/DSL ,6,~5, 7~/26~/J-55 2.~5 , 2¢7~ 2,750 ....... 2,~0 2,750 8:30 X 7, ~2 1626.25 1,500 2,250 2,~0 2~2~ :COMME~S: fni~a[ ~ing pressure obse~ed for ~ rain, ' ............. ,, ~ ~ ~,,, ,, .~ , COMMENTS: ' I i I I' I .... I'1 i '"" ' ' COMMenTS: ~ l I I i COM~T8: ......... COMMENTS: , TBG. ll~J. FLUID CODES F = FRESH WATER 1NJ. G = GAS INJ. S - SALT WATER I NJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSU RE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALYTEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. Grad. WELL TEST: DIESEL ! 0.00 Initiat GLYCOL [ 0,00 4 - Year X SALT WATER [ 0,00 Workover DRILLING MUD [ 0,00 Other ~ OTHER I 0.OO Dist~ibufio~: orig - Well Rte c- Opemlor c - Da~ba~e c:- Trip Fl~t File c - Inspector OPERATOR REP SIGNATURE: (Rev 9117/96) ARCO Alaska, Inc. Ancho~'age, Alaska 99510-0300 %elephone 907 2;/8 1215 April 6, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The well is listed below. WELL ACTION 3Q-15 Other (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Well Files (Atch only) FTR040696 (w/o atch) AR3B-6003-93 242 2603 STATE OF ALASKA AI_A~ OIL AND GJ~ C.,(~SERVATION COMMI,5 .~1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Plugging Perforate 6. Datum elevation (DF or KBi"-~ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic Service 4. LocalJon of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM RKB 60' 7, Unit or Property name Kuparuk River Unit 8. Well number 3Q-15 At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth 460' FNL, 723' FEL, Sec. 17, T13N, R9E, UM At total depth 385' FNL 706' FEL Sec. 17 12. Present well condition summary Total Depth: measured 7 4 8 0" true vertical 6 8 5 8' feet Plugs (measured) feet 9. Permit number/approval number 86-178 / 94-044 10. APl number 50-029-2166600 11. Field/Pool Kul3aruk River Oil Pool Effective depth: measured 7367' feet Junk (measured) true vertical 6763' feet 13. 14. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1850# POLESET 115' 115' Surface 3808' 9- 5/8" 1070 SX AS IV & 3845' 3777' Intermediate 250 SX CLASS G Production 7 41 7' 7" 330 SX CLASS G & 74 5 2' 68 4 5' Liner 175 SX AS I Perforation depth: measured 71 94',71 96',71 99',7201 ',7202',7222',7224',722 6',7228', 7230', 72 32', 72 34', 72 35 '-7252' true vertical 6617',6619',6621',6623',6624',6640',6642',6644',6646',6647', 6649', 6651 ', 66 51 '-6 66 6' Tubing (size, grade, and measured depth) 2 7/8" L-80 ABM set at 7092' ~ ~ C ~ ~V ~ ~ Packers and SSSV (type and measured deplfl) Camco HRP-1-SP @ 7062'~ Baker FVL @ 1786' Stimulation or cement squeeze summary Intervals treated (measured) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure Installed 2.31 Otix MCX Injection Valve on Baker 'N' Lock RePresentative Dailv Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 331 -- 1736 Subse( 0 0 1440 -- 2707 16. Status of well classification as: Water Injector ~ Oil Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned'~~ '~ * :'~~----~ 'l'itle Sr. Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE 'ARCO Alaska, Inc. Subsidiary of Atlantic Ricl~flelcl Company WELL Sr C~)NTRACTOR ~ ~ _~~. REMARKS '' ',~, ~U?AF, U~ PETR©L~.UM ENGINEEring, CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well ¢q-'~5'~ 1 L-06 ~f~ -(¢8 3N-08A 6b--i'~ 3Q-15 Action Variance (SSSV) Change Program (Inj Valve) Change Program (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED FEB 1 6 1994 Alaska 0il & Gas Cons, Commission Anchorage AR3B-6003-93 242-26O3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~>,~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program X Susper~l_ Operation Shutdown __ Re-enter suspended well __ Repair well _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance _ Pedorate __ Other __ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ..~ Exploratory _ Stratigraphic _ Service ~ 4. Location of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth 460' FNL, 723' FEL, Sec. 17, T13N, R9E, UM At total depth 385' FNL, 706' FEL, Sec. 17, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 7 4 8 0' true vertical 6 8 5 8' feet Plugs (measured) feet RKB 60' 7. Unit or Property name Effective depth: measured true vertical 7367' feet Junk (measured) 6763' feet Ca~ng Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Kuparuk River Unit 8. Well number 3Q-15 g. Permit number/approval number 86-178 / 92-255 10. APl number 50-029-2166600 11. Field/Pool Kuparuk River Oil Pool RECEIVED feet '! .fi 1994 I,,i~.$~ Oil & Gas Cons. Commission Anchorage Measured depth True vertical depth 8 0' 1 6" 1850# POLESET 115' 3808' 9-5/8" 1070 SX AS IV & 3845' 250 SX CLASS G 741 7' 7" 330 SX CLASS G & 7452' 175 SX AS I measured 115' 3777' 6845' 7194',71 96',7199',7201 ',7202',7222',7224',7226',7228',7230' 7232', 7234', 7235'-7252' true vertical 6617',6619',6621 ',6623',6624',6640',6642',6644',6646',6647' 6649', 6651 ',6651 '-6666' Tubing (size, grade, and measured depth) 2 7/8" L-80 ABM set at 7092' Packers and SSSV (type and measured depth) Camco HRP-1-SP ~ 7062', Baker FVL ~ 1786' 13. Attachments Description summary of proposal ~ Detailed operation program _ Install MCX Injection Valve BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name ~approver Date approved Service Water 17. I here!~y/certif~ th~ the~ for/~l~gojlng__is true and correct to the best of my knowledge. 15. Status of well classification as: Oil Gas _ Suspended Injector Title ,..~"~'. ~YTC~tt~',¢ FOR COMMISSION USE ONLY Date Z"tq Conditions of approval: Notify Commission so rePresentative may witness Plug integrity BOP Test _ Location clearanca __ Mechanical Integrity Test m Subsequent form require 10- ~'~ G~' IApproval No. ~,pproved by order of the Commission Original Signed By David W. Johnston ;~pproved Copy Returned Commissioner Date ~//~/'",~ y ~"~1 Ir~iill- I~.1 mnll~ll I~'~,~r~~ ~'1" Attachment 1 Request for Variance Kuparuk Well 3Q-15 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the surface controlled, subsurface safety valve in Injection Well 3Q-15 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of reservoir fluids. The proposed work is to install an injection valve to prevent uncontrolled flow by automatically closing if upward flow of fluids should occur. STATE OF ALASKA OIL AND GAS CO~SERVATI~ COMMI,~.~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well Perforate :~' Other X 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth 460' FNL, 723' FEL, Sec. 17, T13N, R9E, UM At total depth 385' FNL, 706' FEL, Sec. 17, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7480' feet Plugs (measured) 6858' feet 6. Datum elevation (DF or KB) RKB 60' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-15 9, Permit number/approval number 86-178 / 92-255 10, APl number 50-029-2166600 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical 7367' feet Junk (measured) 6 7 6 3' feet ~" 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 8 0' 1 6" 1850# POLESET 115' 115' 3808' 9-5/8" 1070 SX AS IV & 3845' 3777' 250 SX CLASS G 7417' 7" 330 SX CLASS G & 7452' 6845' 175 SX AS I measured 7194',7196',7199',7201',7202',7222',7224',7226',7228',7230', 7232',7234',7235'-7252' true vertical 6617',6619',6621',6623',6624',6640',6642',6644',6646',6647', 6649',6651',6651'-6666' Tubing (size, grade, and measured depth) 2 7/8" L-80 ABM set at 7092' Packers and SSSV (type and measured depth) Camco HRP-1-SP @ 7062', Baker FVL @ 1786' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & Gas 00ns. ~u,'i~missi0n Anch0rat~e Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~;7~ 2~ ~ O Tubing Pressure 3oG looo ~o 16. Status of well classification as: Water Injector . ~[ Oil Gas Suspended 2.500 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C, (,~,J, ~ Title Petroleum Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 11/20/92 TO 11/21/92 CPF-3 DS-3Q 3Q-15 11/2o/92 11/21/92 CONVERTED TO WATER INJECTION. CONVERTED TO WATER INJECTION. .~iaska Oil & r~as Cons. Oornmissio~'~ Anchorage STATE OF ALASKA 0 ~ ~ OIL AND GAS CONSERVATION COMMI~oiON APPLICATION FOR SUNDRY APPROVALS i. Type of Request: Abandon Suspend Alter casing _ Repair wel~-_ Change approved program X Pull tubing _ Variance 2. Name of Operator ~ 5. Type of Well: Development .~X ARCO Alaska, lDO. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM At effective depth 460' FNL, 723' FEL, Sec. 17, T13N, R9E, UM At total depth 385' FNL, 706' FEL, Sec. 17, T13N, R9E, UM 12. Present well condition summary Total Depth' measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Operation Shutdown _ Re-enter suspended well_ Plugging _ Time extension Stimulate Perforate Qther 7480 feet Plugs (measured) 6 8 5 8 feet None 7367 feet Junk (measured) 6 7 6 3 feet None 6. Datum elevation (DF or KB) Length Size Cemented RKB 60 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-15 9. Permit number 86-178 10. APl number 5o-029-21 666 11. Field/Pool Kuparuk River Field Kuparu_k River_Oil .PPgJ ECl:.ivt-D OCT t 3 !992 Alaska 0il & Gas 00ns. 6ommissi0~ Measured dept~!~lr~9~l~rtical depth 80' 1 6" 1850# POLESET 115' 115' 3808 9 5/8" 1070 SX AS IV & 3845' 3777' 25O SX CLASS G 741 7 7" 330 SX CLASS G & 745 2' 6 845' 175 SX AS I measured 71 94',71 96',7199',7201',7202',7222',7224',7226',7228',7230', 7232',7234',7235'-7252' true vertical 6617',6619',6621',6623',6624',6640',6642',6644',6646',6647', 6649',6651 ',6651 '6666' Tubing (size, grade, and measured depth) 2 7/8" L-80 ABM set at 7092' Packers and SSSV (type and measured depth) Camco HRP-1-SP @ 7062', Baker FVL @ 1786' 13. Attachments Description summary of proposal _X Detailed operation program BOP sketch _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: October, 1992. Oil ,, Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-W- ~ Title Petroleum Engineer FOR COMMISSION USE ONLY Date JO/Z.I / c~ ~ Conditi°ns of approval: Notify Commission so representative may witness Plug integrity_ BOP/Test_ Location clearance__ Mechanical Integrity Test_.L/ Subsequent form require Approved by order of the Commission ORIGINAL SIGNED BY RUSSELL A, DOUGLASS IApproval No. . ~. ., ,, :~ ',: :,"J I I/,oy.,,,,_.:.,: Commissioner Date Form 10-403 Rev 09/12~90 SUBMIT IN TRIPLICATE Well 3Q-15 Conversion to Water Injection ARCO Alaska requests approval to convert Well 3Q-15 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7100' and 7275'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Alaska Oil & Gas Cons, KUPARUK WELL 3Q-15 APl #: 500292166600 SPUD DATE: 11/20/86 ADL LEASE: 25512 COMPLETION DATE: 08/13/87 PERMIT #: WORKOVER DATE: 86-178 ORIGINAL RKB: SURFACE LOCATION: 2295'FNL,1959'FEL,SEC17,T13N,RgE TOP OF KUPARUK: 545'FNL,821'FEL,SEC17,T13N,R9E TD LOCATION: 385'FNL,706'FEL,SEC17,T13N,R9E All depths are MD-RKB to top of equipment unless otherwise noted 60 TUBING SPOOL: 34 PAD ELEVATION: WELLTYPE: PRODUCER 23 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 115 9.625" 36# J-55 3845 7" 26# J-55 7452 2.875" 6.5# L-80 ABM 7092 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.31" 1786 WRDP OTIS K 1.2" SBR CAMCO OEJ 7042 PKR CAMCO HRP-I-SP 7062 NOGO CAMCO 'D' NIPPLE 2.25" 7079 SHROUT CAMCO PE-500 7091 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 33 HOLE ANGLE THRU KUP: 32 LAST TAG DATE: 07/20/92 RATHOLE: -8 FISH/OBSTRUCTION: deg deg DEPTH 3000 6200 7244 PBTD: PBTDSS: 7367 6694 ] ::::::.::::-.:...:.-.:.:.:.,:.:.:.:.:.:. -. :.:.::: :-:-:.:.. ============================================================ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:.:.:.:.:.:.:.:.:.::.:.:.:.:.:.:-:.:.:-:.:.:.-.:.:...:-:-:-:.:-: ............................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ................................. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:.:-:.:-:.:.:.:.:-:.:.:-:-:.:-:-:.:.:.:.:.:.::.:.:.:-:.:.:-:.:-:. :.:.:.:-:.:.:.;-:-:-:-:.:.:-:-:,:.:.:.:.::.:-.:-:.:.:-:.:.:.:-:-: .:.:.:.:.:.;.:.:,:.:.:.:.;.:.:.::.:.:-:.-.,.::-::.:-:-:..-.,.... ................._............., ....... ................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::: ::::::;:::::::::::.. ::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: b STN 1 2 3 4 5 6 GAS LIFT and FLOW INFORMATION VALVE PORT DEPTH MANDREL SIZE SIZE 2557 MCMURRY HUGHES 1" 0.188 4402 MCMURRY HUGHES 1" 0.188 5611 MCMURRY HUGHES 1" 0.188 6282 MCMURRY HUGHES 1" .DV 6636 MCMURRY HUGHES 1" 0.188 6991 OTIS LB 1.5" 0.25 REEEIVED OCT 2 1992_ Ala a Oil .& Gas Cons. 6ommisslo~ Anchorage INTERVAL 7174-7204 7212-7232 7232-7252 PERFORATION DATA ZONE FT SPF PHASE COMMENTS A3 30 6 0 2-1/8" ENERJET II A2 20 6 0 2-1/8" ENERJET II A1 20 6 0 2-1/8" ENERJET II REVISION DATE: 10/20/92 REASON: P RE-CO N VE RS ION ADDENDUM WELL' 8/18/87 3Q-15 RU 1-1/2" CTU & pumper. Test BOP & lines to 4000 psi, ok. RIH w/1.75" jet nozzle to _+6990' while pumping minimum rate. Unable to work past 1-1/2" GLM, POOH. PU 2" nozzle & bend pipe, RIH while pumping minimum rate. Tag sand @ 7200'. Increase rate to 1.75 BPM & start N2 @ 350 scf/min. Wash hard streaked sand to PBTD @ 7367' while holding 250 psi back pressure. Circulate 100 bbls gelled diesel while recipro- cating f/PBTD to tubing tail. Displace with clean diesel and POH. RD and secure well. Turned well over to Production. sor 1. Type of Request: 2. Name of Operator ARCO Alaska1 Inc. 3. Address STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 549' FNL, 779' FEL, Sec. 17, T13N, R9E, UM At effective depth 460' FNL, 723' FEL, Sec. 17, T13N, R9E, UM At total depth 408' FNL, 691' FEL, Sec. 17, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 12. Other 6. Datum elevation (DF or KB) RKB 60 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-15 feet 9. Permit number/approval number Verbal approval from Mr.L.Smith 10. APl number 50-029-21666 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7194', 7196', true vertical 6617', 6618', 7480' MD feet 6858' TVD feet 7367' MD feet 6763' TVD feet Plugs (measured) None Length Size Cemented Junk (measured) Fill @ 7171' Measured depth True vertical depth 80' 1 6" 1850# Poleset 115' MD 115' TVD 3808' 9-5/8" 1070 Sx AS IV & 3845' MD 3777' TVD 250 Sx Class G 741 7' 7" 330 Sx Class G & 7452' MD 6845' TVD 175 Sx AS I measured 7199', 7201', 7202', 7222', 7224', 7226', 7228', 7230', 7232', 6621', 6623', 6624', 6640', Tubing (size, grade, and measured depth) 2-7/8", L-80, tubing w/tail @ 7092' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7062' & FVL SSSV @ 1786' 6642', 6644', 6645', 6647', 6649', 13. Stimulation or cement squeeze summary "A" Sand refracture stimulation performed on 8/7/88 Intervals treated (measured) 7194'-7251' MD Treatment description including volumes used and final pressure 87,000 lbs of 16/20 Carbo Lite proppant. 1190 bbls of diesel/gelled diesel pumped. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 5O0 25O 0 12OO Subsequent to operation 800 400 0 1200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 7234' 6651' Signed ~ /~_J/v/,3~~~Title Sr. Operations Engineer 10-4~4~VV 5/88 Form 06/1 Tubing Pressure 150 135 Date 9/22/88 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Com,r · :LL i~BDT tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL ~EI1VI~E, Ilr...r'~Jn I qONTRACTOR REMARKS I.J PLA e~....<,/cr¢ bC~.,d, E¢o/pMMr'. P/~ ~M ~~ our;. ["'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp, Chill Factor Visibility I WindVel, Report I °F °F miles knots [signed ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 3 3 '3 ''3 ~3 1 '3 1 1 F- 1 3 Kuparuk Fluid Level Report 8 - 2 7- 8 8 Casing K - 1 8 Kuparuk Fluid Level Report 8 - 2 7- 8 8 Tubing B - 1 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing Q- 15 Kuparuk Fluid Level Report 8 - 2 7- 8 8 Casing N-08A Kuparuk Fluid Level Report 8-26-88 Casing - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing - 1 2 Kuparuk Fluid Level Report 8- 2 6- 8 8 Casing K- 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing I - 0 3 Kuparuk Fluid Level Report 8- 2 6 - 8 8 Casing Y- 0 6 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Both Sands Y- 0 7 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska ....... Date;,.~t Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Date: August 12, 1988 Transmittal #: 7257 RETURN TO: ARCO Alaska, inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted. herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 31- 1 2 Kuparuk Well Pressure Report 6- 1 5-88 Amerada 1 G-04 Kuparuk Well Pressure Report. 7 - 1 6 - 8 8 Amerada 2T-06 Post Frac Job Report 7- 1 8-88 Allo Frac A-10 3Q-15 Kuparuk Stimulation Summary 8-07-88 #230DS36QL 3J-10 kuparuk Stimulaiton Summary 8-08-88 #230DS36JL 2V-ll Kuparuk Stimulation Summary 8-03-88 #230DS28VL 1 R- 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing 1 F- 0 7 .. Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing 2 D- 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: 7194 RETURNTO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 1L~16 2D-05 2A-06 2W-09 3K-02 2G-07 2G-07 3B-06 3Q-15 Kuparuk Well Pressure'Report Water Injection Spinner Data Sheet Water Injection Spinner Data Sheet Gas Injection Spinner Data Sheet Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressfire Report 6-02-88 PBU - Sand A 6-08-88 Both Sands 6-09-88 Both Sands 6-08-88 Both Sands 6-10-88 Tubing 6-10-88 Tubing 6-14-88 Casting 6-06-88 Static - Sand A 5-15-88 PBU - Both Sands Naska 0il & Gas Cons. Commission edged: Anchom~gp ..................... Date' DISTRIBUTION: D&M State of Alaska Chevron Mobil Unocal SAPC STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION L,,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Welt OIL ~[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-178 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21666 4. Location of well at surface 9. Unit or Lease Name 2295' FNL, 1989' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 549' FNL, 779' FEL, Sec.17, T13N, R9E, UM 3Q-15 At Total Depth 11. Field and Pool 408' FNL, 691' FEL, Sec.17, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 60'I ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/20/86 11/25/86 04/26/87*I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+FVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7480'MD, 6858'TVD 7367'MD, 6763'TVD YES ~ NO [] 1786' feet MDI 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CBL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115 ' 24" 1850# Pol eset 9-5/8" 36.0# J-55 Surf 3845' 12-1/4" 1070 sx AS IV & 250 sz Class G 7" 26.0# J-55 Surf 7452' 8-1/2" 330 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached. 2-7/8" 7092 ' 7062 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adderldumr dated 5/5/87 for fracture clara. , 27. N/A PRODUCTION TEST , Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Al&S~ Oil 8, G&s Co~S. commis-si WNote: Drilled RR 11/26/86. Tubing run 1/15/87. Perforated well 3/6/87. Fractured well 4/26/87. Workover was performed 8/13/87. , Form 10-407 WC3/6~ :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 7171' 7179' 7179' 7276' TRUE VERT. DEPTH 6597' 660~' 6604' 6686' 31. LIST Of: ATTACHMENTS Addendum (dated 5/5/87) Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Date 9-Z4-87 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 3Q-15 Item #24: Perforations MD TVD 7194 7196 7199 7201 7202 7222 7224 7226 7228 7230 7232 7234 7235 -7252' 6617 6619 6621 6623 6624 6640 6642 6644 6646 6647 6649 6651 6651 -6666' Perforated w/1 spf WC3/69a 9/22/87 GaS Cons. Comm'msio~ STATE OF ALASKA AL, ,A OIL AND GAS CONSERVATION CO .,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing,~ m Other ~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A1 aska, I nc. RKB 60' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 2295' FNL, 1989' FEL, Sec.17, T13N, R9E, UM At top of productive interval 549' FNL, 779' FEL, Sec.17, T13N, RgE, UM At effective depth 460' FNL, 723' FEL, Sec.17, T13N, R9E, UN At total depth 408' FNL, 691' FEL~ Sec.17~ T13N~ R9E~ UN 11. Present well condition summary Total depth: measured 7480 'MD true vertical 6858'TVD Effective depth: measured 7367 'MD true vertical 6763 'TVD 7. Well number 3Q-15 8. Approval number 7-408 9. APl number 50-- 029-21666 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) Fill ~ 7167' feet Casing Length Size Conductor 80' 16" Surface 3808 ' 9-5/8" Producti on 7417 ' 7" Cemented Measured depth 1850# Poleset 115'MD 1070 sx AS IV & 3845'MD 250 sx Class G 330 sx Class G & 7452'MD 175 sx AS I True Vertical depth 115'TVD 3777 'TVD 6845 ' TVD Perforation depth: measured 7194 ' 7196 ' 7199 ' 7201 ' 7202 ' 7222 ' 7224 ' 7226 7228 ' 7230 ' 7232 ' 7234 ' true vertical 6617 ', 6618 ' 6645', 6647' Tubing (size, grade and measured depth) 2-7/8", L-80, tubing w/tail ~ 7092' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7062' & FVL SSSV ~ 1786' , 6621 ' 6623' 6624' 6640' 6642' 6644' , 6649', 6651' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well Hi story) Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85J Title Associ ate Engineer (Dani) SW02/75 Date Submit in Duplicate Al-, J Oil and Gas Company ~) Well History- Initial Report- Daily Instructions: Prec, are and submit the "Initial Report" o~ the first Wednesday ariel a 'hell is spudceCony.Orlw°r~'°ver operahons are sta,'led. Daily work prior to sp~ddOing should be summarized on the form giving inclusive dales . District ]County par,sh or borough Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25512 Auth. or W.O. no |Title AFE AK1690 I Completion Nordic #1 API 50-029-21666 Istate Alaska Well no. 3Q-15 Operator IARCO WI ARCO Alaska, Inc. SpuddedorW.O. begun IDate IHour Pr,orstalusifaW.O. Workover 7/27/87 1800 hrs. Dale and depth as of 8:00 a.m. 7/28/87 7/29/87 7/30/87 7/31/87 8/01/87 thru 8/03/87 8/04/87 Complete record for each day reported The above is correct 56.24% 7" @ 7452' 7367' PBTD, RIH w/fsh'g string 10.0 ppg NaCl/NaBr Accept rig @ 1800 hfs, 7/27/87. Bleed off tbg & ann press thru choke. RU CTU, MU OS/fsh'g assy & RIH. 7" @ 7452' 7367' PBTD, 2699' TOF, POOH w/spear 10.0 ppg NaCl/NaBr RIH; unable to wrk thru SSSV, POOH. Redress OS, RIH, tag fsh @ 2697', POOH; no rec'y. RIH w/spear; rec'd 22' braided in & 20' S/L. RIH w/OS, tag fsh @ 2699', POOH; no rec'y. RIH w/spear, WO fsh, POOH. 7" @ 7452' 7367' PBTD, 2725' TOF, POOH w/FTA #10 10.0 ppg NaC1/NaBr Fin POH w/spear; no rec'y. MU FTA #6, RIH, tag fsh & POOH; rec'd 10' SL. RIH w/FTA #7, tag fsh, POOH; rec'd 1' SL. RIH w/FTA #8, tag fsh, POOH; no rec'y. RIH w/FTA #9, tag fsh, POOH; no rec'y. RIH w/FTA #10, tag fsh @ 2714', POOH; rec'd 25' SL. RIH w/fTA #10, tag fsh @ 2725', POOH. 7" @ 7452' 2676' TOF, POOH w/FTA #17 10.0 ppg NaC1/NaBr Cont fsh'g operations; rec'd total of 33' S/L. (spear), tag fsh @ 2676', POOH. RIH w/FTA #17 7" @ 7452' 6349' TOF, RIH w/Imp Blk 10.0 ppg NaC1/NaBr Cont fsh'g operations. Rec'd entire fish (24'8") & rec'd total of 3895' SL. Cont fish'g for remaining SL. TOF @ 6349'. Rec'd line cutter (3.5'). Rn'g IB. 7" @ 7452' 6349' TOF, POOH w/FTA #23 10.0 ppg NaCl/NaBr Cont fish'g operations; rec'd 5' cutter bar. f/6368'-6392', wrk OS, POOH w/FTA #23. Wsh frac sand For form preparation and distribulion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D INumberall daily well hislory forms consecutively Page. no. as they are prepared for each well. I ARC~. ,.)il and Gas Company ~> Daily Well History--Interim Instructions: This form {5 used Curing drilling or workover operations If testing, coring or perforating, show ferma~ion name in d¢-scr~bmg v,'ork pertormed. Number all drill stem tests sequentially. Attach description of a!l cores Work per[ormed by Producing Section will be reported on "Interim" sheels unlH final completion. Report officia~ or representa[ive test on "Final" form. 1) Submit "Interim" sheets ,,,,hen hlled ou~ bul not less frequently than every 30 days. or 2) on Wednesday of the week m which oil string is set. Subm t week y for workovers and fo owing settmg of oil str nG unlil completion. District Field ICountyor Parish Alaska North Slope Borough state Lease or Unit Kuparuk River ADL 25512 Alaska Date and dept. as of 8:00 a.m. 8/05/87 8/06/87 8/07/87 8/08/87 thru 8/lo/87 8/11/87 Complete record for each day while drilling or workover in progress 7" @ 7452' 6401', POOH 10.0 ppg NaCl/NaBr POOH w/FTA #23; rec'd 26" cutter & 3' S/L. Rn impression block; showed wire & sand. RIH w/FTA #24, tag fill @ 6345', wsh sand to 6394', POOH; rec'd 5' cutter bar & 1' S/L. RIH w/FTA #25, tag @ 6391', wsh to 6401', CBU, wt up to 10.0 ppg. POOH. 7" @ 7452' 6401', RIH w/bailer 10.0 ppg NaCl/NaBr Circ hi vis sweep, POOH. RIH w/FTA #26, att to wsh dn w/o success. RU WL, rec'd 18' wire, pieces of grapple & 7' wire. Bail sand & rec'd grapple pieces. 7" @ 7452' 6385' (tbg meas.), RIH w/bailer 10.0 ppg NaC1/NaBr Fish/wireline unit. Recovered grapple pieces, sand and 1-1/2' of wire. RIH w/overshot on 1-1/4" tbg. No recovery. RU Otis and recovered cutter bar and 11' of wire. Bail sand. 7" @ 7452' 6955', RIH w/mule shoe 10.0 ppg NaCl/NaBr Bailed sand & metal shavings w/~. RU BOPE. RIH w/overshot. Tagged fish @ 6392'MD. CBU, POOH. Rec'd 5' cutter bar. RIH w/mule shoe & wash sand f/6393'-6455'MD. Wash & circ. sand out to 6673'MD. POOH. RU Otis. Fish out 274' wire w/Otis. RD Otis. RIH w/overshot. Tagged fish @ 6673'. POOH. Rec. fish #8. RIH w/overshot. Wash sand f/6670' to fish @ 6955'. POOH, rec. fish #9. RIH w/mule shoe. 7" @ 7452' 7167', RD Otis slickline 10.0 ppg NaC1/NaBr RIH. Washed sand to 7167'. Circ. & pump sweep. POOH. LD 1-1/4" tubing. RU Otis and set blanking plug @ 7105'. Retrieve dummy valve @ 7028'. RD Otis. RU CTU BOPs. The above is correct For form preparation and dis'tribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date / Tille AR3B-459-2-B Drilling Superintendent Number all daily well hislory forms conseculively jJPagef°~ as hey are prepared for each well. AR~.,,J Oil and Gas Company '~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on *.he first Wednesday after aHo',',ab~e has been assigned or ','.'ell is Plugged, Abandoned, o~ Sold "Final Report" should be submitted also when operations are suspended for an indefmite or appreciable length of time. On workovers wheh an official test is not required upon compietion, report completion and representative tea; data in blocks provrded The "Final Reporl" form may be used for reporting the entire operation if space Js available. I Accounting cost center code District ICcunty cr Parish [Slate I Alaska North Slope Borough I Alaska Fieid Lease or Unit 'Well no. Kuparuk River ADL 25512 3Q-15 Auth. or W.O. no. Title AFE AK1690 Completion Nordic Operator IA.R.Co. W.I ARCO Alaska, Inc. 56.24% Spudded or W.O. begun JDate Workover I 7 / 27 / 87 Date and depth Complete record for each day reported as of 8:00 a.m. 8/12/87 8/13/87 8/14/87 API 50-029-21666 Iotal number of wells (active or inactive) on this PSt center prior to plugging and bandonment of this well our 1800 hrs. J Prior status if a W.O. 7" @ 7452' 7167', POOH, standing back tubing 10.0 ppg NaC1/NaBr Displaced well to brine. ND CTU BOPs. NU 7" BOPS & tested to 2500 psi. RU Otis and retrieve blanking plug. RD Otis. Spear tubing. LD hanger. MU storm packer & hang tubing off @ ±60'. ND BOPs. NU & test BOPs to 3000 psi. POOH, stand back tubing. 7" @ 7452'~ Running 2-7/8" completion 10.0 ppg NaC1/NaBr POH w/2-7/8" tbg. Strip seals off OEJ. Reverse circulate clean brine in hole. Pulled packer. Run 2-7/8" completion. 7" @ 7452'MD Rig released 6.8 diesel Ran 218 its. 2-7/8" tubing to 7092', SSSV @ 1786', & HRP-1-SP pkr @ 7062'. Installed B?V. ND BOPE. NU tree & tested. Displaced well w/diesel. Released tis @ 1900 hrs., 8/13/87. Moved rig to 3I pad. Old TO New TD Released rig Date 1900 hrs. 8/13/87 PB Depth IK nd of rig Rotary Classifications {oil. gas, etc.} Oil Producing method IType completion (single, dual, etc.) Single Official rose.pit name(s) Kuparuk Sands Flowing Potential rest data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected The above is correct Signatur(M~ . ~ _/ Date Title , /~d~~_~ ~-~, J ~/'~//'~ Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C JNumberall dally well hislory forms consecutively Page no_ I as they are prepared for each ?,'ell. J 3 I gl'vllJon of AllanlicRIchlleldCompan¥ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing -- Time extension :_' Change approved program .:_ Plugging .'~ Stimulate ~i!C~ Pull tubing'~. Amend order ::_ Perforate- Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc RKB 60' 3. Address 6. UnitorProperty name P. 0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 2295' FNL, 1989' FEL, Sec.17, T13N, RgE, UM At top of productive interval 549' FNL, 779' FEL, Sec.17, T13N, RgE, UM At effective depth 460'deFp~~ 723' FEL, Sec 17, T13N, RgE, UM At total ' ' 408' FNL, 691' FEL, Sec.17, T13N~ R9E~ UM 11. Present well condition summary Total depth:- measured 7480 ' MD feet true vertical 6858 ' TVD feet 7. Well number 3Q-15 8. Permit number 86-178 9. APl number 50-- 10. Pool Kuparuk River Oil Plugs (measured) None Pool Effective depth: measured 7367 'MD feet true vertical feet 6763 ' TVD Casing Length Size Conductor 80' 16' Surface 3808' 9-5/8" Producti on 741 7 ' 7" Cemented 1850# Poleset 1070 sx AS IV & 250 sx Class G 330 sx Class G & 175 sx AS I Junk(measured) Various wireline tools from 2745' to 7000' Measured depth True Vertical depth 115'MD 115'TVD 3845'MD 3777'TVD 7452'MD 6845'TVD Perforation depth: measured 71 94', 71 96', 71 99' 7230', 7232' 7234' true vertical 6617', 6618', 6621 ' 6647', 6649', 6651 ' Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 71 28' , 7201 ' 7202' 7222' 7224' , 6623' , 662.~', 6640' .... '~ ::." ;v :' ~-.~ , 7226' 7228' , 6642', 6644', 6645' Packers and SSSV (type and measured depth) HRP-I-SP okr ~ 7097' FVI ~V ~ l?qn, ~ .... .,. :.~'..',¢. ......... 12.Attachments Descri'ption summary-of Proposal' ' ¢"' "' ~"~u "' ' ,~,¢_cBe;taifed..op,,eraftons program '~ BOP sketch feet 13. Estimated date for commencing operation July 25, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L/~//c'}~.~"'~ .t/.L['!.(/_i.,~.'~ . TitleA~Q¢i,~e gngi Only (,IW~ Commission Use Conditions of approval Notify commission so representative may witness ~'Appro~al No. ~ Plug integrity ~ BOP Test ~ Location clearanceI Approved by'~ ~ ~:;-'- .. ~ .c Approwd C~,p? R,~tume~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate KRU 3Q.-!.5 WELLHEAD CHANGE OUT AND TUBING CLEAN OUT PRELIMINARY PROCEDURE RIG OPERATIONS 1. Move in, rig up workover rig. 2. RU coiled tubing BOPE and test. 3. PU 1-1/4" DP and fish wireline tools. 4. ND tree. NU rig BOPE and test. 5. Set standing valve in "D" nipple. 6. POH 2 stands 2-7/8" tubing. 7. Set RTTS i stand down. ND BOP. 8. Change out tubing spool. 9. NU BOP and test. POH with tubing. 10. Replace SSSV and GLM's and rerun completion assembly, 11. Land tubing. ND BOP's. NU tree. 12. Displace well to diesel. 13. Release rig. NON-RIG OPERATIONS 1. Move in, rig up slickline unit. 2. Pull plug from "D" nipple. 3. Clean out to PBTD w/coiled tubing unit. 4. Refrac well. SA2/54b 06/19/87 ANNULAR PRE GENTER PIPE RAHS 4 BLIND RAHS 5 TUBIN6 HEAD 1. 16" CONDUCTOP SWAGED 1'0 9-5/8" 2. 11"-3000 PSt STARTING HEAD 3. ! 1"-30(10 PSI X 7-1/I6"-5000 PSI TUBING HEAD 4. 7-1/~8" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMUI. ATOR CAPACITY TEST 1. CHECK ANO FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WI TH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LC~VER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRESSURE. 8.OR 5TACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCzEWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TES- PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DO~'N SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSi AND H~D F~ 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND H~D F~ 10 MINUTES, BLEED T0 ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RA~S. 7, INCREASE PRESSURE T0 ~000 PSi AND H~D F~ 10 ~INUTES. 8. CLOSE VALVES DIRECTLY UPSTP. EAM OF CHOKES. BLEED DOWNSTREAM P~ESSURE TO ZERO PSI TO TEST VALVES, TEST REHAINING UNTESTED MANIFOLD VALVES, IF ANY, 'WITH 3000 PSi UPSTREAH 0F VALVE AND WITHZE~ODSIDOWNST~EAM. BLEED SYSTEM TOZERODSI. 9. OPENPlPE~AMS. 8ACKOFF PUNNING JOINT AND PULL OUTOFHOLE CLOSE BLIND PAMS AND TEST T0 3000 PSi FOR 10MINUTES, BLEED TO ZE~0 PSI. 10.0PEN BLIND RAMS AND RECOVER TE$T PLUG, MAKE SURE MANIFOLD ~INE~ APE FULL 0F ARCTIC DIESEL AND ALL VALVES AP.E SET IN THE D~ILLING POSITION. I 1 TESTSTANDPlPE VALVE~ TO ]000 PSI. 12. TE~T KELLY COCKS AND INSIDE ~OP TO 3000 PSi WITH KOOMEY DU~P ~3. REC0PD TEST INFORMATION ON BLOWOUT,~EVENTER. T~ST.. ¢~PM, ., ,, S'~*':.: , AND S NO 14. PENFOPM C~?~ ~B~,DE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAIkYq, . - . . .,-.¢~ ~O~~ JO dULY 28, 1986 (NORDIC RIG 9-5/8") STATE:OF ALASKA ALASK~ OIL AND GAS CONSERVATION t,,~MMISSION . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-178 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21666 ~4. Location of well at surface 9. Unit or Lease Name 2295' FNL, 1989' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 549' FNL, 779' FEL, Sec.17, T13N, R9E, UM 3Q-15 At Total Depth 11. Field and Pool 408' FNL, 691' FEL, Sec.17, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 60'I ADL 25512 ALK 2553 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 11/20/86 11/25/86 04/26/87* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+q-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7480'MD, 6858'TVD 7367'MD, 6763'TVD YES ~] NO []I 1790' feet MD 1600' (approx.) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, CaL, CBL, GCT -23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 115' 24" 1850# Pol eset 9-5/8" 36.0# J-55 Surf 3845' 12-1/4" 1070 sx AS IV & 250 sx (:lass G 7" 26.0# J-55 Surf 7452' 8-1/2" 330 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7128' 7097' See attached. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached addeldum, dated 5/5/87 for fracture ara 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 IGAS-OIL RATIO TEST PERIOD II~ FlowTubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None [',.,sl,'~.",; 1 :) !987 Alaska Oil & ~a.s '..,,: .... ~ .... -,'<0.~'~r;'" * NOTE: Drilled RR 11/26/86. Tubing run 1/15/87. Perforated well 3/6/87. Form 10-407 WC263 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ _/' 29.. . 30. ' GEOLOGIC MARKEF~S FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C .71.71' 6597' N/A Base Kuparuk C 7179' 6604' Top Kuparuk A 7179' 6604' -' '~ .... Base Kuparuk A 7276' 6686' : ! , · . 31. LIST OF ATTACHMENTS Addendum (dated 5/5/87) . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig ned__~ (~/7~/~(.~./ ~ "'~'/~ TitleAssOci ate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such 'interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Wel 1 Completion Or Recompletion Report and Log 3Q-15 (cont'd) Item #24: MD 7194 7196 7199 7201 7202 7222 7224 7226 7228 7230 7232 7234 7235 Perforations TVD 6617 6619 6621 6623 6624 6640 6642 6644 6646 6647 6649 6651 -7252' 6651 -6666' Perforated w/1 spf WC2/63a 05/13/87 ADDENDUM WELL: 4/26/87 3Q-15 Frac Kuparuk "A" sand perfs 7194' 7196' 7199' 7201' 7202', 7222', 7224', 7226', 7228', 7230', 7232', 7234' & 7235'-7252' in 13 stages per frac procedure dated 4/21/87 as follows: Stage 1: 40 bbls 104° diesel w/5% Mu$ol @ 5 BPM, 3220-2860 psi Stage 2: 100 bbls gel diesel @ 12 - 20 BPM, 4830 - 6300 - 3730 psi Stage 3: 100 bbls gel diesel @ 20 BPM, 3730 - 3530 psi Stage 4: 8 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 3530 - 3470 psi Stage 5: 292 bbls gel diesel @ 20 BPM, 3470 - 3400 psi Stage 6: 18 bbls gel diesel 2 ppg 20/40 @ 20 BPM, 3400 - 3180 psi Stage 7: 18 bbls gel diesel 3 ppg 20/40 @ 20.5 BPM, 3180 - 3130 psi Stage 8: 34 bbls gel diesel @ 4 ppg 20/40 @ 20.5 BPM, 3130 - 2900 psi Stage 9: 35 bbls gel diesel 5 ppg 20/40 @ 20.5 BPM, 2900 - 2610 psi Stage 10:30 bbls gel diesel 6 ppg 20/40 @ 20.5 BPM, 2610 - 2400 psi Stage 11:15 bbls gel diesel 7 ppg 20/40 @ 20 BPM, 2400 - 2330 psi Stage 12:15 bbls gel diesel 8 ppg 20/40 @ 20 BPM, 2330 - 2300 psi Stage 13:42 bbls gel diesel flush @ 20 BPM, 2300 - 1700 psi Gained 315 bbls fluid in flow tank @ end of flush. Refrac required. Drilling Supervisor Date Wel 1 Completion Or Recompletion Report and Log 3Q-15 (cont'd) Item #24: MD 7194 7196 7199 7201 7202 7222 7224 7226 7228 7230 7232 7234 7235 Perforations TVD -7252' 6617 6619 6621 6623 6624 6640 6642 6644 6646 6647 6649 6651 6651 -6666' Perforated w/1 spf WC2/63a 05/13/87 SUB. SURFACE DIRECTIONAL SURVEY [~UIDANCE r~ONTINUOUS r-~OOL Company , Well Name Field/Location ARCO ALASKA, INC. i I · 3Q-15{2295' FNL, 1989' mm i KUPARUK, NORTH SLOPE, FEL,SEC ALASKA 17,T13N~R9E,UM) Job Reference No. 72158 Loaaed By: Date 21-DEC-86 Computed By: WEST KRUWELL GCT DIRECTIONAL SURVEY CUSTaMER LISTING FOR ARCO ALASKA, INC. 3Q-15 KUPA~UK F~CRTH SLOPE,ALASKA SURVEY DATE: 21-12-86 ENGINEER: T. WEST METHODS OF COMPUTATION T30L LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 33 DEG 42 MIN EAST ARCO ALASKA, INC. 3Q-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 8-JAN-87 INTERPOLATED VALUES FOR EVEN 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -60.00 100.00 100.00 40.00 200.00 200.00 140.00 300.00 300.00 240.00 400.00 400.00 340.00 500.00 500.00 440.00 600.00 599.99 539.99 700.00 699.99 639.99 800.00 799.99 739.99 900.00 899.98 839.98 1000,00 999,98 ~ 939.98 1100,00 1099,98 1039,98 1200,00 1199,98 1139,98 1300.00 1299.98 1239,98 1400.00 1399.98 1339.98 1500.00 1499.98 1439.98 1600,00 1599.98 1539,98 1700,00 1699.98 1639.98 1800,00 1799,98 1739,98 1900.00 1899,98 1839,98 2000,00 1999.98 1939.98 2100,00 2099,98 1039.98 2200,00 2199.98 2139.98 2300.00 2299.97 2239.97 2400.00 2399,94 2339,~4 2500,00 2499.$8 2439.~8 2600.00 2599.83 2539.83 2700.00 2699.77 2639.77 2800.00 2799,63 2739.63 2900.00 2898.94 2838.94 COURSE VERTICAL DOG.LEG DEVIATION &ZiMUTH SECTION SEVERI'TY DEG MIN DEG MIN FEET DEG/IO0 0 0 N 0 0 E 0.00 0,00 0 3 N 85 39 W -0,02 0.32 0 3 S 11 44 E -0.08 0,18 0 6 S 74 9 E -0,08 0,15 0 8 N 87 23 E 0.04 0.18 0 16 N 88 22 E 0.24 0,26 0 27 $ 89 56 E 0,62 0.30 0 30 S 84 40 E 1,04 0,08 0 27 S 83 34 E 1,45 0,21 0 22 S 79 39 E 1,76 0,30 0 14 S 74 24 E 1.96 0,06 0 10 S 62 49 E 2,05 0,14 0 9 S 61 44 E 2,08 0,10 0 9 S 61 38 E 2.10 0.25 0 10 S 64 22 E 2.13 0.14 O 6 S 51 22 E 2,16 0,14 0 4 S 39 0 E 2,13 0,07 0 4 S 25 53 E 2,08 0.02 0 2 S 3 23 E 2.02 0.14 0 3 S 3 46 E 1.95 0.29 0 2 S 51 13 W 1,88 0,08 0 4 S 89 43 E 1,86 0,23 0 33 N 65 47 E 2.26 0,42 1 7 N 58 47 E 3.50 0.62 1 42 N 4T IT E 5.85 0.44 1 46 N 44 17 E 8.87 0,13 2 1 N 46 40 E 12.19 0.28 1 53 N 64 44 E 15.33 0.37 4 44 N 61 8 ~ 19,80 4,22 3 38 N 35 46 E 30.39 3.73 10 54 N 43 39 E 46.68 3.24 13 56 N 33 43 5 67.85 17 51 N 34 16 E 95.43 4.03 20 8 N 40 21 = 128.31 0.50 21 5 N 36 2 ~ 163,04 2,95 23 30 N 32 18 E 200,89 2,67 26 7 N 32 4.3 = 242.92 2,32 28 20 N 34 7 ~ 288.71 2.23 30 32 N 35 45 E 337.81 2.13 31 9 N 36 1 E 389.46 0.47 3000.00 2997.50 2937.50 3100.00 3095.19 3035.19 3200.00 3191.29 3131.29 3300.00 3285.67 3225.67 3400.00 3379.39 3319.39 3500.00 3471.93 3411.93 3600.00 3562.65 3502.65 3700.00 3651.54 3591.54 3800.00 3738.64 3078.64 3900,00 3824.24 3764,24 DATE OF SURVEY: 21-12-85 KELLY BUSHING ELEVATION: ENGINEER: T. WEST MEASURED DEPTH RECTANGULAR CRORDINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FE ET FEET F E ET 0.00 N 0,00 E 0,00 0.26 N 0,42 W 0,50 O, 18 N 0.42 W O, 46 0,13 N 0,34 W 0,36 0.12 N 0.10 W 0.15 0.13 N 0.23 E 0.27 0.13 N 0.93 E 0.94 0.08 N 1.76 E 1.76 0.00 5 2.63 E 2.63 0.12 S 3.34 E 3.34 0.23 S 3.87 E 3.88 0.36 S 4.24 E 4.25 0.50 S 4.50 E ~.52 0.64 S 4.75 E 4.79 0.77 S 4.99 E 5.05 0.90 S 5.23 E 5.31 1.01 S 5.35 E 5.45 1.12 S 5.42 E 5.54 !,22 S 5.46 E 5.60 1.33 S 5.51 E 5.67 1.38 S 5.47 E 5.64 1.43 S 5.49 E 5.67 1.25 S 5.95 E 6.08 0.61 S 7.21 E 7.24 0.92 N 9.16 E 9.21 3.08 N 11.37 E 11.78 5.48 N 13.74 E 14,80 7.43 N 16,48 E 18,08 9,74 N 21,08 E 23.22 16.05 N 30,72 E 34,66 27.24 N 43.30 E 51,15 43,90 N 56.46 E 71.52 67.14 N 71.32 E 97,95 93.17 N 91.56 E 130.63 120.39 N 113.34 E 165.34 151.88 N 134.32 E 202.76 187.42 N 156.80 ~ 244,36 225.65 N 181.99 E 289.90 265.91 N 210,11 E 338,91 307.66 N 240.60 E 390.57 PAGE 60.00 DEPARTURE AZIMUTH DEG MIN N 0 0 E N 58 17 W N 66 5 W N 69 10 W N 41 53 W N 60 26 = N 82 10 N 87 19 E S 89 55 E S 87 56 E S 86 36 E S 85 8 E S 83 37 E S 82 20 E S 81 14 E S 80 15 E S 79 18 E S 78 20 E S' '77 24 E S 76 23 E S 75 48 E S 75 26 E S 78 7 E S 55 11 E N 84 16 E N 74 50 E N 68 15 N 65 43 ~ N 65 11 N 62 25 E N 57 49 E N 52 7 E N 46 43 E N 44 30 E N 43 16 E N 41 29 E N 39 55 ~ N 38 53 ~ N 38 18 m N 38 1 E COMPUTATION DATE: 8-JAN-87 PAGE 2 ARCO ALASKA, INC. 3Q-15 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 100 MEASU OEP TRUE SUB-SEA RED VERTICAL VERTICAL TH D:PTH DEPTH DATE OF SURVEY: 21-12-86 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 · 00 3909.88 3849.88 · 00 3995.26 3935.26 · 00 4080.56 4020.56 · 00 4165.77 4105.77 .00 4250.89 4190.89 · 00 4335.94 4275.94 .00 4421.03 4361.03 .00 4506.23 4446.23 .00 4591.42 4531.42 · 00 4676.58 4616.58 KELLY BUSHING ELEVATION: ENGINEER: T. WEST 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 .00 4761..78 4701.78 .00 4847.07 4787.07 .00 4932.29 4872.29 .00 5017.12 4957.12 · 00 5101.80 5041.80 .00 5186.42 5126.42 .00 5271.01 5211.01 .00 5355.51 5295.51 · 00 5439.89 5379.89 .00 5524.27 5464.27 FEET OF MEASURE 6000 6100 6200 6300 6400 65OO 8600 6700 6800 6900 7000 7100 7200 7300 7400 7480 .00 5508.65 5548.65 .00 5692.88 5632.88 .00 5776.82 5716.82 .00 5860.88 5800.88 .00 5944.93 5884.93 .00 6029.13 5969.13 .00 6113.39 6053.39 .00 6197.77 6137.77 .00 6282.49 6222.49 .00 6367.44 6307.44 .00 6452.38 6392.38 .00 6537.21 6477.21 .00 6621.85 6561.85 .00 6706.28 6646.28 .00 6790.50 6730.50 .00 6857.82 6797.82 COURSE VERTICAL DOGLEG RECTAN DEVIATION AZIMUTH SECTION SEVERITY NORTH/ DEG MIN DEG MIN FEET OEG/IO0 FEE 31 12 N 35 28 ~ 441.05 31 27 N 35 7 5 493.10 31 30 N 34 54 E 545.28 31 35 N 34 44 E 597.61 31 40 N 34 43 E 650;07 31 44 N 34 47 E 702.67 31 37 N 34 52 ~ 755.18 31 34 N 34 57 E 807.53 31 35 N 35 2 E 859.88 31 36 N 34 57 E 912.29 0.51 349. 0.19 392. 0.36 434. 0.19 477. 0.20 520. 0.15 564. 0.I2 607. 0.09 650. 0.11 693. 0.05 736. 0.27 778. 0.06 821. 0.81 864. 0.11 908. 0.12 952. 0.18 996. 0.09 1040. 0.14 1085. 0.05 1129. 0.07 1174. 0.13 1218. 0.58 1263. 0.26 1308. 0.27 1353. 0.35 1398. 0.40 1443. 0.24 1489. 0.68 1534. 0.56 1579. 0.19 1624. 0.53 1668. 0.11 1713. 0.15 1758. 0.96 1804. 0.00 1849. 0.00 1886. 31 28 N 34 56 E 964.63 31 31 N 34 54 E 1016.82 31 44 N 34 32 E 1069.14 .32 3 N 34 11 E 1122.09 32 11 N 34 8 E 1175.29 32 13 N 34 9 E 1228.57 32 13 N 34 2 E 1281.91 32 25 N 34 0 E 1335.37 32 28 N 33 54 E 1389.03 32 25 N 33 57 E 1442.69 32 33 N 33 57 E 1496.37 32 48 N 33 *7 E 1550.27 32 51 N 33 43 E 1604.62 32 49 N 33 44 E 1658.78 32 41 N 33 28 E 1712.96 32 36 N 33 1 E 1766.91 32 29 N 32 30 E 1820.76 32 18 N 32 13 E 1874.41 31 56 N 32 8 E 1927.52 13_:1 53 N 32 9 E 1950.27 7'32 4:t"- ' c~,~31 59 E 2246.63 ~]:i~}.'i,2 4dO ~lJ~31 59 _= 2269.82 - : 'L . ;+....~ C_ ~.0 · 0 DEPTH GULAR COORDINATES HORIZ. SOUTH EAST/WEST DIST. T FEET FEET 57 N 270.76 E 442.16 07 N 300.83 E 494.18 81 N 330.78 E 546.33 80 N 360.64 E 598.63 93 N 390.52 E 651.06 15 N 420.52 E 703.64 25 N 450.52 E 756.13 19 N 480.50 E 808.47 08 N 510.54 E 860.82 02 N 540.61 E 913.23 93 N 570.50 E 965.56 73 N 600.49 E 1017.76 70 N 630.36 E 1070.07 45 N 660.19 E 1123.00 47 N 690.06 E 1176.17 56 N 719.98 E 1229.43 73 N 749.87 E 1282.75 03 N 779.80 E 1336.18 55 N 809.78 5 1389.83 08 N 839.72 E 1443.47 60 N 869.71 E 1497.13 35 N 899.75 ~ 1551.00 54 N 929.95 E 1605.33 58 N 960.02 E 1659.47 69 N 990.03 E 1713.62 80 N 1019.64 E 1767.54 10 N 1048.76 E 1821.35 44 N 1077.47 E 1874.95 41 N 1105.76 E 1928.02 07 N 1133.85 E 1980.71 79 N 1161.86 E 2033.42 63 N 1190.02 5 208,5.31 73 N 1218.32 E 2139.50 25 N 1246.60 E 2193.02 99 N 1275.16 E 2246.89 65 N 1298.06 E 2290.06 60.00 FT DEPARTURE AZIMUTH OEG MIN N 37 45 E N 37 29 E N 37 15 E N 37 2 E N 36 51 E N 3,5 42 ~ N 36 34 E N 36 27 E N 36 22 E N 36 17 E N 36 13 E N 36 95 N 36 5 E N 36 0 E N 35 55 E N 35 50 E N 35 46 E N 35 42 E N 35 38 E N 35 34 E N 35 30 2 N 35 27 E N 35 24 E N 35 20 E N 35 17 E N 35 13 E N 35 9 E N 35 45 N 34 59 E N 34 55 E N 34 50 ~ N 3* 46 E N 34 42 E N 34 38 = N 34 34 = N 34 31 r- ARCO ALASKA, INC. 3Q-i5 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 8-JAN-87 INTERPOLATED V4LUES FOR EVEN 1000 FEET OF MEASU TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -60.00 1000.00 999.98 939.98 2000.00 1999.98 1939.98 3000.00 2997.50 2937.50 4000.00 3909.88 3849.88 5000.00 4761.78 4701.78 6000.00 5608.65 5548.65 7000.00 6452.38 6392.38 7480.00 6857.82 6'79'7.82 COURSE VERTICAL OOGLEG RECTA DEVIATION AZiMUTm SECTION SEVERITY NORTH DEG MIN DEG MIN FEST DEG/IO0 FE 0 0 N 0 0 E 0.00 0.00 0 14 S T4 24 E 1.96 0.06 O. 2 S 51 13 W 1.88 0.08 10 54 N 43 39 E 46.68 B.24 31 12 N 35 28 E 441.05 0.51 31 28 N 34 56 E 964.63 0.27 32 33 N 33 57 E 1496.37 0.13 31 52 N 32 1 E 2033.01 0.53 32 41 N 31 59 E 2289.82 0.00 0 0 1 27 349 778 1218 1668 1886 ATE OF SURVEY: 21-12-86 ELLY BUSHING ELEVATION: ENGINEER: T. WEST ED DEPT PAGE 3 60.00 GULAR COORDINATES HORIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN 0 E 0.00 7 E 3.88 7 E 5.64 0 E 51.15 6 E 442.16 0 E 965.56 1 E 1497.13 6 E 2033.42 6 E 2290.06 O0 N 23 S 38 S 24 N 57 N 93 N 60 N 79 N 65 N 0.0 3.8 5.4 43.3 270.7 570.6 869.7 1161.8 1298.0 N 0 0 E S 86' 36 E S 75 48 E N 57 49 E N 37 45 E N 36 13 *:' N 35 30 L N 34 50 ~ N 34 31 5 FT COMPUTATION ARCC ALASKA, INC. 3Q-15 KUPARUK NORTH SLOPE,ALASKA iNTERPOLATED VALUE,S TRUE SUB-S~A. COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 60.00 60.00 0.00 0 14 N 63 36 160.00 160.00 100.00 0 3 S 13 9 260.00 260.00 200.00 0 3 S 53 26 360.00 360.00 300.00 0 8 S 88 41 460.00 460.00 400.00 0 11 N 86 30 560.01 560.00 500.00 0 26 S 89 7 660.01 660.00 600.00 0 27 S 86 24 760.01 760.00 700.00 0 30 S 84 27 860.02 860.00 800.00 0 25 S 80 9 960.02 960.00 900.00 0 18 S 78 45 1060.02 1060.00 1000.00 0 13 S 69 11 1160.02 1160.00 1100.00 0 10 S 62 2 1260.02 1260.00 1200.00 0 9 S 60 23 1360.02 1360.00 1300.00 0 10 S 64 27 1460.02 1460.00 1400.00 0 9 S 62 9 1560.02 1560.00 1500.00 0 5 S 47 38 1660.02 1660.00 1600.00 0 3 S 24 42 1760.02 1760.00 1700.00 0 4 S 28 31 1860.02 1860.00 1800.00 0 4 S 26 27 1960.02 1960.00 1900.00 0 2 S 32 51 2060.02 2060.00 2000.00 0 1 S 36 5 2160.02 2160.00 2100.00 0 19 N 67 53 2260.03 2260.00 2200.00 0 51 N 63 28 2360.05 2360.00 2300.00 1 28 N 50 57 2460.09 2460.00 2400.00 1 47 N 45 17 2560.15 2560.00 2500.00 2 0 N 44 43 2660.20 2660.00 2600.00 1 53 N 55 37 2760.28 2760.00 2700.00 3 13 N 62 59 2860.70 2860.00 2600.00 6 53 N 55 44 2961.87 2960.00 2900.00 9 48 N 45 40 3063.86 3060.00 3000.00 12 41 N 37 3 3167.22 3160.00 3100.00 16 41 N 32 ~1 3272.68 3260.00 3200.00 19 46 N 39 14 3379.24 3360.00 3300.00 20 39 N 37 9 3487.03 3460.00 3400.00 23 11 N 32 33 3597.04 3560.00 3500.00 25 3 N 32 40 3709.60 3660.00 3600.00 28 32 N 3~ 15 3824.90 3760.00 3700.00 30 55 N 36 1 3941.76 3860.00 3800.00 31 4 N 35 47 FOR DATE: 8-JAN-87 EVEN 100 FEET VERTICAL DOGL SECTION SEVE FEET DEG/ DATE OF SURVEY: 21-12-86 KELLY 5USHING ELEVATION: ENGINEER: T. WEST OF SUB-SEA DEPTH EG RECTANGULAR CO RITY NORTH/SOUTH EA 100 FEET F 0.00 0.00 0.00 N 0.00 0.28 0.22 N -0.05 0.07 0.23 N -0.09 0.11 0..15 N -0.02 0.11 0.11 N 0.15 0.21 0.13 N 0.46 0.06 0.13 N 0.88 0.07 0.11 N 1.29 0.07 0.03 N 1.64 0.09 0.07 S 1.89 0 2.03 .0 2.07 0 2.10 0 2.12 0 2.15 2.14 0 2.10 0 2.04 0 1.97 0 · 11 0.19 S .03 0.30 S .15 0.45 S · 17 0.58 S .08 O. 72 S .08 0.85 S .12 0.96 S .05 1.08 S .10 1.18 S .10 1.29 S 1.91 0.02 1.36 S 1.85 O.lZ. 1.42 S 2.00 0.71 1.37 S 2.88 0.75 0.95 S 4.78 0.34 0.19 N 7.65 0.15 2.20 N 10.~0 0.41 4.49 N 14.16 0.68 6.79 N 17.39 3.87 8.47 N 25.43 4.16 13.07 N PAGE 60.00 39.92 3.19 22.35 N 59.65 4.04 37.17 N 85.62 3.88 58.94 N 119.01 2.42 86.02 N 155.63 2.61 114.40 N 195.80 2.64 147.58 N 241.61 2.32 186.31 N 293.25 2.19 229.41 N 350.60 1.34 276.26 N 411.00 0.47 325.13 N ORDINATES HORIZ. DEPARTURE ST/WEST DIST. ,aZIMUTH EET FEET DEG MIN 0.00 E 0.00 N 0 0 E 0.33 W 0.40 N 55 38 W 0.43 W 0.49 N 61 45 W 0.39 W 0.42 N 68 26 W 0.20 W 0.23 N 61 4 W 0.07 E 0.15 N 28 56 F 0.62 E 0.64 N 7'7 58 L 1.42 E 1.43 N 85 40 E 2.29 f 2.29 N 89 13 E 3.07 E 3.07 S 88 40 E 3 5 6 8 10 13 15 18 21 25 3.70 E 3.70 S 87 5 E 4.11 E 4.12 S 85 46 E 4.40 E 4.42 S 84 1Z E 4.66 E 4.69 S 82 50 E 4.89 E 4.94 S 81 39 E 5.15 E 5.22 S 80 39 E 5.31 E 5.39 S 79 42 E 5.40 E 5.51 S 78 44 E 5.45 E 5.58 $ 77 46. E 5.49 E 5.64 S 76 46 f 5.49 E 5.55 S 76 2 E 3.43 E 5.63 S 75 27 E 3.66 E 5.82 S 76 21 E 6.60 E 5.67 S 81 50 E 8.32 E 8.33 N 38 41 E 0.49 E 10.72 N 78 8 E 2.73 E 13.50 N 70 34 E 5.34 E 16.78 N 66 7 E 8.65 E 20.48 Fl 65 34 ; 6.27 E 29.34 N 63 32 E 8.43 E 44.46 N 59 48 E 1.77 E 63.73 N 54 19 E 5.95 E 88.45 N 48 12 E 5.51 E 121.29 N 44 49 E 8.96 E 157.98 N 43 36 E 1.61 E 197.73 N 41 43 E 6.09 E 243.06 N 39 57 E 4.53 E 294.42 N 38 48 ~ 7.64 E 351.69 N 38 13 E 3.24 E 412.11 N 37 54 E FT ARCO ALASKA, INC. 3Q-15 KUPARUK NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 4058.67 3960.00 4175.91 4060.00 4293.23 4160.00 4410.70 4260,00 4528.29 4360.00 4645.74 4460.00 4763.12 4560.00 4880.53 4660.00 4997.91 4760.00 5115.17 4860.00 5232.63 4960.00 5350.61 5060.00 5468.78 5160.00 5586.99 5260.00 5705.31 5360.00 5823.84 5460.00 5942.3'1 5560.00 6060.93 5660.00 6179.98 5760.00 6298.95 5860.00 6417.89 5960.00 6536.68 6060.00 6655.25 5160.00 6773.47 6260.00 6891.24 6360.00 7008.98 6460.00 7126.88 6560.00 7245.14 6660.00 7363.76 6760.00 7480.00 6857.82 COMPUTATION DATE: 8-JAN-87 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEPTH DEG MIN DEG MIN 3900.00 31 23 N 35 15 E 4000.00 31 28 N 34 57 E 4100.00 31 35 N 34 43 E 4200.00 31 41 N 34 43 E 4300.00 31 42 N 34 48 E 4400.00 31 34 N 34 54 E 4500.00 31 34 N 35 1 E 4600.00 31 36 N 34 58 E 4700.00 31 29 N 34 56 E 4800.00 31 31 N 34 54 E 4900.00 31 55 N 34 21 E 5000.00 32 8 N 34 9 E 5100.00 32 12 N 34 10 E 5200.00 32 13 N 34 2 E 5300.00 32 25 N 34 0 E 5400.00 32 28 N 33 54 E 5500.00 32 26 N 33 57 E 3600.00 32 37 N 33 50 E 5700.00 32 53 N 33 43 E 5800.00 32 49 N 33 44 5 5900.00 32 40 N 33 25 E 6000.00 32 36 N 32 48 E 6100.00 32 28 N 32 19 ~ 6200.00 32 0 N 32 9 E 6300.00 31 52 N 32 10 E 6400.00 31 54 N 32 2 E 6300.00 32 5 N 32 11 E 6600.00 32 21 N 31 50 E 6700.00 32 41 N 31 59 E 6797.82 32 41 N 31 59 ~ VERTICAL DOGLEG SECTION SEVERITY FEET OEG/IO0 471.55 0.28 532.71 0.21 594.06 0.21 555.68 0.22 717.54 0.12 779.14 0.11 840.57 0.07 902.09 0.06 963.53 0.26 1024.75 0.09 1086.36 0.55 1148.97 0.23 1211.92 0.12 1274.96 0.09 1338.22 0,14 '1401.84 0.08 1465.37 0.22 1529.17 0.46 i593.76 0.28 1658.21 0.26 1722.61 0.26 1786.72 0.47 1850.41 0.35 1913.45 0.27 1975.64 0.20 2037.76 0.41 2100.19 0.47 2153.29 0.22 2227.06 0.00 2259.82 0.00 DATE OF SURVEY: 21-12-86 KELLY BUSHING ELEVATION: ENGINEER: T. WEST SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ. NORTH/SGUTH EAST/WEST DIST. FEET FEET FEET 374.45 N 288.40 E 472.64 424.51 N 323.58 E 533.77 474.89 N 358.61 E 595.08 525.55 N 393.72 E 656.67 576.36 N 429.01 E 718.50 626.91 N 464.23 E 780.09 677.27 N 499.45 E 841.51 727.66 N 534.76 E 903.02 778.03 N 569.97 E 964.47 828.23 N 60.5.03 E 1025.69 PAGE 5 60.00 FT DEPARTURE AZIMUTH OEG MIN N 37 36 ~ N 37 18 E N 37 3 E N 36 50 E N 36 39 E N 36 31 N 36 24 N 36 18 E N 36 13 E N 36 8 E 878.91 N 640.09 E 1087.29 N 36 3 E 930.69 N 575.2'9 E 1149.87 N 35 57 E 982.78 N 710.63 E 1212.79 N 35 52 E 1034.98 N 745.99 E 1275.81 N 35 46 E 1087.39 N 781.40 E 1339.03 N 35 42 E 1140.17 N 816.92 E 1402.62 N 35 37 E 1192.89 N 852.39 E 1466.14 N 35 32 E 1245.82 N 888.00 E 1529.91 N 35 28 E 1299.50 N 923.92 E 1594.47 N 35 24 E 1353.11 N 959.71 E 1658.90 N 35 20 E 1405.74 N 995.35 E 1723.27 1460.43 N 1030.40 E 1787.34 1514.13 N 1064.66 E 1850.97 1567.48 N 1098.28 £ 1913.95 1620.16 N 1131.38 E 1976.09 1672.82 N 1164.38 E 2038.17 1725.68 N 1197.64 E 2100.55 1779.22 N 1231.08 E 2163.61 1833.39 N 1264.79 E 2227.33 1836.65 N 1298.06 E 2290.06 N 35 16 ~ N 35 12 E N 35 6 E N 35 1 E N 34 55 E N 34 50 ~ N 34 45 N 34 40 m N 34 36 E N 34 31 E COMPUTATION OATE: S-JAN-87 PAGE 6 ARCO ALASKA, INC. 3Q-15 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD DATE OF SURVEY: 21-12-86 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: T. W~ST INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB ORIGIN: 2295 FNL, 1989 F TVD REC SUB-SEA NO SURFACE LOCATION AT. EL, SEC 17, T13N, RgE, TANGULAR COORDINATES RTH/SOUTH EAST/WEST UM 7171.00 7179.00 7179.00 7276.00 7367.00 7480.00 ~597.34 6604.10 6604.10 6686.06 6762.73 6857.82 6537.34 6544.10 6544.10 6626.06 6702.73 6797.82 17 17 17 17 18 18 45.59 N 1210.12 E 49.21 N 1212.39 E 49.21 N 1212.39 E 93.27 N 1239.79 5 34.87 N 1265.72 E 86.65 N 1298.06 E- COHPUT4TION DATE: 8-JAN-87 PAGE 7 ARCO ALASKA, INC. 3q-15 KUPARUK NORTH SLOPE,ALASKA TOP BASE TOP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A MEASURED DEPTH BELOW KB 7171.00 7179.00 7179.00 7276.00 7367.00 7480.00 SUMMARY FROM KB 6597.34 6604.10 6504.10 6686.06 6762.73 6857.82 DATE OF SURVEY: 21-12-86 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: T. WEST ORIGIN: 2295 TVD SUB-SEA FNL, 1989 F REC NO SURFACE LOCATION AT EL, SEC 17, T13N, RgE, TANGULAR COORDINATES RTH/SOUTH EAST/WEST 6537.34 6544.10 6544.10 6626.06 6702.73 6797.82 1745 1749 1749 1793 1834 1886 .59 .21 .21 .27 .87 .65 N 1210.12 N 1212.39 N 1212.39 N 1239.79 N 1265.72 N 1298.06 U M FINAL MEASURED DEPTH 7480.00 WELL LOCATION TRUE VERTICAL DEPTH 6857.82 AT TD: SUB-SEA VERTICAL DEPTH 6797.82 HSRIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2290.06 N 34 31 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3Q- 1S F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOEO 21 - DEC - 86 REFERENCE WELt.' 3Q-15 (2295' FNL, 1989' FEL, SEC 17, T13N, R9E, UM) HORIZONTAL PROJECTION NORTH zsoo SOO Iooo soo -soo SOUTH -1000 -]SO0 WEST REF 72158 SCALE = ]/SOO IN/FT --H...4.-~d4-..~.--~-..~ ...... ~.4..4...~-.'.-~...~-.~..+-.~...~.-.~...~...~-.F.~.4...~-.4.... ~--~.--~--.~-~q...~-.4-4 ...... ;4q...;...~--~..4..-~.-4 ....... ;4--~4.~-.~...~--.~...~ ...... ~.--L-~.-.;4-.-~-.4-..;--4 ...... ~ ~:: ~ ~ ~ ~ ~ :: ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ .......... 3'"J ~"7 ....... 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F%F~dd-Tq"'F-FFFT-FF~TTd"~'~"'?~'~"~-'~-'~'~"'~ ...... r~ f- n l- II PROJECTION ON VERTICAL PLANE 33. - 213; SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/SO0 IN/FT ARCO Alaska, Inc Post Office uox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal f~ 5976 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC .~[.lik:O)t & Gas Cons. Commission Anchorage ~S tate.'.of~ Alas~' ~ (+Sepia} ;.~¢~'~ BPAE Chevron Union Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany - STATE OF ALASKA ALAS! OIL AND GAS CONSERVATION COMk SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate ~ Pull tubing COMPLETE Altm' Casing ~ Other J~ 2. N a 0ofA pA ,tOrno, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2295' FNL, 1989' FEL, Sec.17, T13N, R9E, UM At top of productive interval 549' FNL, 779' FEL, Sec.17, T13N, RgE, UM At effective depth 460' FNL, 723' FEL, Sec.17, T13N, RgE, UM At total depth 408' FNL, 691' FEL, $ec.17, T13N, RgE, UM 5. Datum elevation (DF or KB) RKB 60 t 6. U. nit or,PLoperty, na.me r, uparuK ~ver unit 7. Well number 3Q-15 8. Approval number 673 , 9. APl number 50-- 029-21666 Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7480'MD 6858'TVD 7367'MD 6763'TVD Casing Length Size Conductor 80' 16" Surface 3808' 9-5/8" Producti on 7417 ' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 7128' Packers and SSSV (type and measured depth) HRP-I-SP pkr (~ 7097', DB & FVL 555V @ 1790' feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 1850# Pol eset 115 'MD 115 'TVD 1070 sx AS IV & 3845'MD 3777'TVD 250 sx Class G 330 sx Class G & 7452'MD 6845'TVD 175 sx AS I 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [2j~ ~¥r~ , _ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ly; ^ /~ . Associate Engineer · . ~, f '?'~ Signed (' t,O U}L.." Z- ~LL{~,~,~./ Title Date /-~.',-~ 7 Form 10-404 Rev. 12-1-85 (UANI) SWU/h/Z Submit in Duplicate / Feet / .RCO Oil and Gas Company Daily Well History-Final Report Instructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefimte or appreciable !ength of time. On workovers when an official test is not required upon completion, reoort completion and representanve test -data in blocks provided. The "Final Report" form may be used for reporting the entire operation if alsace ~s avaiiabie. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Umt IWell no Kuparuk River ADL 25512 J 3Q-15 Auth. or W.O. no. I Tit!e AFE AK1690 I Completion ! Operator Spudded or W.O, begun Complete Date and depth as of 8:00 a.m. Nordic 1 API 50-029-21666 ARCo W l. rTotal number of wells (active or .nachve) on ~h~sL Icost center prior to plugging and -~RC0 Alaska, Inc. 56.24% labandonment of this ',veil bate IHour I Prior status if a W.O. 1/1/4/87 / 1715 hrs. Complete record for each day reported 1/15/87 1/16/87 7" @ 7452' 7367' PBTD, Rn'g 2-7/8" CA lO.0 ppg brine Accept ri~ @ 1715 hrs, 1/14/87. NU &tst BOPE. RU & rn 220 its, 2-7/8", 6.5#, L-80 EUE 8RD AB-Mod tbg w/SSSV @ 1790', HRP-I-SP pkr @ 7097', TT @ 7128'. 7" @ 7452' 7367' PBTD, RR 6.8 ppg Diesel Lnd tbg, set pkr, tst tbg/pkr to 2500 psi. TsC SSSV; OK. BOPE, NU &tst tree to 250/5000 psi. Displ well w/diesel. @ 1100 hfs, 1/15/87. Old TO New TO PB Depth 7367 ' PBTD Released rig Date Kind of rig 1100 hrs. 1/15/87 Rotary Classifications (oil. gas, etc.) Type completion (single. dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data iWell no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day I Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected =. The a~;~'v;"is correct Sign ture / ( ) ~ ~ For form preparatio~f/~ distributi~ see Procedures Ma~nua~lc'Section 10, Drilling. Pages 86 ~ 87. IDate ITitle Drilling Supervisor ARCO Alaska, Ir, Post Offic ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 20, 1987 Transmittal # 5892 RE%URN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3Q-15 2" & 5" FDC Porosity 11-25-86 5900-7402 2" & 5" FDC Raw 11-25-86 5900-7402 ~/~ 2" & 5" DIL 11-25-86 3850-7428 Cybemlook 11-25-86 6950-7400 3Q-13 2" & 5" FDC Porosity 12-9-86 6500-8146 2" & 5" FDC Raw 12-9-86 6500-8146 O 2'i & 5" DIL 12-9-86 4323-8172 -- ~ Cyberlook 12-9-86 7500-8100 3Q-14 2" & 5" FDC Raw 12-3-86 6850-8472 ~ ~ 2" & 5" FDC Porosity 12-3-86 6850-8472 2" & 5" DIL 12-3-86 1000-8498 C-yberlook 12-3-86 6900-8400 Receipt Acknowledged: DISTRIBUTION: NSK Drilling L. Johnston (vendor pkg) Date: Rathmell D &M .,'-State Vault (film)_ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ARCO Alaska, In(' Post Office . .~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5853 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-15 OH LIS Tape + Listing 11-25-86 #72096 Alaska Oil & Gas Cons. Commission Anchor~pe Recei pt Acknowl edged- Distribution- D. Wethere 11 State of 'Alaska Date' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS,... OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS I. Type of Request: Abandon - Suspend -- Operation Shutdown 7~ Re-enter suspended well -- Alter casing -- Time extension- Change approved program r- Plugging ~ Stimulate- Pull tubing- Amend order- Perforate- Other- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2295' FNL, 1989' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 545' FNL, 821' FEL, Sec. 17, T13N, R9E, UM(Approx) At effective depth 437' FNL, 736' FEL, Sec. 17, T13N, R9E, UM(Approx) At total depth 385' FNL, 706' FEL, Sec. 17, T13N, R9E, UM(Approx) 5. Datum elevation (DF or KB) / 60 ' RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3Q-15 8. Permit number 86-178 9. APl number 50-- 029-21 666 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7480'MD feet 6849'TVD feet 7367'MD feet 6754'TVD feet Casing Length Size Conductor 80' 16" Surface 3808' 9-5/8" Production 7417' 7" lO. Pool K'uparuk River Oil Pool Plugs (measured) None Junk (measured) None Cemented Measured depth 115'MD 3845'MD 7452 'MD True Vertical depth 115 ' TVD 3777'TVD 6825'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments We'l _-L Description summary of proposal Conductor Report not Received 1070 sx AS IV & 250 sx Class G 330 sx Class G BOP sketch - 13. Estimated date for commencing operation January, 1987 14. If proposal was verbally approved Name of approver Detailed operations program _ Date approved 5A/185 Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ / _~ Title As sociate Engineer ~/ Commission Use Only ( DAN ) Conditions of approval Notify commission so representative may witness _- Plug integrity - BOP Test -- Location clearance[ Approval No. ~/,-'~ . ....~ ~¢-¢ ~ --~¢ by order of Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company,~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report'" on the first Wednesday after a weir is spudded or ,vorkover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1690 County oar~s~ or 9orough North Slope Borough Lease or Un!t ADL 25512 Tite Drill State Alaska IWell no. 3Q-15 Doyon 9 API 50-029-21666 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate IHour 11/20/86 Date and depth aa of 8:00 a.m. 11/21/86 :.. ': 11122/86 . . thru 11/24/86 11/25/86 11/26/86 Complete record for each day reported 1600 hrs. ARCO WI. IPr or status if a W.O, 56.24% 16" @ 115' 2143', (2028'), Drlg Wt. 9.7, PV 26, YP 28, PH 8.5, WL 10.8, Sol 10 Accept rig @ 1230 hrs, 11/20/86. NU diverter sys. 1600 hfs, 11/20/86. Drl to 2143'. Spud well @ 9-5/8" @ 3845' 6201', (4058'), Drlg Wt. 9.2, PV 5, YP 3, PH 9.5, WL 9.2, Sol 6 Drl & surv 12¼" hole to 3860', 10 std short trip, C&C, POOH. RU & rn 97 jts, 9-5/8", J-55, 36#, HF-ERW csg w/FC @ 3760', FS @ 3845'. Cmt w/1070 sx AS IV & 250 sx C1 "G" w/.2% S-1 & .02% D-46. Displ using rig pmps, bump plug. ND diverter. NU & tst ~~~su~.~IH w/turbine, conduct formation tst to 12.5 ppg. Drl & ~' hole to 6201'. 3713', 28.8°, N34.4E, 3663.44 TVD, 293.68 VS, 225.11N, 191.76E 3825', 31.5°, N37.1E, 3760.28 TVD, 349.89 VS, 270.76N, 224.62E 4623', 31.9°, N35.2E, 4439.40 TVD, 768.75 VS, 612.95N, 466.45E 5622', 32.5°, N34.3E, 5286.58 TVD, 1298.03 VS, 1047.02N, 769.51E 9-5/8" @ 3845' 7460', (1259'), C&C Wt. 10.1, PV 15, YP 10, PH 9.5, WL 5.2, Sol 12 Drl & surv to 7460', short trip to csg shoe, RIH, C&C f/logs. 6126', 33.1°, N31.1E, 5710.23 TVD, 1570.97 VS, 1276.74N, 916.99E 6628', 32._9°, N29.6E, 6131.24 TVD, 1843.90 VS, 1512.67N, 1055.13E 7096', 32~3°, N30.1E, 6525.51TVD, 2095.48 VS, 1731.36N, I180.63E 7385', 32.9°, N29.7E, 6768.98 TVD, 2250.84 VS, 1866.34N, 1258.25E 9-5/8" @ 3845' 7480', (20'), POH, LD DP Wt. 10.0, PV 13, YP 6, PH 9.0, WL 4.8, Sol 12 Fin POH. RU Schl, rn DIL/GR/SP/SFL/IZDC/CNL/CAL f/7460'-3845', cont w/GR to 1000', RD Schl. RIH, drl 8½" hole to 7480', C&C, spot 10% diesel pill, POOH, LD DP. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 7 Title Drilling Supervisor ARCO Oil and Gas Co.,pany .~. Daily Well History Final Report Instructions: Preoare and submit the "Final Report" on :~'e ¢:rst '~"',"-~cr~esOay a~ter a!'.owabie has been assigned o. well is Plugged. Abandoned. or So!cl. · 'Final Report" should be submitted also when operaticr's a.e susper~ded 'or an malefic,re or aopreciable length of time. On ,vor,<overs when an official test is not required upon comDie,tion, report completion arc representat,.e tbs: data ;n bioc;~s provided The "Final Report" form may De used for repor',ing the entire operation ;f s3ace Js avadab~e. Alaska North Slope Borough Field Lease or U~it Kuparuk River ADL 25512 Auth. or W.O. no. Title AFE 603082 Drill COSt center code Alaska IWell no. 3Q-t5 Doyon 9 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 11/20/86 Date and depth Complete record for each day reported as of 8:00 a.m. 11/26/86 API 50-029-21666 I otal number of wells {active or inactive) on this cst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1600 hrs. 7" @ 7452' 7480' TD, 7367' PBTD, RR 10.0 ppg NaCl/Br RU & rn 178 its + mkr jr, 7", 26#, J-55 BTC csg w/FC @ 7~67', FS @ 7452', Mkr Jt @ 7121'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46 & 230 sx Cl "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. CIP @ 1640 hrs, 11/26/86. Bump plug w/3500 psi. Displ using 10.0 NaC1/Br. ND BOPE, NU & tst tree to 3000 psi. RR @ 2100 hrs, 11/26/86. Old TD I New TD PB Depth 7480' TD Released rig Date IK nd of rig I 2100 hrs. 11/26/86 Classifications (oil, gas, etc.) Type completion (single, dual, etc.) O±l S±ngle Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7367' PBTD Rotary Well no. Date iReservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date j ITitle Drilling Supervisor MEMORANDUM Stat ' of Alaska ALASKA OIL ,~D GAS uONSE~,vA~ION COMM!S$,ON 10: C.V. Q~/~rton DALE: December 4, 1986 Cha i~4~/~~~~ Ht~NO.: D.BDF.88 THRU: Lonnie C. Smith ,,,-'~:;'"'-~ TELEPHONE NO.: / C ommis s ioner FROM: Bobby D. Foster~.~- Petroleum Inspector SUBJECT: BOP Test ARCO KRU 3Q-15 Permit ~86-178 Kuparuk River Field Sun_day, November 23, i986: The BOP test began at 3:30 a.m. and was concluded at 5:00 a.m. As the attached BOP test report shows, there was one failure which was repaired before I departed the location. In summary, I witnessed the BOP test on ARCO's 3Q-15. Attachment 02-001 A ( Rev 1 0-84) ,4 STATE OF ALASKA ~ALASKA OIL & C~3 CONSERVATION B.O.P.E. Inspection Report Date Reserve Pit ~)~/_. Pressure Afl:er Closure /JR ~- pale Mud Svst~s Visual Audio Trip Tank Flo~ Monlnor Pump incr. clos. pres. 200 psiR -- =Ink'sec. Full Charge Pressure Attained: _~ =in/~ sec. ~ 3~ ~ ~o, ~/f~/~ 1~~. · Ke!iv and Floor Safe~v Valves ' BOPE Stack Test Pressure Upper Kelly / Test Pressure Uneck V~ve ~ [ -- Adjus:abie Chokes / Hvdrauica!2v ooeraued choke Tes= Resu!us: Failures / Test Time/ Y~ hrs. Repair or Replacement of failed equipment :o be made ~iuhin day~ and inspector/ o o Co-~-issio~ ~ ' -~ ~ ' · orig. - AO&~CC cc - Opera,or cc - Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944.. Sincerely, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany 8 9 17 16 YIClNITY MAP ALL WELLS LOCATED IN SEC. 17, TI3N, RgE, UMIAT MERIDIAN. ! 'Y' A~ 6,025,875.23 6,025,867.50 6,025,861.28 6,025,855.29 6,025,849.$6 6,025,843.37 6,025, 8 37.44 6,025,851.45 6,025, 81 $.50 6,025, 807.25 6,025, 801. :51 6,025, 795.53 6,025, 6,025, 785.47 6,025, 777.44 6,025, 771.55 ~P$" 'X' 515,959.92 515,984.20 516,008.42 516,0~..55 516,056.99 516,081.28 516,105.64 516,12'9.72 516,202.5~ 511,226.82 516,251.42 516, 275. ~0 5 Il, 215.52 516, :]25.80 516,~4~.20 511,~2.31 LATITUDE 70o 2 8' 54.758" 70° 28'54.701" 70° 28' 54.6~9" 70° 28' 54.510" 70° 28' 54.52 I" 70e 28' 54.462" 70° 26' 54. 403" 70<' 28' 54. 70° 28' 54. li5" 70~ 28' 54. 103" 7oo 28' 54.o4~ 70o 28' 53.9~7" 7o,, 2~' 55.9~"' 7~ 28' 53. 7O° L~' 53.80~" 70" ~' 53.749" NOT~S: I. ALL COO~NATE5 NeE A.S.R, ZONE 4. 2.ALL DISTANC~ ~0WN ~ ~. 4.~F. FIELD ~ LH-II, ~t 21-22. 5. O. G. E~VATION~ FROM F. R. ~LL I ~~TES. ~~S PER LHD ~ ~ '::. DIst. F.N:I' . 219t' 2205' 2211' 2217' 2223' 2229' 22:~' 2241' 2271' 2277' 2283' z28 ' 22~ 2301' 2377' 2352' 232t' 2304' 22~o' 2255' 2251' 2207' 2134' 2110' 2085' 20~2' 2037' LONGITUDE i 149052' 10.512" 149o52'09.798'' 149e 52' 09.0~" 149° 52'08.376" 149~' 52'07.658" 149~ 52'06.944" 14~e 52' 06.220" 14ff:1' 52'05. 520" 149o52'03.378" 149e 52'02.665" 149O 52'01. 942" 141152'01. 240" 14~e 52'oo. 521" 141I' 51' 59.814 14~ 51' 59.0~7" 149O 51'58. 17.1 21.7 17.1 21.7 17.1 21.7 17.2 21.l 17.2 21.1 17.3 220 I?.$ ~ 17.4 2:2.0 17.5 22,0 17.3 22.0 17.5 22.0 ~73 2LI 17.5 21.1 17.5 21.1 17.5 21.l 17.5 21.1 I HEREBY CERTIFY THAT t AM PROI:~RLY REGISTERED ANO LICENSED TO PRAC- TICE LANO SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY M~ OR UNDER MY SUF~:RVISION, AND THAT ALL DIMENSION~ ANO OTHER DETAILS ARE CORRECT AS OF 11/2/'86, D.S. 3Q WELL CONDUCTOR ASBUILT DIN BY' AdR I CHK IY' JWT ~ DATE' II ,/~'N [ NSK t. 317-d$ November 4, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3Q-15 ARCO Alaska, Inc. Permit No. 86-178 TI3N R9E i~. Sur. Loc. 2295'FNL, 1989'FEL, Sec. 17, , , - FN.~ 716'FEL, Sec 17, T13N RgE UM Btmhole Loc. 385' ~ , · , , · Dear Mr ~- ' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverp~enta! agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to co~.encing equipment installation so that the Commission may witness testing o_~o~e drilling below the shoe of the conductor pipe. V~ery tru!3m~?ours, , 7~. ~ ~ /U / / /~~ C. V. Chatterton Chai~an of Alaska Oil and' Gas Conservation Co~ission BY O._~ER OF THE COI~E~iSS!ON - jo Enclosure cc: Department of Fish & Gan~e, Habitat Section w/o encl. Department oz ,~nv_~o~me~,_to. 1 Conse~va. tion w/o ~ncl. l~[r. Doug L. Lowery STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C~,,,1MISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work Drill ~ Redrill '~1 lb. Type of well. Exploratory ~ Stratigraphic Test [] Development Oil Re-Entry [] Deepen []1 Service [] Developement Gas [] Single Zone~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ~,RCO Alaska, Inc. RKB 60' , PAD 23' feet ~<uparuk River Field 3. Address 6. Property Designation Kuparuk Ri var Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 2295'FNL, 1989'FEL, Sec.17, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 545'FNL, 821'FEL, Sec.17, T13N, R9E, UN 3Q-15 #8088-26-27 At total depth 9. Approximate spud date Amount .%85'FNL, 716'FEL, 5ec.17, T13N, R9E, UN 11/10/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(Me and TVD) property line 7445 'MD 716' ¢ total depth feet 3(;;)-16 25' [~ surf~e~e~ 2,560 (6792'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure/see 2o AAC 25.O35 lel/2)l Kickoff depth2718 feet Maximum hole angle33 0 Maximum surface 2230 psig At total depth O'VD) 3375 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2/.~" 16" 62.5# H-qO We~.d ~O' 35' 35' !!5' 1!5' +200 of 12-1/4"9-5/8" 36.0# _l - q"; RTC ~,7ql ' 35' 35' ~n')~ ' 3765' !070 HF-ERW 2~0 _~x £1 a.~.~ 8-1/2" 7" 26.0# J-55 BTC 7411' 34' :~4' 7445' 6792' 200 sx Class G(minimum HF-ERW TOC 5(0' abov top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface I n termed i ate Production OCT2 9 1986 Liner Commission Gas Cons. Perforation depth: measured ~%¢(a0it & true vertical 20. Attachments Filin~g fee ~: Property plat ~ BOP Sketch'~ DiverterSketch ~Drilling program Drilling fluid program ~Time(,s depth plot [] Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing i,s.true and correct to the best of my knowledge . ./x)-~.z~/.:,.~.,'t. Title Rog i cna 1 Dr i lli ng E ng i neer Date Signed //- [¢6' / '- Commission Use Only ( HRE ) PD/01 1 PermitNum~er I APInumber IApprovaldate I See cover letter ~-~-=~i7.~ J 50-C, ~-ff-~-( ~4:,E, 11/04/86 for other requirements Conditions of approval Samples required Q Yes ~..No Mud Icg required ~ Yes ;~-~.No Hydrogen sulfide measures [] _,Yes © N_~_..o Dir~D..ecti.~n~t.,t survey required ,~Yes ~ No ' Required working,pccr~re for_.B'C)PE/,'¢~2,_~I;,/~;/~~' 5M; Iq 10__Q_MLM' ~ 15M Other: / / /¢'-/// //~ /,~/~ by order of Approved by ~,~ ~ '/-L ~~'/ Commissioner the commission Date .... Form 10-401 Rev. 12-1-85 triplicate ::= KOP TVD~2?18-TIID=2718 DEP=O ts T~ U!$AK SNDS TVD=3320 ........ L ......... ~ E~ (9' 5/8' . 33 DEC ,- EE{EIVED ._. 50~_ OCT 2 9 1986 ........ -~ ~.~_~S TVD=~30 T~=6283 DEP=16~ Anchorags ~ T/ ZOO: D T~D-644S _ : ,~_ ;T_Z ZO~ C TVD=65~ T~=Z096 DEP-2104 B/ K~ SNDS~ TVD=6625 T~-7245 DEP-2186 0 t 000 2000 3000 i ~ ooo ) t~ 00o ~.ooo ) ~ooo- , , ! .... 2QQQ .............................................. l DOD . SURF~ LOCAT 2295' FILL,; I g~9' FEL SEC- 1~'. T.:'I3N. ................................................... 20.O0 21~00 - 2700 _ /3gtO I t 2300 / / / )' 2240 / / / / / 22OO 2 ! O0 '~2123 \ \ · 2000 1 900 1 t - I 1800 I 1 700 - ~300 _260Q 2700 · ! KUPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C DESCR I PT I ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. G. 20" 2000 PSI DRILLINQ SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 035 (b) 4 . MA I NTENANCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNN ! ND D I VERS I ON, DO NOT SHUT IN NELL UNDER ANY C I RCUMSTANCES. i 510084002 7 6 13-5/8" DIAGRAM #1 bO00 PS! RSRRA BOP STACK I. 16" - 2000 PSI TA~i<CO STARTING HEAD 2. I1" - 3000 PSI CASING HEAD 5. Il" - 5000 PSI X 13-5,/8" - 5000 PSI SPACER SPOOL 4. 13..-5/8" - 5000 PSI PIPE r/~ 5. 13...-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE ~ KILL LIhES 6. 13,--5/8" - 5000 PSI DOUBLE RAM W/PIPE RA~ ON TOP, BLIhD RA~ ON BOTTCIVt 7. 13-5/8" - 5000 PSI A~ ACCLt~LATOR CAPACITY TEST !. CHECK AhD FILL AC~TOR RESERVOIR TO PROPER LEVEl_ WITH HYDRAULIC FLUID. 2. ~ THAT ACCI~TOR PRESSURE IS 3000 PSI WITH I E~)O PSI D(~TREAM OF THE REGULATOR. 5. OBSERVE TI~E, THEN CLOSE ALL UNITS SIMULTAI~OUSLY ~ RECORD THE TIDE AhD PRESSURE REtCAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING Pt~ OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 45 SEC~ CLOSING TIDE AhD 1200 PSI RE]CAINING PRESSURE. L 5 2 15-5/8" BOP STACK TEST 1. FILL BOP STACK ~ CHOKE MANIFOLD WITH ARCTIC DIESEL. 2. Q-ECK THAT ALL LOCK DOWN SCRE~ IN WEi. LFEAD ARE FULLY RETRACTED. SEAT TEST I:::~_UG IN BEI_LHEAD WITH RI~ING JT AhD RUN IN LO(~ SCREWS. 5. CLOSE /~AR PREVENTER AhD MANUAL KILL AJ~D CHCKE LIHE VALVES ADJACEhFr TO BOP STACK, ALL OTHER VALVES AhD CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 5000 PSI AhD HOLD FOR I0 MIN. BLEED PRESSl~ TO 0 PSI. 5. OPEN AI~ PREVENTER AbE) MA~AL KILL ~ CHOKE LI~E VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON KILL AhD CHOKE LIhES. 6. TEST TO 250 PSI AhD 5000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LI~ES, AhD CHOKES WITH A 250 PSI LOW AhD 5000 PSI HIGH. TEST AS IN STEP 4. Do NOT PRESSURE TEST ANY CHCKE THAT IS ~FU~ FULl. CLOSING POSITIVE SEAL CHOKE. OhLY ION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI AhD 5000 PSI. 9. OPEN BOTTCI~ PIPE RAMS, BACK OUT RUbbING JT AhD PULL OUT OF HOLE. I0. CLOSE BLINO RAMS AhD TEST TO 250 PSI AhD 5000 PSI. II. OPEN BLINO RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIhES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, ANO INSIDE BOP TO 250 PSI AhD 5000 PSI. 15. RECORD TEST IhE'OR~TION ON BLOWOUT PREVENTER TEST FORM, SIGN, AhD SEhD TO DRILLING SUPERVISOR. 14. PERFORM CCIVPLETE BOPE TEST AFTER NIPPLING UP AhD WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15, 1985 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8,' casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" Casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. ,~ DEGASSERI CLEANER SHAL'E SHAKERS .~ ST R .~..p, STIR _._~ STIR CLEANER TYPICAL MUD SYSTEM SCHEMATIC LWK4/ih Density PV DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. \rjr Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. Lw~5 / ih ~!ECK LIST FOR NEW W~.I. PKRMITS I~ . APPROVE DARE (1) ~ ~ ,.t,O-y~-~ 1. Is (2) ~c ~ ~o-~-~ 2. (2tli~ 8) 3. 4. 5. 6. 7. 8 (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For ~Cz~-iY~u 3i) 30. 31. Geolo_~: .Engineering: BBTA~__~ bm! HJH N rev: 07/18/86 6.011 · .. Cotrpany the permit fee attached .......................................... ~ Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance frown other mils .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................ ~ Can permi, t be apl)roved before fifteen-&ay wait ........ i . Does operator have a bond in force .................................. ~' Is a conservation order needed ................................. , .... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique nm~m and number ......................... Is conductor string provided ' ~ Will surface casing protect fresh water zones ....................... ~ Is enough c~nent used to circulate on conductor and surface ......... Will cement tie in surface and inter, m. diate or production strings ... ~_ Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this mi1 to be kicked off from an existing wellbore ............. Is old wellbore abandonnmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~_ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient presstm-e rating - Test to ~cp psig .. Does the choke manifold comply w/AP1 ~R~-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are d~ta presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Lease & w ii No. Additional requirements~. ............................................ INITIAL CLASS STAIUS GEO. AREA ., U~IT NO. Itt&o ON/O~F SHORE Additional Ra~rks: Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. ~;~ .... S C H L U~ 5 E R 6 E R .... ~:: LIS TAPE VERIFICATION LTSTiNG MICROFILMED LVP 'OiO.HO2 VERIFICATION . ~ REEL HEADER ~ ~SERVICE NAME :EDIT ~DATE :86/12/ 6 ~ORIGIN : REEL NAME :149472 CONTINUATION # :01 ,PREVIOUS REEL : ]iCOMMENTS :LIBRARY TAPE LISTING P:,SE TAPE HEADER-~-,- RVICE NAME :EDIT TE :86/12/ 6 IGIN :FSiA PE NAME : NTINUATION ~ :O1 EVIDUS TAPE : MMENTS :LIBRARY TAPE ILE HEADER ...... NAME :EDIT oOOi ZCENAME : ION ~ : : MUM LENGTH : 1024 TYPE : IOUS FILE : NFORMATION RECORDS ARCO ALASKA, INC. 000 000 013 065 3Q-15 000 000 006 065 KUPARUK 000 gO0 00~ 065 gE 000 000 002 065 13N 000 000 004 065 17 000 000 002 065 NORTH' SLOPE 000 gO0 012 065 ALASKA 000 000 005 065 !M CONTENTS' UNIT TYP~ C,~T'E SIZE CODE ooo ooo -~: COMMENT S -",-'~',: ;~ q .,. , ~ , ~., .,..,..,.., .,..,..,..,.., .,..,..,. ~;c ~::" ~ ....................................................................................................... ,, .. ., CONTENTS UNIT TYPE CATE SIZE COSE 02 VERIFICATION LISTING PAGE = 9.625" @ 3845' - BIT SIZE = 8.5" TO 7460' = LSND = lO.O LB/G RM = 4.230 ~ 65 DF = 40.0 S RMF = 4.000 @ 65 DF = 9.5 PHC = 3.820 @ 65 DF = 5.2 C3 RM AT BHT = Z.Ot7 ~ 144 DF SCHLUMBERGER ALASKA COMPUTING CENTER ~OMPANY = ARCO ALASKA INC ~ELL . = FIELD = KUPARUK :,OUNTY : NORTH SLOPE BOROUGH ;~ATE = ALASKA ~J, O8 NUMBER AT ACC: T2096 ~R:UN ~QNE, DATE LOGGED: Z5 NOV 86 OP: T HALSTEAD ASING ~YPE FLUID NSITY ~VISCOSITY PH RIX SANDSTONE :~ THIS DATA HAS NOT BEEN DEPTH SHIFT~C - OV=RLAYS FIELC PRINTS ...... ~',~ ...... .. . .. ~ ~ , ~ ..~ ....... ~ ~ ~ ..................................................................................................................... ~ ~ ~ $ .,= ~ ~ ~.~ ~ ~ ~ ~ ~.~ $ .,..~ .~.. ~ ~ ~k q~ ~ ~',~ ~',= q~ ~,~~,....- .,..¢ .,....,..,..,..,..,. ~,..,..,. ~,..,..,..,. .,..,. -, ................. ,..¢ .,..,..,.., .... ~:= ~,= =,= =,= =~.~ .,..,..,. .,. .,. ';.iVP'OIO.H02 VERIFICATION LISTING · ,- ,',. 'DATA FORMAT RECORD ~-",~ ENTRY, BLOCKS SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNeTiC T.~PE: DUAL INDUCTION SPHERICALLY FDCUSEO LOG (OIL) DATA AVAILABLE: 7428' TO 3950' ::~ FORMATION DENSITY COMPSNS,%TED LOG (~E'N) COMPENSATED NEUTRON LOG (FDN) DATA AVAILABLE: 7402' TO 5900' GAMMA RAY IN CASING (GR.CNL) DATA AVAILABLE: 3850' TO 1000' TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 i 8 4 73 50 9 4 65 .lin 16 1 66 0 1 55 0 TUM SPECIFICATION BLOCKS M.]SERVICE SERVICE UNIT API API AP! APl FiLE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NJ. CODE (OCTAL) ~)~,iEPT. FT O0 000 O0 0 0 4 1 68 00000000000000 J~F~u' ~ oH~ OD ~o o~ o o ~ ~ ~ oooooooooooooo '~LD OHMM O0 120 46 0 0 4 1 65 00000000000000 'L'N DIL OHM~ O0 120 44 0 0 4 ~ 68 00000000000000 !. ?L V P · ~.,SP ~TGR ~CALI RHOB DRHO NRAT RNRA NPHI DPHI NCNL FCNL GR OlO.H02 OIL DIL FDN FDN FDN FDN FDN FDN FDN FDN FON CNL VERIFICATION LISTING MV O0 O1 GAP! O0 31 GAPI O0 31 IN O0 28 G/C3 O0 35 G/C3 O0 35 O0 42 O0 O0 PU O0 89 PU O0 89 CPS O0 33 CPS O0 33 GAPI O0 31 O1 Ol O1 O1 02 O1 O1 O0 O0 OC 31 30 Ol iDEPT :,:SP ':RHOB ~? N P H I GR :?DE P T HI lis P i?R H 0 B ?NPHI i, DE PT I. SP RHOB N'PHI i EpT P RH OB NPHI ,.GR ~,,., ,S P ;RHOB NPHI ',~bE P T ~i!~,':,, ,~' ,,:,,',: 7448.0000 SFLU -35.7500 GR 2.2656 DRHO 37.5000 DPHI -999.2500 7400.0000 SFLU -23.5156 GR 2.2969 DRHO 39.6484 DPHI -999.2500 7300.0000 SFLU -27.7969 GR 2.4160 DRHO 43.6523 DPHZ -999.2500 7200.0000 SFLU -30.7500 GR 2.3301 DRHO 31.6895 DPHI -999.2500 7100.0000 SFLU -33.7500 GR 2.4922 DRHO 31.6406 DPHI -999.2500 7000.0000 SFLU -30.5000 GR 2.3164 DRHO 47.9980 DPHI -999.2500 6900,0000 SFLU 3.8929 93.0000 0.1436 23.3031 3.4437 ':)3. 0000 0.1543 21. 4094 3.5650 94.0000 0.0454 14.1894 18.1403 69.2500 0.0556 19.3973 3.4437 1!3.5625 0.0532 9.5734 1.6297 103.3750 0.0435 20.2258 2.5202 ILD GR NRAT NCNL ILD GR NRAT NCNL ILD GR NRAT NCNL ILO GR NR~T NCNL ILO GR NRAT NCNL ItC NRAT NCNL 3.919':) 93.0000 3.1055 2012.0000 3.0221 93.0000 3.!32~ 13:76.0000 3.1351 94.0000 3.5391 17.83,52 69.2300 2.8533 2150.0'300 3.5309 113.5625 2.%277 1893.0000 1.5511 103.3750 3.8242 1642.0000 52 ,5:3 CALl RNRA PCNL ILM CALl RNRA FCNL l LM CALl ILM CALl R N '2, A ' FC'NL iLM CALl R NR ,A FCNL I LM CALI RNR~ FCNL iLM 0000000 3000000 O00OO00 O000CO0 OOOO000 O00OO00 0330000 O00000O OOOOCO0 0000000 0000000 0000000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 000 000 000 000 000 000 000 000 000 000 3.7504 7.3750 3.2383 521.0000 2.931:5 5.9180 3.3672 563.0000 3.1465 8.6563 4.0156 -50.5000 lg .6435 5.60 ':)4 2.9395 731.0000 3.3319 9.4453 2 · 974,5 636.0000 1.5952 9.2500 4.1211 398.2500 2.1946, VERIFICATION SP OB PHI ;R PT >$ P RHOB :NPHI GR PT SP .RHOB ':.N P H I IEPT ;P !HOB HI -38.7500 2.4375 42.8711 -999.2500 6800.0000 -41'0000 -999.2500 -999.2500 -999.2500 6700.0000 -45.0000 -999.2500 -999.2500 -999.2500 6600.0000 -53.5000 -999.2500 -999.2500 -999.2500 6500.0000 -61.7500 -999.2500 -999.2500 -999.2500 6400.0000 -61.2500. -999.2500 -999.2500 -999.2500 6300.0000 -65.3125 -999.2500 -999.2500 -999.2500 6200.0000 -50.0000 -999.2500 -999.250'0 -999.2500 6100.0000 -57.7813 2.3906 34.2773 -999.2500 6000.0000 GR DRHO DPHI SFLU GR DRHO DPHI SFLU GR DRHO OPHI SFLU GR ORHO OPHI SFLU GR DRHO DPHI SFLU GR DRHO OPHI SFLU GR DRHO DPHI SFLU GR DRHO DPHI SFLU GR DRHO DPHI SFLU LISTING 102.3750 GR 0.1016 NRAT 12.8875 NCNL 3.7724 ILO 189.2500 GR -999.2500 NRAT -999.2500 NCNL 3.4278 ILO 197.8750 GR -999.2500 NRAT -999.2500 NCNL 3.4476 ILD 115.0625 G'R -999.2500 NRAT -999.2500 NCNL 3.7091 iLD 100.3125 GR -999.2500 NRAT -999.2500 NCNL 2.7451 ILD 110.1250 GR -999.2500 NRAT -999.2500 NCNL 4.5907 ILO 87.8125 GR -999.2500 NRAT -999.2500 NCNL 2.5255 ILD 139.8750 GR -999.2500 NRAT -999.2500 NC'NL 2.0600 ltd 90.1250 GR 0.0342 NRAT 15.7281 NCNL 1.6155 ILD 102.3750 3.5625 1694.0000 2.7466 -999..~500 -999.2500 -999.2500 2.515Z -999.2500 -999.2500 -9~.2500 3.0078 -999.2500 -999.2500 -999.2300 3.4'):I -999.2500 -999.2500 -999.2500 3.18il -999.2500 -999.2500 -999.2500 4.1585 -999.2500 -999.2500 -999.2500 t.6691 -999.2500 -999.2500 -999.2500 2.2732 90.1250 3.0039 1923.0000 1.7574 CALl RNR& FCNL ILM CALl RNR~ FCNL ILM CALI RNRA FCNL ILM CALI R N R A FCNL ILm CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRa FCNL !LM CALl RNRA FCNL ILM C AL I RNR~ FCNL ILM P~GE 9.4844 3.5254 430.5000 2.8721 -999.2500 -999.2500 -999.2500 2.620~ -999.2500 -999.2500 -999.2500 3.05'04 -999.2500 -9'99.2500 -999.2500 3.5284 -999.2500 -999.2500 -999.2500 2.8553 -999.2500 '999.2500 -999.2500 4.0074 -999.2500 -999.2500 -999.2500 1.4874 -999.2500 -999.2500 -999.2500 2.0815 ~ .3828 3.0488 530.5000 1.5809 P OiO,H02 VERIFICATION LISTING ,P OB ~NPHI iR -58.2813 GR 2.4004 DRHO 41.1133 DPHI -999.2500 75.6875 GR 0.0234 NRAT 15.1363 NCNL EPT :~':'R H OB ~PHI ~R 5900.0000 SFLU -63.5625 GR 2.4336 DRHO 39.1113 DPHI -999.2500 2.3276 ILD 109.0625 GR 0.0762 NRAT 13.1242 NCNL DEPT OB NPHI GR DEPT P HOB P H I R P DEPT S,P R'HOB ,PHI 'HOB H,I' HOB HI , ,. EPT ;P HOB 5800. -67. -999. -999. -999. 5700. -76. -999. -999. -999. 5600. -71. -999. -999. -999. 5500. -70. -999. -999. -999. 5400. -70. -999. -999. -999. 5300. -73. -999. -999. -999. 5200. -79. -999. -999. -999. 5100. 0000 SFLU 0000 GR 2500 DRHO 2500 DPHI 2500 0000 SFLU 5000 GR 2500 DRH'O 2500 DPHI 2500 0000 SFLU 1875 GR 2500 DRHO 2500 D'PHI 2500 0000 SFLU 5000 GR 2500 DRHO 2500 DPHI 2500 0000 9375 2500 2500 2500 0000 9375 2500 2500 2500 0000 8,750 25O0 2500 2500 0000 sFLu GR ORHO DPHI SFLU GR DRHO DPHI SFLU GR DRHO · DPHI SFLU 2.7201 ILD 98.8750 GR -999.2500 NRAT -999.2500 NCNL 2.7719 ILD 102.7500 GR -999.2500 NRA'T -999.2500 NCNL 2.6406 ILO 95.1250 GR -999,2500 NRAT -999.2500 NCNL 3.2917 ILD $8,3125 GR -999.2500 NRAT -999.2500 NCNL 2.9617 ILO 88.7500 GR -999.2500 NRAT -999.2500 NCNL 2.6267 ILD 87.2500 GR -999.2500 NRAT -999.2500 NC'NL 2.9369 ILD 87.8125 GR -999.2500 NRAT -999.2500 NCNL 2.7004 ILD 75.6875 3. 3825 1981.01.}00 2.0135 109.0625 3.2556 1856,0000 2.5'945 -999.2500 -999.2500 -999.2500 2.7537 -999.2500 -999.2500 -999,2500 2.6761 -999.2500 -999.2500 -999.2500 3.2213 -999.2500 -9~9.2500 -999.2500 3.1223 -999.2500 -999.2500 -999.2500 ~ 82.32 -999.2500 -999.2500 -999.2500 2.9957 -999.2500 -999.2500 -999.2500 2,7268 C~LI RNR'~ FCNL CALI FCNL ILH CALi RNR~ FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL I LM C~LI RNR.~ FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL I LM PAGE 9.4375 3.7969 521.5000 2.02S7 $.3672 3.5527 525.0000 2.5753 -999.2500 -999.2500 -999.2500 2.6818 -999.2500 -999.2500 -999.2500 2.3763 -999.2500 -999.2500 -999.2500 2.8836 -999.2500 -999.2500 -999.2500 2,7471 -999.2500 -'999.2500 -999,2500 2.7763 -999.2500 -999.2500 -999.2500 2.8945 -999.2500 -999.2500 -999.2500 2.6240 ~iVP'Oio.Ho2 VERIFICATIDN LISTING , , ' B .N'P H I 'G R !"DE PT SP ,.RHOB ~,N P H I !:~GR DEPT ::RHO B ' PHI ,.R · ..;!, RHO B PHI ~'HO ~ . ipH T R~:s P '~'~',~ P H ~ ~OEPT .)E P T ~HOB PHI ~,O:E PT ~:~,,'., -81 -999 -999 -999 5000 -80 -999 -999 -999 · 4900 · -84 · -999. -999. -999 · 4800. -81 · -999,' -999. -999. 4700. -83. -999. -999. - 99,9, 4600. -80. -999. -999. -999. '4500 -81 -999 -999 -999 4400 -86 -'999 -999 '4300 -80 -999 -999 -999 4200 .0625 GR .2500 DRH.O .2500 DPHI .2500 .0000 SFLU .8125 GR .2500 DRHO .2500 DPHI 2500 0000 SFLU 3125 GR 2500 DRHO 2500 DPH'I 2500 0000 SFLU 2500 GR 2500 DRHO' 2500 DPHI 2500 0000 SFLU 0000 GR 2500 DRHO 2500 DPHI 2500 0000 SFLU 0000 GR 2500 DRHO 2500 DPHI 2500 .0000 SFLU .7500 GR .2500 DRHO .2500 DPHI .2500 · 0000 SFLU · 0000 GR ,2500 DRHO .2500 OPHI .2500 · 0000 SFLU ,7500 GR. .2500 DRHO · 2500 DPHI .2500 .0000 SFLU 102.3125 GR -999.2500 NRAT -999.2500 NCNL 2.6465 ILD 86.0625 GR -999.2500 NRAT -999.2500 NCNL 1.2042 ltd 88.9375 GR -999.2500 NRAT -999.2500 NCNL 2.2227 ILD 71.9375 GR -999.2500 NRAT -999.2500 NCNL 3.2754 ILO 88.5625 GR -999.2500 NRAT -999.2500 NCNL 2.6738 ILO 89.5625 GR -9'99.2500 NRAT -999.2500 NCNL 3.2953 ILD 88.2500 GR -9'99.2500 NRA'T -999.2500 NCNL 3.5023 ILO 85.2500 GR -999.2500 NRAT -999.2500 NC'NL 3.1459 ILO 91.8750 GR -999.2500 NRAT -999.2500 NCNL 1.510'3 ILO -999.2500 -999.2500 -9 ~ '~.. 2 ¢ = 00 2.7537 -999.2500 -999.2500 -999.2500 0.6'911 -999.2500 -999.2500 -999.2500 2.3296 -999.2500 -999.2500 -999.2500 3.3901 -999.2500 -999.2500 -999.2300 2.676,9 -999.2500 -999.2500 -999.2500 3.4528 -999.2500 -999.2500 -999.2500 3.2130 -999.2500 -999.2500 -999.2500 3.0911 -999.2500 -999.2500 -999.2500 1.8282 C-~Li FCNL I LM CALl RNRA FCNL ItM CALI RNRA FCNL ILM CALl RNRA FCNL ILM C4LI RNRa FCNL ILM CALi RNRA FCNL ILM CALl RNRA FCNL ILM C AL I RNRA FCNL I LM CALZ RNRA FCNL I tM -~99.2500 -999.2500 -~99.2500 2.6946 -999.2500 -999.2500 -999.2500 0.7992 -999.2500 -999.2500 -999.2500 2.1470 -999.2500 -999.2500 -999.2500 3.3421 -999.2500 -999.2500 -999.2500 2.5953 -999.2500 -999.2500 -999.2500 3.3871 -999.2500 -999.2500 -999.2500 3.0383 -999.2500 -999.2500 -999.2500 3.1156 -999.2500 -999.2500 -999.2500 1.7343 ,>RHOB -999.2500 DRH. O mPHI -999.2500 DPHI ~.DEPT 4100,0000 SFLU ~RHOB -999,2500 DRHO i'.NPHI -999,2500 DPHI ;GR -999,2500 ;DEPT 4000,0000 SFLU -86.75oo GR .!.RHOB -999.2500 DRHO iNPHI -999,2500 DPHI -999.2500 I~iDEPT 3900.0000 SFLU ~$'P -87.0000 GR -999.2500 DRHO -999.2500 DPHI 107.1250 ~iE PT ~:'H 0 B ~PHI .' 3800.0000 SFLU -999.2500 GR -999.2500 DRHO ,-999.2500 DPHI 49.8125 PT HOB ~ -. fR HOB HI J~N.P H I P T J~S~P ~R~H'O B 3700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 41.7500 3600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 40.5000 3500.0000 SFLU -999.2500 GR -999-2500 'DRHO -999.2500 DPHI 37.7813 3400.0000 SFLU -999.2500 GR. -999.2500 ORHO -999.2500 DPHI 37~9375 3300.0000 SFLU LISTING 82.7500 GR -999.2500 NRAT -999.2500 NCNL 1.5602 ILO 88.0625 GR -999.2500 NRAT -999.2500 NCNL 3.0778 ILO 98.1250 GR -999.2500 NRAT -999.2500 NCNL 2.4559 ILO 89.3750 GR -999.2500 NRAT -999.2500 NCNL -999'.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2.500 ILO -999.2500 GR -999.2500 NRAT -999.2500' NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 C~LZ -999.2500 RNRA -999.2500 FCNL 1.7163 iLM -999.2500 CALl -999.2500 RNRA -999.2500 FCNL 3.5937 ILM -999.2500 CALI -999.2300 ENE; -99'9.2500 FCNL 2.8950 ZLM -999.2500 CALi -9:~9.2500 RNRA -999.2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 RN~A -999.2500 FCNL -999.2500 ILM -999.2500 CALi -999.2500 RNRA -999.2500 FCNL -999.2500 !tM -999.2300 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 ILM' -999.2500 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 ILM -999.2300 CAL! -999.2:300 Rb,iPA -999.2500 FCNL -999.2500 PAGE -999.2500 -999.2500 -99'9. 2500 1.6685 -999.2500 -999.2500 -999.2500 3.4741 -999.2500 -999.2500 -999.2500 2.7317 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VERIFICATION -999 · -999 · -999. 30. 3200. -999 · -999. -999. 48. 3100. -999. -999. -999 · 37. 3000. -999 · -999. -999 · 32. 2900. -999 · '-999. -999. 21. 2800. -999. -999. -999. 28. 70o. -999. -999. -999. 32. 2600. -999. -999 · -999. 43. 2500- -999. -999 · -999 · 35. ,12400. 2500 GR 2500 DRH.O 2500 DPHI 5781 0000 SFLU 2500 GR 2500 DRHD 2500 DPHI 5313 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 5000 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 0625 0000 SFLU ZSO0 GR 2500 DRHO 2500 DPHI 7031 0000 SFLU 2500 GR 2500 DRHD 2500 DPHI 0938 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 8437 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 3750 0000 SFLU 2500 GR 2500 DRHO 2500 DPHI 1250 0000 SFLU LISTING -999.2500 GR -9'99.2500 NRAT -999.2500 NCNL -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ltd -999.2300 -999.2500 NRAT -999,2500 NCNL -999.Z300tLD -999.2500 GR -999.2500 NR~T -999.2300 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ltd -999.2500 GE -999.2500 NRAT -999.2500 NCNL -999.2500 !LO -999.2500 GR -999.2500 NRAT -99'9.2500 NCNL -999.2500 ILO -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ltd -995.£500 CALl -999,2500 RNRi -999.2500 FCNL -999,2500 !tM -929. ,~500 -999,2500 -999.2500 FCNL -999. 2500 ILM -999.2500 CAt' -9'99. 2500 RNRA -999.2500 FCNL -999,2500 ILM -999,2500 CaLl -999,2500 RNRA -999,2500 FCNL -999.2500 ItM - ~99. . 2300 CAtT~ -999.2,500 RNRA -999.2500 FCNL -999.2500 ILM -999.2500 CALl -999.2300 RNRA -999.2500 FCNL -999.2500 ILM -999.2300 CALf -999,2500 RNR.~ -999.2500 FCNL -$99.2300 !LM -999.2500 CaLl -99~.2500 RNR,~ -999.2500 FCNL -999.2500 ILM -999.2500 CALl -999.2300 RNR~ -999.2500 FCNL -999.2300 ILM -999.2500 -~99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2300 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 010.H02 VERIFIcATIoN RHO B NPHI -,, ~EPT SP ~RHOB PHI ~R ~LRH OB ~'NPHI ~RH'O B ~?'N P H ~ RHOB PHI EpT OB HI ;;R . [PT HOB iN, PHI ,R :?:,D E P T ~!R;'.H 0 B OB HI GR -999.2500 GR -999.2500 DRHO -999.2500 DPHI 30.8281 2300.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 37.2500 2200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPHI 29.7500 2100.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 DPHI 28.9687 2000.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 44.6875 1900.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 34.9062 1800.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPHI 34.9375 1700.0000 SFLU -999.2500 GR -999.2500 DRH'D -999.2500 DPHI 32.5313 1600.0000 SFLU -999.2500 GR -999.2500 DRHO -999,2500 DPHI 25.3438 EPT 1500.0000 SFLU LISTING -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NR4T -999.2500 NCNL -999.2500 !LD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -9'99.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILS -9'99.2500 GR -9'99.2500 NRA'T -999.2500 NCNL -999.2500 !LD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -99S.2500 CAL= -'999.2S00 RNRA -959.2500 FCNL -999.2500 ZLM -999.2500 C~LZ -959.2~'30 RNR~ -999,2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999.2500 ILM -999.2500 C.4LI -999.2500 RNRA -999.2500 FCNL -999.2500 ILM -'99'~.Z500 CALI -999.2500 RNRA -999.2500 FCNL -999.2~00 ILM -999.2500 CALI -999.2500 RNRA -'999.2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999,2500 FCNL -999.2500 iLM -999.2300 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 ILM -999.2500 C4LI -999.2500 RNRA -999,2500 FCNL -999.2500 ILM -'59'~.2900 -999.2500 -995.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10 010 HO2 VERIFICATION '"liSP -999.2500 GR i,'RHOB -999.2500 DRHO :-NPHI -999.2500 DPHI ,GR 33.8750 i~DEPT 1400.0000 PHI -999.2500 .,. R 26.2031 ii~EPT 1300.0000 · P -999.2500 "RHOB -999.2500 ii:~PHIR -999.2500 23.4531 i!ii, b E P T 1200.0000 i~iSP -999.2500 -999.2500 -999.2500 27.7656 ~..~RH OB ~!NPHI ,, ',,;v ' ' ~::E P,T 1100.0000 ~!S;,P' -999.2500 RHOB -999. 2500 N'PHI -999.2500 43.5000 ~O:E P T 1000.0000 -~9.2500 ~'~,.~, .. ~RHOB -999. 2500 ~',NPHI -999. 2500 ?,gR , 66.6250 'iq'' ~ FILE TRAILER ** "~["' T ~.~,FILE NAME :EDI ~:SERVICE ~'ERSI ON ~ ~:M'AXIM~M LENGTH : ?:Et L E TYPE : ~EXT. FILE N ME : , SFLU GR DRHO DPHI SFLU GR DRHO DPHI SFLU GR DRHO OPHI SFLU GR DRHO DPHI SFLU GR DRHO DPHI SFLU GR DRHO DPHI .001 1024 LISTING -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999,2500 NCNL -999,2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999,2500 ILO -999.2500 GR -9'99.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999,2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2.500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 CALl RNRA FCNL ILM CALi FCNL ILM CALl RNR~ FCNL I LM CALl R N R & FCNL I LM C 4L i R NE 4 FCNL ILM CALI RNRA FCNL I LM CALI R NR~ FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.!500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -995.2500 -999.2500 '-999.2500 I1 L"VP '0IO°HOZ vERIFICATION LISTZNG ~ TAPE TRAILER !,SERVICE NAME :EDIT · ATE :86/12/ 6 ,,~DRIGIN :FS1A APE NAME i'~ONTINUATIO~ # :01 · R EEL TRAILER ERVICE NAME :EDIT DATE :85/12/ 6 D.RIGIN : REEL NAME :149472 CONTINUATION ~ :01 iNEXT REEL NAME : COMMENTS :LIBRARY TAPE PAGE 12