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183-062
18&662 REUM0 WELL LOG TRANSMITTAL #906060265 To: Alaska Oil and Gas Conservation Comm. November 21, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1Y-08 Run Date: 10/26/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-08 Digital Data in LAS format, Digital Log Image fileRECEIVED C ^ C �"� D^ 1 CD Rom C 50-029-20944-00 R C G V DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: IVO?/, -)-O � Signed: Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Thursday, August 22, 2019 8:51 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1Y-08 (PTD 183-062) Report of suspect IA pressure increase Attachments: 1Y-08 90 day TIO trend 8.22.19.pdf, 1Y-08.pdf Chris, KRU injector 1Y-08 (PTD 183-062) governed under AIO 26.056 has been shut in since May 26, 2018. On July 9, 2019 a passing Sl MITIA (10-403 submitted July 12, 2019) was performed and the IAP was bled down. While reviewing the well trend it was noticed that subsequent the passing MITIA that the IAP began to increase unexplainably. The well will remain shut in as diagnostics are commenced. Further correspondence will be made once a plan forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Corwc'>Nilips (J ID 0 • r 1 0� wr rO 4J n p = Q cu v > a` a v c c > y co c +... O 141111 Co c v a (0 C. _c U a 7 Q O W r r N r r r r ' N m r r r r r r 0 C L U p N Q 0 > > 3 > > > > O + ° v '7 '7 '7 7w c _C N N 5. 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N = X n MINN W M V' to Q U) 00 O) A Li" �j� C� 0o a O O O O oa0000oaJ C.) 0 0 0 0 0 0 0 ro O 0 0 0 0 0 0 > W --, Q w o00000o a CC Xro ro w V C o C N O CO to 0 0 0 0 0 0 0 - u Q V 00 in 00 O r 6 ( ; Vf r N M a+ Q r4) It 0 N_ D) CD O) N 0 •E N p, N N N N N N N N t .0 N Q co O) O) O) O) M M C 0 • a O N N N N N 0 0 Q1 O O co O Or f6 u O r ' O u C co i v0) U)) U)) U)) U)) U)) G 'o o Oc 4 c a* w v C u U LZ al E d to • a wx w CC w E E CID (0 (o v v Q r 'O 1... v in .zrco co Q r m O co r a d N N w Z f)1 Z O r 0 0 N 17 = D: ✓) (9 r J u' 3 Y > F. _ E N yr C �_ a Q O N W N N M N N h Z N OCC O • ._ Ca r_ .-J O r 3 f6 C d C E O CID a a H a` a F F°- • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 11,2017 TO: Jim Regg P.I.Supervisor?et- 6Il (j- SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA,INC. 1Y-08 FROM: Adam Earl KUPARUK RIV UNIT 1Y-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry `J: NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-08 API Well Number 50-029-20944-00-00 Inspector Name: Adam Earl Permit Number: 183-062-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708062713 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IY-08 " Type Inj W` TVD 5821 Tubing 2465 - 2485 ' 2485 ' 2435 PTD 1830620 ' Type Test SPT Test psi 3000 IA 810 3300 - 3160 - 3110 BBL Pumped: 2.8 • BBL Returned: 2.7 - OA 165 170 - 170 170 - Interval REQVAR P/F P Notes: MIT IA as per AIO 2B.056 SCANNED SEP 2 5 2017 Tuesday,July 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 09,2016 P.I.Supervisor Re-74 '(l 3//(a SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-08 FROM: Jeff Jones KUPARUK RIV UNIT IY-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry eS3/2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-08 API Well Number 50-029-20944-00-00 Inspector Name: Jeff Jones Permit Number: 183-062-0 Inspection Date: 6/5/2016 Insp Num: mitJJ160608090356 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-08 (Type Inj W`TVD 5821 Tubing 1685 1685. 1683 . 1683 - PTD 1830620 - Type Test SPT Test psi 3000 - IA 410 3300 . 3130 - 3100 - Interval REQVAR P/F P ✓ OA 120 120 120 120 . Notes: AIO 2B.056. 1 well inspected,no exceptions noted. SCANNED DEC,' 2 92016 Thursday,June 09,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,February 18,2015 P.I.Supervisor ( eti z/1 Z4SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I Y-08 FROM: Chuck Scheve KUPARUK RIV UNIT IY-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry, NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-08 API Well Number 50-029-20944-00-00 Inspector Name: Chuck Scheve Permit Number: 183-062-0 Inspection Date: 2/15/2015 Insp Num: mitCS150215145114 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-08 ' Type In w 5821 2475 2450 -7 2450 2450 yp j TVD - Tubing 1 PTD I 1830620 Type Test SPT Test psi 3000 IA 1010 3280 3160 - I 3140 IREQVAR ---- 7 Interval P/F P — ✓ OA ---- 96 96 96 i 96 - Notes: Test as required Per AIO 2B 056 ✓ Wednesday,February 18,2015 Page 1 of 1 age Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial.production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing ~on~ [] RESCAN [] Color itemS: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other ~SI BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation ~ x30= ~0 BY: BEVERLY BREN VINCENT SHERYLLMARI~ LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED F,LE: P~E COUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES NO J,_~ = TOTALPAGES ~'~'"' / Stage 2 BY~ BEVERLY BREN VINCEN HE--ARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL AI-rENTION l$ REQUIRED ON AN INOIVlDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) IF NO IN STAGE '~ , PAGE(S} DISCREPANCIES WERE FOUND: YES NO DACE:i/ ~.~ ReScanned ()'t~diuidual p~ze ~'~p~cial ~tt~r tio~ ~c~m~i~.¢~ completed} RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: .Is~ General Notes or Comments about this file: Quality Checked Regg, James B (DOA) 1830 )W From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, February 24, 2012 2:56 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv 21" I'�v Subject: RE: Monthly Failed MIT report for January 2012 Jim, Below in the body of your email are my answers to each question. If there are any other concerns, please call. Brent Rogers / Kelly Lyons Problem Wells Supervisor )�,� ConocoPhillips Alaska, Inc ` Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Monday, February 13, 2012 4:51 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Monthly Failed MIT report for January 2012 What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? This well used to have a wireless pressure transmitter attached to the IA, but it was disconnected several months ago in preparation for an upgrade to a hardwire system. The SCADA system is still set up to read these pressures (which is now essentially reading atmospheric pressure). Unfortunately, the daily well walk pressures are often times not input correctly into the system to allow an overwrite of the erroneous wireless transmitter pressure readings. The issue has been brought to the attention of operations and more diligence will be forthcoming. Any diagnostics done on 1Y -08 (PTD 1830620) 6 evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? Operations intentionally pressured the IA in order to establish a better dP between the IA and OA. We will be pursuing diagnostics in the next couple of days to investigate further. KRU 28 -06 (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for production csg). Why allow 3100psi to remain on IA? The IA was bled several times in January without success. Based on initial diagnostics where the MITIA passed yet failed an IA drawdown test, a packer leak or other one way leak (from formation into the IA) is suspected. On February 1, the IA finally was able to be bled off to — 1750psi and is currently maintaining pressure below 2000 psi. Slickline /E -line work is now under way to secure the well with a downhole plug which will enable us to pursue further diagnostics. What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? This well has wireless pressure transmitters. Reported daily readings are averaged from the entire day's recordings. Occasionally, the transmitters malfunction temporarily, recording very high pressures (several orders of magnitude above actual pressures). These malfunctions usually only last minutes or seconds; but these erroneously high pressures get calculated into the average, causing the reported daily numbers to show up as spikes. Jim Regg AOGCC 1 • • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Tuesday, February 07, 2012 8:46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 2 • i Regg, James B (DOA) From: Regg, James B (DOA) � Sent: Monday, February 13, 2012 4:51 PM c Reqg t ' Z- l 1 -3 (( z' To: 'NSK Problem Well Supv' Subject: RE: Monthly Failed MIT report for January 2012 What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? 'Any diagnostics done on 1Y -08 (PTD 1830620) to evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? KRU 2B -06 (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for production csg). Why allow 3100psi to remain on IA? What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 OFE I ( GU Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617Ca�conocophillips.com] Sent: Tuesday, February 07, 2012 8:46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 • • • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 14, 2011 10 p Commissioner Dan Seamount FEB 17 2011 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 &Gas Cans. Commission Anchorage, AK 99501 Anchorage Commissioner Dan Seamount: A - Q 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 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 corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/15/2011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD y �� " Corrosion . 1 Initial op oti: . of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement _ pumped cement date inhibitor sealant date ft bbls _ ft gal 1B-01 50029204650000 1800400 SF i N/A 19" N/A 1.4 2/11/2011 1D-119 50029228360000 1972220 2" !. NO it 23" N/A 4.2 2/10/2011 1E-117 50029232510000 2050260 1'2" N/A 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 10-21 50029225910000 1951330 5" _ N/A 5" N/A 5.2 2/12/2011 1Q -22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y-06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 r)h 1Y-08 50029209440000 1 830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A _ 18" N/A 3 2/11/2011 3J -17 50029227000000 1961460 SF i N/A 19" N/A 3.3 2/11/2011 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y-10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10 JAN 0 ZU1`p 18. 1Y-09 - AA 2B.051 issued 05/20/2010. --, 17. 1Y -08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1Q-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. : Maunder, Thomas E (DOA) Sent. esday, January 04, 2011 10:53 AM To: NSK -II Integrity Proj Cc: 'NSK Prob = Well Supv' Subject: RE: Con. oPhillips Monthly Injector Report - Dec 2010 All, I am continuing to review the ►- cember Monthly Injector report. I am throu! a total of 13 wells. I wanted to send this latest message due to .t I have found or not found on 10-1 :. As I continue to work through the report, I plan to send interim message -s I get 7 - 10 new wells re -wed. Call or message with any questions. 13. 1Q-02B - Well name is 1Q-02B. Well last injec .-.• 9/10. I do not show having received any specific notification /request in June, 2010 regarding th': wel . There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containi• • a statemen at you intend to return the well to injection and remove it from the waiver report in May. 12. 1 L -05 - AA 2B.054 issued 10/ /2010. Well last injected 9/10 11. 1 L -03A - Well name is -03A. Permit to Drill # is 199 -037. MITIA faile. :•/25/2010. Well last injected 9/10. 10. 1G-01 - :.035 issued 7/30/2008. 9. 1F-16 Well name is 1F-16A. IA DD failed 4/12/2007, but MITs are listed to have passed s e. Well last inject- s 4 /2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. ■oking at th-- •ressure plot, it is shown that the IA pressure appears to have been bled off in October and Novemb- Was 1/4/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907- 943 -1720 / 1999 Pager 907 - 659 -7000 #909 i • ConocoPh i l l i ps Well 1Y-08 Injection Data • Tbg Psi IA Psi • OA Psi1 4000 3500 3000 2500 Q ••••• •••• • ••••• • •• • •NA• • • • •• •••NP••••• ••••M•y •• a 2000 •• 'w• x 1500 1000 - 500 ■■• • 09/10 10/10 11/10 12/10 01/11 Date \ J PTD:183 -062 AIO 2B.056 issued 10/22/2010 Reason: Surface Casing Leak 12/15/2009 06/15/10 - MITIA passed 10/26/10 - IC POT passed Well last injected 04/07. AIO 2B.056 requires any pressure bleeds to be reported monthly No pressure bleeds have occurred in the past month • • ConocoPhillips Well 1Y -08 Injection Data • Water Injection • Gas Injection 1 4000 3500 3000 - 2 2500 - a 2000 a z 1500 - 1000 - 500- 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 2161 589 36 30- Dec -10 0 0 2109 584 29 29- Dec -10 0 0 1987 580 24 28- Dec -10 0 0 1949 585 32 27- Dec -10 0 0 1983 588 42 26- Dec -10 0 0 2000 590 51 25- Dec -10 0 0 2074 594 60 24- Dec -10 0 0 2214 593 60 23- Dec -10 0 0 2116 595 60 22- Dec -10 0 0 2156 596 60 21- Dec -10 0 0 2161 595 60 20- Dec -10 0 0 2252 594 60 19- Dec -10 0 0 2226 594 60 18- Dec -10 0 0 2171 595 60 17- Dec -10 0 0 2141 596 60 16- Dec -10 0 0 2190 600 100 15- Dec -10 0 0 2217 600 100 14- Dec -10 0 0 2022 600 100 13- Dec -10 0 0 1935 600 100 12- Dec -10 0 0 2112 600 100 11- Dec -10 0 0 2177 600 100 10- Dec -10 0 0 2232 600 100 9- Dec -10 0 0 2249 600 100 8- Dec -10 0 0 2256 600 100 7- Dec -10 0 0 2216 600 100 6- Dec -10 0 0 2205 600 100 5- Dec -10 0 0 2255 600 100 • 0 4- Dec -10 0 0 2220 600 100 3- Dec -10 0 0 2240 600 100 2- Dec -10 0 0 2219 600 100 1- Dec -10 0 0 2239 600 100 30- Nov -10 0 0 2143 600 100 29- Nov -10 0 0 2178 600 100 28- Nov -10 0 0 2219 600 350 27- Nov -10 0 0 2200 600 100 26- Nov -10 0 0 2196 600 100 25- Nov -10 0 0 2206 600 100 24- Nov -10 0 0 2192 600 100 23- Nov -10 0 0 2264 600 100 22- Nov -10 0 0 2252 600 100 21- Nov -10 0 0 2210 600 100 20- Nov -10 0 0 2236 600 100 19- Nov -10 0 0 2252 600 100 18- Nov -10 0 0 2317 600 100 17- Nov -10 0 0 2294 600 100 16- Nov -10 0 0 2235 600 100 15- Nov -10 0 0 2178 600 100 14- Nov -10 0 0 2229 600 100 13- Nov -10 0 0 2234 600 100 12- Nov -10 0 0 2205 600 100 11- Nov -10 0 0 2268 600 100 10- Nov -10 0 0 2205 600 100 9- Nov -10 0 0 2163 600 100 8- Nov -10 0 0 2213 550 100 7- Nov -10 0 0 2244 550 100 6- Nov -10 0 0 2233 550 100 5- Nov -10 0 0 2276 500 100 4- Nov -10 0 0 2238 500 100 3- Nov -10 0 0 2207 500 100 2- Nov -10 0 0 2176 500 100 1- Nov -10 0 0 2188 500 100 31- Oct -10 0 0 2206 600 100 30- Oct -10 0 0 2209 600 100 29- Oct -10 0 0 2193 600 100 28- Oct -10 0 0 2184 600 100 27- Oct -10 0 0 2207 600 100 26- Oct -10 0 0 2214 600 100 25- Oct -10 0 0 2249 600 100 24- Oct -10 0 0 2239 600 100 23- Oct -10 0 0 2222 600 100 22- Oct -10 0 0 2248 600 100 21- Oct -10 0 0 2238 600 100 20- Oct -10 0 0 2198 600 100 19- Oct -10 0 0 2212 500 100 18- Oct -10 0 0 2187 500 100 17- Oct -10 0 0 2184 500 100 16- Oct -10 0 0 2182 500 100 15- Oct -10 0 0 2188 500 100 14- Oct -10 0 0 2180 500 100 • 0 13- Oct -10 0 0 2173 500 100 12- Oct -10 0 0 2145 500 100 11- Oct -10 0 0 2174 500 100 10- Oct -10 0 0 2224 500 100 9- Oct -10 0 0 2224 500 100 8- Oct -10 0 0 2150 500 100 7- Oct -10 0 0 2191 500 100 6- Oct -10 0 0 2184 500 100 5- Oct -10 0 0 2193 600 100 4- Oct -10 0 0 2203 600 100 3- Oct -10 0 0 2221 600 100 2- Oct -10 0 0 2240 600 100 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 25, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 WANED QQ)) 2011 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per MO 2B, Rule 9, to apply for Administrative Approval allowing well 1Y -08 (PTD 183 -062) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Perry Klein at 659 -7043, or Brent Rogers / Martin Walters at 659 -7224. Sincerely, / MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 1Y -08 (PTD# 183 -062) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with a known surface casing leak for Kuparuk injection well 1Y -08. Well History and Status Kuparuk River Unit well 1Y -08 (PTD# 183 -062) was drilled and completed in 1983 as a producer and converted to a service well in March 1985_ O 1Y -08 was reported to the Commission on 12 /15 /19rwith a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak to is approximately 240' below the surface (conductor shoe is at 110' RKB). A passing MITIA was conducted on 06/15/10. Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests an AA to continue water only injection until the well can be repaired. Barrier and Hazard Evaluation Tubing: The 3 -1/2" 9.3# J -55 tubing has integrity to the Packer @ 6015' MD based upon a passing MITIA to 3000 psi on 06/15/10. Production casing: The 7" 26# J -55 production casing has integrity to the Packer @ 6015' MD based upon a passing MITIA to 3000 psi on 08/11/10. The production casing is set at 6557' and has an internal yield rating of 4980 psi. Surface casing: The well is completed with 9 -5/8" 36# K -55 surface casing in the upper portion of the hole with an internal yield pressure rating of 3520 psi. The surface casing is set at 2213' MD and was arctic packed in 1983. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T/IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 9/26/2010 1 Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum). 3. IA pressure not to exceed 2000 psi (40% internal yield). 4. OA pressure will be maintained as low as hydrostatic pressure allows. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 9/26/2010 2 • KUP 1Y -08 Conocc : &Wells Well Attributes Max Angle & MD TO Alaska, Inc. WellborAPWWI IFIeld Neme IW.lI BOW Inn' (') ) MD(BKD) AMalm(IKU) 500292094400 UPARUK RIVER UNIT INJ 28.13 J 4,70080 6,557A - -- Comment 828(ppm) Oelo AotaUcn End Date jig (a) - Ord Rip Release eD CQRroo TROP-lAE. _ en Last WO: 1/7/1988 35.01 515/1983 Armddlon Depth (MUD d Oats Annotation et Mod By End Oats Lent Tag: I 6, 359.0 4/9/2006 Rev Reason: add TTl comments n1894 4/10/2006 Casing Strings Balm OD 8tdng ID and Depth set Depth (TVO) Edna Wt Saha Cuing Dandelion (m) (ku) Tap DIM) (888) (D7(11) OtMnt) Grade Btdng Top Thrd — Conductor 18 15.060 0.0 110.0 110.0 66.10 H -40 Sudace 95/8 8.697 0.0 2,2110 2,211.5 40.00 J55 PraductIon 7 6.161 0.0 6,557.0 6,337.2 26.00 J55 cemeowr, l,o Tubing Strings - Sldng OD Bbllg ID Sat Depth get Depth (ND) Btdlrg Wt String Tubing Description (In) On) Top (!1KBL. (BKB) MD) DMA) Grads String Top Thrd TUBING 3112 2.882 0.0 6,044.0 5,849.5 9.20 J-55 BTC AB-MOD Other In Hole (All Jewelry: Tubin Run & Retrievable, Flan, e BMW, t,e4e Top Depth (TVD) Top MN Tap (RK8) (MIN P) Duedplbn Commend Run Dab (In) 1,846 1,845.5 3.91 SSSV moo TRDP-1AE. 21199 12 ° . 813 5,951 6,761.7 19.48 GAS LIFT CAMCO/MMG- 2/1.610MY/RKI// Comment: 118/1988 2,920 5,093 5,801.3 18.13 SBR Can= OEJ 1/7/1988 2.813 Soave %2,213 - 6,015 5,822.1 18.88 PACKER mco HRP -18P 1/111988 2.859 8,033 5,639.1 18.87 NIP mco'D' Nipple NOGO 117/1988 2.750 8,043 5,848.6 18.66 SOS Cameo 117/1988 2.984 6,044 5,849.5 18.86 TTL ELMD TTL Q 6034' during IPROF on 419/2006 117/1988 2.984 ■ GAS LI FT. Perforations & Slots 3, allot Top (ND) Dim (TOO) Deno Top (ODD) Min (MB) (RKD) ( Zone oat. (eh-- Typo Comment 8,110 6,180 5,912.1 5,979.4 8/3/1983 12.0 5' 80S 120 deg. Phasing ■ Guns 6,312 6,328 6,103.7 8,119.0 9)3/1983 12.0 5' SOS 120 deg. Phasing Guns swum 8,343 8,359 6,133.31 8,148.5 613/1985 12.0 5' SOS 120 deg. Phasing Guns I PACKER. 0010 NIP, 5083 809, 8.043 Ill, 5,044 0' 600 Gulls, 6110 -0080 0' -0 ,3 2 e 8 su unk 5' 8,OS Gone. PmemOnn, a,e87 TO.0437 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaatdialaska.00v; doa. aoacc.orudhoe.bavcdtataska.00vi phoebe.brooks(dtalaska.aov; tom.maunder alaskasrov OPERATOR: ConocoPhil lips FIELD / UNIT / PAD: Kuparuk/KRU/ 11/ DATE: 06/15/10 OPERATOR REP: Phlllips/Colee AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Y -08 Type in). N TVD 5,822' Tubing 1,400 1,400 1,400 1,400 Interval p P.T.D. 1830620 _ Type lest _ P Test psi 1500 Casing 600 3,000 2,900 2,875 P/F P Notes: Diagnostic MITIA OA 80 80 80 80 P.T.D.I I Type test I I Test psi Casing InteP /F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). ND Tubing Interval P.T.D._ Type test Test psi_ Casing PIE Notes: OA Well Type Inj. ND , _Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitortrg I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Inter n& Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) KRU IV 0806 15 10.xts • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 15, 2009 2:44 PM To: NSK Problem Well Supv; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: KRU 1Y -08 (PTD# 183 -062) Report Of Surface Casing Leak Attachments: 1Y -08 TIO Plot.pdf; 1Y -08 Wellbore Schematic.pdf Jim /Tom /Guy, Kuparuk WAG injector 1Y -08 (PTD# 183 -062) is suspected of having a surface casing leak based upon results of a survey using an echometer and OA gas injection. Additional troubleshooting will begin as soon as feasibly possible. The well is shut in and will be placed on the monthly report. Attached is a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/4/2011 Well Name 1Y-08 Notes: End Date 1/1/2010 Days 120 Start Date 9/3/2009 Annular Communication Surveillance 6000 �__.� __ _.F.__ — 1.2 WHP IAP OAP 5000 — WHT 1 4000 0.8 • U. 3000 0.60 2000 0.4 1000 0.2 0 ` • 0 Sep -09 Oct -09 Nov -09 Dec -09 • 0.9 """'"DGI 0.9 •MGI O 0.7 ■IPWI 5 0.6 •SWI O 0.5 •••••BLPD u 0.4 -- 2 0.3 - - - -- -- - - - -._. 0.2 0.1 0 Sep -09 Oct -09 Nov -09 Dec -09 Date • MEMORA.NDUM To: Jim Regg ~~~-7 '~~ ~ P.I. Supervisor 4~ t ~ FROM: Lou Grimaldi Petroleum Inspector ~J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-08 KUPARUK RIV UNIT 1Y-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv y~L Comm Well Name: KUPARUK RIV IJNIT 1Y-08 Insp Num: mitLG090703131954 Rel Insp Num: API Well Number: 50-029-20944-00-00 permit Number: 183-062-0 / Inspector Name: Lou Grimaidi Inspection Date: ~~3/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lY-os TYPe Inj. N TVD saz~ . IA iozo z~so ~ 2~ao 2iso .. P.T.D 1830620 TypeTest SPT Test psi isoo p,~ ioo ioo ioo ~oo Interval a~TST p~F P ~ Tubing iaso iaso taso iaso Notes: 1.2 bbPs pumped, good four yeaz test. MI V~ ~ -I~S~i- ~~SS~,~,'~ ~ S~~ ; ,T,,~ .~~.rk~~~'~~ ~~ ,y , 4 ~~,~k v.l.- 7-'. „ Thursday, July 30, 2009 Page 1 of 1 • • ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~N~~ AUG ~ 2008 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 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~ ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field ~~ Date 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 STATE OFALASKA0 RIG IN A ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. i3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 570' FNL, 1791' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1120' FNL, 1048' FWL, Sec. 1, T11N, R9E, UM At effective depth 1143' FNL, 961' FWL, Sec. 1, T11N, R9E, UM At total depth 1163' FNL, 905' FWL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6600' 6377' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 96' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-08 9. Permit number/approval number 83-62 10. APl number 5o-02~)-20944 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6471 ' true vertical 6254' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6110'-6180', true vertical 5912'-5978', Length Size 78' 16" 21 78' 9 5/8" 6524' 7" Cemented Measured depth 251 SxASII 78' 1000 Sx AS III & 221 3' 250 Sx AS I 450 Sx Class G 6 5 5 7' 140 Sx AS I measured 6312'-6328', 6343'-6359' 6104'-6119', Tubing (size, grade, and measured depth) 6133'-6148' 3 1/2" 9.3 Ib/ft, J-55 w/ tail @ 6044' MD RKB Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr @ 6015' & TRDP SSSV @ 1846' RKB 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 78' 2212' 6337' 14. Reoresentative Daily Average Production or In!ectiop Daita OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (injection) 2635 400 psi 1970 psi Subsequent to operation (injection) 8402 0 psi 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run M I Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ,/~-.,~ ~ .~'~~TiIle Sr Operations Engineer~ Form 10-404 ~gv 06/15/88 3250 psi Service WAG Injector ARCO Alaska Inc. O Drillsite Morning Report ' CPF c~l Date ~fl.~/,~ Time 2,,~ oo Drillsite ~¥ Status Production Well Status Gas Lift Status Shut-In Well P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate # SI Zone PSI Bean OF WCO/o PPM 7" 10" Temp Meter Total MSCFD Hrs ={eason .3 I° R Iso r3c. ll~ ~ I 2-7 i~oo Rn ,~& ~a,.,:s-,G- ~zl$ q T ,?~ Io~ lC. ~O ~oao ?2~r I 13 /'.'/'] '1Z I Iq J3O io'z ~' ~3 Jo~o '7_ 8o ioo R '7-] '/ '/ 4. ~ ~.~ ~ :,, : ,.:; ~v ,. ~ ,_'-.~ L ~- ~ . Total -/5' I '~ Status InjectiOn Well Status Shut-In Well Gl, PW Inject. Pressure PSI Temp Choke CSG Pressure PSI Meter Injection Rate # or SW Zone Allowable Actual OF Bean 7" 10" Total BBLSlDay MMSCFD Hrs. Reason 2 ~ H )e 3_~ I~'q "15 13&o .5'00 ~z"llSO q q. 35' --/ iFS-o i~'1 2.0 2&O [3.0 BG~'O IZ~'L I&qq 13. ~3'z4' ts/,,, .,~ a ,1~$0 4. o -3%-.~r.,e i & I._3' Total SWI Total PWI Total 1 5': ~'~ ~ Drillsite i Coil Temperature OF I Coil Pressure PSl I Bath Blanket H~t~r Prod I Test Prod I Test Temp. Gas PSI Run Time Chemicals Type I GaliDay Inc. {) ~--.. ~ Drillsite Morning Report '" CPF I Time 2 ~ o 0 Drillsite I y' '-U'~- Production Well Status Gas Lift Status Shut-In P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate SI Zone PSI Bean °F WC% PPM 7" 10" Temp MeterTotal MSCFD Hrs Reason ~ -' ~ '- ~ P IqE 12Z ~ qn 13oo ~00 III ~o~qq3 I ~5o q J~O io3 lq ~o Logo RO0 I00 ~N~qa LOq3 I WORK -i Total ~ G Gq Status Injection Well Status Shut-In Well Gl, PW Inject. Pressure PSI l'emp Choke CSG Pressure PSI Meter Injection Rate # or SW Zone Allowable Actual °F Bean 7" 10" Total BBLSlDay MMSCFD Hrs. Reason I ?v ~ I-1 :3R 2qaro .t~.& ..~'/- I000 RIO 2~-qgSoa ,45~1~ (~ Total 3E~E~ I~. O~ SWl Total PWl Total ~.5' q s' q Drillsite [ Coil Temperature OF [ Coil Pressure PSI Bath Blanket Heater 'lIPr°d I Test Prod Test Temp. Gas PSI Run Time Chemiials Typ~ Gal/Day k_R_ O ..... STATE OF ALASKA ALASKA r~lL AND GAS CONSERVATION CO~'MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE]~] WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-62 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-20944 , 4. Location of well at surface 9. Unit or Lease Name 570' FNL, 1791' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1120' FNL, 1048' FWL, Sec. 1, TllN, R9E, UM 1Y-8 , At Total Depth 11. Field and Pool 1163' FNL, 905' FWL, Sec. 1, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 96' ADL 25641 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 04/27/83 05/02/8:3 05/:31/8:3' N/A feet MSL 1 17. TotaIDepth(MD+TVD) 18.Plug Back Depth (MEH~TVD)19. D~ctionalSurvey I 20. Depth where SSSV set [ 21. Thickness of Permafrost 6600'MD, 6377'TVD 6471 'MD, 6254'TVD YES ~ NO [] 1846 feet MD 1350~ (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, CBL/CCL/GR/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 16" 62.8# H-40 Surf 78' 24" 251 sx AS II 9-5/8" 40.0# J-55 Surf 22t3' 12-1/4" 1000 sx AS Ill & 250 sc AS I 7" 26.0# J-55 Surf 6557' 8-1/2" 450 sx Class G & 140 ;x AS I · , ,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) ., Perforated w/12 spf, 120° phasing 3-1/2" 6044' 6015' 6110'-6180'MD 5912'-5978'TVD 6312'-6328'MD 6104'-6119'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6343'-6359'MD 6133 ' -6148 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .. N/A , , 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I , Date of Test Hours Tested pRoDuCTION FOR OIL-BBL GAS-MCF WATER-BBL CH'OKESIZE IGAS-OILRATIO TEST PERIOD ~ 1 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-Alii ('c~)rr) Press. 24-HOUR RATE I~! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chip.~, ~ f."" ~ I ~ [ 'r¢~ D .,,,.,, l,J~,.¢;~ ~'l\iote: Drilled RR 5/5/83. Perforated well & tubing run 5/31/83. 6onverted to water injector 3/30/85. Workover performed 1/7/88. . . , . Form 10-407 WCu,/50 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ! , 29. ~ 30. ' GEOLOGIC MARfZ,'ERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand · 6110' 5911' N/A Base Upper Sand 6181' 5978' Top Lower Sand 6291' 6083' Base Lower Sand 6411' 6197' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoin9 is true and correct to the best of my knowledge &_//~/)/~ ~L~L~..~ J Title Associate Engineer Date Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 "-" STATE OF ALASKA ALt, .,-t OIL AND GAS CONSERVATION CON .... ~SsION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging © Perforate .r-; Pull tubing Alter Casing ~ Other ][3. WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 96' 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 570' FNL, 1791' FWL, Sec. 1, T11N, RgE, UN At top of productive interval 1120' FNL, 1048' FWL, Sec. 1, TllN, R9E, UM At effective depth 1143' FNL, 961' FWL, Sec. 1, TllN, R9E, UM At total depth 1163' FNL~ 905' FWL~ Sec. 1~ TllN~ R9E~ UM 7. Well number 1Y-8 8. Approval number 7-944 9. APl number 50-- 029-20944 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 6600 ' MD 6377 ' TVD measured 6471 'MD true vertical 6254 'TVD Length Size 78' 16" 2178' 9-5/8" Casing Conductor Surface Production 6524' 7" feet feet feet feet Plugs (measured) None Junk(measured) None Cemented Measured depth 251 sx AS I1 78'MD 1000 sx AS III & 2213'MD 250 sx AS I 450 sx Class G & 6557'MD 140 sx AS I ~ue Vertical depth 78'TVD 2212'TVD 6337'TVD Perforation depth: measured 6110 ' -6180 ' true vertical 5912' -5978' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 6044' Packers and SSSV (type and measured depth) HRP-1-SP pkr (~ 6015', TRDP SSSV ~ 1846' , 6312'-6328' , 6104'-6119' , 6343'-6359' , 6133'-6148' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure Anchorage 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 (Work-over Well Histor,~y) 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. 12-1-85 Title Associate Engineer Date (Dani) SW03/40 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish /StatL ARCO Alaska, Inc. NORTH SLOPE Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2558 Lease or Unit IWell no. I ADL: 25641 1Y-8 Title WORKOVER API: 50-029020944 Operator ARco Spudded or W.O. begun ACCE?T Date and depth as of 8:00 a.m. 01/08/88 ( TD: · . PB: 64.7I ~ _ SUPV: DL A.R.Co. W.I. 56.0000 IOate 01/05/88 Complete record for each day reported NORDIC 1 I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prlor status If a W.O. I 1030 HRS RIG RELEASED MW: 6.9 DIESEL RD SOS. RIH W/ TP ASSY, PKR ASSY AND 3-1/2" COMP. EQUIPMENT. TEST CONTROL LINK TO 5000 PSI. LAND TBG. SET PKR W/ 2500 PSI. TEST TBG TO 2500 PSI. TEST ANNULUS TO 2500 PSI. TEST SSSV TO 1500 PSI. S~AR OUT BALL. ND BOPE. NU TREE AND TEST TO 5000 PSI. DISPLACE WELL W/DIESEL. TEST CV TO 1200 PSI. SET BPV. RELEASED RIG AT 2145 HRS, 1/7/88. (SSSV @ 1846', PKR @ 6015', TAIL @ 6044') DAILY:S90,961 CUM:$170,684 ETD:S170,684 EFC:$187,000 Old TO New TD ~ Released rig Date PB Depth IKind .of rig Classifications (oil, gas, etc.} Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval iOil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size :T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature IDate For form preparation and distj~/~uti~n, see Procedures Manual, Sect~/h 10, Drilling, Pages 86 and 87, Associate Engineer / ' ARCO Oil and Gas Company~, Well History - Initial Report- Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KupARuK RIVER FIELD Auth. or W.O. no. AK2558 ICounty, parish or borough NORTH SLOPE II. ease or Unit I ADL: 25641 ITitle . J WORKOVER i stat~.K 1Y-8 IWell no. API: 50-029-20944 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/06/88 ( : PB': 6473: 01/07/88 ( TD: PB: 6473 SUPV:ML Date 01/05/88 ]Hour Complete record for each day reported NORDIC i 1030 HRS ARCO w.i. 56.0000 Prior status if a w.o. ND BOPE'S MW:10.7 NaCl/Br MOVE RIG F/ 1Y-12 TO 1Y-8. ACCEPT RIG AT 1030 HRS 1/5/88. pULL BPV. DISPLACE WELL W/ 275 BBLS 10 PPG BRINE. SET BPV. ND FM~ 3000 PSI TREE. NU BOPE AND TEST TO 3000 PSI. OK. MU LAND JT. PU AND SHEAR 'OEJ'. MONITOR WELL. FLOWING. SHUT IN. 200 PSI ON ANN. CIRC 10 PPG. MONITOR WELL. WELL STILL FLOWING. SHUT IN. 200 PSI ON ANN. INCREASE BRINE WT TO 10.7 PPG. CIRC 10~7 AROUND. WELL STATIC. P~ HANGER TO FLOOR AND LD. PULL 2 STANDS TBG. PU BAKER RETRIEVABLE PACKER, EQUALIZING SUB AND SAFETY JT. RIH AND SET 1' BELOW TBG SPOOL. TEST PKR TO 500 PSI. OK. ND BOPE'S. DAILY:S34,750 CUM:$34,750 ETD:S34,750 EFC:$187,000 RIH W/ 6" GR AND JB MW:10.7 NaCl/Br .ND BOPE AND TBG HEAD. NU NEW 5000 PSI TBG HEAD. NU BOPE AND TEST SAME. PULL BAKER STORM CHOKE. RU CAMCO. PULL PLUG F/ D-NIPPLE. POOH W/ 3-1/2" TBG AND COMP EQUIPMENT. CHANGE OUT COUPLINGS TO AB-MOD. PKR WAS SHEARED. RU SOS AND RIH W/ 6" GR AND _JB. DAILY:$4~,973 CUM:$79,723 ETD:S79,723 EFC:$187,000 The above is correct For form preparation and~l~stribution, see Procedures Manual, 16tlction 10, Drilling, Pages 86 and 87',J - Date /'~-~ ITitle Associate Engineer STATE OF ALASKA ALA ..... OIL AND GAS CONSERVATION CON,.,,,$SION APPLICATION FOR SUNDRY APPROVALS . ,**. ' {,~! ~"~ Abandon ~ Suspend F1 Operation Shutdown ~ Re-enter suspended well r~_ Alter casing '_.- ~n( order E! Perforate ~ ~)th.=r/~ 5. Datum elevation (DF or KB) , ~. I/fi. feet 1. Type of Request: Time extension D Change approved program ~ Plugging ~ Stimulate D Pull tubing ~, Amend order ~ Perforate % Other/~ 2. Name of Operator ARCO Alaska, Inc. RKB 96' 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 7. Well number 570' FNL, 1791' FWL, Sec. 1, T11N, R9E, UM 1Y-8 At top of productive interval 8. Permit number 1120' FNL, 1048' FWL, Sec. 1, TllN, R9E, UM 83-62 At effective depth 9. APl number 1143' FNL, 961' FWL, Sec. 1, TllN, RgE, UM 50-- 029_209ztbr At total depth 10. Pool 1163' FNL, 905' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Oil 11. Present well condition summary Total depth: measured true vertical 6600 'MD feet Plugs (measured) None 6377'TVD feet 6. Unit or Property name Kuparuk River Unit Pool Effective depth: measured true vertical Casing Length Conductor 78 ' Surface 2178' Production 6524' 6471'MD feet feet 6254'TVD Size 1 6" 9-5/8" Junk (measured) None Cemented 251 sx AS I1 1000 sx AS III 250 sx AS I 450 sx Class G Measured depth 78'MD 221:3'MD True Vertical depth 78'TVD 221 2 ~ TVD 6557'MD 6337'TVD Perforation depth: measured 6110'-6180', 6:312'-6328,, 6343'-6359' true vertical 5912'-5978', 6104'-6119', 6133'-6148' Tubing (size, grade and measured depth) 3-1/2", J-55 @ 6037' Packers and SSSV (type and measured depth) Camco HRP-1-SP @ 6009', Camco TRDP @ 1837' Oil & Gas Cons. Commissio[~ Anchorage 12.Attachments Description summary of proposal .~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation January 7, 1988 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 (~ ~ J~C/Z~t .~ Title As socia te Enoi neet Commission Use Only ( JWR ) Conditions of approval Approved by Date /Z-I I-~7 SA3/33 Notify commission so representative may witness ! Approval No. [] Plug integrity [] BOP Test [] Location clearancel -~ --- ¢'~,~ ~ Mecha,n~c~ i;;;~ .... ...... ?~;,, T.,Approved Copy ORIGINAL SIGNED BY /~--/~-~ [ONNIF C. ~Mt~ ~ 'COmmissioner Form 10-403 Rev 12-1-85 by order of the commission Date Submit in triplicate KRIJ ~/ELL 1Y~8 3-1/2', COUPLZN6 AND WELLHEAD CHANGEOLIT PRELINZNAR¥ PROCEDURE 1) RU Sl~ckl~ne. Set Plug in "D" n~pple. 2) Pull dummy fro~ botto~ ~LM. R~ slfck~fne. 3) MZRU Workover rig. 4) Circulate kf]~ Weight brine down tu6ing taking returns up annulus. 5) ND tree. NU and test BOPE. 6) Shear SBR off of Packer. POH 2 Stands. 7) Nake up Storm ~ack 8) ND BOPE ,,- · POH. cfm packer. Re/ease st. ' change out tubing head to 5000 psi equi 9~ :~ a!n_ and ~atch Storm ~ · ~ nt. NU BOPE and ..... 10) Contfn _~. packer. PON With same. ~: ...... ue PON whi~e changing out Couplings to AS-Nod · . . . 11) Rerun Comp]etlon With redressed SBR, 1-1/2', GLN and SSSV. 12) ND BOPE. NU and test tree. 13) DiSplace we]7 to diesel. 14) Release rig. 15) RU Slickl~ne. Pull Plug from 16) TOTP. nipple. Workover fluid: NaCl/NaBr BHP = 3485 psi Ca 6030,TVD/6236,ND AntiCipated Start date: 1/7/88 RECEIVED SA3/33a 12/8/87 Gas Cons. Comraissi0~ Anchorage ANNULAR PREVENTER PIPE RAMS 4 BLIND RAMS 5 TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSt STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1 / 16"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSUI:~ IS :~000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. dULY 28, 1986 ATTACIlMENT 1 PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY " ""~E-01A'~'' 2046401 '"~'~lE-Oh '--"'"20478 05/08/83 04/17/83 '"'"'1E-16j 20777 02/11/83 '"'"1E-27 '-"/ 20837 02/11/83 05/31/87 06/03/87 06/01/87 06/02/87 '"""~1G-06~"'"'-20890 07/28/84 06/23/87 1R-08~-''''' 21333 08/29/85 06/11/87 1Y-01 ~ 20933 10/15/85 06/09/87 1Y-02'~'''' 20941 03/30/85 06/21/87 ~1Y-07~' 20950 11/01/85 03/16/87 "'""1Y-08'--~ 20944 03/30/85 06/10/87 '"'"~2B-06,~ 21078 11/07/85 06/14/87 "~-2D-07~' 21080 07/12/86 06/17/87 "~2B-10j 21084 11/09/86 06/15/87 SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER SPINNER REINITIATED INJECTION REINITIATED INJECTION REINITIATED INJECTION REINITIATED INJECTION FOLEOWUP FOLLOWUP FOLLOWUP FOLLOWUP FOLLOWUP FO LLOWU P FOLLOWUP FO LLOWU P FOLLOWUP WELL COMPLETION A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C S A&C S A&C S A&C S ZONES TAKING WATER A&C A&C ABC ABC ABC ABC ABC A&:C A&C ABC ABC A&C A&C I NJ ECT I ON BWPD RECEIVED .AUG - 13..7 Alaska Oi~ & Gas Cons. Commission Anchorage Mr. C. V. May 27, 198. Page 3 Wel 1 Number 1L-5 1R-3 1Q-13 Well Number Date of Initial ~e~o~ ~'~ Injection Pr°file 11/19/85 "- - ~:' 3/21/86 11/16/85 3/18/86 Date of Initial Injection Date of Injection Profile 1Y-2 3/30/85 8/7/85 1Y-8 3/30/85 8/8/85 1Y- 12 3/30/85 8/10/85 1Y- 15 10/28/85 3/23/86 Well Number Date of I nitial Injection Date of Injection 2W-2 11/15/85 3/26/86 2W-8 11/15/85 3/27/86 2W-9 1/13/86 3/28/86 2W-10 11/15/85 3/29/86 2W-14 11/15/85 3/31/86 Wel 1 Number 2X-1 2X-2 2X-3 2X-6 2X-7 Profile Date of Initial Injection Date of Injection Profile 11/4/85 3/22/86 1/19/85 3/14/86 11/4/85 3/23/86 11/4/85 3/21/86 11/4/85 3/23/86 Well Number Date of Initial Injection Date of Injection Profile 2Z-3 2Z-14 2Z-16 11/4/85 4/3/86 12/2/85 4/2/86 12/1/85 4/6/86 VLF:pg:O051 RECEIVED MAYPO 1986 Amska Oil & Gas Cons. FEBRUAR'f 1.9, 1.986 716183 '1~-~ 1.0/?_9/83 1A-5 218182 lA-7 5/7/82 1125182 lA-9 3/23/83 1/19/83 lA-11 3/21/83 1A-12 3/8/8?- 411.182 1A-lA 6/5/82 lA-15 1A-16A 5/11/82 lC-1. 518181 lC-2 7/13181 lC-3 1118181 lC-4 319181 2/26/81 1C-5 :~11/30/81 1C-6 5/19/81 1C-7 5/21/$1 1C-B 15-1 12/26/81 6/25/81 15-2 1B-3 ll/16-1B/B1 3/12/82 18--6 11/18/B1 9/10/82 18-7 11/23/81 1B-$ 15-9 6/24/82 1D-T ~' l/BO 5/?_3/83 113-3 8/5/8o 113-4 7/30/80 811.318o 19-5 6111181 6/9/81 113-6 6/8/B1 113 ~13-8 i7WS-8~ 5/10/78 · Alaska 0il & 6as Co:~s ~ ....... Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ ~IQ_~~I 2/1785~ Drill Site Well No. Loq Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Dri 11 Si te 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/!2/83 1F-7 11/19/85 g ~I Alaska 0il & Gas Oons. A,ncl~ora~)e Lo9 Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment )~-~--. Page 3 Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~(l~6/. ~ 1Y-4 7/2/83 1Y'5 6/29/83 1Y-6 6/27/83 tY-8 6/22/83 1Y-9 6/20/83 )1~-~1~ 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Log Date 2C-4 2/19/85 2/28/85 2C-7 10/15/84 i2C~_ 16~12/11185 Drill Site Well No. Log Date 2Z - ' t2Z~_ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF: pg'O052 R C ED Alaska Oil & Gas Cons Corr.,. Anchorag~ Page 3 Drill Site 1¥ Well No. Log Date '-. i¥-i ~'x'- 6/6/83x,,,~ .~0/21/83/' ~lY-2 6/10/83~-~ %3/4/84.,,/ --~ 1Y-3 '~ 6/18/83 '1Y-4 "* 7/2/83 ,~Y-5 "~6/29/83 . Y-6 ~6/27/83 . "1Y-8 ~6/22/83 ~"~1Y-9. ~'6/20/83 ~- (-% ~l¥-ii "~5/10/83'--> ~ ~11/21/83/ 1Y-12 %5/25/83 1Y-13 "~5/27/83 '~1Y-14 "~5/13/83~-> '~5/18/83/ ~1Y-15 '"'5/29/83 ~ 1Y-16 ~'5/30/83'-., '"~10/23/83 ) "--,,, ,;,/~,/~y / Drill Site Well No. Log Date 2Z "2Z-1 ~2Z-2 .~ '~2Z-4 ~2Z-6 'NJ2Z-8 7/10/83 6/24/83~,. 7/19/83/ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site Well No. 2C --- 2C-4 '~' 2C-7 Log Date '"'z/19/85 \ ~' 2/28/85/' '"~1o/15/84 VLF:pg:O029 RECEIVED FEB 2 1 1985 Alaska 011 & Gas Cons. Conu~n Anchorage ARCO Alaska, In~-''~ Post Offic. .( 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-09-85 TRANS~]ITTAL NO: 5337 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLEKK ATO-1115B P.O. BOX 100360 ~NCHOkAGE, AK 995~0 ~C TRANSMITTED hEt<EWI~'~ ~P~E ThE ~OLL~ING ITCheS. KNOWLLDGE lA-3 f 8/11/85 1G-15 / 8/.9-10/85 1Y-8 J 8/8/85 1Y-12/ 8/11/85 2G-16 / 8/17/85 2U-1 ~-' 8/23/85 PBU "C" PBU "C" SANDS FLO%~ING PRESSURE GRADIENT "A" & "C" 5DS FLO~ING PRES~UP~E GRADIENT "A" & "C" SDS FLOWING PHESSUkE ~I{AD'IENT & PBU PBU "C" SANDS RECEIPT ACKN0~¢LEDGED: BPAE* B. CURkIER CHEVRON* D & DKILLING L. JOHNSTON MOBIL* NSK CLERK DIbT~IbUTION: w. PAShEK EXXON PHILLIPS OIL* J.. RATHMELL* ~~ ~.~-n~.~n SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary o! AtlanhcRichfieldCompany ARCO Alaska, Inc. '~ "- Post Office B~._ 0360 Anchorage, AlaSka 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in- duplicate are subsequent notices following wells at the Kuparuk River Field- Well Action Date Performed 1B-2 Fracture 6 / 1 4/85 1B-4 Fracture 6 / 1 4/85 1E-lA Cancel lation (Reperf) 1E-lA Cancellation (Frac) 1E-27 Cancellation (Frac) 1E-30 Polymer Proi ect 1/5/85 1F-6 Cancel lation (Frac) 1F-13 Cancel lation (Frac) 1G-1 Cancellation (Stressfrac) 1Q-5 Acidize 6/23/85 1Q-6 Acidize 6/24/85 1Q-7 Fracture 6/25/85 1Q-11 Cancellation (Frae) 1Q-13 Fracture 7/2/85 1Q-14 Fracture 7/1/85 1Q-15 Fracture 7/2/85 1Q-16 Fracture 7/2/85 1Y-2 Conversion 3/30/85 1~'¥i.~.8~~ Conversion 3/30/85 1Y-12 Conversion 3/30/85 2A-2 Conversion 3/31185 2C-8 Cancellation (Perf) 2C-14 Acidize 7/2/85 2H-15 Stimulation 6/30/85 2V-2 Conversion 5/16/85 on the If you have any questions, please call · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CON,,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. N~~p~SKA, INC. 3. Ac~resso. BOX 1 00360 , ANCHORAGE, ALASKA 9951 0 4. Lo~il~nF~_,~l LOCATION' 570' FNL, 1791' FWL, SEC. 1, T11N, R9E, UM BOTTOM HOLE LOCATION. 1443' FNL, 870' FWL, SEC. 1, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' (RKB) 6. Lease Designation and Serial No. ADL 25646, ALK 2577 7. Permit No. 83-62 8. APl Number 5o-029-20944 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-8 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On March 30, 1985, Kuparuk well 1Y-8 was converted from a producer to a water injection well. Injection will be in both the "A" and "C" sands. 14.1 hereby certify that the foregoing is true and correct to the best ~X~[~l~lge. Signed ,~, ,,~o~-~- ~ T~t,eOPERATIONS COORDINATOR . The space below for Commission use Conditions of Approval, if any: 7/16/85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 D~,. '--/,ion Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, I Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to stimulate Kuparuk Field well 1F-6~ and to convert the following wells: 1Y-2, 1Y-8, 1Y-12, 1Y-15 2A-l, 2A-2, 2A-3, 2A-4, 2A-5, 2A-6, 2A-7 2V-l, 2V-2, 2V-3, 2V-4 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JAN 0 4 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanflcRIchlieldCompany STATE OF ALASKA ALASKA kilL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-62 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20944 OTHER [] 4. Location of Well SURFACE LOCATION: 570 ' TllN, R9E, UM FNL, 1791' FWL, SEC. 1, BOTTOM HOLE LOCATION: 1443' FNL, 870' FWL, SEC. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 96' (RKB) I ADL 25646, ALK 2577 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-8 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other []~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is water sands. proposed that Kuparuk well 1Y-8 be converted from a producer to a injection well. The well has produced from both the "A" and "C" Injection will be into both sands also. ANTICIPATED START DATE: January 23, 1985. RECEIVED ,3 AN 0 4 1985 Alaska 0ii & Gas Cons. o0mmissi0n Anchorage 14. I hereby certify that the foregoing is,true and correct to the best of my knowledge. Signed Title OPI~,,RATTONS COORDTNATOR The space below for Commission use Date 1/3/85 Conditions of Approval, if any: 'lilll ~llltt[ lltl[I t~Y [~![ I:. $11lTIi~' Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO-Alaska, Inc. . 7., /-- ..... ,3,~: -, ,; ~,c',-,~ £--".- 277 5537 Date: 8/16/84 Transmittal No: 4685 Return To: ARCO ALASKA, %nc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ge, AK 99510 TZ'ansmitted herewith are the following items. /ndreturn one signed of this transmittal. copy Please acknowledge receipt CH FINAL LOGS 1Y-8 5/27/84 Run 1 CBL 5907 - 6407 Gearhart ~cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION D&M Drilling gy/~ J Geolo .... ~._/'~. Mobil NSK Operations Date:~'ms~a i];il & Gas Uons. C01311TIjSSj0rl Anchora0e W.¥. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith State of Alaska Sohio Union Well Files KIJP~K ENG ! NEERIF[3 'TRAN~¢I I"I-FAL #~ TO' William VanAlen ~: D.W. Bose/Shelby J. A~tthews Transmitted herewith are the fol lowing' PLEASE hE)TE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, ARO3 ALASKA, INr__,. ATI'N: gHEL.BY J. IVAT'FHD.~ - ATO/1115-B P. O. BOX 100360 A,Nt:]-DRAGE, AK. 99510 KUP~K ~ 1 NEERII"~ TO: SVi I Ii am VanA! en D. W. Bose/Shelby J. Matthews mitted herewith are the fol lowing ~/~LEASE RERJ~N RECEIPT TO: ARCO ALAS,V~, INC. ATFN: SHELBY J. MATFHB. Y5 - ATO/1115-B P. O. BOX 100360 A~~~E;E, AK. 99510 Alaska 0il & Gas Cons. gommissior~ Anchorage ARCO Alaska, Inc. Post Office Box ;00360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 23, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99S01 SUEJ~CT: 1Y- 8 Dear Mr. Chatterton: Enclosed are the well completion report and subsequent sundry report for 1Y-8. If you have any questions, please call me at 263-4944. Sincere ly, J. Gruber Associate Engineer JG'tw Enclosures Alaska Oil & Gas Cons. 6ommission Ar~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~--- ALASK/- .... ~L AND GAS CONSERVATION C. ,'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-62 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20944 4. Location of well at surface 9. Unit or Lease Name 570' FNL, 1791' FWL, Sec. 1, TllN, R9E, UM LOCATIONS:' Kuparuk River Unit At Top Producing Interval VERIFIED 10. Well Number 1120' FNL, 1048' FWL, Sec. 1 , T11N, R9E, UM 1Y-8 Surf. ~ J At Total Depth B.H. -~ [ 1 1. Field and Poor 1163' FNL, 905' FWL, Sec. 1, T11N, R9E, UN ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 96' RKBIADL 25641 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/27/83 05/02/83 05/31/83I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 6600'MD,6377'TVD 6471 'MD,6254'TVD YES7~] NO []I 1837 feet MD 1350' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/FDC/CNL/Ca 1 , CBL/CCL/GR/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.8# H-40 Surf 78' 24" 251 sx AS II 9-5/8" 40.0# J-55 Surf 2213' 12-1/4" 1000 sx AS Ill & 250 sx A,~ I 7" 26.0# J-55 Surf 6557' 8-1/2" 450 sx Class G 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) 6110 ' -6180 ' 3-1/2" 6038 ' 6009 ' 631 2 ' -6328 ' 6343'-6359' w/1 2 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED N/A 27. N/A PRODUCTION TEST Date First Production I Method Of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · : · Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :" iGEOLOGIC MARKERS .: - . 'FORMATION TESTs NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6110' 5911' N/A Base Upper Sand 6181I 5978' Top Lower Sand 6291 ' 6083' Base Lower' Sand 6411' 6197' 31. LIST OF ATTACHMENTS Drilling History, Completion Summary~ Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engr. 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- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 1Y-8 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2000 hrs, 04/27/83. Drld 12-1/4" hole to 2245'. Ran 56 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2213'. Cmtd 9-5/8" csg w/lO00 sx AS III & 250 sx AS I. ND Hydril & diverter. Install 7" casing spool & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. 'Drld FC, cmt, FS and 10' new form & tstd form to 12.0 ppg EMW - ok. Drld 8-1/2" hole 6600' TD as of 05/02/83. Ran triple combo logs (DIL/SFL/SP/GR/FDC/CNL/Cal) f/6554'-2213'. Ran RFT. Ran 166 jts 7" 26#/ft J-55 csg w/shoe @ 6557'. Cmtd w/450 sx Class G cmt. 6471' PBTD. Bumped plug & tstd csg to 2000 psi. ND Hydril & diverter, displ top 360' of well w/diesel. NU tree & tstd to 3000 psi. Secured well & released rig @ 0430 hrs, 05/05/83. HILL/DH11 06/13/83 1Y-8 COMPLETION SUMMARY RU Gearhart. Ran CBL/CCL/GR/VDL f/6425'-2062' Ran Gyro. RD Gearhart. Accepted rig @ 1500 hours, 05/29/83. ND tree. NU BOPE & tstd - ok. Perforated the following intervals w/12 spf, 120° phase' 6110'-6180' 6312'-6328' 6343'-6359' Ran 3-1/2" completion assembly w/tail @ 6038', pkr @ 6009' & SSSV @ 1837'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 2000 hours, 05/31/83. GRU3'CS3 ARCO ALASKA, INC:. PAD 1Y., WELL NO'.. 8 SIG-GYRO/MMS ._lOB NO:A05:::3Z0135/SOl~::4 KUPARUK FIELD, NORTH SLOPE, ALA'._::KA SIGMA GYRO 0-2200 MD, MMS 2200-6600 MD '.--;URVEYOR: F'EFFERKORN GYRO: 746, PROBE: 067, MMS CAMERA: 1488, 0-90 DEG. A/U: FORESIGHT: N89 46W SURVEY TAKEN FROM ROTARY VERTICAL ~'.:.Ep'_.I ION CALCULATED IN PLANE OF F'ROPOE:AL DIRECTION: S 46 BEG. :31 MIN. W RECORD OF' SURVEY RADIUS OF CURVATURE ME"rHOD ARCO ALASKA, INC:. F'AD 1Y, WELL NO: 8 SIG-GYRO/MMS KUPARUK FIELD, NORTH :--:LOF'E, ALASKA .JOB NO: AO58:3Z0135/'S0134 COMPUTAT I ON T I ME DATE 15: 29: 19 01 - d U N- 83 ~-' AGE NO. 1 TRUE MEASURE1] DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L 0 S U R E I)OGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION ',--~EVERIT' FEET D M D M , FEET FEET FEET FEET FEET FEET D M DG/100F 0. 100. 200. 3oo. 400. 500. 600. 700. 800. 900. 0 0 0 0 O. 0.00 0.00 -96.00 0.00 0. O0 O. 00 0 0 0.00 0:30 '.E; '23 0 W 100. 100.00 0.40 4.00 0.40 8 0,17 W 0.44 S 2:3 0 W 0.50 0:30 S 16 0 W 100. 199.99 1.18 103.99 1.22 S 0.46 W 1.:31 S 20 4.0 W 0.06 0 15 8 12 0 E 100. 299.99 1.64 203.99 1.87 S 0.48 W 1.93 S 14- 30 W 0.30 0 45 S 15 0 E 100. 39~.99 2.08 303.99 2.72 S 0.28 W 2.74 S 5 53 W 0.50 0 45 S 16 0 E 0 45 S 30 0 E 0 45 S 39 0 E 0 30 S 44 0 E 0 30 S 41 0 E 100. 499.98 2./..9 403.9::: 3.98 8 0.07 E 3.98 S I 0 E 0,01 100. 599.97 3.15 503.97 5.18 S 0.58 E 5.22 '.S 6 23 E 0.18 100. 699.96 3.35 603.96 6.26 S 1.32 E 6.40 S 11 54 E 0.12 100. 799.96 3.39 703.96 7.08 S 2.04 E 7.37 S 16 6 E 0.26 100. 899.95 3.40 803.95 7.72 S 2.63 E, 8.16 S 18 49 E 0.03 1000. 1100. 1200. 1300. 1400. 0 30 S 50 0 E 0 45 S 49 0 E 0 15 S 23 0 E I 0 S 11 0 E I 0 S 11 0 E 100. 999.95 100. 1099.94 1 O0. 1199.94 100. 1299.93 100. 1399.92 3.37 903.95 3.26 1003.94 3.37 1103.94 3.86 1203.93 4.79 1303.92 8.:33 S 3.25 E 8.95 S 21 20 E 0.08 9.04 E; 4.08 E 9.92 S 24 18 E 0.'.."'5 9.74 S 4,59 E 10.77 S 25 14 E 0.54 10.7.9 $ 4.91 E 11.85 S 24 29 E 0.76 12.49 8 5.24 E 1:3.55 S 22 4/-. E 0.00 1500. 1600. 1700. 1800. ( ' 900. 2000. ~::. 100. 2200. I 45 8 :,-: 0 E :2 15 S 25 0 E 2 30 :--; 28 0 E :3 0 S 26 0 E 4 15 S 27 0 E 4 15._~ ~' :~A_. ~!~ E 4 :BO $ 37 0 E 5 0 S 40 0 E 100. 1499.89 100. 1599.83 100. 1699.74 100. 1799.63 100. 1899.42 100. 1999.15 100. 2098.86 100. 2198.51 6.14 1403.89 7.71 1503.83 8.92 1603.74 10.28 1703.63 12.13 180:3.42 14.05 1903.15 15.37 2002.86 16.09 210:2.51 14.6:6 S 5.64 E 15.90 S 20 47 E 0.75 18.20 $ 6.63 E 19,37 S 20 I E 0.77 21.90 8 8.4.7 E 23.48 8 21 9 E 0.28 26.1:3 S 10.65 E 2:::. 26 S 22 9 E 0.51 31~84 8 13.47 E 34.57 S 22 56 E 1.25 :38. '-'= - ? · :,._, 'S 17.01 E 41.95. S ;~3 .~] .... '=, E 0 .... 2 44.71 8 21.22 E 47~.48' S 25 23 E 0.59 51.18 S 26.37 E 57.58 S 27 15 E 0.56 220o MD IS MM'._:; TIE IN POINT FROM F'REVIOUS E/W SIGMA-GYRO 2337. 2440. 5 15 S 50 0 E 5 15 S 51 0 E 1:37. 2334.96 103. 2437.53 15.76 2238.96 14.61 2341.53 59.83 S 35.01 E 6?. 32 $ 30 20 E 0../:.8 65.8:2 S 42.29 E 78.24 S 32 43 E 0.09 25:3:3. 5 15 S 4!5 0 E 93. 2530.14 2626. 5 0 S 39 0 E 93. 2622.77 2719. 4 30 S 33 0 E 93. 2715.45 13.94 2434.14. 14.16 2526.77 15.16 '2619.45 71.51S 4.:3.61E 86.47 $ 34 12 E 0.59 77.69 S 54.16 E 94.70 S 34 53 E 0.64 83.91S 58.69 E 102.40 S 34 58 E 0.76 ARCO ALASKA., INC. PAD 1Y. WELL NO: 8 :=':IG-GYRO/MMS KUF:'ARUK FIELD, NORTH SLOPE~ ALASKA ,_10 B N 0: A 05 :=: :3 Z 01:35 / S C) 13.4 COMF'UTAT I ON T I ME DATE 15: 29: 19 01 -,_1U N-r-': :3 ,* , PAGE 'NO. ':.:: TRUE MEA'.::URED DRIFT DRIFT COURSE VERTICAL VERTIF:AL .... SI IBSEA R E C T A N A U L A R C L A ¢'._, I1_ R E DOGLEG DEPTH ANGLE DIRECTION LENi3TH DEPTH '.:;ECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F] 2:311. 2.904. 2'P'.:./7. :..:.: 0'.:.~0. ::: 1:3:3. (' ..::276. :3:369. 3462. 3555. ::.=.:64:=:. 4 30 S 2'~ 0 E 4 15 ::; 27 0 E :3 45 S~_,_'-:'R A. E 3 30 c..., 29 0 E :3 0 S 34 0 E 2 45 S 34 0 E 2:30 S :37 0 E 2 15 S 38 0 E 1 45 S 34 0 E 4 0 S 36 0 W 2. 2:::07. 1'7 16.72 2711. 17 9A. 10 S 62.41 E 109.60 S :2:4 4. '2 E (').:34 .9:::. '-'~'¢'¢~ 90 8. ~, 65 74 E 116.65 $ 34 l:E: E 0 2:1 . -'o :.- :.. I 62 2803.90 96.36 c' . . :3. 2992.67 20.40 2896.67 102. 12 'S /=,:s:. 7:3 E 12:3.09, S :3:3 57 E 0..54 9::: '-'¢ ~'=. . 2'.'}:E:9 107 29 .Z: 7 I 54 E 12:::. 95 '.-=: :3:3 42 E 0.2 _. .:,) ..... , 4:z: 21 92 .48 . ' · 'r--¢:3. :3178. :3:3 23. 02 3082. 3:.]: I 1 i. 78 S 74.25) E 134.22' S :3:3:37 E 0./=,2 .93. 3271.22 23.78 3175.22 115.65 S 76.'.'.70 E 138.88 S 33 37 E 0.27 'P3. 3:364. 12 24.38 3268. 12 119. 11 S 73.~.:37 E 143. 14 S 33 41 E 0.31 93. :3457.04 24.78 3361.04 122. 17 S 81.72 E 146.98 S 33 47 E 0.27 '.-.? 3. :::_ .~_ 4'.~.. 98 '-'..'-...,'- .20 '-'._-, 4 .~'-'._ ._-, . ':~.. :::. 1 24. :3 A. ~--:; q'-':, .6:3 E 150.. 9... ,,.?S .:,""'-'._-, 5 ...... (') E 0. ~ z-., 93. 3642.86 2::. 27 3546.86 129.1 :Z: S 83.55 E 153. :-]:4 '.=: 32 5;4 E 4.0/:, 3741. 8:30 S 56 0 W :3834. 1:3 15 :=; 57 0 W 3926. 17 45 '.S 54 0 W 4. n l':.~ 19:30 '=' F, 5 0 W 4112. 20 45 S 55 0 W 4205. 22 0 S 5/_-, () W 429R. _. .-'.:,'-"-' 0 ,.~'-' 55 0 W 4~:'--.~1 24 15 ¢' .~':' A W -- . . ._1._ 12., . 44:=:4. 25 15 :=; 60 0 W '577 2/_-, 30 ¢' 61 0 W 4670. 27 :=:0 S 61 0 W 47/-,3. '-"-' ':' 6.'3 0 W _. ~:,:,4.5 .., 4856. 28 15 S 6:3 0 W 4948. 27 ~:_0 .., ¢' 64- 0 W 5041. 27 0 S 64 0 W 93. 3735.28 38.34 3639.28 93. 3826.59 55.61 3730.59 92. 3915.22 79.89 :3819.22 ~3. 4003.34 10~.30 3907.34 93.' 4090.6~ 140.~5 3994.66 . 4L}c, 1 27 .'.~.:,. 4-177.27 174 43 ' ~' .-93. 4263. 18 20.9.58 4167. 18 .93. 4348. :39, 246.28 4252.39 .93. 4432.84 284.29 4336.84 93. 4516.52 323.68 4420.52 9:3. 4599.38 .93. 4681.40 ~:3. 4763.13: ..~.. 4844.45 .9:3. 4927.13 :364.55 4503.:38 406.80 4585.40 449.35 4667.13 490.49 4748.45 531.11 4831.13 1:2:6. 17 S 76.._.':'1 E 145.85 $ 61.68 E 159.77 S 41.42 E 177.02 ._"=; 17 . ~.-'-'=; E 195.37 :-3 8.97 W ~- c. 36 S~0 W 214.._ 7 .... 234.73 S 66.23 W 255.30 $ 97.30 W 275.35 S 13£).67 W 23~5.33 $ 166.00 W 315.80 S 202..92 W · :,.:.6...,":'-'=',~, ._, ":' 241 . 63 W · -, I..~- · · :,._6,5:~ S 2:=:1 17 W 375,72 S :319,66 W :=:?/4, 3.9 :=; 357, ':.74 W 156.09 S 2'? 16 E 158.36 S 22 ..=.;5 E 165.06 S 14:32 E 177.8/_", S 5 34 E 195.5:=: S 2:38 W 217.72 S 'P 45 W 243.8.9 S 15 45 W · -i ,'"I . . · ., 7,:.. 21 S 2'(') 52 W 304.7:3 S 25 2:3 W 33E:.7'F~ S 29 2.0 W :375.38 S 32 43 W 414.17 S 2:5 41 W 454.06 S :38 16 W 4.'..:,.31 S 40' 2:3 W 532.60 S 42 14 W 5. :::0 5.11 4.97 1. S~I 1. :34 1.40 1. 15 1.8/=, 1.40 1.42 1.08 1.68 0.54 0.96 0.54 51:34 26 4.5 c. 65 0 W 5227. 25:30 S 64 0 W ri::;.'=: 2~')'='.~ 0 c- 66 ~') W 541:3. 24 45 S 65 0 W 550,/=.. 23:30 '.:: 66 0 W 9:3. 5010.0.9 93. 5093.58 93. 5177.70 93. 5262.07 ~3. 5346.~5 571.09 4914.0~ 610.04 4997.58 647.66 5081.70 684.66 5166.07 720.60 5250.~5 412.49 S 395.,'5:8 W 4:30.12 S 432.84 W 446.c'o ':' 4/-"=' 79 W i.i i;i .I, -- __l I__1 II · 46::-:. 10 S 504. :3':.-/ W 478.87 S 538. ?8 W 571.72 S 43 49 W 610.21 S 45 11 W 647.67 S 46 ';i:2 W 684.75 S 4,7 27 W 72A..9.,_,~' $ 48 23 W 0.56 1.4:}.': 1.06 0.5:.?, i .41 ARCO ALASKA, INC. PAD 1Y, WELL NO: 8 SIG-OYRO/MMS KUF'ARUK FIELD, NORTH :SI_OPE, ALASKA COMPUTAT I ON TI ME DATE] 15: 2 9: 1 '? 01 -,_1U N- 8:3 TRUE MEASUREEI 1]RIFT DRIFT COURSE VERTIE:AL VERTICAL '.--;UBSEA R E C T A N O I_1 L A R C L 0 S I_1 F~ E TiOGLE:G DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R n I N A T E ..E; DISTANCE DIRECTION SEVERI"r FEET D M D M FEET FEET FEET FEET FEET FEET D M DO/1 55'P9. 22 30 S 66 0 W 56'P2. 22 15 S 70 0 W 5785. 21 15 S 71 0 W 5878. 20 30 S 74 0 W 5970. 19 30 S 73 0 W ~'~ ,.:,063. 18 45 :E~ 74 0 W 6156. l:E: 15 8 72 0 W 6248~. 18 0 S 74 0 W 6342. 17 45 S 73 ~'~ W '/:,435. 17 15 S 74 0 W 93. 54:32.55 754.86 5:336.55 48-*:3.65 S 572. 18 W 755.69 S 4'P 1:3 W 1 · 0:--': ?3. 5518.55 787.79 5422.55 506.'Pl .5; 604.97 W 78'P.29 ::; 50 2 W 1.66 'P3. 5604.73 819.28 5508.73 518.41 S 6:37.48 W 821.66 S 50 5:3 W 1. 15 ?3. 5/-',S.~ 1.82 849'. 06 5595.82 528.37 .5: 667.08 W ::.:52.55 S 51 42 W 1.40 · _,6,--', .-' .~.'-, ,-,,z: ,-, ~ - %'::, -" ' 9. 2. 5 7 7 8.2 7 8'7 7 .10 ~- '~'-' .2 7 ._ .:, 7. :31 :S A_ '-.-~. '~.. , '-.-' 5 W ,_,,_ 1 . ,:,.J :5 ....,- '.-' :d W 1 . 15 S~3. 58/_-,6. 14 ?04.25 5770. 14 93. 5~54.33 930.67 5858.33 ~.~3. 6042.72 S~5/_-,. 56 5946.72 '~3. 6131.23 ?82.00 6035.23 ~3. 621~. 93 1006. ~.~2 6123.93 545.96 S 728.46 W 910.3:5 -5; 5:-:: '.--.~ W 0.8:E: 554.59 S 756.68 W 938.16 S 53 46 W 0.87 563.05 ,.E; 784.35 W 965.52 S 54 20 W 0.72 571. 16 $ 811.72 W 992.52 S 54 52 W 0.43 579.10 S 838.53 W 101'.~.06' S 55 22 W 0.63 PRCkJEC:TED TO 6471 MD - F'BTD 6471. 17 15 ._,c' 74 ~'~. W 582.()4 .5; 848.79 W 1029. l:E: F; 55 :'::4 W 0. ('~(.') PRO,_IECTED TO 6600 MD - TD FINAL. CLOSURE .- DIRECTION: D I oTANL. E · :3 ~... 6 D E [.; ::~_ 1 '2 M I hi S 4 C) '-'::,E F'~''_..:, W 1065,54 FEET ARCO ALASKA, INE:. PAD 1Y, WELL NO: 8 SIG-GYRO/MMS dOB NO:AO583ZO135/S0134 KUI='ARUK FIELD, NORTH :E;LOPE, ALASKA SIGMA GYRO 0-22(~0 MD, MM.S 2200-6600 MD '.:;URVEYOR: F'EFFERKORN GYRO: 746, PROBE: 067, MMS CAMERA: 1488, 0-'.-}0 DEG. A/U: I:::ORESIGHT: N89 46W SURVEY ]'AKEN FROM ROTARY RECORD OF INTERPOLATED SURVEY ARCO AI..ASKA, INC. F:'AD 1Y., WELL.. NO: r-': SIG-GYRO/MMS K[JF'ARUK FIELD, NCIRTH SLOPE~ ALASKA .JOB NO: A058:3 Z 01 .:--:5 / SCi 134 COMPUTAT I ON T I ME DATE 15: 51: 12 01-JUN-8:3 PAGE ............. MARKER- CODE NAME TRUE SUBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C: T A N O U L A R C: L 0 S U R E VERTICAL DEPTH DEPTH BIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP UF'PER SANDS BA'.E;E L]F'F'ER SANDS TOP LOWER SANDS · _ .=,AND.=, BASE I_CfWER '" ~' 6110.00 5'~ 10.71 1'.~9. :3 5814.71 6181.00 57~78. C)9 202.9 5882.0.9 Z_-.2'.T~ 1.00 6082. Z_-.'~ 208. :3 5':.-~86.69 6411.00 617~7.04. 214.0 6101.04 550.32 S 742.72 W 556.86 S 764.1'2 W 566.71 S 7'.-.-~6.71 W 577.05 :-q 8:31.61 W 924.39 S 53 28 W 945.50 S 53 55 W 977.70 S 54 35 W 1012.21 S 55 15 W Suggested form to be inserted in each "Active" well folder to check for timely ccmpliance with our regulations. ~ .~O~r~at°r, ~/.'~-/~/-~ ' . 'W~i ~Nan~ and Number Reports and Materials to be received by: _Required Date Received Remarks - C°mPl etio n Report Yes. Wel 1 History Yes . ,. . . , , . . Samples · .Core Chips . ,, Registered Survey Plat Inclination Survey Directional Survey ........ Drill Stem Test Reports · . .. , Production Test Re~orts X)/~.~- ~ ~ ~, ~ ..... ~)~ / Digitized Data. , ~-*--'- STATE OF ALASKA '~" ALASt' ¢ILAND GAS CONSERVATION JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL XI~ OTHER [] 2. Name of Operator 3. Address Location of Well Surface: 570' FNL, 1791' FWL, Sec. 1, T11N, R9E, UN 7. Permit No. 83-62 8. APl Number 50-- 029-20944 9. Unit or Lease Name K. par,Jk River Unit 10. Well Number 1Y-8 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool Check Appropriate Box/o/nd~cate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~[~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X~ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Gearhart. Ran CBL/CCL/GR/VDL f/6425'-2062'. Ran Gyro. RD Gearhart. Accepted rig ~ 1500 hfs, 05/29/83. ND tree. NU BOPE & tstd - ok. Perf'd the following intervals w/12 spf, 120° phase: 6110'-6180' 6312'-6328' 6343'-6359' Ran 3-1/2" completion assy w/tail ~ 6038', pkr ~ 6009', & SSSV ~ 1837'. ND BOPE. NU tree & tstd to 3000 psi. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig ~ 2000 hrs, 05/31/83. RECEIVED JUN 2 ~ '~.'~ Alaska Oil & Gas Cons, Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (/~/'.~C~,~~ Title Area Drilling Engineer The space b/~ C/mission use Condi?~ Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU3/SN23 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Enclosed are the Monthly State Reports for the following wells' * West Sak SWPT #1 * Ciri Wolf Lake 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14 2Z-1 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to the confidential material contained in these reports, please handle and file in a confidential manner. Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH7'sm Attachments RECEIVED JUN 2 0 i,983 Alaska Oil & Gas Cons. Commis$ior~ Anchorage STATE OF ALASKA .~--, ' ' ALASK,~' }ILAND GAS CONSERVATION C .~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellX~[ Workover operation [] Name of operator 7. Permit No. ARCO Alaska, Inc. 83-62 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20944 9. Unit or Lease Name FNL, 1791' FWL, Sec. 1, TllN, R9E, UM Kuparuk River Unit 4. Location of Well 570' at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 67', 96' RKB j 6. Lease Designation and Serial No. ADL 25641 ALK 2577 10. Well No. 1Y-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2000 hrs, 04/27/83. Drld 12-1/4" hole to 2245'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6600' TD. Ran logs. Ran RFT. Ran, cmtd, & tstd 7" csg. Displ top 360' of well w/diesel. Secured well & released rig ~ 0430 hrs, 05/05/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#/ft, J-55, BTC csg w/shoe ~ 2213'. Cmtd w/1000 sx AS II I, 250 sx AS 7" 26#/ft J-55 BTC csg w/shoe ~ 6557' Cmtd w/450 sx Class "G" cmt I . 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/Cal G~ro - f/6554' to surf. f/6554'-2213' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A JUN [~u .L ...~ '.J '~: : ,.. Gas 6oils_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / / -/ · fi~ed in duplicate with the Alaska NOTE--Rep,~oi, u,is uu,,,, is required for each calendar month, regardless of the status of operat,ons, andmustbe Oil and Ga~Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate 1Y-8 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2000 hrs, 04/27/83. Drld 12-1/4" hole to 2245'. Ran 56 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2213'. Cmtd 9-5/8" csg w/lO00 sx AS III & 250 sx AS I. ND Hydril & diverter. Install 7" casing spool & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS and 10' new form & tstd form to 12.0 ppg EMW - ok. Drld 8-1/2" hole 6600' TD as of 05/02/83. Ran triple combo logs (DIL/SFL/SP/GR/FDC/CNL/Cal) f/6554'-2213'. Ran RFT. Ran 166 jts 7" 26#/ft J-55 csg w/shoe @ 6557'. Cmtd w/450 sx Class G cmt. 6471' PBTD. Bumped plug & tstd csg to 2000 psi. ND Hydril & diverter, displ top 360' of well w/diesel. NU tree & tstd to 3000 psi. Secured well & released rig @ 0430 hrs, 05/05/83. HILL/DH11 06/13/83 KUPARUK ENGINEERING TRANSMITTAL - . TO' William Van Alen FROM' D.W. Bose/ShelbS J. Matthews DATE' , ~--/j~- ~ . , Transmitted herewith are the PLEASE NOTE: BL 'BLUELINE, S - SEPIA, F - FILM~PC - PHOTOCOPY , /}5 "~ ~/'-~''~"~;"':'~" --.I,/ :;: i.:~, ~)-' ,--: .... ,,-~ .... .,., ,/,,?, .:.:-/ , R/E~..I~ PT ACKNOWLEDGED: PLEASE RETURN RECEIPT · DATE':., , ~ q\\ 8, ¢~.:,s oo,~s. Oo!;omm~io'-n ARCO A~ASKA, INC. A'I-FN' SHELBY J.. MATTHEWS - AFA/311 P.O. BOX 350 ANCHORAGE, AK.- 99510 ARCO Alaska, Inc. " Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: gnclosed are the Monthly State Reports for the following wells- 1Y- 16 1Y-1 1Y-2 1Y-3 ~lY-8 1Y-9 1Y-10 Ravik State #1 2Z-8 Ugnu ~T #1 ltrest Sak ~'~T #1 Sincerely, · A. VanDusen District Drilling Engineer PAV/SH:tw Attachments STATE Or: ALASKA ~- ALASKA L,,- AND GAS CONSERVATION CC ~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX~ Workover operation [] 2. Name of operator 7, Permit No. ARCO Alaska, Inc. 83-62 3. Address 8. APl Number 029-20944 P. O. Box 360, Anchorage, AK 99510 50- 9. Unit or Lease Name FNL, 1791' FWL, Sec. 1, TllN, R9E, UM Kuparuk River Unit 4. Location of Well 570' at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 67', 96' RKB 6. Lease Designation and Serial No. ADL 25641 ALK 2577 10. Well No. 1Y-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of April , 19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2000 hfs, 04/27/8:3- Drld 12-1/4" hole to 2245'. 9-5/8" csg. Drld 8-1/2" hole to 4622 as of 04/30/8:3 SEE DRILLING HISTORY Ran, cmtd, & tstd 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#/ft, J-55, BTC csg w/shoe ~ 2213'. Cmtd w/lO00 sx AS Ill, 250 sx ASI. 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ........ ......... .... NOTE--Re o~rt/~-~"~';is,~rm~s rec~ired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and ~s Conservat/fon Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate KUPARUK RIVER UNIT 1Y-8 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2000 hrs, 04/27/83. Drld 12-1/4" hole to 2245'. Ran 56 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2213'. Cmtd 9-5/8" csg w/lO00 sx AS III & 250 sx AS I. ND Hydril & diverter. Install 7" casing spool & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS and 10' new form & tstd form to 12.0 ppg EMW - ok. Drlg 8-1/2" hole to 4622 as of 04/30/83. HILL/DHll 156 ~ , LOCATED_ IN. PROTRACTED ....... SEC~I,'TWP, IIN:~ RGE. 9 E,, UMIAT M, ER!DI,A,N 21~-- ............. , ...... ~ PHASE II ~' .PHASE I Y=5975115.33 4. X= 55146024 LAT. ?0° LONG. 149° 44'40.818" 211 ' FNL , 1792' FWL Y=5975 II 5.:50 5. X-- 551520.06 LAT. 70° 20'55.02:96" LO .I~G. 149°44' 59.070' 211 FNL,,185:>' FWL Y' 5975115.54 6. X' 5:51580.12 L AT. 70° 20' 55.0:>75' LONG. 149°44'~7. :515" 211' FNL, 1912'FWL Y; 59'/'5 II 6 A4 X= 55164:0.45 LAT. 70° ;[0' $5.0~60" LON B. 149°4~' $5.552" SURVEY I 2 'D.8. A VICINITY MAP Scale': I%lmi. NOTES' .'1. ALL Y 8~ X COORDINATES ARE ALASK/) STATE PLANE,ZONE 4. ~'. DISTANCES' TO SECTION LINES ARE GEODETIC. ~ SEE REE DWG. 2~29BB, SHl: 7Y'I2-3OOI,REV. 7A. 4. DRILL SITE AND Y 8~ X COORDIr~&TE$ ARE : BASED ON MONUMENTS I'Y EAST AND' I'Y MIDDLE BY LHD ASSOClATE~. 5, EL. BASED ON MON. I.Y MIDDLE BY t..:tD ASSOC. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPF~RLY REGISTERED AND LICENSED TO PRACTICE LAHD SURV~_YINB IN ,THE STATE OF ~, ALASKA~ AND THAT THIS PLAT'REPF~'2SENT3 A SURVEY MADE UNDER MY DIRECT SUPERVISION~ ANDTH/~T ALL DETAIL3 ARE CORRECT AS OF' MARCH I, 198:5. 2 I1' FNL, 1975' FWL , I I IL I . I ~ ~ .... ~----- i. ~' I I I I · II I ':'""'°""' ' '. X, 5] 164~,4~ P ~ ' X, 551 ~2~21 . I ~, ~~ ~ Kup~ruk ;:roJact North Slope Drlllln~ LAT. 70°20 51.4857' LON~So~' '~ D.S. IY CONDUC~RS '; 56.697 ~NO. le°~'Sg, llO' i ti UB'~J I 5ZI' FNL, 1971'FWL I '571' FNL,le~I' FWLIliF'~l &~ .I AS BUILT LOCATIONS ~T.~0~20'~1.488 .' LAT.~O 20Sl.48Sl LONe-i~9°~'57.~B1" LON~.I4S°~'40.S~4"I' [~l~l~l~ '1'-"'r:"i98~ i ,~l,: i",~O0' 571'FNL~ 19il' FWL ~70' ENL~I791~FWL I~~~1 ldrawn by:J.D.' . ldwg. no.9.05'~5.12d28 ...... , !Z'~'," . ., t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface' 570' FNL, 1791' FWL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' RKB 12. 6. Lease Designation and Serial No. ADL 25646 ALK 2577 7. Permit No. 83-62 8. APl Number 50-029-20944 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-8 11. Field ~nd Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows' 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the.BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with' 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRABOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli 'withifi the permafrost interval A 5000 p's~ WP wireline lubricator will be used and tested on .all wireline work. T~e subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start' 05/14/83 Subsequent Work l~eported 14. I hereby certi~that the foregoing is true and correct to the best of my knowledge. _ Signed Title Area Drilling Engineer Date ~' ~--~ lhe space f~o~ission use Condition~of Aoproval, if ang: Approved by BY LOUNIE C. SMITil Approved Copy ]~eturned ., By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 9, 1983 Mr. C., V. Chatterton Commissioner State.of Alaska Alaska Oil & Gas ConserYation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-8 Dear Mr. Chatterton' Enclosed is propose to a Sundry.~Notice for the subject, we.Il, We comple.te this' well with our workOver rig. Since we expect t° start this'work'on May 14~ 1983,. your earliest approva'l will be ~appreciated, If you haVe~ any questions, please call .me at 263-4970~ Sincerely, JBK/JG'sm Enclosures ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany Comings sioner MEMORANDUM State of Alaska ALASKA OIL A~D -GAS CONSERVATION COMMISSION C. V e on DATE: May 9, 19 83 Chai FILE NO: TELEPHONE NO: FROM: Edgar Petroleum Inspector SUBJECT: Witness BOPE Test On ARCO's Kuparuk 1 Y8 Sec. 1, TllN R9E UM Permit No. 83-62 Parker Rig 141 Thursday, April 28, 1983: I travelled this date from ARCO K~aparuk Base--camp ~o witness a BOPE test on ARCO Kuparuk's 1-YS, Parker Drilling Rig 141. The Drilling contractor was in the process of nippling up. F_riday,.AP_ril 29, 1983: The'BOPE test commenced at 6:15 a-m. and was concluded at 8:15 a.m. There were no fa i!ures. I filled out the AOGCC BOPE test on ARCO Kuparuk's 1-YS, Parker Rig ~7o. 141. There w~re no failures. 02-00IA(Rev. 10/79) O&G ~4 ~?so STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COHMISSION B.O.P.E. Inspection Report Inspector Well I7' Location: Sec 7 T~ R ~ ~ ~. Drilling Contractor , ~[~ , Date. Zell Representative Pe rmi t ~ ~3- .~/~ Casing Set . . Representative Location, General Well Sign General Housekeeping Reserve pit Rig ' ACCU~,IULATOR S'YSTEH Full Charge Pressure ~/~r-O ps.i9 ~,~ Pressure. After Closure /qCDO psig ,pla 200 psig Above Precharge Attained: ~ rain ~Osec ~1' ~ Full Charge Pressure Attained: ~ rain ~f sec' N2~Co~ ~(~b,f~'. ~ ..... ~V~-o psig %~ BOPE Stack An n.~l~-r _Preventer Pipe Rams Blind R~s Choke Line Valves H ,C. R..Valve/ Kill Line Valves Check Valve Cqntrols: Master Remote Blinds switch cove_r Test Pressure Kelly and Floor Safety Valves - ! ~o Upper Kelly. ~ Test Pressure 3,Q ~ ~ Lower Kelly. ~st Pressure 30~ ~ Ball Type o~ Test Pressure ~0~ ~ Inside BOP ~-Test Pressure .... ~ ~ Choke Manifold Test Pressure ~ No. Valves Adjustable Chokes.._ }lydrauically operated choke Test Results: Failures' ;~ -~- Te ~" St TJ~a-~' .... ~J --hrs. --i~ -,. ~ !~ ~ _ ~= Repair or Replacement' of failed equipment to be made within ~:days and'~[~9(~(~ Ins~ctor/Com~ssion office notified. . Distribut:ion orig.' - AO&GCC cc - Operator cc - Supervisor. April 12, 1983 ~fr. Jeffrey = Kewin Senior Dr il ling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 · P- it Re. Kuparuk ~iver Un 1Y-8 ARCO Alaska, Inc. Pe~it ~ . ~83-62 ~ ' Sec Sur. Loc. 570'~L, !7~.~ F~,, . .~, ~., , . ~- ~--~ ~-~L, 870' Sec. 1 ~.~u~e Loc. 1443' ' ~/L, , ~ .., ~ ~, · Dear Mr. Kewin: ~nc~o~e~ is the sDproved aoplication for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of r ~,~ · . Samples of well cuttings and a recovered core is _eq~red tog are not required. A continuous directions] survey is required as per 20 AAC 25.050(b)(5). if available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dip~eter surveys.. ~-~an¥ rivers in ~laska and their drainage systems have been classified as important for the spa~ing or n~gration of anadr~.ous fish. ~peratzons in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (~:ztl~'~ e 5, Alaska Administrative Code). Prior to comm. encin~ operations you [nav be contacted by the Habitat Coordinator s Ozz~ce==', Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal IJater Pollution Control Act, as a~ended. Prior to cot]~encing operations you ~ay be contacted by s representative of the Department of E~vironmenta! Conservation. To aid us in scheduling field work, please notify this office 2~ hours orior~ to cor~encin~ ins''~=,~latio" of the blowout Mr. Jeffrey B. k~win Kuparuk River Unit 1Y-8 -2- April 12, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system, is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In ~the event of suspe .szon or abandor~ent, please give this office adequate advance notification so that we may have a witness 'present. y_.~. truly your s, C, V, Chatterton Chairman of ~¥ ORDSR O~ THE CO~,~,,,~,N Alas~m Oil and GaS Conservation Co~ission Ene 1 o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office Bc,~ 360 'Anchorage, Alaska 99510 Telephone 907 277 5637 April 4, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-8 Dear Mr. Chatterton' Enclosed are- o An application for Permit to Drill Kuparuk 1Y-8, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on April 19, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG2L47' 1 lm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA blL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~]( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE [~]X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 570' FNL, 1791' FWL, Sec. 1, T11N, R9E, UN At top of proposed producing interval @ Target: 1320' FNL, 1000' FWL, Sec. I T11N, R9E, UM At total depth 1443' FNL, 870' FWL, Sec. 1, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. PAD 67', RKB 96' I ADL 25646 ALK 2577 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 33 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 6685' MD, 6377' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT3600 feet. 21 14. Distance to nearest property or lease line miles @ Surface 3489' FEL feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 29 o (see 20 AAC 25.035 (c) (2) 9. Unit or lease name Kuparuk River Unit 10. Well number 1Y-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 18. Approximate spud date 04/19/83 15. Distance to nearest drilling or completed 1Y-1 well 360' ~ surface feet 2669 .. psig@ 80°F Surface 3040 psig@ 5907 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE [ 8,1/2" Hole Casing Weight 7" 26# CASING AND LINER Grade Couplinc_ H-40 PER K-55 BTC J-55/ BTC HF-ERW iK'55 I BTC _ 22. Describe proposed program: Length SETTING DEPTH MD TOP TVD 80' 29' I 29' 41 ' 29 ' I 29 ' I 2130' 70' ~ 70' I 28' I 28' 6657' MD BOTTOM TVD 109'I 109' 70'I 70' 2200'12200' I 6685 ' ! 6377 ' I QUANTITY OF CEMENT (include stage data) ±200 cf 800 sx AS III & 250 sx AS I 332 sx Class "G"extended 395 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 6685' MD, (6377' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA ROPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2669 psig. Pressure calculations are based on latest reservoir pressure data. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 1Y-1 will be 360' away from 1Y-8 @ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 2297' MD, approximately 500' MD 23. I hereby certify that the foregoing is true and correct to the best of my knowledge above top of West Sak Sands. SIGNED ?r~.~~is. n ~,~~' TITLE Area Drilling Engineer DATE ~//~'/~'..~ The space belo ~se CONDITIONS OF APPROVAL SamplesrequiredE]YES ~XIO I Mud log required[_]YES ~]JXIO IDirecti°nalsurveyrequired~YEs i--INO Permit number _ ~ ] Approval date ~3~6c ,~n~,J SEECOVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY~ /~~~,COMMISSIONER DATE k ~ '/' k ~~ ~~ by order oft he Commission Form 10401 GRU2/PD19 ~ Submit in triplicate · . · ~ 1 : i , ~ ~ ~ ~ I I ! ~ . , i , ~ I ~ ; ' i : : ' J I i '~ i ~~~ j ~ ' i j i I J I J ~ "i L, J I ; L =-~ - iiI , i,,, ;._ _ -iii Ii,! iLil _ILL': i J I J I J J l -iil l!Ji ~,~ iii': ii' j j j ! j i j i i , j J ~ ~ i I i ~ ~ ', i i , . _~., .~_ .... ~- ~7-~; , ~ ~ . : . : : ; - . : . , - ~ I ~ ' , , · ' ' - : "~' iii! illi,~ '~ ' ''' il ~ ~, } Hil '~ ,:,i ~,,, ~ ~~ ,~,, :,'. .,~ ' .'- ................... ~ ............ ! I ; i i I ~ I- i N~~'~ ~ i i i i :~:: ~~'~-t-~-- ~~-rs~r ......... :-t .............. -a ~ ~ , ~ KOP ~vut~~~,i6eU~~U · :~q ~ .... ~ ..... ~-,-. .......... : ....... ~ ..................... I--:---? ........ : ........ ' ; ~ ; ' ~ : : : : : ' ' : - --- ~ ........................ I .... ? ....... ~ ..... ~i . ~ ,-~ ~ e~~~4-'~; ----~-4--.;:~ ........ ~ ........................ ~ ....................... J- ..... ?~ i. I ;. ~ i i ~'¢!~i i i ~[ -: : J : :/ ; '. i~ : ~ ;~ ~ · i .................... ~ ............ i ........ ~ ............... ~ .... -- , : ~ : ! ~; --- ~;~ 'i:iprff~i ~ IIP=Wpl v, ~1~l 7~T~ i .................... ~ ..................... ~._M . . ~_~ ; : ~ : ; : ' : : i~--i ~ ;~-~- · ~ ~i ~ -~'-~-~-- ............................................................ t ..... , -'~T~ ~. : : : I :~ ; ~ ', i : T-¥~' :, : ~ ~ ~ I : ~ : ', ', , ~ , : ...... ' ...... i · 2. 3. ¢. . . Surface Diverter System 16" - 2000 psi Tankco starting head. Tankco quick connect assy. 16" x 20" 2000 psi double studded adapter. 20" 2000 psi .drilling spool w/!O" side outl ets. 10" ball valves, hydraulically actuaSed,~ w/lO" lines So reserve piS. Valves So open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. 1, Maintenance & Operation Upon initial installation close annular preventer and.verify that ball valves have opened properly. Close annular preventer and blow air :brough diverter lines 'every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diver:er line. Do not shut in well under any circumstances. 16" Conductor ANNULAR PREVENTER 9 BLIND RAMS PIPE ARMS ) S CSG HD £ D blGRAM ~ 1 13-5/8" 5000 PSI RSRRA BOP STACK Tankco starting head 1. 16" - 2000 psi 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool ~. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi dri111ng spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - 5000 psi blind rams " '9. 13-5/8' - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CI. IECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI OOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORO ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 4S SECONOS CLOSING TIME ANO 1200 PSZ REMAINING PRESSURE. 13-5/8' 80P STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH'ARCTIC DIESEL. 2. ,CHECK Ti.tAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- EO. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND'SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAl). 3. CLOSE ANNUI.~LR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. ~" 5. INCREASE PRESSURE T PSI ANO HOLE FOR 10 MINUTES. BLEED TO Z 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO(~PSI ANO HOLO FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTRF. JU4 PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI OOWNSTREAM. BLEEO SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAHS AND CLOSE BOTTOM.SET OF PIPE RAMS. lOo INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES 8LEEO TO ZERO PSI. I1. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT ANO PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLO ANO LINES ARE FULL OF ARCTIC DIESEL ANO ALL VALVES ARE SET IN ORILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANO SENO TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. ANNULAR PREVENTER 11 BLIND R~S · ) C I0 PIPE ARMS 9 <_. DRILLING i [ £. PIPE ARMS HD 2 CSG 12. , 14. :/<.. ? ~'. % * .:.~. . 16. 1. FILL BOP STACK AND HANIFOLD WITH ARCTIC DIESEL. Z. CHECK THAT'ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT Ill WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND..CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNUl.AR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD' FOR I0 MINUTES. 8. CLOSE VAJ. VES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WIllJ 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAH. BLEED SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAILS. INCRE/LSE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BO1-FOM SET OF PIPE RAHS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. OIAGRAN ~2 13-5/8" 5000 PSI RSRRA BOP STACK spool ' 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and ki'!l lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8" - 5000 psi blind rmms 1I. 13-5/8" - 5000 psi annular 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. !I" ~ 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7~:/:5" 3000 psi x ~1" - 3000 psi double studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPE~ LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIM)T IS 45 SECONDS CLOSING TIME AND 1200 PSI REblAINING PRESSURE. 13-5/8" BOP STACK TEST CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM (1) Fee (2) Loc APPROVE DATE thru 8) ,1. Is 2. Is 3. Is 4. Is 5. Is 6. Is 7. Is 8. Can permit be approved before ten-day wait (4) .,Casg ~.~~' ('12 thru 20) (2~ 'thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO (6) Ad d___~: the permit fee attached ............................... well to be located in a defined pool .................. well located proper distance from property line ....... well located proper distance from other wells ......... sufficient undedicated acreage available in this pool . well to be deviated and is well bore plat included ....... operator the only affected party ...................... Does operator have a bond in force ................................. - Is i ord eeded ~, a conservat on er n .................. ..... .............. ~' Is administrative approval needed .................................... ~~.. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and .surface ......... Will cement tie in surface and intermediate or production .s~.r~n.g.s. Will cement cover all known productive horizons ........... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ DoCs BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engi ~n_~e~r ing: HWK_~ LCS /~BEW ~ W~'A~ JKT ~ HJIt ---- ,! rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. -: · .. · 30NTINUA~ON # :01 ~OMME~TS :L~BR~RY TAPE 3RIGI~ :0000 2ONTINUATION # :01 PREVIOUS TAP~ { 2OM~NTS :LIBRARY TAPE SERVZCE NAME VERSION # DATE ~ MAXIMUM L~NGTH { 1024 FILE TYPE PREV~O[.IS FILE CN ~ ~RCb ,~bASK~ WN { 1Y-8 FN I KUPARUK TOWN: tln ~oo ooo ooo,~ ooooo oo~ o~ ooo ooo oo, o~, oooooo ~ O65 000 000 004 065 K SCXbU~B~R~ * ~ ALASKA,COmPUTING CENTKR * dELL = lY-8 ~]~LD = ~UPARUK STATE = ,~LASKA JOB NUMBER AT ACC: 68236 CASING = 9,625~ SURFACE Th 22~2' BIT SIZ~ = 8.1/2" VISCOSITY = 4~.0 S RMF P~ = 9,5 RMC · ~UA~, ~N~UCT~N ~PHE~CALt, Y ?~CI.I$~D 6~G fD~b) * , COMPENSATeD. NEUTRON bO~ fCNL) e · GAMMA RAY LOG (~R) * ****************************** DATA P~RMAT RECORD ~NTRY ~60CKS 4 $ 4 73 60 0 1 66 0 DATU~ SP~C[F)CATX0N BLOCKS DEPT SFLU NPH'! FDN DRHO RHO~ ~DN NCNL CALl GR FDN NRAT FDN RN~A FDN ORDER F? 0 0 GAPI PU',~ :4.,~~A31' ~/C3 4~ LOG TYPE CLASS MOD NO. LEVEL CODE 0 0 0 4 0 I 68 0 0 0 4 0 ! 68 0 0 0 4 0 1 68 46 0 0 4 0 1 68 0 0 0 4 0 I 68 32 0 0 4 0 I 6~ 0 0 4 o I 6B 4 0 I 68 8 o o I 0 ~ 0 68 0 0 4 0 1 68 o 0 4 0 I 68 0 4 0 1, 68 4 0 68 0 1 DATA ** )EPT 6566.5000 SWLU ~P. -24.5469 GR 97. ~HOF ~.4~i9 NCNL 2436. iR 97.3750 NRA? 3. }EPT 6500.0000 8FLU 4. 5P '20.5313 GR ~HO~ 2.4961 NCN~ 248R. ~P 107.4375 N~l? 4863 II, U 3750 NPHI 16MO IBM 43?5 NPHI 0000 FCNL 9707 R~RA 1055 IBM. 8125 NP~I 4199 RNRA 1250 NPHI 0000 FCN[, 5R79 RNR!. 7344 1875 NPH! 0000 go04 2r)zP't 61_oo',oooo s~i,u 697) ~hM BP. RHOB G~ ,142, D~PT RHO~ DEPT Sp RHOB g 00 1'. :ii: 3 !t l' t, M '36 ,,i57.8.750 ~!pH! · ,999 :: '".999'; ~':S:O:O' PCNL 157 8750 NRAT '909.~500 RNRI 5700. 0000 8Ft, U 4'.22e~ It,~ -38,-0625' GR : :~:t0:2:'~0000 :NP:HI -999,2500 NCNG -999,2500 FCNL 10:2.0000 :N:R~ :: .-0g:~:'25.00: R~EA RHOB 34,570] DRHO 717.5000 3.302? 1319~44 ls.sooo ..2,1262 41.6016 DRHO 521.0000 .8516 ~ 5391 DRHO 1002.0000 CAGI 2.9i80 )~,.o]13 DRHO st .~ooo t~.Olll DRHO 45,4599 RHO 451,.'500 ~AL! 158 7500 8000 0.0620 8.4922 0.01~ ~.8041 -0.002~ 8,6484 ?.1875 8.7969 1,.9238 . 0405 .5078 g..0474 .'24~2 -' ) DRHO -999,Z2500 -' CRt, l 9. 4844 999,2500 DRHO -999,2500 -g~:g'- 2500 CRLI ~. 6953 ~9~:.25:o0:' ,~o .¢g~: SOO -999,2500 ~hI 10.2266 '999,:2500 0 :-gO:g* 2'800 CA~I 9 bvP O~10'.HO~ V~RIt~CA?~bN ~',tS?TNG PAC,,~ 5 g'E J15~.0625 NRAT DEP? 5300.0000 SFLU SP. -49.9062 ~R EHO~ -999.2500 NCNL ~R 1.20.3125 NR~T SP. ' 41,0313 GE RHCqB 999. 2500 GE 176.7500 NRA. T ~? ~ooo~ SP.. "45. ~HOB '999. O~ 144. v~p~ 4~oo~ RHOB -999. RHOB GR DEPT .$p. RHO~ GR DEPT -999.~500 FCN[, -O99.2500 R~RA 3.5918 IbM 120.3125 NPH! -999.2500 FCNL -q09.2500 RNRA 3.2754 ~76.7500 NPH! -999.2500 RNRA 1.]344 ILM ,-201~. 750 NPH! -999.~500 ?CN~,, -999. 500 R~RA 0000 ~FLU 3~7676 ILM 0313 GR .1.44.6250 NPH! 2500 N~NL -999.~500 FCNL 6250 HRAT -999.2500 RNRA 0000 8Ft, U 3,7246 IL, 5313 ~R . ~,~0'00 :NP~! 2500 NCNL -999.~500 FCNI, 5000 ~ .i2o.oooo 999~500 -999.2500 RNRA 47ooLoooo srt, u ~,o3s~ '- O0 N N "999 ~500 FCNL '999,.25 C,,L ....... 4soo:,oooo srt,,u: :., ~::: It, M ,,5.1. o 3 1,05.4.375 NRAT .999.~500 RNRA , .: : ~. ~ ::.~ . 4500, LU ~.8750 TIM -999.2500 · .,~,~9.:~oo r,,,.,o ,.~,~.soo CA~Z -999.2500 2.6465 [LD. -999.2500 DRHO -999.2500 CALl -999.2500 2.7598 lbD. '999.2500 DRHO -999.2500 CALl -999.2500 ... 2~4004 ltD.. -999.2500 DRHO .~99.~,$oo c~t,l -999.2500 1.6210 II, D,. -999.2500 DRHO -999.2500 CAbI -999.~00 2'.8828 ILD- -999.2500 DRHO '999.2500 CAS! '999.2500 ILD_ DRHO -999.2500 CALl '999.,250~ · 999.2500 DRHO "9§9*2.50'0 CA:bi -999'.2500 -999.2)00 DRMO 1.327! =999.2500 9.3594 2.6289 -999.2500 10.4609 -999.2500 [0.6563 -999. 2500 9'-9062 1.6680 -999.2500 9.59]8 2,.?:520 -999.2500 8.9687 '999,25 9.8047 · 3. 3691 -999.2500 10.2344 2.6934 -999~2~00 9.6484 -999.2500 10.0547 -999. 2500 :,vp,olo'.,o2 v~I~'IC~TIaN t, ISTINC, p~ 6 )EPT 4400.0000 8rlLU BP. -53. 8437 GR JR 97.0000 NR~T , DEPT 4100.0000 8FLU SP~ .-52,406~ G~ ~HOB 999.2500 NCNb ~ 74.3i~5 NRAT OEPT 4200'.0000 SP- -57.5000 RI{OB -999.2500 NCNL GR 76.3125 ,,. DEPT 4100,0000 SFLU SP. .~54,,5313 C,R RHOB - 99, 2500 79.6875 NRAT ,, DEP? 4000 0000 SFLU SP. ,-57!0313 GR RHOP, 'P99 2500 NCN[, D.E.T) 0o2 o000 RHOB -999.~500 NCNb ~ 1,~9~ 1250 NR,A~ DEPT R,HOB DEPT GR EPT RHOB DEPT '999"2500 PCNL -999,2500 CAI, I -999.2500 2,4688 q?.O000 NPH! '999.~500 FCNL -099.2500 ~NRA 74.31~5 NPH! -999.2500 FCNL -~9~.~500 2.037t ILO. -999.2500 DRHO -999.2500 CALl -999.2500 · 2.2969 I[,D. -999.2500 DRHO -999.2500 ClbI -999.~500 76 3125 NPH! -~99~2500 ~CNt.! -999.2500 , 74 . 2..2~44 It, D. 999.2500 DRHO -999.2500 CAb! -999.2500 -90 ~500 DRHO '999.2500 C~bI -999.~00 SFLU 4 NCNb: :., 3 2109 87 2500 -999 2500 -999 2500 3,~9134 -999,2500 ~NL ~NRA FCNL 95. 8750 NRAT -999 RN!RA 3700,0000 SFLU .,:' ,]477 IbM. -999. 2500 NCNb ;999, q4'7500: : "999, "999.2500 DRHO "999~2500 C~%,,! -999.2500 -999~,2500 DEHO -999.2500 CILI -9:99.2500 -999.2500 DRHO C/~LI ILD. DRHO 3600 .. 000 O: < S~,l~l.! , '53,,3'415 GR , -9~9-~00 NCNb 79. 50 NRAT ,2:50'0: :PCNL 999'2500 CALl -999'2500 RNRA -999.2500 3,9082 -99:9.2~:00 D'RHO -999.2500 3400'. 0000 SFLU tO.lOi6 'o97 -999.2500 9.6437 -999.~500 10.1094 2.3633 -999.2500 10.6641 2,4863 -999.2500 10.4609 iO 17 -99 I00 . 3:,39 4 999.25 11.06~ ° 5 3. 6926 *999.2500 12.17:! 9 13.4609 2.7656 '999.2500 11,6875 . 4'2500 . 8692 4.4336 >EPT ~HOB DF.P? RHOI~ RHOB OEP? OEP? RHOB RHOB D£PT RHOB -57'0313 .2;080! NCNb 70.6875 NRAT · o :oooo 5 593O 2.093B NCNb ,6~, 6 9 NCNB 66.0000 ,ioo:oooo 64.5625 .2.1328 NCNb 74.2500 NRA? 32ooioooo S~hU 86 Bi25 , 2go0,0000 2,2090 ~1.5000 NR~T 2~00.0000 7~..6250 GR 58,20:12 .62~0 2700,~000 2~00, 77.. 12. 69. oo,oooo soo 0 6875 lqPHI 17 7;0000 F'CNL 3.4453 , 3 5762 82'.1875 1613,0000 FC~L 3.83~0 4~t875 0000 ?CUT, 3,B496 RNRA 7 * 996 .250 NPHI 1709.0000 FC~L, ~.7754 58 8.t25 NPHI 3.4805 RNRA o I:: ooo 16 0000 FCNL · .?,6484 IBM 58.6250 NPHI t$69.0000 ~CNL 3.74~ RNRA 18,5000 'Tt, M ', 71 ~. 625:0 0000 8:?I,,U 14:. 4g 22 ! DM 2305 N~N[., .0000 7500 NRA? 3.6133 oooo 8FLU 9.7188 It,~ 1§36 NCNb lgag. 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CALI t2.9297 0.029~ 13.5~59 39'.4063 -0 13 23.5469 -0.486~ 8.8359 DATE 1~3/05/ll OR~OT~ 1.0000 TAPE NAME ., :8236 CONT~NUATTON # 101 NEXT TAPE, NAME I =e3/05/11 ~ON?)NUA?~O:N :# ************************** *****************************
